Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
193-076
ULUGG- · LOCATION , REPORT State of Alaska Well }fame LccaZicn .%bnd Data & 9rccedur~. Review the well file, and' c~-~.en= on plugging, well head Co~c!usion.~: ~ Code · Date PHILLIPS PEkr OLEUM COMPANY P.O. Box 1967 Houston, Texas 77251-1967 6330 West Loop South Bellaire, Texas 77401 May 20, 1998 Sunfish No. 3 PPCo. Tyonek Platform NoAh Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Steve McMahon Gentlemen: Enclosed is a Form 10-407 (Well Completion Report), which states the abandonment characteristics of the Sunfish No. 3 well. After the Sunfish No. 3 was plugged back and temporarily abandoned in March / 1994, 9100' of 9 5/8" casing was recovered, a plug was spotted across the casing cut point, and the exsisting wellbore was utilized for the NoAh Cook Inlet Unit "B" No. 2 sidetrack (November & December / 1997). Enclosed with the well completion report are the following support documents: 1) The daily operations summarys (11-17-93 to 4-3-94 & 11-21-97 to 12-4-97) of the Sunfish No. 3. 2) A current abandonment wellbore diagram of the Sunfish No. 3. 3) The casing, liner, and cementing record of the Sunfish No. 3. Please reference the previous Sunfish No. 3 well completion report, dated May 3, 1994, for the remaining required documents, such as; logs, core data, geologic markers, directional surveys, and formation tests. No additional reservoir characterization data of the Sunfish No. 3 well has been acquired since it was temporarily abandoned in March, 1997. The AOGCC is requested to keep this report and the attachments confidential. Should you have any questions or require any additional information, please contact Paul. R. Dean at (713) 669-3502 or James C. Shoumaker at (713) 669-2197. Regards, N.P. Omsberg NoAh America Drilling Manager enc: cc: J.W Konst (w/o enc) W.L. Carrico " P.R. Dean (w/enc) J.C. Shoumaker (w/enc) · '~" STATE OF ALASKA ALA,~ .)IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well -- OIL GAS SUSPENDED ABANDONED X SERVICE 2. Name of Operator:. '7. Permit Number Phillips Petroleum Co. 93-76 3. Address: 8. APl Number 6330 W. Loop South, Bellaire, Texas 77401 50 - 883 -20090 4. Location of well at surface: Tyonek Platform Leg 1 Slot 6 ~ ' 9. Unit or Lease Name 1249' FNL & 980' FWL SEC 6-T 11N-R09W ~ North Cook Inlet At top of productive interval: NA ~ 10. Well Number t Sunfish No. 3 , . At total depth: 11. Field and Pool 4347' FSL & 1395' FWL SEC 31-T 12N-R09W 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Sedal No. Exploration 132 ft RKBI ADL 17589 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 11-19-93 03-04-94 12-01 -97I 100' feetMSLI None 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 14~705' (13,281 TVD) 9~014' (8~230"1'VD) YES X NOI NA Feet MDI NA 22. Type Electric or Other Logs Run NA CASING, LINER, AND CEMENTING RECORD :SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 457 B 55 407' Ddven None 20" 169 X-56 59 2~602' 24" Attached None 13-3/8" 72 ',180; Pll 59 8~909' 17 1/2" None 9-5/8"; 9-7/8" 53.5 & 62.8 ~180; Q12 57 12r 138' 12 1/4" 9~ 100' {211 its/ 7" 32 L-80 11,837 13,941' 8 1/2" None 24. Perforations open to Production (MD + -I'VD of Top and Bottom an(; 25. TUBING RECORD interval, size, and number) SIZE IDEPTH SET (MD) IPACKER SET (MD) 26. ACIDr FRACTUREr CEMENT SQUEEZEl ETC. DEPTH INTERVAL (MD/ DATE AMOUNT & KIND OF MATERIAL USED None - Well abandoned Openhole 13916' - 14214' 03 - 09 - 94 60 sxs "G" below retainer (~ 13916' Perf.'s 13594' - 13644' 03 - 28 - 94 50 sxs "G" below retainer @ 13489' 13656' - 13706' Perf.'s 12478' - 12502' ~03 - 31 - 94 80 sxs "G" below retainer @ 12375' 12526' - 12538' 7" Liner Top 11837' 03 - 31 - 94 88 sxs "G" balanced plug F/11950' to 11700' 9 5/8" Cut Pt. 9100' 11 - 28 - 97 555 sxs "G" balanced plug F/9200' to 8640' (NOTE: Ddd thru cmt to NCIU B-2 KOP ~ 8970') 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas, lift, etc.) Date First Production Hours Tested PRODUCTION FOR OIL - BBLs GAS - MCF WATER - BBLs CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ==> Flow Tubing Pressure Casing Pressure CALCULATED OIL - BBLs GAS - MCF WATER - BBLs OIL GRAVITY - APl (corr.) 24 - HOUR RATE ==> 28. CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Submitted core description previously with Form 10-407 dated May 3, 1994. -- Form 10-407 Rev. 12-1-85 CONTINUED ON REVERSED SIDE Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONv'~''' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 29. NAME Submitted geologic marker GEOLOGIC MARKERS MEAS. DEPTH previously with Form TRUE VERT. DEPTH -407 dated May 3, 1994 30. FORMATION TESTS Submitted test formations previously with Form 10-407 dated May 3, 1994. 31. LIST OF ATTACHMENTS Daily Operations Summan/(11-17-93 to 4-3-94 & 11-21-97 to 12-4-97)r Wellbore Diac~ram~ Liner/Cementing] Record 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ! · INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 12-1-85 PHILLIPS PETROLEUM CO Operations Summary Report Page 1 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: SUNFISH 000003 North Cook Inlet Unit B-2 Sidetrack POOL ARCTIC ALASKA Start: 1 1/14/97 Rig Release: 04/02/94 Rig Number: 429 Spud Date: 11/19/'93 End: Group: Date 11/21197 11123/97 11124/97 ,, iFrom - To · 12:00 - 14:00 "14:00 - 17:00 17:00 - 00:00 00:00 - 02:30 02:30 - 05:00 !05:00 - 06:00 i 06:00 - 07:00 !07:00 - 08:00 !08:00 - 14:00 14:00 - 17:30 17:30 - 20:00 20:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 05:00 ,05:00 - 06:00 I :: 06:00 - 07:30 07:30 - 08:00 08:00 - 19:00 19:00 - 20:00 20:00 - 23:00 23:00 - 00:00 00:00 - 01:00 01:00 - 06:00 Hours Sub t,.,o!h'naseI Code ! 2.00:, MV 3.00' DR 7.00~ OR 2.50' DR 2.50. DR 1.00 DR 1.00'. DR 1.00! DR f 6.00i DR 3.501WC 2.50 WC 3.0O WC 1.00' WC 2.00 WC 0.50' WC 1.50i WC I 1.00 WC 1.50i WC o.5oi wc 11.00~, DR 1.00 DR 3.00 DR 1.00: DR 1.00 DR 5.00; DR Description of Operations r :, 00Mb1 R 1 ;OOMM,R 1 , O0MMIR 1 95RNTR 8 95RNTR i5 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR ;95RNTR ;95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR i SKID RIG TO NCIU B-2. .~',.,4~--.a ~4,~. ~ !CHECK PRESSURE ON 9 5i8" CSG 0#. CHECK PRESSURE ON 9 5i8" x 13 3/8" ANNULUS 0 #. RD 11"10M x 13 5/8" SM TBG HEAD. NU 13 5/8" 5M x 13 5/8" 10M DSA, RISER, & DOPE. FINISH NU 8OPE & STRIP O MATIC. .CLOSE BLIND RAMS & TEST STACK TO 250/5000 PSI AGAINST CSG. TEST ALL CHOKE MANIFOLD, CHK LINE, KILL LINE & FLOOR VALVES TO 250/5000 PSI PU BIT #1 & BHA. TIH & TAGGED CMT (~ 335'. ClRC OUT 40 BBLS CONTAMINATED FLUID TO APOLLO F/ INJECTION. BUILD VOLUblE IN ACTIVE ORLG CMT FP-J 335 TO 468'. AT 468" PRESSURE BELOW CN1T PLUG PUSHED DP 2' UP HOLE. SHUT DOWN PUMP & OBSERVE WELL - STATIC. CONT ORLG CMT F~ 468 - 472'. CMT PLUG PUSHED DP UP HOLE 6'. BENT 2 JTS DP. SHUT WELL IN. WELL STATIC, SI PRESSURES = 0. LD BENT JTS. PU DART VALVE, I JT DP & 1 - 10' DP PUP JT. DRILLED FPJ 472 - 475'. PIPE WAS HYDRAULICED UP 6'. CLOSED RAMS TO HOLD DP. WELL STILL WOULD NOT FLOW. CIRCULATE THROUGH CHOKES. OBSERVED OIL & GAS IN ~ RETURNS. PLUGGED ALL CHOKES. CLOSED HCR VALVE. BLED OFF CHOKE MANIFOLD. CLEAN OUT HAND ADJUSTABLE, REMOVED HYD CHOKES & CLEAN OUT CMT. I NU CHOKES & RETESTED MANIFOLD TO 250/5000 PSI. OPEN HCR - WELL DEAD. OPEN PIPE RAMS & CIRCULATE OUT GAS CUT MUD THROUGH FLOW LINE. 3100 UNITS MAXIMUM & GAS DECREASING. ClRC OUT GAS CUT MUD. WASH DOWN TO 480". CIRC TILL GAS FELL BELOW 100 UNITS. MAX GAS 3100. POOH, LD 10' PUP & 1 BENT JT DP. AT"Ff'EMPT TO BREAK OUT GRAY VALVE BUT FLUID UNBALANCED. ClRC & COND MUD. LD GRAY INSIDE VALVE. POOH TO BHA TO CHECK F/BENT DP. PU 1 JT DP & TIH TO 462', TAG CMT PLUG. WASH DOWN TO 472'. PU i& MADE CONNECTION. THEN TAGGED CMT @ 464'. PLUGGED BIT. WORKED & SURGED PIPE IN ATTEMPT TO UNPLUG BIT W/NO !SUCCESS. WELL STATIC - WILL NOT FLOW. CONFIRMED PLUG STILL ~ 464'. POOH. CLEAN CMT OUT OF BIT & BIT SUB. INST FLOAT. TIH TO :472'. DID NOT TAG PLUG. HELD PRE JOB SAFETY MEETING. iTIH. STOP & ClRC OUT GAS CUT MUD ~ 1123', 2430', 3460', 5513', i7464'. GAS IN BOTTOMS UP PEAKING BETWEEN 3100 5513 UNITS. !CONTINUED TIH TO 8314'. DRAG INCREASED TO 40K. SCREWED IN ;WI TOP DRIVE & BROKE CIRC. EST ROTATION W/TOP DRIVE - 'TOOK 1700 PSI TO BREAK CIRC. CIRC BOTTOMS UP. WASH (ROTATING) FPJ 8314' - 9500'. CIRC & COND MUD. CIRC & COND MUD. PUMP DRY JOB. POOH. Pnn(ed: 03/31t98 4:38:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I11/2J.197 11/25/97 From - To 06:00 - 06:30 06:30 - 11:00 11:00 - 12:00 12:00 - 16:00 16:00 - 23:00 '23:00 - 00:00 i 00:00 - 02:30 '02:30 - 03:30 ~ 03:30 - 07:30 i 07:30 - 08:30 :08:30 - 10:00 10:00 - 13:00 13:00 - 13:30 13:30 - 16:30 11/26/97 11/27/97 11/28/97 16:30 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 02:30 ,02:30 - 05:00 05:00 - 07:00 07:00 - 09:00 ~ 09:00 - 14:00 '14:00 - 15:00 15:00 - 21:00 21:00 - 22:30 22:30 - 00:00 00:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 18:00 18:00 - 19:30 19:30 - 21:00 ,21:00 - 00:00 00:00 - 01:00 PHILLIPS PETROLEUM CO Operations Summary Report Page 2 of 21 SUNFISH 000003 North Cook Inlet Unit B-2 Sidetrack POOL ARCTIC ALASKA Start: 1 1/14/97 Rig Release: 04102194 Rig Number: 429 Spud Date: 11/19/93 End: Group: Hours Sub Co Phase, Code Description of Operations 0.50 OR 4.50' OR '4 1.oo DR 5 .t.00 OR 4 7.00 OR 4 1.00 OR 2.50 1.00 DR 4.00 FI 1.00 FI 1.50 Fl 3.00 FI 0.50 FI 3.00 FI 3.50,. FI ! 3.50i F1 0.50 FI 2.501 FI 2.50 FI 2.00 Fl 2.00 FI 5.00 FI 1.00 Fl 6.00; FI 1.5o! Fi 1.50! FI 8.50, FI 2.00; FI 1.50! FI 6.00i FI 1.50 FI 1.50'. FI 3.00 ': FI 1.00 DR j2 Y 7 '. 95RNTR ~ 95RNTR ,95RNTR · 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR J95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR '95RNTR :95RNTR ; 95RNTR ~95RNTR :95RNTR i 95RNTR (95RNTR {95RNTR ,, PU 9 5i8 CSG SCRAPER. TiH TO 9500' ( BROKE CIRC ~ 4860'). CIRC BOTTOMS UP ( MAX GAS 180 UNITS ). SLIP & CUT DRLG LINE. PUMP DRY JOB. POOH & LD BHA. PU 9 5/8" EZSV BP. TIH & SET BP @ 9437'. PRESS UP & TESTED BP TO 2500 PSI - OK. BROKE CIRC, MIXED & PUMPED DRY JOB. POOH w/EZSV RUNNING TOOL. POOH. LD RUNNING TOOL F/ EZSV. MU CSG CU'1-1'ER. TIH W/CSG CUTTER. CUT 9 5/8" CSG @ 9100'. CIRC BOTTONIS UP & PUMP DRY JOB. POOH W/CSG CUTTER. HELD PRE JO8 SAFETY MEETING. PU SPEAR ASSY & 2 - 8" DC'S. ENGAGED SPEAR. PU 650K LBS ( CALC'D BOUYED WT OF CSG = 475K) SLACK OFF. APPLY 1000 PSI PUMP PRESS TO 9 5/8". PU 650K AGAIN & PIPE STARTED MOVING. PRESS GRADUALLY BLED OFF BUT DID NOT CIRC. PU 60' SO THAT CUT & SLIPS WERE ABOVE ROTARY. RU WEATHERFORD'S 350T SPIDER. RELEASED SPEAR, PULL ASSY IOUT OF CSG. LD 2 8" DC'S & FISHING TOOLS. ~CHANGED OUT RIG ELEVATORS & BALES F/WEATHERFORD'S TOOLS & RU POWER TONGS. MU SWAGE, LOTORQUE & CMT LINE. iPRESS TEST TO 1500 PSI - OK. BROKE CIRC WHILE PU ON CSG. i : PU WT 500K. MIX & PUMP DRY JOB. !HELD PRE JOB SAFETY MEETING PRIOR TO LD 9 5/8. I POOH, LD 9 5/8" CSG. HOLE TRYING TO SWAB WHILE PULLING. iWlLL NOT FILL FR/ANNULUS SIDE. PULL SLOWLY & FILL PIPE I EVERY 5 JTS FPJ INSIDE. j BROKE CIRC ~ 8700'. MIXED & PUMPED 40 BBL DESCO/WTR PILL. [PUMPED 2 X BTMS UP ¢_., 900 GPM. Ii CONTINUE POOH LD 9 5/8" CSG STILL PULLING SLOWLY & FILLING i PIPE FR/THE INSIDE EVERY 5 JTS. ~: ClRC CSG @ 8200'. GAS 0 - 10 UNITS. ~ i CHANGE OUT ELEVATORS, SLIPS & TONG HEADS FOR 9 7/8" CSG. ~ POOH LD 9 7/8" CSG. CIRC BTMS UP @ 7785'. -' !CIRC & CHANGED OUT ELEVATORS, SLIPS & TONG HEADS F/9 5/8" ;CSG. CONTINUE POOH LD 9 5/8 CSG. ;CIRC BTMS UP WHILE WORKING BOAT. . CONTINUED POOH LD 9 5/8" CSG. FINISHED LAYING DOWN CSG FOR A TOTAL OF 211 JTS. RJD CSG TOOLS & SET WEAR BUSHING BREAK DOWN FISHING SPEAR. MU BIT & RIH TO 13 3/8" SHOE AT 8909' :WASH & REAM TO TOP OF 9 5/8" CSG STUB AT 9100'. REAM OPEN HOLE SECTION CLEAN & 8ACK REAM TO 13 3/8" SHOE AT 8909'. CBU FROM INSIDE SHOE. POOH TO PU CEMENT STINGER. FINISH POOH. Pnnled; 0~31198 4:38:24 PM PHILLIPS PETROLEUM CO Operations Summary Report Page 3 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/28/97 11129/97 11/30/97 From - To 01:00 - 02:00 !02:00 - 04:00 '04:00 - 07:30 07:30 - 08:30 :08:30 - 11:00 11:00 - 11:30 11:30 - 13:00 13:00 - 13:30 13:30 - 16:00 16:00 - 20:00 20:00 o 22:00 22:00 - 00:00 00:00 - 04:00 04:00 - 08:30 08:30 - 09:30 ! 09:30 - 12:30 112:30 - 19:30 19:30 - 21:00 21:00 - 21:30 21:30 - 22:30 22:30 - 00:00 00:00 - 05:30 05:30 - 09:30 09:30 - 10:00 10:00 - 12:15 12:15 o 13:30 SUNFISH 000003 North Cook Inlet Unit B-2 Sidetrack POOL ARCTIC ALASKA ' ] ' Hours ]Sub Co Phase. Code 1.00 DR 2.00 CE !2 195RNTR ; 95RNTR 4 '95RNTR 5 ;95RNTR 5 195RNTR 0 !95RNTR 13:30- 17:00 3.50~ CE 1.00 CE 2.5O CE O.5O CE 1.50 CE 0.50 CE 2.50~ CE 4.o01 CE 2.00 RM 2.00 DR I I 4.00i WC 4.50 RM 1.00 CS 3.00 RM 7.00 CS 1.50 CS 0.50 CS 1.00 CS 1.50 CS 5.50 CS 4.001 CS 1 i 0.50~ CS 2.251 CS 1.25'. CS Start: 1 1/14/97 Rig Release: 04/02/94 Rig Number: 429 Spud Date: 11/19/93 End' Group: 3.50. cs 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR 95RNTR Description of Operations i LD 12 1/4" BIT & 9 - 6 1/2" OC'S. i PU 2 7/8" DIVERTER SUB & 15 JTS OF 2 7/8" PAC DP. RIH W/CMT STINGER TO 13 3/8" SHOE. BREAK CIRC & WASH TO 9200' = 100' INSIDE 9 5i8" CSG STUB. CIRC & COND MUD FOR CEMENTING, ldo TOP SINGLE & RU HALLIBURTON, HELD SAFETY MEETING & TESTED LINES TO 2500 PSI. PUMPED 30 BBLS OF FW AHEAD OF 98 BBLS (555 SX) OF CLASS W/ADDITIVES AS PER PROG AT 17.0 PPG. BALANCED WI4.3 BBLS FW & DISPLACED W/148.4 BBLS OF MUD. PULLED 10 STDS. CIRC DP CLEAN. POOH & ldo 2 7/8" STINGER. CHANGED SWIVEL PACKING. PULL WEAR BSHG & SET TEST PLUG. TEST BOPE: U & L VB RAMS, C & K LINE VALVES/HCR'S TO 250~5000 PSI. ANNULAR TO 250~3500 PSI, FINISH TESTING BOP'S. NOTE: WITNESSING OF BOP TEST WAVED BY BLAIR WONDZEL W/AOAGCC AT 0845 HRS ON 11-26-97. HE ALSQ WAVED WITNESSING ANY CSG TESTS IN THIS SECTION AT 0926 HRS ON 11-28-97. CHANGED OUT BRAKE BLOCKS ON DRAWWORKS. ATTEMPTED TO TEST CSG TO 2000 PSI. PRESSURE LEAKED OFF TO 1700 PSI IN 17 MIN. PRESSURED BACK UP BUT LEAK OFF ONLY ;GOT WORSE. ,SLIPPED & CUT 119' OF DRILL LINE. REPACKED STANDPIPE VALVE. REPAIRED BLADDER IN KOOMEY BO"I-FLE. MU 12 1/4" BIT W/CSG SCRAPER. PU 30 JTS OF HWDP W/JARS & CONTINUE IN HOLE TO 8300'. WASH FROM 8300 - 8634' TAGGED HARD CMT. ' A'CFEMPT TO PRESS TEST CSG. APPLIED 2000 PSI BLED BACK TO 1800 PSI IN 2 MIN. WOULD NOT HOLD. !ClRC BO'CI"OMS UP. i PUMP DRY JOB & POOH. I POOH & LD BIT & SCRAPER. i PU R'i-'i'S TOOL & CIRCULATING VALVE. TIH & SET RTTS AT 4100', i(DV TOOL AT 4045'). 95RNTR iTEST BACK SIDE TO 2000 PSI FOR 15 MtN. OK. 95RNTR !RIH W/R'fiTS & SET SAME AT 7415'. (DY TOOL AT 7385"). 95RNTR iTESTED BACK SIDE (DV TOOL AT 7385'), TO 2000 PSi. PRESSURE BLED TO 1500 PSI IN 10 MIN. PRESS BACK TO 2000 PSl. PRESS FELL TO 1550 PSi IN 7 MIN & LEVELED OFF. PRESS BACK UP TO 2200 PSI. PRESS FELL TO 1750 PSI IN 6 MIN & LEVELED OFF. PRESS BACK UP TO 2200 PSI. PRESS BLED OFF TO 1750 PSI IN 6 MIN AGAIN & LEVELED OFF. PUMPED 6.5 BBLS & BLED OFF 6.0 BBLS. 1750 PSI = 14.5 EMWAT 13 3/8" SHOE & 15.3 PPG EMW AT THE DV TOOL. PRESSURED OOWN DP TO 2000 PSI. GOOD TEST ON LOWER CSG. BLED OFF PRESSURE. RELEASE & POOH WI RTTS. LD SAME. 95RNTR Pnnted: 03131,98 4:38:24 PM PHILLIPS PETROLEUM CO Operations Summary Report Page 4 of 21 Legal Well Name: Common Well Name: Even[ Name: Contractor Name: Rig Name: SUNFISH 000003 North Cook Inlet Unit B-2 Sidetrack POOL ARCTIC ALASKA SIart: 1 1/14/97 Rig Release' 04102/94 Rig Number: 429 Spud Date: 11/19/'93 End: Group: Date 1/30/97 From - To Ho6rs [Sub Co;iPhasei Code , Description of Operations 12101/97 1 2/02/97 12/03197 1 2/04197 17:00 - 19:30 19:30 - 00:00 00:00 - 01:00 .01:00 - 08:00 08:00 - 09:4.5 09:45 - 00:00 00:00 - 05:00 05:00 - 07:30 07:30 - 08:00 108:o0 - 11:00 ; 11:00 - 18:00 18:00 - 22:00 22:00 - 00:00 00:00 - 00:00 ; 00:00 - 02:30 :02:30 - 04:30 04:30 - 05:30 05:30 - 08:00 08:00 - 10:00 10:00 - 23:00 2.50 OR 2 4.50 OR 1.00 CE 7.0O CE 1.75 DR 14.25 OR 5.00 OR 2.50: OR 0.50; Ff' 1 3.00' DR 7.001 DR 4.ooi DR I 2.001 OR 24.00 DR 2.50 2.00 DR 1.00 DR 2.50 DR 2.O0; RM 13.00 ! OR iz ~m 95RNTR PU HYCALOG "STEERING WHEEL" POC BIT & STEERABLE BHA WI A SLICK 9 1/2" EXP MOTOR SET .~ 1.5 DEG. 95RNTR TIH. 95RNTR FINISH TIH W/POC BIT & STEERABLE BHA. 95RNTR DRILLED HARD CMT Fi8640' TO 13 3/8" SHOE AT 8909'. 95RNTR ~CONTINUE DRILLING C,'vlT F/8909' TO KICK OFF POINT AT 8970'. 95RNTR .ORIENTING & SLIDING WHILE TIME DRILLING TO KiCK OFF F/8970' TO 9003'. ONLY 20% FORMATION IN RETURNS AT REPORT TIME. 95RNTR . CONTINUE SLIDING WHILE TIME DRILLING TO KICK OFF WELL Fi9003' TO COAL AT 9014'. RETURNS WENT F/40% FORMATION TO 100% COAL. GAS WENT Fl8 UNITS TO 29 UNITS. DRILLED 5' MORE , : TO 9020'. ;&",4~ ~- · 95RNTR . CBU PRIOR TO LEAK OFF. GASRUNNING 18UNITS BACK GROUND :WHERE IT HAD BEEN 8 UNITS. LARGE COAL CHUNKS OVER , SHAKERS. 95RNTR iWlTH BIT INSIDE 13 3/8" CSG AT 8909'MD (8123'TVD), & W/10.5PPG : MUD, PERFORMED LEAK OFF TEST. LEAK OFF PRESS = 905 PSI = 12.6 EMW !95RNTR ', TRANSFERRED MUD F/PITS TO APPOLLO FOR INJECTION DUE TO HIGH PH OF MUD & SLIPPED & CUT 153' OF DRILL LINE. 95RNTR CLEANING PITS IN PREPARATION FOR BUILDING OIL BASE MUD. OPERATION SLOWED DUE TO APPOLLO'S LIMITED INJECTION RATE OF CUTTINGS & WASH WATER. 95RNTR MIXED & PUMPED 30 BBL SPACER. TRANSFERRED & BUILT 300 BBLS OF OIL BASE MUD IN RIG PITS TO 11.0PPG. )5RNTR BEGAN DISPLACEMENT BY PUMPING 300 BBLS OF 11.0 PPG OIL BASE MUD & TAKING RETURNS TO APPOLLO FOR INJECTION. WILL HAVE TO DISPLACE HOLE IN 300 BBL BATCHES DUE TO LIMITED PIT SPACE & APPOLLO'S ABILITY TO INJECT RETURNS FAST ENOUGH. 95RNTR CONTINUE BUILDING 300 BBL BATCHES OF OIL BASE MUD TO 11.0 PPG & DISPLACING HOLE WHILE TAKING RETURNS TO APOLLO !FOR DISPOSAL. HAD TO SHUT DOWN SEVERAL TIMES BECAUSE I, APOLLO NEEDED TIME TO THIN & DISPOSE OF THE WATER-BASE MUD. MUD RETURNS STILL THICK & CONTAMINATED WI ,,WATER-BASE MUD. 95RNTR i Build oil-base mud & displ out contaminated water-base/oil-base mud. 'Apollo having to work at dealing w/thick mud. MW 10.7#. 95RNTR Mud returns became better while circ oil-base mud & screens working OK at 750 gpm. 95RNTR Washed to bottom. Had 1 spot dght below shoe taking weight, then cleared up. Took 15,000#,,vt at 8980'. Picked back. then ,,vent back down thru spot w/no wt. WIH to TO 9020'. 95RNTR Started drilling. Rotated 20', l~en slid. Screens became unable to handle pump rate due to thick contaminated mud. Pulled one screen f/end of one shaker. Drilled to 9039' but DP screen & pump suction plugging up w/ coal. Put 10 mesh screen back on & cleared pump suction. 95RNTR At. tempt to ddll but blew pop off valve on # 1 mud pump 3 [Jmes. Repaired same. 95RNTR Drilling directionally f/9039' to 9,256' MD (8,441' TVD). Total sliding time 5 hrs; rotating time 11-1/2 hrs. Last survey at 9156' MD: 22.83 dec incl, Prmled: 03131,98 4:38:24 PM l ~30" Drive Pip ~ 407' 20" @ 2,602' DV Tool @ 4,045' NCIU "B" No.2 ST 9,200' 11 DV Tool @ 7,385' 13 3/8" @ 8,909' KOP ~ 8,970' Cut 9 5i8" @ 9,100' TOC @ 11,000' 7" Liner Top @ 11,837' 9 5~8" @ 12,138' Sub "C" EZSV @12,375' Packer & TCP Guns 12,478'-12,502' 12,526'-12,538' .~unfish Perfs. iCMT:PEUG .-=:;::-:! '::: ;.:::' :i i 14,214' j Total Depth: 14,705' EZSV ~ 13,464' Halco BWD @ 13,482' Perm. Pkr / TCP Guns 13,594' - 13,644' 13,656'-13,706' EZSV @ 13,916' 7" @ 13,941' CASING & CEMENTING DIAGRAM BPV (Make, T'~ae, OD) Not Applicable RKB Tbg. Hgr.(Make,Type) Not Applicable RKB-THF: Annulas Fluid: 13.6 ppg mud between all cement plugs RKB-MSL: TOC ' Water Dept OD I Top I Bottom I w'r I OradeJ Conn. J Burst I Collapse J Tension ' 30" I 55 - 2o- I 59 13-3/8" 59 13-3/8" 3804 · 9-5/8- I 57 9 7~8" 1014 9 5~8" 2117 . 7" 11837 Structural Casin,cj: Drive Pipe 407 1457-0 PPf I I I I Conductor Casing: 2602 J169.0 pp J X-56 J r,I- Qu,p J J 3804 761 8909 2433 Surface Casing: 72.oo pp N-80 BT&C 4730 2520 72.00 pp P-110 BT&C 7400 2880 Intermediate Casing: 1014 53.5 ppf N-80 BT&C 7930 6620 1329 2117 62.80 pp Q-125 BT&C J 12138 53.5 ppf N-80 BT&C J 7930 6620 1329 Production Liner CEMENTING SUMMARY i Date casing sbin~ Description 11/25/1993 2o" Cemented 20" with 1070 sxs 12.8 ppg Class "G" with 0.25 cjal/sx D-77.0.05 gal/sx D-47 and 0.28 gal/sx D-75. Tailed with 600 sx Class "G" mixed at 15.8 ppg with 0.25 gal/sx D-77 and 0.05 gat/sx D-47. Cement circulated to sun'ace. 12/18/93 13318" Cemented I st Stage of 13 3/8" with 900 sx 12.5 ppg Class "G" with 1.0% D-65 and 0.05 gal/sx D--47. Tailed with 700sx Class "G" mixed at 15.8 ppg with 0.05 gal/sx D-47. 0.5% D-59, 0.15 gal/sx D-801, 0.4% D-65, 0.10 % D-134 and 0.25% S-1. Stage tool ¢,, 7~385' Stage tool ¢~, 4,045' Cemented 2nd Stage of 13 3/8" thru DV tool at 7,385' with 3r700sxs 15.8 PPg class "G" With 0.1% D-65~ 0.1 gal/sx D--47~ 0.1% D-135~ 1 gal/sx D-60Oand 0.3% D-800. Cemented 3rd Staqe of 13 3/8" thru DV tool at 4.045' with 1,000 sx 15.8 ppg Class "G" With 0.2% D-65. 0.1 gal/sx D-47.0.1 gal/sx D-135. 1 gal/s× D-600 and 0.3 gal/sx D-801. )1/16/94 9 5/8" & 9 7/8" Cemented 9 5/8" with 1,000 sx 15.8 ppg Class "G" wilh 0.1 qal/sx D-47.0.01 gal/sx D-080. 0.10 gal/sx D-135~ 1.00 gal/sx D-600 and 0.06 gal/sx D-801. Estimated TOC at 11 000'. 02/23/94 7" Cemented 7" liner with 674 sx 15.8 ppg Class "G" cement with 0.10 gal/sx D-47, 1.50 gal/sx D-600, 0.1 ~]al/sx D-135. 0.07 gal/sx D-8 and 0.03 gal/sx D-801. ABANDONMENT PLUGS 03/09/94 7" Set EZSV Cement Retainer at 13.916'. Cemented with 70 sx Class "G". Pumped 58 sx below retainer, 12 sx (50') on top of retainer. 03/28/94 7" Set EZSV Cement Retainer at 13~464' (WL depth). Cemented with 58 sx Class "G". Pumped 50 sx below retainer, 8 sx (30') on top of retainer. 03/31194 7" Set EZSV Cement Retainer at 12,375' (DP depth). Cemented with 68 sx Class "G" Pumped 58 sx below retainer, left 100' on top of retainer. TOC ~ 12,275'. 03/31/94 7" Spot 68 sx Class "G" cement plug 11,950' - 11,700'. 11/24/97 7" Set EZSV Bridge Plug at 9~437' (DP depth)~ test same to 2500 psi (Test Good). 11/25/97 9 5/8" Cut 9 5/8" casing at 9,100' and recovered 211 its. 11/28/1997 9 5/8" Stub Spot 555 sx Class "G" 17.0 ppg cement pi 9.200' - 9.1oo' (Inside 9 5/8" Casing stub) 9,100' - 8.909' (12 1/4" Openhole) 8.909' - 8,640' (Inside 13 3/8" Casing) 12/0119/ 12 1/4" Openhole Drdled out cement to KOP from 8640' to 8970' (Cutbng 100% formation for NCIU "B" No. 2 S [ at 9014') NOTE: Depths measured from KB PBTD: 9014' MD TVD: 8230' Well: Sunfish No. 3 Drill Deck 59.00 132.00 100.00 Location: T¥onek Platform Cook Inlet~ Alaska Field: North Cook Inlet I Date: 05/20/98 jcs Casing size 30" 20" 13 3/8" 9 5/8" 9 7/8" 9 5/8" 1, CASING, LINER AND CEMENTING RECORD ' SUNFISH No. 3 Weight , per Foot 457 169 Grade "BI! X-56 Top 55' 59' 72 !.N-80; P-110! 59' Stage Collar for 2nd St, age @ 7,381'. Stage Collar for 3rd Stage @ 4,045'. 53.5 62.8 53.5 32 N-80 Q-125 N-80 L-80 57' 1,014' 2,116' 11,837' Bottomi Hole Size 407' 2,602' NA 24" 8,909' 17 1/2" 1,014' 2,116' 12,138' 13,941' 12 1/4" 8 1/2" Cementing Record Driven 1,070 sx "G" @ 12.8 lb/gal + 600 sx "G" @ 15.8 lb/gal. Stage 1 900 sx "G" @ 12.5 lb/gal tailed with 700 sx "G" @ 15.8 lb/gal. Stage 2 3,700 sx "G" @ 15.8 lb/gal Stage 3 1,000 sx "G" @ 15.8 lb/gal 1,000 sx "G" @ 15.8 lb/gal ;***NOTE: 9 5/8" & 9 7/8" csg's iwere cut @ 9100' and removed !from the well, with 555 sxs "G" balanced plug from 9200'- 8640'. ***NOTE: Drld thru cmt to NCIU B-2 KOP Of 8970'. 130' cmt remaining over 9 5/8" stub w/100' below cut pt. 674 sx "G" ~, 15.8 lb/gal PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY May 6, 1997 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: Phillips Petroleum Company is considering using the Sunfish #3 well as an alternative to inject oil based mud and drill cuttings generated while drilling the N.C.I.U. #B-1 well. The disposal waste would be injected down the 9-5/8" X 13-3/8" annulus at a depth of approximately 8909' MD (8120' TVD). We are asking for approval to perform a pump-in test using water to determine if it is mechanically possible to inject into this zone. If successful, we will then proceed with obtaining approval for annular injection of oil based cuttings. I have attached an Application for Sundry Approvals, wellbore schematic, wellhead drawing, directional survey and procedure for the proposed work. If you have any questions regarding this, please contact Shonna Boyer at (713) 669-7980 or Paul Dean at (713) 669-3502. ,¢r-¢.' ~-~ .¢¢-- .~,~ ~t'(;,~c,~~ Sincerely, ~ h~ ~~ ~ 7e. ~-~. N: P. Omsberg ~ ¢/~[?e Drilling Manager Phillips Petroleum Company NPO/smb CC: J. R. Soybel (r) P. R. Dean W. L. Carrico S. M. Boyer J. D. Admire A. J. Lasche' ,~TATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR 1. Type of Request: Abandon ~ Suspend ~ Alter Casing __ Repair Well Change Approved Program ~ 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire, Texas 77401 4. Location of well at surface: 1249' FNL & 980' FWL Sec 6 - T11N - R9W At top of productive interval: 12478' MD SUNDRY APPROVALS Operation Shutdown Plugging ~ Time Extension Pull Tubing ~ Variance ~ 5. Type of Well Development ~ Exploratory ~X Stratigraphic Service Leg 1, Slot 6 PPCo. Tyonek Platform North Cook Inlet, Ak. 11329' TVD At effective depth: 13866' MD 12540' TVD At total depth: 15400' MD 4530' FSL & 1486' FWL Sec 31 - T12N - R9W 12. Present well condition summary: Total Depth: measured 15400 true vertical 14150 14150' TVD Reenter Suspended Well~ Stimulate Perforate~ Other ~ (annular inj) 6. Datum elevation (DF or RKB) RKB 132 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number Sunfish 3 9. Permit Number / Approval Number 93-76 10. APl Number 50-883-20090 11. Field / Pool Cook Inlet / Belu~la / Sunfish feet feet Effective Depth: measured 13866 feet true vertical 12540 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size 30" 20" 13-3/8" 9-5/8" 7" Cemented Driven 1700 sx CI "G" 6300 sx CI "G 1000 sx CI "G" 675 sx CI "G" Measured Depth 407 2602 8909 12138 13941 True Vertical Depth 4O7 2535 8125 11016 12604 Perforation Depth: measured 12478'- 13706' ~ue ve~ical 11329'-12404' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) NONE NONE MAY 19 1997 Alaska .0i! ,& Gas G0ns. ,60_m_.m_iss~u' 13. Attachments: Description Summary of Proposal Detailed Operations Program BOP Sketch ~ 14. Estimated Date for Commencing Operations: Ma~/15, 1997 16. If Proposal was Verbally Approved: Oil ~ Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~~'~¢~'~'6-~-/0~'~ N.P. Omsberg Title Drilling Manager FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so Representative may witness Plug Integrity ,~ Mechanical Integrity Test Approved by Order of the Commission Form 10-403 Rev. 06/15/88 15. Status of Well Classification as: Gas __ Suspended X_~ I Approval No. BOP Test__ Location Clearance __ ,'~ - ~¢ Subsequent Form Required 10- ~oflr t~,~,~,,,~'~, O'~ "~ -i~ "~ ,~,',~nal Signed By ,~,,~a O~~ ~ ~.¢'"- ~O6~ , . ~ 0a~id W, Johnston ..,¢ G¢~/~omm,ss,oner Date~~ '~¢~ SUBMIT IN TRIPLICATE 14,214' Tota~ D~ = 14,705' 30'@ 407 DV Tool @ 4,045' DV Tool @ 7,3~5 13 3/8' @ 8,909' TOG@ 11,000' 9 SiS' @ 12,138 F_ZbN 12.375' Packet & TC~ C~rm .12478-12~02' Halco B943 @ 13,48~' ~4ard'mh P~'~I 13.594-13644' --~ 13658-137(~' EZSV 13,916' 7 · @ 13,93~g' ~f. fi~,~.t M · k e,'13'pe) Not Appllcabl~ ~ .... ulus ~uld: 13.6 Ib/~al Iud ~t~a allcem-" pla~s ~R~LSL: 1~.~ [ ;: WA~R D~H: .OD'" [.. ToP. J ~ttom ~ I Gn ] ~nn. J. B~I ] ~11 ~ Tcnanl 1 ',~'. I ss ~ .~s~,J . w~ ' 20' I 59 2,~ 1691b~ ] X-~ DHl-~ulp i3~' [ 59' 8,~ ~lb~- ~ ~7.m[P-~o BT&C ~'~ ~ ~'~ ~l BT~C I Pr~uctlo. Liaer ' 7' ~ 11,~ 13,~! ~l~a Dc~cdp<lc~ CEMENTING SUMMARY Dat~ Caaing String Deacripllon t 1/25/93 2O · 1~18/93 01116/94 13 3/8" Stage tool @ 7,385' Stage tool @ 4,045' 9 5~ · 7· Cemented 20' with 1070 sa 12.8 lb/gal Cla~a 'G" with 0.25 gat/~ D-T/, 0.05 gal/ax D-47 and 02.8 gal/ax D-75. Tailed with 61210 ax Ciasa "G" mixed at 15.8 lb/gal with 0.25 gal/ax D-77 and 0.05 gal/ax D-47. C~mcnt circulated to surface. Cemented fat Stage of 13 3/8' with 900 ax 12.5 lb/gal Cla~s "G" with 1.0 % D-6 and 0.05 gal/ax D-47. Tailed with 700 ax Claxa 'G' mixed at 15.8 lb/gal with 0.05 gal/sa D-47, 0.5 % D-59, 0.15 gal/ax D-801, 0.4 % D-65, 0.10 % D- 12~ and 0.25 % S- 1. Cemented 2nd Stage of 13 3/8' thru DV tool at 7,385' with 3,700 ax 15.8 lb/gal Cla.~ 'G" with 0.1% D-65, 0.1 gal/ax D-47, 0.1% D- 135, I gal/ax D-600 and 0.3 % D-800. Cemented 3rd Stage of 13 3/8' thru DV tool at 4,045' with 1,000 ~x 15.8 lb/gal Class 'G' with 0.2 % D-65, 0.1 gal/~ D-47, 0.1 gal/ax D- 135, 1 gal/ax D-600 and 0.3 gal/ax D-801. Cemented 9 5/8' with 1,000 ax 15.8 lb/gal Ciasa "G" with 0.1 gal/ax D-47, 0.01 gal/ax D-080, 0.10 gal/ax D- 135, 1.0 gal/ax D-600 and 0.06 gal/ax D-801 Estimated TOC at 11,000'. Cemented 7 · llnex with 674 ax 15.8 lb/gal Cla.~ "G" cement with 0. I0 galAx D-47, 1.50 gal/ax D-600, 0.1 gal/ax D- 135, 0.07 gal/ax D-8 and 0.03 gal/ax D-801. ABAN-DONMENT PLUGS O3/'28/94 03/31/94 7 · 7 · 7m 7m 9 5/8" Set EZ. SV Cemcnt Rctaincr at 13,916'. Ccmcntcd with 70 ax Cla~ "G". Pumped 58 ax b~low rctaincr, 12 ax on top of rctainer. PBTD 13,866' MD (12,533' TVD). S~t EZSV Cement Rctaincr at 13,464' CWL depth). Cemented with 58 ax Cla~ Pumped 50 ax b~low retainer, 8 ax (30') oa top of retainer. Set EZSV Cement Retainer at 12,375' (DP depth). Cemcnted with 6,8 tx Clas~ Pumped 58 ax below retainer, left 100' on top of retainer. 'lOC @ 12,275'. Spot 68 ax C1a$$ 'G" ocmcnt plug 11,950' - I1,700'. Spot 68 ax Cla~ "G" ct:mcat plug 300' - 500'. PBTD: [ Su pr:. [ Tbg Wi: Well: Sunfish No. 3 April 28, 1994 Dy_~tiou: Cook lnlet~ Alaska Field: Cook Inlet Unit PRD Il" l opoo S? MAY 19 '1997 .~.a~c~ .Qil .& Gas C,.)nso (,un-m~iss,,-" "- .... ~chorago Procedure for Sunfish #3 Annular Injection Pump-In Test 1. MI & RU test pump. 2. Check for pressure in 9-5/8" X 13-3/8" annulus. 3. Bleed off any pressure in 9-5/8" X 13-3/8" annulus. . Begin to pump down the 9-5/8" X 13-3/8" annulus and determine pump-in rates and pressures. It may take 4000 psi to pump into the formation. DO NOT EXCEED 4300 PSI. . After determining pump-in rates and pressures, shut down pumps. Displace entire annulus with inlet water to prevent a solids bridge. 6. RD & MO test equipment. PHILLIPS PETROLEUM DRAWER 66 KENAI, ALASKA 99611 NORTH AMERICA PRODUCTION Kenai Profit Center August 15, 1996 Blair E. Wondzell, PE Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950i-3192 Subject' Suspended and Other Wells COMPANY RECEIVED AUG ] 9 1996 Alaska Oil & Gas Cons. Commission Anchorago Dear Mr. Wondzell, As per to your letter on this subject dated July 15,1996, AOGCC records indicate that Phillips Petroleum Co. has four wells that need work and/or location inspections in 1996. Item Well Name & No. Loc, sec, T, R, M Description of What's Needed 1 Sunfish #3 2 Cook Inlet St #1 A 3 P.T.U.N. Staines R 1 4 Sullivan # 1 Sec 6, 11N, 9W, S Sec 6, 11N, 9W, S Sec 8, 9N, 24E, U Sec 10, 22S, 21E, CR. Suspended well Suspended well Susp. Well, WH rptd leaking Susp. Well, no surface plug The following are Phillips' plans for each well: 1. Sunfish #3~ 93-076. This well is suspended pending further evaluation and/or development of the Sunfish formation. . Cook Inlet St. #1A~ PTD 62-028. An intensive search for additional information is being made within Phillips' Kenai, Houston, and Bartlesville offices. Once those searches are complete a proposed plan for this well will be transmitted to the AOGCC. . PT Unit N. Staines River #1, PTD 81-069. Plans and procedures for well plug and abandonment and site remediation are being developed. Once completed the plans and procedures will be transmitted to the appropriate agencies for approval. P & A Operations are tentatively scheduled for 1996 - 97 with Site Remediation planned for 1997. Blair Wondzell, AOGCC -' Suspended and Other Wells August 14, 1996, Pg. 2 of 2 . Sullivan #1, PTD 00-051. This well location was reviewed in July, 1993, in accordance with the Alaska Department of Environmental Conservation (ADEC) June 1991 guidelines entitled ltTterim Site Assessment G~tida~ce for h~ctclive Dril/i~g 14/ct.s'le Sites. A three member field team spent 4 hours trying to locate the Sullivan #1 well site in heavy foliage near the Little River and Lare Glacier. A GPS, quadrangle topographic map, field compass, and air support were used to establish (with an accuracy of 75 feet) the wellhead location. The surrounding 300 by 500 foot are was searched for remnants of a wellhead, reserve pit, and well site debris. No apparent evidence of the wellhead or reserve pit could be found:_ Additionally, no evidence of leakage, seepage, or vegetation stress could be found. Based on the July 1993 site review no further action is recommended fbr the Sullivan #1. The findings of a benefit and impact evaluation estimated that the impacts of implementing an action plan would exceed the benefits of an action plan. No Further action is warranted because actions implemented to reduce an already negligible risk would create more risk to human health and the environment than the no action alternative. A copy of the 1993 site assessment is available for your review. If you have any questions concerning these wells please contact Len Janson of this office (907-776-8166). Sincerely, Phillips Petroleum Company CC~ P Dean L Janson S Arbelovsky S Mc Gee file E14-6(~) E14-2 El4-1 E1-21(~5) N. STAIN-ES RIVER STATE #1 SULLIVAN stnqF~SH /;3 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 15, 1996 Mr. John Landrum Phillips Petroleum Company Drawer 66 Kenai, Alaska 99611 Subject: Suspended and Other Wells Dear Mr. Landrum' Our Location Clearance Status records show that Phillips Petroleum Co. and Phillips Kerr have some wells that need location inspections and two wells that need well work. Our records, copy attached, show the following wells need work and/or location inspections in 1996: Item Well Name & No. Loc, sec, T, R, M Description of What's Needed Sunfish #3 Cook Inlet St #lA P.T.U.N. Staines R 1 Sullivan #1 Sec 6, 11N, 9W, S Sec 6, 11N, 9W, S Sec 8, 9N, 24E, U Sec 10, 22S, 21E, CR. Suspended well Suspended well Susp. well, well head reported leaking Susp, well, no surface plug 1. Sunfish #3, 93-076. Our records show this well suspended - surface location is Platform "A", Leg 1, Slot. 6. well appears to be properly suspended with the formation abandoned and a surface plug from 500' to 300'. No additional action appears necessary to maintain as "suspended"; however, please advise as to your plans for this well. 2. Cook Inlet St. #lA, PTD 62-028. Our records show this well was drilled from a barge. Several intervals were production tested; as testing moved up hole, the last-tested interval was squeezed before perforating the next interval. The upper most interval tested and squeezed was 31 50 -31 55' (sqz'd w/245 sacks). The final daily report: "8/2/64 Moved drilling barge off location. Well is shut in producing well." Our records do not indicate any subsequent work done on the well or any plugs shallower than 31 50' - as such, this well is not properly abandoned. If you have additional data, please provide us a copy; tell us of your. plans for this well. 'Mr. John Landrum Phillips Petroleum Company 2 July 15, 1996 3. PT Unit N. Staines River #1, PTD 81-069. Leon Lynch, DNR, reported surface valve leaking problems with the P. T. Unit North Staines River//1 well. Following his lead, Fairweather submitted a report to the Commission for the work they had done last summer; this data showed significant pressure on the inner and outer annuli and showed well head equipment that was deteriorating to the point of leaking. This well is in violation of AOGCC regulations, 20AAC25. Within 30 days, please advise this office of your plans to correct the deficiencies. 4. Sullivan #1, PTD 00-051. Our records on this well indicate the top plug is at 1 25'.. if your records show differently, please provide us with the additional data; otherwise, plan to place the surface plug in this well and notify us of the opportunity to perform a location clearance inspection. Sincerely, Blair E. WOndl~i, PE Senior Petroleum Engineer cc: Paul Dean Attachments ~/0 ~/~b ALJtSKA WELLS LOCATION CLEAR3UNCE STATUS PAGE 1 PERMIT 00-0050-0 00-0051-0 00-0109-0 NEW COD LOC CLEAR D'CLEAR-PRE Z'NOT-PLUGGED 4-RDY-FOR-INSP OPER3ITOR WELL NAME PHILLIPS KERR SULLIVA/q 2 SULLIVAN 1 SULLIVAN STRAT 1 PHILLIPS KERR SEC 09 10 20 WELL TWP RNG MER STATUS 22S 021E C P&_A 22S 021E C P&_A 22S 022E C P&_A ~1U'1/96 ALASfCA WELLS LOCATION CLEARJ%NCE STATUS PAGE 2 OPERATOR PHILLIPS PETR PHILLIPS PETR NEW PERMIT COD WELL NAME 82-0042 TERN A - SRS 1 93-0076 SUNFISH 3 62-0028 COOK INLET ST 17589 1-A 66-0025 COOK INLET ST 18741 2 65-0030 COOK INLET ST 18740 1 73-0016 N TYONEK ST 58838 1 76-0059 BIG RIV A-01 81-0069 P.T.UN.N.STAINES RV.1 LOC CLEAR C*CLEAR-UW S*SUSP-WELL .. Y*COND-UK ~.. C*CLEAR-UW C*CLEAR-UW 6-CLEARED 6-CLEARED WELL SEC TWP RNG STATUS 19 10N 010W P&A 06 liN 009W SUSP 06 liN 009W SUSP 08 liN 009W P&A 11 liN 010W 25 13N 011W P&_A 15 495 068W 08 09N 024E SUSP STATUS DATE 8/28/82 4/o2/94 5/lg/73 5/15/73 5/1~/73 8/12/73 3/25/77 5/06/82 ** THIS LIST EXCLUDES WELLS WITH LEASE FED-NPP~A ** 9 3 -0 7 6 x, 3- 07'6 q3-076 93~076 93~076 93-076 9~°-076~ ~ 93-076 93-n'76,~ 93-076 93 -0 ? 6 93-076 93-0}6 5:3 -{3'76 rJo-076 93-076 93-076 9.3 - 076 q3-076 '~ AOGCC indivluuc~l Well ~a~e~!~s IItvellLo.,. ,. .... ~iogical .... ' -~ 6393 407 CORE ~"'?~' ? '- CORE DESCRIPTiu:-:~ ~Rf 12o85 1Z306 CORE DESCRIPTION ~/!2~05-!2~65 CORE DESCRIPTION Rz 13628-13641 CORE DESCRIPTION ~,c~ DESCRIPTION 12285-1 WELL OP ~"-'ST SURVEY CBT "'~ /Gx CDR CET-VD ~-~ ~ ..~, / ~ ~,.- GR CNL/DLT DDL DSI FMi FMS LDT/GR '~602-14670 LDWG OH EDIT /Cr'~r° DATE'04/02/94 p~2285-14365 ~. 03/13-03/22/94 P~,~O. 00-1470=; Ai~AuRiLL"~ ~ - FINAL BAKER-HUGHES .~i813-13750 =J~i0100-12~00 TVD -8844 ~1813-i°7~'~ 'o 594-17678 ~700-14000 ~600-13200 TVD ~594-i7622 ~94-17622 ~!2135-i3702 ~z3926-14638 ~600-13200 TVD ~594-8884 INTEQ P age: Date: RUN 1-4 ]. 2 3 4 1-2 I 1 1 1 1-4 1 1-4 1-4 4 1 . 10/13/95 DATE_RECVD o2/o6/~5 05/09/94 05/31/94 05/09/94 05/09/94 05/09/94 05/09/94 05/31/94 05/09/94 os/15/~ 05 / 09 / 94 08/01/94 05/10/94 08/01/9~ o5/io/~4 o5/io/9~ O5/lO/9~ 08/15/94 08/01/94 o5/~o/9~ 05/10/94 05/10/94 05/10/'94 08/01/94 o5/~o/9~ PERMIT DATA 93-076 ML 93-0 / 6 ML 93-076 MSD DiP 93-076 MSD DIPS 93-076 ~ D~L 93 -076 MUD ~3-07b Muu ~ 93--076 MUD p~ 93-076 HUD ~- HuD 93 076 '~ ? e~ s-0/e PDi/~:~ 93-076 PDL 93-076 PDL ~-0u6~ , PDL 93~076 RFT 076 RFT AOGCC !n~iv!~ual well Geological Natezm s Inve~ery T DATA_PLUS ~!40-!3880 L~iI000~ 12300 /21~0-i3700 ~'~3926-14632 -'~13500-147 O0/~5 L 400-13970 ,~w~'407-!4706 ~/407-12640 ~ 12200-1~300 TV ~/13500-14700 ~2594-i7674 '~/2600-13200 TVD 500-12750 L 13500-14700 ~2260-i3500 ~4286-14550 ~"12491-13680 Date' 10,/13/95 RUN DATE_RECVD 3 O5/lO/9~ 1-4 08/01/94 3 o5/~o/94 4 05/10/94 0~/I0/9~_, o5/~o/94 i o8/!5/s4 1 08/15/~ i 0~/i5/94 1 08/15/94 1-4 05/10/'94 i-4 o$/oi/~4 -i os/i5/94 i o~/i5/9~ i e8/i5/9~ 4 05/10/94 3 05/'10/94 Are dry ditch samples required? o And received?~lv~.~ n kkt_3~ /o Was the well cored? '~:no Analysis~ & description received? ~e~2' no . Are well tests required? ~-~s '~ece~ved? ~_o We!i is in compliance 1~ Initial COMMENT S State of Aiaska Oil Gas Conservation Commission 3001 Porcupine Drive Arl,~hnrn~e Alnskn _¢i.q.~01 ..'~1 .el9 To: Paul Dean Phillips Petroleum Company 6330 W Loop S Beilaire TX 77401 ph: (713) 669-2173 Sunfish #3 Permit #: 93-076 The following data is hereby acknowledged as being received' Quantity Description 1 Tape & LIS verification J~ing Merged LDWG OH Merged Edit, Runs '.,.~, interva~'~~-i4670 "% PERMIT 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS CBT/GR CDR L 11813-13750 L 10100-12600 TVD CET-VD L 52-8844 CET/GR CNL/DLT DDL L 11813-13780 L 2594-17678 L 700-1400 DS L 2600-13200 TVD DSI L 2594-17622 DSI L 2594-17622 FMI L 12135-13702 FMS LDT/CNL LDT/GR ML L 13926-14638 L 2600-13200 TVD L 2594-8884 L 11000- 12300 TVD ML L 12140-13880 MSD DIP L 12140-13700 MSD DIPS L 13926-14632 MUD L 12200-13300 MUD L 13500-14700 MUD L 13500-14700 MUD L 400-13970 MUD L 407-12640 MUD L 407-14706 PDI-SFL PDI/SFL PDL L 2594-17674 L 2600-13200 TVD L 12260-13500 PDL L 13500-14700 PDL L 500-12750 Page- 1 Date' 10/19/94 RUN DATE_RECVD 1 05/10/94 1 08/01/94 1 05/10/94 1 05/10/94 1-4 05/10/94 1 08/15/94 1-4 08/01/94 1-4 05/10/94 1-4 05/10/94 3 05/10/94 4 05/10/94 1-4 08/01/94 1 05/10/94 1-4 08/01/94 3 05/10/94 3 05/10/94 4 05/10/94 1 08/15/94 05/10/94 1 08/15/94 05/10/94 1 08/15/94 1 08/15/94 1-4 05/10/94 1-4 08/01/94 1 08/15/94 1 08/15/94 1 08/15/94 PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS Page: 2 Date: 10/19/94 RUN DATE_RECVD 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 93-076 RFT RFT 407 L 12491-13680 L 14286-14550 CORE ANALYSIS R COMP DATE:04/02/94 R 12285-14365 CORE DESCRIPTION R 12285-12306 CORE DESCRIPTION R 12285-14367 CORE DESCRIPTION R 12405-12465 CORE DESCRIPTION R 13628-13641 CORE DESCRIPTION R 13641-13659 DAILY WELL OP. 93-076 DST 93-076 SURVEY 93-076 R 11/17-04/03/94 R 03/13-03/22/94 R 0.00-14705 ANADRILL WELL REPORT R FINAL BAKER-HUGHES INTEQ 3 05/10/94 4 05/10/94 05/09/94 05/31/94 1 05/09/94 05/31/94 2 05/09/94 3 05/09/94 4 05/09/94 05/09/94 1-2 08/15/94 05/09/94 08/01/94 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required?~ye~Received? yes no Well is in compliance COMMENTS yes no yes no PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Sunfish No. 2; Sunfish No. 3 Phillips Tyonek Platform "A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Larry Grant Re: Sunfish Mud Logs Enclosed are the blue-line copies of the Mud Logs as requested for both wells. If you have any further questions or require more information, please contact Paul R. Dean at (713) 669-3502. Regards, ,,.,~ , ~. D. C. Gill, Manager .p~ Drilling and Production Engineering cc:(wo/enc) V.R. Chamberlain .... %...?/, "~'/6' i ' ~?/¢p~O M. L. Jones (r) P. R. Dean "'/r'~,0,¢ "~' ~0,, J.F. Mitchell ! ,-J,, -r~'~G~/~ '"'~,,Y~;~"~' Central files 4:,_;~~~ - ~",~¥/;.~-.,.t , ,, STATE OF ALASKA Alaska Oil Gas Conservation Commission Anchorage, Alaska 99501-3192 CONFIDENTIAL DATA RELEASE The AOGCC will release confidential well data to authorized DNR/DOG employees, All data is to be inventoried prior to release and a copy of the inventory given to the DNR/DOG employee, 01) Permit to Drill (401): pages 02) Completion Report (407) · .'7_.~ pages 03) Daily Drilling History:. _~pages 0~4)Directional Surveys: ~ 'p. ages 05) Drill Stem Tests: ~pages : 06; Core Analysis Report: //:pages 07) Core Description: ~~"--~'~pages/ 08) Digital Data: __. reels LOG TYPE INTERVAL RUN # SCALE TODAY'S DATE' The under-signed ]~]-R/])o~ employee hereby accepts receipt of the above listed confidential materials. Print and sign your n__~a~elow. - '-) ---- Authorized ~cc personnel, s~n below t~ verify transference of these confidential materials. Signature: Facsimile Cover Sheet To: Com~ny: Phone: Fax: LARRY GRANT Oil & Gas Conservation Comm. 907-279.1'433 907.276-7542 From: Company: Phone: Fax: Timothy J. Ryherd Alaska D,N,R, (907)762-2140 (907)562-3852 Date: 06/16/g4 Pages including this cover page: 1 - Division of Oil & Gas JUN ] 6 1994. 41~ka Oit & Gas Uons. Uommis~ion Lan'y, ~ohorage I ~:lUeSt tl~ following well data be ~ for me to pinup aa ~oon ~ possible. Please call when you I~ave this data i~ut together or If you have any questions. Thanks for your help. ARCO South Cook Inlet ~2 (confidential well stltus)-all well logs, well history, completion rel~rL horizon ai¢~, dlrec~ional surveys, core clesct'~ons & analysaa, & pmcluaion tests. ARCO South Cook Inlet ~ (confidential well stltus)--all well logs, well history, com~etJon rel~rt, horizon picks, clirKtlonal surveys, c~ra clesctii3tiona & analyses, & production tests. Phillips Sunfish ~2 (~nf,:lerdjel well status)-.mud log. 8tewa~t_West McArthur River #2 (¢onlldentlal well status)--all well logs, well history, oompletlon report, horizon plc, l~, dim~ionel surveys, core (lese~ption$ & anatyses, & BP YulJon Gold #1 (genfidentiel well status) all well logs, well history, completion rel~rt, horizon ~¢ks, clire~onal ~rveys, oore de~'lptlons & analyae~, & production tests. ARCO Fiord ~2 (oontldentlal well statua)-all well logs, well history, OOmpletlon report, horizon ~lcks, dimelJonai surveys, corn cl~a=tipJion$ & analyses, & 13'oclucllon tests. Amerade Northstar ~ (mrlfldentlel well altus)--all well logs, well hi~tory, completion report, horizon 131GI~, dlmCti~l ~rveys, core desorlptlons & aruillyses, & production tests. - ARCO 8unflsll la (¢on~entlal welt status)-all well logs, well history, completion report, horizon pietJs, di~l surveys, cote dese, tipiJo~li & anslyMs, & production tests. BP Soun:lough~ (confidential well status) all well logs, well history, completion report, horizon picks, directional surveys, ~on~ deseatptiona & analyses, & ~'odu~lon tests. ARCO 'Betgsctlrund #1 (confidential well status)-all well logs, well'hlstory, completion report, horizon lOlda, directional ~rveya, core clesorlpflons & analyses, & l:)mductlon tactic. UNOCAL Amet~State ffi (oonfklentiat well status)--all well logs, well history, report, horizon picks, cllrecllonal Surveys, corn clescrlptlona & analyses, & production tests. PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 EXPLORATION AND PRODUCTION GROUP COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING May 19, 1994 Sunfish No. 3 North Cook Inlet, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501 Attn: Bob Crandali r) Larry Grant Enclosed for your records are the Core Descriptions and the Core Analysis. Halliburton Services will have the Drill Stem Test reports May 23-24th. Phillips will have Halliburton send you a copy directly as soon as they have it ready in Anchorage. If you have any questions regarding this please contact Paul Dean at (713) 669-3502. M. L. Jones (r) P. R. Dean // Drilling-and Production Engineering Manager RECEIVED MkY 3 1 1994 /Xt~$t(a 0il & Gas Cons. Commission Anchorage CORE #1 PHILLIPS/ARCO #3 SUNFISH CORE DESCRIPTIONS 12,285'-12,306' (driller's depths) Cut 21' recovered 21' Lithology: 12,285'-12,287.3' - Shale, olive gray, silty with laminations of very fine sand and silt. 1 2,287.3'-1 2,294.75' - Sandstone, fine grained, fair porosity, no show. 1 2,294.75'-12,296' - Shale with sandy laminae 12,296'-12,304.8' - Sandstone, fine grained, fair to poor porosity, no show. 12,304.8'-12,306' - Shale, medium gray, silty CORE #2 12,405'-12,465' Cut 60' recovered 56.5' Lithology: 12,405'-12,412.5' - Claystone with interbeds of dirty coal. 12,412.5'-1 2,420.25' - Claystone with laminations of very fine sand at the base. 12,420.25'-12,425' Sandstone- fine grained, poor porosity, no show. 1 2,425'-1 2,465' - Interbedded mudstone, siltstone and very fine to fine sandstone, laminated, sands less than 1 foot thick, poor porosity, no show. CORE #3 13,628'-13,641' Cut 13' recovered 8.5' Assumed missing portion was drilled up at top of core. Lithology: 13,632.5'-13,637.7' - Sandstone, coarse to very coarse grained, fair porosity, even yellow-white fluorescence, oil odor. 13,637.7'-13,641' - Sandstone, fine grained, muddy, laminated with claystone, poor porosity, fluorescence as above, poorest layers are non-fluorescent. E C E IV E P CORE #4 13,641'-13,659' MAY .~ 1 1994 Cut 18' recovered 1 7.5' AIsska Oil & 6as O0ns. Commission Lithology: Anchorage 13,641'-13,649' - Sandstone, medium to coarse grained, pebbly in part, fair porosity, even yellow-white fluorescence, oil odor. 13,649'-13,658.5' - Pebbly sandstone/conglomerate medium sand to 2 cm pebbles, fair porosity, strong oil show as above. .,,,~lps/Arco #3 Sunfish Core Descriptions Page 2 CORE #5 CORE #6 (SIDETRACK #1 ) CORE #7 CORE #8 049294-1. WFK 13,659'-13,680' Cut 21' recovered 19' Lithology: 13,659'-13,664.5' - Pebbly sandstone/conglomerate medium sand to 2 cm pebbles, fair porosity, even yellow-white fluorescence, oil odor. 13,664.5'-13,669' - Silty sandstone/siltstone, no porosity, no show. 13,669'-13,678' - Pebbly sandstone/conglomerate, coarse sand to 2 cm pebbles, porosity fair to poor, even yellow-white fluorescence, oil odor. 13,680'-13,700' Cut 20' recovered 19.5' Lithology: 13,680'-13,684.4' - Sandstone, medium-coarse grained, pebbly in part, even yellow-white fluorescence, oil odor. 13,684.4'-13,699.5' - Silty sandstone- very fine to fine grained, muddy, poor porosity, no show. 13,681'-13,731' Cut 50' recovered 50' Lithology: 13,681'-13,715.3' - Pebbly sandstone/conglomerate, medium- coarse sand up to 2 cm pebbles, even yellow-white fluorescence, oil odor 13,715.3'-13,723.5' - Conglomerate, medium sand up to 15 cm pebbles/cobbles, clast supported, poor porosity, even yellow- white fluorescence, oil odor 13,723.5'-13,724.2' - Sandstone, medium to coarse grained, fair porosity, strong oil show as above 13,724.2'-13,731' - Silty sandstone/siltstone, very fine grained, no porosity, no show 14,324'-14,367' Cut 43' recovered 41.5' Lithology: 14,324'-14,326.2' - Sandstone, fine-medium grained, fair to good porosity, no show 14,326.2'-14,364.8' - Siltstone/mudstone, laminated to massive, no porosity, no show 14,364.8'-14,365.5'-Coal, brittle, rubbled p~ ECEIVED ~,~y ~ ] 1994 Gas Cons. Cornmissi[ Anchorage ORIGINAL ROUTINE CORE ANALYSIS PHILLIPS PETROLEUM COMPANY Sunfish #3 Well Kenai Borough, Alaska Prepared for: PHILLIPS PETROLEUM COMPANY NORTH AMERICA EXPLORATION & PRODUCTION 6330 West Loop South Bellaire, Texas 77401 Prepared by: TerraTek, Inc. University Research Park 360 Wakara Way Salt Lake City, Utah 84108 J IC OFILMED May 1994 TerraTek Project No. 5625 PHILLII~ETROLEUM COMPANY Well: Sunfish//3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03 -May. TerraTek Project Number: 56., Permeability Saturation Sample Sample Depth Plug Plug Porosity Grain Number Type (fee0 @400 psi NES @2300 psi NES Oil Water Density Lithology (md) (md) % % % (gm/cc) C-Sand - Core I 1 P 12285.1 0.036 .':' :. il;: i:.'): i.ii! ....... : 7.0 20.8 77.7 2.71 !Ss,gy,vfgr,slty lam,pof 3 P 12286.5 0.066 0.006 8.1 13.2 84.3 2.68 Ss,gy,vfgr,sl/dol,slty,lam 4 P 12287.4 0.150 0.054 11.8 7.2 87.6 2.67 Ss,gy,vfgr,sl/dol,sl/slty i 1004 V 12287.6 0.250 0.086 12.0 7.7 85.0 2.67 Ss,gy,vfgr,sl/dol 5 P 12288.2 0.112 0.036 11.4 9.0 83.9 2.69 Ss,gy,vfgr,sl/dol 6 A 12288.4 0.105 ' "!!;::: : 11.1 14.5 80.9 2.68 Ss,gy,vfgr,sl/dol 7 A 12288.5 0.041 " . ... 10.3 14.6 83.7 2.70 Ss,gy,vfgr,sl/dol 8 P 12289.1 0.030 0.008 8.6 17.8 79.6 2.70 Ss,gy,vfgr,sl/dol , ,, 9 P 12290.1 0.064 0.019 10.2 14.4 80.8 2.70 Ss,gy,vfgr,sl/dol , 10 P 12291.1 0.091 0.029 11.1 10.2 87.4 2.68 Ss,gy,vfgr,sl/dol 11 V 12291.8 0.075 0.021 10.2 5.3 91.2 2.68 Ss,gy,vfgr,sl/dol 12 P 12292.1 0.058 0.012 10.5 1.9 96.5 2.70 Ss,gy,vfgr,sl/dol,sl/lam 13 P 12293.1 0.085 0.022 11.3 5.0 90.6 2.70 Ss,gy,vfgr,sl/dol,sl/lam 14 P 12294.1 0.089 0.011 9.1 16.0 76.3 2.68 Ss,gy,vfgr,sl/dol,sl/lam : 15 P 12295.1 8.643+ 0.411 + 7.8 20.6 77.2 2.68 Sltst,dkgy,sl/dol,lam,of 16 P 12296.1 0.020 0.006 5.8 20.7 79.3 2.72 Ss,gy,vfgr,sl/dol 17 P 12297.1 0.006 0.002 3.5 43.8 55.0 2.71 Ss,gy,vfgr,sl/dol 18 V 12297.4 0.003 0.002 3.3 40.9 55.4 2.71 Ss,gy,vfgr,sl/dol 19 P 12298.4 0.070 0.020 6.6 2~4_r .t-. _r- ~'.rqr. r_ ~ 2.80 Dol,gy,fxl,intxl,calc,bdd Key to Sample Types: A- Alternate Plug Sample P - Horizontal Plug Sample Notes: + - Fracture affecthtg permeability measurement V - Vertical Plug Sample N1AY 31 1994 Gas Cons. Commission Anchorage PHILLIP~ETROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03 -May-'. TerraTek Project Number: 562, ,,, Permeability Saturation Sample Sample Depth Plug Plug Porosity Grain Number Type (feet) ~400 psi NES {~2300 psi NES Oil Water Density Lithology (md) (md) % % % (gm/cc) ,,, 20 V 12298.7 0.007 0.003 6.0 10.1 87.8 2.85 Dol,gy,fxl,intxl,calc,bdd,styl 21 P 12299.4 0.030 ~. 0.012 ~ 8.1 9.1 82.1 2.69 Ss,gy,vfgr,sl/dol 22 P 12299.6 0.068 :. 9.4 12.9 74.2 2.68 Ss,gy,vfgr,sl/dol · 23 P 12299.8 0.080 ' 10.3 9.8 78.2 2.68 Ss,gy,vfgr,sl/dol 24 P 12300.1 0.041 <0.001 9.9 9.0 85.6 2.69 Ss,gy,vfgr,sl/dol 25 P 12301.0 0.091 0.037 10.5 8.9 79.5 2.67 Ss,gy,vfgr,sl/dol 26 V 12302.0 O. 1 O0 0.042 12.3 1.4 85.4 2.67 Ss,gy,vfgr,sl/dol 27 P 12302.4 O. 142 0.064 12.3 5.4 81.3 2.67 Ss,gy,vfgr,sl/dol 12303.0-04.8 ' ' "' ,:::i:i'l ASR Samples; No analysis 28 P 12305.1 3.944+ 6.8 23.0 71.5 2.68 Sltst,gy,lam,of C-Sand - Core 2 29 P 12405.8 1.324+ ' 6.1 18.9 81.1 2.67 Sltst,dkgy,sl/shy,pof 12405.8-10.7 ~ Shale; No analysis 30 P 12411.1 0.016 4.0 15.7 83.4 2.79 Dol,dkgy,vfxl,intxl,calc,slty,lam,if 31 P 12413.3 0.036 6.1 19.8 79.0 2.71 Sltst,dkgy,sl/dol 32 P 12414.2 0.312+ 6.0 21.3 78.1 2.70 Sltst,dkgy,sl/dol,pof 12415.0-18.0 '" ' '::':~i. i.' Shale; No analysis 33 P 12418.3 0.091 7.4 16.4 79.1 2.66 Ss,gy,vfgr,slty,lam 34 P 12419.4 0.086 9.9 5.5 89.3 2.68 Ss,gy,vfgr,slty,lam . 35 P 12420.4 0.106 .... ~ 10.8 6.3 86.8 2.69 Ss,gy,vfgr,slty,lam Key to Sample Types: A - Alternate Plug Sample P - Horizontal Plug Sample Notes: + - Fracture affecting permeability measurement V - Vertical Plug Sample RECEIVED PItILLIP~[TROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROIJTINE CORE ANALYSIS 03-May-~, TerraTek Project Number: Permeability Saturation ,, Sample Sample Depth Plug Plug Porosity Grain Number Type (feet) (~400 psi NES 1~2300 psi NES Oil Water Density Lithology (md) (md) % % % (gm/cc) 12421.0-22.0 . :. . i .::'.:::. 'i':. ;:~i:.i ::::il.;'!,; Shale; No analysis 36 P 12422.2 0.022 6.2 12.8 75.4 2.72 Ss,gy,vfgr,sl/dol , , 1036 V 12422.2 0.033 0.01.4 6.4 3.3 44.7 2.71 Ss,gy,vfgr,sl/dol 37 P 12423.4 0.059 6.8 9.2 70.3 2.70 Ss,gy,vfgr,sl/dol 38 P 12424.4 0.038 6.0 4.0 73.0 2.71 Ss,gy,vfgr,sl/dol 12425.0-28.0 :' ': ::~:'ii: i:':~::~! ':; :'iI~ i~i .:~ii:;:~?~: Shale; No analysis 39 P 12428.3 0.006 6.7 30.9 61.1 2.71 Sltst,gy,sl/sdy,lam 12429.0-30.0 . Shale; No analysis 40 P 12431.3 0.120 7.4 28.8 66.4 2.70 ISItst,gy,sl/sdy,lam 41 P 12432.4 0.034 5.5 14.5 74.3 2.73 Ss,gy,vfgr,dol , 12433.0-39.0 : "~: :. Shale; No analysis' 42 P 12439.0 0.018 9.7 11.6 82.5 2.70 :Sltst,gy,sl/sdy,lam,if 12440.0-43.0 Shale; No analysis 43 P 12443.0 O. 148 12.0 13.0 83.0 2.69 Ss,gy,vfgr,sl/lam 44 P 12444.4 0.049 6.6 24.7 71.6 2.74 !Ss,gy,vfgr,dol,lam 45 P 12445.1 O. 105 4.0 16.9 76.6 2.73 Ss,gy,vfgr,dol,lam , 46 P 12445.8 0.495 11.2 42.4 57.6 2.68 :Ss,gy,vfgr,v/lam 47 P 12447.9 0.022 9.1 26.5 64.3 2.69 Ss,gy,vfgr,sl/slty 48 P 12449.2 0.469 13.4 11.2 85.5 2.68 Ss,gy,vfgr,sl/slty 49 P 12450.1 0.051 9.4 25.8 65.6 2.71 Sltst,gy,sl/sdy,lam Key to Sample Types: A - Alternate Plug Sample P - Horizontal Plug Sample Notes: + - Fracture affecting permeability measurement V - Vertical Plug Sample PHILLIPS LIM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-May-94 TerraTek Project Number: 5625 Permeability Saturation Sample Sample Depth Plug Plug Porosity Grain Number Type (feet) (~400 psi NES (~2300 psi NES Oil Water Density Lithology (md) (md) % % 95 (gm/cc) 50 P 12451.0 1.31 2 12.8 3.5 85.2 2.69 Ss,gy,vfgr,sl/dol 51 P 12452.1 0.052 9.4 23.6 67.8 2.70 Ss,gy,vfgr,sl/dol,sl/lam · , ' 12453.0-56.5 ' ' ' '' ' ' . .. . :. .. ~ ~ ... :::...~::![:.~.~ ASR Samples; No analysis . . .. 52 P 12456.9 0.028 : .. ' 9.1 34.2 57.4 2.69 Ss,gy,vfgr,sl/dol,sl/lam . 53 P 12458.4 0.023 9.1 29.9 61.9 '2.69 Ss,gy,vfgr,sl/dol,sl/lam 54 P 12459.1 0.020 8.6 24.3 67.6 2.70 Sltst,gy,sl/sdy,lam -- 55 P 12460.1 2.489+ 7.1 1.8 86.0 2.68 Sltst,dkgy,sl/sdy,lam,pof ~._ 56 P 12461.3 0.015 8.4 40.6 52.0 2.69 Sltst,gy,sl/sdy,lam Sunfish - Core 3 57 V 13632.5 1.032 13.0 26.3 62.5 2.63 Ss,gy,f-mgr,sl/calc ., 58 P 13633.0 3.314 14.5 14.9 64.5 2.63 Ss,gy,f-mgr 59 P 13633.5 3.090 1.91 9 14.6 28.8 56.7 2.64 Ss,gy,f-mgr 60 P 13634.0 6.680 14.0 23.0 59.4 2.62 Ss,gy,c-vcgr 61 P 13635.1 2.719 13.2 20.9 67.3 2.63 Ss,gy,c-vcgr 62 P 13636.8 3.593 14.4 17.1 60.8 2.63 ISs,gy,f-mgr,pof 13638.0-38.5 :· ASR Samples; No analysis 63 P 13639.2 26.31 17.3 32.4 43.8 2.66 Ss,gy,f-mgr ' 13639.3-39.9 ' . ~:..: ~ ASR Samples; No analysis 64 P 13640.9 16.15 . 17.2 25.5 50.3 2.66 Ss,gy,f-mgr Key to Sample Types: A - Alternate Plug Sample P - Horizontal Plug Sample Notes: + - Fracture affecth:g permeability measurement V - Vertical Plug Sample RECEIVED !~,,i~\Y 3 ] 1994 Gas Cons. Commission Anchorage PItILLi~ETROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonie ROUTINE CORE ANALYSIS 03 -Iv., TerraTek Project Number: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (fee0 ~400 psi ~2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) Sunfish - Core 4 65 P 13641.1 46.13 39.84 .. 17.3 15.9 66.6 2.65 Ss,gy,f-cgr,grnl clst )_, 66 P 13642.1 28.47 . ' ' ' 17.7 20.3 59.0 2.66 Ss,gy,f-mgr , . , 67 P 13643.2 13.68 .. ':....:. :.. . . . .:. .. 16.5 24.7 54.4 2.66 Ss,gy,f-mgr 68 P 13644.2 26.87 . ' ' ' . . 17.0 19.4 55.8 2.66 Ss,gy,f-mgr . . . . 69 V 13644.3 15.28 15.7 15.9 60.5 2.66 Ss,gy,f-cgr,grnl clst . 70 P 13645.1 14.94 : . 14.8 17.4 55.0 2.66 Ss,gy,f-mgr,pof 71 P 13646.1 310.6 263.9 17.1 31.0 47.2 2.64 Ss,gy,cgr 72 P 13647.1 107.9 92.60 15.2 24.0 58.6 2.65 Ss,gy,cgr,pbl clst 73 P 13648.1 187.5 16.5 26.8 56.9 2.64 Ss,gy,cgr,pbl clst 74 P 13649.2 56.94 39.22 10.9 40.5 52.7 2.64 Cgl,dkgy,pbl,sdy mtx 75 P 13650.1 17.37 : 10.1 28.4 52.0 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 76 P 13651.3 10.62 '· ·· ·· 8.5 36.0 48.9 2.66 Cgl,dkgy,grnl-pbl,sdy mtx · 77 V 13651.9 20.87 12.8 46.0 44.0 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 78 P 13652.4 56.57 10.62 8.0 27.6 53.2 2.65 Cgl,dkgy,grnl-pbl,sdy mtx ., 79 P 13653.3 22.82 10.9 20.1 58.4 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 401 AW 13653.6-54.0 27.67 27.55 27.50 10.7 8.1 35.5 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 402 AW 13654.0-54.4 52.67 36.64 58.25 13.1 9.2 34.5 2.64 Cgl,dkgy,grnl-pbl,sdy mtx , . · . 403 AW 13654.4-54.8 393.4 25.05 27.93 10.8 9.5 46.6 2.64 Cgl,dkgy,grnl-pbl,sdy mtx . . 80 P 13655.7 2.113 0.983 . .... .... '-.:. 9.0 26.5 56.8 2.67 Cgl,dkgy,grnl-pbl,sdy mtx,sl/calc .. 81 P 13656.1 0.932 " :" : 6.9 10.4 62.1 2.68 Cgl,dkgy,grnl-pbl,sdy mtx,sl/calc : · .. . . : .: . :, : .. .' . Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting perme4~bility measurement W - Laboratory Whole Core Sample PHILLII~ETROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-Mi TerraTek Project Number: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (feet) ~400 psi ~2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) Sunfish - Core 5 501 W 13659.0-60.0 37.05 33.98 36.74 10.9 11.9 73.9 2.63 Cgl,dkg¥,grnl-pbl,sdy mtx . 502 W 13660.0-61.0 16.74 14.12 14.18 11.2 2.7 64.0 2.66 Cgl,dkg¥,grnl-pbl,sdy mtx 503 W 13661.0-62.0 34.90 26.48 32.60 14.6 10.1 59.2 2.65 Ss,gy,fgr,pbl clst 504 W 13662.0-63.0 63.47 7.868 6.738 7.7 9.3 155.2 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 505 W 13663.0-64.0 20.78 11.28 2.324 6.9 5.2 73.8 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 506 W 13664.0-65.0 33.91 3.043 7.729 7.0 13.1 71.3 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 82 P 13664.9 0.005 5.4 20.5 67.3 2.71 ISItst,dkgy 83 P 13665.1 <0.001 14.4 5.5 27.4 2.74 :Sltst,dkgy 84 P 13666.2 0.007 5.1 31.0 54.2 2.68 iSItst,dkgy 85 P 13667.6 0.010 4.5 15.1 76.3 2.73 Ls,dkgy,vfxl,intxl,slty,brec 507 W 13669.0-70.0 5.032 3.043 3.083 7.1 14.5 55.0 2.68 iCgl,dkgy,grnl-pbl,sdy mtx,calc 508 W 13671.0-72.0 16.05 10.00 12.84 10.9 9.5 53.4 2.67 ;Cgl,dkgy,grnl-pbl,sdy mtx,calc I 509 W 13672.0-73.0 24.68 16.00 17.12 10.8 13.3 54.9 2.65 ~Cgl,dkgy,grnl-pbl,sdy rntx · 512 AW 13672.3-72.8 27.24 20.27 20.59 11.9 8.5 42.5 2.66 ICgl,dkgy,grnl-pbl,sdy mtx .' 513 AW 13672.8-73.3 30.77 23.85 34.92 14.3 11.4 45.4 2.65 Ss,dkgy,mgr,pbl clst,lig 514 AW 13673.3-73.8 29.02 17.38 27.63 13.8 8.0 46.0 2.65 Ss,dkgy,mgr,pbl clst 510 W 13674.0-75.0 252.2+ 78.51+ 205.8+ 15.7 1.0 55.8 2.63 Ss,gy,mgr,gilsonite frac,of 511 W 13675.0-76.0 21.68 14.29 18.49 12.1 7.1 61.0 2.63 Ss,gy,mgr,pbl clst 86 P 13676.0 10.59 .. . : 9.2 14.6 54.4 2.67 Cgl,dkgy,pbl,sdy mtx . 87 P 13677.8 3.805 : · 9.8 15.9 55.9 2.68 Cgl,dkgy,grnl-pbl,sdy mtx Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement W - Laboratory Whole Core Sample PHILLI~ETROLEUM COMPANY Well: Sunfish//3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03 -Ma TerraTek Project Number: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core] Porosity Grain Numbe[ Type (feet) (~400 psi (~2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) Sunfish - Core 6 88 P 13680.1 4.812 11.8 32.6 54.9 2.67 Ss,gy,fgr,grnl clst 602 AW 13680.3-80.7 . . 4.075 2.555 3.530 11.1 5.9 58.9 2.66 Ss,gy,fgr,grnl clst ~- . 603 AW 13680.7-81.3 ~ 0.798 0.772 0.478 10.8 5.4 66.2 2.67 Ss,gy,fgr,grnl clst . 604 AW 13681.3-81.7 1.310 0.224 0.246 10.4 1.2 '72.5 2.67 Ss,gy,fgr 89 P 13682.0 15.72 14.2 30.6 55.2 2.66 Ss,gy,vfgr,grnl clst 90 P 13683.1 25.85 16.0 25.7 63.6 2.66 Ss,gy,vfgr,grnl clst 91 P 13684.3 0.014 0.002 6.3 20.8 78.8 2.70 Sltst,gy,larn 1091 V 13684.6 0.006 4.7 16.9 68.7 2.72 Sltst,gy,pof 92 P 13685.2 0.003 ~ " .. 2.9 31.1 68.7 2.72 Sltst,gy . 93 P 13686.1 0.007 0.003 4.4 43.6 56.1 2.69 Sltst,gy · 94 P 13687.1 0.007 .: 5.0 44.3 48.1 2.70 Sltst,gy 95 P 13688.1 0.014 0.004 " 5.4 16.2 75.2 2.67 Sltst,gy - 96 P 13689.1 0.008 0.002 4.4 15.7 64.2 2.71 Sltst,gy '1 1096 V 13689.7 0.006 ' 4.2 32.0 51.2 2.74 Sltst,gy,pof .. 97 P 13690.1 0.012 0.003 4.5 14.3 66.7 2.72 Sltst,gy,lam :: 98 P 13691.1 0.004 . 2.3 45.3 54.0 3.07 Dol,gy,vfxl,intxl,slty,sid(?) · .... 99 P 13692.1 0.014 7.1 4.2 85.2 2.69 Sltst,gy,lam 100 P 13693.5 0.026 0.007 7.4 13.3 72.4 2.67 Ss,gy,vfgr,lam I 101 P 13694.1 0.024 .. " 7.3 11.3 80.7 2.68 Ss,gy,vfgr,lam , · 102 P 13695.2 0.049 ~ . ' '"' :" '- ' 5.2 8.0 87.1 2.69 Sltst,gy,lam Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement W - Laboratory Whole Core Sample PHILLIO~I~TROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-M~ TerraTek Project NUmber: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (feet) ~400 psi t~2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) 103 P 13696.4 0.073 9.8 10.3 69.0 2.67 Ss,gy,vfgr,lam · . 1103 V 13696.8 0.055 .. . 10.2 8.2 50.7 2.68 Ss,gy,vfgr,lam 104 P 13697.4 0.043 ' ' ." :' 9.0 8.3 73.3 2.67 Ss,vfgr,lam 105 P 13698.0 0.796 :. 5.1 22.3 73.6 2.67 Sltst,gy,lam 106 P 13699.1 0.035 7.3 11.5 '79.0 2.68 Ss,gy,vfgr,lam Sunfish - Core 7 701 W 13681.0-82.0 5.313 3.590 4.947 10.3 4.4 67.7 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 702 W 13682.0-83.0 5.786 3.908 3.818 11.6 12.8 65.2 2.64 Ss,gy,mgr,pbl ¢lst 703 W 13683.0-84.0 11.44 9.319 10.51 13.4 11.6 58.2 2.65 Ss,gy,mgr,pbl clst 704 W 13684.0-85.0 ... 10.28 9.223 7.131 8.7 6.8 72.3 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 705 W 13685.0-86.0 * * * 10.2 11.9 52.7 2.61 Cgl,dkgy,grnl-pbl,sdy mtx,v/lig 706 W 13686.0-87.0 11.80 9.901 11.22 11.6 9.3 63.4 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 707 W 13687.0-88.0 6.162 5.906 6.981 10.1 10.2 63.2 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 708 W 13688.0-89.0 12.58 11.97 11.67 10.9 11.4 59.6 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 709 W 13689.0-90.0 8.352 6.712 7.130 11.0 10.5 63.4 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 710 W 13690.0-91.0 225.1 67.16 251.1 11.1 7.8 68.4 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 711 W 13691.0-92.0 4.250 3.837 5.378 9.8 8.5 66.9 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 712 W 13692.0-93.0 8.783 7.578 7.895 10.7 10.1 62.2 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 713 W 13693.0-94.0 5.938 5.145 4.896 8.0 11.2 72.5 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 714 W 13694.0-95.0 ' 617.2 24.60 6.318 9.6 6.9 68.4 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 715 W 13695.0-96.0 6.733 4.862 5.492 10.9 9.6 58.4 2.67 Cgl,dkgy,grnl-pbl,sdy mtx,sl/calc Key to Sample Types: AW- ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement W - Laboratory Whole Core Sample PHILLIPi~TROLEUM COMPAHY Well: Sunfish//3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-May TerraTek Project Number: 56 Permeability Saturation Sample Sample l Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (feet) (~400 psi @2300 psi Kb-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) 716 W 13696.0-97.0 6.176 5.956 6.241 10.2 32.4 58.7 2.68 Cgl,dkgy,grnl-pbl,sdy mtx,sl/calc . 717 W 13697.0-98.0 ' 7.129 6.407 7.316 8.8 4.6 64.6 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 718 W 13698.0-99.0 ' ' 12.26 7.942 9.563 8.5 7.9 67.5 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 719 W 13699.0-00.0 . * * * 9.9 13.9 66.1 2.64 Ss,gy,mgr,grnl clst,sl/calc,lig · 720 W 13700.0-01.0 71.92 6.847 6.206 10.8 9.3 6'0.3 2.65 Ss,gy,mgr,grnl clst 721 W 13701.0-02.0 18.20 16.89 22.33 12.1 10.6 58.6 2.64 Ss,gy,mgr 722 W 13702.0-03.0 14.53 10.73 12.48 9.9 10.3 63.8 2.64 Cgl,dkgy,grnl,sdy mtx -- ., 723 W 13703.0-04.0 73.05 16.16 13.81 11.3 11.0 59.5 2.65 Ss,gy,mgr,pbl clst 724 W 13704.0-05.0 14.92 12.16 14.53 12.0 13.4 56.6 2.65 Ss,gy,mgr,pbl clst 725 W 13705.0-06.0 17.05 12.93 7.363 8.5 6.3 69.9 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 726 W 13706.0-07.0 35.03 28.73 7.214 9.2 11.4 63.6 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 727 W 13707.0-08.0 37.99 19.12 6.440 9.8 7.5 62.8 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 728 W 13708.0-09.0 20.29 18.00 6.746 8.3 7.3 70.7 2.63 Cgl,dkgy,grnl-pbl,sdy mtx 729 W 13709.0-10.0 131.3 11.00 7.768 7.9 7.7 67.9 2.65 Cgl,dkgy,grnl-pbl,sdy mtx 730 W 13710.0-11.0 8.825 6.338 3.981 8.1 9.4 69.6 2.65 Cgl,dkgy,grnl-pbl,sdy mtx .... 731 W 13711.0-1 2.0 12.48 7.931 11.47 7.0 7.9 67.0 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 732 W 13712.0-13.0 0.682 0.617 0.623 7.2 13.0 71.1 2.67 Ss,gy,mgr,pbl clst,sl/calc 733 W 13713.0-14.0 96.74 46.98 136.7 10.7 39.0 45.8 2.63 Cgl,dkgy,grnl-pbl,sdy mtx .. · 734 W 13714.0-15.0 45.87 29.97 41.48 11.2 40.1 41.1 2.65 ~Cgl,dkgy,grnl-pbl,sdy mtx 735 W 13715.0-16.0 13.25 11.26 14.08 9.2 6.6 67.6 2.66 Cgl,dkgy,grnl-pbl,sdy mtx 736 W 13716.0-17.0 '~' 8.478 8.226 6.703 6.0 2.5 79.1 2.67 Cgl,dkgy,pbl-cob,sdy mtx,sl/calc Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement W - Laboratory Whole Core Sample PHILLI~ETROLEUM COMPANY Well: Sunfish #3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03 TerraTek Project Number: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Numbe[ Type (feet) (~400 psi @2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) 737 W 13717.0-18.0 16.53 13.77 13.59 7.7 7.3 70.6 2.64 Cgl,dkgy,grnl-pbl,sdy mtx 738 W 13718.0-19.0 .. . .. 37.88 30.40 44.40 11.5 6.5 67.3 2.65 Cgl,dkgy,grnl-pbl,sdy mtx. 739 W 13719.0-20.0 . .':' 95.66 13.60 4.507 9.1 10.5 67.6 2.65 Cgl,dkgy,pbl,sdy mtx 740 W 13720.0-21.0 17.16 15.24 8.619 7.5 25.1 67.8 2.67 Cgl,dkgy,pbl,sdy mtx,sl/calc 741 w 13721.0-22.0 7.307 6.182 4.675 6.7 24.3 ' 70.9 2.66 Cgl,dkgy,grnl-pbl,sdy mtx,sl/calc 742 W 13722.0-23.0 8.196 5.754 8.536 5.8 4.3 79.3 2.64 Cgl,dkg¥,grnl-pbl,sdy mtx 743 AW 13723.0-24.0 12.87 9.626 7.574 8.0 15.2 60.4 2.68 Cgl,dkgy,pbl-cob,sdy mtx,sl/¢alc 107 P 13724.4 0.317 9.0 4.5 76.2 2.66 Ss,gy,fgr,slty,pbl clst 108 P 13725.3 0.003 3.0 7.3 85.2 2.71 Sltst,dkgy,lam 109 P 13726.4 0.010 4.4 15.0 73.9 2.70 Sltst,dkgy,lam 110 P 13727.2 2.696+ 4.0 6.7 77.0 2.69 Sltst,dkgy:lam,pof 13728.0-29.0 . .. ':' . i.~ ~+~ ...... "~.!..:: ~' ~:.i Shale; No analysis 111 P 13729.7 0.016 3.5 21.8 62.0 2.68 Sltst,dkgy,sl/calc North Foreland - Core 8 112 P 14324.3 0.526 12.2 0.0 84.1 2.67 Ss,gy,vf-fgr 113 P 14325.1 0.397 11.2 0.0 91.4 2.68 Ss,gy,vf-fgr 114 P 14326.1 0.031 7.9 0.0 86.4 2.73 Sltst,dkgy,lam . 14327.0-28 . ." . Shale; No analysis · . · ' , ~.. "' . ~.: '- Shale; No analysis 14328.0-29 .~ ,'..... . 115 P 14329.2 0.009 . .. · ~.. 6.1 0.0 86.8 2.70 Sltst,dkgy 14330.0-31.0 ~' .' ..... " ' 'i'::~:'....: :: .... ~.:.' ':i'~: Shale; No analysis Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement W - Laboratory Whole Core Sample PItlLLIP~TROLEUM COMPANY Well: Sunfish//3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-May TerraTek Project Number: 56 Permeabilit3/ Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (feet) ~400 psi ~2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) 116 P 14331.2 0.134 ' 5.8 0.0 92.5 2.68 Sltst,dkgy,lam · 117 P 14332.2 0.013 · ~ . !~. ..~ ~ 5.7 0.0 90.9 2.68 Sltst,dkgy,lam · 14333.0-34.0 ' ' ' : ' :' ' ..:'i.:'.' · ...... "" ": · :::....... Shale; No analysis ' . . 14334.0-35.0 ' ' '. ' ' ' ' ' .'' i:!'?i.:...~.. ' '!;..'...:i.':':: Shale; No analysis · 14335.0-36.0 ' ' ..... : :" .' ' ... ...... .' :: .'.. Shale; No analysis 14336.0-37.0 . '. Shale; No analysis ., 14337.0-38.0 · ". .. ' ' ." :..':. ':''~.' Shale; No analysis 118 P 14338.2 0.172 5.3 0.0 92.7 2.67 Sltst,dkgy,lam,pof 119 P 14339.2 0.263 5.4 0.0 90.8 2.67 Sltst,dkgy,lam,pof . .. 120 P 14340.2 0.138 5.9 0.0 95.9 2.69 Sltst,dkgy,lam,pof 1120 P 14341.2 0.031 6.0 0.0 90.5 2.69 Sltst,dkgy,lam,pof 121 P 14342.1 1.071+ · 6.9 0.0 90.7 2.63 Sltst,dkgy,lam,pof 122 P 14343.3 0.030 5.2 0.0 88.7 2.69 Sltst,dkgy,sl/calc,lam 123 P 14344.2 0.108 5.2 0.0 87.3 2.68 Sltst,dkgy,sl/calc,lam,pof 124 P 14345.2 0.027 4.6 0.0 95.4 2.71 Sltst,dkgy,calc,lam 125 P 14346.2 0.008 2.9 0.0 65.4 2.70 Sltst,dkgy,calc,lam : 126 P 14347.3 0.014 5.1 0.0 78.5 2.69 Sltst,dkgy,calc,lam ._ 127 P 14348.2 0.022 6.8 0.0 81.0 2.68 Sltst,dkgy,lam ... 128 P 14349.2 0.067 6.4 0.0 72.7 2.70 Sltst,dkgy,lam 129 P 14350.2 0.080 . : 6.2 0.0 92.4 2.68 Sltst,dkgy,lam = .. 130 P 14351.2 0.010 ' " . 6.6 0.0 88.4 2.71 Sltst,dkgy,lam Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affectiug permeability meast,remc,~t W - Laboratory Whole Core Sample PHILLIOETROLEHM COMPANY Well- Sunfish//3 Field: Cook Inlet Drilling Fluid: Water Base State: Alaska Borough: Kenai Location: Platform Tyonic ROUTINE CORE ANALYSIS 03-M~ TerraTek Project Number: Permeability Saturation Sample Sample Depth Plug Plug Whole Core Whole Core Whole Core Porosity Grain Number Type (feet) ~400 psi @2300 psi Kh-max Kh-90° Kv Oil Water Density Lithology (md) (md) (md) (md) (md) % % % (gm/cc) 131 P 14352.2 0.271 ~ : : ~ ' i::: :: : ::;:ii : ': ?:.:'.::i);: ' ' 6.9 0.0 91.1 2.69 Sltst,dkgy,lam I ....... 132 P 14353.2 0.622 .. .. 6.6 0.0 92.8 2.76 Sltst,dkgy,lam 14354.0-55.0 . ' ': ' . ' ::.i'(:.;i.:i;:; .::.::.?'. :ii ii!;:.: ::.i: :iII ...! ii;;ii:'!'.~!::. Shale; No analysis ; , , 14355.0-56.0 : ..::~ ....... ~ .... :: . Shale; No analysis 133 P 14356.2 0.625 ':; : ' ' 7.0 0.0 94.3 2.68 Sltst,dkgy 134 P 14357.2 0.324 ' :: 6.0 0.0 92.6 2.77 Sltst,dkgy 135 P 14358.2 0.184 5.8 0.0 80.2 2.66 Sltst,dkgy,lam 136 P 14359.2 20.9+ 6.3 0.0 79.8 2.66 Sltst,dkgy,larn,of 137 P 14360.2 0.016 5.0 0.0 76.5 2.69 Sltst,dkgy,lam,pof 138 P 14361.2 0.281 5.2 0.0 91.2 2.69 Sltst,dkgy,larn 139 P 14362.4 1.032+ . 5.1 0.0 86.1 2.69 Sltst,dkgy,lam,pof 140 P 14363.2 1.662+ " 6.1 0.0 88.5 2.72 Sltst,dkgy,lam,pof · 14364.0-65.0 . ' . ~.~':.... Shale; No analysis 14365.0-66.0 : : '.' . :..i.i Shale; No analysis L" Key to Sample Types: AW - ASR Whole Core Sample P - Horizontal Plug Sample V - Vertical Plug Sample W - Laboratory Whole Core Sample Notes: * - Sample not suitable for permeability measurement + - Fracture affecting permeability measurement RECEIVED Gas Cons. Commission Anchorage DESCRIPTION SCHEME FOR CARBONATE SEDIM~ENTARY ROCKS: ROCK TYPE, COLOR, GRAIN SIZE / CRYSTAL SIZE, POROS1TY TYPE, ACCESSORIES _ - _ . DESCR/FrlON SCHEM~ FOR CLASTIC SEDIMENTARY 'POCKS: ROCK TYPE, COLOR, GRAIN SIZE, CEIVIENT, STRUCTURES AND ACCESSORIES KEY TO ABBREVIATIONS: afl - anhydrite filled fos - fossil(iferous) pel - peloids fracture frae - fracture pff - pyrite filled alt - altered fri - friable fracture anhy - anhydrite(ie) gff - gouge filled pis - pisolific arg - argillaceous fracture pk - pink bald - bedded gla~c - glauconitie pof - partially open bent - bentonite gn - green fracture bf - buff gr - grain(ed) ppvgs - pinpoint vugs biot - bioturbated grnl - granule ptg - parting(s) bit - bitumen gy - gray purp - purple bl - blue(ish) gyp - gypsum(iferous) pyr - pyrite(it) blk - black hem - hematite(ie) qff - quartz filled bnd - banded if - incipient fracture fracture bree - breccia(ted) incl - inclusion qtz - quartz bm - brown intprt - interparticle red - red bur - burrowed intrprt - intraparti¢le sa - salty e - coarse intxl - intererystalline sdy - sandy eale - ealeite(areous) lam - laminated sh - shale earb - carbonaceous lay - lavender shy - shaley eft - calcite filled lig - lignite(ie) sial - siderite fracture ls - limestone sil - silica(eous) egl - conglomerate It - light sl/ - slightly ehlcy - chalky m - medium sltst - siltstone chlor - chlorite mar - maroon slty - silty eht - chert mas - massive ss - sandstone chty - cherty mdy - muddy sm - stain(ed)(ing) elst - elast mic - micro str - streak ely - elay(ey) mica - mieaceous styl - stylolite clyst - claystone mol - moldie sue - suerosie cob - cobble ms - mudstone tan - tan dism - disseminated mtx - matrix v/ - very dk - dark nod - nodule(s) ve - very coarse dff - dolomite filled o - oil vf - very f'me fracture of - open fracture vgy - vuggy dol - dolomite(ie) ool - oolitic wh - white f - time org - organic wthrd - weathered fen - fenestral orng - orange ~de~ - yellow tis - fissile pbl - pebble R ~ C ~! ~) crystalline iX\~sk5 Oil & Gas Cons. Commission Anchorage ********* ********** ********* ANADRILL ********** ********* SCHLUMBERGER ********** SURVEY PROGRAM COMPANY PHILLIPS WELL NAME SUN FISH #3 LOCATION 1 TYONEK PLATFORM LOCATION 2 COOK INLET, ALASKA MAGNETIC DECLINATION 23.19 DATE: 10-MAR-94 WELL NUMBER 0 WELL HEAD LOCATION: LAT (N/-S) 0.00 AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IN POINT(TIP) : MEASURED DEPTH TRUE VERT DEPTH INCLINATION AZIMUTH LATITUDE (N/-S) DEPARTURE (E/-W) 363.00 363.00 1.25 52.00 0.16 2.17 DEP (E/-W) 0.00 5.01 PAGE NO. MEASURED DEPTH ft 363.00 481.23 557.91 589.76 620.69 651.55 682.41 713.23 744.13 775.08 806.02 836.86 867.68 898.64 929.52 960.39 993.77 1024.75 1055.63 1086.51 1117.34 1146.78 1177.37 1208.99 1240.28 INTERVAL VERTICAL DEPTH ft ft 0.0 363.00 118.2 481.21 76.7 557.87 31.9 589.72 30.9 620.64 30.9 651.50 30.9 682.35 30.8 713.17 30.9 744.06 31.0 7?5.00 30.9 805.93 30.8 856.75 30.8 867.56 31.0 898.50 30.9 929.35 30.9 960.18 33.4 993.52 31.0 1024.44 30.9 1055.25 30.9 1086.04 30.8 1116.75 29.4 1146.05 30.6 1176.46 31.6 1207.86 31.3 123S.92 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 0.35 1.25 52.00 0.16 1.46 1.02 82.15 1.10 1.90 1.13 73.07 1.41 2.16 0.99 62.21 1.63 2.48 1.04 57.29 1.91 2.82 0.98 56.30 2.20 3.23 1.09 36.19 2.59 3.78 1.24 29.71 3.11 4.43 1.49 35.75 3.73 5.17 1.47 14.80 4.44 6.03 1.73 4.99 5.28 7.00 1.91 14.52 6.24 7.98 1.82 16.78 7.21 9.07 2.25 8.60 8.28 10.36 2.56 9.76 9.56 11.81 2.85 8.12 11.00 13.57 3.20 2.83 12.75 15.42 3.70 356.46 14.61 17.52 4.16 357.40 16.72 19.87 4.65 356.17 19.09 22.48 5.30 350.12 21.74 25.25 5.95 348.42 24.57 28.44 6.55 347.90 27.83 31.98 6.82 350.35 31.45 35.68 7.29 348.33 35.22 SUN FISH DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W deg/ ft ft deg 100ft 2.17 2.18 85.78 0.00 4.23 4.37 75.45 0.53 5.63 5.81 75.93 0.26 6.18 6.39 75.21 0.76 6.65 6.92 73.99 0.31 7.10 7.44 72.76 0.19 7.49 7.93 70.96 1.22 7.83 8.43 68.33 0.64 8.23 9.04 65.63 0.95 8.57 9.65 62.62 1.74 8.71 10.19 58.75 1.21 8.88 10.85 54.88 1.15 9.15 11.65 51.76 0.38 9.38 12.51 48.57 1.69 9.59 13.54 45.09 1.01 9.81 14.74 41.74 0.96 9.98 16.19 38.04 1.34 9.96 17.68 34.28 2.03 9.85 19.41 30.49 1.49 9.71 21.42 26.96 1.62 9.38 23.68 23.35 2.71 8.84 26.12 19.79 2.28 8.16 29.00 16.34 1.96 7.47 32.32 13.36 1.24 6.75 35.86 10.85 1.69 PAGE NO. MEASURED DEPTH ft 1271.46 1302.76 1333.80 1365.23 1397.36 1428.64 1460.25 1490.77 1522.30 1554.05 1585.68 1616.13 1647.70 1678.30 1708.43 1738.78 1769.93 1801.59 1832.41 1863.38 1895.03 1926.27 1957.79 1989.10 2020.78 INTERVAL VERTICAL DEPTH ft ft 31.2 1269.82 31.3 1300.81 31.0 1331.47 31.4 1362.46 32.1 1394.08 31.3 1424.80 31.6 1455.80 30.5 1485.72 31.5 1516.59 31.8 1547~65 31.6 1578.56 30.4 1608.26 31.6 1639.00 30.6 1668.72 30.1 1697.94 30.3 1727.32 31.2 1757.44 31.7 1788.01 30.8 1817.71 31.0 1847.50 31.7 1877.85 31.2 1907.70 31.5 193'7.70 31.3 1967.40 31.7 1997.37 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 39.63 7.90 349.04 39.26 43.93 8.44 350.94 43.64 48.58 9.32 351.89 48.38 53.71 9.96 351.46 53.59 59.24 10.56 349.35 59.23 SUN FISH #3 DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W deg/ ft ft deg 100ft 5.95 39.71 8.61 1.98 5.18 43.95 6.76 1.93 4.46 48.58 5.27 2.87 3.70 53.71 3.95 2.06 2.74 59.29 2.65 2.18 64.86 11.06 347.21 64.97 1.55 64.99 1.36 2.06 70.68 11.40 345.21 70.95 0.08 70.95 0.06 1.64 76.36 11.52 343.63 76.79 -1.55 76.80 358.84 1.09 82.33 11.89 344.54 82.94 -3.30 83.00 357.72 1.31 88.53 12.09 345.21 89.31 -5.02 89.45 356.78 0.77 94.85 12.42 345.57 95.80 -6.72 96.04 355.99 1.06 101.17 12.98 346.01 102.29 -8.36 102.63 355.33 1.87 107.99 13.48 345.71 109.30 -10.12 109.76 354.71 1.62 114.83 13.92 345.55 116.32 -11.92 116.93 354.15 1.43 121.78 14.37 345.58 123.45 -13.76 124.21 353.64 1.50 128.93 14.61 345.30 130.80 136.42 14.96 345.49 138.49 144.20 15.27 345.46 146.49 151.96 15.65 345.99 154.45 159.99 16.13 346.46 162.68 -15.67 131.73 353.17 -17.67 139.62 352.73 -19.74 147.81 352.32 -21.77 155.98 351.98 -23.79 164.41 351.68 0.81 1.13 0.99 1.30 1.62 168.52 16.83 347.14 171.43 -25.84 173.36 351.43 2.30 177.31 17.50 347.79 180.43 -27.84 182.56 351.23 2.22 186.56 18.23 348.35 189.89 -29.83 192.22 351.07 2.38 196.04 18.63 348.15 199.58 -31.85 202.11 350.93 1.29 205.86 19.15 348.57 209.63 -33.92 212.35 350.81 1.70 PAGE NO. SUN FISH #3 MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 2051.65 30.9 2026.49 2082.28 30.6 2055.28 2112.52 30.2 2083.60 2144.10 31.6 '2113.05 2174.88 30.8 2141.67 2206.50 2238.06 2268.82 2299.03 2330.62 31.6 2171.06 31.6 2200.38 30.8 2228.96 30.2 2256.97 31.6 2286.16 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 215.71 19.64 349.18 219.68 225.77 20.27 349.56 229.96 236.02 20.84 349.96 240.40 247.04 21.52 350.01 251.64 257.97 21.64 349.99 262.79 269.24 21.68 349.79 274.28 280.48 21.68 349.45 285.74 291.44 21.75 349.56 296.93 302.34 22.23 349.37 308.06 313.98 22.72 349.64 319.93 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft deg -35.90 222.60 350.72 -37.82 233.05 350.66 -39.71 243.66 350.62 -41.69 255.07 350.59 -43.66 266.39 350.57 -45.71 278.06 350.54 -47.81 289.72 350.50 -49.88 301.09 350.46 -51.95 312.41 350.43 -54.15 324.48 350.39 DLS deg/ 100ft 1.70 2.10 1.95 2.15 O.4O 0.25 0.40 0.28 1.61 1.59 2361 2393 2423 2456 2487 .95 .02 .58 .72 .76 31.3 23].5.1o 31.1 2343.80 30.6 2371.95 33.1 2402.41 31.0 2430.87 325.55 22.35 349.20 331.74 336.99 22.67 349.04 343.42 348.42 23.14 349.03 355.10 360.99 23.29 349.22 367.93 372.90 23.77 348.79 380.09 -56.35 336.49 350.36 -58.60 348.38 350.32 -60.86 360.27 350.27 -63.32 373.34 350.23 -65.69 385.73 350.19 1.31 1.05 1.54 0.50 1.64 2518.46 2550.08 2651.09 2744.56 2837.56 30.7 2458.89 31.6 2487.65 101.0 2578.93 93.5 2662.95 93.0 2746.37 384.93 24.39 348.84 392.38 -68.12 398.25 350.15 2.01 397.57 24.76 348.88 405.29 -70.66 411.40 350.11 1.18 439.17 25.95 349.35 447.77 -78.83 454.65 350.02 1.19 478.55 26.02 348.80 487.97 -86.59 495.59 349.94 0.27 517.93 26.44 348.05 528.23 -94.83 536.68 349.82 0.57 2930.00 3023.82 3117.21 3210.11 3304.51 92.4 2828.98 93.8 2912.45 93.4 2995.16 92.9 3077.10 94.4 31~9.97 557.56 26.91 347.47 568.79 598.39 27.40 347.44 610.59 639.80 27.95 347.93 652.96 681.60 28.27 347.60 695.74 724.73 28.97 347.47 739.89 -103.63 578.15 349.67 -112.93 620.94 349.52 -122.18 664.30 349.40 -131.46 708.05 349.30 -141.21 753.24 349.19 0.58 0.53 0.63 0.38 0.74 3380.91 3473.78 3565.53 3657.79 3751.21 76.4 3226.71 92.9 3307.83 91.8 3388.23 92.3 3469.12 93.4 3551.10 760.21 29.27 347.84 776.20 803.40 29.01 347.66 820.40 845.65 28.59 348.19 863.62 888.04 28.89 347.47 906.99 930.82 28.42 348.04 950.77 -149.16 790.41 349.12 -158.76 835.62 349.05 -168.01 879.81 348.99 -177.36 924.17 348.94 -186.86 968.96 348.88 0.46 0.30 0.53 0.49 0.58 PAGE NO. 5 SUN FISH #3 MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 3845.06 93.8 3633.69 3939.38 94.3 3716.88 4033.07 93.7 3799.79 4126.76 93.7 3882.83 4220.79 94.0 3966.24 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 973.39 28.27 347.62 994.33 1015.80 27.97 347.41 1037.74 1057.32 27.54 346.78 1080.27 1098.63 27.61 347.83 1122.58 1140.07 27.40 347.40 1164.99 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft deg -196.26 1013.51 348.83 -205.86 1057.96 348.78 -215.61 1101.58 348.71 -225.14 1144.94 348.66 -234.45 1188.35 348.62 DLS deg/ 100ft 0.26 0.33 0.56 0.53 0.31 4314.18 4408.56 4500.62 4593.29 4687.46 93.4 4049.28 94.4 4133.39 9.2.1 4215.55 92.7 4298.36 94.2 4382.68 1180.78 27.05 347.31 1206.68 1221.47 26.91 346.55 1248.38 1260.82 26.73 346.16 1288.74 1300.23 26.62 346.42 1329.16 1339.96 26.25 346.44 1369.91 -243.80 1231.06 348.58 -253.49 1273.85 348.52 -263.29 1315.36 348.45 -273.15 1356.94 348.39 -282.98 1398.83 348.33 0.38 0.39 0.27 0.17 0.40 4779 4871 4963 5054 5148 .30 .74 .52 .52 .79 91.8 4465.19 92.4 4548.31 91.8 4630.88 91.0 4712.98 94.3 4798.18 1378.19 25.86 346.33 1409.11 1416.54 26.05 346.54 1448.44 1454.63 25.73 347.29 1487.48 1492.06 25.35 347.80 1525.79 1530.62 25.33 348.04 1565.24 -292.47 1439.15 348.27 -301.96 1479.58 348.22 -311.04 1519.65 348.19 -319.50 1558.88 348.17 -327.94 1599.23 348.17 0.43 0.23 0.50 0.48 0.11 5242 5336 5430 5523 5617 .13 .93 .64 .84 .35 93.3 4882.54 94.8 4968.18 93.7 5052.75 93.2 5136.76 93.5 5220.83 1568.79 25.35 347.68 1604.30 1607.65 25.44 348.08 1644.04 1646.24 25.59 347.85 1683.52 1684.78 25.72 347.74 1722.96 1723.94 26.22 348.24 1763.01 -336.35 1639.17 348.16 -344.88 1679.83 348.15 -353.30 1720.20 348.15 -361.84 1760.55 348.14 -370.35 1801.49 348.14 0.16 0.21 0.19 0.14 0.58 5708.19 5801o99 5894.98 5989.65 6082.21 90.8 5302.31 93.8 5386.32 93.0 5469.39 94.7 5553.85 92.6 5636.39 1762.35 26.25 347.94 1802.31 1802.22 26.56 347.77 1843.09 1842.17 26.87 348.05 1883.97 1883.09 26.84 348.14 1925.81 1923.16 26.97 347.96 1966.80 -378.64 1841.65 348.14 0.15 -387.42 1883.37 348.13 0.34 -396.18 1925.17 348.12 0.35 -405.00 1967.94 348.12 0.05 -413.68 2009.83 348.12 0.17 6176.92 6271.89 6365.57 6460.14 6554.53 94.7 5720.81 95.0 5805.33 93.7 5888.55 94.6 5972.44 94.4 6956.03 1964.22 26.94 348.13 2008.80 2005.70 27.32 348.53 2051.20 2046.96 27.34 348.69 2093.37 2088.92 27.65 349.19 2136.22 2131.11 27.70 349.30 2179.29 -422.57 2052.76 348.12 -431.33 2096.06 348.12 -439.82 2139.07 348.13 -448.19 2182.73 348.15 -456.37 2226.56 348.17 0.09 0.44 0.09 0.40 0.08 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft SUN FISH #3 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD********TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLACEMENT at AZIMUTH SECTION INCLN. N/-S E/-W ft deg deg ft ft ft deg DLS 100ft 6648.97 6741.72 6837.20 6930.11 7024.74 7118.66 7210.32 7304.46 7398.52 7490.51 94.4 6139.53 92.8 6221.30 95.5 6305.38 92.9 6387.10 94.6 6469.98 93.9 6552.10 91.7 6632.32 94.1 6714.68 94.1 6796.94 92.0 6877.36 2173.57 27.99 349.24 2222.63 -464.59 2270.67 348.19 2215.66 28.33 348.95 2265.61 -472.87 2314.44 348.21 2259.15 28.26 348.93 2310.03 -481.56 2359.69 348.22 2301.62 28.55 348.88 2353.41 -490.06 2403.89 348.24 2345.44 29.16 348.48 2398.19 -499.03 2449.55 348.25 2389.21 28.90 349.18 2442.89 -507.86 2495.13 348.26 2431.89 28.98 349.35 2486.47 -516.12 2539.47 348.27 2475.75 28.97 348.93 2531.25 -524.71 2585.06 348.29 2519.57 29.04 348.90 2576.00 -533.48 2630.67 348.30 2562.50 29.06 348.98 2619.85 -542.05 2675.34 348.31 0.31 0.40 0.08 0.31 0.68 0.46 0.12 0.22 0.08 0.04 7585.59 7679.74 7774.30 7870.21 7966.75 95.1 6960.52 94.1 7042.84 94.6 7125.34 95.9 7208.76 96.5 7292.48 2606.72 28.92 348.31 2665.03 -551.13 2721.42 348.32 2650.51 29.15 348.58 2709.80 -560.28 2767.11 348.32 2694.86 29.37 348.69 2755.11 -569.39 2813.33 348.32 2740.24 29.76 348.38 2801.49 -578.80 2860.65 348.33 2786.27 29.96 348.19 2848.56 -588.56 2908.72 348.33 0.37 0.28 0.23 0.44 0.23 8062.89 8159.71 8254.42 8317.35 8413.49 96.1 7375.80 96.8 7459.95 94.7 7542.66 62.9 7597.80 96.1 7682.28 2832.23 29.89 348.56 2895.53 -598.22 2956.68 348.33 2878.16 29.40 348.57 2942.47 -607.72 3004.57 348.33 2922.37 28.89 348.33 2987.67 -616.96 3050.70 348.33 2951.41 28.74 348.02 3017.36 -623.17 3081.04 348.33 2995.21 28.29 347.26 3062.19 -632.99 3126.93 348.32 0.21 0.50 0.55 0.34 0.60 8509.06 8603.20 8699.57 8795.93 8848.07 95.6 7766.64 94.1 7849.93 96.4 7935.48 96.4 8021.54 52.1 8068.29 3037.99 27.77 347.34 3106.00 -642.87 3171.83 348.31 3079.93 27.79 348.49 3148.90 -652.05 3215.71 348.30 3122.45 27.03 348.46 3192.37 -660.92 3260.07 348.30 3163.95 26.45 347.93 3234.80 -669.79 3303.42 348.30 3186.02 26.12 347.83 3257.38 -674.63 3326.50 348.30 0.54 0.57 0.79 0.65 0.64 8973.00 9029.00 9128.00 9221.00 9318.00 124.9 8180.33 56.0 8230.62 99.0 8319.97 93.0 8404.20 97.0 8491.83 3239.08 26.40 349.70 3311.58 -685.40 3381.77 348.31 3262.78 25.80 348.70 3335.78 -690.01 3406.40 348.31 3303.89 25.20 350.80 3377.72 -697.60 3449.00 348.33 3342.40 25.00 354.40 3416.82 -702.68 3488.33 348.38 3383.56 25.80 359.30 3458.33 -704.94 3529.45 348.48 0.70 1.33 1.10 1.66 2.32 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 9414.00 96.0 8578.13 9510.00 96.0 8664.24 9605.00 95.0 8749.12 9702.00 97.0 8835.59 9798.00 96.0 8921.05 9900.00 9995.00 10085.00 10179.00 10273.00 102.0 9011.69 95.0 9096.14 90.0 9176.08 94.0 9259.46 94.0 9342.88 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 3425.54 26.20 6.30 3500.30 3467.88 26.30 11.20 3542.23 3510.17 27.10 14.00 3583.87 3553.40 26.80 16.90 3626.23 3596.09 27.40 18.10 3667.94 3641.64 27.20 18.30 3712.38 3683.91 27.30 19. O0 3753.59 3724.03 27.40 19. oo 3792.69 3766.08 27.60 19.70 3833.64 3808. O0 27.30 19.70 3874.43 SUN FISH #3 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft deg -702.87 3570.17 348.65 -696.42 3610.04 348.88 -687.09 3649.14 349.15 -675.39 3688.59 349.45 -662.24 3727.24 349.77 -647.62 3768.44 350.10 -633.71 3806.71 350.42 -620.25 3843.07 350.71 -605.87 3881.22 351.02 -591.26 3919.29 351.32 DLS deg/ 100ft 3.22 2.26 1.57 1.39 0.85 0.22 0.35 0.11 0.40 0.32 10370 10468 10561 10657 10756 .00 .00 .00 .00 .00 97.0 9428.92 98.0 9515.65 93.0 9597.76 96.0 9682.21 99.0 9769.21 3851.30 27.70 19.90 3916.58 3895.41 27.80 19.80 3959.50 3937.57 28.20 20.40 4000.50 3981.52 28.60 21.00 4043.21 4027.00 28.40 20.40 4087.40 -576.09 3958.72 351.63 -560.60 3998.98 351.94 -545.59 4037.53 352.23 -529.45 4077.72 352.54 -512.75 4119.43 352.85 0.42 0.11 0.53 0.51 0.35 10852.00 10948.00 11043.00 11133.00 11232.00 96.0 9853.66 96.0 9937.94 95.0 10021.23 90.0 10100.33 99.0 10187.58 4071.02 28.40 20.40 4130.19 4115.33 28.80 20.40 4173.26 4159.34 28.70 20.80 4216.04 4200.64 28.30 21.10 4256.14 4245.54 28.10 21.50 4299.73 -496.84 4159.97 353.14 -480.82 4200.87 353.43 -464.74 4241.57 353.71 -449.39 4279.80 353.97 -432.39 4321.42 354.26 0.02 0.42 0.23 0.47 0.28 11328 11424 11522 11616 11712 .00 .00 .00 .00 .00 96.0 10272.69 96.0 10358.64 98.0 10447.17 94.0 10532.63 96.0 10620.54 4288.00 27.00 22.50 4340.90 4328.79 25.90 22.50 4380.40 4368.80 24.90 23.20 4419.14 4405.90 24.30 23.90 4455.01 4442.17 23.10 26.00 4490.00 -415.77 4360.76 354.53 1.24 -399.40 4398.57 354.79 1.15 -383.09 4435.71 355.05 1.07 -367.45 4470.14 355.28 0.71 -351.19 4503.71 355.53 1.53 11904.86 12001.56 12096.47 12195.62 12288.07 192.9 10798.53 96.7 10887.83 94.9 10975.03 99.1 11065.79 92.5 11150.34 4511.11 22.19 27.66 4556.26 4545.14 22.93 29.23 4588.87 4579.18 23.59 30.28 4621.41 4614.92 23.88 32.54 4655.46 4647.94 23.85 33.45 4686.83 -317.70 4567.32 356.01 -300.03 4598.67 356.26 -281.42 4629.97 356.52 -260.62 4662.75 356.80 -240.25 4692.98 357.07 0.58 0.99 0.82 0.96 0.40 PAGE NO. 8 MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 12385.27 97.2 11239.56 12479.95 94.7 11327.04 12576.98 97.0 11416.82 12672.98 96.0 11505.28 12772.59 99.6 11596.25 12864.90 92.3 11679.58 12962.43 97.5 11766.57 13058.53 96.1 11851.13 13155.37 96.8 11935.20 13250.37 95.0 12016.56 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 4681.78 22.92 33.96 4718.92 4713.29 22.03 34.99 4748.76 4745.09 22.54 35.48 4778.81 4777.14 23.20 36.06 4809.08 4811.83 24.87 36.41 4841.80 4845.63 26.09 36.89 4873.65 4883.24 27.68 36.13 4909.10 4922.34 29.05 36.06 4946.00 4963.58 30.45 35.73 4984.92 5005.69 31.71 35.92 5024.68 SUN FISH #3 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft -218.85 4723.99 -198.37 4752.90 -177.14 4782.10 -155.33 4811.59 -131.35 4843.58 DLS deg/ deg 100ft 357.34 0.98 357.61 1.02 357.88 0.55 358.15 0.73 358.45 1.68 -107.64 4874.84 358.73 1.34 -81.41 4909.78 359.05 1.67 -54.51 4946.30 359.37 1.42 -26.34 4984.99 359.70 1.45 2.36 5024.68 0.03 1.33 13347.87 97.5 12098.77 13441.76 93.9 12].76.60 13475.00 33.2 12204.03 13489.00 14.0 12215.64 13524.00 35.0 12244.83 5050.68 33.34 35.86 5067.15 33.09 5067.26 5095.76 34.69 35.90 5109.70 63.87 5110.10 5111.83 34.10 36.40 5124.86 74.94 5125.41 5118.39 33.80 39.40 5131.03 79.75 5131.65 5134.33 33.20 39.40 5145.96 92.01 5146.78 0.37 1.67 0.72 1.44 0.84 1.96 0.89 12.16 1.02 1.71 13563.00 39.0 12277.50 13986.00 423.0 12639.34 14082.00 96.0 12722.97 14177.00 95.0 12&06.42 14272.00 95.0 12891.14 5151.83 33.00 40.10 5162.33 105.62 5163.41 5336.56 29.40 34.50 5336.10 238.70 5341.44 5377.78 29.40 33.50 5375.17 265.05 5381.70 5417.59 27.70 34.00 5412.93 290.27 5420.70 5455.06 26.10 34.70 5448.41 314.52 5457.48 1.17 1.11 2.56 1.09 2.82 0.51 3.07 1.81 3.30 1.72 14368.00 96.0 12977.60 14464.00 96.0 13064.50 14623.00 159.0 13209.53 14678.00 55.0 13260.23 5491.50 25.40 33.50 5482.94 337.90 5493.35 5527.50 24.90 32.70 5517.12 360.19 5528.86 5584.62 23.50 34.90 5571.29 396.41 5585.38 5603.02 22.10 35.80 5588.68 408.74 5603.60 3.53 0.91 3.74 0.63 4.07 1.05 4.18 2.62 PROJECTED SURVEY AT 14705' 14705.00 27.0 13285.26 5611.71 21.90 35.80 5596.88 414.65 5612.22 4.24 0.74 PERMIT DATA 93-076 CBT/GR 93-076 CET-VD 93-076 CET/GR 93-076 CNL/DLT 93-076 DSI 93-076 DSI 93-076 FMI 93-076 FMS 93-076 LDT/GR 93-076 ML 93-076 MSD DIP 93-076 MSD DIPS 93-076 MUD AOGCC Individual Well Geological Materials Inventory T DATA_PLUS -- L 11813-13750 L 52-8844 L 11813-13780 L 2594-17678 .'L 25942176:22 . L 2594-17622 L 12135-13702 L 13926-14638 L 2594-8884 L 12140-13880 L 12140-13700 L 13926-14632 L 13500-14700 93-076 MUD L 400-13970 93-076 PDI-SFL 93 - 076 RFT '~-'-~ · 93-076 RFT L 2594-17674 L 12491-13680 L 14286-14550 Page' 1 Date' 05/11/94 RUN DATE_RECVD 1 05/10/94 I 05/10/94 1 05/'10/94 1-4 05/10/94 1-4 05/10/94 1-4 05/10/94 3 05/10/94 4 05/10/94 1 05/10/94 o 05/10/94 3 05/10/94 4 05/10/94 05/10/94 05/10/94 1-4 05/10/94 3 05/10/94 4 05/10/94 Are dry ditch samples required? ~~ And received? yes no Was the well cored? /~-~~no Analysis & description received? Are well tests required?/~-~ no Received? yes no Well is in compliance Initial COMMENTS~ ~ . ~_ ~ 0~-~. yes no Oil Gas Conservation Commission JUUl ~'orcupin¢ Drive 907-279-1 ~33 The foiiowing data is hereby acknowledged as being received: Descdptior., Received by: Dated: PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 May 3, 1994 EXPLORATION AND PRODUCTION GROUP COMPA~ BELLAIRE. TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Alaska Oil and Gas Conservation Commi~ion 3001 Porcupine Drive Anchorage Alaska 99501 Attn: Bob Crandall Attached are 2 copies of the well completion report for the Sunfish No. 3 well drilled from the Phillips Platform A (Tyonek) in the North Cook Inlet Unit. The well was drilled to 14,705' MD and drill stem tests were conducted on two intervals. After completing these two tests, the well was plugged back and temporarily abandoned as per verbal correspondence between D.R. Morgan and Bob Crandall. Included with the completion report are the logs, directional survey, Daily Drilling Report Summary, and Core Description. Drill stem test reports have not been received from Halliburton yet, but will be submitted immediately upon receipt of same. Samples and core chips were submitted to AOGCC as obtained. If you have any questions regarding this please contact Paul Dean at (713) 669-3502. CC: / Drillin Drilling and Production Engineering Manager A. R. Lyons (r) W. L. Carric M. L. Jones (r) P. R. Dean J. F. Mitchell M. A. Blasdel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI~'ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1, Stetus of Well Claulficetion of Serv<e Well OIL C~ GAS [~ SUSPENDED (~ ABANDONED 2. Name of Ooerator Phillips Petroleum CoMpany, 3. Ac~clr.s 6330 W. Loop South, Bellaire, Texas 77401 , , ?latform "A" Leg 1, Slot 6 1249' FNL;980'~ ~,~L~IN-R9W 5. El~ation in f~t {ind~atl KB. O~, e~.J 6. L~e O~a,on and Serial No. .~o- 883-20090 . - ~or%V ~o~ Inlet 10. Well NumOe~ Sunfish No. 3 Exploration 132 ft RKB . ADL 17589-. 12. Oate SI3udd~d 13. Date T.D. Re~h~l [ 14. Olt, COral3.. Sum. ~ Al;end. / 15. WI,er De;th. if ofhho~, 15 No. of Corn 11-19-93 3-4-94 ! 4-2-94 I 100 ' f,,, MSL None . 1 7. TOtal OeOth (MD+TVD) 18.Plug Back DeOth (MO+T~OlI 1¢J. Oir~tionll Surly 20. O~th wmere $SSV sit 21. Thlckn~ of Permafrost !4,705' (13,281) 300' ] YES~ NO~ NA f~tMO NA 22. Type El~tr~ ~ Oth~ L~S Run 23. CASING. LINER AN[ SETTING DEPTH MO I BOTTOM 55' 40; 59 ' ! 2 ~ 60~ 59'! 8,90c~ 57'I 12.~.138 11 ~837' .13~94! CASING SIZE WT. PER FT. 30" 457, 20" 169 I3-3/8" 72 7" 32 GRAOEX_56B tT°P CEMENTING RECORO -IDLE SIZE CEMENTING RECORD 24': I AMOUNT PULLED Driveh ,, ] 'Non~ Attached I None Ngn¢ None None 25. TUBING RECORO SIZE DEPTH SET (MOl PACKER SET (MOl NA 26. AC~O. FRACTURE. CEMENT SaUEEZE. ETC. DEPTH INTERVAL {MOl J'AM ,O.U, NT & KIND O~ MA~'ERIAL USED 13916-14214 [6.0sx"C" below retainer 13594-13644;136~-13706 50sxC below re 12478-] 2502~ 12Si N80:pi~0 N8D.-. ~125 L-80 24. Perforation= Boon to Production (MO+TVO of To; and Bottom and interval, size end n~bte'l PROOUCTION TEST None - Well temporarily abandoned iMetho4 of OPeration (Flowing, 9a$ lift, etc.) TEST PERIOD ~ CiLCU~TEO . /OIL-eeL GAS.MCF 24-HOUR RATE ~ I WATER-88L JCHOKESIZE GAS-OIL RATIO WATER-eeLIOILGRAVITY'API(c°'I 27. Dire First Production Date of Test Houri TettKI Flow TuBing Ca~ng Pr.s~rl Press. 28. CORE DATA 8ne! cltmriptmn of lithology, p~'O~ty, fr~etu~,. ~ent Chl)l lnd J~rllfrlct of 0il, g415 (34' water. Submfl core chil31. See accompanying Core Description. RECEIVED MAY -9 1994 Gas Cons. Commission Anchorage Form 10407 Rev. 7.1-80 CONTINUED ON REVERSE SIDE ~. 30. GEOLOGIC MAh,..~R$ ~MATION TESTS , ,, ,= ~ ,, . ~ppe~ Cook Sands 3,750' 3,550' ~eluga Fo~ation 4,774' 4,460' %yonek Fo~ation 8,687' 7,924' MGS Member 10,950 ' 9,940 ' ~GS "C" Sand 12,400' 11,253' DST No. 2 (12,478'-12,502'; 12526'- 12,538') See DST Report Sunfish Sand 13,594' 12,303' DST No. 1 (13,594-13,644'; 13656'- 13706') See DST Report q. Forelands Sand 14,096' 12,735' ~irectional ~yvey, Da~ly operat~,o~.s s~.~ar?, Core Per~: T.~g~; n~ P~p~= . .. -- ,, 32. ~ hereby clrti~ cnl~ ~1 tor~Jng il ~rue and corr~t to t~e ~t of my knowl~gl Drilling ~ Production Ti~.gn~ineerin~ M~r ~ O~t. M~ ..... t , , .... . · .. INSTRUCTIONS General: This form is designed for submitting a compiete and correg, t 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 iniection, 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 in[erval 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 core, taken, indicate "none". R E C E tV ~ D - 50 - MAY -9 ]994 Oil & Gas Cons. Commission Anchorage PHILLIPS PETROLEUM Sunfish #3 DHil Stem Test March 13 - March 22, 1994 ORI®IRIAL HALLI B U RTON HALLIBURTON ENERGY SERVICES Anchorage, Alaska CUSTOMER: WELL NAME: FIELD: AREA: TEST DATE: TEST: Phillips Petroleum Sunfish #3 North Cook Inlet Kenai, Alaska March 13 - March 29, 1994 DST #1 - DST #2 HALLIBURTON report copies have been sent to the following companies and/or individuals: #COPIES RECIPIENT 11 Phillips Petroleum Company Attn: Paul Dean 6330 West Loop South Bellaire, TX 77401 (713) 669-7465 T#.462909 - 462911 PHILLIPS PETROLEUM Sunfish #3 Drill Stem Test March 13 - March 29, 1994 HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: DRILLING CONTRACTOR: LEGAL LOCATION: OPERATOR: WELL NAME: TEST NO: TESTED INTERVAL: 462909 462909 13-Mar-94 Kenai R.A. Richey S. M. Hurst Pool Arctic Alaska 1250' FNL & 980' FWL S6-T11 N-R9W Phillips Petroleum Sunfish #3 One 13594.00 - 13706.00 ft FIELD AREA: North Cook Inlet COUNTY/LSD: Kenai STATE/PROVINCE: Alaska COUNTRY: USA NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR IMPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS OR OPINIONS. TABLE OF CONTENTS SECTION 1: TEST SUMMARY & INFORMATION Test and Formation Data 1.1 Sequence of Events 1.2 Tool String Configuration 1.3 Pressure Temperature History Plot 1.4 Test Period Summary 1.5 Tank Readings 1.6 Well Test Summary 1.7 Production Data 1.8 SECTION 2: ANALYSIS RezScan Semi-Log Analysis Results 2.1 RezScan Semi-Log Analysis Plots 2.2 SECTION 3: MEMORY GAUGE DATA Gauge No. 10781 History Plot 3.1 Gauge No. 10781 Reduced Listing 3.1.1 Gauge No. 10780 History Plot 3.2 Gauge No. HSRO4 History Plot 3.3 Gauge No. HSRO5 History Plot 3.4 Gauge No. HSRO7 (Annulus) History Plot 3.5 Date: 13-Mar-94 Ticket No: 462909 Page No: 1,1 TEST AND FORMATION DATA Formation Tested: All Depths Measured From: Elevation: Total Depth: Thickness: Hole or Casing Size: Tester Valve Depth: Packer Set Depth: Gross Tested Interval: Perforated Interval (fl): "Sunfish" KB 132 ff MLLW 13866 fi 28 ff 7.00in 13426 fi 13482 fi 13594-13706 ff 13594-13644 fi 13656-13706 fl HOLE FLUID Type: 2% KCL Brine Weight: 8.45 lb/gal HOLE TEMPERATURE Depth: 13457 Temp: 198 fi degf HYDROCARBON PROPERTIES CUSHION DATA Oil Gravity (APl): 42.2 @ 60 degf Gas/Oil ratio (ScF/STB): 890 Gas Gravity (SG): 0.81 Type Amount Weight 2% KCL Brine 44.4 bbl 8.45 ppg Nitrogen 14.4 mcf 2270 psi CALCULATED PARAMETERS FOR LIQUID WELL USING SEMI-LOG ANALYSIS: Gauge No: 10781 Gauge Depth: 13457.00 ft Period No.: 5 Period Type: BU X-axis Function Y-axis Function Production Rate (bbl/D) Pressure Intercept (psi) Flow Capacity (md-fi) Permeability (md) Skin Factor DeltaP due to Skin (psi) Damage Ratio Flow Efficiency Theoretical Rate (bbl/D) Radius of Investigation (ft) at Transient Time (hr) Pressure 549.3 6275.71 400.57 14.31 11.828 1536.371 2.544 0.393 1397.3 457.31 10.31 Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.1 Time l Remarks Bhp ! Bht ; Whp Wht i Casing Choke · ] ~ ! ~ (psia) i (degf) i (psig) ~ (degf) I (p~i~) (64th~) 13-Mar-94 i ! , ! -- 13:00:00 J Pickup Gun~ ~ ; r 14:45:001R IH w/Tubing i i i : 14-Mar-94 i i ~ ; ; ' 01:00:00 i Set Guns on Hanger Assembly i I 17:00:0Oi Set 'BWD' Packer & Seal Assembly on Wireline ~ ~ ~ 19:30:00! Pickup Test Tool String ~ , , 20:00:00iS tart HMR Gauges ~ 21 I 70i 115i 501 _ 23:15:001Toois in hole, RIH w/Tubing i 23:30:00 j Test Sluing to 5000 psi 50301 60 i ' 15-Mar-94 i '~ 03:00:00 i Test Tubing String ~ 78541 126! ' i 10343) 188l 06:07:001~ Test Tubing String i , I 06:45:00!Space Out String ; 53991 188) 07:30:OOJRig up Test Tree i 53941 188 09:08:00 i Test Annulus 2000 psi, Shear TST, Unlock LPR-N j 5392J 188[ ] ; 5397 189J 09:18:00t Bleed off Annulus. LPR-N closed r 09:30:001 Rig up SWS ~ I · 13:05:00j Pressure Teet Suface Equipment I 5391! 188 60! 351 1 ' i 5396 188 4023i 371 1 15:30:00J Teat, Completed, Cool Down N2 Unit i , ~ 16:00:00 i Cycle OMNI il 53971 188! 0i 35 1 16:33'00 J Finish CycJing OMNI, Une up to displace w/N2 I 5388 188i 01 341 1 _ · i i 88 16:40:00i Displace downhole w/N2 i 5388! I 91 32] 1 17:20:00i Close BOP Rems I 5390i 1881 24291 32i 3 17:30:00 ! OMNI to Blenk Position, Shut down N2 I i 5393i , 189! 3020! 31~ 570' 17:35:00 Bleed off Anr~_.~_m_ i 53911 189! 3090j 31i 1089 17:45:00tShoot Fluid Level. 7552 ft I 18:00:00 ! Sefaty Meeting i 53901 1881 30801 29 9 18:36:00 Cycle OMNI to Well Test Position ! 53951 188 3071 ! 30[ 16 , 18:49:001 Open LPR-N i 53961 188 30681 606 i ! 6068' 189 3067 1962 19:00:00 Pump downhole w/N2 i 19:19:301Reach Minimum I~wing Pressure 7995 189 46421 32 1990 ' 19:23:00; ch Nom Fi, ng Pr.--. i 8475 189 5096!_ 321 2OOO 19:27:00! Reach Maximum Firing Pressure~i 9047 189 5591 i 32 2010 19:28:00 i Bleed Off N2 to desired 1000 psi underbelance i 8676 189 5536 32l 2010 9=,:oois i. c,oko. S ndby on,..Ii 5151t 89t Z303 541 925 19:42:58i .-. Fired 53971 189 ZZT01 51i 1927 ' ; ' 189 19:47:30 i Open well to 12/64 aclj choke i 5081! 22841 50 1921 12 20:59:001 Shut in at choke ; 3889 196 288 i ~57 1986 0 21:00:001 Shoot Ruid Level i 3907 196 2781 56 1988 0 21:27:00! Fiuid Level 2866 ft i 45791 195 507 51 2024 ~ i 46571 195 540/ 50 2027 12 21:30:00 i, Open well to 12/64 adj choke I ', , r 21:34:00 i Change to 14/64 I 45131 1951 3741 521 2026~ 14 '~ '~ r I ; ----t 2031' 21:45:00iseparetor on bypass to Surge Tank , 43681 1951 581 541 14 22:10:001 Fluid to Surface i 4681! 195i, 0t, 49J, 20451, 14 Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.2 Time i Remarks Bhp Bht ~ Whp I Wht J Casing Choke , ~ ; (psis) i (degf) i (psig) i (degf) (p~l) (64tha) , 15-Mar-94 i 22:15:001Ruid to Separator (Bypassed To Surge Tank),i 4930l, 1951, 2561.__ 561 2060 14 22:25:00 ! Rock Choke ~ 48691 195 i 2641 59 2048 14 i 22:26:00i Open to 20/64 choke :~ 4869l 195J 241i 59i 2047 20 22:45:00 t Rock Choke i 51751 194i 6051 58 1917 20 22:54:001 Open to 24/64 Choke 51471 194l 614i 571 1915 24 23:03:001 Trace Oil to Surface = 44571 194i 2701 621 1909 24 16-Mar-94 i : ' i ' 00:00:00i Continue to flow well. ! 4268 ! 1951 4371 59i 1793 24 01:06:00!Rock Choke. Change to 26/64 , 4623J 195l 6131 591 1809 26 01:31:00 i Change choke to 18/64, Flow to Separator i 4083i 1951 380i 601 1809 18 01:45:00iOump Surge Tank To Tank #1 ; 4292! 195i 4721 59i 1817 18 01:51:00t Change choke to 22/64 i 44141 1951 5361 591 1820 22 02:45:001 Gas Gravity = 0.856 ! 4243 i 195 02:50:O01BS&W 40% Mud 1.5% water i 4265 195i 483 591 1832 22 : ~ , 03:00:00 BS&W i , 1951 504i 1834 22 40% Mud 2% H20 4313i 59 03:15:00 BS&W 36% Mud 5% H20 .I 4344i, 195 514J 58. 1836 22 03:30:00188&W 36% Mud 5% H20 i 43611 195! 5161 581 1837 22 ~ 58 03:45:00 Dump Surge Tank BS&W 32% Mud 5% H20 i 4370,i 195 5141 1838 22 i . I ~ , ' 04:IS:001BS&W 35% Emulsion ; 4385i 1951 5151 581 1840 22 04:30:00 BS&W 35% H20 Gas Gravity = 0.861 4387i 195t 522t 58 1841 22 05:00:O0!BS&W 35% H20 i 42301 195 4571 1841~ 24 05:15:00iBS&W 35% H20 ~ 41071 1951 4101 58i 1643 24 O5:30:O0!BS&W 35% H20 ! 40321 195i 374t 58i. 1848 24 05:38:00i Change Choke 26/64tha i 40o71 195 3661 591 1850 26 i i 3923' i , 05:45:001BS&W 35% H20 i 196 326; 59 1862 26 06:00:OOiBS&W 35% H20 i 3825i 196! 290i, 58 1868 26 06:15:00 , BS&W 35% H20 ~i 3791 196i 2751 59 1867 26 06:30:00 { BS&W{ 35% H20 {i 37841l 196[ 2621,r 59 1877 26 06=45:00, &w 22%,20 20 Emu,Mon 3780, 196 277, 1686 26 06:50:001Oil Gravity = 36.3 APl (b 60 F. 37911 1961 273{ 60 1889 26 07:00:00, Dump Surge Tank BS&W 35% H20 i 3809! 1961~ 273 1896 26; 07:15:001BS&W 35% H20 i 3828i 196i 285i 57 1903 26 OT:3O:OOl S&w 35%.2o 38481 196i o8i 56 191o 26 07:45:001BS&W 35% H20 t 38631 1971 322 55 1917 26 08:00:00 Dump I Surge Tank BS&W 35% H20 i 3874! 1971 324! 551 1924 26 i 08:30:O0tBS&W 35% H20 ; 3876 197 344j 58t 1782 26 08:45:00t BS&W 35% H20 I 3877i 1971 338j 581 1756 26 ' 60 i 3864 197 3441 59 1726 26 09:00:00i Dump Surge Tank BS&W 35% H20 09:30:00i BS&W 30% H20 5% Emulsion i 3803i 197! 328i , 1720 26 lO:O0:OOiDump Surge Tank BS&W 28% HZ0 5% Emulsion i 3806i 197i 331i 60i 1656 26 lO:30:O0!Surge Tank Level 49 bbl BS&W 60% H20 0.2% Sand '= 38591 197i 351i 61i 1662 241 11:00:O01Dump Surge Tank Chng c~ifice plate (1.125") i 36911 197! 287! 611 1666 24 Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.3 · Timel Remarks Shp ; Sbt ' Whp ; Wht i C acing Choke ,. ~, ' (psia) ] (degf)i (psi9) (degf) (p~l) (64the) 16-Mar-94 ~ : : i 277 11:15:00 0 11:00 BS&W 35% H20 0.2% Sand 3646! 197t . 62! 1670 24 13:00=00! Chlorides 7,000 PH 7.5 ; 3588! 198 271i, 64I, 1690 24 i ; 3618} 198l 287i 64i 16~9 24 14:00:001Dump Surge Tank ! i I .... , 15:00:OOiCh~oHdes 7,000 PH 7.5 ~ 36341 1981 3001 63t 1684 24 16:00:O01Dump Surge Tank 3643i 1981 304J 63 1677 24 17:30:OOiCh~orides 7,000 PH 7.5 : 37101 1981 3161 62i 1671 24 i ' ; 355 18:30:OOIRock Choke, Set to 24/64 Gas Gravity = 0.772 ~ 3804! 198 61J 1666 24 ,. 20:O0:O01BS&W 30% H20 Chlorides 9,500 PH 7.0 ~ 3704i 198! 318! 58i 1649 24 21:00:O01BS&W 30% H20 ~ 38141 198i 354 59 1635 24 ~ ; · 21:12:00i Change to 24 positive ~ 3786i 198i 342i 601 1631 24 22:00:OOiBS&W 30% H20 ~, 3812! 198 347i 56! 1619 24 ~ , 22:30:00]Gas Gravity = 0.792 i 3821! 198i 345! 55; 1613 24 . 23:00:O01BS&W 35% H20 ~ 38031 198i 3361 53, 1610 24 23:30:00i Gas Gravity 0.792 i 3786i 198j 332! 52 1610 24, 17-Mar-94 iil ,, ,, ! , ' ~ ' 326 ~ 3780 198i 50 1611 24, 00:00:00i Dump Surge Tank i ' 00:15:00 BS&W 30% H20 Oil Gravity 42.2 APl ~) 60 F. i 3774 198! 329, 50 1611 24 ' 198 00:30:00i Start Pumping Emulsifier (i~ Data Headers i 3775i 325 50 1612 24 01:00:00' BS&W 30% H20!; 3799t! 198!, 336 55 , 1615 24 01:30:O0!BS&W 20% H20 ; 3795! 198 3311 57 1616 24 o2:oo:ooJD.., S=,e i 02:30:O0!BS&W 30% H20 i 3813 198 333 56 1621 24 , ' 56 03:00:ooi.s&w 30% H20 i 3818! 1981 3411, 1623 24 03:30:OOiBS&W 40%, H20 Chlorides 14.000 PH 7.0 i 3820i. 198 346)~ 51 1626 24 04:00:OOiDump Surge Tank BS&W 40% H20 i 38071~ 198 343, _ 52 1626 24 04:15:00i RIH SWS (bO4:00 w/production logging tool i 3804 198 3271 51 1627 24 1 98 332 04:30-.oo!es&w 26% H20 Chloe,es 14,000 7.0 i 3810! 50 1627 24 ' ' 198 05:00:O01BS&W 24% H20 Chlorides 14.000 PH 7.0 I 38211 334 51 1630 24 i,s&w 23% H20 i 3 24' 198 341j 501 1631 24 05:30:001 ! . , . , 3816 198 345 50 1631 24 06:00:OOiDump Surge Tank BS&W 14% H20 i 38051 198 3381 52 1632 24 06:30:O0!BS&W 15% H20 Chlorides 14,000 PH 7.0 i ' I 07:00:OOiBS&W, 12% H20 Chlorides 14,000 PH 7.0 i 3793i~ 1981 339 52 1633 24 ; 3797 198 3341 52 1636 24 07:30:OOiBS&W 27% H20 Chlorides 14,000 PH 7.0 i , 08:00:OOiDump ST BS&W 33% H20 Chlorides 14,000 PH 7,0 i 38131 198 340 51 1640 24 08:30:O01BS&W 27% H20 Chlorides 14,000 PH 7.0 3818i 198 337 52 1643 24 08:45:00iSWS Finish Logging POOH i 3814i 198 341 52 1646 24 09:00:O01BS&W 15% H20 Chlorides 10,000 PH 7.5 , 381 198 341 53 1648 24 09:30:O01BS&W 25% H20 Chlorides 10,000 PH 7.5 i 3798! 198 344 53 1649 24 , 10:00:00 Dump ST BS&W 28% H20 Chlorides 10,500 PH 7.0 i . 10:15:00i Closed Swab SWS Tools in Lubricator i 3776i 199~ 335 56i 1661 24 ' i 3776! 1991 332J 571 1651 24 IO:30:O0!BS&W 30% H20 Cidorides 10.000 PH 7.0 ; , 343 - 11:00:OOiBS&W 17% H20 Chlorides 10.000 PH 7.0 i 3782! 199 57i 1662 24 11:30:00 ! BS&W 20% H20 Chlorides 10.000 PH 7.0 i 3784i 199t 3461 59i 1653 24 ~ i 37791 199! 3431 581 1663 24 12:00:OOiDump ST 8S&W 25% H20 Chlorides 10.000 PH 7.0 ~ . . Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.4 Timei Remarks i Bhp ; Bht i Whp i Wht i Caeing Choke 17-Mar-94 i i i ! ~ ---- f , 12:30:OOjBS&W 26% "20 Chlorides 10,000 P. 7.0 , 3783i 1991 3511 61L_ 164.3) 24 ~ I 633 13:O0:OOiBS&W20% H20 Chlorides 10.000 PH 7.0 i 3780l 199i 3471 601 I 24 13:20:00iStoP Pumping Emulsion Bresker BS&W 10% j 3778! 189i 350i 58 1627 24 13:30:00!BS&W 10% H20 Chlc~ides 10,000 PH 7.0 i 3786l 199~ 3471 57 15241 24 14:00:OOiDump ST BS&W 17% H20 Chlorides 10,000 PH 7.0 ~ 3793! 1991 357i 56B 1613 24 15:00:00!BS&W 16% H20 Chlorides 11,000 PH 7.5 ! 3779) 199i 366F 15901 24 15:30:00iBS&W 27% H20 Chlorides 11,000 PH 7.5 i 3761i 199i 364f 58~ 15781 24 16:00:OOiBS&W 30% H20 Ch~oride~ 11,000 PH 7.5 ~ 3759 199j 364i 58! 15671 24 16:30:OOiBS&W 33% H20 Chlorides 11,000 PH 7.5 i 3759 199 366l 57 1668il 24 17:00:00! BS&W 31% H20 Chlorides 11,000 PH 7.5 i 7:30:00~ i 3776 199 356j 56 24 1 , Bs&w 15% H20 Chlorides 11,000 PH 7.5 ~ r 18:00:O0!Dump, ST BS&W 20% H20 Chlorides 11,000 PH 7.5 ~I 3778 1991 362j 55 1667 24 ' i 54 · ~ 37651 199 371 54 1644 24 HmO .ooo ! . 19:00:O01BS&W 15% H20 Chlorides 11,000 PH 7.5 19:30:O0!BS&W 15% H20 Chl(xides 14,000 PH 7.5 i 3703 199 351 53 1713i 24 20:O0:OOiBS&W 20% H20 Chlorides 14,000 PH 7.5 i 3701 199 349 52 1712 24 20:30:O0!BS&W 20% H20 Chlorides 10,000 PH 7.5 ! 3702 199 342 51 1713 24 20:45:00 RIH SWS w/TDT-P logging tool I 199 21:00:OOiDump Surge Tank BS&W 22% H20 Chlorides 10,000 PH 7.5! 3704, 199 345 50 1712 24 21:30:O01BS&W 21% H20 Chlorides 10,000 PH 7.5 ; 3715i 199 34~ 50 1713 24 22:00:O0!BS&W 26% H20 Chlorides 10,000 PH 7.5 ! 37331 199 345/ 50 1713 24 22:30:OOiBS&W24% H20 Chlorides 10,000 PH 7.5 i 3730i 1991 354 50 17141 24 I ' 1715 23200=OOiBS&W. 25% .20 Chlo, des 10,000 P. 7.5 i 37281~ 1981, 351 491_~_ ~ 24 23:30:OOiBS&W 30% H20 Chlorides 10,000 PH 7.0 ! 3722! 1991, 354 501 1716 24 ' I 37321 199 355j 50_~ 17181 24 23:45:00i SW$ POOH w/TDT , , O0:O0:OOjBS&W 30% H20 Chlorides 11,000 PH 7.0 O0:30:OOiBS&Wi 26% H20 Chlorides 11,000 PH 7.0 I' 3728 199! 36011 -- 49! 1720 24! 01:00:00 BS&W 30% H20 Chlorides 11,000 PH 7.0 I 3721 199i 365 491 1722 24 01:30:O01BS&W 30% H20 Chlorides 11,000 PH 7.0 I 3715 199 364 50 1723 24 02:00:OOiBS&W 30% H20 Chlorides 10,500 PH 7.0 ! 37341 199 356, 49 1726 24 o=:~o:ooi,s~w,%,=o c~o~,. ~o.,oo ,, ;.o I =;"~r 03:00:OOiBS&W 30% H20 Chlo~de~ 10,500 PH 7.0 j 37361 199 368 48 1728 Z4 03:16:00 Dump Surge Tank to Frae Tank #1 e 03:00 hrs. I 3739) 189 368 50 1728 24 199 371 491 1730 24 03:30:00!BS&W 3O% H20 Chlorides 10,500 PH 7.O 3742 , 04:00:00!BS&W 3O% H20 CUo~des lO,SO0 PH 7.O 3742 199 37O 50t 1732 24 04:30:00tBS&W 30% H20 Chlorides 10,500 PH 7.0 i 3742 199) 3741 511 1733 24 ~ 199 373t 5O 1735 24 05:00:O0!Shut Welt in Q LPR-N. 3740i ' i 3740 1991 ' -I ' 0 05:00:451 Monitor, Surface Transducers during buildup I , , 49r 05:05:25 J Monitor S~rface Transducers during buildup i 5808 1991 379! 33 0 05:30:00 I Rig: up to run RT-91 Probe i! 5970I. 198 3931 321, 34 0 o5:55:ooiMo~ ~ T.an.duc.. duri.g ~,dup ! 6Olll 197j ~4! 26! o Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.5 Time i' Remarks ' Bhp =i Bht i Whp ,: Wht i Casing; Choke , ~ (psia) i (degf) I (psig) I (degf)i (pei~l) i (64tbs) 1S-Mar-94 i ~ i , ~ 06:55:00 Monitor Surface Transducers during b~ildup ! 60591 1961 379i 23i 2 0 i 60671 196i- 3811 23! 2] 0 07:11:00 ! Latch in w/RT-91 Probe ~ ~ ~ , o?:30=ooi^.o=pt~g to [ink../RT-Sl i 6076! 1661 3821 241 2i 0 t 6087 ' 06:00:00 u..u.,o ,.k w/.T-91. POOH i 196i 389i 24! 2 0 os:oo:oot o~ of H~e w~robe ~ 6105! 195i 4~3i 25i 21 0 09:lS:00iRebu,., Probe w/.o...~.., c...doe, i 61091~ ~95i 420i 251 ~ 0 09:30:00i Monitor Surface Transducers during buildup .. 61121 1951 4261 25i Oi i ~= ~ r ~0=00:00 Ri= up Probe i. ~u..=or. ~ 61181 ~95i 435i 26i 21 0 " 6121 ~65t 662i 26i 21 0 1 O: 15:00i Pressure test lubricator. : , 11:45:00!Att°m~t to Rill w/Probe. Huna up i, ~ubH¢,tor. ; 6136i ~941 6~6i 34i 2i O: 15:00:00i Rig up Probe in Lubricator. ; 6157i 1941 696! 40 15:16:00 eaedofftu~ngp~es,u,°, i 6158i ~94! 5351 ;! 0 15:30:00i0p~ Sw,b. Ri, w/Probe. = 61591 ~94i 205 491 11 0 16:30:00i Moftitor Surface Transducers during buildup i 6164 193t 313i 421 1} 0 16:45:00 Latch in with Probe - no link I 6165 193 346! 11 0 17:00:00 Relatch and attempt to link. 6166i 193i 3801i I 0 4-1 Xt- o! o 23:30:00 i Monitor Surface Transducers during buildup 6188 193~ --T464i, 26 2II 0 00:00:00 Monitor Surface Transducers during buildup j 6189 193t 461t 24. 2, 0 06:15:00t Mor~tor Surface Transducers during buildup i 6201! 192 440, 21i 2i 0 08:00:00 Rig testing pumps exc. Casing xducer isolated II 6204i, 192 4331 19i 0 0 08:15:00 during this time. i 6204 192 4311 18i OJ 0 , 6209 192t 431i 261 o! 0 12:00:O01RU SWS bottom hole samplers I . ,~:~=oot~..~=w;~-o-.~......- ! ~2o~i ,~1, ~"! =~l oi o , , 12:30:00 End pump test. Annulus Xducer o~ line.ii 6209 192! 4931 29! 0 0 13:15:001 Monitor 14:15:00i OOH w/SWS bottornhole samplers I 6210 1921 462i 2~1 Ot 0 14:45:00 I RIH w/SWS bottomhole samplers I 6211 192 4611 31 O i 0 20:15:001 Monitor ' iJ' ', ! 20-Mar-94 i I ( 921 428 19 43 0 6219 I , 00:00:00 Monitor Surface Transducers during buildup I 6220 1921 427 15 27 0 03:00:00 Mordtor Surface Transducers during buildup ! 05:00:OOIRig powe~ want down. Shut down DAS and wait I 62211 192! 426 14 0 0 05=55:00,s~.- ~o.~ Choko ~ 10/64 ! 4060 ~92! 6~1t ~51 171~! 0 ,i"" ,--., .o' :; ,o 06:02:00i.u~,o..rface i 3952! 193! 4e~_~ 1712i 24 06:07:00iLow~, 1.375' o.,=. plato I 38~i ~941, Z05 =11 17111 24 06:30:00i Bypass Surge Tank Flow To Tank #1 i 41221 1951 281! . ~ 36 i ! 4125, 196i 287! 1723 24 06:31:00!Gas Gravity = 0.818 i . Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.6 Time i Remarks ! Bhp i Bht Whp , Wht Casing Choke ~: :~ (peia) I (degf)I (psig) i (degf)I (p~i9) (64the) . i '~i 96 38~ 07:00:001Flow To Surge Tank BS&W 0.0% All Oil ~ 4123~ I 378 1719 24 07:30:00 i Bypass S4Jrge Tank to Tank #1 BS&W = 0.25% H20 '; 40581 197 3091 401 1711 24. 07:34:001 Rock Choke ! 40581 197t 290t 401 1711 24 08:00:O0!Switch Reck to 8urge Tank~ 88&W = 80% H20 39671 197ii :~141 45_ 1722 24 o : o:oo! s&w o :oo:oo! s&w .20 09:30:OOiBS&W 16% H20 i 3914 198, 428i 41l 1735 24 09:45:00 Gas = .828 = 39171 1981 4111 42i 1735 24 Gravity , 10:00:00IDump 8urge Tank to #2 80&W 38% H20 I 40131 198i 4481 46i 1737 24 IO:30:O0!BS&W 30% H20 ; 4023i 1981 4611 48J 1735 24 ; 11:00:OOJBS&W 30% H20 i 4083i 198i 493i 49i 1724 24 11:30:OOIBS&W 27% H20 SWS RIH w/Sampling Tool i 41221 198i 511j 48 1717 24 ' I 50 · , 12:30:00lBS&W, 25% H20Ii 4172j 198i 5341 49 1701 24 13:00:OOiBS&W 25% H20 Dump Surge Tank to #2 ~ 41851 198 5421 51 1691 24 13:30:00188&w 25% H20 41681 198 5351 5OI 1682 2.~ 14:00:00 ! 88&W 23% 1-120 I 4168 198 5301 50 1674 24 14:30:O0!BS&W 25% H20 Chlorides 11,000 PH 7.0 4173 198 5331 521 1666 24 , 14-.45:00100, w/sws Sam .. ! 4180 198 531i 54 1,60 24 15:00:O0,BS&W 22% H20 ! 4183 198~ 524! 52J 1666 24 4198!1 198 529l, 53 1645 24 15:30:00i BS&W 20% H20 16:00:00 i I~&W~' 20% H20 Chloridee 11,000 PH 7.0 .i~ 41991, 198 5271 53 1743 24 16:21:00 i $w$ m. w/Sampler #2 ! 4208i 198t 24 16:30:00!88&W 20% 1-120 i 4210 1981 5331 50 1730 24 16:45:00 Updated Program to 1.00" Orifice Size ! 4230t 1981' 5441 51 1723 24 17:00:OOiDump Surge Tank BS&W 24% Cl 11,000 Ph 7.0 ' 42381 198 550t 50 1716 24 17:30:O01BS&W 28% H20 Chlorides 7,000 PH 7.0 4235 1981~ 557 491 1701 24 17:45:00! Gaa~ Meter Run Sensor Unee Freezing off. ! 4229t 1981, 558- 48 1693 24 18:30:O01BS&W 25% "20 ChloHdee 7.000 "H 7.0 4181! 1981 5371 1672 24 BS&W 19:00:00 25% H20 Chlorides 6.000 PH 7.0 j 41631 198 5301 49t 1668 24 19:30:00 i 88&W ~ 22% H20 i! 4182i 1199i 5221 -~-- 47 48! 11044632 24 24 20:00:00IBS&W 23% H20 Chlorides 6,000 PH 7.0 42081 991 5321 20:30:00t BS&W,i 24% Chlorides 8,000 PH 7.0II 4216 199! 532i 481 1618 24 20:45:00, Remove orifice plate. Gas meter out of service , 4ZOSl 199 525 47 1610 Z4 20:55:00i Uquid Turbines out of service 4204i 199 527 47 1606 24 21:00:00 ! Shut in ~i~ Choke Manif(fld i 4206 1991 526 471603 24 21:15:ooj=o Do . . etor I 4679 199 768! 39r 1601 0 21:30:00i Rig Down SVV$ and Rig up Wir{fline ! 5187 1991 1122 35 15~. 0 21 -Mar-94 ! J J oo:oo:ooi Continue to rig up wir~line ! 61141 196 1996i 18 1646 0 02:15:00i00., w~ ~r~ine ~!1 61141 195i~ 2003i lS, 1737 0 03:46:00i G~. ~XN ~,k & PXX ~.~ to iso~et~ ~o~ p~ ! *,O66 1941 1986, 23i 1769! 0 Phillips Petroulem Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Sequence Of Events Page No. 1.2.7 ~ ! Bhp i Bht ; Whp ; Wht i Casing Choke Time l Remarks i __ ; ;i (p$ia) ; (degf) i, [ (psig) ; : (de,If) ;~ (psi~l) |64the) 21 -Mar-94 i i I i , 04:15:00~ Corrtinue wiretine operations i 6165i 1941 1988; 22: 1744 07:15:00 i POOH w/Setting tool ~ 61591 194! 2044i 24! 1696 07:45:00} OOH w/Setting tool ,, 6163; 1941 2027; 22i 1766 ; 193i 1443} 37i 1741 11:15:00! Continue wi~eline operations i 6176i . 12:30:00i Wiretine OOH Close Swab : 6033i 193i 19201__43! 1670 13=00=00!0p~ Choko on 10/64 To test downh~. ~-g i 59821 1512; 193l 42! 1646 ' ~ 1508; 14:46:00 i Close Ma~ter Bleed Off to Rig Down Lubricato~ : 2460i 193i 421 14:48:00 i Switch to Tank #1 i 2467i 193i 9i 50i 1506 ~ 25201 193i Oi 47i 1498 15:00:001 Open Master i ~ ~ " 2468i 193! 57i 49i 1486 _ 15:15:00 i Close Master ~, ; 15:30:00 ! Open Master : 2520i 193J oi 481 1474 15:45:00 ! Shut in choke and cycle the OMNI ',i 2404i, 193ii 32i7__ 53i, 1460 __ 16:15:00j Open on a 24/64ths choke and start reverse out ~ 2424i 1931 146i 52J 0 ; ' 153j 317i 531 16:30:00! Begining S~rge Tank 34 bid Tank #1 = 8"(13.33 bid) i 24371 __ ,, ! 16:48:00i Bypaes Surge Tank Row to #1 ; 24381 193i 23i 57i 201 18:00:001 Continue reverse out operations I 24501 1931 417i 50i 412 18:30:O0!Complete reverse out Rig Down Tree End of Test I 5383i 1931 ~ , , Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Toolstring Configuration Page No. 1.3.1 Depth Tubulars Length i OD ID (Tops) 3 1/2 PHo6 Tubing XO 3 1/2 PH-6 Box X 3 7/8 CAS Pin RD Safety Circulating Valve XO 3 7/8 CAS Box X 3 1/2 PH-6 Pin 2 Jts 3 1/2 PH-6 Tubing XO 3 1/2 PH-6 Box X 3 7/8 CAS Pin Drain Valve APR OMNI Valve XO 3 7/8 CAS Box X 3 1/2 PH-6 Pin 2 Jts 3 1/2 PH-6 Tubing XO 3 1/2 PH-6 Box X 3 7/8 CAS Pin i (MDft) i (in) (ft) 13210.78i 0.00j 4.310l 2.750~ 1.50i 5.67i 1.48i 60.161 1.48i 3.42i 1.48 65.00 1.49 3.441 13210.78! 5.030 2.250 13212.28! 5.030 2.250i 13217.95i 5.050 2.250 13219.43i 4.310, 2.750 13279.59J 5.030j 2.250 13281.07 5.030t 2.250l 13284.49i 5.030i 2.250 ! , 13305.65i 5.04Oi 2.2501 13307.131 4.3101 2.750 13372.13i 5.0501 13373.62 5.030 2.250 Drain Valve Two RT-91 Flow Extensions ~ 25.82 RT-91Surface Readout Valve : 22.87 LPR-N Tester Valve ' 16.86 Drain Valve i 3.44 SG- 15 Bundle Carrier RD Safety Circulating Valve TST Valve Big John Jars Safety Joint XO 3 7/8 CAS Box X 3 1/2 PH-6 Pin XO 3 1/2 PH-6 Box X 2 7/8 8rd Pin Seal Assembly (Top of Packer) 16.84 3.59; 4.60 5.22 3.41 1.48 0.81 9.85 13377 13402.88i 13425 13442.61 13446.05 13462.89 13466.48 13471.08 13476.30 13479.71 13481.19 13482.00 13491.85 5.030 5.030 2.250 5.030 2.250! 5.030 2.250 5.030 2.250 5.030 5.030! 2.250 5.000j 2.250 5.030j 2.250i 5.050i 2.250= 4.375 ~ 2.3701 End of Seal Assembly Halliburton 'BWD' Packer 3.94 13482.00 5.678i 3.250 Seal Bore Extension 7.40 13485,94 4.243! 3.250 Tubing Adapter 0.80 13493.34 2 7/8 EUE 8rd Pup Jt 3.67 13494.14 0.44 3.61 0.44 2 7/8 EUE 8rd Coupling 13497.81 13498.25 13501.86 2 7/8 EUE 8rd Pup Jt 4.988i 2.467 3.110 3.682 3.109 2.441 2 7/8 EUE 8rd Coupling 3.687 3.4551 2.188 Halliburton 'R' Nipple 0.85 13502.30 27/8 EUESrdCoupling 0.44 13503.15 3.710J 27/8 EUESrdPupJt 9.71 13503.59 3.108 Combination Coupling 0.54 13513.30 23/8 EUESrd PupJt 3.86 13513.84 23/8 EUESrdCoupling 0.41 13517,70 Halliburton 'XN' Nipple 0.95 13518.11 X023/8 EU BoxX27/8 EU Pin 0.79 13519.06 2 7/8 EUE 8rd Coupling 0,44 13519.85 27/8 EUESrdPupJt 3.73 13520.291 3.111 !Re Entry Guide 0.68 13524.021 3.983! 2.485 End of Tail Pipe 13524.70i Comments RD Circ Valve: 13212' MD (11989' 'I-VD) OMNI 13284' MD (12060' TVD) RT-91 Gauge Depth 13403' MD (12150' TVD) LPR-N 13426' MD (12170' TVD) HMR Gauges: 13457' MD (12195' TVD) RD Circ Valve: 13462' MD (12200' 'I'VD) BWD Packer: 13482' MD (12216' TVD) Tubing Tail: 13525' MD (12252' TVD) Perforations: Top Shot 13594'MD (12309' 'I-VD) Mid Perfs 13650'MD (12357' TVD) Perforated Interval 13594-13644' MD 13656-13706' MD Gun Hanger 13713' MD PBTD 13866'MD Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Tooistring Configuration Page No. 1.3.2 Tubulars ' Length ,i Depth OD ' ID . i · ; i ,~ i ! !i~ I I ' ! J ' Comments ) (Tops)~ : ~ i ,i ~ ~ , i ' ! !:. , : (ft) i (MDft)i (in) (in) · 27/STubingSeal Divider 1.15. 13584.84i 3.625i 2.250i 2 7/8 8rd Coupling ! ~ ; 0.431 13585.99i 3.630i 2.44Oi ) ! ~ 27/SPortedSub : 1.30i 13586.42J 3.750i 2.2501 ~ ! , 3 3/8 Time Delay Firing Head 1.831 13587.72J 3.375i ' i I , i ' 3 3/8 Delay Fuse 1.10[ 13589.55! 3.375) 33/8 DelayFuse : 1.10J 13590.65! 3.375i 3 3/8 Initiator Sub : 0.701 13591.75i 3.375i 45/8 Blank Gun : 1.55i 13592.45J 4.625! i i i J Top Shot i 13594.001 45/SVannGuns6spf 112.00l 13594.00l 4.625iI~ ,1 ~' ' !' ,~ i' 45/8 BlankGun ! 6.70i 13706.001 4.625! Bottom Shot i 13706.00l . 3 3/8 Emergency Release O.48i 13712.70! 3.3751 7" Gun Hanger ! 6.04i 13713.18i~ 5.500i ,Bottom of BHA i 13719.22; 'PBTD "13866.00i : ,, i Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 1.4 Gauge No. 10781 Gauge Depth 13457' MD 12000 10000 8OOO 6OO0 4000 2OOO Test Tubing ~ ........... ,. Fin Guns / / Shear RD Flow 1 Exten Buildup W/L 240 200 160 120 .~ 8O 4O 0 3/13 0:00 3/15 0:00 3/17 0:00 3/19 0:00 3/21 0:00 0 3/23 0:00 Plot Start Time: 13-Mar-94 00:00:00 Plot End Time: 23-M,,r-94 00:00:00 Date: 13-Mar-94 Gauge No: 10781 Gauge Depth: 13457 ft MD Hallibuton Energy Services Test Period Summary Page No. 1.5.1 Period No Start Time End Time Duration Cum Time Start Press End Press Volume Avg Rate Cum Vol _ This Period This Period {hours) {hoursl (ps/al {ps/a} {bbl} {bpd) {bb-I) 0 Start of Test {Pick Up Guns} .... 3/13 13:00:001 3/15 19:43:15 __ 54.72 54.72 __ 0.00 0.00 _ 0.00 _ I ,_ I Gun Firing, Initial Flow 3/15 19:43:151 3/15 23:32:05 3.81 58.53 ___5129.05 4215.45 32.03 ____ 201.57 32.03 2 Continued Flow, Well Cleanup _ __ 3/15 23:32:051 3116 04:48:55 5.28 63.82 4215.45 4375.97 _ 65.51 297.72 97.54 I 3 'Continued Flow, Well Cleanup 3/16 04:48:55 3/16 10:30:00 5.68 69.50 4375.97 3855.09 116.56 492.11 214.10 -- 4 I Stabilized Flow - 3/16 10:30:00 3/18 05:00:45 42.51 112.01 3855.09 3740.08 972.97 549.28 1187.07 -- __ -- 5 Buildup, Shut in at LPR-N _ __ 3/18 05:00:45[ 3/20 05:36:55 48.60 160.62 ~740.08 6221.29 0.00 0.00 1187.07 6 Secondary Flow, BH Samples 3/20 05:36:551 3~20 21:00:00 15.38 176.00 6221.29 4238.75' 268.84 419.38 1455.90 7 W/reline Operations, Shut in at Choke __ 3/20 21:00:001 3/21 12:30:00 15.50 191.50 4238.75 6033.9~ 0.00 0.00 1455.90 I -- 8 End of Test (Corn )lete Reverse Out/POOH} 3/21 18:30:00 6.00 197.50 0.00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.1 Time Surge Tank #1 Strap Tank #2 Strap ___ Tank #3 Strap Tank Total Inc. Total Inc. Total Inc. Readin~ ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 15-Mar-94 ...... 19:43:15 0.00 Surge Tank Increments Start At 23:08:00 21.00 '21 bbl.. 23:11:00 23.00 ..... 23:18:00 27.00 23:30:00 32.00 ____ 23:45:00 36.00 ..__ 16-Mar-94 ___ 00:00:00 39.00 - 00:15:00 42.00 ._ 00:30:00 45.00 .... 00:45:00 47.00 01:00:00 50.50 01:15:00 57.001 01:30:00 63.00 01:45:00 30.00 -- -- 02:01:00 30.50 -- 02:17:00 35.00 -- __ 02:30:00 40.00 02:45:00 44.00 03:00:00 45.50 03:15:00 46.50 __ -- 03:30:00 51.50 03:45:00 30.50 1 11.00 23.00 38.33 I 6.00 18 30.00 0 0.00 0 0.00 04:00:00 33.00 1 11.00 23.00 0.00 I 6.00 18 0.00 0 0.00 0 0.00 04:15:00 37.00 1 11.00 23.00 0.00 1 6.00 18 0.00 0 0.00 0 0.00 04:30:00 40.50 1 11.00 23.00 0.00 I 6.00 18 0.00 0 0.00 O, 0.00 04:45:00 42.50 1 11.00 23.00 0.00 I 6.00 18 0.00 0 0.00 O' 0.00 05:00:00 48.25 I 11.00 23.00 0.00 1 6.00: 18 0.00 O' 0.00 0 0.00! Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.2 Time Sur~te Tank #1 Strap ,., Tank #2 Strap Tank #3 Strap Tank Total Inc. Total Inc. Total Inc. Reading ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 16-Mar-94 05:15:00 53.00 I 11.00 23.00 0.00 I 6.00 18 0.00 0 0.00 0 0.00 05:30:00 57.00 I 11.00 23.00 0,00 I 6.00 18 0.00 0 0.00 0 0.00 05:45:00 70.00 I 11.00 23.00 0,00 1 6.00 18 0.00 0 0.00 0 0.00 ....... 06:00:00 79.00 I 11.00 23.00 0,00 1 6.00 18 0.00 0 0.00 0 0.00 06:15:00 56.00 1 11.50 23.50 0,83 3 0.00 36 30.00 0 0.00' 0 0.00 06:30:00 60.00 I 11.50 23.50 0.00 3 0.00 36 0.00 0 0.00 0 0.00 -- -- 06:45:00 63.00 I 11.50 23.50 0.00 3 0.00 36 0.00 0 0.00 0 0.00 -_ 07:00:00 74.00 I 11.50 23.50 0.00 3 0.00 36 0.00 0 0.00 0 0.00 07:15:00 51.50 I 11.50 23.50 0,00 4 6.00 54 30.00 0 0.00 0 0.00 07:30:00 54.50 I 11.50 23.50 0,00 4 6.00 54 0.00 0 0.00 0 0.00 .... 07:45:00 62.50 I 11.50 23.50 0,00 4 6.00 54 0.00 0 0.00 0 0.00 -- 08:00:00 69.00 I 11.50 23.50 0.00 4 6.00 54 0,00 0 0.00 0 0.00 __ , 08:15:00 45.00 I 11.50 23.50 0.00 5 9.50 70 25.83 0 0.00 0 0.00 08:30:00 54.00 I 11.50 23.50 0.00 5 9.50 70 0.00 0 0.00 0 0.00 08:45:00 60.00 1 11.75 23.75 0,42 5 9.50 70 0.00 0 0.00 0 0.00 __ 09:00:00 68.50 1 11.75 23.75 0,00 5 9.50 70 0.00 0 0.00 0 0.00 __ 09:15:00 38.50 I 11.75 23.75 0,00 7 5.50 90 33.33 0 0.00 0 0.00 09:30:00 45.00 1 11.75 23.75 0,00 7 5.50 90 0.00 0 0.00 0 0.00 __ . 09:45:00 1 11.75 23.75 0o00 7 5.50 90 0.00 0 0.00 0 0.00 10:00:00 55.00 1 11.75 23.75 0,00 7 5.50 90 0.00 0 0.00 0 0.00 ._ 10:15:00 43.00 2 0.00 24.00 0.42 8 2.50 99 15.00 O: 0.00 0 0.00 10:30:00 49.00 2 0.00 24.00 0,00 8 2.50 99 0.00 0 0.00 0 0.00 -- 10:45:00 2 0.00 24.00 0,00 8 2.50 99 0.00 0 0.00 0 0.00 11:00:00 55.00 2 0.00 24.00 0.00 8 2.50 99 0.00 0 0.00 0 0.00 11:15:00 43.00 2 2.25 26.25 3.75 8 11.55 108 15.08 0 0.00 0 0.00 11:30:00 2 2.25 26.25 0.00 8 11.55 108 0.00 0 0.00 0 0.00 11:45:00 2 2.25 26.25 0.00 8 11.55 108 0.00 0 0.00 0 0.00 12:00:00 74.00 2 2.25 26.25 0.00 8 11.55 108 0.00 0 0.00 0 0.00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.3 Time Surge Tank 81 Strap Tank #2 Stra_p Tank #3 Strap Tank Total Inc. Total Inc. Total Inc. Reading ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 16-Nlar-94 -- __ , 12:15:00 43.00 2 3.00 27.00 1.25 10 6.00 126 30.75 0 0.00 0 0.00 -- _ 12:30:00 54.00 2 3.00 27.00 0.00 10 6.00 126 0.00 0 0.00 0 0.00 -- -- _ 13:00:00 67.50 2 3.00 27.00 0.00 10 6.00 126 0.00 0 0.00 0 0.00 -- 13:30:00 81.00 2 3.50 27.50 0.83 10 6.00 126 0.00 0 0.00 0 0.00 14:00:00 93.00 2 5.001 29.00 2.50 10 6.00 126 0.00 0 0.00 0 0.00 ............ __14:15:00 51.50 2 6.007 30.00 1.67 12 11.00 155 48.33 0 0.00 0 0.00 --__ 14:30:00 2 7.00 31.00 1.67 12 11.00 155 0.00 0 0.00 0 0.00 -- __ 15:00:00 60.00 2 8.25; 32.25 2.08 12 11.00 155 0.00 0 0.00 0 0.00 ,., 15:30:00 2 9.00 33.00 1.25 12 11.00 155 0.00 0 0.00 O' 0.00 16:00:00 86.50 2 10.50 34.501 2.50 12 11.00 155 0.00 0 0.00 0 0.00 -- _ 16:15:00 45.00 2 11.25 35.25 1.25 12 11.00 155 0.00 2 1.00 25 41.67 ___ 16:30:00 52.00 3 0.00 36.00 1.25 12 11.00 155 0.00 2 1.00 25 0.00 ~._ 17:00:00' 59.50 3 2.75 38.75 4.58 4.00 4 -251.67 2 1.00 25 0.00 17:30:00 74.00 3 3.50 39.50 1.25 4.00 4i 0.00 2 1.00 25 0.00 -- _ 18:00:00 84.00 3 3.50 39.50 0.00 4.00 4 0.00 2 1.00 25 0.00 18:15:00 45.00 3 4.75 40.75 2.08 4.00 4 0.00 4 3.00 51 43.33 __ 18:30:00 51.00 3 6.00 42.00 2.08 4.00 4 0.00 4 3.00 51 0.00 19:00:00 64.00 3 8.00 44.00 3.33 4.00 4 0.00 4 3.00 51 0.00 19:30:00 77.00 3 9.00 45.00 1.67, 4.00 4 0.00 4 3.00 51 0.00 20:00:00 87.00 3 9.00 45.00 0.00 4.00 4 0.00 4 3.00 51 0.00 ____ 20:15:00 45.00 3 9.25 45.25 0.42 4.00 4 0.00 6, 5.00 77 43.33 20:30:00 52.00 3 9.50 45.50 0.42 4.00 4 0.00 6 5.00 77 0.00 __ 21:00:00 65.00 3 9.50 45.50 0.00 4.00 4 0.00 6 5.00 77 0.00 -- 21:30:00 79.00 3 9.50 45.50 0.00 4.00 4 0.00 6 5.00 77 0.00 22:00:00 87.00 3 9.50 45.50 0.00 4.00 4 0.00 6 5.00 77 0.00 22:15:00 45.00 3 9.50 45.50 0.00 4.00 4 0.00 8 10.00 106 48.33 22:30:00 52.00 3 9.50 45.50 0.00 4.00 4 0.00 8 10.00 106 0.00 23:00:00 64.00 3 9.50 45.50 0.00 4.00 4 0.00 8 10.00 106 0.00 Phillips Petroleum Company Sunfish #3 DST//1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.4 Time Surge Tank//1 Strap __ Tank 82 Strap Tank #3 Strap Tank Total Inc. Total Inc. Total Inc. -- Readin~ ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 16-Mar-94 23:30:00 77.00 3 9.50 45.50 0.00 4.00 4 0.00 8 10.00 106 0.00 17-Mar-94 __ 00:00:00 87.00 3 9.50 45.50 0.00 4.00 4 0.00 8 10.00 106 0.00 __ 00:15:00 45.00 3 9.75 45.75 0.42 4.00 4 0.00 11 1.50 134 45.83 00:30:00 51.00 3 10.00 46.00 0.42 4.00 4 0.00 11 1.50 134 0.00 01:00:00 60.00 3 11.00 47.00 1.67 4.00 4 0.00 11 1.50 134 0.00 01:30:00 74.00 3 11.50 47.50 0.83 4.00 4 0.00 11 1.50 134 0.00 02:00:00 84.00 4 0.00 48.00 0.83 4.00, 4 0.00 11 1.50 134 0.00 -- 02:15:00 45.00 4 0.00 48.00 0.00 4.00 4 0.00 13 3.25 159 42.92 02:30:00 51.00 4 0.00 48.00 0.00 4.00 4 0.00 13 3.25 159 0.00 ,.. 03:00:00 64.00 4 1.00 49.00 1.67 4.00 4 0.00 13' 3.25 159 0.00 -- 03:30:00 76.00 4 1.00 49.00 0.00 4.00 4 0.00 13 3.25 159 0.00 04:00:00 87.00 4 1.50 49.50 0.83 4.00 4 0.00 13 3.25 159 0.00 04:15:00 42.00 4 1.50 49.50 0.00 4.00 4 0.00 15 9.00 189 49.58 04:30:00 47.00 4 1.50 49.50 0.00 4.00 4 0.00 15 9.00 189 0.00 05:00:00 56,00 4 2.50 50.50 1.67 4.00 4 0.00 15 9.00 189 0.00 05:30:00 70.00 4 3.00 51.00 0.83 4.00 4 0.00 15 9.00 189 0.00 06:00:00 82.00 4 3.50 51.50 0.83' 4.00 4 0.00 15 9.00 189 0.00 06:15:00 45.00 4 3.75 51.75 0.42 4.00 4 0.00 17 7.25 211 37.08 06:30:00 53.00 4 4.00 52.00 0.42 4.00 4 0.00 17 7.25 211 0.00 07:00:00 67.00 4 4.50 52.50 0.83 4.00 4 0.00 17 7.25 211 0.00 08:00:00 89.00 4 4.75 52.75 0.42 4.00 4 0.00 17 7.25 211 0.00 08:15:00 45.00 4 4.88 52.88 0.21 2 9.25 33 48.75 17 7.25 211 0.00 08:30:00 50.00 4 5.00 53.00 0.21 2 9.25 33 0.00 17 7.25 211 0.00 -- 09:00:00 63.50 4 5.75 53.75 1.25 2 9.25 33 0.00 17 7.25 211 0.00 -- 09:30:00 74.00 4 6.75 54.75 1.67 2 9.25 33 0.00 17 7.25 211 0.00 10:00:00 84.00 4 7.75 55.75 1.67 2 9.25 33 0.00 17 7.25 211 0.00' 10:15:00 45.00 4 8.38 56.38 1.04 4 10.75 59 42.50 17 7.25 211 0.00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.5 Time Surge Tank #1 Strap Tank #2 Strap , Tank #3 Strap ___ Tank Total Inc. Total Inc. Total Inc. Readin~ ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 17-Mar-94 10:30:00 49.00 4 9.00 57.00 1.04 4 10.75 59 0.00 17 7.25 211 0.00 .... 11:00:00 58.00 4 9.25 57.25 0.42 4 10.75 59 0.00 17 7.25 211 0.00' 11:30:00 72.00 4 10.00! 58.00 1.25 4 10.75 59 0.00 17 7.25 211 0.00 12:00:00 83.00 4 10.75 58.75 1.25 4 10.75, 59 0.00 17 7.25 211 0.00 12:15:00 45.00 4 10.88 58.88 0.21 7 0.00 84 42.08 17 7.25 211 0.00 12:30:00 50.00 4 11.00 59.00 0.21 7 0.00 84 0,00 17 7.25 211 0.00 13:00:00 57.00 5 1.00 61.00 3.33 7 0.00 84 0.00 17 7.25 211 0.00 13:30:00 72.00 5 3.00 63.00 3.33 7 0.00 84 0.00 17 7.25 211 0.00 14:00:00 79.00 5 3.50 63.50 0.83 7 0.00 84 0.00 17 7.25 211 0.00 -- 14:15:00 45.00 5 3.75 63.75 0.42 9 0.00 108 40.00 17 7.25 211 0.00 -- 14:30:00 50.00 5 4.00 64.00 0.42 9 0.00 108 0.00 17 7.25 211 0.00 15:00:00 58.00 5 4.50 64.50 0.83 9 0.00 108 0.00 17 7.25 211 0.00 -- 15:30:00 73.00 5 4.50 64.50 0.00 9 0.00 108 0.00 17 7.25 211 0.00' 16:00:00 83.00 5 5.00 65.00 0.83 9 0.00 108 0.00 17 7.25 211 0.00 16:30:00 93.00 5 6.25 66.25 2.08 9 0.00 108 0.00 17 7.25 211 0.00 17:00:00 106.00 5 7.00 67.00 1.25' 9 0.00 108 0.00 17 7.25 211 0.00 -- 17:30:00 116.00 5 7.75 67.75 1.25 9 0.00 108 0.00 17 7.25 211 0.00 -- -- 18:00:00 127.00 5 9.00 69.00 2.08 9 0.00 108 0.00 17 7.25 211 0.00 18:15:00 65.00 5 9.50 69.50 0.83 12 4.00 148 66.67 17 7.25 211 0.00 --. 18:30:00 68.00 5 10.00 70.00 0.83 12 4.00 148 0.00 17 7.25 211 0.00I 19:00:00 76.00 5 11.00 71.00 1.67 12 4.00 148: 0.00 17 7.25 211 0.00 19:30:00 87.00 5 11.50 71.50 0.83 12 4.00 148 0.00 17 7.25 211 0.00 20:00:00 97.00 6 1.00 73.00 2.50 12 4.00 148 0.00 17 7.25 211 0.00 -- -- 20:30:00 108.00 6 1.75 73.75 1.25 12 4.00 148 0.00 17 7.25 211 0.00 -- 21:00:00 118.50 6 2.50 74.50 1.25' 12 4.00 148 0.00 17 7.25 211 0.00 21:15:00 65.00 6 2.75 74.75 0.42 151 3.25 183 58.75 17 7.25 211 0.00 21:30:00 70.00 6 3.00 75.00 0.42 15 3.25 183 0.00 17 7.25 211 0.00 22:00:00 80.00 6 3.25 75.25 0.42 15 3.25 183 0.00 17 7.25 211 0.00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.6 Time Surge Tank//1 Strap Tank//2 Strap Tank//3 Strap Tank Total Inc. Total Inc. Total Inc. ,_ Readin~ ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 17-Mar-94 -- 22:30:00 92.00 6 3.50 75.50 0.42 15 3.25 183 0.00 17 7.25 211 0.00 23:00:00 103.00 6 4.00 76.00 0.83 15 3.25 183 0.00 17 7.25 211 0.00 .-- -- 23:30:00 115.00 6 4.00 76.00 0.00 15 3.25 183 0.00 17 7.25 211 0.00 18-M ar-94 00:00:00 127.00 6 4.00 76.00 0.00 15 3.25 183 0.00 17 7.25, 211 0.00 -- 00:15:00 65.00' 6 4.00 76.00 0.00 18 9.00 225~ 69.58 17 7.25 211 0.00 00:30:00 68.50 6 4.00 76.00 0.00 18; 9.00 225 0.00 17 7.25 211 0.00 -- 01:00:00 81.00 6 4.00 76.00 0.00 18 9.00 225 0.00 17 7.25 211 0.00 01:30:00 92.00 6 4.00 76.00 0.00 18 9.00 225 0.00 17 7.25 211 0.00 ._ 02:00:00 105.00 6 4.00 76.00 0.00 18 9.00 225 0.00 17 7.25 211 0.00 02:30:00 117.00 6 4.00 76.00 0.00 18 9.00 225 0.00 17 7.25 211 0,00 03:00:00 128.00 6 4.00 76.00 0.00 18 9.00 225 0.00 17 7.25 211 0.00 03:30:00 45.00 11 3.50 135.50 99.17 18 9.00 225 0.00 17 7.25 211 0.00 __ -- 04:00:00 51.00 11 3.50 135.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 04:30:00 66.00 11 3.50 135.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 -- 05:00:00 78.00 11 3.50 135.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 05:15:00 37.00 13 5.50 161.50 43.33 18 9.00 225 0.00 17 7.25 211 0.00 __ -- Total Liquid Per Tank -o Flow I 269.17 626.68 352.0__9 Total Liquids Produced -- Flow 1 1247.94 I Total Liquids Per Tank Transfered -- Flow I 0.00 251.67 0.00 I I ,Total Liquids Transfered To Girder Tank -- Flow 1 251.67 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.7 Time Surge Tank//1 Strap Tank//2 Strap Tank//3 Strap ~_ Tank Total Inc. Total Inc. Total Inc. Readin~ ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 20-Mar-94 .... 05:00:00 37.00 13 5.50 161.50 0.00 18 9.00 225 0.00, 17 7.25 211 0.00 -- 06:00:00 13 5.50 161.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 __ -- 06:15:00 37.50 13 5.50 161.50 0.00 18 9.00 225 0.00 17 7.25. 211 0.00 06:30:00 13 5.50 161.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 07:00:00 42.00 14 1.50 169.50 13.33 18 9.00 225 0.00 17 7.25 211 0.00 07:30:00 53.00 14 2.00 170.00 0.83 18 9.00 225 0.00 17 7.25 211 0.00 ___ 08:00:00 53.00 15 0.50 180.50 17.50 18 9.00 225 0.00 17 7.25 211 0.00 08:30:00 70.00 15 0.50 180.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 09:00:00 81.00 15 0.50 180.50 0.00 18 9.00 225 0.00 17 7.25 211 0.00 09:30:00 93.00 15 0.50 180.50 0.00 2 0.25 24' -334.59 17 7.25 211 0.00 10:00:00 105.00 15 0.50 180.50 0.00 2 0.25 24 0.00 17, 7.25 211 0.00 -- 10:30:00 27.00 0 8.00 8.00 -287.51 6 3.50 76 85.42 17 7,25 211 0.00 11:00:00 37.00 0 8.00 8.00 0.00 6 3.50 76 0.00 17 7.25 211 0.00 -- 11:30:00 44.00 0 8.00 8.00 0.00 6 3.50 76 0.00 17 7.25 211 0.00 12:00:00 51.00 0 8.00 8.00 0.00 6 3.50 76 0.00 17 7.25 211 0.00 12:30:00 63.00 0 8.00 8.00 0.00 6 3.50 76 0.00 17 7.25 211 0.00 ._ 13:00:00 75.00 0 8.00 8.00 0.00 6 3.50 76 0.00 17 7.25 211 0.00 -- 13:15:00 25.00 0 8.00 8.00 0.00 9 0.50 109 55.00 17 7.25 211 0.00 13:30:00 28.50 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 __ 14:00:00 37.50 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 ___ 14:30:00 46.00 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 15:00:00 53.00 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00' 15:30:00 67.00 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 16:00:00 75.00 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 16:30:00 85.00 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 17:00:00 94.50 0 8.00 8.00 0.00 9 0.50 109 0.00 17 7.25 211 0.00 17:15:00 40.00 0 8.00 8.00 0.00 11 0.25 132 39.58 17 7.25 211 0.00 17:30:00 44.00 0 8.00 8.00 0.00 11 0.25 132 0.00 17 7.25, 211 0.00 Phillips Petroleum Company Sunfish #3 DST 81 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.8 Time Sur~le Tank #1 Strap Tank//2 Strap Tank//3 Strap Tank Total Inc. Total Inc. Total Inc. -- Reading ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume 20-Mar-94 -- __ 18:00:00 53.00 0 8.00 8.00, 0.00 11 0.25 132 0.00 17 7.25 211 0.00 -- 18:30:00 60.50 0 8.00 8.00, 0.00 11 11.25 143 18.33 17 7.25 211 0.00 -- 19:00:00 71.00 0 8.00 8.00 0.00 11 11.25 143 0.00 17 7.25 211 0.00 --- -- 19:30:00 82.00 0 8.00 8.00 0.00 11 11.25 143 0.00 17 7.25 211 0.00 _ 20:00:00 89.00 0 8.00 8.00 0.00 11 11.25 143 0.00 17 7.25 211 0.00 20:15:00 30.00 0 8.00 8.00 0.00 15 2.25 182 65.00 17 7.25 211 0.00 __ 20:30:00 33.00 0 8.00 8.00 0.00 15 2.25 182 0.00 17 7.25 211 0.00 -- -- _ 21:00:00 40.00 0 8.00 8.00 0.00 15 2.25 182 0.00 17 7.25 211 0.00 -- 21:30:00 0.00 0 8.00 8.00 0.00 17 0.25 204 36.67 17 7.25 211 0.00 -- --- --. _Total Liquid Per Tank -- Flow 2 31.67 300.01 0.00 I Total Liquids Produced -- Flow 2 331.67 -_ T_otal Liquids Per Tank Transfered -- Flow 2 287.51 334.59 0.00 Total Liquids Transfered To Girder Tank -- Flow 2 622.10 -- __ .Total Liquids Produced -- Flow 1 and Flow 2 1579.61 I I __ Total Liquids Transfered To Girder Tank -- Flow 1 and Flow 2 873.77 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Surge and Frac Tank Readings Page No. 1.6.9 _ Time Sur~le __ Tank 81 Strap Tank 82 Strap _ Tank//3 Strap Tank ,_ Total Inc. Total Inc. Total Inc. -- Readin~l ft. in. Inches Volume ft. in. Inches Volume ft. in. Inches Volume Reverse Out and Misc. Liquids ! _ Begin Stra_E Tank//1 0 8.00 8.00 13.33 End Strap Tank//1 ___ 12 11.00 155.00 258.3_~4 ...................................................................... -- Total Liquids Reversed 245.00 --- -- -- -- --. -- ---- -_ -- -- -- --- --- -. ...... Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.1 Time Remarks , , Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol ,. ......... (psi~l) (de,If! (psi~ll (mscf/dl (mscf) (bbl/d! .... {bbll (scf/bbl} (bpd). (bbl) 13-Mar-94 __ , 13:00:00 Pickup Guns --. 14:45:00 RIH w/Tubing 14-Mar.-.94 ................................... · 01:00:00 Set Guns on Hanger Assembly .... 17:00:00 ~Set 'BWD' Packer & Seal Assembly on Wireline 19:30:00 Pickup Test Tool String 20:00:00 Start HMR Gauges .......................................... 23:15:00 Tools in hole, RIH w/Tubing 23:30:00 Test String to 5000 psi 15-Mar-94 03:00:00 Test Tubing String 06:07:00 Test Tubing String 06:45:00 Space Out String 07:30:00 Rig up Test Tree 09:08:00 Test Annulus 2000 psi, Shear TST, Unlock LPR-N 09:18:00 Bleed off Annulus, LPR-N closed 09:30:00 Rig up SWS 13:05:00 Pressure Test Suface Equipment 60.06 34.79 0.70 ...... -- 15:30:00 Test Completed, Cool Down N2 Unit 4023.28 37.12 0.96 16:00:00 Cycle OMNI 0.00 34.94 1.18 16:33:00 Finish Cycling OMNI, Line up to displace w/N2 0.00 34.24 1.21 16:40:00 Displace downhole w/N2 9.01 32.42 1.01 17:20:00 Close BOP Rams 2428.53 32.36 3.50 -- 17:30:00 OMNI to Blank Position, Shut down N2 3020.03 31.38 569.66 17:35:00 Bleed off Annulus 3089.78 30.83 1089.16 -- 17:45:00 Shoot Fluid Level, 7552 ft 3083.78 29.50 4.90 18:00:00 Safety Meeting 3079.78 28.90 9.16 _ 18:36:00 Cycle OMNI to Well Test Position 3070.78 29.56 15.33 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.2 ,,, Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -- Total Total Rate Volume Rate Vol ...... {psig) (de,If) {psiQ) {mscf/d) (mscf) (bbl/d) {bbl) (scf/bbl) {.bpd) (bbl) 15-M ar-94 .... 18:49:00 Open LPR-N 3068.03 29.94 605.41 19:00:00 Pump downhole w/N2 3066.53 30.68 1962.03 19:19:30 Reach Minimum Firing Pressure 4641.78 31.96 1990.41 19:23:00 Reach Nominal ..Firing Pressure 5095.53 31.76 1999.53 19:27:00 Reach Maximum Firing Pressure 5591.28 31.63 2009.53 19:28:00 Bleed Off N2 to desired 1000 psi underbalance 5535.53 31.77 2009.78 19:34:00 Shut in at choke. Standby on guns 2302.53 54.43 1925.16 19:42:55 Guns Fired 2270.03 51.04 1926.91 19:47:30 Open well to 12/64 adj choke 2283.53 50.37 1921.16 ___ 20:00:00 1650.78 58.60 1913.28 _ ., 20:15:00 1141.78 58.20 1920.41 -- 20:30:00 773.78 58.21 1938.16 -- 20:45:00 492.28 57.32 1961.53 20:59:00 Shut in at choke 287.53 56.55 1985.78 -- -- 21:00:00 Shoot Fluid Level 278.28 56.45 1987.53 21:15:00 391.78 52.40 2011.66 -- -- 21:27:00 Fluid Level 2866 ft 506.53 50.52 2024.28 ...... 21:30:00 Open well to 12/64 adj choke 540.03 50.06 2026.66 -- 21:34:00 Change to 14/64 373.53 51.99 2026.41 -- 21:45:00 Separator on bypass to Surge Tank 58.21 53.64 2030.66 .... 22:00:00 0.00 51.62 2040.41 22:10:00 Fluid to Surface 0.00 49.43 2045.41 22:15:00 Fluid to Separator (Bypassed To Surge Tank) 256.28 55.91 2049.53 22:25:00 Rock Choke 263.53 58.92' 2048.41 22:26:00 Open to 20/64 choke 240.66 58.61 2047.28 __ 22:30:00 100.73 58.11 1906.78 22:45:00 Rock Choke 604.53 58.22 1916.91 22:54:00 Open to 24/64 Choke 614.03; 57.25 1915.28= Phillips Petroleum Sunfish//3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.3 ............... Time Remarks __ Whp Wht Casing_ Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMete_r Total Total Rate Volume Rate Vol ... Ipsi~l) (de,If) (psig!. {mscf/d) (mscf) (bbl/d) (bbl) (scf/bbl) {bpd) (bbl) 15-Mar-94 --. -- 23:00:00 264.78 61.18 1908.53 23:03:00 Trace Oil to Surface 270.03 61.66 1908.91 23:08:00 282.03 62.16 1910.28 23:1 1:00 307.28 61.94 1911.78 23:15:00 21.41 0.22 23:18:00 384.78 61.02 1914.91 23:30:00 414.28 59.91 1780.16 255.82 2.89 23:45:00 440.03 59.02 1787.16 222.77 5.21 16-Mar-94 00:00:00 Continue to flow well. 436.53 58.88 1792.91 242.09 7.73 00:15:00 405.03 58.38 1797.66 226.71 10.09 00:30:00 434.78 59.29 1802.66 177.28 11.94 00:45:00 501.03 58.98 1806.66 136.54 13.36 __ -- 01:00:00 595.28 59.05 1808.41 129.54 14.71 01:06:00 Rock Choke, Change to 26164 613.03 59.22 1808.66 -- 01:15:00 456.78~ 59.45 1805.28 314.94 17.99 01:30:00 388.53 59.65 1808.28 366.57 21.81 0.00 0.00 01:31:00 Change choke to 18/64, Flow to Separator 379.78 59.76 1808.66 01:45:00 Dump Surge Tank To Tank #1 471.78 59.30 1816.66 96.21 22.81 0.00 0.00 .. 01:51:00 Change choke to 22164 536.28 59.09 1819.53 02:00:00 467.53 59.05 1819.41 8.27 22.90 0.00 0.00 -- 02:01:00 463.78 59.10 1819.53 02:15:00 442.28 58.79 1822.28 23.62 23.14 -- 02:17:00 442.78 58.71 1822.78 __ 02:30:00 447.03 58.86 1826.16 18.57 23.34 216.08 4.50 02:45:00 Gas Gravity = 0.856 470.03 58.88 1830.28 7.86 23.42 02:47:00 474.28 58.79 1830.78 293.19 26.88 -- 02:50:00 BS&W 40% Mud 1.5% water 483.03 58.78 1831.53 292.72 27.49 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.4 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -- Total Total Rate Volume Rate Vol __ -- ...................... (psis) (de,If) {psis) (mscf/d) {ms?f) (bblld) (bbl) (scf/bbl) (bpd} (bbl) 16-Mar-94 03:00:00 BS&W 40% Mud 2% H20 504.28 58.64 1833.53 255.82 29.29 179.62 8.24 ........ _ 03:15:00 BS&W 36% Mud 5% H20 513.53 58.47 1835.66 246.05 31.8.5 .............. 1 03:30:00 BS&W 36% Mud 5% H20 515.78 58.28 1837.16 263.22 34.59 290.86 14...,d' .03:4.5:00 Dump Surge Tank BS&W 32% Mud 5% H20 513.78 57.96 1838.28 257.18 37.27 322.93' 30.27 796.39 04:00:00 BS&W 32% Mud Trace H20 514.03 58.04 1839.28 255.96 39.94 419.35 23.04 04:15:00 BS&W 35% Emulsion 514.53 57.96 1840.16 253.42 42.58 04:30:00 BS&W 35% H20 Gas Gravity = 0.861 521.53 58.35 1841.03 253.90 45.22 457.96 32.58 04:45:00 BS&W 35% H20 Choke Change to 24/64 ths 528.53 58.30 1841.91 251.85 47.85 ,, 05:00:00 BS&W 35% H20 457.28 57.63 1841.28 399.49 52.01 504.50 43.09 05:15:00 BS&W 35% H20 410.03 57.68 1843.41 387.40 56.04 05:30:00 BS&W 35% H20 374.28 58.43 1847.53 389.77, 60.10 517.36, 53.87 05:38:00 Change Choke 26/64ths 365.53 58.83 1850.28 307.14 61.81 05:45:00 BS&W 35% H20 326.03 58.88 1851.91 437.20 64.12 06:00:00 BS&W 35% H20 289.78 58.14 1858.03 409.82 68.39 733.95 69.16 06:15:00 BS&W 35% H20 275.03 58.81 1866.91 378.56 72.33 262.07 60.30 1444.50 06:30:00 BS&W 35% H20 261.78 58.99 1876.66 344.59 75.92 765.98 85.12 - 06:45:00 BS&W 22% H20 20 Emulsion 276.78 60.04 1886.03 360.13 79.67 06:50:00 Oil Gravity = 36.3 APl @ 60 F. 272.78 60.10 1888.91 322.62 80.79 07:00:00 Dump Surge Tank BS&W 35% H20 273.03 60.59 1894.78 343.09 83.24 662.98 98.93 07:15:00 BS&W 35% H20 284.78 56.67 1902.53 344.95 86.83 571.04 90.04 604.07 -- 07:30:00 BS&W 35% H20 308.03 56.37 1910.16 338.76 90.36 663.58 112.75 07:45:00 BS&W 35% H20 321.53 54.85 1917.03 372.77; 94.24 -- 08:00:00 Dump Surge Tank BS&W 35% H20 324.03 54.69 1923.53 377.91 98.18 691.88 127.17 08:15:00 337.03 57.32 1929.91 364.65 101.98 506.58 116.43 719.84 __ -- 08:30:00 BS&W 35% H20 343.78 57.99 1782.16 391.52 106.06 696.12 141.67 08:45:00 BS&W 35% H20 338.28 57.95 1754.91 402.32 110.25 09:00:00 Dump Surge Tank BS&W 35% H20 344.03 59.28 1725.66 401.22 114.43 672.3_6 15.5..6.8, 09:15:00 326.78 59.99 1758.03 366.65 118.25 632.65 149.38 579.54 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.5 , , Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol {psi~l) (de,If) {psig) (mscf/d) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) {bbl) 16-Mar-94 09:30:00 BS&W 30% H20 5% Emulsion 328.28 60.01 1720.28 368.56 122.08 802.23 172.39 -- -- 09:45:00 328.03 59.54 1627.03 387.01 126.12 10:00:00 Dump Surge Tank BS&W 28% H20 5% Emulsion 331.03 59.51 1655.53 377.86 130.05 1276.46 198.~,~ 10:15:00 332.53 60.31 1658.78 363.92. 133.84 284.50 164.20 1279.16 10:30:00 Surge Tank Level 49 bbl BS&W 60% H20 0.2% Sa 350.78 60.93 1661.66 329.69 137.28 1438.25 228.95 10:45:00 313.28 61.04 1663.03 504.63 142.53 -- 11:00:00 IDump Surge Tank Chng orifice plate (1.125") 286.53 61.10 1665.91 4.05 142.58 835.00 246.34 11:15:00 @ 11:00 BS&W 35% H20 0.2% Sand 276.78 61.59 1670.16 620.82 149.04 284.50 179.01 2182.18 11:30:00 264.53 61.78 1675.03 527.80 154.54 545.47 257.71 __ - 11:45:00 265.03 62.48 1679.53 403.35 158.74 ... 12:00:00 BS&W 25% H20 264.03 62.98 1683.53 428.19 163.20 692.69 272.14 12:15:00 BS&W 32% H20 262.78 63.59 1686.16 390.42 167.27 569.02 208.65 686.12 -- 12:30:00 BS&W 37% H20 265.78 62.13 1688.03 419.61 171.64 748.29 287.73 12:45:00 BS&W 25% H20 257.03 63.01 1690.03 418.03 176.00 13:00:00 BS&W 40% H20 Chlorides 7,000 PH 7.5 271.28 63.71 1690.16 406.81 180.23 457.06 297.25 13:15:00 BS&W 33% H20 277.53 64.12 1690.41 432.26 184.74 13:30:00 BS&W 22% H20 284.03 64.43 1690.41 411.24 189.02 226.41 301.97 13:45:00 BS&W 25% H20 279.78 63.34 1689.78 432.16 193.52 -- 14:00:00 Dump Surge Tank BS&W 11% H20 287.03 63.58 1688.9' 417.48 197.87 187.15 305.87 -- 14:15:00 BS&W 11% H20 286.78 62.12 1687.66 380.53 201.83 509.81 256.45 746.42 14:30:00 BS&W 10% H20 284.53 62.56 1686.28 387.31 205.87 236.03 310.78 14:45:00 BS&W 11% H20 296.78 63.01 1685.66 302.19 209.02 .... 15:00:00 BS&W 10% H20 Chlorides 7,000 PH 7.5 299.53 62.58 1684.16 424.70 213.44 307.29 317.19 15:15:00 BS&W 16% H20 297.53 62.49 1681.91 415.69 217.77 _ 15:30:00 BS&W 17% H20 300.78, 63.13 1680.03 425.03 222.20 235.10 322.08 __ ,. 15:45:00 BS&W 16% H20 300.78; 63.36 1678.78 414.85 226.52 16:00:00 Dump Surge Tank BS&W 20% H20 304.03 63.26 1677.28 399.48 230.68 158.99 325.40 16:15:00 BS&W 17% H20 300.53 63.22 1676.41 386.07 234.70 439.18 297.62 879.08 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.6 Time' Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -- Total Total Rate Volume Rate Vol - (psi~l) (degf) (psig) {mscf/d) (mscf) {bbl/d) {bbl) {scf/bbl) (bpd) (bbl) 16-Mar-94 16:30:00 BS&W 8% H20 307.53 62.90 1675.28 383.09 238.69 203.32 329.63 16_:45:00 BS&W 12% H20 305.53 62.36 1674.03 398.52 242.84 17:00:00 BS&W 6% H20 313.78 61.71 1672.91 394.14 246.95 323.54 336.,,,.' 17:15:00 BS&W 12% H20 315.53 62.021 1672.16 400.89 251.12 17:30:00 BS&W 15% H20 Chlorides 7,000 PH 7.5 315.53 62.03 1671.28 404.89 255.34 356.60 343.80 17:45:00 BS&W 18% H20 319.53 61.93 1670.28 398.98 259.50 18:00:00 BS&W 15% H20 329.78 61.97 1668.66 407.37 263.74 298.54 350.02 18:15:00 @ 18:30 8S&W 11% H20 329.28 61.48 1666.66 354.37 267.43 462.49 340.98 766.23 18:30:00 Rock Choke, Set to 24/64 Gas Gravity = 0.772 355.03 61.46 1664.53 285.17 270.40 277.48 355.80 18:45:00 BS&W 20% H20 334.53 60.96 1660.91 428.34 274.87 I 19:00:00 327.78 61.53 1658.03 415.85 279.20 348.52 363.06 19:15:00 325.03 62.02 1655.53 413.01 283.50 -- 19:30:00 BS&W 30% H20 322.78 62.41 1652.91 439.56 288.08, 372.66 370.83 -- 19:45:00 309.78 60.94 1650.78 418.54 292.44 20:00:00 BS&W 26% H20 Chlorides 9,500 PH 7.0 317.78 57.99 1648.78 388.86 296.49 257.48 376.19 20:15:00: 322.28 58.50 1646.03 353.99 300.18 462.86 384.37 764.78 20:30:00 BS&W 35% H20 331.03 56.74 1642.53 365.68 303.99 234.14 381.07 __ -- 20:45:00 335.78 58.53 1638.78 374.36 307.89 21:00:00 BS&W 30% H20 354.03 59.16 1635.03 342.50 311.45 164.54 384.50 21:12:00 Change to 24 positive 342.28 60.00 1631.03 395.92 314.75 21:15:00 340.28 59.66 1630.03 418.10 315.88 21:30:00 345.53 59.24 1626.66 377.46 319.81 186.37 388.38 -- 21:45:00 351.03 57.05 1623.03 384.02 323.81 22:00:00 BS&W 30% H20 346.78 56.13 1619.28 391.28 327.89 177.22 392.07 -- 22:15:00 349.78 55.89 1615.66 370.18 331.75 516.39 432.78 716.85 22:30:00 Gas Gravity = 0.792 344.78 54.61 1612.53 367.61 335.58 179.76 395.82 22:45:00 345.53 53.62 1610.28 377.63 339.51 23:00:00 BS&W 35% H20 335.53 52.75 1610.41 367.12 343.33 208.01 400.15, Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7,7 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol .... (psis) (de,If) (psis) (mscf/d) (mscf) (bbl/d) (bbl! . (scf/bbl) (bpd.) (bbl) 6-M a r-94 23:15:00 334.28 53.11 1610.28 388.89 347.38 23:30:00 Gas Gravity 0.792 331.78 52.16 1610.28 385.07 351.39 205.48 404 23:45:00 330.03 50.51 1610.66 382.84 355.38 _ 7-Mar-94 -- 00:00:00 Dump Surge Tank 326.28 49.88 1611.03 366.54 359.20 173.21 408.04 00:15:00 BS&W 30% H20 Oil Gravity 42.2 APl @ 60 F. 329.28 49.67 1611.03 351.14 362.86 489.58 478.68 717.24 00:30:00 Start Pumping Emulsifier @ Data Headers 324.78 49.86 1611.66 359.75 366.61 173.34 411.65 00:45:00 338.78 52.27 1615.16 377.09 370.53 -- 01:00:00 BS&W 30% H20 335.78 54.53 1615.03 357.96 374.26 172.17 415.24 01:15:00 334.53 54.43 1615.16 371.03 378.13 01:30:00 BS&W 20% H20 330.78 56.74 1615.91 379.92 382.09 166.27 418.70 -- 01:45:00 329.53 55.02 1617.16 364.63 385.88 02:00:00 Dump Surge Tank 333.03 57.10 1618.16 368.90 389.73 234.82= 423.59 02:15:00! 326.53 57.75 1619.16! 354.01 393.41 458.39 521.65 772.30 __ 02:30:00 BS&W 30% H20 332.78 55.65 1620.53 345.68 397.01 197.62 427.71 -- 02:45:00 338.28 56.67 1621.66 374.79 400.92 03:00:00 BS&W 30% H20 340.53 55.77 1622.66 383.90 404.92 176.94 431.40 03:15:00 329.78 51.71 1623.53 379.68 408.87 -- 03:30:00 BS&W 40% H20 Chlorides 14,000 PH 7.0 345.28 51.30 1624.66 371.64 412.74 242.63 436.,+o 03:45:00 340.53 51.99 1625.28 387.14 416.78 -- 04:00:00 Dump Surge Tank BS&W 40% H20 343.28 51.50 1625.91 392.08 420.86 242.46 441.50 04:15:00 RIH SWS @04:00 w/production logging tool 327.28 50.95 1626.53 349.64 424.50 529.89 571.33 659.84 .. 04:30:00 BS&W 26% H20 Chlorides 14,000 PH 7.0 331.78 50.32 1627.41 362.67 428.28 165.55 444.95 04:45:00 335.53 50.81 1628.53' 369.39 432.13 __ . 05:00:00 BS&W 24% H20 Chlorides 14,000 PH 7.0 334.03 50.67 1629.66 369.14 435.97 161.38 448.31 05:15:00 339.53' 50.45 1630.16 375.88 439.89 05:30:00 BS&W 23% H20 340.78 50.01 1630.53 369.41 443.74 166.84 451.79' -- 05:45:00 339.03 49.95 1630.91 381.96 447.72 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.8 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter _, Total Total Rate Volume Rate Vol -_ (psi~l) (de,If) (psis) (mscfld) (mscf) {bbl/d) {bbl) (scf/bbl) (bpd) (bbl) 17-Mar-94 06:00:00 Dump Surge Tank BS&W 14% H20 345.28 50.46 1631.16 396.66 451.85 156.98 455.06 06:15:00 334.03 51.46 1631.53 350.80 455.50 396.40 608.49 884.96 __ -- 06:30:00 BS&W 15% H20 Chlorides 14,000 PH 7.0 337.53 52.22 1632.16 _ 372.62 459.38 _ _ 150.8_~4 _4_.5~ 06:45:00 338.03 52.37 1632.78 376.42 463.30 07:00:00 BS&W 12% H20 Chlorides 14,000 PH 7.0 339.28 52.01 1633.41 403.70 467.51 104.20 460.37 07:15:00 331.28 50.71 1634.41 381.45 471.48 -- 07:30:00 BS&W 27% H20 Chlorides 14,000 PH 7.0 334.28 51.67 1635.78 387.62 475.52 146.27 463.42 07:45:00 340.78 51.31 1637.78 392.98 479.61 -- 08:00:00 Dump ST BS&W 33% H20 Chlorides 14,000 PH 340.28 51.41 1639.91 391.39 483.69 186.27 467.30 -- 08:15:00 338.78 51.29 1641.53 387.07 487.72 520.01 657.24 744.36 ...... 08:30:00 BS&W 27% H20 Chlorides 14,000 PH 7.0 336.78 51.56 1643.41 357.11 491.44 .. 165.87 470.76 -- Tank Temperature .... 08:45:00 SWS Finish Logging POOH 340.78 52.25 1645.53 376.33 495.36 Transducer 09:00:00 BS&W 15% H20 Chlorides 10,000 PH 7.5 340.53 52.59 1647.53 375.70 499.28 Inoperative. 126.47 ___ 473.39 09:15:00 345.03 52.52 1648.78 377.05 503.20 kFactor set to 1.00 __ . -- 09:30:00 BS&W 25% H20 Chlorides 10,000 PH 7.5 344.28 52.94 1649.16 378.65 507.15 146.46 476.44 09:45:00 323.53 53.62 1649.28 368.58 510.99 __ -- 10:00:00 Dump ST BS&W 28% H20 Chlorides 10,500 PH 341.03 54.03 1649.78 403.71 515.19 170.20 479.99 10:15:00 Closed Swab SWS Tools in Lubricator 334.53 55.53 1650.53i 358.52 518.93 453.34 699.74 790.83 -- 10:30:00 BS&W 30% H20 Chlorides 10,000 PH 7.0 332.28 56.65 1650.78 368.83 522.77 214.92 484.,~! 10:45:00 339.03 56.03 1651.41 366.78 526.59 11:00:00 BS&W 17% H20 Chlorides 10,000 PH 7.0 342.78 56.80 1651.91 380.09 530.55 149.47 487.58 · _ 11:15:00 346.28! 58.63 1652.28 404.52 534.76 11:30:00 .BS&W 20% H20 Chlorides 10,000 PH 7.0 345.53 59.19 1653.03 393.71 538.86' 137.28 490.44 ,. 11:45:00 346.78 58.19 1653.66 394.44 542.97 12:00:00 Dump ST BS&W 25% H20 Chlorides 10,000 PH 7 343.03 57.97 1652.53 390.99 547.05 138.49 493.33 12:15:00 347.53 61.38 1647.91 372.70 550.93 448.90 741.83 830.26 12:30:00 BS&W 26% H20 Chlorides 10,000 PH 7.0 351.03 61.41 1643.28 368.79 554.77 127.59 495.98 12:45:00 354.53 61.19 1638.53 396.58 558.90 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.9 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (psis) (de,If) (psis) (mscf/d) (mscf) (bblld) (bbl) (scf/bbl) (bpd) (bbl) 17-Mar-94 13:00:00 BS&W 20% H20 Chlorides 10,000 PH 7.0 346.53 59.78 1633.41 396.03 563.03 154.50 499.20 -- 13:15:00 350.28 58.53 1628.78 396.00 567.15 13:20:00 Stop Pumping Emulsion Breaker BS&W 10% 350.28 57.98 1627.28 369.74 568.44 13:30:00 BS&W 10% H20 Chlorides 10,000 PH 7.0 346.78 56.57 1623.78 395.74 571.28 168.95 502.72 -- 13:45:00 359.03 56.51 1618.41 402.62 575.47 14:00:00 Dump ST BS&W 17% H20 Chlorides 10,000 PH 357.28 56.17 1612.78 392.10 579.55 192.43 506.73! 14:15:00 358.78 55.50 1607.03 379.16 583.50 426.68 781.83 888.64 14:30:O0'BS&W 30% H20 Chlorides 11,000 PH 7.5 366.78 56.39 1601.41 401.78 587.69 178.07 510.44 14:45:00i 367.78 56.02 1595.91 401.09 591.87 -- 15:00:00 BS&W 16% H20 Chlorides 11,000 PH 7.5 365.53 56.32 1589.531 405.07 596.09 101.91 512.56 15:15:00 365.28 57.03 1583.28 422.62 600.49 ,, -- 15:30:00 BS&W 27% H20 Chlorides 11,000 PH 7.5 364.03 58.06' 1577.66 416.30 604.83 184.91 516.4Z 15:45:00 361.78' 58.23 1572.16 407.51 609.07 16:00:00 BS&W 30% H20 Chlorides 11,000 PH 7.5 364.28 58.45 1567.16 403.94 613.28 220.47 521.01 16:15:00 362.53 57.29 1562.91 404.97 617.50 16:30:00 BS&W 33% H20 Chlorides 11,000 PH 7.5 366.03 56.96 1557.91 409.07 621.76 165.21 524.45 16:45:00 361.03 56.91 1553.03 419.28 626.12 ___ 17:00:00 BS&W 31% H20 Chlorides 11,000 PH 7.5 357.78 56.55 1548.03 408.47 630.38 176.11 52~' 17:15:00 346.28 56.24 1543.03 405.80 634.61 17:30:00 BS&W 15% H20 Chlorides 11,000 PH 7.5 355.78 55.94 1670.03, 394.44 638.72 88.77 529.97 .... 17:45:00 354.03 55.83 1663.78 402.68 642.91 18:00:00 Dump ST BS&W 20% H20 Chlorides 11,000 PH 361.53 54.61 1657.16 402.06 647.10 190.04 533.93 --, 18:15:00 367.28 54.31 1650.78 376.11 651.02 377.88 848.74 995.33 18:30:00 BS&W 23% H20 Chlorides 11,000 PH 7.5 371.28 54.28 1644.41 390.56 655.08 243.05 538.99 -- 18:45:00 363.78 54.44 1635.66 394.99 659.20 -- 19:00:00 BS&W 15% H20 Chlorides 11,000 PH 7.5 356.53 53.60 1627.78 417.43 663.55 155.08 542.22 19:15:00 351.78 53.09 1621.16 403.00 667.75 19:30:00 BS&W 15% H20 Chlorides 14,000 PH 7.5 350.53 52.64 1713.16 404.69 671.96 173.50 545.84 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.10 Time Remarks Whp Wh! Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol -- {psis) {de,If) {psi~l) {mscfld) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 17-Mar-94 ._ 19:45:00 349.03 52.61 1712.66 395.46 676.08 -- 20:00:00 BS&W 20% H20 Chlorides 14,000 PH 7.5 349.28 52.03 1712.28= 398.65 680.23 226.50 550 =~ 20:15:00 346.28 51.91 1712.91 408.66 684.49 -- 20:30:00 BS&W 20% H20 Chlorides 10,000 PH 7.5 342.28 51.04 1712.91 401.22 688.67 194.98 554.62 20:45:00 RIH SWS w/TDT-P logging tool 341.03 49.86 1712.66 383.31 692.66 21:00:00 Dump Surge Tank BS&W 22% H20 Chlorides 10,0 344.53 50.19 1712.41 394.90 696.78 197.29 558.73 21:15:00 34.53 50.10 1712.16 378.30 700.72 435.55 907.73 868.56 21:30:00 BS&W 21% H20 Chlorides 10,000 PH 7.5 344.03 50.14 1712.53 376.94 704.64 173.31 562.34 21:45:00 346.78 49.77 1712.41 392.31 708.73 _ -- 22:00:00 BS&W 26% H20 Chlorides 10,000 PH 7.5 345.28 49.53 1712.53 381.42 712.70 186.25 566.22 22:15:00 355.53 49.69 1713.16 394.53 716.81 .. 22:30:00 BS&W 24% H20 Chlorides 10,000 PH 7.5 353.78 49.51 1713.78 403.70 721.02 159.16 569.54 22:45:00 350.28 49.46 1714.41 419.00 725.38 -- 23:00:00 BS&W 25% H20 Chlorides 10,000 PH 7.5 351.03 49.41 1715.16 417.30 729.73 153.94 572.74 23:15:00 359.03 49.70 1716.03 430.05 734.21 -- 23:30:00 BS&W 30% H20 Chlorides 10,000 PH 7.0 354.03 49.68 1716.03 417.86 738.56 180.18 576.50 .._ 23:45:00!SWS POOH w/TDT 354.53' 49.67 1717.53 414.70 742.88 18-Mar-94 00:00:00 BS&W 30% H20 Chlorides 11,000 PH 7.0 355.28 49.34 1718.78 408.75 747.14 179.52 580.,_-~ 00:15:00 357.28 49.57 1719.78 381.79 751.12 516.12 977.62 739.74 00:30:00 BS&W 26% H20 Chlorides 11,000 PH 7.0 359.78 49.36' 1720.28 397.04 755.25 164.48 583.66 00:45:00 359.78 49.32 1721.28 411.14 759.53 -- 01:00:00 BS&W 30% H20 Chlorides 11,000 PH 7.0 364.78 49.40 1722.03 435.34 764.07 190.28 587.63 01:15:00 357.03 49.65 1720.78 448.41 768.74 01:30:O0,BS&W 30% H20 Chlorides 11,000 PH 7.0 364.03 50.01 1723.41 426.49 773.18 175.78 591.29 01:45:00 ~ 368.28 49.71 1724.78 438.47 777.75 02:00:00 BS&W 30% H20 Chlorides 10,500 PH 7.0 356.03 48.64 1725.78 438.95 782.32 117.24 593.73 02:15:00 360.03 48.76 1726.91 418.87 786.69 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.1 1 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -- Total Total Rate Volume Rate Vol {psi~l) {de~f) Ipsig) (mscfld) (mscf) (bbl/d) (bbl) (scf/bbl) {bpd) (bb!) 18-M ar-94 02:30:00 BS&W 25% H20 Chlorides 10,500 PH 7.0 361.78 49.37 1727.78 441.15 791.28 149.39 596.84 02:45:00 359.53 49.12 1728.78 426.38 795.72 03:00:00 BS&W 30% H20 Chlorides 10,500 PH 7.0 368.78 49.11 1728.28 431.53 800.22 183.44 60(, -- 03:15:00 Dump Surge Tank to Frac Tank #1 @ 03:00 hrs. 368.03 49.55 1728.66 402.37 804.41 03:30:00 BS&W 30% H20 Chlorides 10,500 PH 7.0 371.03 49.20 1729.78 413.58 808.72 683.07 1077.23 605.46 183.96 604.50 __ 03:45:00 370.28 50.29 1730.91 413.96 813.03 04:00:00 BS&W 30% H20 Chlorides 10,500 PH 7.0 370.28 50.48 1732.16~ 434.25 817.55 186.231 608.38 _ -- 04:15:00 375.28 50.13 1733.03 430.71 822.04 04:30:00 BS&W 30% H20 Chlorides 10,500 PH 7.0 373.78 50.67 1733.03 433.04 826.55 186.07 612.25 -- -- -- 04:45:00 372.03 49.62 1734.03 431.75 831.05 05:00:00 Shut Well in @ LPR-N. 373.03 50.44 1734.66 436.67 835.60 184.64 616.10 _ -- 05:00:45 Monitor Surface Transducers during buildup 05:00:55 05:01:05 368.28 50.45 1743.78 05:01:15 05:01:25 __ -- 05:01:35 -- 05:01:45 05:01:55 -- 05:02:05 372.53 50.39 115.01 05:02:25 -- 05:02:45 05:03:05 373.53 50.35 = 17.65 05:03:25 -- 05:03:45 -- 05:04:05 376.28 49.42 0.00 , ,, 05:04:25 05:04:55 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.12 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -- Total Total Rate Volume Rate Vol -- (psi~l) (de,If) (psi~l) (mscfld) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 18-Mar-94 -- 05:05:25 Monitor Surface Transducers during buildup 378.78 48.79 32.75 05:05:55 382.28 48.18 23.80 - 05:06:25 ....... . 05:06:55 385.28 47.62 20.55 .......... 05:07:25 -- __ -- 05:08:05 388.53 46.88 19.57 05:08:45 ._ 05:09:25 390.78 45.98 5.35, .. 05:10:05 389.78 45.01 4.87 -- 05:10:45 05:11:05 389.78 43.87 4.82 05:11:55 390.28 42.88 4.76 -- 05:12:45 05:13:05 391.53 41.99 4.70 05:13:45 05:14:25 393.53 41.14 4.61 05:15:00 395.53 40.32 4.53 522.40 1120.76 835.89 05:16:00 397.78 39.55 4.46 05:17:00 399.78 38.86 4.35 05:18:00 399.78 38.16 4.26 05:19:00 399.03 37.47 4.15 05:20:00 398.28 36.82 4.12 05:21:00 397.78 36.24! 4.06 05:22:00 397.03 35.66~ 4.06 05:23:00 396.53 35.20 4.08 -.~ 05:24:00 395.78, 34.77 4.02 05:25:00 395.28 34.30 4.01 05:26:00 394.78 33.81 4.00 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.13 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol -- {psig) {de,If} (psig) (mscf/d) (mscf) (bblld) (bbl) (scf/bbl) (bpd) (bbl) 18-Mar-94 05:27:00 Monitor Surface Transducers during buildup 394.28 33.35 3.95 05:28:00 393.78 32.80 3.91 05~29:00 393.28 32.28 3.90 05:30:00 Rig up to run RT-91 Probe 392.53 31.88 3.82 05:31:00 392.78 31.50 3.76 -- 05:32:00 391.53 31.05 3.81 05:33:00 391.28 30.61 3.67' 05:34:00 391.03 30.29 3.73 -- -- 05:35:00 390.78 29.85 3.45 05:36:00 390.53 29.43 3.86 05:37:00 390.78 29.11 3.86 05:38:00 390.28 28.85 3.70 ----4 05:39:00 389.78 28.50 3.66 05:40:00 388.53 28.23 3.28 05:41:00 388.28 28.02 3.28 05:42:00, 387.78 27.91 3.28 -- 05:43:00 387.28 27.86 3.27 05:44:00 387.03 27.76 3.26 05:45:00 386.78 27.62 3.20 05:46:00 386.78 27.46 3.36 05:47:00 386.53 27.23 3.42 05:48:00 386.28 27.07 3.48 _ -- 05:49:00 385.78 26.90 3.45 05:50:00 385.28 26.75 3.40 05:51:00 384.78 26.63 3.25 05:52:00 384.78 26.51 3.18 05:53:00 384.78 26.35; 3.05 05:54:00; 384.53 26.19 3.08 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.14 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (psi~l) Ide~lf) (psis) (mscfld) (mscf) {bblld) (bbl) {scf/bbl) (bpd) (bbl) 18-Mar-94 05:55:00 Monitor Surface Transducers during buildup 384.28, 26.04 3.00 --. 05:56:00 384.03 25.88 2.83 05:57:00 384.28 25.75 3.43 05:58:00 383.78 25.63 3.00 05:59:00 383.78 25.49 3.03 -- 06:00:00 383.78 25.28 3.27 06:01:00 383.28 24.99 2.96 06:02:00 382.78 24.64 2.90 06:03:00 382.53 24.31 2.92 06:04:00 382.28 24.04 2.83 06:05:00 382.03 23.78 2.83 __ 06:06:00 381.53 23.62 2.50 06:07:00 382.03 23.49 2.86 -- 06:08:00 381.53 23.38 2.98 06:09:00 381.03 23.27 2.78 06:10:00 380.78 23.21 3.06 __ -- 06:1 1:00 380.53 23.18 2.88 __ -- 06:12:00 380.53 23.11 2.94 06:13:00 380.03! 23.04 2.85 06:14:00 379.78 24.65 2.81 -- 06:15:00 RIH w/RT-91 Probe 381.53 23.62 2.50 -- 06:20:00 379.28 24.94 2.67 06:25:00 377.78 23.03 2.20 06:30:00 377.78 22.39 2.83 06:35:00 377.53 22.72 2.52 -- 06:40:00 379.03 23.23 2.61 06:45:00 379.03 23.26 2.53 06:50:00 379.28 23.49 2.56 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.15 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol -- (psig) (degf) Ipsig) Imscf/d) (mscf) (bbl/d) {bbl) (scflbbl) (bpd) {bbl) 18-Mar-94 06:55:00 Monitor Surface Transducers during buildup 379.03 23.27 2.45 07:00:00 380.03 22.96 2.48 -- -- 07:05:00 379.53 22.99 2.51 .... ~ -- 07:10:00 380.78 23.14 2.50 07:11:00 Latch in w/RT-91 Probe 380.78 23.16 2.48' .__ 07:15:00 380.78 23.49 2.23 07:20:00 381.03 23.80 2.27 -- 07:25:00 381.78 23.60 2.35 -- 07:30:00 Attempting to link w/RT-91 382.28 24.01 2.40 .... 07:35:00 382.53 24.10 2.28 -- 07:40:00 383.03 23.88 2.02 -- 07:45:00 385.28 24.19 2.21 07:50:00 386.28 23.93 2.02 07:55:00 387.28 23.99 2.10 08:00:00 ;Unable to link w/RT-91. POOH 388.53 24.43 2.01 08:05:00 390.53 24.46 2.03 08:10:00 391.03 23.83 2.11 08:15:00 392.78 23.67 1.98 I -- 08:20:00 394.53 24.19 1.77 08:25:00 397.03 24.64 2.27 08:30:00 398.78 24.85 1.87 08:35:00 400.78 24.46 1.66 08:40:00 403.28 24.00 1.83 08:45:00 405.53 24.19 1.90 08:50:00 407.78 24.26 1.71 08:55:00 411.03 24.76 1.56 09:00:00 Out of Hole w/Probe 413.03 25.22 1.58 -- 09:lS:00~Rebuild Probe w/no meterin~l cartrid~le. 420.03 25.00 1.67 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.16 Time Remarks Whp Wht Casing Gas Rata Gas Vol Oil Tank Oil Tank GOR WaterMetar WaterMeter -- Total Total Rate Volume Rate Vol (psi~l) (de,If) (psig). (mscf/d) (mscf) (bbl/d) (bbl) (scf/bbl) {bpd) (bbl) 18-Mar-94 -- -- 09:30:00 Monitor Surface Transducers during buildup 425.78 25.17 1.71 , 09:45:00 430.28 24.84 1.71 10:00:00 Rig up Probe in lubricator. 435.28 25.91 1.82 ........... 1 O: 15:00 Pressure test lubricator. 692.03 27.62 1.65 -- 10:30:00 692.78 28.29 2.01 10:45:00 689.78 29.72 1.82 .............. 11:00:00 688.78 30.98. 1.71 11:15:00 687.28 31.15 1.62 11:30:00 686.78 33.37 1.62 .... 11:45:00 Attempt to RIH w/Probe. Hung up in lubricator. 685.78 34.41 1.60 12:00:00 685.28 33.86 1.46 12:15:00 685.53 39.43 1.43 12:30:00 686.28 36.58 1.30 12:45:00 686.78 35.96 1.26 13:00:00 687.28 34.35 1.26. 13:15:00 687.78 32.63 1.26 13:30:00 688.53 32.86 1.38 13:45:00 689.78 33.55 1.27 14:00:00 689.03 32.64 1.13 14:15:00 691.78 34.57 1.37 14:30:00 695.28 37.10 1.17 -- _ 14:45:00 695.78 38.90 0.92 15:00:00 Rig up Probe in Lubricator. 696.03 40.48 0.91 15:15:00 Bleed off tubing pressure. 534.53 43.84 1.00 15:30:00 Open Swab. RIH w/Probe. 205.48 49.34 1.08 15:45:00 225.88 47.45 1.02 16:00:00 254.53 44.56 1.62 16:15:00 285.28 42.87 1.37 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.17 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMater Total Total Rate Volume Rate Vol .......... (psig) (degf) , (psi~l) (mscfld) (mscf) (bbl/d) (bbl) (acf/bbl) (bpdl {bbl) 18-Mar-94 -- 16:30:00 Monitor Surface Transducers during buildup 313.03 41.72 1.21 -, , -- 16:45:00 Latch in with Probe - no link 345.78 39.84 0.95 17:00:00 'Relatch and attempt to link. 380.03 38.52 1.06 ,., 17:15:00 417.53 38.21 0.97 17:30:00 iPOOH wi Probe 451.03 38.03 0.35 17:45:00 475.28 35.67 0.27 16:00:00 492.03 34.35 0.58 16:15:00 OOH w/Probe 500.53 34.14 0.92 -- ._ 18:30:00 496.53 33.68 1.15 -- 18:45:00 493.78 33.02 1.31 19:00:00! 491.03 32.47 1.33 19:15:00 487.03 30.82 1.28 -- 19:30:00 483.03 29.50 1.31 19:45:00 481.03 29.14 1.51 20:00:00 479.78 29.13 1.50 20:15:00 478.78 28.93 1.52 20:30:00 478.03 28.75 1.53 20:45:00 476.28 27.85 1.47 21:00:00 475.03 27.12 1.58 - , 21:15:00 473.53 26.43 1.73 21:30:00 472.28 26.18 1.70 __ . 21:45:00 470.53 25.95 1.71 22:00:00 469.28 25.88 1.67 22:15:00 467.78' 25.63 1.65 22:30:00 466.78 25.49 1.77 22:45:00 466.53 25.93 1.83! ,_~ 23:00:00 465.53 25.81 1.82 23:15:00 464.78 25.77 1.85 . . , Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.18 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol {psis) (de,If) {psis) (mscfld) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) !bbl) 18-M ar-94 -- 23:30:00 Monitor Surface Transducers during buildup 463.78 25.55 1.90 23:45:00 462.03 24.65 2.00 -- 19-M ar-94 00:00:00 Monitor Surface Transducers during buildup 460.53 23.75 2.10 00:15:00 459.53 24.07 1.97 00:30:00 459.28 24.67 1.90 00:45:00 458.53 24.00 1.85 01:00:00 457.28 23.64 1.80 01:15:00 456.28 23.14 1.77 01:30:00 455.03 23.10 1.85 01:45:00 454.28 23.35 2.03 02:00:00 453.78 23.16 2.06 02:15:00 452.53 22.54 2.01 02:30:00 451.03! 22.03 2.07 -- 02:45:00 449.78 21.73 2.13 .__ 03:00:00 448.78 21.62 2.10 . 03:15:00 447.78 21.49 2.10 03:30:00 447.28 21.16 2.21 03:45:00 446.53 21.50 2.21 04:00:00 446.03 21.44 2.26 04:15:00 445.78 21.86 2.23 -- 04:30:00 444.53 21.34 2.12 04:45:00 444.03 21.69 2.05 05:00:00 443.53 21.87 2.06 05:15:00 443.28 22.29 1.98 05:30:00 442.03 21.68 1.92 05:45:00 440.78 20.93 1.80 06:00:00 439.28 20.36 2.05 Phillips Petroleum Sunfish//3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.19 ............. .'[_,[_m_e_ Remarks Whp Wht Casing ..... Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (psis) {de~f) {psis) (mscf/d) (mscf) (bbl/d) (bbl) (scf/bb!) {bpd) Ibbl) 19-Mar-94 -- 06:15:00 Monitor Surface Transducers during buildup 439.53 21.23 2.26 06:30:00, 439.78 20.82 0.00 06:45:00 439.03 20.75 0.00 07:00:00 438.03 20.94 0.00 07:15:00 437.03 20.73 0.00 07:30:00 435.28 19.94 0.00 07:45:00 434.03 19.26 0.00 08:00:00 Rig testing pumps exc. Casing xducer isolated 432.53 18.73 0.00 08:15:00 during this time. 431.03 18.40 0.00 08:30:00 432.03 19.10 928.66 -- __ 08:45:00 432.28 20.241 0.80 09:00:00 432.53 20.04 0.00 09:15:00 432.03 19.48 0.00 09:30:00 432.53 20.42 909.53 09:45:00 432.78 21.30 0.28 10:00:00 433.28 22.75 919.16 10:15:00 431.78 22.79 0.00 10:30:00 431.78 23.95 0.00 __ -- 10:45:00 431.78 25.35 274.16 11:00:00 431.28 26.87 0.22 11:15:00 431.28 27.96 593.16 . 11:30:00 430.78 26.50 0.76 -- 11:45:00 431.28 25.12 0.00 12:00:00 RU SWS bottom hole samplers 430.53 25.83 0.00 -- 12:15:00 RIH w/SWS bottomhole samplers 494.78 28.66 0.00 __.. 12:30:00 End pump test. Annulus Xducer on line. 493.28 29.44 O. 13 12:45:00 491.53 30.23 0.00 13:00:00 490.03 29.64 0.00 ,,. Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.20 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter -_. Total Total Rate Volume Rate Vol Ipsigl (de,If! (psig! {mscf/d} {mscf! (bbl/d) Ibbl! (scf/bbl) {bpdl (bbl) 19-Mar-94 13:15:00 Monitor Surface Transducers during buildup 486.78 28.35 0.00 13:30:00 483.78 29.60 0.00 13:45:00 472.78 29.92 .... 0._____00 ............................................................. , 14:00:00 467.53 29.42 0.00 14:15:00 OOH w/SWS bottomhole samplers 462.03 29.31 0.00 14:30:00 461.28 29.32 0.00 14:45:00 RIH w/SWS bottomhole samplers 461.03 31.05 0.00 15:00:00 458.03 31.26 0.00 15:15:00 460.53 30,98 0.00 15:30:00 462.03 32.13 0.00 15:45:00 463.78 31.45 0.00 16:00:00 463.53 30.17 0.00 16:15:00 461.53 29.22 0.00 16:30:00 457.78: 28.42 0.00 16:45:00 457.03 27.62 0.00 17:00:00 450.28 26.41 0.00 ., 17:15:00 452.53 25.55 0.00 17:30:00 454.28 25.36 0.00 _ -- 17:45:00 457.03 24.91 0.00 18:00:00 457.03 24.26 0,00 18:15:00 456.03 23.72 0.00 18:30:00 453.53 23.01 0.00 18:45:00 448.53 22.39 0.00 19:00:00 447.03 21.67 0.00 -- 19:15:00 445.03 20.89 0.00 19:30:00 443.53 20.56 0.00 19:45:00 442.28 19,95 0.00 -- 20:00:00 440.53 19.58 0.00 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.21 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (psig) (de,If) (psi~l) {mscfld) (mscf) (bblld) (bbl) (scf/bbl) (bpd) (b.b!) 19-M ar-94 20:15:00 Monitor Surface Transducers during buildup 438.53: 19.01 0.00 _ 20:30:00 436.78 18.30 0.00 20:45:00 435.03 18.00 0.00 21:00:00 433.78 17.79 0.00 21:15:00 432.78 17.91 0.00 21:30:00 431.78 17.76 63.10 21:45:00 430.78 17.79 50.80 22:00:00 430.28 17.55 51.02 ___ __ -- 22:15:00 428.78 17.00 46.20 22:30:00 427.53 16.94 41.10 __ -- 22:45:00 427.28 16.94 41.02 23:00:00 426.53 17.16 42.27 23:15:00 426.78 17.80 42.77 23:30:00 427.53 18.03 33.12 -- 23:45:00 427.53 18.08 32.83 20-Mar-94 -- 00:00:00 Monitor Surface Transducers during buildup 428.28 18.75 42.63 00:15:00 429.03 18.83 42.96 00:30:00 429.53 19.08 28.60 00:45:00 430.28 19.7~ 28.80 01:00:00 431.53 20.10 29.15 01:15:00 430.28 17.76 28.36 01:30:00 429.78 17.64 28.06 __ 01:45:00 429.28 16.76 29.33 02:00:00 428.03 16.00 27.55 -- 02:15:00 427.03 15.16 27.73 ___ 02:30:00 427.28. 15.70 27.80 02:45:00 427.28 15.31 27.23 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.22 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol -- (psis! (de,If} (psigl (mscfld) (mscf} {bbl/d} (bbl) (scf/bbl) {bpdl (bbll 20-Mar-94 ..... 03:00:00 IMonitor Surface Transducers during buildup 427.28 14.92 26.80 03:15:00 426.78 14.45 26.48 -- 03:30:00 426.28 13.87 26.18 03:45:00 427.03 14.71 25.85 04:00:00 427.53 14.60 26.40 ., 04:15:00 426.28 14.22 25.72 04:30:00 425.53 14.10 0.00 04:45:00 425.28 14.06 0.00 05:00:00 Rig power went down. Shut down DAS and wait 426.33 14.23 0.00 05:15:00 425.03 13.95 0.00 05:30:00 425.53 14.09 0.00 05:41:00 Pressure casing to open LPR-N 05:45:00 475.53 14.58 1720.78 05:55:00 Start Flowing Choke @ 10/64 611.28 15.38 1710.91 06:00:00 Change Choke to 24/64 620.03 22.61 1713.53 6.73 616.12 06:02:00 Fluid to surface 497.78 26.91 1712.41 06:07:00 Lower 1.375" orifice plate 204.81 31.13 1710.53 -- 06:15:00 __ 06:Z7:00 Lower 1" orifice plate 265.28 35.07 1722.28 06:30:00 Bypass Surge Tank Flow To Tank #1 281.28 35.92 1722.78 0.87 616.14 06:31:00 Gas Gravity = 0.818 287.28 36.07 1723.03 06:45:00 07:00:00 Flow To Surge Tank BS&W 0.0% All Oil 378.28 37.64 1718.91 320.93 842.06 0,00: 616.14 07:15:00 374.28 38.60 1715.16 307.28 845.26 07:30:00 Bypass Surge Tank to Tank #1 BS&W = 0.25% H2 309.28 40.09 1710.78 278.50 848.16 2.33 616.19 07:34:00 Rock Choke 290.03 40.09 1710.78 256.86 848.87 07:45:00 224.41 39.64 1715.41 205.74 850.45 08:00:00 Switch Back to Sur~le Tank BS&W = 60% H20 343.78 44.51 1722.16 375.61 854.36 429.17 625.13 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.23 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (ps!~) (de~f) (I)si~l) (mscf/d) {mscf) (bbl/d) {bbl) (scf/bb!) (bpd) {bbl), 20-Mar-94 08:15:00 406.03 44.24 1727.03 247.84 856,94; 08:30:00 BS&W 45% H20 437.03 44.38 1730.16 315.07 860.22 308.40 631 - ' 08:45:00 467.78 41,97 1733.16 399.12 864.38 09:00:00 BS&W 26% H20 458.03 41.13 1734.41 431.48 868.88 150.60 634.69 09:15:00 446.53 41.29 1735,16 421.49 873.27 09:30:00 BS&W 16% H20 428.28 41.22 1735,16 417.43 877.61 95.41 636.68 09:45:00 Gas Gravity = .828 410.78 42.24 1735.41 379.14 881.56 10:00:00 Dump Surge Tank to #2 BS&W 38% H20 447.53 45.90 1737.28 219.24 883.85 142.21 639.64 10:15:00 458.78 47.67 1736,66 317.31 887.15 10:30:00 BS&W 30% H20 460.78 47.71 1734.66 332.28 890.61 447.72 1206.27 742,14 159.67 642.97 10:45:00 474.78 48.70 1728.41 336.70 894.12 11:00:00 BS&W 30% H20 492.53 49.32 1724.28 333.60 897.60 168.34 646.48 11:15:00 503.78 49.84 1720.78 346.71 901.21 11:30:00 BS&W 27% H20 SWS RIH w/Sampling Tool 510.78 48.28 1717.03 354.39 904.90 130.28 649.19 11:45:00 514.53 49.48 1713.41 358.58 908.63 12:00:00 BS&W 27% H20 Gas Gravity = ,802 519.03' 49.52 1709.53 361.63 912.40 137.12 652.05 12:15:00 525.78 50.41 1705.28 338.76 915.93 12:30:00 BS&W 25% H20 533.78 49.09 1700.78 340.94 919.48 126.66 654 -- ,. 12:45:00 538.53 50.62 1696.16 332.02 922.94 13:00:00 BS&W 25% H20 Dump Surge Tank to #2 541.78 50.62 1691.28 365.50 926.75 125.92 657.31 13:15:00 538.78 49.77 1686.28 417.86 931.10 439.98 1261.26 949.72 13:30:00 BS&W 25% H20 535.03 50.15 1681.78 411.38 935.38 122.23 659.86~ 13:45:00 533.03 50.6~ 1677.66 330.54 938.83 14:00:00 BS&W 23% H20 529.53 50.06 1673.53 336.20 942.33i 109.61 662.14 14:15:00 532.03 50.04 1669.16 408.46 946.58 14:30:00 BS&W 25% H20 Chlorides 11,000 PH 7.0 533.28 51.79 1664.53 349.47 950.23 133.89 664.93 14:45:00 OOH w/SWS Samplers 530.53 53.64 1659.78 428.11 954.68 15:00:00 BS&W 22% H20 524.28. 52.44 1654.91 450.91 959.38 100.64 667.03 Phillips Petroleum Sunfish//3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.24 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol {psig) {degf) Ipsig) (mscfld) {mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 20-Mar-94 15:15:00 526.03 51.98 1650.03 434.68 963.91 -- 15:30:00 BS&W 20% H20 528.53 53.14 1644.78 436.221 968.45 92.26 668 15:45:00 526.78 53.63 1750.03 448.08 973.12 16:00:00 BS&W 20% H20 Chlorides 11,000 PH 7.0 526.53 52.90 1743.41 442.46 977.73 93.41 670.90 16:15:00 532.78 51.86 1736.66; 429.05 982.20 16:21:00 SWS RIH w/Sampler 82 533.78 51.17 1733.91 420.53 983.95 __ 16:30:00 BS&W 20% H20 533.28 49.93 1729.91 414.77 986.64 93.80 672.85 16:42:00 542.28 50.28 1724.53 397.37 989.95 16:45:00 Updated Program to 1.00" Orifice Size 544.03 50.63 1723.03 425.02 991.04 17:00:00 Dump Surge Tank BS&W 24% CI 11,000 Ph 7.0 550.28 49.71 1715.78 435.74 995.57 113.56 675.22 17:15:00 554.28 50.09 1708.78 473.19 1000.50 327.49 1319.26 1444.90 17:30:00 BS&W 28% H20 Chlorides 7,000 PH 7.0 557.28 48.55 1701.03 482.42 1005.53 132.66 677.98 17:45:00 Gas Meter Run Sensor Lines Freezing off. 558.03 47.57 1693.16 522.52 1010.97 18:00:00 BS&W 24% H20 Chlorides 7,000 PH 7.0 546.28 48.25 1685.66 549.42 1016.69 112.96 680.33 18:15:00 540.03 47.90 1678.53 549.65 1022.42 18:30:00 BS&W 25% H20 Chlorides 7,000 PH 7.0 536.53 49.34 1672.16 604.30 1028.71 115.41 682.74 18:45:00 531.78 50.08 1665.16 666.64 1035.66 -- 19:00:00 BS&W25% H20 Chlorides 6,000 PH 7.0 529.53 49.26 1657.78 714.42 1043.10 115.54 685 19:15:00 526.28 48.57 1650.53 684.82 1050.23 19:30:00 BS&W 22% H20 522.28 48.48 1644.41 666.28 1057.17 97.54 687.18 19:45:00 528.28 47.42 1638.16 618.44 1063.62 20:00:00 BS&W 23% H20 Chlorides 6,000 PH 7.0 532.28 47.23 1631.53 988.40 1073.91 103.30 689.33 ._ 20:15:00 532.28 47.65 1624.53 148.66 1075.46 481.12 1384.41 308.99 20:30:00 BS&W 24% Chlorides 8,000 PH 7.0 531.53 47.75 1617.53 285.04 1078.43 106.33 691.54 20:45:00 Remove orifice plate. Gas meter out of service 525.28 47.40 1610.41 20:55:00 Liquid Turbines out of service 526.53 47.30 1605.66 112.5.4. 693.50 21:00:00 Shut in @ Choke Manifold 526.28 47.45 1603.41 21:15:00 Blow Down Separator 768.03 39.46 1600.53 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.25 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol {psi~l) {de,If) {psig) {ms.cf/d) (mscf) {bbl/d) Ibbl) (scf/bbl) {bpd) {bbl) 20-Mar-94 -- 21:30:00 Rig Down SWS and Rig up Wireline 1122.28 34.90 1593.78 588.25 1421.17 21:45:00 1609.78 31.59 1582.16 22:00:00 1899.03 28.65 1561.28 -- 22:15:00 1947.53 26.68 1536.41 22:30:00 1980.03 23.36 1745.53 -- 22:45:00 1980.03 23.36: 1745.53 23:00:00 1985.78 20.41 1722.16 -- 23:15:00 1992.28 18.88 1701.41 23:30:00 1999.78 21.90 1681.66 23:45:00 2000.78 19.93 1662.91 21-Mar-94 00:00:00 Continue to rig up wireline 1995.78 18.11 1644.91 -._ 00:15:00 1991.03 18.33 1628.03 00:30:00 1988.28 19.23 1611.78 00:45:00 1990.03 19.89 1596.28 01:00:00 RIH w/gauge ring on Wireline 1934.78 20.92 1810.66 01:15:00 2024.03 19.64 1796.41 -- 01:30:00 2038.03 19.63 1780.66 -- 01:45:00 2020.78 19.79 1765.41 -- 02:00:00 2003.03 19.82 1751.16 02:15:00 OOH w/Wireline 2002.53 19.17 1737.28 02:30:00 2000.03 20.23 1723.78 02:45:00 1980.03 22.27 1710.03 ____ 03:00:00 1982.03 23.62 1696.78 -- 03:15:00 1989.28 24.38 1799.28 03:30:00 1990.78 23.87 1784.78 03:45:00 GIH w/XN lock & PXX plug to isolate below pkr 1986.28 23.20 1768.53 -- 04:00:00 1991.03 22.83 1757.66 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.7.26 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol {psi~l) {de~f) {psig) {mscf, ld) {mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 21-Mar-94 04:15:00 Continue wireline operations 1988.03 22.47 1744.03 04:3.0.:00 1984.53 22,81 1730.16 _ 04:45:00 1990.78 23.92 1716.78 05:00:00 1995.28 23.98 1703.41 ........ . 05:15:00 1996.03 23,73 1690.28 05:30:00 1998.53 23.94 1677.53 -- 05:45:00 2000.03 24.31 1664.91 06:00:00 1997.03 22.82 1652.41 06:15:00 2026.28 24.38 1746.28 06:30:00 2046.03 24.76 1732.91 06:45:00 2047.53 24.71 1720.16 -- 07:00:00 2047.78 24.74 1707.41 07:15:00 POOH w/Setting tool 2044.281 24.44 1694.53 -- 07:30:00 2032.28 22.82 1788.16 .__ 07:45:00 OOH w/Setting tool 2027.28 22.16 1766.03 08:00:00 2011.53 21.78 1744.16 -- 08:15:00 2020.53 22.78 1722.28 08:30:00 2027.28 23.42 1699.28 08:45:00 2012.03 24.75 1676.41 09:00:00 2010.28 25.75 1654.03 09:15:00 2026.78 26.25 1630.78 09:30:00 1866.28 26.69 1607.91 09:45:00 2038.28 28.33 1715.91 · , 10:00:00 2068.78 29.38 1691.41 10:15:00 2060.28 30.92 1666.66 10:30:00 2060.78 32.45 1791.91 10:45:00 2026.53 35.47 1772.16 11:00:00 2017.53 37.77 1759.66 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.27 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter Total Total Rate Volume Rate Vol (psig) {de,If) (psis) (mscfld) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 21-Mar-94 11:15:00 Continue wireline operations 1442.53 37.23 1740.53 . 11:30:00 2030.53 40.49 1721.78 11:45:00 2073.28 43.71 1709.66 -- 12:00:00 2073.53 42.72 1696.91 12:15:00 2008.53 40.39 1683.78 12:30:00 Wireline OOH Close Swab 1919.53 42.57 1670.16 12:45:00 1925.28 42.35 1657.41 13:00:00 Open Choke on 10/64 To test downhole plug 1911.78 41.50 1645.16 13:15:00 570.28 50.70 1601.16 13:30:00 425.28 51.61 1582.91 ___ 13:45:00 289.03 53.61 1565.41 14:00:00 214.68 53.23 1550.28 14:15:00 142.71 52.59 1535.53 14:30:00 89.13 50.74 1521.91 14:46:00 Close Master Bleed Off to Rig Down Lubricator 42.23 50.95 1508.03 14:48:00 Switch to Tank #1 9.06 50.44 1506.41 -- 15:00:00 Open Master 0.00 47.40 1497.53 -- 15:15:00 Close Master 57.33 49.33 1485.41 15:30:00 Open Master 0.00 47.83 1473.53 15:45:00 Shut in choke and cycle the OMNI 31.61 53.18 1460.03 16:00:00 57.36 52.32 1042.03 16:15:00 Open on a 24/64ths choke and start reverse out : 146.26 51.71 0.00 16:30:00 Begining Surge Tank 34 bbl Tank//1 = 8"(13.33 b 316.78 52.96 284.78 -- 16:48:00 Bypass Surge Tank Flow to #1 22.83 56.99 201.16 17:00:001 22.66 57.64 191.91 -- 17:15:00 23.11 56.68 191.66 17:30:00 20.66 56.17 190.91 17:45:00 18.58 52.51. 185.28 Phillips Petroleum Sunfish #3 DST #1 HALLIBURTON ENERGY SERVICES Well Test Summary' Page No. 1.7.28 Time Remarks Whp Wht Casing Gas Rate Gas Vol Oil Tank Oil Tank GOR WaterMeter WaterMeter ,, Total Total Rate Volume Rate Vol (psig) (de,If) (psig) (mscf/d) (mscf) (bbl/d) (bbl) (scf/bbl) (bpd) (bbl) 21-Mar-94 .. 18:00:00 Continue reverse out operations 416.53 .4.9.53 412.28 .................... 18:15:00 18:30:00 Complete reverse out Rig Down Tree End of Test 18:45:00 19:00:001 .... -- 19:15:00 19:30:00 -- 19:45:00 20:00:00 Reverse Out To Tanks 20:15:00 Tank #1 Begin Strap -- 13.33 bbl 20:30:00 Surge Tank Begin Strap -- 34 bbl 20:45:00 21:00:00 Tank #1 End Strap -- 258.34 bbl -- Surge Tank End Strap o- 34 bbl ...... Total Fluid Reversed -- 245.01 bbl Phillips Petroleum Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Separator Sample Data HES Represenative: Jim Mills Phillips Petroleum Rep: Hurst / Bergren Date: 17-March-94 ,,, Label 3 gallon HP 3 gallon HP 3 gallon HP _ 3 gallon HP 3 gallon HP _ Cyl. Serial Number 725881E 725861E 725879F 5973420 725830 -- Time 9:40 9:50 10:01 10:08 10:18 -- ...... Fluid Type Gas _ Gas Gas Gas Gas 10% Removed on Lig. NO NO .,__NO NO _ _ NO Pressure and Temperatures __ _ _ _ Reservoir psig D.F psig D.F psig , D.F psig D.F _, psig ,_ D.F Bottom Hole psig D.F psig D.F psig _ D.F .... psig D.F psig .... D.F Wellhead 337 psig 53 D.F 334 psig 54 D.F 341 psig 54._ D.F_ 333 psig 54 D.F 333 psig 5.6 D.F Primary Separator 135 psig 86 D.F 136 psig 86 D.F 136 psig 86 D.F 137 psig 87 D.F 138 psig 86 D.F Sec. Separator paig D.F psig D.F psig D.F psig D.F psig D.F Stock Tank psig D.F psig D.F psig D.F psig D.F psig ___ D.F -- Fluid Rates{ or Stock Tank OiI(STB/D) 345 345 345 345 345 Pr. Sep Gas(MCF/D 0.394 0.394 0.394 0.394 0.394 GOR(scf pr. sep gas/STB 0.876 0.876 0.876 0.876 0.876 -- __ APl Gravity of Oil 42.2 42.2 42.2 42.2 42.2 Gas Gravity 0.792 0.792 0.792 0.792 0.792 -- Gas Gravity Used to Calibrate Primary Separator Gas Meter OR Fg -- Gas Z-Factor Used to Calibrate Primary Separator Gas Meter OR Fpv -- Send To: ARCO Expl. Production Technology Attn: Russ Bone, PRC-E 1115 2300 West Piano Parkway Piano, TX 75075 Sent via: Airbill No. Page No. 1.8.1 Phillips Petroleum Company Sunfish No. 3 Drill Stem Test No. 1 Halliburton Energy Services Separator Sample Data HES Represenative: Jim Mills Phillips Petroleum Rep- Hurst / Bergren Date' 17-March-94 Label 3 gallon HP ...... 3 ~lallon HP 3 gallon HP .... 3 gallon HP 3 gallon HP Cyl. Serial Number 725827F 725822E 597388D 725878E 597371D _ Time 10:27 10:36 10:40 10:45 10:50 Fluid Type Gas Gas Gas Gas Gas _ 10% Removed on Li~l. NO ___NO NO ........ NO NO Pressure and Temperatures ..... ..... Reservoir psig _ __ D.F psig D.F psig D.F psig__ D.F psi</ D._F_ Bottom Hole psi~l D.F ._ psig __ D.F __ psig ............... D:F ............... ~ .... D..,F ....... s_p__~9__ D.F Wellhead 338 psi~l 56 D.F 338 psig 57 D.F 335 psig 57 D.F 339 psig 56 D.F 340___psig 55 D.F .... Primary Separator 137 psi~l 86 D.F 138 psi~l 87 D.F 137 psi~l 87 D.F 136 psi~l 87 D.F 137 psi~l_ 87 D.F_ Sec. Separator psig D.F psig D.F psig __ D.F psi~l D.F psig D.F Stock Tank psig D.F psig D.F psig D.F _ psig D.F psig D.F Fluid Rates{ or GOR} Stock Tank OiI{STB/D) 345 345 345 345 345 Pr. Sap Gas(MCF/D 0.394 0.394 0.394 0.394 0.394 GQ_R(scf pr. sap 9as/STB 0.876 __ 0.876 0.876 0.876 0.876 __ __ APl Gravity of Oil 42.2 42.2 42.2 42.2 42.2 Gas Gravity 0.792 0.792 0.792 0.792 0.792 Gas Gravity Used to Calibrate Primary Separator Gas Meter OR Fg Gas Z-Factor Used to Calibrate Primary Separator Gas Meter OR Fpv _ -- Send To: ARCO Expl. Production Technology Attn: Russ Bone, PRC-E 1115 2300 West Piano Parkway Piano, TX 75075 Sent via: Airbill No. Page No. 1.8.2 Phillips Petroleum Company Sunfish No. 3 Drill Stem Test No. I Halliburton Energy Services Separator Sample Data HES Represenative: Jim Mills Phillips Petroleum Rep' Hurst / Bergren Date: 17-March-94 Label , 3 gallon HP 3 gallon HP I Liter HP I Liter HP I Liter HP CyI. Serial Number 725829E 725828E I OFK080 920590C 824585C Time 10:58 11:03 14:47 14:52 15:05 Fluid Type __Gas Gas Oil Oil Oil .... 10% Removed on Lig. NO NO Yes ....... Yes Yes Pressure and Temperatures _ __ Reservoir psig D.F psig D.F psig D.F _psig D,F _Bsig D.F Bottom Hole p~ig D.F psig D.F psig D,F psi~l D.F psig ..... D.F Wellhead 344 psig 56 D.F 346 psig 57 D.F 369 psig 56 D.F 367 psig 56 D.F 369 psig .57_ D.F ,,_ Pr!mary Separator 137 psig 87 D.F 139 psig 87 D.F 149 psig 95 D.F 149 psig 95 D~F _ 150 psig 96 D.F Sec. Separator psig D.F psig D.F psig D.F psig D.F psig D.F Stock Tank psig D.F psig D.F psig D.F psig __ D.F psig D.F -- ,Fluid ,Rates{ or GOR} Stock Tank OiI(STB/D) 345 345 432 432 432 -- Pr. Sep Gas(MCF/D 0.394 0.394: 0.408 _ 0.408 0.408 GOR(scf pr. sep gas/STB 0.876 0.876 1.059 1.059 1.059 ......... -- APl Gravity of Oil _ 42.2 42.2 42.2 ..................... 42.2 .............. ~42-_2 Gas Gravity 0.792 0.792 0.792 0.792 0.792 Gas Gravity Used to Calibrate Primary Separator Gas Meter OR Fg Gas Z-Factor Used to Calibrate Primary Separator Gas Meter OR Fpv Send To: ARCO Expl. Production Technology Attn: Russ Bone, PRC-E 1115 2300 West Piano Parkway Piano, TX 75075 Sent via: Airbill No. Page No. 1.8.3 Phillips Petroleum Company Sunfish No. 3 Drill Stem Test No. 1 Halliburton Energy Services Separator Sample Data HES Represenative: Jim Mills Phillips Petroleum Rep: Hurst / Bergren Date: 17-March-94 Label I Liter HP 10 Gallon Anaarobic 10 Gallon Anaarobic 10 Gallon Anaarobic 10 Gallon Anaarobic _ Cyl. Serial Number 874595C K21676 K21676 K21631 K21638 Fluid Type Oil Oil Oil Oil Oil 10% Removed on Lig. Yes 20% Removed 20% Removed _ 20% Removed 20% Removed __ .__ Pressure and Temperatures., __ Reservoir psi~l D.F psi~l D.F psi~l D.F psi~l ,D.F psi~l __ D.F Bottom Hole psig D.F psig D.F psig _ D.F psig __._ D.F psig D.F_ Wellhead 365 psig 57 D.F 364 psi~l 58 D.F 360 psig 58 D.F 367 psig 59 D.F 364 ps!9 58 D.F Primary Separator 152 psig 96 D.F 150 psig 96 D.F 152 psig 96 D.F 151 psig 96 D.F 151 psig 96 D.F__ Sec. Separator psig D.F psig D.F psig D.F psig D.F psig _ D.F Stock Tank psi~l D.F psi~l D.F psi~l ~D.F._ psig D.F psig D.F Fluid Rates{ or GOR} Stock Tank OiI(STB/D) 432 432 432 432 432 Pr. Sep Gas(MCF/D 0.408 _ 0.408 0.408 0.408 0.408 GOR(scf pr. sep ~Ias/STB 1.059; 1.059 1.059 1.059 1.059 -- APl Gravity of Oil 42.2 42.2 42.2 42.2 42.2 Gas Gravity 0.792 0.792 0.792 0.792 0.792 Gas Gravity Used to Calibrate Primary Separator Gas Meter OR Fg Gas Z-Factor Used to Calibrate Primary Separator Gas Meter OR Fpv Send To: ARCO Expl. Production Technology Attn: Russ Bone, PRC-E 1115 2300 West Piano Parkway Piano, TX 75075 Sent via: Airbill No. Page No. 1.8.4 Date: 13-Mar-94 Ticket No: 462909 Note: RESERVOIR PARAMETERS USING SEMI-LOG METHOD FOR LIQUID WELLS Oil Gravity: Gas Gravity: Gas/Oil Ratio: Well Bore Radius: Net Pay: Porosity: Water Salinity: Fluid Properties Reference: Formation Temperature: Viscosity: Formation Volume Factor: Total System Compressibility: Bubble Point: 42.2 APl @ 60 F 0.810 SG 890.0 ScF/STB 0.3542 fi 28.00 ft 20.00 % 1.10 % SALT 6280.0 psi 198.000 F 0.460 cp 1.457 Rvol/Svol 7.867 x 10^-6 vol/vol/psi 2973.10 psi Gauge number: Gauge Depth (ft): Test Period: Period Type: X-axis Function: Y-axis Function: Period Start Press. (psi): Y Intercept (#1 Units): Pressure Intercept (psi): Slope (#2 Units): Sy (#1 Units): 10781 13457.00 5 Build-up xj Pressure 3740.08 6275.708 6275.708 149.540 0.390 Production Rate (bbl/D): Flow Capacity (md-fi): Permeability (md): Skin Factor: Delta P due to Skin (psi): Damage Ratio: Flow Efficiency: Theoretical Rate (bbl/D): Rad. of Investigation (ft): at Transient Time ( hr): 549.3 400.57 14.31 11.828 1536.371 2.544 0.393 1397.3 457.31 10.31 #1 Units = psi for Pressure Y-axis function. #1 Units = psi/bbl/D for dp/dq Y-axis function. #2 Units = psi/cy for Pressure Y-axis function. #2 Units = psi/cy/bbl/D for dp/dq Y-axis function. Page No: 2.1.1 SEMI-LO0 PLOT 6.5 6.0 X 4.0 3.5 m m - = Yet I - 6275.7 psi kh = 400.6 rrkt-ft - k = 14.306 md - Skin = 11.83 I ,,[, m I i i ill ~~ i 10 o 10 ~ I I I I I I I ~- I ! 10~ Gouge No: 10781 - Period No: 5 - Well: Co .mpq.~: Phillips - Anul~s~: Mills - Transient Time: 105.97 hr _ Superposition Time HRS _ I I I I L I I DERIVATIVE LOG-LOG PLOT 10 4 o 102 ..... t' ' 1 --I r~ I 'T'I i i i i i i il I I I I [ I'1'" ..... i ' i --T--I' I"l [' Test No: One - Gauge No: 10781 Period No: 5 - Well: Company: Phillips Analyst:. Mills Trans, ient, Ti,me[ ,,1o,.~.89 hr 10 -3 10 -2 ! i I I I I ~0 -~ ]0o t i i I I I I ! l ! I I i Equivalent Time HRS X 6.5 6.0 5.5 5.0 4.5 4.0 3.5 Pressure V$ Del(a Time - [ - ' Test No: One - ~- I ~uge No: 10781 ' I Peribd No: 5 -2.0 ,3.8 9.6 15.,321.1 38.4 44.2 Delto Time 26.9 32.7 (hours) HRS 50,0 Pressure Vs Delta 'T[ine 5.9 5.5 X 3.9 3.5 '' T~st' NIo:' tine'' I ' ' ' ' ~auge No: 10781 - h'eriod No: 1 Well: #5 - Company: Phillips Analyst: Mills - /,, ! / / / / ..- / / ..' / Oo 0.0 0.5 1.0 1.5 3.5 4.0 4.5 --t 2.0 2.5 5.0 Delta Time (hours) HRS Pressure Vs Delta Time x 4.7~ 4.5( 4.21 4.0! G~u,~, No:10781 Peri~l ~1~: 2 Well: t~ . ~~ Phd~a ~ Angst:' ~b ~ .. 0.00 0.67 1.53 2.00 4.67 5.55 2.67 Delt~ Time 3.33 4.00 (hours) HRS 6.00 Pressure Vs Delta Time x 4.41 4,21 3.9~ 3.7' Gauge No: 10781 - Period No: 3 - Well:#3 _ Co .ropany: Phillips Analyst: Mills - 0.00 0.67 1.33 2.00 4-.67 5.33 2,67 5.55 ~-.00 Delta Time (hours) HRS 6.00 Pressure Vs Delta Time X 3.8~ 3.81 3.7~ 3.7: 3.6i 3.6( 3.51 ~0 _,iii, l lll ii i'll l'l'l ilI iii iii Ii"/"I ii'l il'il I iI ii i'i'i'l'l l'i"i'llli Iii lest N~: n - Gauge No: 10781 PeriF:~l t~l~: 4 Well: Compony: Phillips Anol~sfi Mill~ Delto 20 25 30 Time (hours) HRS Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 3.1 Gauge No. 10781 Gauge Depth 13457' MD 12000 10000 8000 6000 4000 Test Tubing Fir Guns / Shear RD Fowl Exten Buildup W/L 240 20O 16O 120 80 2000 40 0 3/13 0:00 3/15 0:00 3/17 0:00 3/19 0:00 3/21 0:00 0 3/23 0:00 Plot Start Time: 13-Mar-94 00:00:00 Plot End Time: 23-Mar-94 00:00:00 Date: 13-Mar-94 Ticket No: 462909 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Page No: 3.1.1 Gauge Depth: 13457.00 ft COMMENTS 14 15 -Mar-94 20:02:04 21:02:10 22:06:10 23:06:10 23:30:10 23:38:10 -Mar-94 00:10:10 00:30:10 00:46:10 01:06:10 01:22:10 01:38:10 01:50:10 02:02:15 02:16:25 02:27:45 02:39:35 02:52:05 02:56:45 02:57:05 02:57:15 02:57:25 02:57:35 02:57:45 02:58:05 02:58:25 02:58:35 02:58:55 02:59:05 02:59:15 02:59:45 03:00:05 03:13:45 03:14:05 03:14:15 03:14:25 03:14:35 03:14:45 03:14:55 03:15:05 03:15:15 03:15:35 03:36:45 03:50:35 04:03:55 Data Print Frequency: 20.780 70.171 14.611 43.648 37.814 59.370 115.128 49.716 5029.563 60.474 153.002 59.589 402.513 76.260 653.907 80.505 857.440 82.838 1130.742 85.591 1367.637 89.962 1622.025 95.026 1841.803 100.751 2062.323 101.362 2279.070 109.459 2479.529 114.803 2695.123 119.889 2895.131 124.402 3313.937 125.361 3809.735 125.499 4056.510 125.552 4302.452 125.604 4551.368 125.657 4802.674 125.709 5295.787 125.780 5785.375 125.850 6034.888 125.864 6526.126 125.891 6767.773 125.905 7004.385 125.919 7307.811 125.838 7696.132 125.839 7031.168 125.192 5754.640 124.839 5217.435 124.733 4730.804 124.627 4315.678 124.584 3950.608 124.540 3636.713 124.546 3388.738 124.552 3187.432 124.558 2947.978 124.648 3150.011 129.979 3362.976 134.708 3573.676 139.765 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.2 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 15-Mar-94 Data Print Frequency: 04:16:25 3789.110 145.096 04:30:55 3996.316 150.954 04:42:55 4205.015 156.376 04:54:55 4413.195 161.703 05:07:45 4618.890 167.176 05:18:15 4819.630 172.521 05:30:55 5024.541 178.885 05:42:15 5226.574 182.982 05:59:55 5457.338 187.795 06:00:25 5820.074 187.868 06:00:45 6087.361 187.932 06:01:05 6356.473 187.963 06:01:25 6624.892 187.994 06:01:45 6894.295 188.025 06:02:05 7156.781 188.056 06:02:25 7430.750 188.087 06:02:45 7694.074 188.118 06:03:05 7963.117 188.149 06:03:25 8224.383 188.180 06:03:45 8478.664 188.211 06:04:05 8758.049 188.225 06:04:25 9020.563 188.240 06:04:45 9267.692 188.254 06:05:05 9490.073 188.268 06:05:35 9863.587 188.289 06:05:55 10088.732 188.303 06:06:25 10338.591 188.324 06:24:35 9387.079 187.937 06:24:55 8690.183 187.771 06:25:15 8052.335 187.694 06:25:35 7493.868 187.618 06:25:45 7239.728 187.579 06:25:55 7005.026 187.541 06:26:05 6784.288 187.538 06:26:15 6582.661 187.535 06:26:35 6229.278 187.529 06:26:55 5938.068 187.537 06:27:15 5711.744 187.560 06:27:45 5485.605 187.593 07:28:05 5393.518 188.236 08:28:55 5391.987 188.305 09:29:35 5386.427 188.297 10:30:05 5386.697 188.323 11:30:15 5387.969 188.349 12:30:25 5389.596 188.367 13:30:25 5391.424 188.384 Date: 13-Mar-94 Ticket No: 462909 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 15-Mar-94 Data Print Frequency: 14:31:15 5393.448 188.405 15:31:15 5395.711 188.422 16:31:35 5388.009 188.638 17:31:55 5400.401 188.597 18:31:55 5391.668 188.451 18:49:15 5896.658 188.688 18:49:25 6123.178 188.708 19:04:25 6331.123 188.899 19:06:35 6548.601 188.908 19:08:35 6757.604 188.908 19:10:35 6971.352 188.916 19:12:25 7171.453 188.924 19:14:25 7394.779 188.931 19:16:25 7623.430 188.938 19:18:15 7829.911 188.943 19:19:55 8036.425 188.946 19:21:35 8251.334 188.949 19:23:15 8475.057 188.951 19:24:55 8705.142 188.954 19:26:35 8942.479 188.957 19:28:05 8675.986 188.917 19:28:25 8325.001 188.831 19:28:45 8010.418 188.746 19:29:05 7727.872 188.694 19:29:25 7471.178 188.673 19:29:45 7236.542 188.653 19:30:05 7018.608 188.633 19:30:25 6817.121 188.613 19:30:55 6539.799 188.589 19:31:35 6161.104 188.563 19:32:15 5800.328 188.537 19:32:55 5486.407 188.531 19:33:35 5209.734 188.526 19:43:05 4922.329 188.589 Page No: 3.1.3 Gauge Depth: COMMENTS 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.4 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 15-Mar-94 Data Print Frequency: 1 *** Start of Period 1 *** 19:43:15 0.0000 5129.056 188.588 19:48:35 0.0889 5024.163 188.555 19:50:15 0.1167 4920.391 188.615 19:52:15 0.1500 4806.981 188.677 19:54:15 0.1833 4703.894 188.738 19:56:45 0.2250 4590.214 188.817 19:59:25 0.2694 4483.025 188.955 20:02:25 0.3194 4377.538 189.421 20:05:45 0.3750 4275.812 190.504 20:09:45 0.4417 4168.305 191.938 20:14:25 0.5194 4064.349 193.533 20:20:55 0.6278 3960.970 194.940 20:31:'25 0.8028 3859.798 195.544 20:41:45 0.9750 3833.188 195.744 20:52:15 1.1500 3859.471 195.745 21:02:15 1.3167 3965.349 195.653 21:06:15 1.3833 4065.487 195.614 21:10:25 1.4528 4167.759 195.577 21:14:35 1.5222 4269.114 195.550 21:18:55 1.5944 4376.100 195.525 21:23:05 1.6639 4477.777 195.484 21:27:15 1.7333 4578.911 195.422 21:35:25 1.8694 4472.463 195.282 21:42:15 1.9833 4370.760 195.142 21:52:45 2.1583 4441.269 195.014 21:59:55 2.2778 4547.279 194.942 22:07:25 2.4028 4653.525 194.895 22:11:25 2.4694 4754.534 194.874 22:13:05 2.4972 4867.369 194.866 22:17:35 2.5722 4969.686 194.828 22:25:15 2.7000 4869.075 194.727 22:27:05 2.7306 4767.159 194.686 22:29:05 2.7639 4664.721 194.643 22:35:45 2.8750 4765.685 194.549 22:38:35 2.9222 4868.444 194.524 22:40:35 2.9556 4974.089 194.523 22:43:05 2.9972 5085.507 194.510 22:53:15 3.1667 5140.972 194.406 22:54:05 3.1806 4989.051 194.362 22:54:55 3.1944 4855.234 194.321 22:55:55 3.2111 4752.016 194.306 22:57:35 3.2389 4642.742 194.280 22:59:55 3.2778 4540.714 194.245 23:03:45 3.3417 4440.522 194.184 23:11:55 3.4778 4340.125 194.093 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.5 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 15-Mar-94 23:22:35 3.6556 23:31:05 3.7972 23:32:05 3.8139 Data Print Frequency: 1 4281.798 194.064 4214.489 194.145 4215.453 194.177 *** End of Period 1 *** Date: 13-Mar-94 Ticket No: 462909 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) 15-Mar-94 23:42:45 0.1778 23:53:35 0.3583 16-Mar-94 00:04:05 0.5333 00:14:55 0.7139 00:24:55 0.8806 00:35:15 1.0528 00:45:55 1.2306 00:56:15 1.4028 01:06:15 1.5694 01:08:55 1.6139 01:11:55 1.6639 01:16:15 1.7361 01:22:45 1.8444 01:33:05 2.0167 01:40:05 2.1333 01:45:25 2.2222 01:50:25 2.3056 01:57:15 2.4194 02:07:45 2.5944 02:17:45 2.7611 02:28:15 2.9361 02:38:15 3.1028 02:48:45 3.2778 02:59:35 3.4583 03:10:35 3.6417 03:20:35 3.8083 03:31:35 3.9917 03:42:25 4.1722 03:53:25 4.3556 04:04:25 4.5389 04:15:15 4.7194 04:26:15 4.9028 04:37:15 5.0861 04:47:35 5.2583 04:48:35 5.2750 04:48:55 5.2806 Data Print Frequency: *** Start of Period 2 4237.944 194.481 4248.970 194.704 4281.583 194.852 4290.207 194.942 4334.575 194.978 4420.252 195.001 4520.897 195.025 4593.100 195.048 4598.809 194.974 4487.145 194.942 4383.326 194.902 4280.938 194.855 4177.636 194.794 4096.814 194.760 4197.453 194.868 4298.093 194.961 4404.482 195.045 4302.844 195.116 4227.901 195.128 4196.734 195.139 4187.155 195.151 4213.359 195.210 4262.409 195.272 4309.259 195.281 4334.776 195.286 4351.032 195.290 4361.691 195.295 4367.844 195.292 4376.316 195.279 4381.726 195.266 4384.662 195.266 4387.044 195.267 4387.886 195.268 4388.911 195.267 4378.673 195.266 4375.966 195.266 *** End of Period 2 1 Page No: 3.1.6 Gauge Depth: 13457.00 ft COMMENTS Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.7 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 16 -Mar-94 04:55:55 05:06:15 05:16:25 05:26:35 05:37:05 05:46:05 05:56:35 06:07:35 06:17:45 06:28:45 06:39:05 06:49:05 06:59:'45 07:10:45 07:21:35 07:32:35 07:43:35 07:53:55 08:04:25 08:14:55 08:25:05 08:36:05 08:47:05 08:57:05 09:07:55 09:18:45 09:29:35 09:40:15 09:50:45 10:01:45 10:12:15 10:22:25 10:32:35 10:42:55 10:53:35 11:04:25 11:14:45 11:24:55 11:35:15 11:46:15 11:56:35 12:07:25 12:18:25 12:29:25 12:39:35 0.1167 0.2889 0.4583 0.6278 0.8028 0.9528 1.1278 1.3111 1.4806 1.6639 1.8361 2.0028 2.1806 2.3639 2.5444 2.7278 2.9111 3.0833 3.2583 3.4333 3.6028 3.7861 3.9694 4.1361 4.3167 4.4972 4.6778 4.8556 5.0306 5.2139 5.3889 5.5583 5.7278 5.9000 6.0778 6.2583 6.4306 6.6000 6.7722 6.9556 7.1278 7.3083 7.4917 7.6750 7.8444 Data Print Frequency: 1 *** Start of Period 3 *** 4273.406 195.250 4168.517 195.232 4101.933 195.267 4051.025 195.353 4016.601 195.457 3916.295 195.550 3842.356 195.664 3804.988 195.810 3787.266 195.957 3784.429 196.100 3787.568 196.210 3792.375 196.287 3807.442 196.335 3819.325 196.383 3835.992 196.429 3851.639 196.476 3861.219 196.524 3869.454 196.551 3876.062 196.574 3876.589 196.595 3876.096 196.587 3876.381 196.615 3878.319 196.643 3881.686 196.669 3835.122 196.652 3814.229 196.627 3804.384 196.642 3800.300 196.690 3801.802 196.736 3807.987 196.785 3814.499 196.831 3829.057 196.870 3867.188 196.886 3788.063 196.902 3718.427 196.906 3676.607 196.957 3647.965 197.022 3630.283 197.103 3619.724 197.170 3613.813 197.241 3610.492 197.307 3601.801 197.366 3594.405 197.419 3588.746 197.468 3584.763 197.499 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.8 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 16-Mar-94 Data Print Frequency: 12:50:35 8.0278 3588.302 197.549 13:00:45 8.1972 3588.346 197.581 13:11:05 8.3694 3594.609 197.610 13:21:05 8.5361 3597.729 197.640 13:32:05 8.7194 3602.473 197.672 13:42:15 8.8889 3600.479 197.698 13:52:45 9.0639 3609.618 197.717 14:03:45 9.2472 3620.540 197.736 14:13:45 9.4139 3625.520 197.752 14:24:45 9.5972 3627.591 197.771 14:35:35 9.7778 3631.384 197.789 14:46:35 9.9611 3631.809 197.804 14:57:05 10.1361 3633.315 197.818 15:08:05 10.3194 3628.556 197.832 15:19:05 10.5028 3624.964 197.846 15:29:55 10.6833 3633.901 197.876 15:40:15 10.8556 3637.355 197.891 15:51:15 11.0389 3637.058 197.902 16:01:35 11.2111 3643.897 197.911 16:12:25 11.3917 3648.254 197.917 16:22:25 11.5583 3651.951 197.922 16:32:35 11.7278 3658.425 197.927 16:42:35 11.8944 3663.302 197.932 16:53:35 12.0778 3673.563 197.939 17:04:35 12.2611 3685.010 197.945 17:15:35 12.4444 3695.193 197.951 17:26:35 12.6278 3705.694 197.958 17:37:15 12.8056 3714.448 197.959 17:48:15 12.9889 3723.152 197.958 17:59:15 13.1722 3730.425 197.957 18:10:15 13.3556 3738.130 197.956 18:20:15 13.5222 3751.214 197.954 18:30:35 13.6944 3806.748 197.953 18:41:15 13.8722 3777.442 197.930 18:51:45 14.0472 3743.295 197.917 19:02:45 14.2306 3723.764 197.919 19:13:45 14.4139 3709.707 197.920 19:24:05 14.5861 3701.274 197.945 19:34:15 14.7556 3689.598 197.968 19:44:15 14.9222 3685.227 197.986 19:55:15 15.1056 3699.042 198.007 20:06:15 15.2889 3714.998 198.027 20:17:15 15.4722 3735.936 198.048 20:27:15 15.6389 3750.622 198.066 20:37:25 15.8083 3757.060 198.074 20:47:25 15.9750 3774.714 198.066 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.9 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 16 -Mar-94 Data Print Frequency: 20:58:25 16.1583 3808.116 198.056 21:08:45 16.3306 3797.113 198.047 21:19:25 16.5083 3779.682 198.038 21:30:05 16.6861 3793.511 198.038 21:40:45 16.8639 3803.786 198.041 21:51:45 17.0472 3808.081 198.045 22:02:45 17.2306 3814.129 198.047 22:13:45 17.4139 3817.621 198.047 22:22:45 17.5639 3820.067 198.047 22:23:45 17.5806 3820.438 198.048 *** End of Period 3 *** Date: 13-Mar-94 Ticket No: 462909 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) 16-Mar-94 Data Print Frequency: 1 *** Start of Period 4 *** 22:34:05 0.1722 3823.821 198.042 22:45:05 0.3556 3812.924 198.035 22:55:.55 0.5361 3806.326 198.031 23:06:55 0.7194 3799.015 198.043 23:17:55 0.9028 3793.797 198.056 23:27:55 1.0694 3787.805 198.068 23:38:05 1.2389 3786.575 198.082 23:48:35 1.4139 3783.792 198.096 23:59:35 1.5972 3780.110 198.112 17-Mar-94 00:09:35 1.7639 3773.682 198.125 00:20:35 1.9472 3772.115 198.140 00:31:35 2.1306 3776.045 198.156 00:41:45 2.3000 3810.593 198.198 00:52:15 2.4750 3803.182 198.160 01:02:35 2.6472 3797.325 198.114 01:13:35 2.8306 3791.996 198.093 01:23:45 3.0000 3792.197 198.129 01:34:45 3.1833 3797.267 198.169 01:45:05 3.3556 3798.884 198.199 01:55:35 3.5306 3802.296 198.211 02:06:35 3.7139 3803.775 198.223 02:17:35 3.8972 3806.647 198.235 02:28:15 4.0750 3813.474 198.239 02:38:35 4.2472 3816.101 198.242 02:48:45 4.4167 3817.344 198.247 02:59:45 4.6000 3817.331 198.250 03:10:05 4.7722 3817.707 198.251 03:20:45 4.9500 3813.799 198.253 03:30:45 5.1167 3819.708 198.256 03:40:55 5.2861 3816.921 198.260 03:50:55 5.4528 3810.570 198.267 04:01:55 5.6361 3807.756 198.275 04:12:55 5.8194 3805.037 198.282 04:23:45 6.0000 3806.777 198.290 04:34:45 6.1833 3807.416 198.297 04:45:15 6.3583 3814.661 198.304 04:55:45 6.5333 3817.051 198.309 05:06:15 6.7083 3821.965 198.316 05:16:25 6.8778 3822.788 198.318 05:26:45 7.0500 3822.723 198.320 05:37:15 7.2250 3823.680 198.321 05:47:55 7.4028 3824.511 198.325 05:58:15 7.5750 3817.757 198.322 06:08:25 7.7444 3810.515 198.323 Page No: 3.1.10 Gauge Depth: 13457.00 ft COMMENTS Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.11 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) 17-Mar-94 06:18:35 7.9139 06:28:55 8.0861 06:39:55 8.2694 06:49:55 8.4361 07:00:35 8.6139 07:11:05 8.7889 07:21:35 8.9639 07:32:35 9.1472 07:42:35 9.3139 07:53:35 9.4972 08:04:35 9.6806 08:15:25 9.8611 08:26:05 10.0389 08:36:'25 10.2111 08:46:55 10.3861 08:57:15 10.5583 09:07:15 10.7250 09:17:55 10.9028 09:28:05 11.0722 09:38:25 11.2444 09:48:35 11.4139 09:59:35 11.5972 10:10:15 11.7750 10:21:15 11.9583 10:31:55 12.1361 10:42:15 12.3083 10:52:25 12.4778 11:02:25 12.6444 11:13:25 12.8278 11:24:15 13.0083 11:35:15 13.1917 11:46:15 13.3750 11:57:15 13.5583 12:07:15 13.7250 12:17:25 13.8944 12:27:35 14.0639 12:38:35 14.2472 12:48:45 14.4167 12:59:15 14.5917 13:10:15 14.7750 13:21:15 14.9583 13:31:15 15.1250 13:42:15 15.3083 13:53:15 15.4917 14:03:25 15.6611 14:14:05 15.8389 Data Print Frequency: 3810.005 198.339 3806.409 198.356 3797.504 198.371 3797.062 198.384 3792.654 198.398 3793.939 198.407 3797.022 198.414 3794.706 198.421 3806.648 198.427 3813.480 198.434 3813.823 198.438 3814.363 198.438 3814.043 198.443 3818.934 198.446 3813.480 198.441 3814.843 198.448 3814.235 198.449 3811.923 198.449 3801.091 198.451 3789.237 198.457 3785.866 198.477 3782.891 198.499 3778.567 198.520 3777.563 198.541 3777.614 198.561 3780.576 198.579 3781.230 198.601 3781.707 198.610 3782.520 198.619 3782.616 198.627 3783.860 198.636 3781.454 198.645 3780.485 198.654 3780.258 198.662 3780.790 198.670 3783.993 198.678 3783.134 198.688 3780.662 198.694 3778.892 198.701 3781.482 198.708 3777.778 198.715 3787.346 198.722 3791.058 198.729 3793.700 198.736 3794.333 198.735 3794.012 198.737 Gauge Depth: COMMENTS 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.12 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 17-Mar-94 14:24:55 16.0194 14:35:55 16.2028 14:46:55 16.3861 14:57:55 16.5694 15:08:05 16.7389 15:19:05 16.9222 15:29:35 17.0972 15:40:15 17.2750 15:50:35 17.4472 16:01:25 17.6278 16:11:25 17.7944 16:22:15 17.9750 16:32:15 18.1417 16:43:'15 18.3250 16:54:15 18.5083 17:05:15 18.6917 17:15:15 18.8583 17:26:15 19.0417 17:37:15 19.2250 17:48:15 19.4083 17:58:15 19.5750 18:09:15 19.7583 18:19:35 19.9306 18:30:05 20.1056 18:41:05 20.2889 18:52:05 20.4722 19:03:05 20.6556 19:13:55 20.8361 19:24:45 21.0167 19:35:45 21.2000 19:46:45 21.3833 19:56:45 21.5500 20:07:45 21.7333 20:17:55 21.9028 20:28:05 22.0722 20:38:45 22.2500 20:48:55 22.4194 20:58:55 22.5861 21:09:55 22.7694 21:20:55 22.9528 21:31:55 23.1361 21:41:55 23.3028 21:52:55 23.4861 22:03:55 23.6694 22:14:35 23.8472 22:24:35 24.0139 Data Print Frequency: 3796.168 198.745 3799.060 198.754 3796.967 198.764 3786.217 198.774 3770.663 198.782 3766.240 198.808 3762.577 198.836 3762.685 198.856 3765.900 198.867 3758.925 198.879 3759.221 198.890 3760.271 198.900 3758.727 198.909 3759.039 198.918 3761.891 198.928 3766.460 198.938 3767.782 198.946 3774.306 198.956 3778.457 198.967 3778.569 198.977 3776.898 198.986 3779.296 198.996 3777.201 199.003 3765.458 198.998 3742.740 198.992 3724.332 198.987 3715.221 198.982 3709.128 198.976 3704.689 198.996 3701.310 199.017 3698.681 199.037 3700.649 199.056 3702.011 199.077 3703.208 199.091 3703.885 199.098 3701.921 199.104 3701.971 199.114 3704.501 199.125 3701.133 199.138 3708.035 199.150 3717.372 199.162 3722.360 199.173 3730.317 199.181 3727.743 199.187 3729.059 199.192 3729.995 199.198 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.13 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 17-Mar-94 22:34:45 24.1833 22:45:25 24.3611 22:55:25 24.5278 23:05:55 24.7028 23:16:15 24.8750 23:27:15 25.0583 23:38:05 25.2389 23:49:05 25.4222 18-Mar-94 00:00:05 25.6056 00:11:05 25.7889 00:21:05 25.9556 00:31:25 26.1278 00:42:05 26.3056 00:52:15 26.4750 01:03:15 26.6583 01:14:15 26.8417 01:24:45 27.0167 01:35:15 27.1917 01:45:45 27.3667 01:56:45 27.5500 02:07:45 27.7333 02:18:45 27.9167 02:28:45 28.0833 02:39:05 28.2556 02:50:05 28.4389 03:00:25 28.6111 03:10:35 28.7806 03:21:35 28.9639 03:32:15 29.1417 03:42:15 29.3083 03:53:15 29.4917 04:04:15 29.6750 04:15:05 29.8556 04:25:25 30.0278 04:36:25 30.2111 04:46:25 30.3778 04:56:55 30.5528 04:59:55 30.6028 05:00:45 30.6167 Data Print Frequency: 3729.248 199.198 3731.877 199.196 3728.936 199.180 3729.639 199.174 3729.861 199.182 3721.207 199.189 3730.735 199.195 3736.343 199.202 3740.221 3737.060 3738.277 3734.282 3725.946 3726.147 3714.758 3694.452 3711.797 3718.976 3728.193 3732.782 3739.524 3745.998 3745.832 3747.659 3745.923 3736.088 3737.606 3740.817 3742.211 3745.560 3746.984 3743.380 3742.423 3740.933 3742.497 3742.027 3739.235 3739.630 3740.082 *** End 199.209 199.215 199.221 199.228 199.224 199.230 199.236 199.242 199.248 199.254 199.259 199.261 199.262 199.263 199.264 199.267 199.274 199.280 199.285 199.308 199.309 199.307 199.305 199.303 199.306 199.312 199.317 199.322 199.328 199.329 199.330 of Period 4 *** Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.14 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 18-Mar-94 Data Print Frequency: 1 *** Start of Period 5 *** 05:01:05 0.0056 4411.221 199.491 05:01:15 0.0083 4906.355 199.652 05:01:25 0.0111 5197.593 199.661 05:01:35 0.0139 5370.940 199.669 05:01:45 0.0167 5477.677 199.632 05:02:05 0.0222 5596.151 199.559 05:03:05 0.0389 5720.797 199.393 05:06:25 0.0944 5828.389 199.214 05:16:55 0.2694 5922.303 198.663 05:27:35 0.4472 5961.281 198.208 05:37:45 0.6167 5984.650 197.868 05:47:55 0.7861 6001.189 197.593 05:58:25 0.9611 6014.726 197.348 06:08:35 1.1306 6025.323 197.134 06:18:55 1.3028 6034.554 196.948 06:29:15 1.4750 6042.575 196.777 06:39:25 1.6444 6049.490 196.625 06:49:55 1.8194 6055.917 196.476 07:00:15 1.9917 6061.673 196.342 07:10:35 2.1639 6066.900 196.219 07:20:55 2.3361 6071.740 196.101 07:31:25 2.5111 6076.280 195.987 07:41:45 2.6833 6080.458 195.884 07:51:55 2.8528 6084.304 195.788 08:02:45 3.0333 6088.120 195.686 08:13:35 3.2139 6091.704 195.587 08:24:25 3.3944 6095.100 195.504 08:35:15 3.5750 6098.292 195.416 08:45:35 3.7472 6101.187 195.338 08:55:45 3.9167 6103.889 195.264 09:06:05 4.0889 6106.496 195.192 09:16:05 4.2556 6108.912 195.123 09:26:25 4.4278 6111.306 195.056 09:37:25 4.6111 6113.734 194.988 09:47:55 4.7861 6115.956 194.925 09:58:05 4.9556 6118.016 194.867 10:09:05 5.1389 6120.145 194.805 10:19:25 5.3111 6122.075 194.748 10:30:25 5.4944 6124.055 194.688 10:40:35 5.6639 6125.812 194.634 10:51:25 5.8444 6127.629 194.585 11:02:25 6.0278 6129.399 194.532 11:13:25 6.2111 6131.095 194.479 11:24:25 6.3944 6132.741 194.427 11:34:55 6.5694 6134.257 194.378 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.15 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 18-Mar-94 Data Print Frequency: 11:45:05 6.7389 6135.687 194.337 11:55:35 6.9139 6137.115 194.294 12:06:15 7.0917 6138.531 194.252 12:16:55 7.2694 6139.899 194.212 12:27:55 7.4528 6141.274 194.172 12:37:55 7.6194 6142.487 194.135 12:48:55 7.8028 6143.777 194.094 12:59:55 7.9861 6145.024 194.054 13:10:55 8.1694 6146.242 194.013 13:20:55 8.3361 6147.325 193.980 13:31:55 8.5194 6148.487 193.945 13:42:55 8.7028 6149.617 193.909 13:53:55 8.8861 6150.719 193.874 14:03:55 9.0528 6151.696 193.842 14:14:55 9.2361 6152.741 193.807 14:25:55 9.4194 6153.772 193.775 14:36:05 9.5889 6154.703 193.748 14:46:35 9.7639 6155.635 193.719 14:57:35 9.9472 6156.609 193.689 15:08:35 10.1306 6157.554 193.659 15:19:35 10.3139 6158.481 193.629 15:29:35 10.4806 6159.305 193.602 15:40:35 10.6639 6160.207 193.571 15:51:35 10.8472 6161.090 193.545 16:02:35 11.0306 6161.973 193.519 16:13:35 11.2139 6162.835 193.493 16:24:35 11.3972 6163.693 193.467 16:35:35 11.5806 6164.544 193.441 16:46:35 11.7639 6165.374 193.415 16:57:35 11.9472 6166.209 193.393 17:08:35 12.1306 6167.025 193.370 17:19:35 12.3139 6167.839 193.348 17:30:35 12.4972 6168.638 193.325 17:41:35 12.6806 6169.426 193.302 17:51:35 12.8472 6170.132 193.282 18:02:35 13.0306 6170.897 193.261 18:13:35 13.2139 6171.641 193.240 18:24:35 13.3972 6172.381 193.219 18:34:35 13.5639 6173.038 193.199 18:44:55 13.7361 6173.713 193.180 18:55:35 13.9139 6174.392 193.161 19:06:35 14.0972 6175.093 193.142 19:16:35 14.2639 6175.714 193.125 19:27:35 14.4472 6176.386 193.106 19:38:35 14.6306 6177.045 193.088 19:48:45 14.8000 6177.644 193.070 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.16 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 18-Mar-94 19:59:45 20:09:55 20:20:55 20:31:55 20:41:55 20:52:55 21:03:55 21:14:55 21:25:55 21:35:55 21:46:55 21:57:55 22:08:55 22:18:55 22:29:55 22:40:55 22:51:55 23:01:55 23:12:55 23:23:55 23:34:55 23:45:55 23:55:55 19-Mar-94 00:06:55 00:17:55 00:28:55 00:38:55 00:49:55 01:00:55 01:11:55 01:21:55 01:32:55 01:43:55 01:54:55 02:05:55 02:15:55 02:26:55 02:37:55 02:48:55 02:58:55 03:09:55 03:20:55 03:31:55 03:41:55 03:52:55 14.9833 15.1528 15.3361 15.5194 15.6861 15.8694 16.0528 16.2361 16.4194 16.5861 16.7694 16.9528 17.1361 17.3028 17.4861 17.6694 17.8528 18.0194 18.2028 18.3861 18.5694 18.7528 18.9194 19.1028 19.2861 19.4694 19.6361 19.8194 20.0028 20.1861 20.3528 20.5361 20.7194 20.9028 21.0861 21.2528 21.4361 21.6194 21.8028 21.9694 22.1528 22.3361 22.5194 22.6861 22.8694 Data Print Frequency: 6178.286 193.052 6178.866 193.037 6179.484 193.020 6180.085 193.004 6180.634 192.989 6181.216 192.972 6181.785 192.956 6182.343 192.939 6182.890 192.923 6183.371 192.908 6183.890 192.892 6184.405 192.876 6184.902 192.859 6185.347 192.846 6185.833 192.833 6186.298 192.819 6186.746 192.806 6187.155 192.793 6187.595 192.780 6188.025 192.766 6188.443 192.753 6188.848 192.739 6189.207 192.727 6189.601 192.713 6189.987 192.699 6190.372 192.687 6190.709 192.677 6191.076 192.665 6191.436 192.653 6191.782 192.641 6192.100 192.630 6192.446 192.618 6192.781 192.606 6193.113 192.594 6193.444 192.582 6193.745 192.571 6194.066 192.560 6194.379 192.550 6194.696 192.540 6194.992 192.532 6195.309 192.522 6195.622 192.512 6195.932 192.503 6196.218 192.494 6196.528 192.485 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.17 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 19-Mar-94 Data Print Frequency: 04:03:55 23.0528 6196.845 192.475 04:14:55 23.2361 6197.162 192.466 04:25:55 23.4194 6197.483 192.457 04:35:55 23.5861 6197.776 192.448 04:46:55 23.7694 6198.097 192.439 04:57:55 23.9528 6198.426 192.430 05:08:55 24.1361 6198.758 192.421 05:19:05 24.3056 6199.062 192.412 05:30:05 24.4889 6199.391 192.403 05:40:25 24.6611 6199.687 192.394 05:51:25 24.8444 6200.014 192.385 06:01:55 25.0194 6200.319 192.376 06:12:25 25.1944 6200.635 192.371 06:23:25 25.3778 6200.944 192.363 06:33:25 25.5444 6201.235 192.356 06:43:35 25.7139 6201.527 192.349 06:53:35 25.8806 6201.807 192.341 07:04:35 26.0639 6202.112 192.333 07:15:35 26.2472 6202.424 192.325 07:26:35 26.4306 6202.722 192.317 07:36:35 26.5972 6202.995 192.309 07:47:35 26.7806 6203.292 192.301 07:58:35 26.9639 6203.574 192.292 08:08:55 27.1361 6203.846 192.286 08:19:05 27.3056 6204.113 192.279 08:30:05 27.4889 6204.386 192.271 08:40:15 27.6583 6204.639 192.265 08:51:15 27.8417 6204.907 192.258 09:01:35 28.0139 6205.158 192.253 09:11:35 28.1806 6205.388 192.248 09:21:45 28.3500 6205.614 192.242 09:31:45 28.5167 6205.840 192.237 09:42:25 28.6944 6206.065 192.228 09:52:35 28.8639 6206.279 192.222 10:02:35 29.0306 6206.478 192.210 10:13:05 29.2056 6206.699 192.209 10:23:05 29.3722 6206.885 192.203 10:34:05 29.5556 6207.095 192.197 10:45:05 29.7389 6207.295 192.190 10:56:05 29.9222 6207.498 192.184 11:06:05 30.0889 6207.666 192.178 11:16:45 30.2667 6207.840 192.169 11:26:55 30.4361 6208.005 192.163 11:37:25 30.6111 6208.177 192.161 11:48:25 30.7944 6208.353 192.155 11:58:25 30.9611 6208.512 192.151 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.18 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) 19-Mar-94 Data Print Frequency: 12:09:25 31.1444 6208.673 192.145 12:20:25 31.3278 6208.838 192.140 12:30:35 31.4972 6208.986 192.135 12:41:35 31.6806 6209.132 192.129 12:52:15 31.8583 6209.280 192.122 13:02:15 32.0250 6209.412 192.113 13:12:25 32.1944 6209.558 192.109 13:22:35 32.3639 6209.688 192.105 13:33:35 32.5472 6209.830 192.098 13:43:45 32.7167 6209.955 192.093 13:54:45 32.9000 6210.095 192.088 14:05:35 33.0806 6210.236 192.083 14:16:35 33.2639 6210.366 192.078 14:27:35 33.4472 6210.499 192.073 14:37:35 33.6139 6210.619 192.069 14:48:35 33.7972 6210.756 192.064 14:59:35 33.9806 6210.893 192.059 15:10:35 34.1639 6211.025 192.054 15:20:35 34.3306 6211.139 192.048 15:31:05 34.5056 6211.268 192.042 15:42:05 34.6889 6211.406 192.038 15:53:05 34.8722 6211.544 192.034 16:04:05 35.0556 6211.682 192.030 16:14:15 35.2250 6211.816 192.025 16:24:25 35.3944 6211.943 192.018 16:34:25 35.5611 6212.074 192.015 16:45:25 35.7444 6212.231 192.011 16:56:25 35.9278 6212.383 192.006 17:07:25 36.1111 6212.547 192.002 17:17:55 36.2861 6212.707 191.999 17:28:55 36.4694 6212.874 191.995 17:39:05 36.6389 6213.034 191.991 17:50:05 36.8222 6213.214 191.986 18:00:45 37.0000 6213.390 191.981 18:11:05 37.1722 6213.558 191.977 18:22:05 37.3556 6213.745 191.975 18:32:15 37.5250 6213.922 191.970 18:43:15 37.7083 6214.105 191.965 18:54:05 37.8889 6214.281 191.960 19:05:05 38.0722 6214.473 191.955 19:15:25 38.2444 6214.643 191.950 19:25:45 38.4167 6214.822 191.948 19:35:45 38.5833 6214.992 191.946 19:46:05 38.7556 6215.166 191.944 19:57:05 38.9389 6215.347 191.939 20:07:45 39.1167 6215.521 191.935 Gauge Depth: COMMENTS 13457.00 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.19 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 19-Mar-94 Data Print Frequency: 20:18:45 39.3000 6215.702 191.931 20:28:55 39.4694 6215.869 191.927 20:39:55 39.6528 6216.043 191.920 20:50:25 39.8278 6216.212 191.920 21:00:55 40.0028 6216.377 191.917 21:11:15 40.1750 6216.536 191.912 21:22:15 40.3583 6216.701 191.909 21:32:15 40.5250 6216.851 191.906 21:42:45 40.7000 6216.999 191.902 21:53:45 40.8833 6217.160 191.895 22:03:55 41.0528 6217.296 191.895 22:14:25 41.2278 6217.452 191.894 22:25:25 41.4111 6217.589 191.891 22:36:25 41.5944 6217.733 191.889 22:46:25 41.7611 6217.856 191.886 22:56:35 41.9306 6217.982 191.884 23:06:35 42.0972 6218.104 191.881 23:17:35 42.2806 6218.225 191.878 23:28:35 42.4639 6218.340 191.874 23:39:35 42.6472 6218.461 191.871 23:50:35 42.8306 6218.568 191.868 20-Mar-94 00:01:35 43.0139 6218.678 191.864 00:12:35 43.1972 6218.780 191.860 00:23:35 43.3806 6218.883 191.856 00:34:35 43.5639 6218.974 191.852 00:44:35 43.7306 6219.062 191.848 00:55:05 43.9056 6219.142 191.844 01:05:05 44.0722 6219.214 191.838 01:15:55 44.2528 6219.306 191.840 01:26:15 44.4250 6219.383 191.838 01:37:15 44.6083 6219.469 191.835 01:48:15 44.7917 6219.562 191.832 01:58:35 44.9639 6219.626 191.830 02:09:35 45.1472 6219.698 191.825 02:19:45 45.3167 6219.769 191.821 02:30:45 45.5000 6219.835 191.817 02:40:45 45.6667 6219.903 191.814 02:51:45 45.8500 6219.980 191.810 03:02:15 46.0250 6220.052 191.812 03:12:35 46.1972 6220.125 191.808 03:23:15 46.3750 6220.200 191.810 03:33:25 46.5444 6220.266 191.806 03:44:25 46.7278 6220.339 191.802 03:54:55 46.9028 6220.409 191.798 04:05:55 47.0861 6220.478 191.795 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.20 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 ft 20-Mar-94 04:16:55 47.2694 04:27:55 47.4528 04:37:55 47.6194 04:48:55 47.8028 04:59:55 47.9861 05:10:55 48.1694 05:20:55 48.3361 05:31:55 48.5194 05:35:55 48.5861 05:36:55 48.6028 05:41:25 05:41:45 05:41:55 05:52:35 06:52:35 07:53:05 08:53:55 09:54:25 10:54:55 11:55:15 12:55:15 13:56:15 14:57:05 15:57:35 16:58:25 17:58:45 18:59:45 20:00:35 21:00:55 21:07:35 21:14:05 21:20:45 21:26:45 21:32:25 21:37:55 21:43:35 21:50:45 22:51:15 23:51:45 21-Mar-94 00:44:55 00:48:25 01:49:05 02:46:25 02:52:05 Data Print Frequency: 6220.560 191.793 6220.643 191.790 6220.716 191.788 6220.802 191.785 6220.896 191.785 6221.009 191.797 6221.117 191.807 6221.234 191.818 6221.286 191.822 6221.291 191.823 *** End of Period 3824.898 191.321 3597.234 191.085 3799.990 191.191 4005.374 191.076 4130.774 196.180 4010.814 197.078 3955.475 197.734 3948.296 198.108 4076.275 198.233 4137.444 198.239 4184.023 198.238 4167.038 198.251 4183.224 198.308 4198.676 198.350 4237.075 198.365 4203.440 198.360 4163.709 198.431 4207.872 198.527 4238.751 198.553 4445.894 198.578 4647.396 198.635 4857.958 198.646 5064.679 198.656 5275.703 198.666 5487.780 198.644 5689.687 198.573 5895.164 198.412 6083.718 196.872 6111.698 195.986 5792.445 195.383 5996.662 195.378 6117.817 194.988 5859.537 194.526 6062.562 194.543 Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.21 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 21-Mar-94 Data Print Frequency: 03:40:55 5816.803 194.276 03:43:55 6030.721 194.322 04:44:25 6161.871 194.120 05:45:05 6162.227 193.934 06:45:15 6155.736 193.751 07:46:15 6163.973 193.573 08:34:45 5874.724 193.373 08:38:55 6083.354 193.429 09:39:25 6130.752 193.318 10:40:25 6141.600 193.281 11:18:45 5878.916 193.123 11:22:45 6084.819 193.181 12:23:15 6033.920 193.127 13:00:25 5708.823 193.025 13:00:55 5463.222 192.944 13:01:35 5184.134 192.906 13:02:55 4983.396 192.922 13:05:05 4773.957 192.934 13:08:05 4563.756 192.910 13:10:15 4334.102 192.893 13:13:55 4130.015 192.864 13:19:55 3926.748 192.845 13:27:35 3725.314 192.828 13:32:55 3518.561 192.817 13:39:35 3316.189 192.803 13:47:45 3114.341 192.796 13:58:05 2910.211 192.771 14:09:55 2706.112 192.742 14:34:45 2502.344 192.740 15:34:55 2461.493 192.757 16:35:05 2436.864 192.550 17:35:45 2441.392 192.580 18:08:05 2647.735 193.044 18:08:55 9584.212 194.375 18:09:25 9914.139 195.128 18:09:45 9531.594 194.708 18:09:55 8803.724 194.372 18:10:05 8192.183 194.036 18:10:15 7633.463 193.789 18:10:25 7136.781 193.543 18:10:35 6750.685 193.387 18:10:45 6450.671 193.231 18:10:55 6114.398 193.110 18:11:05 5772.767 192.989 18:11:15 5477.057 192.867 19:11:15 5380.118 192.653 ft Date: 13-Mar-94 Ticket No: 462909 Page No: 3.1.22 PRESSURE VS TIME HALLIBURTON Gauge No.: 10781 Memory Recorder No.: 20223 TIME D TIME PRESSURE TEMP HH:MM: SS (hr) (psi) (F) Gauge Depth: COMMENTS 13457.00 21-Mar-94 Data Print Frequency: 20:11:25 5341.063 191.731 20:20:45 5119.803 185.636 20:31:55 4915.549 181.323 20:42:.55 4706.144 175.685 20:54:35 4503.487 170.081 21:02:45 4287.970 165.563 21:12:35 4069.451 159.949 21:22:25 3860.789 154.227 21:32:35 3639.257 148.115 21:43:45 3408.141 141.975 21:54:05 3200.081 136.327 22:03:35 2992.753 131.018 22:13:05 2779.379 125.637 22:21:45 2574.836 120.784 22:30:55 2365.088 115.247 22:38:15 2160.360 110.477 22:47:05 1933.663 104.181 22:55:25 1714.492 99.621 23:03:45 1478.610 94.180 23:11:35 1277.940 88.957 23:33:25 1077.766 84.598 23:40:45 867.333 81.220 23:46:55 654.492 78.140 23:55:15 439.281 74.776 22-Mar-94 00:01:45 236.959 01:02:25 95.353 02:02:45 42.252 03:02:55 41.590 03:13:25 40.928 68 52 54 52 52 .181 .613 .807 .046 .860 ft Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 3.2 Gauge No. 10780 Gauge Depth 13457' MD Test Tubing 8000 6000 Fire Guns / / FI, I Extend~d Buildup Shear RD VaJve ........... -~ ........ ~ I I W/L I 4000 2000 240 200 160 80 40 /- 3/13 0:00 3/15 0:00 3/17 0:00 3/19 0:00 3/21 0:00 3~23 0:00 Plot Start Time: 13-Mar~94 00:00:00 Plot End Time: 23-Mar-94 00:00:00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 3.3 Gauge No. HSR04 Gauge Depth 13403' MD 12000 Flow FI,)w I Extend~rd Buildup W/L C peration: - I I ! I I I I I t I I I I i I I I I ...--I I I 240 200 10000 80OO 600O 4000 2000 160 · 120 ~ 8O 4O 3/13 0'00 3/15 0:00 3/17 0:00 3/19 0:00 3/21 0:00 3/23 0:00 Plot Start Time: 13-Mar-94 00:00:00 Plot End Time: 23-Mar-94 00:00:00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 3.4 Gauge No. HSRO5 Gauge Depth: 13403' MD 12000 240 10000 8000 6000 4000 2000 0 3/13 0:00 Test Tubing 3/15 0:00 Guns Shear RD Val / / / / / / Buildup W/L 3/17 0:00 3/19 0:00 3/21 0:00 200 160 120 8O 4O 0 3/23 0:00 Plot Start Time: 13-Mar-94 00:00:00 Plot End Time: 23-Mar-94 00:00:00 Phillips Petroleum Company Sunfish #3 DST #1 Halliburton Energy Services Pressure/Temperature History Plot Page No. 3.5 Gauge No. HSRO7 Gauge Depth: 13403' MD 12000 10000 80OO 600O 4000 Fh I ExtendE Buildup Flow 2 W Operatiom 240 2O0 160 120 ~ 80 2000 0 3/13 0:00 3/15 0:00 3/17 0:00 3/19 0'00 3/21 0:00 0 3/23 0:00 Plot Start Time: 13-Mar-94 00:00:00 Plot End Time: 23-Mar-94 00:00:00 PHILLIPS PETROLEUM Sunfish #3 Drill Stem Test March 28 - March 29, 1994 HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: DRILLING CONTRACTOR: LEGAL LOCATION: OPERATOR: WELL NAME: TEST NO: TESTED INTERVAL: 462911 462911 13-Mar-94 Kenai R. A. Richey S. M. Hurst Pool Arctic Alaska 1250' FNL & 980' FWL S6-T11N-R9W Phillips Petroleum Sunfish ~ Two 12478.00- 12538.00 ft FIELD AREA: North Cook Inlet COUNTY/LSD: Kenai STATE/PROVINCE: Alaska COUNTRY: USA NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR IMPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS OR OPINIONS. TABLE OF CONTENTS SECTION 1: TEST SUMMARY & INFORMATION Test and Formation Data 1.1 Sequence of Events 1.2 Tool Stdng Configuration 1.3 Pressure Temperature History Plot 1.4 Well Test Summary 1.5 Production Data 1.6 SECTION 2: MEMORY GAUGE DATA Gauge No. 10780 History Plot 2.1 Gauge No. 10780 Reduced Listing 2.1.1 Gauge No. 10220 History Plot 2.2 Gauge No. HSRO4 History Plot 2.3 Gauge No. HSRO5 History Plot 2.4 Gauge No. HSRO7 (Annulus) History Plot 2.5 Date: 28-Mar-94 Ticket No: 462911 TEST AND FORMATION DATA Page No: 1.1 Formation Tested: All Depths Measured From: Elevation: Total Depth: Thickness: Hole or Casing Size: Tester Valve Depth: Packer Set Depth: Gross Tested Interval: Perforated Interval (ft): "Sunfish" KB 132 ft MLLW 13434 ft 38 ft 7.00 in 12315 ft 12372 ft 12478 - 12538 ft 12478 - 12502 ft 12526 - 12538 ft HOLE FLUID Type: 2% KCL Brine Weight: 8.45 lb/gal HYDROCARBON PROPERTIES Oil Gravity (APl): 48.0 Gas/Oil ratio (ScF/STB): Gas Gravity (SG): HOLE TEMPERATURE Depth: 12347 ft Temp: 175 degf CUSHION DATA @ 60 degf Nitrogen 57 bbl @ 7647fl RECOVERY: REMARKS: Phillips Petroleum Sunfish #3 DST #2 HALLIBURTON ENERGY SERVICES Sequence of Events Page No. 1.2.1 TimeI Remarks Bhp I Bht Whp Wht Casing Choke (psia)1 (degf) (psig) (degf) (psig) (64the) 28-M ar-94 04:00:00 Run Gun/Pecker Assembly on wireline 09:40:00 Pick up Test Tools 18:30:00 Rig up Test Tree 19:30:00 !Rig up RT-91 SRO Probe 20:00:00 Pressure Test to Separator 1700 psi 0.21 45.22 2006.41 0 20:40:00 Fill Lubricator, PT 8000 psi 88.18 50.03 0.00 0 21:35:00 Cycle OMNI to Circ Position -0.97 50.43 594.28 0 21:55:00 OMNI to Circulating Position [ 54.53 50.57 118.63 0 22:05:00 PT N2 LineI 11.96 50.08 0.00 0 I I 46.78 48.72 0.00 0 22:13:00 Start displacing with N2 (57 bbl) 22:47:00 Shut in Annulus Continue to pump N2 22:56:00 Shut down N2 Shoot Fluid Level @ 7647' I 2889.781 46.43 516.03 0 23:16:00 Cycle OMNI to well test position I 2879.78 45.39 593.66 0 23:30:00 Hold Safety Meeting 2875.78 44.92 0.001 0 23:48:00! Pressure up to open LPR-N 2874.28 44.88~ 0.00 0 23:55:00!Pump N2 to fire guns 2872.53 45.02 1604.16 O. 29-Mar-94 00:15:30 Reach Min firing pressure (4722 psi) 4684.78 45.46 1634.53 0 00:18:45 Reach Nora firing pressure (5100 psi) 5121.53 45.71 1642.53 0 00:26:30 Reach Max firing pressure {6000 psi) 6010.03 45.80 1658.91 0 00:26:45 Shut Down N2 6028.03 45.79 1659.41 0 00:27:15 Bleed Down To 4100 On 10/64 choke 6023.28 45.99 1659.28 0 00:32:15 Shut in Wait on Gun Firing 4068.03 58.06 1617.53 0 00:36:00 Guns Fired 4096.78 57.28 1614.16 0 00:38:30 Open well for initial flow 6/64 adj choke 4056.53 56.42 1613.28 6 00:41:00 Shut in @ choke 2996.031 57.61 1589.28 6 00:49:00 Shoot Fluid Level @ 7141' 3020.28 54.84 1586.41 0 O0:59:001Shoot Fluid Level @ 7078' 3021.03 51.45 1585.16 0 01:00:O01Shut in choke manifold. Choke was washed out. 3019.53 51.07 1585.16 0 01:02:00 Shut in @ LPR-N and Safety valve 0.00 50.50 1564.16' 0 01:12:00 Open swab.RIH w/RT91 probe. 0.00 40.66 0.00 O! 01:22:00 Choke Repaired, Safety Valve closed 2.63 40.38 0.00 0 02:40:00 Latched probe in RT91 tool 3017.53 45.13 0.00 0 02:50:00 Download RT-91 Data 3017.53 44.94 0.00 0 03:39:00 Establish Real Time Link, Monitor BHP 6875.54 171.71 3016.53 44.77 0.00 0 04:00:00 6910.78 171.78 3016.03 45.02 0.00 0 04:30:00 6955.32 171.90 3013.78 45.40 0.00 0 04:45:00 6974.25 171.95 3013.53! 45.38 0.00 0 05:00:00 6992.53 171.99 3013.28 45.15 0.00 0 05:15:00! 7009.18 172.05 3013.03 45.01 0.00 0 05:30:00 7024.39 172.09' 3012.78 44.95 0.00 0 0S:4S:00 ~ 7039.04 172.13 3012.78 45.161 0.00 O' Phillips Petroleum Sunfish #3 DST #2 HALLIBURTON ENERGY SERVICES Sequence of Events Page No. 1.2.2 Time Remarks Bhp Bht Whp Wht Casing Choke (psia) (de,If) (psig) (de~f) (psig! (64the) 29-Mar-94 05:49:00 Open Safety Valve 7042.79 172.13 2548.28 44.74 0.00 0 06:03:00 Open LPR-N 7055.72 172.20 3010.28 45.59 174.03 0 06:15:00 5805.40 172.46 3036.78 46.26 1578.66 0 06:21:00 Open on 12/64 pos choke 5782.40 172.45 3026.53 46.25' 1576.53 12 06:25:00 Close safety valve Work on Adj Choke 5439.63 172.45 2725.03 54.11 1568.78 0 06:40:00 Open safety valve 5429.33 172.43 1.31 47.67 1565.78 0 06:43:00 Open Well on 14/64th adj choke I 5381.33 172.43 2668.03 54.08 1564.91 14 I 4986.56 172.44 2335.78 56.42 1556.28 10 06:52:00 Change choke to 10/64th adj i I 4969.82 172.45 2322.28 56.30 1555.78 12 06:53:00 Change choke to 12/64th adj ] 07:00:00 i 4915.08 172.45 2272.53 55.73 1554.41 12 08:29:00 Shut in at choke, shoot fluid level i 4355.34 172.44 1776.28 55.83 1541.91 12 08:32:00 Open to 12/64 I 4353.63 172.45 1777.53 55.71 1541.78 12 08:39:00 Shut in at choke, Shoot fluid level 6636 ft 4344.641 172.45 1764.78 55.77 1541.53 12 I 08:43:00 Open to 12/64 I 4347.93 172.45 1766.53 55.23 1541.66 12 08:49:00 Change choke to 14/64 4336.82 172.45 1755.53 54.90 1541.41 14 09:10:00 Change choke to 16/64 3909.98 172.47 1395.03 57.48 1533.28 16 10:38:00 'Shut in for fluid level 2503.83 172.541 184.23 52.53 1511.78 16 10:39:00 Open well to 16/64, Fluid level 6320 ft 2501.54 172.55 182.01 52.40 1511.78 16 11:45:00 Download RT-91 Data 2369.36 172.71 36.08 49.99 1510.53 16 12:55:00 Unlatch RT-91, Pull out of hole 4.58 47.40 1510.41 16 14:05:00 At surface w/RT-91 3.51 46.15 1510.78 16 14:08:00 Swab valve closed, rig down tool 3.51 45.97 1510.78 16 14:44:00 Start to cycle OMNI 4.93 46.21 1043.16 16 15:00:00 OMNI to 1st blank pceition, Start filling tubing 9.56 45.68 1620.03 16 15:25:00 Tubing loaded w/43 bbl -6.69 48.32 0.00 16 15:31:00 Cycle OMNI 36.26 52.25 956.53 16 15:38:00 OMNI to Circulating Position 122.83 54.08 47.70 16 15:40:00i Open well to 24/64 choke 76.23 53.46 6.80 24 15:41:00 Start Reverse Out 70.51 53.26 3.31 24 15:46:00 Open to 32/64 choke 240.61 56.38 263.53 32 16:33:00 Open to 36/64 231.81 58.14 263.66~ 36 16:39:00 !Finish Reverse Out, End Test 250.06 58.33 305.53 36~ Phillips Petroleum HALLIBURTON ENERGY SERVICES Page No. 1.3.1 Sunfish #3 DST #2 Toolstring Configuration ~ ! OD ~ ID ! , ! , Comments Tubulars i Length Depth i i ~ i ' i (Tops) ; (ft) (MD ft) ! (in) (in) 3 112 PH-6 Tubing i 12100.08t O.OOi 4.310 2.750 XO31/2PH-6BoxX37/8CASPin i 1.50i 12100.08!~ 5.030i 2.250 " 5.67i 12101.58 5.030 2.250 RD Safety Circulating Valve XO37/8CASBoxX3 I/2PH-6Pin i 1.48i 12107.25! 5.050i 2.250 i 60.63J 12108.73~ 4.310i 2.750 2 Jts 3 1/2 PH-6 Tubing i XO3 1/2 PH-6 Box X 3 7/8 CAS Pin i 1.48i 12169.361 5.030 2.250 ' i Drain Valve i 3.42i 12170.84j 5.030 2.250 RD (::irc Valve: APR OMNI Valve ~ 21.16i 12174.26~ 5.030 2.250 ~= 12102' MD (10983' 'I-VD) i 1.48 12195.42! 5.040 2.250 XO 3 718 CAS Box X 3 1/2 PH-6 Pin i 2 Jts 3 1/2 PH-6 Tubing ! 64.96i 12196.90' 4.310 2.750 XO3 1/2 PH-6 Box X 3 7/8 CAS Pin i 12261.86i 5.050i 2.250 i 3.44 12263.35 5.030 2.250 Drain Valve Two PT-91 Flow Extensions ~i 25.82 12266.79 5.030~ 3.0001 i 22.87j 12292.61 5.030 2.250 RT-91 Surface Readout Valve LPR-N Tester Valve ! 1 6.86 12315.48 i ~ ~ 5.030i 2.250 OMNI Drain Valve i 3.44 12332.34. 5.030 2.2501~ 12174' MD (11049' TVD) SG-15 Bundle Carrieri! 16.84i 12335.78i 5.030t 2.250 RD Safety Circulating Valve i 3.59J 12352.62 5.030 2.250 4.60 12356.21 ' TST Valve i 5.030 2.250I J 5.000 j 2.250 Big John Jars j 5.221 12360.81! ' 3.41j 12366.03 5.030 2.250 RT-91 Gauge Depth Safety Joint i 1.48 12369.44 5.050J 2.250 ~ 12313' MD (11177'TVD) XO 3 7/8 CAS Box X 3 1/2 PH-6 Pin j O.81 12370.92! 4.375 2.500 XO 3 1/2 PH-6 Box X 2 7/8 8rd Pin i 9.85 12371.73i., 2.370 LPR-N ,, Seal Assembly (Top of Packer) End of Seal Assembly ~ I i 12381.58 12315' MD (11179' TVD) J ]i HMR Gauge Depth i I 12347' MD (11208' TVD) Halliburton 'BVVD' Packer ! 3.92i 5.677 3.250t RD Circ Valve: Seal Bore Extension i 7.38 ' ~ 4.250 3.250 12353' MD (11214' TVD) ~ 1.00 4.970 2.020i Tubing Adapter 2 3/8 EUE 8rd Pup Jt11 9.72 ~ ~ BVVD Packer: 2 3/8 EUE 8rd Coupling I! ~ ~ _r- ~~D~ Halliburton 'XN' Nipple i 0.96 2.7001 1.790! 2 3/8 EUE 8rd Coupling I 0.41 3.060! I Ported Sub 2 3/8 EUE 8rd Pup Jt 9.70 12395.53 2.610 1.990 12406'MD (11262' TVD) ] 12405.23, XO 2 3/8 EU Box X 2 7/8 EU Pin ,' 0.33 2.8751~ 1.990! 2 7/8 Ported Sub i 2.231 12405.56 3.7501 2.450i i 2.58 1 ~, Perforations: 2 7/8 Housing i 12407.79 3.370 2.500 ~ 2.58 12410.37 3.3701 2.500 ~, Top Shot 12478'MD (11329' TVD) 2 7/8 Housing i Tubing Release Housing I 0.851 12412.95i 3.370 2.630l~ ~, Mid Perfs 12508'MD (11357' 7"VD) Auto Release Firing Head i 1.51 12413.80 3.370 · 61.92 12415.31 3.370. ~ !Perforated Intervals: 3 3/8 Spacer Gun 4 5/8 Blank Vann Gun 0.77 12477.23 4.620 i 12478' - 12502' MD =Top Shot 12478.001! I 12526' - 12538' MD 4 5/8 Vann Guns 6 spf, 32 gm 24.00 12478.001 4.6201 4 5/8 + 3 3/8 Spacer Gun 24.00 12502.00! 4.620 4 5/8 Vann Guns 6 spf, 32 gm I 12.ooj 12526.00 4.6201 Bottom Shot ] ! 12538.00 PBTD = 13434' MD Phillips Petroleum Sunfish #3 DST #2 HALLIBURTON ENERGY SERVICES Toolstring Configuration Page No. 1.3.2 Tubulars Length i Depth ~ OD i ID i ! i i Comments i (Tops) i (ft) ! (MDft) : (in) I (in)I 4 5/8 Blank Vann Gun 2.001~ 12538.00i~ 4.620i 3 3/8 Initiator Sub , 0.70i 12540.00i 3.370! i 3 3/8 Extended Delay Assembly 1.101 12540.70J 3.370l 3 3/8 Extended Delay Assembly 1.10i 12541.80i 3.370i '. ~ : ' , 13 3/8 Time Delay Firing Head 1.84! 12542.901 3.370i ! ~ 3.370i i , Vented C osure 0.49i 12544.74i Bottom of BHA i i ; : 13434.00! PBTD ! i ) i i I i , , ', ~ I , Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 1.4 Gauge No. 10780 Gauge Depth 12347' MD 14000 210 12000 Test Tubing 10000 8000 6000 4000 200O 0 3/28 6'00 Initial Fire Guns Buildup Flow 2 3/28 12:00 3/28 18:00 3/29 0:00 3/29 6:00 3/29 12:00 3/29 18:00 3/30 0:00 180 150 90 ~. 60 30 0 3~30 6:00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 Phillips Petroleum Sunfish//3 DST #2 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.5.1 Time Remarks Bhp Bht Whp Wht Casing Choke Fluid Level Influx Influx Increment Rate -- (ps/a) {de~f) {ps/g) (de,If) (ps/g) (64ths) (ft MD) (bbl) (bl~d) 28-Mar-94 04:00:00 Run Gun/Packer Assembly on w/reline -- _ 09:40:00 Pick up Test Tools 18:30:00 Rig up Test Tree 19:30:00 Rig up RT-91 SRO Probe -- 20:00:00 Pressure Test to Separator 1700 psi 0.21 45.22 2006.41 0 20:40:00 Fill Lubricator, PT 8000 psi 88.18 50.03 0.00 0 21:35:00; Cycle OMNI to Circ Position -0.97 50.43 594.28 0 21:55:00 OMNI to Circulating Position 54.53 50.57 118.63 0 22:05:00 PT N2 Line 11.96 50.08 0.00 0 22:13:00 Start displacing with N2 (57 bbl! 46.78 48.72 0.00 0 22:47:00 Shut in Annulus Continue to pump N2 2280.78 47.05 0.00 0 -I 22:56:00 Shut down N2 Shoot Fluid Level @ 7647' 2889.78 46.43 516.03 0 7647.00 0.00 0.00 23:16:00 Cycle OMNI to well test position 2879.78 45.39 593.66 0 23:30:00 Hold Safety Meeting 2875.78 44.92 0.00 0 23:48:00 Pressure up to open LPR-N 2874.28 44.88 0.00 0 23:55:00 Pump N2 to fire guns 2872.53 45.02' 1604.16 0 -- 29-Mar-94 -- 00:15:30 Reach Min firing pressure (4722 psi) 4684.78 45.46 1634.53 0 -- 00:18:45 Reach Nom firing pressure (5100 psi) 5121.53 45.71 1642.53 0 00:26:30 Reach Max firing pressure (6000 psi) 6010.03 45.80 1658.91 0 -- 00:26:45 Shut Down N2 6028.03 45.79 1659.4~ 0 00:27:15 Bleed DownTo 4100 On 10/64 choke 6023.28 45.99 1659.28 0 00:32:15 Shut in Wait on Gun Firing 4068.03 58.06 1617.53 O' 00:36:00 Guns Fired 4096.78' 57.28 1614.16 0 00:38:30 Open well for initial flow 6/64 adj choke 4056.53 56.42 1613.28 6 O0:41:001Shut in @ choke 2996.03 57.61 1589.28 6 00:49:00 Shoot Fluid Level @ 7141' 3020.28 54.84 1586.41 0 7141.00 3.72 412.06 00:59:00 Shoot Fluid Level @ 7078' 3021.03 51.45 1585.16 0 7078.00 0.461 66.24 Phillips Petroleum Sunfish #3 DST #2 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.5.2 Time Remarks Bhp Bht Whp Wht Casing Choke Fluid Level Influx Influx -- Increment Rate -- (psia) {de~f) (psi~l) (de,If) (psiS) (64ths) irt MD) {bbl) (bp .d.) 29-Mar-94 , -- 01:00:00 Shut in choke manifold. Choke was washed out. 3019.53 51.07 1585.16, 0 01:02:00 Shut in @ LPR-N and Safety valve 0.00 50.50 1584.16 0 --. 01:12:00 Open swab. RIH w/RT91 probe. 0.00 40.66 0.00 0 01:22:00 Choke Repaired, Safety Valve closed 2.63 40.38 0.00 0 02:40:00' Latched probe in RT91 tool 3017.53 45.13 0.00 0 -- 02:50:00 Download RT-91 Data 3017.53 44.94 0.00 0 -- 03:39:00 Establish Real Time Link, Monitor BHP 6875.54 171.71 3016.53 44.77 0.00 0 04:00:00 6910.78 171.78 3016.03 45.02 0.00 0 04:30:00 6955.32 171.90 3013.78 45.40 0.00 0 04:45:00 6974.25 171.95 3013.53 45.38 0.00 05:00:00 6992.53 171.99 3013.28 45.15 0.00 0 05:15:00 7009.18 172.05 3013.03 45.01 0.00' 0 05:30:00 7024.39 172.09 3012.78 44.95 0.00 0 05:45:00 7039.04 172.13 3012.78 45.16 0.00 0 05:49:00 Open Safety Valve 7042.79 172.13 2548.28 44.74 0.00 0 -- 06:03:00 Open LPR-N 7055.72 172.20 3010.28 45.59 174.03 0 -- 06:15:00 5805.40 172.46 3036.78 46.26 1578.66 0 __. -- 06:21:00 Open on 12/64 pos choke 5782.40 172.45 3026.53 46.25 1576.53 12 06:25:00 Close safety valve Work on Adj Choke 5439.63 172.45 2725.03 54.11 1568.78 0 06:40:00 Open safety valve 5429.33 172.43 1.31 47.67 1565.78 0 06:43:00 Open Well on 14/64th adj choke 5381.33 172.43 2668.03 54.08 1564.91 14 06:52:00 Change choke to 10/64th adj 4986.56 172.44 2335.78 56.42 1556.28 10 __ 06:53:00 Change choke to 12/64th adj 4969.82 172.45 2322.28 56.30 1555.78 12 07:00:00 4915.08 172.45 2272.53' 55.73: 1554.41 12 08:29:00 Shut in at choke, shoot fluid level 4355.34 172.44 1776.28 55.83 1541.91 12 08:32:00 .Open to 12/64 4353.63 172.45 1777.53 55.71 1541.78 12 08:39:00 Shut in at choke, Shoot fluid level 6636 ft 4344.64 172.45 1764.78 55.77 1541.53 12 6636.00 3.25 30.00 08:43:00;Open to 12/64 4347.93 172.45 1766.53 55.23 1541.66 12 Phillips Petroleum Sunfish//3 DST #2 HALLIBURTON ENERGY SERVICES Well Test Summary Page No. 1.5.3 Time Remarks Bhp Bht Whp Wht Casing Choke Fluid Level Influx Influx Increment Rate (psia) (de~f) (psis) (de~f) (psi~l) (64ths) (ft MD) (bbl) (bpd) 29-Mar-94 08:49:00 :Change choke to 14/64 4336.82 172.45 1755.53 54.90 1541.41 14 09:10:00 IChange choke to 16/64 3909.98 172.47 1395.03 57.48 1533.28 16 10:38:00 Shut in for fluid level 2503.83 172.54 184.23 52.53 1511.78 16 10:39:00 Open well to 16/64, Fluid level 6320 ft 2501.54 172.55 182.01 52.40 1511.78 16 6320.00 2.32 27.84 11:45:00 Download RT-91 Data 2369.36 172.71 36.08 49.99 1510.53 16 12:55:00 Unlatch RT-91, Pull out of hole 4.58 47.40 1510.41 16 14:05:00 At surface w/RT-91 3.51 46.15 1510.78 16 14:08:00 Swab valve closed, rig down tool 3.51 45.97 1510.78 16 14:44:00 Start to cycle OMNI 4.93 46.21 1043.16 16 15:00:00 OMNI to 1st blank position, Start filling tubing 9.56 45.68 1620.03 16 ! 15:25:00 ;Tubing loaded w/43 bbl -6.69 48.32 0.00 16 5850.00 3.45 17.43 15:31:00 Cycle OMNI 36.26 52.25 956.53 16 15:38:00 OMNI to Circulating Position 122.83 54.08 47.70 16 Fluid level 15:40:00 Open well to 24/64 choke 76.23 53.46 6.80 24 -- estimated from 15:41:00 Start Reverse Out 70.51 53.26, 3.31 24 the 15:46:00 Open to 32/64 choke 240.61 56.38 263.53 32 43 bbl_r~luired to 16:33:00 Open to 36/64 231.81 58.14 263.66 36 16:39:00 Finish Reverse Out, End Test 250.06 58.33 305.53 36 Phillips Petroleum Sunfish #3 DST #2 HALLIBURTON ENERGY SERVICES Sample Descriptions Page No. 1.6 i ! pH i CI Sample Description Sample i Time BBL , I (ppm) !l~l Returned Samples retrieved from Reverse Out 3-29-94 1 16:05 351 7.00 10500 Water 2 16:10! 431 7.00 11500 10-15% Oil 3 16:131 49-54} 7.00 11500 10-15% Oil 4 16:20 58-62 7.00 11500 10-15% Oil 16:28 68-71~ 7.00 11000 10-15% Oil 6 16:37 78-82 7.00 10500 Trace Oil 7 16:42 85-89! 7.00 10500 Trace Oil 8 16:45 89.5-91t 7.00 10500 Water I Samples retrieved from Downhole lest Tools 3-~0-94 9 1 :OOi i 10.00 8?00 Water 10, 1:101 i 10.00 71 O0 Water 11! 1:201 i 10.00 7400 Water !Sample descriptions are visual estimates from sample bottles ! , Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 2.1 Gauge No. 10780 Gauge Depth 12347' MD 14000 12000 10000 8000 6000 4000 2000 Test Tubing Guns Buildup / Initial Flow 2 3/28 6:00 3/28 12:00 3/28 18:00 3/29 0:00 3/29 6:00 3/29 12-00 3/29 18:00 3/30 0:00 210 180 150 120 90 6O 30 0 3/30 6'00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.1 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 28-Mar-94 Data Print Frequency: 09:55:14 10.906 54.122 09:55:24 10.869 54.142 09:55:34 10.805 54.162 09:55:44 10.786 54.182 09:55:54 10.784 54.202 11:39:10 70.546 58.142 12:19:10 142.568 59.700 12:47:10 235.798 66.562 12:51:10 312.675 69.175 12:55:10 385.208 70.943 12:59:10 439.907 72.157 13:07:10 557.193 73.622 13:11:10 637.049 74.526 13:15:10 727.100 75.221 13:19:10 811.605 76.208 13:23:10 887.484 77.195 13:27:10 962.100 77.953 13:31:10 1047.239 78.805 13:35:10 1123.135 79.997 13:39:10 1201.710 81.188 13:43:10 1280.426 82.477 13:47:10 1352.781 84.032 13:51:10 1432.479 85.586 13:55:10 1532.345 87.228 13:59:10 1604.036 88.759 14:11:10 7506.857 91.513 14:15:10 1659.237 89.754 14%23:10 1759.470 92.105 14:27:10 1832.631 94.204 14:31:10 1940.090 95.970 14:35:10 2014.278 96.265 14:39:10 2119.764 99.901 14:43:10 2204.071 102.492 14:47:10 2284.220 104.237 14:51:10 2367.873 106.461 14:55:10 2475.999 108.471 14:59:10 2550.153 110.480 15:03:10 2646.101 112.664 15:07:10 2738.180 115.184 15:11:10 2857.132 117.214 15:15:10 2908.549 119.243 15:19:10 2997.668 121.149 15:23:10 3079.087 123.054 15:27:10 3138.642 124.700 15:31:10 6860.893 125.575 15:35:10 7559.578 125.134 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.2 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 28-Mar-94 Data Print Frequency: 15:39:10 3146.460 125.040 15:43:10 3198.288 125.482 15:47:10 3267.339 127.328 15:51:10 3363.883 129.432 15:55:15 3468.563 131.594 15:57:15 3520.937 132.716 15:59:15 3577.752 133.801 16:02:15 3640.772 135.662 16:04:15 3691.450 136.807 16:07:15 3773.472 138.843 16:10:15 3862.493 140.884 16:14:45 3939.490 143.590 16:17:15 3993.343 144.958 16:19:45 4046.318 146.327 16:23:15 4112.562 147.886 16:26:15 4166.384 149.500 16:28:15 4233.726 150.622 16:31:15 4301.412 152.113 16:34:45 4369.852 154.177 16:37:45 4451.970 155.798 16:40:45 4521.519 156.950 16:43:45 4595.404 158.672 16:47:15 4654.305 160.370 16:49:15 4716.245 161.419 16:50:45 4767.202 162.291 16:55:15 4848.942 166.004 16:59:15 4925.442 168.761 17:06:15 5028.856 170.517 17:06:45 4971.309 170.524 17:18:15 4912.972 169.769 17:34:45 4939.703 170.109 17:35:15 4952.304 170.216 18:21:45 5076.636 171.113 18:22:15 5215.855 171.144 18:22:45 5186.203 171.130 18:23:15 5133.796 171.116 18:24:45 5523.508 171.158 18:25:15 5955.384 171.228 18:25:45 6383.646 171.298 18:26:15 6813.273 171.334 18:26:45 7244.445 171.369 18:27:15 7676.413 171.404 18:27:45 8107.356 171.440 18:28:15 8537.260 171.467 18:28:45 8965.295 171.494 18:29:15 9391.254 171.521 Gauge Depth: 12347.00 ft COMMENTS Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.3 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 28-Mar-94 Data Print Frequency: 18:29:45 9816.101 171.548 18:30:15 10238.634 171.576 18:30:45 10304.012 171.520 18:31:45 10583.818 171.506 18:32:15 11007.972 171.547 18:32:45 11428.336 171.589 18:33:15 11845.875 171.630 18:33:45 12264.150 171.672 18:34:15 12675.986 171.713 18:34:45 12809.460 171.674 18:36:15 12699.753 171.555 18:36:45 11110.557 171.167 18:37:15 9680.584 170.907 18:37:45 8458.625 170.798 18:38:15 7436.109 170.690 18:38:45 6601.662 170.687 18:39:15 5946.817 170.684 18:39:45 5464.744 170.738 18:40:15 5152.043 170.791 18:40:45 5012.272 170.845 18:41:15 4979.104 170.897 18:41:45 4943.903 170.949 18:42:15 4971.357 171.000 21:35:15 5005.908 172.085 21:36:15 4929.941 172.170 21:37:45 4955.293 172.154 22:56:45 4982.185 172.431 23:48:45 4995.103 172.467 23:49:15 5031.325 172.500 23:49:45 5552.526 172.701 23:50:15 5583.217 172.710 23:50:45 5596.178 172.719 23:52:15 5606.438 172.746 23:55:45 5625.530 172.806 23:56:15 5681.143 172.811 23:56:45 5733.604 172.817 23:57:15 5784.866 172.823 23:58:15 5886.246 172.834 23:59:15 5987.001 172.845 29-Mar-94 00:00:15 00:01:15 00:01:45 00:02:45 00:03:45 00:04:45 6087.837 172.857 6189.256 172.868 6240.241 172.874 6342.949 172.878 6446.938 172.883 6552.125 172.887 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.4 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 00:05:45 6658.459 172.892 00:06:45 6765.933 172.897 00:07:45 6875.361 172.901 00:08:45 6985.612 172.906 00:09:45 7097.344 172.910 00:10:45 7210.945 172.915 00:11:45 7325.848 172.920 00:12:45 7442.121 172.924 00:13:45 7560.020 172.929 00:14:45 7679.367 172.930 00:15:45 7800.067 172.931 00:16:45 7922.482 172.932 00:17:15 7984.726 172.933 00:18:15 8108.493 172.934 00:19:15 8234.040 172.935 00:20:15 8361.415 172.936 00:21:15 8490.387 172.938 00:22:15 8621.063 172.939 00:23:15 8753.299 172.940 00:24:15 8887.358 172.941 00:25:15 9023.266 172.942 00:26:15 9160.975 172.944 00:26:45 9191.442 172.944 00:27:45 9169.059 172.945 00:28:15 8740.318 172.846 00:29:15 8696.161 172.864 00:29:45 8425.886 172.812 00:30:15 8075.964 172.760 00:30:45 7768.784 172.709 00:31:15 7490.187 172.693 00:31:45 7214.933 172.677 00:32:15 6994.556 172.661 00:32:45 7013.645 172.700 00:33:15 7031.546 172.739 00:33:45 7036.097 172.778 00:34:15 7033.674 172.783 00:34:45 7032.759 172.789 00:35:45 7036.274 172.800 00:36:15 6942.784 172.806 00:36:45 6965.734 172.812 00:37:15 6971.843 172.789 00:38:15 6975.228 172.743 00:38:45 6847.605 172.720 00:39:15 6531.783 172.625 00:39:45 6088.381 172.530 00:40:15 5875.962 172.531 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.5 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 00:40:45 5761.367 172.531 00:41:15 5742.723 172.561 00:41:45 5746.963 172.590 00:42:15 5756.119 172.620 00:42:45 5762.824 172.626 00:43:15 5766.900 172.633 00:43:45 5764.375 172.640 00:45:15 5768.315 172.660 00:46:15 5770.353 172.673 00:46:45 5771.205 172.680 00:47:45 5772.613 172.682 00:48:15 5773.173 172.683 00:48:45 5772.423 172.684 00:49:45 5773.797 172.686 00:51:15 5775.512 172.690 00:52:45 5776.389 172.693 00:53:15 5786.013 172.694 00:53:45 5778.736 172.695 00:54:15 5775.086 172.696 00:56:45 5778.172 172.701 00:57:45 5778.782 172.703 00:58:45 5769.791 172.705 00:59:15 5774.762 172.706 00:59:45 5782.275 172.708 01:00:15 5726.765 172.709 01:00:45 5753.890 172.710 01:01:15 5771.734 172.711 01:02:15 5727.857 172.713 01:02:45 5745.508 172.662 01:03:15 5766.312 172.611 01:04:15 5809.814 172.509 01:05:15 5849.772 172.408 01:05:45 5868.666 172.357 01:06:45 5904.002 172.348 01:07:15 5921.256 172.344 01:08:15 5951.750 172.336 01:08:45 5966.182 172.331 01:09:15 5980.226 172.335 01:10:15 6007.448 172.341 01:11:15 6033.872 172.347 01:12:15 6059.103 172.354 01:13:15 6083.062 172.360 01:14:15 6106.038 172.367 01:15:15 6127.697 172.373 01:16:15 6148.163 172.379 01:17:15 6168.717 172.386 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.6 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 01:18:15 6188.851 172.392 01:19:15 6208.200 172.399 01:20:15 6226.426 172.405 01:21:15 6243.616 172.411 01:22:15 6260.089 172.418 01:23:15 6275.588 172.424 01:24:15 6290.314 172.431 01:25:15 6304.853 172.437 01:26:15 6318.799 172.443 01:27:15 6332.566 172.450 01:28:15 6346.831 172.456 01:29:15 6359.589 172.463 01:30:15 6371.888 172.469 01:31:15 6386.268 172.475 01:31:45 6394.600 172.479 01:32:15 6401.590 172.482 01:33:15 6412.343 172.488 01:34:15 6422.593 172.495 01:35:15 6432.575 172.501 01:36:15 6441.987 172.508 01:37:15 6451.540 172.514 01:38:15 6460.344 172.516 01:39:15 6469.023 172.519 01:40:15 6477.581 172.521 01:41:15 6486.055 172.524 01:42:15 6494.379 172.526 01:43:15 6502.624 172.528 01:44:15 6510.768 172.531 01:45:45 6522.496 172.535 01:46:45 6529.787 172.539 01:47:45 6536.812 172.542 01:48:45 6543.609 172.545 01:49:45 6550.231 172.548 01:50:45 6556.601 172.552 01:51:45 6562.823 172.555 01:52:45 6568.940 172.558 01:53:45 6574.768 172.562 01:54:45 6580.364 172.565 01:55:45 6585.700 172.568 01:56:45 6590.808 172.571 01:57:45 6595.825 172.575 01:59:45 6605.380 172.581 02:01:45 6614.781 172.588 02:03:45 6623.968 172.594 02:05:45 6632.426 172.601 02:07:15 6638.811 172.606 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.7 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 02:09:15 6647.290 172.612 02:11:15 6655.468 172.619 02:13:15 6663.675 172.625 02:15:15 6671.342 172.631 02:17:15 6678.969 172.638 02:19:15 6686.312 172.644 02:21:15 6693.403 172.650 02:23:15 6700.289 172.657 02:25:15 6706.989 172.663 02:27:15 6713.475 172.669 02:29:15 6719.802 172.676 02:31:15 6726.038 172.682 02:33:15 6732.099 172.688 02:35:15 6738.297 172.694 02:37:15 6744.127 172.700 02:39:45 6751.361 172.707 02:41:45 6757.019 172.712 02:43:45 6762.657 172.717 02:45:45 6768.057 172.722 02:47:45 6773.360 172.727 02:50:15 6780.005 172.735 02:52:15 6785.168 172.741 02:54:15 6790.173 172.748 02:57:15 6797.498 172.758 03:00:15 6804.773 172.768 03:03:15 6812.023 172.778 03:06:15 6819.106 172.788 03:09:15 6826.243 172.798 03:12:15 6833.067 172.808 03:15:15 6839.896 172.818 03:18:15 6846.385 172.828 03:21:15 6852.566 172.838 03:24:15 6858.728 172.848 03:27:15 6864.641 172.858 03:30:15 6870.640 172.868 03:33:15 6876.501 172.878 03:36:15 6882.207 172.888 03:39:15 6887.688 172.898 03:42:15 6893.054 172.908 03:45:15 6898.313 172.918 03:49:15 6904.904 172.931 03:53:15 6911.575 172.944 03:57:15 6918.119 172.957 04:01:15 6924.480 172.970 04:05:15 6930.933 172.983 04:09:15 6937.147 172.996 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.8 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 29-Mar-94 Data Print Frequency: 04:13:15 6942.938 173.008 04:17:15 6948.787 173.021 04:21:15 6954.463 173.034 04:25:15 6960.048 173.047 04:29:15 6965.516 173.060 04:33:15 6970.923 173.073 04:37:15 6976.250 173.084 04:41:15 6981.293 173.094 04:45:45 6986.889 173.106 04:50:45 6993.097 173.120 04:55:45 6999.151 173.134 05:00:45 7005.090 173.148 05:05:45 7010.863 173.163 05:10:45 7016.382 173.177 05:15:45 7021.630 173.191 05:20:45 7026.652 173.205 05:25:45 7031.761 173.220 05:30:45 7036.803 173.234 05:36:15 7042.241 173.250 05:42:45 7048.547 173.268 05:48:45 7054.229 173.285 05:54:45 7059.635 173.302 06:00:45 7064.912 173.322 06:02:45 7066.762 173.328 06:03:15 5745.777 172.976 06:03:45 5769.389 173.114 06:04:15 5798.655 173.253 06:04:45 5811.669 173.392 06:18:15 5821.741 173.621 06:20:45 5805.769 173.615 06:21:15 5765.007 173.613 06:21:45 5717.228 173.612 06:22:45 5628.371 173.609 06:23:15 5585.859 173.608 06:24:15 5504.293 173.605 06:25:15 5425.891 173.603 06:35:15 5436.078 173.575 06:42:45 5410.846 173.555 06:43:15 5374.156 173.553 06:43:45 5348.137 173.552 06:44:45 5302.381 173.549 06:45:45 5257.019 173.547 06:46:45 5212.587 173.544 06:47:45 5169.427 173.541 06:48:45 5127.438 173.539 06:49:45 5085.957 173.536 Gauge Depth: 12347.00 ft COMMENTS Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.9 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 06:50:45 5044.909 173.533 06:51:45 5004.863 173.530 06:52:15 4985.065 173.529 06:54:45 4972.571 173.522 06:56:45 4954.821 173.517 06:58:45 4936.916 173.511 07:00:45 4919.559 173.506 07:02:45 4902.676 173.500 07:04:45 4886.197 173.495 07:06:45 4870.066 173.490 07:08:45 4854.435 173.484 07:10:45 4839.007 173.479 07:12:45 4823.660 173.477 07:14:45 4809.132 173.475 07:16:45 4794.379 173.472 07:18:45 4780.131 173.470 07:20:45 4766.354 173.468 07:22:45 4752.561 173.466 07:24:45 4738.685 173.464 07:26:45 4724.702 173.462 07:28:45 4710.519 173.460 07:30:45 4696.936 173.458 07:32:45 4682.699 173.456 07:35:15 4666.512 173.456 07:37:45 4649.422 173.459 07:39:45 4635.786 173.461 07:42:15 4619.612 173.464 07:44:15 4606.445 173.466 07:46:45 4590.822 173.469 07:49:15 4574.499 173.471 07:51:15 4561.699 173.474 07:53:45 4545.825 173.476 07:56:15 4530.705 173.479 07:58:15 4518.383 173.481 08:00:15 4506.377 173.484 08:02:45 4491.320 173.486 08:05:15 4477.178 173.489 08:07:45 4464.194 173.492 08:09:45 4453.975 173.494 08:12:15 4441.284 173.497 08:15:15 4426.965 173.501 08:17:45 4414.925 173.504 08:20:45 4401.323 173.508 08:23:45 4388.120 173.512 08:26:45 4375.588 173.515 08:29:15 4364.716 173.518 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.10 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 08:43:15 4352.157 173.536 08:49:15 4337.002 173.543 08:49:45 4317.487 173.544 08:50:45 4300.222 173.545 08:51:45 4279.383 173.547 08:52:45 4258.699 173.548 08:53:45 4238.161 173.549 08:54:45 4217.745 173.550 08:55:45 4197.578 173.552 08:56:45 4177.406 173.553 08:57:45 4157.365 173.554 08:58:45 4137.680 173.555 08:59:45 4118.111 173.557 09:00:45 4098.468 173.558 09:01:45 4078.977 173.559 09:02:45 4059.710 173.560 09:03:45 4040.619 173.562 09:04:45 4021.629 173.563 09:05:45 4002.794 173.564 09:06:45 3984.040 173.566 09:07:45 3965.297 173.567 09:08:45 3946.806 173.568 09:09:45 3928.422 173.567 09:10:15 3908.973 173.567 09:10:45 3892.074 173.566 09:11:45 3856.638 173.566 09:12:45 3822.160 173.565 09:13:45 3788.381 173.564 09:14:45 3755.469 173.563 09:15:45 3723.363 173.562 09:16:45 3691.733 173.562 09:17:45 3660.881 173.561 09:18:45 3630.349 173.560 09:19:45 3600.715 173.559 09:20:45 3571.948 173.558 09:21:45 3543.679 173.557 09:22:45 3516.389 173.557 09:23:45 3489.253 173.556 09:24:45 3462.489 173.556 09:25:15 3450.055 173.556 09:26:15 3424.251 173.555 09:27:15 3398.782 173.555 09:28:15 3373.894 173.555 09:29:15 3349.600 173.554 09:30:15 3325.821 173.554 09:31:15 3302.472 173.553 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.11 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 29-Mar-94 Data Print Frequency: 09:32:15 3279.816 173.553 09:33:15 3257.412 173.553 09:34:15 3235.457 173.552 09:34:45 3224.699 173.552 09:35:45 3203.606 173.551 09:36:45 3182.854 173.550 09:37:45 3162.517 173.549 09:38:45 3142.859 173.548 09:39:45 3123.372 173.547 09:40:45 3104.641 173.545 09:41:45 3085.755 173.544 09:42:45 3067.986 173.543 09:43:45 3050.297 173.542 09:44:45 3032.683 173.541 09:45:45 3015.597 173.540 09:47:15 2991.194 173.535 09:48:15 2975.250 173.532 09:49:45 2951.840 173.526 09:50:45 2936.983 173.522 09:51:45 2922.226 173.518 09:52:45 2907.752 173.515 09:53:45 2893.539 173.511 09:54:45 2879.683 173.507 09:55:45 2866.217 173.503 09:56:45 2853.038 173.500 09:57:45 2840.053 173.498 09:58:45 2827.553 173.497 09:59:45 2815.135 173.495 10:00:45 2803.122 173.494 10:01:45 2791.231 173.492 10:02:45 2779.653 173.491 10:03:45 2768.626 173.490 10:04:45 2757.761 173.488 10:05:45 2747.121 173.487 10:06:45 2736.748 173.485 10:07:45 2726.582 173.484 10:09:45 2707.094 173.481 10:11:45 2688.244 173.478 10:13:45 2670.512 173.476 10:15:45 2653.590 173.473 10:17:45 2637.535 173.470 10:19:45 2622.179 173.467 10:21:45 2607.385 173.464 10:23:45 2593.454 173.461 10:25:45 2580.329 173.459 10:27:45 2567.897 173.456 Gauge Depth: 12347.00 ft COMMENTS Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.12 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 29-Mar-94 Data Print Frequency: 10:29:45 2555.974 173.453 10:30:45 2550.265 173.451 10:31:45 2544.686 173.450 10:32:45 2539.260 173.449 10:33:45 2533.978 173.447 10:34:45 2528.848 173.446 10:35:45 2524.092 173.444 10:36:45 2519.208 173.443 10:37:45 2514.462 173.441 10:38:15 2512.141 173.441 10:38:45 2510.799 173.443 10:39:15 2511.817 173.444 10:40:15 2507.702 173.448 10:41:15 2503.253 173.452 10:42:15 2498.930 173.456 10:43:15 2494.726 173.459 10:44:15 2490.599 173.463 10:45:15 2486.593 173.467 10:46:15 2482.776 173.470 10:47:15 2479.023 173.474 10:48:15 2475.350 173.478 10:49:15 2471.842 173.482 10:50:15 2468.354 173.485 10:51:15 2465.007 173.489 10:52:15 2461.754 173.493 10:53:15 2458.565 173.496 10:54:15 2455.450 173.500 10:55:15 2452.363 173.505 10:56:15 2449.302 173.511 10:57:15 2446.355 173.516 10:58:15 2443.450 173.521 10:59:15 2440.775 173.527 11:00:15 2438.164 173.532 11:01:15 2435.493 173.537 11:02:15 2433.128 173.543 11:03:15 2430.765 173.548 11:04:15 2428.499 173.553 11:05:15 2426.254 173.559 11:06:15 2424.182 173.564 11:07:15 2422.186 173.569 11:08:15 2420.208 173.575 11:09:15 2418.363 173.580 11:09:45 2417.409 173.583 11:10:45 2415.556 173.586 11:11:45 2413.864 173.590 11:12:45 2412.177 173.594 Gauge Depth: 12347.00 ft COMMENTS Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.13 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 11:13:45 11:14:45 11:15:15 11:16:15 11:17:15 11:18:15 11:19:15 11:20:15 11:21:15 11:22:15 11:23:15 11:24:15 11:25:15 11:26:15 11:27:15 11:28:15 11:29:15 11:30:15 11:31:15 11:32:15 11:33:15 11:34:15 11:35:15 11:36:15 11:37:45 11:38:45 11:39:45 11:40:45 11:41:45 11:42:45 11:44:15 11:45:15 11:46:45 11:49:15 11:50:45 11:52:15 11:55:15 11:57:15 12:02:45 12:25:45 12:29:45 12:33:45 12:37:15 12:40:15 12:43:15 12:46:15 Data Print Frequency: 2410.564 173.598 2409.013 173.601 2408.230 173.603 2406.701 173.608 2405.221 173.613 2403.818 173.617 2402.417 173.622 2401.117 173.627 2399.774 173.631 2398.540 173.636 2397.265 173.641 2396.093 173.645 2394.971 173.650 2393.883 173.655 2392.782 173.660 2391.764 173.664 2390.782 173.669 2389.799 173.674 2388.895 173.678 2388.005 173.683 2387.145 173.688 2386.335 173.693 2385.552 173.697 2384.816 173.702 2383.681 173.709 2382.972 173.714 2382.377 173.718 2381.737 173.723 2381.105 173.728 2380.496 173.732 2379.636 173.740 2379.074 173.744 2378.342 173.751 2377.231 173.763 2376.591 173.770 2376.056 173.777 2375.165 173.791 2374.658 173.801 2373.859 173.827 2374.435 173.935 2375.075 173.955 2375.876 173.975 2376.670 173.992 2377.442 174.006 2378.253 174.020 2379.167 174.034 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.14 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 12:49:15 2380.170 174.049 12:52:15 2381.295 174.063 12:54:15 2382.120 174.072 12:57:15 2380.549 174.086 12:57:45 2382.305 174.088 13:00:45 2382.872 174.102 13:04:45 2381.317 174.121 13:10:15 2381.892 174.147 13:12:45 2382.424 174.158 13:17:15 2383.019 174.179 13:21:15 2383.787 174.197 13:24:45 2384.578 174.212 13:28:45 2385.471 174.230 13:32:15 2381.552 174.245 13:32:45 2383.455 174.248 13:34:15 2384.056 174.254 13:35:15 2384.559 174.259 13:36:45 2385.347 174.265 13:38:15 2386.145 174.272 13:39:15 2386.652 174.276 13:40:45 2387.514 174.283 13:42:15 2388.342 174.290 13:44:15 2389.333 174.298 13:45:45 2390.205 174.305 13:47:15 2390.893 174.312 13:48:45 2391.753 174.319 13:49:45 2392.269 174.323 13:50:45 2392.816 174.327 13:51:45 2393.398 174.332 13:52:45 2393.973 174.336 13:54:45 2394.994 174.345 13:56:15 2395.781 174.352 13:58:15 2396.781 174.361 14:00:15 2397.851 174.370 14:01:45 2398.648 174.377 14:02:45 2399.166 174.382 14:04:15 2399.937 174.389 14:05:15 2400.550 174.394 14:06:45 2401.355 174.401 14:08:15 2402.085 174.408 14:09:45 2402.875 174.415 14:10:45 2403.488 174.419 14:11:45 2404.028 174.424 14:13:15 2404.783 174.431 14:14:15 2405.375 174.436 14:15:45 2406.191 174.440 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.15 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 14:17:15 2406.951 174.444 14:18:15 2407.490 174.447 14:19:45 2408.284 174.452 14:21:15 2409.009 174.456 14:22:15 2409.585 174.459 14:23:15 2410.186 174.462 14:24:45 2410.966 174.466 14:25:45 2411.509 174.469 14:27:15 2412.301 174.473 14:28:15 2412.802 174.476 14:29:45 2413.563 174.480 14:32:15 2414.771 174.487 14:33:45 2415.576 174.492 14:34:45 2416.095 174.495 14:36:15 2416.818 174.499 14:37:15 2417.331 174.502 14:38:45 2418.056 174.506 14:40:15 2418.767 174.510 14:41:15 2419.385 174.513 14:42:15 2420.179 174.516 14:43:15 2421.040 174.519 14:44:15 2431.640 174.522 14:45:15 2464.244 174.463 14:45:45 2479.371 174.433 14:46:15 2421.295 174.485 14:46:45 2422.838 174.537 14:47:15 2436.925 174.508 14:47:45 2456.405 174.478 14:48:15 2417.170 174.448 14:48:45 2425.439 174.499 14:49:15 2423.977 174.551 14:49:45 2441.218 174.517 14:50:15 2459.841 174.483 14:50:45 2418.203 174.449 14:51:15 2427.678 174.497 14:51:45 2424.932 174.545 14:52:15 2437.869 174.524 14:52:45 2456.279 174.504 14:53:15 2473.450 174.484 14:53:45 2429.971 174.464 14:54:45 2428.218 174.562 14:55:15 2439.724 174.526 14:55:45 2458.885 174.490 14:56:15 2448.253 174.454 14:56:45 2431.855 174.478 14:57:15 2429.688 174.502 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.16 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 14:57:45 2437.624 174.527 14:58:15 2457.057 174.485 14:58:45 2475.197 174.444 14:59:15 2435.513 174.480 14:59:45 2434.358 174.516 15:00:15 2432.697 174.526 15:00:45 2446.392 174.536 15:01:15 2465.532 174.491 15:01:45 2482.488 174.447 15:02:45 2513.960 174.444 15:03:45 2545.147 174.442 15:04:45 2576.156 174.439 15:05:15 2591.701 174.438 15:05:45 2607.193 174.440 15:06:15 2623.073 174.442 15:07:15 2653.947 174.446 15:08:15 2685.224 174.450 15:09:15 2716.509 174.455 15:10:15 2747.815 174.459 15:11:15 2779.387 174.463 15:12:15 2810.908 174.467 15:13:15 2843.091 174.471 15:14:15 2874.837 174.475 15:14:45 2890.794 174.477 15:15:45 2923.093 174.489 15:16:45 2955.421 174.500 15:17:45 2987.710 174.512 15:18:45 3019.986 174.523 15:19:45 3052.620 174.534 15:20:15 3074.998 174.540 15:21:15 3107.075 174.551 15:22:15 3139.934 174.563 15:23:15 3172.935 174.574 15:24:15 3206.223 174.586 15:25:15 3239.565 174.597 15:26:15 3272.745 174.609 15:27:15 3305.743 174.620 15:27:45 3323.534 174.626 15:28:45 3356.365 174.637 15:29:45 3389.105 174.648 15:30:15 3405.916 174.659 15:30:45 3377.357 174.670 15:31:15 3393.636 174.716 15:32:15 3429.102 174.807 15:32:45 3443.654 174.853 15:33:45 3477.436 174.782 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.17 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 15:34:15 3494.024 174.746 15:34:45 3508.847 174.807 15:35:15 3525.523 174.868 15:36:.15 3557.309 174.991 15:36:45 3572.719 175.004 15:37:15 3586.930 175.017 15:37:45 3601.361 174.959 15:38:45 3632.407 174.844 15:39:15 3647.818 174.786 15:40:15 3678.668 174.793 15:41:15 3709.364 174.800 15:42:15 3739.575 174.808 15:43:15 3769.561 174.819 15:44:15 3799.223 174.830 15:45:15 3828.649 174.842 15:45:45 3843.338 174.847 15:46:15 3857.741 174.846 15:47:15 3887.446 174.843 15:47:45 3902.163 174.841 15:48:45 3931.288 174.850 15:49:45 3960.063 174.859 15:50:45 3988.759 174.868 15:51:45 4017.339 174.876 15:52:45 4045.335 174.885 15:53:45 4073.103 174.894 15:54:45 4100.396 174.903 15:55:45 4127.538 174.911 15:56:45 4154.134 174.920 15:57:45 4180.690 174.929 15:58:45 4207.030 174.938 15:59:45 4232.296 174.946 16:00:45 4257.343 174.955 16:01:45 4282.346 174.964 16:02:45 4307.691 174.973 16:03:45 4332.053 174.982 16:04:45 4356.117 174.990 16:05:45 4380.349 174.999 16:06:45 4404.080 175.008 16:07:45 4427.784 175.017 16:08:45 4451.384 175.025 16:09:45 4474.716 175.034 16:10:45 4497.546 175.043 16:11:45 4519.794 175.052 16:12:45 4541.422 175.061 16:13:45 4562.541 175.069 16:14:45 4583.777 175.078 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.18 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 16:15:45 4604.283 175.087 16:16:45 4624.422 175.096 16:17:45 4644.238 175.104 16:18:45 4663.770 175.113 16:19:45 4683.541 175.122 16:20:45 4703.136 175.131 16:21:45 4723.220 175.140 16:22:15 4733.068 175.144 16:22:45 4742.765 175.147 16:23:45 4760.964 175.154 16:24:45 4779.454 175.160 16:25:45 4797.382 175.167 16:26:45 4815.934 175.173 16:27:45 4834.604 175.180 16:28:45 4853.302 175.187 16:29:15 4862.352 175.190 16:30:15 4879.624 175.195 16:31:15 4897.176 175.201 16:32:15 4913.978 175.206 16:33:15 4930.215 175.212 16:34:15 4947.385 175.217 16:35:15 4963.420 175.223 16:36:15 4979.894 175.228 16:37:15 4996.130 175.234 16:38:15 5012.381 175.239 16:39:15 5028.978 175.245 16:40:15 5045.315 175.250 16:41:15 5060.692 175.256 16:42:15 5076.159 175.261 16:43:15 5091.770 175.267 16:44:15 5106.687 175.272 16:45:15 5121.747 175.278 16:46:15 5136.656 175.283 16:47:15 5151.679 175.289 16:48:15 5166.893 175.294 16:48:45 5173.753 175.297 16:49:15 5179.280 175.300 16:50:15 5193.721 175.300 16:50:45 5200.411 175.300 16:51:45 5214.942 175.301 16:52:45 5228.102 175.302 16:53:15 5234.953 175.302 16:54:15 5249.331 175.307 16:55:15 5262.763 175.313 16:56:15 5276.234 175.318 16:57:15 5289.186 175.324 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.19 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 16:58:15 5302.077 175.329 16:59:15 5315.322 175.334 17:00:15 5328.997 175.340 17:01:15 5342.688 175.345 17:02:15 5355.843 175.351 17:03:15 5368.067 175.356 17:04:15 5379.887 175.361 17:05:15 5392.061 175.367 17:06:15 5403.787 175.372 17:07:15 5416.027 175.378 17:08:15 5427.805 175.383 17:09:15 5439.283 175.389 17:10:15 5450.858 175.394 17:11:15 5462.257 175.399 17:12:15 5473.708 175.405 17:13:15 5485.317 175.410 17:14:15 5496.817 175.416 17:15:15 5508.268 175.421 17:16:15 5519.152 175.426 17:17:15 5528.736 175.432 17:18:15 5539.035 175.437 17:18:45 5544.061 175.440 17:19:15 5464.064 175.443 17:19:45 5476.847 175.445 17:20:15 5487.230 175.448 17:21:15 5504.838 175.465 17:22:15 5519.453 175.482 17:23:15 5532.571 175.500 17:23:45 5538.963 175.508 17:24:15 5519.413 175.517 17:25:45 5539.220 175.543 17:26:45 5552.896 175.560 17:27:45 5565.438 175.577 17:28:45 5577.413 175.594 17:29:45 5588.852 175.611 17:30:45 5600.121 175.629 17:31:45 5611.043 175.646 17:32:45 5621.761 175.663 17:33:45 5632.278 175.680 17:34:45 5642.180 175.697 17:35:45 5651.672 175.701 17:36:45 5661.058 175.705 17:37:45 5670.599 175.709 17:39:15 5684.039 175.715 17:40:15 5693.678 175.718 17:41:15 5703.121 175.722 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.20 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 17:42:15 5712.261 175.726 17:43:45 5724.432 175.733 17:44:45 5733.590 175.738 17:45:45 5742.601 175.743 17:46:15 5544.653 175.677 17:46:45 4942.339 175.466 17:47:15 4994.075 175.368 17:47:45 4959.287 175.270 17:48:15 4920.973 175.172 17:48:45 4931.296 175.074 17:49:15 4946.726 175.022 17:49:45 4938.686 174.970 17:50:15 4931.816 174.919 17:51:15 4939.312 174.884 18:21:45 4930.801 174.811 18:22:15 4923.718 174.700 18:31:45 4915.219 174.079 18:32:15 4900.846 174.073 18:32:45 4909.886 173.989 18:34:45 4901.895 173.652 18:35:45 4911.075 173.477 18:36:45 4905.434 173.383 18:39:15 4919.399 173.269 18:39:45 4910.924 173.252 18:40:15 4897.722 173.221 18:41:15 4906.543 173.160 18:42:15 4898.970 173.099 18:42:45 4884.315 172.881 18:43:15 4889.600 172.663 18:43:45 4850.121 172.321 18:44:15 4845.097 171.576 18:44:45 4853.025 171.040 18:45:15 4821.565 170.658 18:46:15 4816.072 169.655 18:47:15 4764.145 169.053 18:48:15 4775.247 168.467 18:48:45 4728.889 168.251 18:50:45 4723.875 167.113 18:51:15 4691.412 166.755 18:52:15 4651.768 166.256 18:52:45 4661.558 166.007 18:53:45 4641.184 165.533 18:54:15 4636.132 165.296 18:54:45 4610.499 165.060 18:55:15 4579.633 164.823 18:57:15 4538.831 163.914 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.21 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 18:57:45 4549.205 163.686 18:58:15 4542.035 163.459 18:58:45 4505.313 163.231 18:59:15 4510.462 163.004 19:00:45 4465.262 162.376 19:01:15 4478.407 162.105 19:01:45 4470.054 161.835 19:02:15 4449.525 161.595 19:02:45 4443.539 161.355 19:03:15 4432.859 161.100 19:04:15 4423.135 160.629 19:04:45 4393.732 160.321 19:05:45 4361.880 159.911 19:06:15 4371.754 159.648 19:07:15 4323.992 159.148 19:07:45 4318.781 158.911 19:08:15 4331.367 158.663 19:08:45 4300.831 158.416 19:09:15 4294.917 158.168 19:09:45 4289.503 157.848 19:10:15 4264.668 157.604 19:10:45 4257.838 157.360 19:12:15 4230.401 156.544 19:13:45 4178.225 155.714 19:14:15 4202.194 155.424 19:14:45 4191.986 155.134 19:15:15 4160.248 154.898 19:15:45 4167.363 154.661 19:16:15 4151.735 154.335 19:17:15 4129.354 153.894 19:17:45 4117.069 153.534 19:18:45 4080.796 153.060 19:19:15 4069.516 152.750 19:19:45 4083.841 152.439 19:20:15 4041.575 152.184 19:20:45 4049.314 151.929 19:21:15 4030.946 151.603 19:21:45 4047.477 151.382 19:22:15 4022.547 151.161 19:22:45 4010.020 150.860 19:23:45 3960.490 150.345 19:24:15 3973.854 150.026 19:24:45 3967.864 149.707 19:25:15 3953.401 149.478 19:25:45 3937.057 149.151 19:26:15 3942.889 148.824 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.22 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 19:26:45 3918.179 148.548 19:27:15 3897.185 148.272 19:28:15 3859.049 147.693 19:28:45 3864.913 147.436 19:29:45 3873.316 146.854 19:30:15 3836.236 146.617 19:30:45 3819.982 146.240 19:31:15 3834.211 145.975 19:31:45 3812.104 145.709 19:32:15 3793.392 145.444 19:32:45 3801.584 145.181 19:33:15 3761.768 144.918 19:33:45 3745.515 144.628 19:34:15 3757.482 144.338 19:35:15 3727.653 143.800 19:35:45 3712.105 143.405 19:36:15 3718.961 143.146 19:36:45 3674.196 142.888 19:37:15 3682.769 142.539 19:38:15 3658.006 141.950 19:38:45 3645.051 141.582 19:39:45 3609.141 140.914 19:40:45 3601.268 140.220 19:41:45 3564.637 139.712 19:43:15 3543.873 138.792 19:43:45 3527.334 138.459 19:44:45 3503.693 137.890 19:45:15 3489.597 137.560 19:45:45 3497.337 137.230 19:46:45 3453.895 136.733 19:47:45 3461.314 136.143 19:48:15 3426.946 135.907 19:48:45 3409.972 135.597 19:49:15 3416.629 135.287 19:49:45 3405.008 135.076 19:50:15 3373.045 134.763 19:50:45 3379.243 134.450 19:51:15 3357.911 134.208 19:52:15 3339.241 133.632 19:53:15 3310.518 133.164 19:54:45 3283.602 132.355 19:55:15 3274.213 132.059 19:55:45 3266.205 131.763 19:56:15 3246.304 131.528 19:57:15 3234.083 130.946 19:57:45 3206.470 130.705 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.23 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) 29-Mar-94 19:58:15 19:58:45 19:59:15 19:59:45 20:00:15 20:00:45 20:02:15 20:02:45 20:03:15 20:03:45 20:04:15 20:04:45 20:05:15 20:05:45 20:06:15 20:07:15 20:07:45 20:08:45 20:09:15 20:09:45 20:10:15 20:11:45 20:12:45 20:13:45 20:14:15 20:14:45 20:15:45 20:16:15 20:16:45 20:17:15 20:17:45 20:18:45 20:20:15 20:20:45 20:21:15 20:22:15 20:23:15 20:23:45 20:24:15 20:24:45 20:25:15 20:26:15 20:26:45 20:27:15 20:28:15 20:29:45 Data Print Frequency: 3212.696 130.382 3194.335 130.059 3167.407 129.819 3159.920 129.512 3165.452 129.206 3132.137 128.958 3106.053 128.090 3097.354 127.737 3091.687 127.504 3047.608 127.270 3056.470 126.966 3066.265 126.661 3043.326 126.447 3013.784 126.233 3021.993 125.965 2974.687 125.458 2985.267 125.128 2952.778 124.659 2947.132 124.311 2940.418 124.057 2904.063 123.802 2866.376 122.920 2843.490 122.271 2828.081 121.637 2809.229 121.392 2787.067 121.042 2759.746 120.440 2775.055 120.087 2758.574 119.734 2738.644 119.500 2727.772 119.164 2695.419 118.549 2666.459 117.626 2656.028 117.351 2646.982 116.953 2606.347 116.403 2614.244 115.714 2569.210 115.427 2575.986 115.019 2566.961 114.717 2532.385 114.415 2517.662 113.739 2506.944 113.454 2491.431 113.076 2457.081 112.539 2413.431 111.608 Gauge Depth: 12347.00 ft COMMENTS Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.24 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 20:30:15 2419.392 111.220 20:30:45 2394.660 110.916 20:32:15 2360.256 109.940 20:32:45 2350.612 109.642 20:33:45 2321.961 108.976 20:34:15 2316.270 108.684 20:35:15 2285.804 108.042 20:35:45 2270.604 107.682 20:36:15 2277.867 107.322 20:36:45 2238.087 107.057 20:37:45 2231.834 106.310 20:38:15 2186.879 106.037 20:38:45 2195.858 105.675 20:39:45 2166.041 105.045 20:40:15 2151.832 104.655 20:40:45 2143.852 104.367 20:41:15 2118.762 104.080 20:41:45 2111.747 103.711 20:42:15 2085.207 103.446 20:43:15 2073.838 102.693 20:43:45 2060.979 102.387 20:44:15 2038.855 101.892 20:44:45 2016.524 101.504 20:45:45 2010.867 100.620 20:46:15 1988.230 100.263 20:47:15 1970.931 99.548 20:47:45 1924.700 99.284 20:48:15 1940.821 99.019 20:49:15 1883.311 98.533 20:49:45 1902.687 98.311 20:50:15 1888.295 98.089 20:50:45 1856.773 97.867 20:51:45 1826.040 97.437 20:52:15 1813.335 97.229 20:52:45 1822.880 96.994 20:53:15 1794.019 96.758 20:53:45 1784.960 96.522 20:54:15 1748.955 96.266 20:54:45 1742.899 96.010 20:55:15 1753.726 95.716 20:55:45 1713.314 95.422 20:56:45 1666.587 94.662 20:57:15 1676.109 94.281 20:57:45 1670.703 93.900 20:58:15 1628.696 93.520 20:58:45 1635.831 93.093 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.25 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print Frequency: 20:59:15 1611.121 92.759 20:59:45 1596.112 92.330 21:00:15 1581.164 91.994 21:00:45 1571.441 91.658 21:01:15 1566.148 91.312 21:01:45 1532.843 90.966 21:02:15 1522.709 90.620 21:02:45 1500.273 90.316 21:03:15 1485.774 90.012 21:03:45 1491.587 89.708 21:04:15 1458.883 89.405 21:05:15 1414.560 88.705 21:06:15 1398.110 87.962 21:06:45 1382.915 87.579 21:07:45 1339.385 86.895 21:08:15 1332.241 86.480 21:08:45 1315.841 86.150 21:09:15 1301.996 85.820 21:10:15 1270.249 85.155 21:10:45 1276.109 84.823 21:11:15 1233.381 84.529 21:12:15 1227.906 83.942 21:12:45 1195.043 83.649 21:13:45 1161.287 83.075 21:14:15 1151.206 82.788 21:14:45 1124.463 82.548 21:15:15 1116.899 82.308 21:16:15 1076.150 81.828 21:17:15 1051.328 81.348 21:17:45 1033.183 81.108 21:18:45 1001.598 80.659 21:19:45 969.483 80.241 21:20:15 958.152 80.032 21:21:15 916.576 79.724 21:21:45 921.795 79.570 21:22:15 887.988 79.442 21:23:15 882.835 79.186 21:23:45 851.887 79.058 21:24:45 811.894 78.728 21:25:45 805.779 78.398 21:26:15 770.394 78.203 21:27:15 732.884 77.813 21:28:15 707.543 77.423 21:28:45 690.303 77.228 21:29:45 649.234 76.837 21:30:45 616.662 76.530 Date: 28-Mar-94 Ticket No: 462911 Page No: 2.1.26 PRESSURE VS TIME HALLIBURTON Gauge No.: 10780 Memory Recorder No.: 20068 TIME D TIME PRESSURE TEMP HH:MM:SS (hr) (psi) (F) Gauge Depth: COMMENTS 12347.00 ft 29-Mar-94 Data Print 21:31:15 607.734 21:32:15 565.707 21:33:15 529.723 21:33:45 522.815 21:34:45 488.713 21:35:45 462.824 21:36:15 448.808 21:37:15 406.717 21:38:15 399.995 21:38:45 363.011 21:40:15 319.882 21:41:15 291.148 21:41:45 277.069 21:43:15 236.654 21:44:45 207.532 21:45:15 193.635 21:46:45 151.112 21:48:45 146.097 21:52:45 118.934 22:06:45 103.913 22:08:45 88.757 22:17:15 79.645 22:17:45 70.850 22:18:45 54.620 23:14:45 68.984 23:15:15 83.370 23:21:15 77.625 23:30:15 72.170 23:30:45 58.397 23:37:45 49.989 23:38:15 37.621 23:38:45 29.367 23:45:15 23.631 23:49:45 16.544 66.305 64.503 62.117 61.050 59.277 59.064 58.583 58.555 58.520 58.246 58.110 57.362 57.339 57.334 58.232 58.252 58.352 58.592 58.523 Frequency: 76.376 76.087 75.769 75.595 75.205 74.658 74.385 73.771 72.982 72.588 71.607 70.911 70.382 68.727 66.956 30-Mar-94 00:18:15 33.276 59.312 00:18:45 41.034 59.269 00:20:45 33.868 58.739 00:21:45 27.806 58.728 00:30:45 22.257 59.609 00:37:45 17.028 59.569 01:29:45 16.000 59.582 Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 2.2 Gauge No. 10220 Gauge Depth 12347' MD 14000 210 12000 10000 8000 6000 4000 2000 0 3/28 6:00 Test Tubing Guns Buildup Initial Flow Flow 2 180 150 120 = 90 E 60 30 3/28 12:00 3/28 18:00 3/29 0:00 3/29 6:00 3/29 12:00 3/29 18:00 3/30 0:00 3/30 6:00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 2.3 Gauge No. HSRO4 Gauge Depth 12313' MD 14000 12000 Test Tubing 10000 .E 8000 ~ 6000 40OO 2000 0 3/28 6:00 Initial Flow I 3/28 12:00 3/28 18:00 3/29 0:00 Buildup Guns Flow 2 I 3/29 6:00 3/29 12:00 3/29 18:00 3/30 0:00 210 18O 150 120 = 90 c~ E 60 30 0 3/30 6:00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 2.4 Gauge No. HSRO5 Gauge Depth 12313' MD 14000 210 12000 10000 8000 6000 4000 2000 0 3/28 6:00 Test Tubing Initial Fire Guns Buildup Row 2 3/28 12:00 3/28 18:00 3/29 0:00 3/29 6:00 3/29 12:00 3/29 18:00 3/30 0:00 18O 150 120 · 90 ~. E 6O 3O 0 3/30 6:00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 Phillips Petroleum Company Sunfish #3 DST #2 Halliburton Energy Services Pressure/Temperature History Plot Page No. 2.5 Gauge No. HSRO7 Gauge Depth 12313' MD 8000 7000 6000 5000 4000 3000 2000 1000 0 3/28 6:00 Annulus Pres.,,ure Initial 3/28 12:00 3/28 18:00 ,w 3/29 0:00 Buildup I 3/29 6:00 Flow 2 I 3~29 12:00 3/29 18:00 3/30 0:00 210 180 150 60 30 0 3/30 6:00 Plot Start Time: 28-Mar-94 06:00:00 Plot End Time: 30-Mar-94 06:00:00 PHILLIPS/ARCO #3 SUNFISH CORE DESCRIPTIONS CORE # 1 12,285'-12,306' (driller's depths) Cut 21' recovered 21' Lithology: 12,285'-12,287.3' - Shale, olive gray, silty with laminations of very fine sand and silt. 12,287.3'-12,294.75' - Sandstone, fine grained, fair porosity, no show. 1 2,294.75'-12,296' - Shale with sandy laminae 12,296'-12,304.8' - Sandstone, fine grained, fair to poor porosity, no show. 1 2,304.8'-12,306' - Shale, medium gray, silty CORE #2 CORE #3 12,405'-12,465' Cut 60' recovered 56.5' Lithology: 1 2,405'-12,412.5' - Claystone with interbeds of dirty coal. 12,412.5'-12,420.25' - Claystone with laminations of very fine sand at the base. 12,420.25'-12,425' Sandstone- fine grained, poor porosity, no show. 1 2,425'-12,465' - interbedded mudstone, siltstone and very fine to fine sandstone, laminated, sands less than l l~c~;F~il~! I~'~lr porosity, no show. I~,L~ L iV MAY -9 1994 13,628'- 13,641' >.~ask~ u, & Gas Cons. Commission Cut 13' recovered 8.5' Anchorage Assumed missing portion was drilled up at top of core. Lithology: 13,632.5'-13,637.7' - Sandstone, coarse to very coarse grained, fair porosity, even yellow-white fluorescence, oil odor. 13,637.7'-13,641' - Sandstone, fine grained, muddy, laminated with claystone, poor porosity, fluorescence as above, poorest layers are non-fluorescent. CORE #4 13,641'-13,659' Cut 18' recovered 17.5' Lithology: 13,641 '-13,649' - Sandstone, medium to coarse grained, pebbly in part, fair porosity, even yellow-white fluorescence, oil odor. 13,649'-13,658.5' - Pebbly sandstone/conglomerate medium sand to 2 cm pebbles, fair porosity, strong oil show as above. 3.e ro/g~ fluid TOC @ 11,700' 3O"@ 4O7 DV Tool @ 4,045' 59 -- ~? EXISTINg3 WELLBORE DIAC'~-~-~AM .'V(Make.TTpe,OD) Not ~pllcab~ E~-D~II Not ~plicab~ R~-~e 59.~ Annulus ~ui~ 13.6 ib/~al mud ~t~en all cement pluxs R~-SL: T~: WA~R D~PTH: I~ R~-ML: ~t~m ] ~sin~ St~ ~: ~ 457 I~t ] Weird . . 2,~ ~69~ ~ x-~ ~-~u!p . 8,~ ~ I~t 12,1~ P~uction Line~ . 13,~1 ~ lb~t ~ L-~ BT~C I .... ~:..'.~ ............ ~~ ..: ........ CEMENTING SUM ~RY DV Tool 13 3/8' (~ 8,909' TOC @ 11,O<X)' 9 5/8" (~ 12,138 12/18/93 01/16/94 9 5/~ · 02/23/94 7" Casing String 20' 13 3/8" Stage tool @ 7,3&5' Stage tool (~ 4,045' ~ption C. ement~d 20' with 1070 ax 12.8 lb/gal Ciasa "G" with 025 gal/ax D-77, 0.05 gal/ax D-47 and 0.28 gal/ax D-75. Tailed with 600 ax Cla~ "G" mixed at 15.8 lb/gal with 025 gal/ax D-77 and 0.05 gal/ax D-47. Cement circulated to surface. Cemented 1st Stage of 13 3/8" with 900 ax 12.5 lb/gal Ciasa "G" with 1.0 % D-6 and 0.05 gal/ax D-47. Tailed with 700 ax Cla~ "G" mixed at 15.8 lb/gal with 0.05 gal/s~t D-47, 0.5 % D-59, 0.15 gal/ax D-801, 0.4 % D-65, 0.10 % and 025 % S-1. Cemented 2nd Stage of 13 3/8" thru DV tool at 7,385' with 3,700 ax 15.8 lb/gal Class 'G' with 0.1% D-65, 0.1 gal/ax D-47, 0.1% D- 135, I gal/sx D-600 and 0.3 % D-8(X). Cemented 3rd Stage of 13 3/8' thru DV tool at 4,045' with 1,000 ax 15.8 lb/gal Clasa 'G" with 0.2 % D-65, 0.1 gal/ax D-47, 0.1 gal/ax D-135, 1 gal/ax and 0.3 gal/ax D-801. Cemented 9 5/8' with 1,0(}0 ax 15.8 lb/gal Ciasa "G" with 0.1 gal/ax D-47, 0.01 gal/ax D-080, 0.10 gal/ax D- 135, 1.0 gal/ax D-600 and 0.06 gal/sx D-801 Estimated TOC at 11,000'. Cemented 7" linen' with 674 ~ 15.8 lb/gal Cla~ "G" cement with 0.10 gal/ax D-47,130 gal/ax D-600, 0.1 gal/ax D- 135, 0.07 gal/ax D-8 and 0.03 gal/ax D-801. EZb-~V 12,375' P&c~ker & TCP G4Jn$ 12478 - 12502' 1252~- 12538' 14.214' Halco BWD @ 13,4.82' Sunfish Ped~ 135~- 13644' '-~ 13~56-13708' EZSV 13,916~ 7" @ 13,93)' Tolad Depth - 14,705' ABANDONMENT PLUGS Set EZSV Cemcat Rctaincr at 13,916'. Cemented with 70 sx Class 'G". Pumped 58 sx b~low retainer, 12 ax on top of retainer. PBTD 13,866' MD (12,533' TVD). 03/'28/94 7 · Set EZSV Cement Retainer at 13,464' (WL depth). Cemented with 58 sx Class Pumped 50 ax b~low retainer, 8 ax (30') oa top of retainer. Set EZ.SV Cement Retainer at 12,375' (DP depth). Cemented with 68 sx Class Pumped 58 ax b~low retainer, left 100' on top of retainer. TOC ~ 12,275'. 03/31/94 7 · Spot 68 sx Cla~ "G" c~mcnt plug 11,950' - 11,700'. 04/01/94 95/8' S~ 68 ax Clas~ ~ ~n~:~t plug 300' - 500'.ECE/ MAY -9 199 - PBTI~. Well: /,3~ska Oil & Gas Cons. Commission Anchorage lSu _~. I'r'~,wt:, Sunfish No. 3 I April 28, 1994 PRD Lc~.ation: Cook Alaska Field: Cook 12/18/95 8,930 $3~9,96~3 $3,3~30,692 -- CEMENT 3RD STAC~E W/lO00 SX W/ADOITIVES.13 3/8 CC~LETE AT 1630 MRS 12-17-93.gCX:,N/D · ~,~ PHILLIPS PETROLEUM PAGE:2 , DAILY REPORT SUMMARY WELL:Sunfish No. 3 RIG:Pool Arctic ...laska/Pool Arctic Alaska FIELD:COOK INLET AFEf:P-V181 CNTY/STATE:TYONEK OFFSHORE\ALASKA AUTH COST: $13,993,200 DATE DEPTN RPT I~0 ted C~ER. ATIONS SLI~I,~d~Y DAILY COST ~ COST 12/15/93 8,930 ~ 9.8 L~ ~LL ~ / DITE-LOT-CNL-~-~ 8922 TO ~. OSZ-~ ~ S51,~ ~,~,3~ TO 25~.L~ ~. ~/~ a~ TZH F~ CL~ ~T. CZRC.~ ~EP. ~ PILL. ~ F~ CSG. 30 9~8 R~ CSG T~S TO R~ 13 ~/~ CSG. PRE-J~ & ~FETY R~ 8~ 13 3/8 P-110 & ~-~.E~P g/T~IZERS & STA~ ~S PER PR~.R~ CSG & ~NG ~ ~R.S~ ' '3t 9~8'CIRC J C~ F~ JST STA~ CE~T.CEME~T IST STA~ g/~ITI~S.DR~ ~.~LD ~OT ~E~ DV.R~ ~E~ DV.CIRC & ~.CEME~T 2~ STA~ ~/3~ SX W/~ITI~S. ~ 9.7 ~I~LA~ 2~D STA~ ~ME~T.~E~ OV T~.CIRC 12/19193 8,9:T~0 55 9.7 FI~ISH ~IPPLE D~.INSTALL 20" ~ X 13 5/8" 5M CSG SPCX~L. $65,031 N/U 13 5/8" 1~ ~ STACK AND ALL RELATED E~I~ENT. ~2/2~/93 8,930 ~ 9.5 I~ITIAL ~ TEST ~ 13' 5/8" STACK.P~ & M~ BIT f16.TIH TO 4~5.TEST CSG.LEAKED.DR~LL PL~S.RETEST.LE~ED. ~.P~ RTTS.TI~.TEST CSG TO 21~ PS~ ~ 4013.~.~M WRTTS. TIH TO ~'. TEST CSG. TO 2100 PSi. DRILL or. R~H TO ~5' TEST CSG.~ TEST.T~.TZ~ ~/RTTS.TEST UPPER DV.~.TEST L~R DV. INJECT BEL~ L~R OV.RTTS FA~LED ~ ~L~ TEST. ATTESTING TO I~ATE AND IDE~T~FY LE~S lB 13'3/8" CSG. ~ITH RTTS. ~P~ENTLY ~PE~ A~O L~R DY ~S LE~. PREP~E TO ~EZE OV'S AT RE~T T~ME. 8,930 ~2/22/93 8~930 ' S6' '9'.? $50,260'' $3','607,5~., 12/7.3/93 8,Sr50 37 9.7' RUN CSL/VOL AJdO GYRO, RIM WITH RTTS AgO SPOT AgO SQLJ~EZE $54,455 :L3,661,989 50 SX ACROSS LOI,/ER DV AND 100 SX ACROSS U~R OV COLLAR. WOC AT REPORT TINE. 12/24/93 8,9:~0 3~ 9.9 tL~IT 014 CEHENT/POOfl LO PACKER/TIll W/DRLG 8~LAJCUT DRLG LI#E $105,8~9 $5,762,828 TEST CSG.(INCONCLU$[VE) POH PICL'IJP RTTS AND RETEST ABOVE LDV TEST GOCO 1. RIG U~ TO SPOT C~T. ACROSS LDV FOR S.Q~EZE. 12/25/93 8,940 59 9.9 SCaJEEZE CEI, IEWT IN LCR.,'ER DV TOOL/~ LO Pr, R/TIN W/DRLG BI{A $90,050 $5,857,878 TO T561/ORLG C;,IT TO ?420/TlH. ORILL (X/T FLOAT EQ. RUB F.I.T. TO 14.8 PPG F.I~. CLEAN PITS AND CF, ANGE OJT NLO SYSTEM. 12/26/93 8,940 &O 9.? ~IXING NEW leX) SYSTEM/ $65,395 S3,923,27'5 · ~2/27/93 9,112 41 9.8 C~b~lG~ OVER /~ SYSTEM, DRILL 8~40i 'TO 9112' PON FOR BOP $65,825 $3,98~,0'98 TEST AND MLO MOTOR A~O i~. (DIRECTIONAL CORRECTZOR) 12/28/93 9,:T1~3 42 9.? TEST I~/TIH/DRILL[NG W/MUD MOTOR 9112 - 9315/S~K~RT TRIP $4,053,856 STOS INTO CSG/ORILLI#G 9315 - 93~3 "12/29/93 9,660 /,3' ' 9.7 DRILLING FRCI~ 93~3 TO 9660. $56,7¢3 t~,110,599 12/50/93 9,860 4.4 9.? DRILL AgO SURVEY 12 1/4" HOLE TO 9860, POll FOR lilt AND iii'lA $75,3~>4 :$4,185,965 CllA~. MADE UP BIT #14. CRAGE BRA Rill. ~i~/31/93 10,220 45' 9.7 DRILL AgO S~VEY 12 1//,- HOLE. $55,780 $4,241,743' 01/01/9~ 10,450 4.6 9.7' DRILL AND SURVEY 12 1/4" ttOLE. $56,845 $4,Lx;8,589 ~Z 9.8 DRILL A~O SURVEY 12 1/4" HOLE TO 106~. CSU, PO~ FOR lilt 01/02/94 10,60~ S53,672 0'1/03/94 10,835" ~S 10.0 DRILL AND SURVEY 12:1/4 HOLE TO 10~5 FT. $52,837' ' 01/0~/94 11,09S ''~9 "10.'I DRILL AND SURVEY, MADE 10 STD. SHORT TRIP AT 1~021, ~ S56,431 '$4,~)1,530 TIGHT SPOTS. OR~LL TO 110<75. 01/0S/94. 11,;'01 50 'i0.1 DRILL 11095 TO 11116.TRIP FOR BIT 16 & IiI,(A.t,,'EEKLY 8C~ TEST. $58,901" $4,520,431 TRIP I~ [40LE.DR[LL 11116 TO 11203. 01/06/94 11,370 51 10.0 DRLG 11201 TO 11570. $57,84Z, $4,5~,275 01/07/94 11,4.a5 52 10.0 DRLG 11370-11474(10401 TYO).C~J.TOH FOR BRA C~NGE.P/U & M/U $63,~21 $4,641,696 ~HA ~ & BIT #17. TIN TO 8900.SLIP & CUT 76 LI~E.TI~.DRLG 1167&-114~53. ~'~/08/9~ 11,63~ 53 10:1DRLG 114~33' TO 116Z~3, (10553' TVO). S53,502 $4,695~'197 ~1~09~94' 11,'740 ' 54. 10.'10RLG 1163.8-1165f~10566 TVO).CSU.T~.P/U liMA 24 & alt 18.TZN. $56,5%6 $4,751,743 ORLG 11651-117~0. 01/10/9~ 11,8X,2 55 10.1DRLG 11740-111~x~.C81J.TOtI.L/O RETRIEVABLE le, D TC~S.P/U L~O S6,?.,241 $4,813,98~, TOOLS (BRA 2~ & lit 19).T~#. DATE DEPTH 11/17/93 0 q)AILY REPORT SUMMARY WELLlSUnfish No. 3 MAY-9 1994 RIG:Pool Arctic Alaska/Pool Arctic Alaska FI ELD: COOK INLET AFE/: P-Vl 81 CNTY/STATE: TYON~$~~~~i~i0" AUTH COST: $13,993,200 RPT ~ W ~chorage ~E~TI~S ~Y DALLY ~T ~ ~T 0 2 1 0,0 RIGGING UP ROTARY TOOLS AND RELATED EQUIPMENT TO DRILL THE SUNFISH # 3 NELL FROIq THE TYONEK PLATFORm. NCIU ALASKA. 0.'0 RIGGING UP ROTARY TOOLS. HOOK UP DIVERTER SYSTE# AND ALL 3~3 3 8.7 1/18/93 ~1/19/9] 11/20/9] _ 11/21/93 __ 1,115 2,297 RELATED EI~IIPHENT. RIG UP DIVERTER SYSTEH AND FUHCTION TEST SA~E. HIX SPUD HUO. PICK UP BHA #1. TIH AND TAG UP AT 248'. CLEANING OUT CONDI~TOR PiPE FRON 2'~8~ TO 323'. 8.7 CLEAN CENENT OJT OF 30" TO 406.TOH.P/U BHA # 2 TO KICK OFF. TIH.DRLG U/I~OTOR AND ROTARY FRON &06 TO 1115. 8.9 DIRECTIONAL DRILLING 1115-2297.TRIP FOR BIT # 2. $316,061 ~116,061 5110',27T s~6~,oo3 ~6,11& $531,117 ~3,233 $594,351 2,622 6 8.9 TIH.DRLG 2297 TO 2622.CBU.TOH.LDDP.SLIP & CUT.L/I) BHA.P/U S63,081 S657,&31 11/23/93 2,622 BHA TO OPEN HOLE TO 24".TIH.COULD NOT PASS 399.TOH.P/U HILL. TIH.HILL CEHENT SHEATH FRON CONDUCTOR FRC~I 270 TO ~5. 7 8.9 CLEAN OUT 30# TO 407.TOH.P/U BHA ~6 TO OPEN HOLE TO 24".TIH. $51,?91 $709,222 11/24/93 2,622 8 ~.3 -- 11/25/93 2,622 9 9.4 ~1/26/93 2;622 10 9.5 1t/27/93 2,622 11 0.0 11/28/93 2,622 12 8.7 ~1/29/93 3',382 13 8.8 ~1/30/93 4,300 ' 14 '9.3 ~2/01/93 5,124 15 OPEN HOLE FRON &OZ TO 17~9. OPEN HOLE FROI4 1749 TO'22(~.TRIP.SAFETY NEETING.OPEN HOLE FRC~! 220~ TO 2270. OPEN HOLE TO 24" TO'2607'.CIRC & COND.SHORT TRIP.CIRC & COND TOtI.L/D HOLE OPENING BFLA.R/U CASING TOOLS.SAFETY FLEETING. RA~ 6~ JTS 20" 169 LBS/FT C-60 DRILQUIP CSG.LAND AT 2602 RKB i,43,385 ' $349,934 R/D CASING TOOLS.R/U TO RUN STAB-IN CHTG TOOL.TIN.STING IN. I~IT 20" CSG ~/1670 SXS CEMENT ~/ADDITIVES.JOB C04PLETE 1522 HRS 11-25-93.R/D DIVERTER EQUIP.PREPARE NIPPLE UP BOPS FINISH NIPPLE DOgg.CUT OFF 2b".NIPPLE DO~ BOPS.gELD ON ~04~0 PSI 20 3/&# HEAD PER HOT-HED.TEST I~LDS ON HEAD.NIPPLE UP BOPS AND RELATED EQUIPHENT. NIPPLE UP BOP EQUIP.RUN SPERRY SUN GYRO 2S50 TO SURFACE I/HILE NIPPLING UP.BOP TEST TO PPCOAND STATE OF ALASLA SPECIFICATIONS. INITIAL ~ TEST.P/U BHA t~.TIH.TEST CSG TO 2000.DRILL FLOAT EQUIP & 10 flOLE.FORHATION INTEGRITY TEST TO 12.0 PPG HME.OK. DRLG 2632-3382.CBU.TOH.CHANGE BHA& BIT.TRIPPING IN HOLE. TIH ~AS~ 3280-~382/DRLG ~]82-~9~6/CIRC OUT GAS/DRLG 3946 - ~158/CIRC OUT GAS/DRLG ~158-&Z:,~/CIRC OUT GAS/DRLG &23~B - &lO0~ ~REPORT TIHE ~139,119 S62,878 $74,963 9.7 DRLG 4300-438~/CBU FOR glPER TRIP/11 STD SHORT TRIP/DRLG $67,267 $1,102,541 $1,308,414 $1,371,292 $1,495,094 $1,562,361 ~2/02/93 5,8~0 16 :1'2/03/93 6,345 17 9.7 9.7 4384-5124/CBU FOR BIT TRIP/POOH FOR BIT/CHG BHA ~REPORT TINE TIN TO 2600/CUT DRLG LINE/TIH TO TD/DRLG S1'24-572'O/CIRCULATE HI-VIS SgEEP/DRLG 5720-58~0' $57,772 DRLG 58~O-58FS/CBU/SHORT TRIP 11 STDS/DRLG 5875-6345 $1,620,133 $1,668,424 ~2/0~/93 6,5~3 18 ~2/05/93 6,96O 19 ~2/06/93 7,1~9 20 9.8 DR~G'6~S-6438/CBU/SHORT TRIP TO CSG SHOE a2602/DRLG 64::~1-' $78,3~8 65&3/CBU/P(X)fl/TIH g/NEg BIT 9.8 TIH/DRLG 65&3-6960 S51,051 9.7 DRLG 6960-7065/CBU/10 STD SHORT TRIP/DRLG 7065-7129/CBU/ $42,3~7 POOH FOR BHA CHG/TEST BOP $1,7~6,812 $1,797,86~ $1,840,250 12/0Z/93 Z,400 21 ~2/08/9~ '7,800 22 ~2/09/93' 8,059 2~ 12/10)~3 8,297 24 ~2/11/93 8,556 9.7 TEST BOP/TIH/DRLG 7129-7204/RIG REPAIR/DRLG 7204-7400 $128,313 9.7 DRILLING 7400, TO 7800'. SHC~T TRIP AT 7646'. NO PROBLEMS. $60,8~1 9.7 DRILLING 7800' TO I~)~9' HD' (T555' 11~).CBU.TOH. 9.8 P/U BHA 13 & BIT 10. TIH. DRLG. FN. 8039-8297 TVO 7~'79; $1C~,276 25 9.8 DRLG 8?97-8400.SHORT TRIP TO 6870.N0 PRORLEHS.DRLG 8400-8556 S52,520 Sl,968,56& /2,029,39S /2,0~,267 /2,194,543 $2,247,063 ~[2/1'2/93 '8',671 '26 ~2/13/93 8,918 27 9.8 DRLG 8556:8585.CBU.TRIP FOR BIT I1. NO PROeLEHS ON TRIP HOLE IN (~X:O CONDITION. 561,447 /2,308,510 9.8 DRILLING FRO# 8,671' TO 8918' (8130' TVO) $52,560 /2,$61,0Z0 9.8 DRLG 8918-8930(81~2 TVD).CBU.$H(~T TRIP TO 7SO0.Pt.14P SleEP. CBU.SPOT PILL.TON.R/U SI/S.E LOG #I(DITE-LDT-CgL-SP-GR). S54,205 /2,415,275 '8,930 Y REPORT SUMMAR~ WELL:Sunfish No. 3 RIG:Pool Arctic Alaska/Pool Arctic Alaska FIELD:COOK INLET MAY -9 1994 AFE$:P-V181 cost: ~mmission DATE DEPTH RPT ~ ~ ~ChO~ge ~E~T]~S ~Y DALLY ~T ~ ~T 12/15/93 8,930 ~ 9.8 L~ ~LL g / DITE-LDT-CNL-~-~ ~22 TO ~. DSI-~ 8~ $51,~ ~,~,3~ ~EP. ~ PILL. ~ F~ ~ '9~8 R~ CSG T~S TO R~ 13 3/8 CSG. PRE-J~ & ~FETY MEETING. ~53,~ ~,920,132-- R~ ~ 13 3/8 P-110 & H-~.E~IP g/T~lZERS & STA~ ~S PER PR~.R~ CSG & ~G ~ ~GER.SH~ g 8~.C~ 12/17/93 8,930 31 9.8 CIRC & CZ)NO FOR 1ST STAGE CEMENT.CEMENT 1ST STAGE W1600 SX $70,593 S2,990,72~ - ~I/ADOITIVES.DRO~ BOMB.COULD NOT OPEN DV.R/U & TAP OPEN DV.CIRC & COMO.CEMENT 21~ID STAGE g/3700 SX g/ADOITIVE$. 12/18/93 8,930 32 9.7 DISPLACE 2ND STAGE CEMENT.OPEN DV TOOL.CIRC & CORD leJO. $]89,968 ~,]80,692 CEHENT 3RD STAGE Id/lO00 $X V/ADDITIVES.13 3/8 CEMENTING COMPLETE AT 1630 HRS 12-17-9].IdOC.N/D BOPS. 12/19/93 8,930 33 9.7' FINISH NIPPLE DOM4.1NSTALL 20" ~1 X 13 5/8" 5N CSG SPOOL. $65,031 $3,~5,723 N/U 13 5/8" 1014 BOP STACK AND ALL RELATED EQUIPNENT. ~2/20/93 8~930 3~ 9.5 INITIAL BOP TEST ON 13 5/8" STACK.P/U & M/U BIT # 12 & BNA $58,206 $3,503;929 #16.TIH TO 40~5.TEST C$G.LEAKED.DRILL PLUGS.RETEST.LEAKED. POH.P/U RTTS.TIH.TEST CSG TO 2100 PSI ~ 4013.0K.F~C)N WRTTS. -- 12/21/93 8,930 35 9.7 TIN TO r58oi. TEST CSG. TO 2100 PSi. DRILL DV. RIH TO 8865' $53,3~5 $3',557,27~ TEST CSG.NO TEST.TOH.TIH U/RTTS.TEST UPPER DV.OK.TEST LC)~/ER DV.1NJECT BELCR/ LCNdER DV.RTTS FAILED ON ANNULUS TEST. 9.7 ATTEMPTING TO ISOLATE AND IDENTIFY LEAKS IN 13 '3/8# CSG. T/ITH RTTS. APPARENTLY UPPER ANO LO~ER DV COLLARS LEAK. PREPARE TO SOUEEZE DV'S AT REPORT TINE. ~2/22t93" 8;930 36 $50,260' $3,607;'534 ~2/23/93 8,930 37' 9.7' RUN CBL/VDL ANO GYRO, RIH IdlTH RTTS AND SPOT AND SGUEEZE $54,455 S3,661,989 50 SX ACROSS L(~ER DV AND 100 SX ACROSS UPPER DV COLLAR. gOC AT REPORT TINE. ~2/24/93 8,9~0 ]8 9.9 gAIT ON CEMENT/POOH LD PACKER/TIN Id/DRLG BHA/CUT DRLG LINE $105,839 $3,767,828 TEST CSG.(INCONCLUSIVE) PON PICKUP RTTS AND RETEST ABOVE LD¥ TEST GOC)O 1. RIG UP TO SPOT CI4T. ACROSS LDV FOR SGUEETI:. ~2/25'/93 8,9~0 39 9.9 SQUEEZE CEMENT IN LO~R DV TOOL/POOH LO PKR/TIH Id/DRLG BHA $90,050 $3,857,878 TO TJ61/DRLG CHT TO 7'420/TIH. DRILL OUT FLOAT EQ. RUN F.I.T. TO 14.8 PPG EI~. CLEAN PITS AND CHANGE OUT /gJl:) SYSTEM. 12/26/93 8,940 40 9.7 MIXING MEg igJD SYSTEM/ $65,39S $3,923,273 , CHANGE OVER 14LE) SYSTEM, DRILL 8940' TO 9112' PON FOR BOP TEST AND ~ MOTOR AND I~,~. (DIRECTICWAL CORRECTION) ~2/27193 9,112 41 9.8 -- 12/28/93 9,~3 42 9.7' $65,825 $3,989,098 TEST RtaO/TIH/DRILLING IJ/MUO IdOTOR 9112 - 931S/SHORT TRIP & $6~,758 $4,0S3,856 STDS INTO CSG/DRILLING 9315 - 9~3 12/29/93 9,660 43 9.7' DRILLING FROM 9~3 TO 9660. $56,745 S~,110,599 42/30/93 9,860 4~ 9.7 DRILL AND SURVEY 12 1/4~ HOLE TO 9860, POH FOR BIT AND BNA $75,~ ~,185,963 CHANGE. MADE UP BIT 1114. CHAGE BNA RIH. ~2/:31/93 10,2Z0 ~5 9.? DRILL AND SURVEY 12 1/~" HOLE. $55',780 ' ' S~,241,743 bl/01/9/. 10.~,50 ~6 9.7' ~1/02/94 10,60~ ~? 9.8 DRILL AND SURVEY 12 1/4N HOLE. S56,845 $4,298,589 DRILL AND SURVEY 12 1/4" HOLE TO 10604. CBU, POll FOR BIT S53,672 S~,,352,261 01/03/94 10,835 01/0~/94 11,095 01/0S/94 11,201 b1/O619& 11,370 48 10.0 DRILL AND SURVEY 12-1/4 HOLE TO 108~5 FT. $~2,837 ' S4,405,098 4/; 10.1 DRILL AND SURVEY, MADE 10 STD. SHORT TRIP AT 11021, HO S56,&31 $4~461,530 - TIGHT SPOTS. DRILL TO 11095. 50 10.1 DRILL 110~ TO 11116.TRIP FOR BIT 16 & BHA.lal?EKLY BOP TEST. $58,901 S~,520,431 - TRIP IN HOLE.DRILL 11116 TO 11203, 51 10.0 DRLG 11201 TO 11370. $57,8/~ S~,578,275 01/07194 11,L63 52 10.0 DRLG 11370-11474(10401 TVO).CBU.TOH FOR BHA CHANGE.P/U & M/U $63,421 ~,641,696 01/os/~ 111638 bl/09~94 11; 7,r.o BFLA 1123 & BIT #17. TIH TO 8900.SLIP & CUT 7'6 LINE.TIH.DRLG 11474-11483. 53 10.1 D~LG i14;.;63"T0 11638' (10S53' TVO). S53,502' S~,695,197 ' 5~ 10.1 DRLG 11638-11651(10~66 TVO).CBU.TOH.P/U BNA 24 '& BIT 18.TIH. $56,5~6 S4,7'51,743 ' DRLG 11651'117~0. 01110/9~ 11,8/,2 55 10.1 DRLG 11740-118~2.CBU.TOH.L/O RETRIEVABLE lC4) TOOLS.P/U LI~ S~.,~41 ~,813,98~ TOOLS (BI4A 2S & BIT 19).T1#. ~1/12/94 12,100 __ 01/13/94 12,150 L¥ RE?ORT S~~ WELLtSunf~sh No. 3 RIG:Pool Arctic Alaska/Pool ~ctic Alaska FIELD:COOK INL~ M~ -9 ]~4 AFE~:P-V181 $ oo DATE DEPTH RPT ~ ~ : ~ChO~O~ ~T[~S ~Y DAILY ~T ~T 01/11/~ 11,~6 ~ 10.1 TIH TO ~.$LIP & ~ 85.TIH TO 111~.L~ RES & ~ L~ L~ ~ & RESISTIVITY 11~6-11~6 ~ T~. 57 10.1 T~.~EKLY ~ TEST.P~ B~ ~26, BIT'~O & TIH.DRLG 11~6- $~',~ ' '~,~7,8~ 121~ (1~ T~). ~ '10~1 D~LG 121~-12'15b(llOZA T~).~EP & ~.SH~T TRIP TO AT ~.~ ~EP & ~T PILL.T~ TO R~ "E" L~S.R~ SCHL~BER~R. §1/14/94 ' IZ,150 59 "10.1 "E" LOGS (DITE-LDT-CAL-CNL-GR-A/4S) & (DSl-G~-AJqS).LOGGERS $140,933 TD=12135.TIH TO 8900.STRING UP 12 LINES.TIH TO 12150.ClRC AND CONDITI~ FOR 9 518 CASING. ~ii15/¢4' 12,15o 01/16/94 12,150 SS~1L8,085 60 10.1 CIRCULATE & CONDZTION/TOft/R/U CASING CREW/SAFETY NEETING. RUNNING 9 5/8 CASING. S44,954 S5,193,039 61 10.1 RUN 9 5/8 & 9 7/8 CSG TO 12137 I0 (11012 TVD).CEMENT WITH S181,421 $5,374,460 1000 $X G WITH ADDITIVES.OMT IN PLACE 1719 HRS 1-15-93.N/D SET SLIPS.L/D LANDING ITS.SET & TEST PACKOFF.N/U BOPS. 01/17/94 12,150 ''62 10.1 NIPPLE LN0 BOPS.INITIAL TEST TO 3(~0/10000 PSI.P/U BIT 21'& $57,838 BHA 28.INSPECT HI~)P.TEST CSG TO 5000 PSI.STRING TO 10 LINES. TIN.TAG OMT AT 11397.DRLG CHT OUT OF CSG AT 116~9. bl/18~94 12;'160 63 13.5 DRILL CEJ4ENT OUT OF CASING TO SHOE AT 12137.DRILL 8 1/2" S325,00'Z S5,7~?,~ HOLE TO 12160.CBU.FIT TEST TO 16.2 PPG EJqV.REBUILD HUD SYSTEN TO 13.5 PPG. BUILDING HUD WT TO 13.5#/DRLG 12160' TO'122~5%/CIRC PRIOR TO POOH FOR CORING. b1/19/9~ t2,285 6/, 1'3.5' ~1/20/94 12,306 65 13.5 _ 01/21/94 t2,405 66 13.5 $5,432,298 -- CBU/POOH/PU CORING TOOLS/RIH & CORE FROM 12285' TO 12306'/ BARREL PLUGGED/POOH/EVALUATED CORE/PREPARE TO DRILL. TIN W/DRLG ASSY/I~ASHDCXdN 122~5:12306~DR~G 17_306' TO 12405'/ CIRC HOLE CLEAN/POOfl TO PU CORE ASSENBLY/14U CORE ASSEI4BLY. NOTE: A C04PLETE SAFETY [NSPECT[OR gAS PERFORNED. S131,(~,8 S5,~8~,267 $63,456 $5,952,77.3 $129,254 $6,081,977 ~/22/94 12,465 67 13.4 TIH W/CORING TOOLS/CORING 12&05' - 12465'. $52,644 $6,1.T~,622 01/2.3/9~ 12,540 68 13.5 FINISH CORiNG/POOH LD CORE (RECOVERED 56.5')TIH W/DRLG SEA $80,114 $6,21&,TJ5 CUT DRLG LINE/FINISH RIN/REAH CORED SECTION/DRILL FRC~ 12465' TO 12540' 01/24/94 12,616 69 13.5 DRLG 12540-12616/CBU/POOH/TEST BOPtS/RIH WITH PDC BIT/ S8~,083 $6,298,818 01/25/9~ 12,832' ?0 13.5 CUT DRLG LINE/TIH TO 12586 - WASH TO TD g12616/DRLG 12616 - S51,459 S6,350,277 12832gREPORT TINE bl/26/94 13,010 71 13.5 DRILLED FROM 12,&32' TO 12,850'/14ADE WIPER TRIP - OK/ S58,~6 $6,409,033 CONTINUED DRILLING FROM 12,850~ TO 13,010~. b'1/27/94 13,209 72 13.5 DRILLED FROM 13,010' TO 13,107'/RADE WIPER TRIP/CONTINUED $59,159 $6,4~,192 - DRILLING FROM 13,107' TO 13,209'. _ 01/28/94 13,613 73 13.5 DRILLING FROM i3,209' TO 13,413"." ~20~'). '$58,571 S6,526,763 bi/29/94 13,603 ' 74 13.5 DRILLED FROM '13,4i3' TO 13',491'/ldADE SHORT TRIP/DRILLED S65,850 S6,592,613 FROM 13,491~ TO 13,603'. bi/30/94 13;6~1 ~ 13.5 DRILLED TO 13,628'/~/RZH WITH CORE ASSEMBLY/CUT DRILL Sa8,2~l $6,680,823 LINE/CORE FROM 13,628' TO 13,641~ & PROGRESS QUIT/POOH. 01/31/94 13,659 76 13.5 PC~ W/CORE f3/LAY OUT 8' OF CORE/RIH WITH & CORE #4 TO S75,087 $6,755,910 13,659'/POOH & LAY DOq~ 18' OF OIL SATURATED SANDSTONE/ TEST 02/01/94 13,680 7'7 13.5 FINISHED TESTING BOP'S/CORED FROM 13,659' TO 13,680'/PULLED $66,635 $6,822,545 & RECOVERED 19' OF OIL SATURATED SAND CORE/PU &HU NEW CO~E ASSEHgLY & 02/02/94 13,~2 7'8 13.6 CORE ~6 FROM 13680-13700.TOH.RECOVER 19.5~ CORE.P/U BHA #38 $115,605 $6,938,150 & BIT #29.TIH.DRLG 13700-13?52(12424 TVO). 02/03/94 13,852 ?9 13.8 DRILLING 13~52~ TO 13852' 0~/04/94 13,986 80 14.0 DRLG 13852-13986(12614 TVD).SLUG.START SHORT TRIP.PIPE STUCK $61,801 S?,O&3,001 WiTH BIT AT 13210.2ORE STLICK PIPE.PIPE CAME LO0~ AT 0530 HOURS.ATTENPT TO WORK PIPE UP FROM 13~10. RECE v'ED #ELI,~ Sunfish 9 1994 FIELD: COOK INLET - PHILLIPS PETROLEUM PAGE:4 DAILY REPORT SUMMARY RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE$:P-V181 DATE DEPTH 02105194 l&,Ol& 02/06/94 l&'~Ol& AUTH COST: $13,993,200 RPT NO IW Anchorage OPERATIONS SUI4qARY DAILY COST CLN COST 81 1~.1 ~CK R~ ~T OF ~E TO 13110.STRING FREED ~.T~ W/BIT ~ $~,7~ S7,161,769 & B~ ~.C~ ~T L~,~ & J~S.TIH ~/B~ 39 & BIT ~.L~ 1]~-I]~.DRLG 1~9~-14014'(12~').J~ ST~K PIPE ~ 1~,1 JM ST~ PIPE.~ FREE-~INT T~S.FIRST T~ FREE-~INT $58,1~ R~S FA~L~.S~T HI-V~S PILL ~ B~ & ~P.FREE-~T 02/07/94, 14,,014, 83 14,.0 13.5 ~2/09/9% 13,457 85 13.5 02/10/94 13,457 TON TO 12137.SLIP & CUT.TON.P/U FISHING TOOLS.SCREW IN SUg BLiP SUB-JARS-9 DC-ACC-12 H'.q)P-TIH-REAN 17-3~-12762 & 13083 133~ ON TIH.CATCHFISH.CIR THRU BIT.JARoLCYdER ICJ TO 13.5 PPG JAR ON FISH.NO SUCCESS.FREE-POINT.BACK OFF STRING AT 1~611' (17313 TVO).TON TO SHOE.CUT LINE.TOH.L/D FISHING TOOLS & FISH.P/U DIVERTER SUB & TIH TO SET CEMENT PLUG AT 1~611. TIH TO l~511.CIRC,CONO,CBU.SET 1'2'5 SX SIDETRACK PLUG FROM 13611-1~5.TOH.L/D EXCESS DP.WEEKLY BOP TEST.P/U BIT 31 & BNA &O.TIH.TOC AT I~5.CLEAN OUT TO 13457.CBU.TOH. 86 13.5 POOH TITE SPOTS 12~50-12300/CUT DRLG LINE/RIG REPAZR/I:NDOH $76, ~ $7, F;6,899 $535,620 S7,8J2,519 $126,013 $7,958,531 $55,052 $8,013,58~ PU SIDETRACK BHA/TIH TO 12302 HIT TITE HOLE/PU KELLY WASH TO 12402/1~ORK SECOND TIME PiPE STUCKa12362/JARRING STUCK PiPE 02/11/94, 13,457 87 13.5 JAR ON STUCK PIPE.RU FREE POINT TOOL FAILED.JAR ON PiPE CAME LOOSE/TON,L/D SIDETRACK BHA & P/U BHA TO CLEAN OUT.TIN. TLASH & RE, AN 12200-17330. $73,682 $8,087,266 02/12/9% 13,457 b2/13/94 13,469" 88 13.5 89 13.5 %~ASH & REA~ TO 12426.CIRC.TIH TO PBTD 1~57.CIRC & COND leX). SHORT TRIP TO CSG ~ 12137.CIRC & COND.TOfloSLIP & CUT 500.TOH P/U SIDETRACK; ASS. & RET KkO TOOLS.TEST & REPAIR TOOCSoTIHo TIH TO SHOE.CHECK I~).OK.TIH TO PBTD ~ 13457.SIDETRACKI#G OFF BOTTGH OF OLD HOLE FROM 134,57' TO 1~69' (12199' TVI)). $71,629 M, 158,895 $76,918 S8;735,813 0Z/14/94 13,515 02/15/94' 13,560 ~2/16/94 13,681 §2/17/94 13,73i 02/18/94, 13,876 90 13.5 TIME DRILLING ON SIDETRACK FROI4 1~69' TO 13515'.** SURVEYS & CUTTIHG$ INOICATE ~LL IS SIDETRACKED.CiRC BOTT UP.TON. $57,661 $8,293,474 $90,912 $8, Z.84,38~ $72,585 ~8j~56,971 91 13.5 '92' 13.5 93 13.4 POOH/BOP TEST/PU DRLG BHA/TIH TO SHOE/TEST FR,tD/TIH/REAH THRU SIDETRACK INTERVAL/DRLG 13515' TO 13560' (12275' TVD). DRLG"13560-l~6~l/CIRCULATE HOLE CLEAN/PULL OUT OF HOLE/ KAKE UP CORE ASSEI48LY # ? & RIM WITH SAME/TAG FILL 015671 WASHING IX)tIN TO TD 013681 gREPORT TINE I~ASH TO I~I/CORING FROM 13~81' TO 13,731' & BARREL JAJq4ED/ POOH WITN CORE/ $100,755 ' $8,557,727' 94 13.4 CONTIIRI~ P(X)H NO PROeLEJ4/LAYDCRai 50' CORE & CORING EQUIPME#T $62,515 $8,620,242 ~2/19/94' 13,941 b2/20/94 13,941 PU DRLG BH~/RIH/DRILL FRON 13731 TO 13876. 95 13.4 DR[G 138:76 : ~3941/CBU/l~IPER TRIP TO CSG/CBU/POOH/BEGIN $53,583 LOGGING 96 13~5 LOGGING 2 RUNS/RD WIRELINE FOR WIPER TRIP/TIH & MAKE WIPER $/~1&3 TRIP/POOH TO LOG/LOGGING RUN # 3, F#I LOG. $8,67~,825' ' $8;717,9 02/21/94 13,941 97 13.6 b2/22/94 13,9~1 98 13.'5 b2/23/94 13,941 99 13.5 b2/24/94 13:W. 1 lO0 13.5 FINISHED LOGGING/TEST BOP'S/RIH FOR WIPER TRIP PRIOR TO RUNNING CASING TIH TO 13,B81/1,/ASH & REAN TO TDgl~9%l/~IkC & CC)ND FOR LINER/ POOH/RU CASING EGUIPHENT/RUN 7" LINER TO BOTTOM/CIRCULATE BEFORE CEHENTING $44, ~4, $236,051 CONDITIONE~ HUO/CEMENTED 7" LINER/POOH/RIM & CLEAN OUT TO LINER TOP/CIRC CLEAN/POOH TESTED LINER TOP/~U & RIH WITH NEW DRILLING ASSEMBLY/DRILLED S~25,050 LANDING COLLAR/TESTED CASING/CONTINUED DRILLING FLOAT TRACK $8,762,192 $8,~8,2;~ S9,173,293 S9,171,030 02/25/94 13,969 101 13.8 b2/26/94 14,130 ' 102 14.1 DRILLED 10' OF NEW HOLE/RAN LEAK OFF TEST/RAISED CHANGE BHA/RIH TO DRILL AHEAD/DRILL FRON 13,947' TO 13,969'. DRILLING ~/13,969' TO ~49,978 02/27/94 14,269 103 1(.1 b2/~8/94 14,325 10/. 14.1 b3/01/94 14,'363 105 1~.5 DRILLING F/14,,130' TO 1&,269'. DRILLED FRON 14,~269~'~01&,287~q4AOE SHORT TRIP/WENT BACK TO DRLG F/14,287' TO 14,325' U/BREAK/CIRC UP IOOX~M4OWITN HYOROCJUtBONS/P(X~/RI# WITH ~E AS~LY TO~E ~. ~TI~ RIH &'~ FR~ 14,325' TO S59,734 s~35,LIo 59,353,Z76 $9.407,'640 $9,542,869 03/03/94 14,515 -- 031C~194 14,650 _ 03/05/94 1~,705' DAILY REPORT SUMMARY WELL:Sunfish No. 3 RIG Pool Arctic Alaska/Pool Arctic Alaska FIELD:COOK INLET ~A¥ -9 1994 : AFE/: P-Vl8 ! CNTY/STATE: TYON .E~6~~F,~F~0" AUTH COST: $13,993,200 ~ Anchorage DATE DEPTH RPT NC) NW OPERATIONS S~I44ARY DALLY COST C1]4 COST 03/07/9~ 14,385 106 14.5 CORE #8(14363-14368).TOff.OUT &3'.REC &2'.t~EKLY BOP TEST.P/U $~,237 $9,627,106 BHA 53 & BIT 38.TIH.DRLG W/HOTOR & ROTARY 14368-14385. 107 14.5 DRILLING WITH 14C)TO4t AJ4D ROTARY FRCI4 1438'$' TO 14515' $55,282 $9,682,388 (13107" TVD). 108 '14.5 DRILLING WITH 140TON AND ROTARY FROI4 14515"T0 14650' $60,099 S9,T&2,~67 (13228" TVD). 109 14.5 DRLG w//qOTOR & ROTARY 14650'14705'(13281 TVD).CBU.START SHORT $71,120 '$~,813,~)7 TRIP.COULD NOT GET ABOVE 14105.TIH.CIRC & COHD & PUNP 100 BBL HI'VIS SYEEP.START TRIP.TITE AT 14175.WORK TITE SPOT. ~3/06/94 14,705 i10 14L5 IL~CKREAN OUT OF HOLE TO 14087.TOH TO SHC~ ~ 13939.RENq AND $72,898 $9,886,505 COND 14087-14159.TIN.CIRC & COND.TOfl TO RUN E LOGS.RUN # 1 (DIL-DSI-GR).LOGGERS TD=14~32.*.E LOG RUN # ~ (CNL-FDC-G~). ~3/07/94 t4,70~ 111 14.5 E LOG RUN 2(LDT-CNL-GR),3(F~S-GR),4(SgC'GR/23 RECOVERED OUT $.44,923 ' $9,931,428 OF 45 SHOT).P/U BFLA #54/BIT #3SRR TO CLEAN OUT & TAKE IqULTI SHOT SURVEY.TIki.WASH & REAR 14645-14705.CIRC 03/08/94 14,705 112 14.5 TOH TO 7" CSG.CUT 119' LINE.TOH.RFT LOG(4 SETS).POOH.JUNK $245,747 $10,177,175 BASKET & GAUGE RING RUN TO 13920.RZkl & SET EZSV g 13916.POH. WEEKLY BC~ TEST.TIN W/BHA & L/D SANE.TIH W/STAB-IN FOR EZSV. 03/09/9% 14,705 113 14.5 TIH TO EZSV O 13916.INJ RATE..S~4J~EZE lOSX CEJ, LEklT W/ADDITIVES $105,396 $10,2~,571 BELCh/ RETAINER.SPOT 2 SX ON TOP.REVERSE OUT . SLUG. TOg . R/U W/L AND RUN GYRO.RUN CET-CBT-CCL-GR LOG IN 7" LINER. 03/10/94 14,705 114 14.5 CET-CBT-CCL-GR LOG IN 7" LINER.RIG DO~N WIRELINE.CLEAJ4 HUD $78,456 $~o,~,ozz PITS.BRING 3.5" TUBING & HRS TEST EOUIPt4~NT ON BOARD. HCX:)K UP FLOWI. INE ANt:) LINES TO SAVE DISPLACED NUD. 03/11/94 14,705 115 8.5 o3/1~/94 14,~o~ 7" & 9 5/8" SCR.4J>ER RUN TO 1::~',66'.DISPLACE DRLGHLJO W/SEA H~O.SHC)RT TRIP TO LINER LAP.DISPLACE SEA H~C) I,//~ KCL H20. LAY ~ DRILL P]PE. $62,454 $10,423,481 116 8.5 LOAD OUT E~UIPNENT TO BOAT.LAY DC)~14 DRILL PIPE & SCRAPERS. $62,3~ S10,4~S,858 03/13/94 14;i0'5 i17 8.5 03/14/94 14/705 118 8.5 03/15/94 14,705 119 8.5 03116194 14,705 03/17/94 14,705 120 8.5 121 ' '8.5 PULL WEAR BUSHING & SET TEST PLUG.CHANGE RN4S TO 3.5" AgO BLIND/SHEAR.TEST BOPS.AHHULAR FAILED.INSTALLING NEW ELEJ4ENT. REPAIR ANNULAR BOP.WEEKLY BOP TEST.P/U BALL CATCHER SUB.TIH S51,776 PICKING UP 3 1/2" 12.9~# N-80 PH-6 TBG.DROP BALL,PRESSURE UP & TEST TBG TO ~000 PSI.REVERSE OUT BALL.TOH W/TBG. TOH.W/L CORRELATION LOG.P/U,RUN,CORRELATE AND ~T TCP GUNS S51,~:~5 S10,.~89,259 TO PERFORATE SUNFISH SA~ (1359~-136~ & 13656-13706).R/1) WIRELINE.SLIP & CUT DRILL LINE.TOH WITH 'rU61NG STRING. TOH.R/U W/L.JUNK BASKET & GAUGE RING RUN.TIH W/HALLIBURTON BIJ) PERI4ANENT PACKER & SET AT 1348~.~H.P~ HALLIBURTON RESEVOIR SERVICES CASED HOLE TEST TOOLS & Tlkl. TIH/SPACEOUT/RU TEST TREE & WIRELINE/TEST LINES & MANIFOLD DISPLACE W/NITROGEN/FIRE GUNS/OPEN W~LL TO FLO~/FLO~ING W~LL g~EPORT TINE CONTINUE TESTING 1,fl41LE RUNNING PRODUCTION LOGS. $105,~3 S10,69~,891 S57,907 S10,7~2,799 $133,276 S10,886,074 03/18/94 14,705 122 8.5 b3/19/94 14,705 12.3 8.5 b3/20/94 14;705 124 '8.5 b3/21/94 14,705' 125 '8.5 PROOUCTION LOGGING t,'HILE FLOg TESTING BELL. SHUT IN bIELL & HU RT-91 SURFACE READ OUT TOOL FOR PRESSURE BUILD UP. gtELL SHUT IN FOR PRESSURE BUILD UP. SHUTIN FOR PRESSURE BUILDUP. ATTEI4~T TO GET SAJ4PLES W/NO SUCCESS. OPEN ~,/~LL TO O~TAIN FLOWING SAJ4PLES FLOglNGgELL FOR CLEAN UP. RECOVERED BOTTC~4 HOLE SAJ4PLES. RUN PLU~ (PXN) IN HOLE. S76,497 S10,962,571 $68,817 S11,03~,388 $67,81~ S11,099,206' $70,177'' $11,169,383 03/22/94 14,705 §3/23/94 14;705 ~3~,2~,~94 14,705 03/26/9~ 1;,;705 126 8.5 127 8.5 SET PXN PLUG/REVERSED TBG CLEAJ4/POOfl WITkl TUBING/LAY DOWN TEST TOOLS/TEST BOP'S FINISHED BOP TEST/RIN WITkl SEALS/PULL PLUG/PUMP AWAY PRODUCED FLUID BACK INTO SUNFISH FORMATION . ,, 17.8 8.5 INJECTING PRODUCED FLUIDS BACK INTO SUNFISH FORMATION. FINISHED PUI4PING AIL4Y PRODUCED FLUIDS/CHANGED OUT KCL WATER WITH t3.6 PPO 14UI)/BtlILD II.ID VOLLWE 13.6 B. UII~D G BALANCE I~/PtAP & REVERSE OUT CEJ4ENT/~/RU SCHLLg48ERGER & Rig WITH VSP LOG. S177,247 Sl1,~6,630 S188,829 S11,$35,4~9 S~7,979 S11,583,438'' $63,524 S11,646,962' $94,148 $1~,741,110 WELL= Sunfish No. FIELD: COOK INLET CNTY/STATE: TYONEK oFFSHORE\ALASKA PHILLIPS PETROLEUM PAGE: 6 DAILY REPORT SUMMARY 3 RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE$:P-V181 AUTH COST:$13,993,200 DATE DEPTH RPT NO I, IU OPERATIONS SUMMARY DALLY CO~T CUM 0]/27/94 1&,?05 131 13.6 FINISH LOGGING ~ITH VSP/RECOVER FISH IN I,/ELLHEAD/RIH ~ITH $~2,013 $11,783,17.3 EZSVCENENT RETAINER. §3/28/94 1&,705 132 ~.4 SET EZSV/SQUEEZE OFF SUNFISH/CHANGE OUT MUD TO 2~ KCL/ $170,642 $I1,1;~3,765 POOH/I~ GUN & PACKER ASSEMBLY ~3/29/9~ 1&,?05 133 8.& RIH ~ITH PERFORATING GUNS & PACKER/PERFORATED SU~ nC~ SAND/ $~1,826 RIH glTH RT-91 FOR PRESSURE BUILD UP. OPENING UP I~IELL TO TESTERS AT REPORT TINE. 03/~0/94 14,705 1~4 8.4 OPEN YELL TO TEST FOR 9 HOURS.RECOVERED 14 BELLS PROOUCED $104,061 $12,099,652 14,705 FLUID(lO-15% OIL & REMAINDER gATER).TOH & LAY DOq,/M TEST TCX~.S.P/U HALLIBURTON EZSVON ~ 1/2~ TBG & Tiff. 135 12.8 SET EZSV ~ 1237~.ClRC & COHO.DISPLACE 8.6 PPG H20 ~iTH 12.8 $149,556 $12,249,209 PPG MUO.S~EZE 10 SX CEMENT BELO~ EZSV & 100' ON TOP.EST TO(: a 122?5.SET BALANCED PLUG 11950-11700.LAY DC~ TUBING. 04/01/94 14,705 1~6 0.0 04/02/9~ 14,705 ~4/03/94 14,705 i37 LAY DC~ 3 1/2" TUElING.SET TOP CEMENT PLUG FRON 500' TO 300' ~/68 SX CLASS G.LAY DCRat REMAINING TUBING.CLEAN AND FLUSH PUMPS A~D MUO LINES.CLEANING MUD PITS. $12,331,943 0.0 N/D BOPS, RISERS AND ALL ASSOCIATED EOUIPMENT. INSTALL 1044 BLIND FLANGE ON 1OR TUBING HEAD. CLEANING MUD PITS. S43,414 $12,3~35Y ~" 138 0.0 FINISH CLEANING MUD PITS. CC~LETE DISPOSAL OF KCL ~ATER $47,39~ S12,422,752 FRON HRS TEST TANKS. RELEASE RIG FROFI SUNFISH # 3 AT 2400 HOURS 4-2-9~. RECEIVED MAY -9 1994 A~aska Oil & Gas Cons. Commission Anchorage 04/19/9& CASING ," LINER AND CE'M[::NTING RECORD SUNFISH NO. 3 Casing Weight 'Grade Top 'Bottom Hole Cementing Fi~:~ord Size per Foot Size i ii i i i i i i ii 30" 457 "B" 55' 407' NA Driven 20" 169 X-56 59' 2,602' 24" 1,070 sx "G" @ 12.8 lb/gal + 600 sx '~"@ 15.8 lb/gal. 13 3/8" 72 ~-8o;, P-110 59' 8,909' 17 1/2" Stage 1 900 sx "G" @ 12.5 lb/gal tailed with 700 sx '~" @ 15.8 lb/gal. Stage Colar for 2nd S'lage @ 7,381'. Stage 2 3,700 sx "G" @ 15.8 lb/gal Stage Collar for 3rd Stage @ 4,04."". Stage 3 1,000 sx "G" @ 15.8 lb/gal 9 5/8" 53.5 N-80 57' 1,01 4' 12 1/4" 1,000 sx "G" @ 15.8 lb/gal 9 7/8" 62.8 Q-125 1,014' 2,116' 9 5/8" 53.5 N-80 2,116' 12,138' 7" 32 L-80 11,837' 13,941' 8 1/2" 674 sx"G" @ 15.8 lb/gal i i RECEIVED MAY - 9 1994 A!aska 0il & Gas Cons. Commission Anchorage ********* ********** ********* ANADRILL ********** ********* SCHLUMBERGER ********** SURVEY PROGRAM COMPANY PHILLIPS WELL NAME SUN FISH #3 LOCATION 1 TYONEK PLATFORM LOCATION 2 COOK INLET, ALASKA MAGNETIC DECLINATION 23.19 DATE: 10-MAR-94 WELL NUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IN POINT(TIP) : MEASURED DEPTH 363.00 TRUE VERT DEPTH 363.00 INCLINATION 1.25 AZIMUTH 52.O0 LATITUDE(N/-S) 0.16 DEPARTURE(E/-W) 2.17 DEP(E/-W) 0.00 5.01 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 363.00 0.0 363.00 481.23 118.2 481.21 557.91 76.7 557.87 589.76 31.9 589.72 620.69 30.9 620.64 651.55 682.41 713.23 744.13 775.08 806.02 836.86 867.68 898.64 929.52 960.39 993.77 1024.75 1055.63 1086.51 1117.34 1146.78 1177.37 1208.99 1240.28 30.9 651.50 30.9 682.35 30.8 713.17 30.9 744.06 31.0 775.00 30.9 805.93 30.8 836.75 30.8 867.56 31.0 898.50 30.9 929.35 30.9 960.18 33.4 993.52 31.0 1024.44 30.9 1055.25 30.9 1086.04 30.8 1116.75 29.4 1146.05 30.6 1176.46 31.6 1207.86 31.3 1235.92 SUN FISH #3 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 0.35 1.25 52.00 0.16 1.46 1.02 82.15 1.10 1.90 1.13 73.07 1.41 2.16 0.99 62.21 1.63 2.48 1.04 57.29 1.91 DEPARTURE DISPLACEMENT at AZIMUTH E/-W ft ft deg 2.17 2.18 85.78 4.23 4.37 75.45 5.63 5.81 75.93 6.18 6.39 75.21 6.65 6.92 73.99 2.82 0.98 56.30 2.20 3.23 1.09 36.19 2.59 3.78 1.24 29.71 3.11 4.43 1.49 35.75 3.73 5.17 1.47 14.80 4.44 DLS deg/ 100ft 0.00 0.53 0.26 0.76 0.31 6.03 1.73 4.99 5.28 7.00 1.91 14.52 6.24 7.98 1.82 16.78 7.21 9.07 2.25 8.60 8.28 10.36 2.56 9.76 9.56 8.71 10.19 58.75 1.21 8.88 10.85 54.88 1.15 9.15 11.65 51.76 0.38 9.38 12.51 48.57 1.69 9.59 13.54 45.09 1.01 11.81 2.85 8.12 11.00 13.57 3.20 2.83 12.75 15.42 3.70 356.46 14.61 17.52 4.16 357.40 16.72 19.87 4.65 356.17 19.09 9.81 14.74 41.74 0.96 9.98 16.19 38.04 1.34 9.96 17.68 34.28 2.03 9.85 19.41 30.49 1.49 9.71 21.42 26.96 1.62 22.48 5.30 350.12, 21.74 25.25 5.95 348.42 24.57 28.44 6.55 347.90 27.83 31.98 6.82 350.35 31.45 35.68 7.29 348.33 35.22 9.38 23.68 23.35 2.71 8.84 26.12 19.79 2.28 8.16 29.00 16.34 1.96 7.47 32.32 13.36 1.24 6.75 35.86 10.85 1.69 7.10 7.44 72.76 0.19 7.49 7.93 70.96 1.22 7.83 8.43 68.33 0.64 8.23 9.04 65.63 0.95 8.57 9.65 62.62 1.74 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 1271.46 31.2 1269.82 1302.76 31.3 1300.81 1333.80 31.0 1331.47 1365.23 31.4 1362.46 1397.36 32.1 1394.08 1428.64 1460.25 1490.77 1522.30 1554.05 1585.68 1616.13 1647.70 1678.30 1708.43 1738.78 1769.93 1801.59 1832.41 1863.38 1895.03 1926.27 1957.79 1989.10 2020.78 31.3 1424.80 31.6 1455.80 30.5 1485.72 31.5 1516.59 31.8 1547~65 31.6 1578.56 30.4 1608.26 31.6 1639.00 30.6 1668.72 30.1 1697.94 30.3 1727.32 31.2 1757.44 31.7 1788.01 30.8 1817.71 31.0 1847.50 31.7 1877.85 31.2 1907.70 31.5 1937.70 31.3 1967.40 31.7 1997.37 SUN FISH $3 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 39.63 7.90 349.04 39.26 43.93 8.44 350.94 43.64 48.58 9.32 351.89 48.38 53.71 9.96 351.46 53.59 59.24 10.56 349.35 59.23 DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W deg/ ft ft deg 100ft 5.95 39.71 8.61 1.98 5.18 43.95 6.76 1.93 4.46 48.58 5.27 2.87 3.70 53.71 3.95 2.06 2.74 59.29 2.65 2.18 64.86 11.06 347.21 64.97 1.55 64.99 1.36 2.06 70.68 11.40 345.21 70.95 0.08 70.95 0.06 1.64 76.36 11.52 343.63 76.79 -1.55 76.80 358.84 1.09 82.33 11.89 344.54 82.94 -3.30 83.00 357.72 1.31 88.53 12.09 345.21 89.31 -5.02 89.45 356.78 0.77 94.85 12.42 345.57 95.80 101.17 12.98 346.01 102.29 107.99 13.48 345.71 109.30 114.83 13.92 345.55 116.32 121.78 14.37 345.58 123.45 -6.72 96.04 355.99 1.06 -8.36 102.63 355.33 1.87 -10.12 109.76 354.71 1.62 -11.92 116.93 354.15 1.43 -13.76 124.21 353.64 1.50 128.93 14.61 345.30 130.80 136.42 14.96 345.49 138.49 144.20 15.27 345.46 146.49 151.96 15.65 345.99 154.45 159.99 16.13 346.46 162.68 -15.67 131.73 353.17 -17.67 139.62 352.73 -19.74 147.81 352.32 -21.77 155.98 351.98 -23.79 164.41 351.68 168.52 16.83 347.14 171.43 177.31 17.50 . 347.79 180.43 186.56 18.23 348.35 189.89 196.04 18.63 348.15 199.58 205.86 19.15 348.57 209.63 -25.84 173.36 351.43 -27.84 182.56 351.23 -29.83 192.22 351.07 -31.85 202.11 350.93 -33.92 212.35 350.81 0.81 1.13 0.99 1.30 1.62 2.30 2.22 2.38 1.29 1.70 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 2051.65 30.9 2026.49 2082.28 30.6 2055.28 2112.52 30.2 2083.60 2144.10 31.6 2113.05 2174.88 30.8 2141.67 2206.50 2238.06 2268.82 2299.03 2330.62 2361.95 2393.02 2423.58 2456.72 2487.76 2518.46 2550.08 2651.09 2744.56 2837.56 2930.00 3023.82 3117.21 3210.11 3304.51 3380.91 3473.78 3565.53 3657.79 3751.21 31.6 2171.06 31.6 2200.38 30.8 2228.96 30.2 2256.97 31.6 2286.16 31.3 23].5.10 31.1 2343.80 30.6 2371.95 33.1 2402.41 31.0 2430.87 30.7 2458.89 31.6 2487.65 101.0 2578.93 93.5 2662.95 93.0 2746.37 92.4 2828.98 93.8 2912.45 93.4 2995.16 92.9 3077.10 94.4 31E9.97 76.4 3226.71 92.9 3307.83 91.8 3388.23 92.3 3469.12 93.4 3551.10 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 215.71 19.64 349.18 219.68 225.77 20.27 349.56 229.96 236.02 20.84 349.96 240.40 247.04 21.52 350.01 251.64 257.97 21.64 349.99 262.79 DEPARTURE E/-W ft -35.90 -37.82 -39.71 -41.69 -43.66 ,269.24 21.68 349.79 274.28 -45.71 280.48 21.68 349.45 285.74 -47.81 291.44 21.75 349.56 296.93 -49.88 302.34 22.23 349.37 308.06 -51.95 313.98 22.72 349.64 319.93 -54.15 SUN FISH #3 DISPLACEMENT at ft 222.60 233.05 243.66 255.07 266.39 278.06 289.72 301.09 312.41 324.48 325.55 22.35 349.20 331.74 -56.35 336.49 336.99 22.67 349.04 343.42 -58.60 348.38 348.42 23.14 349.03 355.10 -60.86 360.27 360.99 23.29 349.22 367.93 -63.32 373.34 372.90 23.77 348.79 380.09 -65.69 385.73 -68.12 -70.66 -78.83 -86.59 -94.83 384.93 24.39 348.84 392.38 397.57 24.76 348.88 405.29 439.17 25.95 349.35 447.77 478.55 26.02 348.80 487.97 517.93 26.44 348.05 528.23 -103.63 -112.93 -122.18 -131.46 -141.21 557.56 26.91 347.47 568.79 598.39 27.40 347.44 610.59 639.80 27.95 347.93 652.96 681.60 28.27 347.60' 695.74 724.73 28.97 347.47 739.89 -149.16 -158.76 -168.01 -177.36 -186.86 760.21 29.27 347.84 776.20 803.40 29.01 347.66 820.40 845.65 28.59 348.19 863.62 888.04 28.89 347.47 906.99 930.82 28.42 348.04 950.77 398.25 411.40 454.65 495.59 536.68 578.15 620.94 664.30 708.05 753.24 790.41 835.62 879.81 924.17 968.96 AZIMUTH deg 350.72 350.66 350.62 350.59 350.57 350.54 350.50 350.46 350.43 350.39 350.36 350.32 350.27 350.23 350.19 350.15 350.11 350.02 349.94 349.82 349.67 349.52 349.40 349.30 349.19 349.12 349.05 348.99 348.94 348.88 DLS deg/ 10Oft 1.70 2.10 1.95 2.15 0.40 0.25 0.40 0.28 1.61 1.59 1.31 1.05 1.54 0.50 1.64 2.01 1.18 1.19 0.27 0.57 0.58 0.53 0.63 0.38 0.74 0.46 0.30 0.53 0.49 0.58 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 3845.06 93.8 3633.69 3939.38 94.3 3716.88 4033.07 93.7 3799.79 4126.76 93.7 3882.83 4220.79 94.0 3966.24 4314.18 4408.56 4500.62 4593.29 4687.46 4779.30 4871.74 4963.52 5054.52 5148.79 5242.13 5336.93 5430.64 5523.84 5617.35 5708.19 5801o99 5894.98 5989.65 6082.21 6176.92 6271.89 6365.57 6460.14 6554.53 93.4 4049.28 94.4 4133.39 92.1 4215.55 92.7 4298.36 94.2 4382.68 91.8 4465.19 92.4 4548.31 91.8 4630.88 91.0 4712.98 94.3 4798.18 93.3 4882.54 94.8 4968.18 93.7 5052.75 93.2 5136.76 93.5 5220.83 90.8 5302.31 93.8 5386.32 93.0 5469.39 94.7 5553.85 92.6 5636.39 94.7 5720.81 95.0 5805.33 93.7 5888.55 94.6 5972.44 94.4 6056.03 SUN FISH #3 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 973.39 28.27 347.62 994.33 1015.80 27.97 347.41 1037.74 1057.32 27.54 346.78 1080.27 1098.63 27.61 347.83 1122.58 1140.07 27.40 347.40 1164.99 DEPARTURE DISPLACEMENT at E/-W ft ft -196.26 1013.51 -205.86 1057.96 -215.61 1101.58 -225.14 1144.94 -234.45 1188.35 1180.78 27.05 347.31 1206.68 1221.47 26.91 346.55 1248.38 1260.82 26.73 346.16 1288.74 1300.23 26.62 346.42 1329.16 1339.96 26.25 346.44 1369.91 AZIMUTH deg 348.83 348.78 348.71 348.66 348.62 1378.19 25.86 346.33 1409.11 1416.54 26.05 346.54 1448.44 1454.63 25.73 347.29 1487.48 1492.06 25.35 347.80 1525.79 1530.62 25.33 348.04 1565.24 DLS deg/ 100ft 0.26 0.33 0.56 0.53 0.31 1568.79 25.35 347.68 1604.30 1607.65 25.44 348.08 1644.04 1646.24 25.59 347.85 1683.52 1684.78 25.72 347.74 1722.96 1723.94 26.22 348.24 1763.01 -243.80 1231.06 348.58 0.38 -253.49 1273.85 348.52 0.39 -263.29 1315.36 348.45 0.27 -273.15 1356.94 348.39 0.17 -282.98 1398.83 348.33 0.40 1762.35 26.25 347.94 1802.31 1802.22 26.56 347.77 1843.09 1842.17 26.87 348.05 1883.97 1883.09 26.84 348.14 1925.81 1923.16 26.97 347.96 1966.80 -292.47 1439.15 348.27 -301.96 1479.58 348.22 -311.04 1519.65 348.19 -319.50 1558.88 348.17 -327.94 1599.23 348.17 1964.22 26.94 348.13 2008.80 2005.70 27.32 348.53 2051.20 2046.96 27.34 348.69 2093.37 2088.92 27.65 349.19 2136.22 2131.11 27.70 349.30 2179.29 -336.35 1639.17 348.16 -344.88 1679.83 348.15 -353.30 1720.20 348.15 -361.84 1760.55 348.14 -370.35 1801.49 348.14 -378.64 1841.65 348.14 -387.42 1883.37 348.13 -396.18 1925.17 348.12 -405.00 1967.94 348.12 -413.68 2009.83 348.12 -422.57 2052.76 348.12 -431.33 2096.06 348.12 -439.82 2139.07 348.13 -448.19 2182.73 348.15 -456.37 2226.56 348.17 0.43 0.23 0.50 0.48 0.11 0.16 0.21 O. 19 0.14 O. 58 0.15 0.34 0.35 0.05 0.17 0.09 0.44 0.09 0.40 0.08 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 6648.97 6741.72 6837.20 6930.11 7024.74 7118.66 7210.32 7304.46 7398.52 7490.51 7585.59 7679.74 7774.30 7870.21 7966.75 8062.89 8159.71 8254.42 8317.35 8413.49 8509.06 8603.20 8699.57 8795.93 8848.07 8973.00 9029.00 9128.00 9221.00 9318.00 94.4 6139.53 92.8 6221.30 95.5 6305.38 92.9 6387.10 94.6 6469.98 93.9 6552.10 91.7 6632.32 94.1 6714.68 94.1 6796.94 92.0 6877.36 95.1 6960.52 94.1 7042.84 94.6 7125.34 95.9 7208.76 96.5 7292.48 96.1 7375.80 96.8 7459.95 94.7 7542.66 62.9 7597.80 96.1 7682.28 95.6 7766.64 94.1 7849.93 96.4 7935.48 96.4 8021.54 52.1 8068.29 124.9 8180.33 56.0 8230.62 99.0 8319.97 93.0 8404.20 97.0 8491.83 SUN FISH ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD********TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLACEMENT SECTION INCLN. N/-S E/-W ft deg deg ft ft ft 2173.57 27.99 349.24 2222.63 -464.59 2270.67 2215.66 28.33 348.95 2265.61 -472.87 2314.44 2259.15 28.26 348.93 2310.03 -481.56 2359.69 2301.62 28.55 348.88 2353.41 -490.06 2403.89 2345.44 29.16 348.48 2398.19 -499.03 2449.55 2389.21 28.90 349.18 2442.89 -507.86 2495.13 2431.89 28.98 349.35 2486.47 -516.12 2539.47 2475.75 28.97 348.93 2531.25 -524.71 2585.06 2519.57 29.04 348.90 2576.00 -533.48 2630.67 2562.50 29.06 348.98 2619.85 -542.05 2675.34 2606.72 28.92 348.31 2665.03 -551.13 2721.42 2650.51 29.15 348.58 2709.80 -560.28 2767.11 2694.86 29.37 348.69 2755.11 -569.39 2813.33 2740.24 29.76 348.38 2801.49 -578.80 2860.65 2786.27 29.96 348.19 2848.56 -588.56 2908.72 2832.23 29.89 348.56 2895.53 -598.22 2956.68 2878.16 29.40 348.57 2942.47 -607.72 3004.57 2922.37 28.89 348.33 2987.67 -616.96 3050.70 2951.41 28.74 348.02 3017.36 -623.17 3081.04 2995.21 28.29 347.26 3062.19 -632.99 3126.93 3037.99 27.77 347.34 3106.00 -642.87 3171.83 3079.93 27.79 348.49 3148.90 -652.05 3215.71 3122.45 27.03 348.46 3192.37 -660.92 3260.07 3163.95 26.45 347.93 3234.80 -669.79 3303.42 3186.02 26.12 347.83 3257.38 -674.63 3326.50 3239.08 26.40 349.70 3311.58 -685.40 3381.77 3262.78 25.80 348.70 3335.78 -690.01 3406.40 3303.89 25.20 350.80 3377.72 -697.60 3449.00 3342.40 25.00 354.40 3416.82 -702.68 3488.33 3383.56 25.80 359.30 3458.33 -704.94 3529.45 at AZIMUTH deg 348.19 348.21 348.22 348.24 348.25 348.26 348.27 348.29 348.30 348.31 348.32 348.32 348.32 348.33 348.33 348.33 348.33 348.33 348.33 348.32 348.31 348.30 348.30 348.30 348.30 348.31 348.31 348.33 348.38 348.48 DLS deg/ 100ft 0.31 0.40 0.08 0.31 0.68 0.46 0.12 0.22 0.08 0.04 0.37 0.28 0.23 0.44 0.23 0.21 0.50 0.55 0.34 0.60 0.54 0.57 O. 79 0.65 0.64 0.70 1.33 1.10 1.66 2.32 PAGE NO. MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 9414.00 96.0 8578.13 9510.00 96.0 8664.24 9605.00 95.0 8749.12 9702.00 97.0 8835.59 9798.00 96.0 8921.05 9900.00 9995.00 10085.00 10179.00 10273.00 10370.00 10468.00 10561.00 10657.00 10756.00 10852.00 10948.00 11043.00 11133.00 11232.00 11328.00 11424.00 11522.00 11616.00 11712.00 11904.86 12001.56 12096.47 12195.62 12288.07 102.0 9011.69 95.0 9096.14 90.0 9176.08 94.0 9259.46 94.0 9342.88 97.0 9428.92 98.0 9515.65 93.0 9597.76 96.0 9682.21 99.0 9769.21 96.0 9853.66 96.0 9937.94 95.0 10021.23 90.0 10100.33 99.0 10187.58 96.0 10272.69 96.0 10358.64 98.0 10447.17 94.0 10532.63 96.0 10620.54 192.9 10798.53 96.7 10887.83 94.9 10975.03 99.1 11065.79 92.5 11150.34 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD********TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S ft deg deg ft 3425.54 26.20 6.30 3500.30 3467.88 26.30 11.20 3542.23 3510.17 27.10 14.00 3583.87 3553.40 26.80 16.90 3626.23 3596.09 27.40 18.10 3667.94 SUN FISH #3 DEPARTURE DISPLACEMENT at E/-W ft ft -702.87 3570.17 -696.42 3610.04 -687.09 3649.14 -675.39 3688.59 -662.24 3727.24 3641.64 27.20 18.30 3712.38 3683.91 27.30 19.00 3753.59 3724.03 27.40 19.00 3792.69 3766.08 27.60 19.70 3833.64 3808.00 27.30 19.70 3874.43 AZIMUTH deg 348.65 348.88 349.15 349.45 349.77 3851.30 27.70 19.90 3916.58 3895.41 27.80 19.80 3959.50 3937.57 28.20 20.40 4000.50 3981.52 28.60 21.00 4043.21 4027.00 28.40 20.40 4087.40 -647.62 3768.44 350.10 -633.71 3806.71 350.42 -620.25 3843.07 350.71 -605.87 3881.22 351.02 -591.26 3919.29 351.32 4071.02 28.40 20.40 4130.19 4115.33 28.80 20.40 4173.26 4159.34 28.70 20.80 4216.04 4200.64 28.30 21.10 4256.14 4245.54 28.10 21.50 4299.73 -576.09 3958.72 351.63 -560.60 3998.98 351.94 -545.59 4037.53 352.23 -529.45 4077.72 352.54 -512.75 4119.43 352.85 4288.00 27.00 22.50 4340.90 4328.79 25.90 22.50 4380.40 4368.80 24.90 23.20 4419.14 4405.90 24.30 23.90 4455.01 4442.17 23.10 26.00, 4490.00 -496.84 4159.97 353.14 -480.82 4200.87 353.43 -464.74 4241.57 353.71 -449.39 4279.80 353.97 -432.39 4321.42 354.26 4511.11 22.19 27.66 4556.26 4545.14 22.93 29.23 4588.87 4579.18 23.59 30.28 4621.41 4614.92 23.88 32.54 4655.46 4647.94 23.85 33.45 4686.83 -415.77 4360.76 354.53 -399.40 4398.57 354.79 -383.09 4435.71 355.05 -367.45 4470.14 355.28 -351.19 4503.71 355.53 -317.70 4567.32 356.01 -300.03 4598.67 356.26 -281.42 4629.97 356.52 -260.62 4662.75 356.80 -240.25 4692.98 357.07 DLS deg/ 100ft 3.22 2.26 1.57 1.39 0.85 0.22 0.35 0.11 0.40 0.32 0.42 0.11 0.53 0.51 0.35 0.02 0.42 0.23 0.47 0.28 1.24 1.15 1.07 0.71 1.53 0.58 0.99 0.82 0.96 0.40 FINAL WELL REPORT PHILLIPS PETROLEUM COMPANY SUNFISH NO. 3 COOK INLET, ALASKA NOVEMBER 19, 1993 TO MARCH 4,1994 THE INFORMATION, INTERPRETATIONS, RECOMMENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORMANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. BAKER HUGHES I NT~,.~¢~~ .9~:~<~/z~ '~ 0 '/~ z~.~zDOUG FORSTER APPROVED BY: JOHN MORRIS ORiGiNAL EXECUTIVE SUMMARY THE SUNFISH NO. 3 WELL WAS DRILLED FROM THE PHILLIPS TYONEK PLATFORM IN THE COOK INLET, ALASKA BY PHILLIPS PETROLEUM COMPANY. ARCO ALASKA INC. WAS A PARTNER IN THE WELL. IT WAS SPUD ON NOVEMBER 19, 1993, AND REACHED A TOTAL DEPTH OF 14,705' MD (13,285' TVD) MARCH 4, 1994. PRIMARY OBJECTIVES WERE THE "SUNFISH SANDS" AND THE "NORTH FORELAND SANDS". THE GAS SANDS CURRENTLY BEING PRODUCED ON THE TYONEK PLATFORM WERE PENETRATED IN THE UPPER PART OF THE WELL. HYDROCARBONS WERE ENCOUNTERED IN THE MIDDLE GROUND SHOALS MEMBER OF THE TYONEK FORlW~ATION, THE "SUNFISH SAND" AND IN ONE SAND IN THE "NORTH FORELANDS SANDS". FORMATIONS ENCOUNTERED WERE, FROM SURFACE TO TD: THE STERLING; BELUGA; AND TYONEK FORMATIONS. TESTING OF ZONES OF INTEREST WAS TO BE CONDUCTED AFTER BAKER HUGHES INTEQ PERSONNEL HAD LEFT LOCATION. TABLE OF CONTENTS PAGE INTRODUCTION ......................................... 1 SL,m~iARY OF DATA ...................................... 2 METHODOLOGY .......................................... 3 ~DLOG ....................................... 3 DRILL DATA ACQUISITION ....................... 3 COI, HVlUNICATIONS ............................... 3 SAMPLING .................................... 3 STERLING FORMATION ........................... 5 LITHOLOGY ............................ 5 DRILL RATE AND GAS DATA .............. 6 OIL AND GAS SHOWS .................... 6 BELUGA FORMATION ............................. 6 LITHOLOGY ............................. 6 DRILL RATE AND GAS DATA .............. 7 OIL AND GAS SHOWS .................... 7 TYONEK FORMATION ............................. 8 LiTHOLOGY ............................ 8 CHUITNA MEMBER ....................... 8 MIDDLE GROUND SHOALS MEMBER .......... 8 LOWER TYONEK ......................... 9 DRILL RATE AND GAS DATA .............. 9 OIL AND GAS SHOWS ................... 10 CONCLUSION .......................................... 11 APPENDICES I · II. III. IV. V. SHOW REPORTS DRILL RECORD SAMPLE SHIPMENTS BIT RECORD LOGS (FORMATION EVALUATION LOG (MD),FORMATION EVALUATION LOG (TVD), DRILLING DATA LOG, PRESSURE DATA LOG) INTRODUCTION THE SUNFISH NO. 3 WELL IS ONE OF A SERIES OF DELINEATION WELLS FOR THE SUNFISH DISCOVERY. PHILLIPS PETROLEUM COMPANY AND ARCO ALAKA, INCOPORATED WERE PARTNERS IN THE WELL. THE WELL WAS DRILLED FROM THE PHILLIPS TYONEK PLATFORM IN ALASKA'S COOK INLET. THE PLATFORM IS LOCATED APROXIMATELY 10 MILES WEST OF THE KENAI PENINSULA, AND IS THE MOST NORTHERN PLATFORM IN THE-INLET. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 1249' FNL, 980' FWL, IN SECTION 6, TllN, R9W, SEWEARD MERIDIAN. PROPOSED BOTTOMHOLE LOCATION WAS 4150' FSL, 1550' FEL IN SECTION 31, T12N, Rgw, SEWARD MERIDIAN. PRIMARY OBJECTIVE HORIZONS OF THIS WELL WERE DELINEATION OF THE "SUNFISH" AND "NORTH FORELAND" SANDS. THESE SANDS WERE PROJECTED TO BE AT APROXIMATELY 12280 FEET AND 12660 FEET SUBSEA, RESPECTIVELY. DRILLING BEGAN NOVEMBER 19, 1993 AND TOTAL DEPTH WAS REACHED MARCH 4, 1994. CASING WAS SET AS FOLLOW: 30" CONDUCTOR AT 40?' RKB, 20 "AT 2622' MD (2553' TVD), 13 3/8" AT 8909' MD (8123' TVD), 9 5/8" AT 12137' MD (11012' TVD), AND A 7" LINER FROM 11836' TO 13939' .MD (10725' - 12602' TVD) THE PRESENCE OF HYDROCARBONS IN THE MIDDLE GROUND SHOALS MEMBER OF THE TYONEK FORMATION, IN THE "SUNFISH SAND", AND "NORTH FORELAND SANDS", WERE INDICATED BY CUTTINGS AND GAS ANALYSIS. CHEMICALLY TREATED ~.~DS PARTIALLY MASKED THE PRESENCE OF FREE OIL IN THE MUD OR ON DRILL CUTTINGS. FURTHER EVALUATION IS TO BE PERFORMED BY AND CASED HOLE TESTING OF THE W~LL. - 1- SUMM~Y OF PERTINENT DATA WELL NAME: API NUMBER: OPERATOR: PARTNERS: CONTRACTOR: LOCATION: ELEVATION: CASING: CONVENTIONAL CORES: DATE SPUDDED: DATE TOTAL DEPTH REACHED: TOTAL DEPTH: ORIGINAL HOLE: SIDETRACK NO. 1: EXLOG GEOLOGISTS: FINAL WELL STATUS: SUNFISH NO. 3 50-883-20090 PHILLIPS PETROLEUM COMPANY ARCO ALASKA, INCORPORATED POOL ARCTIC ALASKA RIG 429 PHILLIPS TYONEK PLATFORM SURFACE - 1249' FNL, 980' FWL SEC 6, TllN, R9W SEWARD MERIDIAN TOTAL 232' ABOVE SEA FLOOR w~ D~.~H - 1~ 9 MLLW RKB - 132' ABOVE MSL 30" CONDUCTOR AT 407' MD RKB 20" CSG AT 2622' MD ( 2553' TVD) 13 3/8" CSG AT 8909' MD ( 8123' TVD) 9 5/8" CSG AT 12137' MD (11012' TVD) 7" LINER FROM 11836' MD (10725' TVD) TO 13939' MD (12602' TVD) CORE NO. 1 12285' - 12306' MD CORE NO. 2 12405' - 12465' MD CORE NO. 3 13626' - 13641' MD CORE NO. 4 13641' - 13659' MD CORE NO. 5 13659' - 13680' MD CORE NO. 6 13680' - 13800' MD CORE NO. 7 13681' - 13731' MD NOVEMBER 19, 1993 MARCH 4, 1994 14705' MD, 13285' TVD 407' MD TO 14014' MD (12639' TVD) 13457' MD (12188'TVD) TO 14705' MD (13285'TVD) SAM HEWITT, GARY HAMBURG, RALPH WINKELMAN, DOUG FORSTER, BOB ROURKE, FERGUS CONWAY RUN 7" LINER TO TD AND TEST WELL. -2- METHODOLOGY GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLSITE USING BAKER HUGHES INTEQ'S DRILL MONITOR SYSTEM (DMS). THE DMS SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT USED IN ACQUISITION, COMPILATION AND OUTPUT OF DRILLING AND GEOLOGIC DATA. ADDITIONAL LITHOLOGIC AND HYI)ROCABBON EVALUATION WAS PROVIDED BY BHI'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION FOLLOW BHI'S "MUDLOGGING PRINCIPLES AND INTERPRETATION" MANUAL (MS-196). MLq) LOG THE MUDLOG FORMAT WAS DESIGNED BY BAKER HUGHES INTEQ FOR PHILLIPS PETROLEUM TO THEIR SPECIFICATIONS FOR FORMAT AND CONTENT. DATA DISPLAYED ON THE LOG INCLUDES: PERCENTAGE LITHOLOGY, INTERPRETIVE LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHRO~iTOGRAPH DATA, AND RESISTIVITY AND GAMMA RAY DATA PROVIDED BY ANADRILL AT THE END OF EACH MWD RUN. CHROMATOGRAPH AND RESiSTiViTY DATA ARE PLOTTED LOGARITt~MICALLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LINEARLY. LOGS ARE PLOTTED AT A SCALE OF 2 INCHES PER 100 FEET (1:600), WITH THE EXCEPTION OF THE PRESSURE DATA LOG WHICH IS PLOTTED AT A SCALE OF 1 INCH PER 250 FEET (1:3000). DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (BOP) USING THE KELLY HEIGHT SYSTEM, ROTARY SPEED, HOOKLOAD, WEIGHT ON BIT, TORQUE (MINIMUM, MAXIMUM, AND AVERAGE), MUD FLOW IN AND OUT, MUD TEMPERATURE IN AND OUT, STANDPIPE PRESSURE, CASING PRESSURE, PUMP STROKES, AND ',~D PIT VOLUME. ALSO THREE H2S STATIONS WERE MONITORED AT ALL TIMES. DRILL DATA IS PLOTTED ON THE DRILLING PARAMETERS LOG. COMMUNICATIONS BAKER HUGHES INTEQ PROVIDED FOUR ONSITE TERMINALS FOR THE DISPLAY OF ALL DRILLING PARAMETERS. WYSE TERMINALS WERE PROVIDED FOR THE COMPANY MAN, PHILLIPS GEOLGIST, AND THE CONTRACT MUD ENGINEER. AN EXPLOSION PROOF HAZARDOUS AREA DISPLAY (HAD) WAS PROVIDED THE DRILLER ON THE RIG FLOOR. ALL MUDLOG AND DRILLING DATA COLLECTED WAS TRANSMITTED BY MODEM DAILY TO PHILLIPS IN KENAI AND HOUSTON, AND TO ARCO IN ANCHORAGE. SAMPLING WET AND DRY SAMPLES WERE COLLECTED AT 30 FOOT INTERVALS FROM 407' TO 8950'. TEN FOOT SAMPLES WERE COLLECTED FROM 8950' TO 14014' IN THE -3- ORIGINAL HOLE, AND FROM 13460' TO 14705' IN THE SIDETRACKED HOLE. THREE SETS OF WET AND FIVE SETS OF DRY SAMPLES WERE COLLECTED TO $950'. FOUR SETS OF WETS ~4ERE COLLECTED BELOW 8930' (AN ADDITIONAL PHILLIPS QFT SET). A SET OF GEOCHEMICAL CANNED SAMPLES WERE COLLECTED AT 60' INTERVALS FOR PHILLIPS AND AT 30' INTERVALS FOR ARCO FROM SURFACE TO TOTAL DEPTH. A SET OF SAMPLEX TRAYS WERE COLLECTED FOR BOTH PHILLIPS AND ARCO. SAMPLES WERE SHIPPED TO PHILLIPS' CORE STORAGE BUILDING IN BARTLESVILLE, OKLAHOMA AND TO ARCO'S BAYVIEW GEOLOGIC FACILITY IN ANCHORAGE, ALASKA. THE STATE OF ALASKA SET OF DRY SAMPLES WERE SHIPPED TO THE ALASKA OIL AND GAS CONSERVATION ON PORCUPINE DRIVE IN ANCHORAGE. S~PLE SHIPMENT RECORDS ARE IN APPENDIX III. FORMATION EVALUATION LOGGING COI~MENCED AT 2130 HOURS, NOBEMBER 18, 1993, AT 407 FEET MEASURED DEPTH. THE FORMATIONS DRILLED (FROM SURFACE TO TD, RESPECTIVELY) WERE: THE STERLING FORMATION; THE BELUGA FORMATION; AND THE TYONEK FORMATION. ALL DEPTHS ARE REFERENCED FROM THE ROTARY KELLY BUSHING (RKB) WHICH IS 232 FEET ABOVE THE SEA FLOOR. FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE. ALL FORMATIONS ARE TERTIARY IN AGE. STERLING FORMATION LITHOLOGY THE STERLING FORMATION (407'- 4802' MD, 407'- 4485' TVD) IN THE SUNFISH #3 WELL CONSISTED OF THREE DISTINCT SECTIONS: THE UPPER ~T AU ~T SECTION CONSISTED OF CONGLOMERATE, ~-~, AND SAND WITH ~,~NOR COAL INTERBEDS. THE MIDDLE SECTION CONSISTED OF SAND, SILTSTONE AND CLAY WITH MINOR COAL INTERBEDS. THE LOWER SECTION (COOK INLET SANDS) CONSISTED OF GAS RICH SANDS, MORE ABUNDANT COAL INTERBEDS, AND LESS CLAY AND SILTSTONE. THE UPPER, CONGLOMERATIC, SECTION WAS ENCOUNTERED FROM 407' TO 2617' MEASURED DEPTH (407' - 2550' TVD). THE CONGLOMERATE AND COARSE SANDS CONSISTED OF ABUNDANT LITHIC FRAGMENTS, QUARTZ, AND CHERT. THE CONGLOMERATE AND SANDS WERE UNCONSOLIDATED AND PRESUMABLY CONTAINED A SILT AND CLAY MATRIX. LITHIC FRAGMENTS RANGED FROM BLUE TO GREEN, BLACK AND GRAY AND WERE PROBABLY OF VOLCANIC ORIGIN. CLAY AND SILT IN THIS SECTION WAS PRESENT AS A MATRIX FOR CONGLOMERATE AND SANDS, AND ALSO AS DISTINCT INTERBEDS IN THE LOWER PORTION OF THE SECTION. MINOR COAL INTERBEDS WERE ENCOUNTERED BELOW 1390 FEET (MD). THE MIDDLE, SAND AND SILTSTONE, SECTION WAS ENCOUNTERED FROM 2617' TO 3734' MEASURED DEPTH (2550' - 3545' TVD). SANDS IN THIS SECTION WERE GENERALLY FINER GRAINED THAN THE PREVIOUS SECTION. SAND RANGED FROM VERY FINE TO MEDIUM GRAINED, WITH OCCASIONAL COARSE GRAINED AND CONGLOMERATIC INTERVALS. THE SAND CONSISTED OF QUARTZ AND FELDSPAR WITH ABUNDANT VOLCANIC LITHIC FRAGMENTS. THE SAND WAS GENERALLY SUBANGULAR, MODERATELY SORTED, UNCONSOLIDATED AND PRESUMED TO HAVE A MATRIX OF CLAY AND SILT. SILTSTONE AND CLAY INTERBEDS WERE ALSO PRESENT. THE SILTSTONE WAS A MEDIL~ GRAY BROWN, SANDY SILTSTONE, WITH COMMON CARBONACEOUS LAMINATIONS. THE CLAY AND CLAYSTONE WAS GENERALLY SOFT, LIGHT GRAY BROWN, AND OCCASIONALLY WITH CARBONACEOUS SPECKS OR LAMINATIONS. AN INCREASING AMOUNT OF COAL WAS PRESENT IN THE LOWER PORTION OF THIS SECTION. -5 - THE LOWER STERLING, OR COOK INLET SANDS, WAS ENCOUNTERED FROM 3734' TO 4802' MEASURED DEPTH (3545' - 4485' TVD). THIS SECTION WAS CHARACTERIZED BY A DISTINCT INCREASE IN COAL AND A DECREASE IN CLAY AND SILT MATRIX, AS W~LL AS AN INCREASE IN BACKGROUND GAS. THE SAND/SANDSTONE IN THIS SECTION WAS AGAIN A MIXTURE OF QUARTZ, FELDSPAR, AND VOLCANIC LITHIC FRAGMENTS. SAND GRAINS RANGED FROM FINE TO MEDIUM GRAINED, SUBANGULAR TO SUBROUNDED, POOR TO MODERATELY SORTED AND WERE COMMONLY UNCONSOLIDATED. CLAY MATRIX AND CALCITE CEMENT WERE ALSO PRESENT. COAL (AND COAL SLOUGH) DRAMATICALLY INCREASED IN THIS SECTION. COAL AND COAL SLOUGH WAS PRESENT IN ALMOST EVERY SAMPLE. CLAY/CLAYSTONE AND SILTSTONE WERE ALSO PRESENT IN MUCH LESSER .%MOUNTS IN THIS SECTION. DRILL RATE AND GAS DATA DRILL RATES RANGED FROM 60 TO 500+ FEET PER HOUR THROUGH THE STERLING FORMATION. DRILL RATES AVERAGED APROXIMATELY 250 FEET PER HOUR. LOWER DRILL RATES OCCURRED iN THE COOK iNLET SANDS (LOWER STERLING) LIKELY DUE TO THE GREATER INDURATION OR CEMENTATION OF THESE ROCKS. DITCH GAS READINGS RANGED FROM 1 TO 1485 UNITS OF GAS. GAS THROUGHOUT THE UPPER TWO SECTIONS OF THE STERLING FORMATION WAS VERY LOW, WITH A HIGH OF 28 UNITS. .WHILE IN THE COOK INLET SANDS, GAS READINGS AVERAGED 75 TO 150 UNITS. GAS INCREASED DRAMATICALLY AT THE TOP OF THE COOK INLET SANDS. THE MAXIMUM GAS OF 1485 UNITS WAS ENCOUNTERED AT 4102 FEET MD (3860 FEET TVD). CHROMATOGRAPHIC BREAKDOWN OF THE GAS INDICATED IT WAS ENTIRELY METHANE (C1). THE IC4 (ISO BUTANE) ORIGINALLY LOGGED FROM 3719' TO 4159' MD, WERE DUE TO CHROMATOGRAPH ERROR. BLENDER GAS READINGS WERE USED TO DISTINGUISHING COAL BEDS FROM COAL SLOUGH. BLENDER GAS INCREASES SEEMED TO CORRELATE WELL WITH FRESHLY DRILLED COALS. OIL AND GAS SHOWS GAS SHOWS WERE ENCOUNTERED IN THE COOK INLET SANDS. THESE SANDS ARE CURRENTLY BEING PRODUCED ON THE TYONEK PLATFORM. NO OIL SHOWS WERE ENCOUNTERED IN THE STERLING FORMATION. OCCASIONALLY MUD ADDITIVES DID FLUORESCE AND CUT (SPECIFICALLY BORE-PLATE). BELUGA FORMATION LITHOLOGY THE BELUGA FORMATION (4801'- 8686' .MI), 4485'- 7924' TVD) CONSISTED OF TWO DISTINCT SECTIONS: AN UPPER SECTION COMPRISED PRIMARILY OF SANDS/SANDSTONE, AND A LOWER SECTION COMPRISED OF SILTSTONE AND CLAYSTONE. -6- THE UPPER, SANDY, SECTION OF THE BELUGA FORMATION WAS ENCOUNTERED FROM 4801' TO 7407' MEASURED DEPTH (4485'- 6810' TVD). THE SANDS WERE PREDOMINATELY COMPOSED OF QUARTZ AND FELDSPAR, WITH A LESSER PERCENTAGE OF LITHIC GRAINS AS COMPARED TO THE STERLING SANDS. THE SANDS RANGED FROM FINE TO MEDIUM GRAINED, WERE GENERALLY POORLY SORTED, AND SUBANGULAR TO SUBROUNDED. OCCASIONAL COARSE GRAINED AND ANGULAR SANDS WERE PRESENT. MATRIX WAS PRESUMABLY CLAY, AS SAND WAS GENERALLY UNCONSOLIDATED IN CUTTINGS SAMPLES. OCCASIONAL CALCITE CEMENTED SANDS WERE PRESENT. SILTSTONE AND COAL INTERBEDS WERE ALSO COMMON. THE LOWER, SILTSTONE, SECTION OF THE BELUGA FORMATION WAS ENCOUNTERED FROM 7407' TO 8686' MEASURED DEPTH (6810'- 7924' TVD). THE SILTSTONE IN THIS SECTION WAS LIGHT TO MEDIUM GRAY, AND RANGED FROM SOFT-CLAY RICH SILTSTONE TO HARD-CALCIC SILTSTONE. SILTSTONE COMMONLY CONTAINED HIGH PERCENTAGES OF VERY FINE GRAINED SAND, AND WHAT WAS PRESUMED TO BE VOLCANIC ASH. CARBONACEOUS LAMINATIONS WERE ALSO COMMON. CLAY AND CLAYSTONE FORMED GRADATIONAL INTERBEDS WITHIN THIS SECTION. COAL INTER- BEDS WERE ALSO COMMON, ESPECIALLY NEAR THE BASE OF THIS SILTY INTERVAL. DRILL RATE AND GAS DATA DRILL RATES IN THE UPPER BELUGA RANGED FROM 20 TO 300 FEET PER HOUR, DECREASING WITH DEPTH. AVERAGE DRILL RATES OVER THIS INTERVAL WERE APROXIMATELY 100 FEET PER HOUR. IN THE LOWER BELUGA, DRILL RATES RANGED FROM 5 TO 80 FEET PER HOUR, AVERAGING 15 FEET PER HOUR, AND WERE MUCH LESS VARIABLE THAN THE UPPER (SANDY) SECTION. DITCH GAS READINGS IN THE UPPER BELUGA WERE HIGH. GAS READINGS RANGED FROM 15 TO 2455 UNITS, AVERAGING 60 UNITS. MAXIMUM GAS OF 2455 UNITS WAS ENCOUNTERED AT 7002 FEET MD (6451' TVD). DITCH GAS IN THE LOWER BELUGA WAS SUBSTANTIALLY LOWER AND LESS VARIABLE. GAS READINGS RANGED FROM 10 TO 105 UNITS, AVERAGING 20 UNITS. CUTTINGS GAS WAS GENERALLY BELOW TEN UNITS, EXCEPT THROUGH FRESHLY DRILLED COALS. CHROMATOGRAPHIC BREAKDOWN OF THE GASSES SHOWED PREDOMINENTLY METHANE (C1). THERE WAS OCCASIONAL ETHANE (C2), AND PROPANE (C3) ASSOCIATED WITH COALS IN THE LOWER PART OF THE INTERVAL. OIL AND GAS SHOWS GAS FROM THIS FORMATION IS CURRENTLY BEING PRODUCED ON THIS PLATFORM. THERE WERE NO OIL SHOWS. THE MILKY WHITE TO YELLOW CUT FLUORESCENCE PRESENT IN MANY OF THE SAMPLES WAS DUE TO MUD ADDITIVES. - 7- TYONEK FORMATION LITHOLOGY THE TYONEK FORMATION (8686'- 14705' MD, 8180'- 13285' TVD) CONSISTED OF THREE DISTINCT SECTIONS: THE UPPER SECTION (CHUITNA MEMBER) CONTAINED INTERBEDDED SANDS, CLAY-RICH SILTSTONES, AND COALS; THE MIDDLE MEMBER (MIDDLE GROUND SHOALS) ALSO CONTAINED INTERBEDDED SANDS, SILTSTONES, AND COALS, WITH THE SILTSTONE BEING SOMEWHAT MORE INDURATED; THE LOWER SECTION (LOWER TYONEK) ALSO WAS AN INTERBEDDED SEQUENCE, BUT OF PRIMARY INTEREST WERE THE TWO OBJECTIVE SANDS (THE "SUNFISH" AND "NORTH FORELAND" SANDS). CHUITNA MEMBER THE CHUITNA MEMBER, UPPER SECTION OF THE TYONEK FORMATION, WAS ENCOUNTERED FROM 8686' TO 11347' MEASURED DEPTH (7924'- 10290' TVD). THIS SECTION CONTAINED INTERBEDDED CLAY-RICH SILTSTONES AND COAL, BECOMT~ ~ ~T~, ~ T~m ~ ~o BASE. ~,= ~REDv~.~A~,TLY ,~,~ERoEDDED SANDS AND COAL TOWARDS ~° THE CLAY-RICH SILTSTONE RANGED FROM LIGHT TO DARK GRAY AND GRAY-BROWN. IT WAS GENERALLY SOFT TO FIRM IN CUTTINGS SAMPLES, AND WAS CARBONACEOUS AND OCCASIONALLY SLIGHTLY CALCIC. VOLCANIC ASH (TUFF) WAS PRESENT IN THIN INTERBEDS AND AS MATRIX IN THE SILTSTONE. COAL AND CARBONACEOUS SHALE WERE PRESENT IN THIS SECTION IN VARYING BED THICKNESSES. SAND AND SANDSTONE INTERBEDS WERE PRESENT THROUGHOUT THE CHUITNA, BECOMING MORE CO.?~MON IN THE LOWER CHUITNA. SANDS RANGED FROM FINE TO COARSE GRAINED QUARTZ AND FELDSPAR, WITH GRAY, GREEN, AND RED VOLCANIC LITHIC FRAGMENTS. SANDS WERE POORLY TO MODERATELY SORTED, $UBROUNDED TO SUBANGULAR, AND WERE COMMONLY CEMENTED WITH CALCITE OR HAD AN ARGILLACEOUS MATRIX. MIDDLE GROUND SHOALS MEMBER THE MIDDLE GROUND SHOALS MEMBER, MIDDLE SECTION OF THE TYONEK FORMATION, WAS ENCOUNTERED FROM 11347' TO 12650' MEASURED DEPTH (10290'- 11490' TVD). THIS SECTION ALSO CONTAINED INTERBEDDED SANDS, SILTSTONES, AND COALS. THE SILTSTONES IN THIS SECTION WERE GENERALLY HARDER. THEY WERE ALSO DARKER IN COLOR, POSSIBLY INDICATING A GREATER CONCENTRATION OF CARBONACEOUS MATERIAL. COAL AND COAL SLOUGH IN THIS SECTION WAS VERY ABUNDANT. SANDS IN THE MIDDLE GROUND SHOALS RANGED FROM FINE TO COARSE GRAINED QUARTZ, FELDSPAR, AND VOLCANIC LITHIC FRAGMENTS. SANDS WERE POORLY TO MODERATELY SORTED, SUBROUNDED TO SUBANGUL~d{, AND CEMENTED WITH CALCITE AND ARGILLACEOUS MATRIX. TWO SANDS WERE CORED FROM 12285' TO 12306' MD, AND FROM 12405' TO 12465' WHICH CORRELATED WITH THE "C" SAND INTERVAL IN NEARBY WELLS. THESE SANDSTONES WERE LIGHT GREY, VERY FINE TO FINE GRAINED, HARD WITH A CALCAREOUS, CLAYEY MATRIX, AND HAD COMMON CARBONACEOUS PARTINGS. THEY HAD NO OIL SHOW. SANDSTONES DRILLED FROM 12502' - 12570' WERE LIGHT GREY, FRIABLE WITH A CLAY MATRIX, FINE TO COARSE GRAINED QUARTZ AND FELDSPAR, AND APPEARED TIGHT (CO~MON WHITE CLAY MATRIX). THEY APPEARED TO CONTAIN SOME LIGUID HYDROCARBONS LOWER TYONEK THE LOWER TYONEK SECTION WAS ENCOUNTERED FROM 11490' TO 14705' (TD) MEASURED DEPTH (12940'- 13285' TVD). THIS SECTION CONTAINED THE TWO OBJECTIVE SANDS FOR THE WELL, THE "SUNFISH" AND THE "NORTH FORELAND" SANDS. THIS SECTION AGAIN WAS AN INTERBEDDED SEQUENCE OF SANDSTONE, SILTSTONE, AND COAL. COMMON VOLCANIC TUFF AND REWORKED VOLCANIC TUFF WAS PRESENT. THE "SUNFISH" SAND WAS CORED BETWEEN 13623'MD TO 13683' MEASURED DEPTH (12304' -12371'TVD) IN THE ORIGINAL HOLE. IT WAS MEDIUM TO COARSE GRAINED AT THE TOP, FINING DOWNWARD. IT WAS ANGULAR TO SUBROUNDED FELDSPAR, QUARTZ, WITH MINOR LITHIC FRAGMENTS. THE SAND ...... ~, CO~ WAS MODERATELY WELL cnR~En AND APP?~ED LOORELY CONSOLIDATED T, ,,_ CUTTINGS (CORE CHIPS NOT EXAMINED BY BHI PESONNEL). IT APPEARED TO CONTAIN LIQUID HYDROCARBONS. IT WAS AGAIN CORED IN THE SIDE TRACKED HOLE FROM 13681' TO 13731'MD (12368' TO 12408' TVD). IT DID NOT APPEAR TO HAVE AS GOOD A HYDOCARBON SHOW IN THIS CORE. THE "NORTH FORELAND" SANDS WERE PRESENT IN 4 OR 5 LOBES OF SAND. IT WAS ENCOUNTERED FROM APROXIMATELY 14086' TO 14705' MEASURED DEPTH (12693'- 13285' TVD). SAND RANGED FROM FINE TO OCCASIONALLY MEDIUM GRAINED THE SANDSTONES CONSISTED OF VARYING PERCENTAGES OF QUARTZ, FELDSPAR, AND LITHIC GRAINS. THE SANDS RANGED FROM POORLY TO WELL SORTED, $UBANGULAR TO SUBROUNDED (EXCEPT WHERE BROKEN BY THE BIT). CALCITE CEMENT AND KALONITE (WHITE CLAY) MATRIX WERE THE CEMENTING AGENTS IN MOST OF THE "NORTH FORELAND" SANDS. OCCASIONAL SILICIOUS CEMENTED SANDSTONE OCCURED. THE SILTSTONE IN THE LOWER TYONEK SECTION WAS COMMONLY A DARK BROWN VERY CARBONACEOUS SILTSTONE, OCCASIONALLY BECOMING A DARK GRAY-BLACK CARBONACEOUS SHALE WITH DEPTH. COAL INTERLAMINATIONS WERE COMMON IN THE SILTSTONE AND SHALE. HOWEVER, DISTINCT COAL BEDS WERE MUCH LESS COMMON THAN PREVIOUS HOLE SECTIONS. DRILL RATE AND GAS DATA DRILL RATES IN THE CHUITNA M~MBER OF THE TYONEK RANGED FROM 8 TO 115 FEET PER HOUR, AVERAGING 15 FEET PER HOUR. THE RATES IN THIS SECTION WERE HIGHLY DEPENDENT ON THE SAND AND COAL CONTENT OF THE FORMATION BEING DRILLED. THE MIDDLE GROUND SHOALS MEMBER EXHIBITED DRILL RATES FROM 10 TO 150 FEET PER HOUR, AVERAGING 15 FEET PER HOUR. OCCASIONAL COALS DRILLED OVER 200' PER HOUR FOR 2 - 5 FEET. DRILL RATES IN THE LOWER TYONEK MEMBER RANGED FROM 2 TO 40 FEET PER HOUR, WITH AN OCCASIONAL COAL DRILLING AT 60 -?0' PER HOUR. AVERAGE DRILL RATE WAS 5-10 FEET PER HOUR. - 9- DITCH GAS FOR THE CHUITNA MEMBER RANGED FROM 5 TO 297 UNITS, AVERAGING 15 UNITS. GAS PEAKS IN THIS MEMBER WERE GENERALLY ASSOCIATED COAL INTERBEDS, AND CONTAINED C1 THROUGH C3. DITCH GAS FROM THE MIDDLE GROUND SHOALS MEMBER 'RANGED FROM 5 TO 314 UNITS, AVERAGING 10 UNITS. HIGHEST GAS READINGS WERE ASSOCIATED WITH THE SANDSTONES FROM 12502' TO 12573' ~ AND CHROMATOGRAPHY INDICATED THE PRESENCE OF METHANE THROUGH PENTHANE$ (C1 - C5) IN THIS INTERVAL (SEE SHOW REPORTS 1 AND 2, APPENDIX I). DITCH GAS IN THE LOWER TYONEK RANGED FROM 2 TO 195 UNITS. SANDSTONES FROM 13345' TO 13382' .MI), 13623' TO 13683' MD ("SUNFISH SANDS"), AND 14310' TO 14325' ~ ("NORTH FORELANDS SANDS"?) ALL HAD METHANE THROUGH PENTHANES (C1 - C5'S) PRESENT IN THEM (SEE SHOW REPORTS 3,4, AND 5 IN APPENDIX I). OIL AND GAS SHOWS PRESENCE OF OIL WAS INDICATED IN THE DITCH SAMPLES FROM THE SANDgTOMES IN THE T. mpp~,t~ ~o~00, - 12572' MD, ..... - ~o~o~ ,..~, 13623' - 13683' MD ("SUNFISH SAND"), AND 14310' - 14325' MD ("NORTH FORELAND SANDS"?). THE SHOWS ARE DETAILED IN SHOW REPORTS 1 THROUGH 5 IN APPENDIX I. THESE SHOWS WERE ACCOMPANIED BY HIGH DITCH GAS AND METHANE THROUGH PENTHANES (C1 - C5'S). THE SHOW IN THE "SUNFISH SAND", WHEN CORED IN THE ORIGINAL HOLE, APPEARED TO BE THE BEST IN THE WELL. - 10 - CONCLUSION IN CONCLUSION, SUNFISH NO. 3 WELL WAS DRILLED FROM NOVEMBER 19, 1993 TO MARCH 4, 1994 TO A TOTAL DEPTH OF 14705 FEET MEASURED DEPTH 13285 FEET TVD). THE THREE FORMATIONS PENETRATED WERE THE STERLING, BELUGA, AND TYONEK FORMATIONS. GAS SANDS WERE ENCOUNTERED IN THE STERLING (COOK INLET SANDS) AND THE BELUGA FORMATIONS. THE OBJECTIVE HORIZONS OF THE "SUNFISH SAND" AND "NORTH FORELAND SANDS" WERE PENETRATED. HDROCARBON SHOWS OCCURED IN THE MIDDLE GROUND SHOALS MEMBER OF THE TYONEK FORMATION, IN THE "SUNFISH SAND", AND IN ONE SAND IN THE "NORTH FORELAND SANDS". CASED HOLE TESTING WAS TO BE PREFORMED TO DETERMINE THE EXTENT AND QUALITY OF THESE SHOWS. - 11 - APPENDIX I SHOW REPORTS SHOW REPORT # 1 OIL COMPANY: PHILLIPS PETROLEUM CO. WELL#: SUNFISH #3 LOCATION:COOK INLET ALASKA DATE:l/23/94 TIME 0300 HRS INTERVAL: 12502 ' TO 12512 ' (MD) 12519 ' TO 12525 ' (MD) BIT SIZE: 8 1/2' BIT TYPE' SEC MM44NG BIT DIST: 35' MUD WEIGHT:13.5 ppg VISCOSITY: 58 FILTRATE: 6.8 WOB: 35 klb LOGGING COND:GOOD RPM: 90 PUMP PR:2705 T~'~ T ,~URS: 6 PORE PRES:12 1 ppg PUMP q~"' 100 BEFORE DURING AFTER ROP ft/hr 35 TOT GAS units 188 21 OIL IN MUD: NONE Cl ppm 1260 20526 4598 C2 ppm 882 154 C3 ppm 1520 168 C4 ppm 1201 74 C5 ppm 368 CHL ppm 3800 3800 ~800 LITHOLOGY SILTSTONE, MED - DK GY BRN, CLYEY SANDSTONE, CLR - LT GY, LSLY CONSL SW/ WHITE CLAY MATRIX SILTSTONE, MED - DK GY BRN, CLYEY SOLVENT CUT FLUOR' MED - BRIGHT YEL FLUOR: MEDIUM YELLOW INTENSITY' MODERATE UNWASHED SPL FLUOR: MEDIUM YELLOW TYPE & SPEED: MEDIUM WASHED SPL FLUOR: MEDIUM TO BRIGHT YEL NAT COLOR & RESIDUE: NO VIS CUT STAIN: NONE VISUAL POROSITY' LSLY CONSOLIDATED CUTTINGS DESCRIPTION: SS, CLR - TRANSL - LT GY, LSLY CONSL, F GR, SBANG - SBRND, MOD WELL SRTD. COMMENTS: APPEARS TO BE A FAIR, LIGHT OIL SHOW. TVD INTERVALS OF SHOW 11346' - 11356' 11362' - 11367' .RATING: FAIR LOGGING GEOLOGIST:S. HEWITT, D. FORSTER SHOW REPORT # 2 OIL COMPANY: PHILLIPS PETROLEUM CO. WELL#: SUNFISH #3 DATE:l/23/94 BIT SIZE: 8 1/2' BIT TYPE: SEC MM44NG BIT DIST: 85' BEFORE DURING AFTER ROP ft/hr 43 TOT GAS units 7 314 11 LOCATION' COOK INLET ALASKA TIME 0720 HRS INTERVAL: 12550 ' TO 12573 ' (MD) 11390 ' TO 11411 ' (TVD) MUD WEIGHT:13.5 ppg VISCOSITY: 58 FILTRATE: 6.8 EST. PgRE PRES'!2.! ppg WOB: 40 klb LOGGING COND:GOOD RPM: 90 PUMP PR:2650 PUMP S?M:IO0 C1 ppm 724 34848 2642 C2 ppm 18 1743 22 C3 ppm 37 3122 3O C4 ppm 33 2467 17 C5 ppm TR 768 CHL ppm 3800 3800 3800 LITHOLOGY SILTSTONE, MED - DK GY BRN, CLYEY, MNR SANDY SILTSTONE SANDSTONE, CLR - LT GY, LSLY CONSL SW/ WHITE CLAY MATRIX, P - MOD SRT SILTSTONE, MED - DK GY BRN, CLYEY, MNR COAL OIL IN MUD' TRACE VERY LIGHT BROWN SOLVENT CUT FLUOR' MILKY YELLOW FLUOR: MEDIUM YELLOW INTENSITY' MODERATE - BRIGHT UNWASHED SPL FLUOR: MEDIUM YELLOW TYPE & SPEED: MEDIUM TO INSTANT WASHED SPL FLUOR' MEDIUM TO BRIGHT YEL NAT COLOR & RESIDUE: NO VIS CUT COLOR STAIN: RARE VERY LIGHT BROWN VISUAL POROSITY: LSLY CONSOLIDATED CUTTINGS DESCRIPTION: SS, CLR - TRANSL - LT GY, LSLY CONSL, VF - CSE GR, PRED MED GR, SBANG - SBRND, P - MOD WELL SRTD, ABNT ARG MTX, WHT CLY. COI%MENTS: APPEARS TO BE A GOOD, LIGHT OIL SHOW. RATING: GOOD ; LOGGING GEOLOGIST:S. HEWITT, D. FORSTER SHOW REPORT # 3 OIL COMPANY: PHILLIPS PETROLEL~ CO. WELL#: SUNFISH #3 LOCATION:COOK INLET ALASKA DATE:l/27/94 TIME: 20:41HRS SHOW INTERVAL:13345 ' TO 13353 ' (MD) 12099 ' TO 12105 ' (TVD) BIT SIZE:8 1/2" BIT TYPE: HYCALOG BIT DIST: 729' HOURS: 74 MUD WEIGHT: 13.5ppg VISCOSITY: 51 FILTRATE: 7.8 EST. PORE PRES: 12.8ppg WOB: 18 RPM: 143 klb LOGGING COND:GOOD PUMP PR: 2590 PUMP SPM: 104 BEFORE DURING AFTER ROP ft/hr 11 17- 25 11 TOT GAS units 10 195 20 Cl ppm 1471 20228 2457 C2 ppm 30 1099 139 C3 ppm 34 1843 85 C4 ppm 1510 45 C5 ppm 464 CHL ppm 3100 3100 3100 LITHOLOGY CLAYSTONE, SILTSTONE SANDSTONE, CLAYEY, SILTY CLAYSTONE, SILTSTONE OIL IN MUD' NONE FLUOR: YELLOW - GREEN UNWASHED SPL FLUOR: EVEN YEL - GRN WASHED SPL FLUOR: EVEN LIGHT YEL STAIN: NO VISABLE STAIN SOLVENT CUT FLUOR: YEL - WHT INTENSITY: BRIGHT TYPE & SPEED: INSTANT NAT COLOR & RESIDUE: NO VIS CUT YEL RES RNG VISUAL POROSITY: POOR CUTTINGS DESCRIPTION: SD/SS: CLEAR, TRANSLUCENT, LIGHT GREY, FELDSPAR, MINOR QUARTZ, LOOSLY CONSOLIDATED W/ WHT, ASHY, CLAY MATRIX, V FINE GRAINED TO SILT, GRADES TO CLAYEY, SANDY SILTSTONE COMMENTS:FAIR TO GOOD OIL SHOW IN A CLAYEY, SILTY, VERY FINE GRAINED SANDSTONE ,-'-~'.,RATING:FAIR - GOOD LOGGING GEOLOGIST: SAM HEWITT SHOW REPORT # 4 OIL COMPANY: PHILLIPS PETROLEUM CO. WELL#: SUNFISH #3 LOCATION- COOK INLET ALASKA DATE:2/29/94 TIME:09:05 HOURS SHOW INTERVAL: 13623' TO 13683 ' (MD) 12304' TO 12371 ' (TVD) BIT SIZE: 8.5" BIT TYPE:HYC DS56H MUD WEIGHT: 13.5 ppg VISCOSITY: 66 BIT DIST: 12 FILTRATE: 4.6 HOURS: 1 EST. PORE ..~=~: ppg WOB: 18 KLB RPM: 115 PUMP PR: 2800 ~.~,o ,,.M: !00 LOGGING COND'FAIR · ~ BEFORE DURING AFTER ROP ft/hr 11 18 13 TOT GAS units 25 66 39 C1 ppm 4122 7651 1334 C2 ppm 280 687 207 C3 ppm 120 554 167 C4 ppm 355 81 C5 ppm 109 CHL ppm 3100 3100 3100 LITHOLOGY SILTSTONE, COAL, MINOR SAND/SANDSTONE SAND/SANDSTONE SILTSTONE OIL IN MUD: NONE FLUOR: NONE UNWASHED SPL FLUOR: SCATTERED YELLOW WASHED SPL FLUOR: SCATTERED YELLOW STAIN: TRACES LIGHT BROWN VISABLE SOLVENT CUT: NONE SOLVENT CUT FLUOR: INSTANT YELLOW WHITE REIDUE: YELLOW RES RING VISUAL POROSITY: UNCONSOLIDTED CUTTINGS DESCRIPTION (LOGGED FROM DITCH CUTTINGS WHILE CORING): SAND/SANDSTONE: LIGHT GREY TO MEDIUM BROWN, LOOSLY TO UNCONSOLIDATED, MEDIUM TO OCCASION- ALLY COARSE GRAINED AT TOP, BECOMES FINE GRAINED BELOW 13635', SUBANGLAR TO SURROUNDED, MODERATELY WELL SORTED FLEDSPAR, CHERT, MINOR LITHIC .... · COMMENTS: WEAK TO FAIR OIL SHOW IN LOOSLY CONSOLIDSTED SAND/SANDSTONE RATING:WEAK TO FAIR ( ) LOGGING GEOLOGIST: SAM HEWITT SHOW REPORT # 5 OIL COMPANY: PHILLIPS PETROLEUM CO. WELL#: SUNFISH #3 LOCATION: COOK INLET ALASKA DATE:2/27/94 TIME: 1430 hrs. SHOW INTERVAL: 14310' TO 14325 ' (MD) 12903' TO 12915 ' (TVD) BIT SIZE:5.875" BIT TYPE: HYCALOG BIT DIST' 378' HOURS: 49.3 MUD WEIGHT:14.1 ppg VISCOSITY: 61 FILTRATE: 6.2 EST. PORE PRES: 13.0ppg WOB:10 RPM: 265 klb LOGGING COND: FAIR PLOP PR: 2700 PSI PUMP SPM: 65 BEFORE DURING AFTER ROP ft/hr 20 TOT GAS units 12 80 C1 ppm 2000 8812 C2 ppm 224 792 C3 ppm 323 897 C4 ppm 156 230 308 460 OIL IN MUD: NONE FLUOR: NONE UNWASHED SPL FLUOR: NONE WASHED SPL FLUOR: TRACE BRI YL/GN STAIN: NONE C5 ppm 162 160 CHL ppm 3400 340 LITHOLOGY SILTSTONE, CLAYSTONE, locally COAL SANDSTONE POOH TO CORE SEE CORE REPORT ~8 SOLVENT CUT FLUOR' YEL-GN INTENSITY' MODERATELY BRIGHT TYPE & SPEED: STREAMING, SLOW NAT COLOR & RESIDUE: MLKY RES RNG VISUAL POROSITY: TRACE CUTTINGS DESCRIPTION: SANDSTONE: CLR, LT GY, FROS, I/P DK GY, FRM, RNDD, PR SRTD, F, VF, M GRN, PRED UNCONS, TR WELL CEM W/SIL, TR PR CEM W/CLAY, TR VOLC, TR FELDS, TR CHLOR. ~-.&..COMMENTS: OIL SHOW IN CONSOLIDATED SILICA SANDSTONE, IN PART SANDSTONE IS UNCONSOLIDATED OR HAS A SOFT CALY MATRIX. RATING: FAIR-POOR ( ) LOGGING GEOLOGIST: BOB ROURKE APPENDIX II DRILL RECORD DRILLING LOG FOR SUNFISH # 3 November 16, 1993 Powered up and began rig up of logging unit. November 17, 1993 Continued rig up of logging unit. Drilling rig is rigging up. November 18, 1993 407' MD Rig up of logging unit was essentially complete. Drilling rig was preparing for drill out of cement in the surface conductor pipe. Diverter lines were hookcd up and tested. The boat waz unlcadc~ while the trip tank and degasser pit was cleaned. 8.7 ppg spud mud was mixed. Bit # 1, HTC ATJ15, 13-1/2", was picked up as well as 8" drill collars and ran in the hole. Cement was tagged at 248' inside the 30" conductor pipe. Circulation was begun and the mud system was checked for leaks. Drilled ahead cleaning cement out of conductor pipe to 273'. November 19, 1993 587' MD Drilled ahead cleaning cement out of conductor pipe to 406' (1 foot above the shoe at 407'). Pulled out of hole, inspected the bit, and ran it back in the hole with a mud motor and an MWD tool. Ran the BHA in the hole to 406' and drilled ahead while picking up heavy weifht drill pipe. Sunfish No. 3 was spudded at 21:30 hours on November 19, 1993.Drilled ahead with RR Bit #1, making 13-1/2" pilot hole to 587'. Hole angle near the conductor shoe was approximately 1 degree. November 20, 1993 587' - 2297' MD Continued drilling 13-1/2" pilot hole through conglomerates and sands, while gradually building hole angle to 12.1 degrees at an azimuth of 345.2 at 1554' ,MD. Ditch gas readings, of 0 to 1 unit, were recorded until the depth of 1370' MD. The gas gradually increased to a maximum of 30 units at 1529' MD and then decreased to an average of 1 unit background by 1628' MD. Penetration rates ranged from 40 to 1000' feet per hour with mud weights of 8.6 to 8.6+ ppg and a bit weight of 5 - 15 thousand. The lithology began to change to clay and sand, with minor conglomerate and local coal beds, by 1480' MD. Ditch gas remained low at 1 to units background. Penetration rates changed to vary from a low of 8 to a high of 740 feet per hour. Bit weight ranged from 5 - 25 thousand pounds and the mud weight increased to range from 8.8 to 8.9 ppg. Drilled ahead to 2297' MD where it was decided to pull Bit No. RR1 after drilling 1891 feet in 27.5 hours. Hole angle increased to 21.68 degrees from true vertical with an azimuth of 349.79 degrees by 2206' MD. November 21, 1993 2297' - 2622' ~iD Circulated bottoms up and pulled out of the hole. Picked up new Bit No. 2, HTC ATJ15, and run in the hole to drill ahead from 2297'. Trip gas at 2297' MD was 1 unit. Continued to drill ahead through clay and sand with bit weights of 10 to 30 thousand at penetration rates of 24 to 540 feet per hour. Ditch gas remained at 1 to 2 units background while drilling to surface casing point at 2622' MD. Bottoms up was circulated before pulling out of the hole with Bit No. 2 after drilling 325 feet in 3.1 hours. Hole angle increased to 23.77 degrees from true vertical with an azimuth of 372.64 degrees by 2487' MD. Pulled out of the hole laying down drill pipe and slipping drill line. The BHA was laid down and Bit No. 3, Grant 24" hole opener, was picked up to run in the hole. November 22, 1993 2622' MD Ran in the hole to 399' where the cutters tagged up and could not be worked deeper. ~dlled out of the hole and stood back the hole opener. A 24" mill was picked up and run in the hole where it tagged up at 270'. The cement sheath in the 30" conductor pipe was milled from 270' to where the shoe was tagged at 399' MD. Pulled out of the hole and laid down the mill. The Grant hole opener, Bit No. 3, and BHA was picked up and run in the hole to 406' ~.~4D. Reaming of 13.5" hole out to 24" hole was began at 406' MD with a bit weight of 20 thousand pounds and rotary rpm of 30. Hole was opened from 406' to 1470' ND. November 23, 1993 2622' MD Reamed ahead from 1470' to 2204' where it was decided to pull Bit No. 3 after reaming 1979 feet in 32.0 hours. Pulled out of the hole and laid down Bit No. 3. Bit No. 4, and a24" Grant hole opener, was picked up and ran into the hole. November 24, 1993 2622' MD Continued to run in the hole and reamed ahead from 2204' to 2607' with a bit weight of 10 to 20K and a rotary rpm of 40 to 60. No trip gas was recorded at 2204'. The mud was circulated and conditioned, after a 5 stand short trip, at 2607' MD before pulling out of the hole. Bit No. 4 reamed 403 feet in 11.5 hours. Pulled out of the hole and laid down Bit No. 4 and the BHA. Rigged up to run 20", 169 lb/ft, casing. November 25, 1993 2622' MD Held a safety meeting and began to run 20" casing. Run casing to 2602' MI) and then cut the casing at the rig floor while rigging down casing equipment. Picked up and run in the hole with a seal assembly. Circulated and conditioned for cement. Tested the cement lines to 2000 psi and pumped 600 barrels of lead, followed by 124 barrels of tail, and followed by 4 barrels of water. Pulled out of floats and tripped out of the hole. Nippled down diverter to raise for rough cut. November 26, 1993 2622' MD Nipple down diverter, wait on cement, change shaker screens, clean pits, cut casing, and continue nippling down stack. Made up 1" for top job, flush with water, tag cement 23' below well head, and pump 30 sacks of cement. Make finish cut for well head, set well head in place, pre heat and weld well head, and post heat well head. November 27, 1993 2622' MD Continue to post heat well head and then nipple up risers and stack. Rigged up wireline and ran 2 gyro survey runs. Continued to nipple up stack and began mixing mud. November 28, 1993 2622' - 3364' MD -Rigged up the koomey lines and function tested the stack. Pressur'e test stack at 300 psi low to 3000 psi high. Picked up bit # 5, SMITH DSJC, and a conventional BHA to run in the hole. Tagged up at 2553' MD where the casing was tested to 2000 psi before circulating and conditioning the mud. Drilled float equipment at 2556' and continued through the shoe to stop in formation at 2632' MD. A formation integrity test was,conducted at an equivalent mud weight of 12.0 ppg before drilling ahead. Drilled ahead through sands and silts at penetration rates of 50 to 640 feet per hour with a bit weight of 45 to 60K pounds and a mud weight of 8.8 ppg. Ditch gas ranged from 1 to 13 units for an average of 5 units background. Hole angle was 28.97 degrees from true vertical with an azimuth of 347.47 degrees at 3304' MD. November 29, 1993 3364' - 4102' MD Drilled ahead to 3382' MD where it was decided to circulate bottoms up and pull Bit No. 5, and make a BHA change, after it made 775 feet in 3.2 hours. The lead monel and 2 stabilizer blades were changed out. A string reamer was picked up as well as Bit No. 6, SMITH MFDSHC, and run in the hole. Circulation was broke and the MWD tool was tested at the shoe. Continued to run in the hole to 3280' where the bit was washed and reamed to bottom at 3382. Maximum trip gas was recorded at 5 units. Drilled ahead at penetration rates ranging from 5 to 340 feet per hour through sands and siltstones with occasional coal stringers. Mud weight was increased from 9.0 to 9.1 ppg as the background gas began to increase with depth. The background gas began to increase dramatically at about 3740' .MI) and continued to increase to over 400 units at 3844' ~I). Drilling progressed to 3946' where gas was circulated out to reach a maximum value of 1445 units at 3908' MD. Drilled ahead after the gas dropped below 100 units. November 30, 1993 4102' - 5124' MD Drilled ahead at penetration rates of over 250 feet per hour to 4158' ,KD where high gas was again circulated out of the hole to reach a maximum value of 1385 units background associated with the depth of 3983' MD and a maximum value of 1485 units from the returns depth of 4119'. Drilled ahead, when the ditch gas fell below 100 units, to 4384' where bottoms up was circulated out and an 11 stand short trip was made. A short trip gas of 330 units was recorded while drilling ahead through silts, sands, and occasional coal stringers. A bit weight of 60 to 65K was used while the mud weight ranged from 9.7 to 9.7+ ppg. Drilled ahead to 5124' MD where it was decided to circulate bottoms up and pull Bit No. 6 after making 1742 feet in 23.3 hours. December 1, 1993 5124' - 5669' MD Finished circulating bottoms up and pulled out of the hole encountering a tight spot at 4380' MD. Hole angle was 25.35 degrees from true vertical with an azimuth of 347.80 degrees at 5054' MD. Changed out the BHA, picked up new Bit No. 7, SMITH MFDSHC, and run in the hole to 2600' where the MWD was tested and the drill line was slipped. Run to bottom and drilled ahead through sands, silts, and clay with occasional coal stringers. Ditch gas values in excess of 200 units were record while drilling with 9.7+ ppg mud in the hole. The highest ditch gas reading of 627 units background was recorded at 5391' MD with methane as the only chromatograph component that was recorded. No connection or swab gases were noted. December 2, 1993 5669' - 6224' MD Drilled ahead to 5720' where cuttings were circulated out while the rig was serviced. Continued to drill ahead with 9.7 to 9.7+ ppg mud while the background gas decreased to range from 18 to 100+ units. A noteable increase in clay content started at about 5660' as well as an increase in the occurance of coal stringers starting at about 5950'. Drilled ahead to 5875' MD where bottoms up was circulated and an 11 stand short trip was made with no problems. A short trip gas of 43 units was recorded. The penetration rate began to decrease to range from a low of 8 to a high of 150 feet per hour with the increase in clay content. The drill rate decreased to average below 50 feet per hour after 5940' MD. Hole angle at 6177' MD was 26.94 degrees from true vertical with as azimuth of 348.13 degrees. December 3, 1993 6224' - 6543' MD Drilled ahead to 6438' where bottoms up was circulated while pumping a sweep around. A short trip to the 20" casing shoe at 2602' MD was pulled. Ran in the hole to bottom and drilled ahead. A short trip gas of 106 units was recorded. Drilled ahead to 6543' MD where a sweep was pumped and bit.# 7 was pulled out of the hole after drilling 1419 feet in 41.2 hours. Pulled out of the hole. December 4, 1993 6543' - 6877' MD Changed BHA and picked up new Bit No. 8 and ran in the hole stopping to check the ~%iWD tool. Tight spots were encountered at 3970' and 4625' while running in the hole. A trip gas of 64 units was recorded at 6543' while drilling ahead through clay and silts with occasional sand and coal stringers. The penetration rate averaged less than 30 feet per hour while drilling with a bit weight of 40 to 50K with a 9.8 ppg mud in the hole. Ditch gas ranged from a low of about 15 units to a high of 125 units at 6740' and 274 units at 6881', with an average of 70 units. December 5, 1993 6877' - 7129' MI) Drilled ahead to 7065' MI) where bottoms up was circulated and a 10 stand short trip was pulled with no problems. A short trip gas of 80 units was recorded while drilling ahead to 7129' where bottoms up was circulated and Bit No. 8 was pulled out of the hole after drilling 586 feet in 30.9 hours. D~.tch g~s averaged about 70 un~.t~ with , high reading of 2455 units background recorded and associated with coals and sands at 7002' MD. Methane, ethane, and propane were recorded at that depth but no shows were encountered. December 6, 1993 7129' - 7307' MD Continued to trip out of the hole and changed out the BHA. Tested the stack and picked up new Bit No. 9, SEC SS33SGJ4. Tripped in the hole and stopped to test the MWD tool. A trip gas of 158 units was recorded at 7129' while drilling ahead through clay, silts, and sand. December 7, 1993 7307' - 7715' MD Drilled ahead to 7646' MD where bottoms up was circulated and a 10 stand short trip was pulled with no problems. A short trip gas of 5 units was recorded while drilling ahead with an average penetration rate of 21 feet per hour through predominate silts and clay with minor sand. Ditch gas averaged 45 units with 9.8 ppg mud in the hole. December 8, 1993 7715' - 8039' MD Drilled ahead through clay and siltstone at an average penetration rate of 14 feet per hour while recording ditch gas readings ranging from 15 to 78 units for an average of 28 units background gas. Hole angle was at a high of 30.0 degrees from true vertical with an azimuth of 348.2 degrees at 7967' MD. At 8039' MD it was decided to circulate bottoms up and pull Bit No. 9 out of the hole after drilling 910 feet in 50.1 hours. December 9, 1993 8039' - 8209' Continued circulating bottoms up and pulled out of the hole. Changed BHA and picked up new Bit No. 10, SEC SS33SGJ4. Checked the MWD tool while running in to bottom at 8039' and drilled ahead. A trip gas of 28 units was recorded with 9.8 ppg mud 'in the system. Penetration rates averaged at about 15 feet per hour while the ditch gas ranged from 10 to 40 units for an average background gas of 20 units. An increase in frequency of coal stringers was noted after about 8060' MI). Bit weights varied from 60 to 70K pounds. December 10, 1993 8209' - 8493' MD Drilled ahead through predominate silt and sand with some clay. Bottoms up was circulated at 8400' MD and a 16 stand short trip was pulled with no tight spots encountered. Ran in the hole to bottom and drilled ahead with a trip gas of 44 units recorded. The drill rate averaged 14 feet per hour while ditch gas background averaged 32 un~t~. Lithology drilled was silt, sand, and clay with local coal stringers. December 11, 1993 8493' - 8619' MD Drilled ahead to 8585' MD where bottoms up was circulated and Bit No. 10 was pulled out of the hole after drilling 546 feet in 37.7 hours. Changed out one stabilizer blade and NB NO. 11, SMITH SDGHC, was picked up. Run in the hole to the 20" casing shoe and tested the MWD tool while slipping drill line and servicing the rig. Run in hole to bottom and drilled ahead. A trip gas of 61 units was recorded at 8585'. December 12, 1993 8619' - 8630' MD Drilled ahead through interbedded silts, clays, sands, and coals at an average rate of penetration of 11 feet per hour with occasional rates of 20 to 30 feet per hour through the coal beds. Ditch gas averaged at about 25 units background with local maximums of up to 96 units in the coals. Local ethane and butane was noted and associated with the coal. December 13, 1993 8630' - 8872' MD Drilled ahead through silts, sands, clay, and coals at an average rate of about 11 feet per hour with local highs of 40 to 50 feet Der hour in the coals. Ditch gas averaged about 35 units with local highs of 90 to 130 units in the coals. Local ethanes and butanes were recorded with the coals. December 14, 1993 8872' - 8930' Drilled ahead to casing point at 8930' KDI). Drill rates ranged from 8 to 33 feet per hour for an average of 11 feet per hour. Ditch gas varied from 16 to 24 units with an average of 18 units. Bit No.ll made 345 feet in 30.6 hours. Hole angle at 8796' KD was 26.4 degrees from true vertical with an azimuth of 347.9 degrees. Circulated bottoms up and pulled a short trip of 15 stands. Ran in the hole and circulated a sweep. Short trip gas was 41 units. Pulled out of the hole and laid down the BHA. Rigged up to run E-Logs. Schlumberger ran two wire line suites. Laid down Schlumberger and and ran in to bottom to condition hole for 13 3/8" casing. tripping out of hole to run casing at midnight. December 15, 1993 (8930' KD, 8142' TVD) Tripped out and laid down bottom hole assembly. Rigged up for casing run and ran 13 3/8" casing (started at 09:00 hours). Ran casing to 7000' at midnight. December 16, 1993 (8930' MD, 8142' TVD) Ran 13 3/8" casing to 8909' (Float collar at 8865', lower DV collar at 7380', upper DV collar at 4048'). Cemented at the shoe, conditioned mud, and cementing through DV collar at 7380' at midnight. December 17, 1993 (8930'KD, 8142' TVD) Completed cementing at 7380' (stage 2), and at 4048' (stage 3). Had 177 units ditch gas while circulating at 4048' prior to cementing. December 18, 1993 (8930'MD, 8142' TVD) Nippled down 20" BOP's. Nippling up 13 3/8" BOP'S at midnight. December 19, 1993 (8909'KD, 8142' TVD) Completed nippling up. Ran into hole to 4048', attempted to test casing to 2100 psi with no sucess. Drilled out DV collar plug at 4048'. Attempted to test casing again with no sucess. Circulated bottoms up with 317 units maximum gas (C1, trace C2). Pick up Dowell and run into hole to squeeze DV valve at 4048'. December 20, 1993 (8930' MD, 8142' TVD) Pressured up on casing at 4048' (Haliburton RTTS packer), casing held pressure. Pressured up on backside, pressure held. Layed down Haliburton and Dowell. Ran in with bit to 7380'. Circulated bottoms up. Gas started building at 3100 strokes (3 units) and peaked at 2300 units at 4600 strokes. Pressured up casing, held. Drilled out plug at DV collar at 7380' and ran in to 8850'. Could not get casing to hold 2100 psi. Tested all surface equipment to 3000 psi. Rigged up Dowell; injected at 0.8 barrels a minute through casing at 2100 psi. Tripped and ran in with Haliburtons RTTS packer to find leak in casing. December 21, 1993 (8930' MD, 8142' TVD) RTTS packer failed at 7406' while testing casing (would not hold pressure). Tripped and redressed RTTS (appeared to be ok at surface). Ran in to 800', tested RTTS packer, ok. Ran into hole to 8852', set KTTS, pressured up on casing, failed. Fump~d down drill pipe wit;, Dowell's pumps, held 2100 psi (shoe is good, appear to have leak somewhere up hole in casing). Unseat packer, pull up to 8200' (approx), reset packer and test drillpipe to 2100 psi. Tested casing, failed. Continue testing casing on the way out of the hole. 86 unit gas peak inside casing. December 22, 1993 (8930' MD, 8142' TVD) Ran cement bond log and multishot gyro. Trip in hole and prepare to squeeze cement around upper and lower diverter valves. Squeezed 50 sacks of cement around lower DV. December 23, 1993 (8930' MD, 8142' TVD) Pulled out of hole to upper DV. Squeezed 100 sacks of cement around upper DV. Held pressure and wait on cement. Tripped out of the hole. Ran in the hole to top DV. Reamed and circulated bottoms up. Pressure tested to 2100 psi. Seemed ok (possible slight leak). Ran in the hole to bottom DV. Reamed and circulated bottoms up. Pressured test to 2100 psi. Would not hold pressure. Pulled out of the hole. December 24, 1993 (8930' MD, 8142' TVD) Ran in hole with RTTS packer to isolate leaks. Pressure tested upper DV to 2100 psi, slow leak. Pressure tested lower DV to 2100 psi, moderate leak. Squeezed 50 sacks cement in lower DV. Pulled out of the hole. Ran in hole to lower DV and pressure test. Moderate leak. Ran in hole to float shoe and begin drilling out. Drilled shoe and 10 feet of new formation. Circulated bottoms up. Performed formation integrity test to 14.86 lb/gal. December 25, 1993 (8940' MD, 8150' TVD) Dumped mud and cleaned pits. Displace 850 barrels from hole. Built volume again. December 26, 1993 (8940' MI), 8150' TVD) Continued displacing hole volume. Built volume in pits again. Drilled to 9112' (8304' TVD), and circulated bottoms up. Pulled out of the hole. Tested BOP'S. December 27, 1993 (9112' MD, 8304' TVD) Picked up mud motor and M~D tool. M~rD tool would not surface test. Fixed ~ tool and ran into the hole. On bottom drilling at 11:30 hfs, with NB NO.13, SMITH FDSHC (12.25"; jet's 3x13,15). December 28, 1993 (9278' MD, 8453' TVD) Trip gas 480 units. Drilling ahead. Orienting 90 degrees right last 12 feet of each kelly to turn hole to the right. Interbedded coals, carbonaceous mudstone, and sandstone. Made a short trip at 9315 feet (getting abundant coal sluff). Short trip gas 55 units. Drilling ahead at midnight. December 29, 1993 (9575' MD, 8723' TVD) Drilling ahead. Drill to 9764', do short trip. Short trip gas 820 units. Drill to 9860', pull out of the hole (Anadril tool not pulsing up surveys). December 30, 1993 (9860' MD, 8978' TVD) Lay down mud motor. Pick up 2 stabilizers. Run in the hole with NB No. 14 SMITH MFDSHCL (3X12, 15 jets). On bottom drilling at 06:30 hours. Trip gas 2650 units. Drilling with one pump (working on #2). December 31, 1993 (10130' MD, 9216' TVD) Drilling ahead with one pump. Anadrill MWI) having problems decoding. Encountered coal at 10170'. Drill to 10182', hole becomes very tight. Work pipe through tight spots. Made a short trip at 10285'. January 1, 1994 (10402' ~iD, 9457' TVD) Drilling ahead Anadrill tool not pulsing up surveys Drill to 10604' circulate bottoms up, pull out of the hole. January 2, 1994 (10604' MD, 9639' TVD) Out of the hole. Begin testing BOPs. Gas bubbles in mud. Close rams, no shut-in pressure. Run in hole with new bit and BHA. Watch well. Everything okay. Run in the hole and increase mud weight to 10.0 lb/gal. Trip gas 2290 units. Drilling ahead. January 3, 1994 (10743' MD, 9758' TVD) Drilling ahead. Anadril tool having decoding problems. Do 10 stand short trip at 11021'. Short trip gas 375 units. Drill ahead. January 4, 1994 (11045' MD, 10023' TVD) Drilling ahead. Anadrill tool having trouble decoding signal. Last survey showed that the hole was building angle. Anadrill tool failed. Drill to 11116' and Dull out of the hole. Test BOP's and K~. Run in the hole with NB No 'C ""~"~° '~"~" 14 j~s) .~ ,u~,mo ~ .... ~-~. (3x13, . Change BHA slightly. Run in the hole. Trip gas of 1350 units. January 5, 1994 (11126' KD, 10093' TVD) Drilling ahead. Encounter coals from 11155' to 11185'. Almost stuck pipe. Abundant coal slough. Very slow drill rates (3 to 6 ft/hr) below 11270'. January 6, 1994 (11339' KD, 10282' TVD) Drilling ahead. Drill to 11474'. Bit torquing up and angle dropping on last two surveys. Pull out of the hole to change BHA and bit. January 7, 1994 (11474' KD, 10402' TVD) Run in the hole with NB No.17 SMITH MSDGHODCL (3X13, 14). Trip gas of 985 units. Drilling ahead. January 8, 1994 (11607' KD, 10525' TVD) Drilling ahead. Drill to 11652'. Inclination of hole has dropped to 24.2 degrees. Circulated bottoms up, pulled out of the hole, and changed bottom hole assembly. Pick-up NB #18 SMITH MFDSH (3X15). Run in the hole. Trip gas 1135 units. Drilling ahead. January 9, 1994 (11721' MD, 10629' TVD) Ran to bottom, drilled to 11721'. January 10, 1994 (11842' MD, 10739' TVD) Drilled to 11842', tripped to pick up new bottom hole assembly. January 11, 1994 (11956' MD, 10843' TVD) Ran in hole to 11000', ran LWD log to bottom, and drilled to 11956'. Trip gas at 11842' was 856 units. Tripping for bit at report time. January 12, 1994 (12150' MD, 11025' TVD) Drilled from 11956'to 12150'. Circulated bottoms up and circulated Hi-Vis sweep. Tripped to shoe. Ran in to bottom circulatcd hole clean and another Hi-Vis sweep. Tripping to run wireline logs. January 13, 1994 (12150' MD, 11025' TVD) Ran Schlumberger wireline logs (Two suites). Ran into hole to 13 3/8" (8909') and strung 12 lines for 9 5/8" casing run. Run to bottom and circulate and condition hole for casing at report time. January 14, 1994 (12150' MD, 11025' TVD) Circulate and condition hole. Trip out and rig up casing crew. Running 9 5/8" casing at report time. January 15, 1994 (12150' MD, 11025' TVD) Ran 9 5/8" casing to 12137' (11012' TVD). Circulated hole volume twice. Cemented with 1000 sacks. Changing out BOPS at report time. January 16, 1994 (12150' MD, 11025' TVD) Completed nippling up 9 5/8" BOPS. Ran into hole with new bit No. 21 (BHA 28). Tagged cement at 11397'. Drilled out cement to 11450' at report time. January 17, 1994 (12160' MD, 11035' TVD) Drilled out cement to 12150' (shoe at 12137'). Drilled to 12160'. Ran leak off test to 16.2 ppg equivalent. Weighting up mud system from 10.1 ppg to 13.5 ppg at report time. January 18, 1994 (12160' MD, 11035' TVD) Continued.weighting up mud and adding check loss and soltex. On bottom drilling at 13'40 hours. Drill to 12256' at midnight. January 19, 1994 (12256' KD, 11122' TVD) Drill to 12285'. Pull out of the hole for Core #1. Run in the hole with CB#1 BHI SC712 (0.95 TFA). Begin coring at 15:45 hours. Core to 12306 feet, core barrel jammed. Pull out of the hole with Core #1. January 20, 1994 (12306' KD, 11167' TVD) Continue pulling out of the hole. Service core. Wait on orders regarding another core or conventional drilling assembly. Decide on conventional drilling assembly. Pickup ~ and BHA and run in the hole with new bit #23, SMITH MFDSH (jets 3x12). Ream 30 feet for .~I). On bottom drilling at 10:15 hours. Drill to 12405 feet. Circulate bottoms up, and pull out of the hole for Core #2. January 21, 1994 (12405' KD, 11258' TVD) Out of the hole at 9~:09 hours. Make up coring bottom hole assembly. Run in the hole for Core #2, with Core Bit #2 (NB #24), BHI SC777, 0.6 TFA. Begin coring at 09:51 hours at 12405' md. January 22, 1994 (12451' ~{D, 11300' TVD) Core to 12465 feet. Begin pulling out of the hole with core #2 at 06:30 hours. Out of the hole at 10:30 hours. Service core and lay down core barrel. Pick-up ~ tool and run in the hole with new bit #25, SECURITY ~I44NG (jets 3x12). Slip and cut drilling line. Ream/MWD log 60 feet to bottom. On bottom drilling at 19:30 hours. January 23, 1994 (12495' KD, 11340' TVD) Drilling ahead. Encounter oil bearing sand from 12502 feet to 12512 feet and from 12519 to 12526 feet (no visible oil, but cut and CS's, Show #1). Encounter another oil bearing sand from 12550 feet to 12573 feet (Show #2). Drill to 12616 feet, circulate bottoms up and pull out of the hole. Test BOP's. January 24, 1994 (12616' ~ID, 11454' TVD) Continue testing BOP's. Run in the hole with new bit #26, Hycalog D556H (PDC bit w/ 4x!l jets). Slip and cut drilling line at shoe. On bottom drilling at 0815 hours. Maximum trip gas was 37 units. Drill ahead to a depth of 12802 feet in a predominantly sandstone/claystone lithology with occasional thin coals. Connection gas ranged from 2 to 25 units. Maximun gas observed was 265 units which was recorded at 12753 feet and was associated with a coal seam. Janurary 25, 1994 (12802' MI), 11624' TVD) Drill ahead to a depth of 12850 feet where a ten-stand short trip was performed without incident. Normal drilling operations resumed within 75 minutes. Drilling continued to a depth of 12963 feet in a sandstone/claystone lithology with occasional coals. There were no shows. Short trip gas was 19 units. Maximum formation gas was 213 units at 12891 feet and was associated with a coal seam. Janurary 26, 1994 (12964' MD, 11770' TVD) Drill ahead to a depth of 13107 feet where a ten-stand short trip was performed without incident. Normal drilling operations resumed within two hours and continued to a depth of 13169 feet in a predominantly clay and siltstone lithology with occasional sands and minor coals. There were no shows. Short trip gas was 37 units. Maximum formation gas was 110 units observed at 13096 feet and was associated with a coal seam. Janurary 27, 1994 (13170' MD, 11950' TVD) Drill ahead to a depth of 13379 feet in a predominantly claystone and siltstone lithology with occasional thin sands and minor coals. A weak show was observed between 13345' and 13353' MD. The ROP increased from an average of 12 fph to 25 fph. Maximum formation gas recorded was 195 units over a background of 25 units. Butanes and Pentanes were recorded in trace amounts. Yellow sample fluorescence was seen. There was no cut fluorescence. No oil or oil stain was seen. Janurary 28, 1994 (13380' MD, 12129' TVD) Drill ahead to a depth of 13491 feet where a six-stand short trip was performed without incident. Normal drilling operations resumed within ninty minutes and continued to a depth of 13556' MD. in a sandstone/claystone lithology with occasional thin coals. Short trip gas was 30 units. Maximum formation gas was 69 units. There were no shows. Janurary 29, 1994 (13557' MD, 12273' TVD) Drill ahead to a depth of 13627' MD, stopping occasionally to circulate samples to surface. Circulate the well and trip out. Lithology continued in a siltstone/claystone system with minor coals. An oil-sand show was seen in the interval between 13626 MD and 13627 MD. Maximum drill gas was 61 units over a background of 12 units. Trace butanes and pentanes were noted. A trace of live oil was seen. Slow residual cut fluorescence was seen. Lithology was a lightly-consolidated fine grained sandstone. Janurary 30, 1994 (13627' MD, 12326' TVD) Continue POOH. Lay down drilling BHA. Make up coring BHA. Pick-up bit 27, an 8.5" Eastman Christiansen RC 412 with a .50" TFA. RIH to shoe, slip and cut drill-line. RIH to 13588. Pick up kelly and wash to bottom. Janurary 31, 1994 (13627' MD, 12326' TVD) Continue washing to bottom. Core to a depth of 13641' MD (12337') TVD where the core barrel jammed. Pump slug and POOH. Core 3 cut 13', recovered 8.5'. Maximum drill gas while coring was 18 units. Trip gas was 69 units. Core was not examined by loggers. Cuttings lithology indicated a sandstone interval of undetermined potential. Redress coring tools. Pick up NB28(24RR) Eastman Christiansen SC777, 8.5" corehead with a TFA of .60". RIH. Wash thru cored interval. Core to a depth of 13659' MD, (TVD 12352) where the core barrel jammed. Pump slug and POOH. Maximum drill gas observed for core 4 was 18 units. Cuttings recovered while coring indicate a sandstone lithology. February 1, 1994 (13659' MD, 12352' TVD) Continue POOH with core 4. Core 4 cut 18', recovered 17.5'. Core was not examined by loggers. Redress core barrel, RR bit 28. RIH for core 5. Pressure test BOP equipment at casing shoe. Wash past cored interval. Trip gas was 76 units. Core to a depth of 13680 MD, (12369 TVD) where the core barrel jammed. Maximum drill gas recorded for core 5 was 14 units. Examination of drilled cuttings while coring indicated a sandstone interval. Pump slug and POOH. February 2, 1994 (13680' MD, 12366' TVD) Continue POOH with core 5. Core 5 cut 21', recovered 19'. Core was not examined by loggers. Redress core barrel, RR bit 28, RIH for core 6. Stop at csg. shoe to slip and cut drilling line. RIH and wash thru cored interval. Trip gas was 90 units. Core to a depth of 13700' MD, (12384' TVD) where the core barrel jammed. Maximum drill gas while coring was 13 units. Cuttings lithology indicated a sandstone interval. POOH with core 6. Core 6 cut 20', recovered 18.5'. Core was not examined by loggers. Lay down coring tools. NB29, HYCALOG DS56H, 8.5", jetted with 4 ll's, was run in on a conventional BHA with MWD tools for GR and RES in the string. RIH to aMD of 13564'. Begin Wash to bottom for MWD (GR and RES) data of cored interval. February 3, 1994 (13700' MD, 12384' TVD) FiniSh washing to bottom. Trip gas was 128 units. Drill ahead to 13822' MD in lithology consisting of sands in the upper part, becoming silty, and then clayey siltstone. Maximum drill gas was 44 units at 13705' MD. Trip gas was 128 units. There were no shows. February 4, 1994 (13822' MI), 12483' TVD) Drill ahead to 13986' MI). Pump a high-vis pill to sweep hole. Start eight-stand short trip. Pipe becomes stuck with bit at 13210' MD. Work jars. Kelly-up and circulate. Free pipe and POOH. Drilling was in a siltstone lithology interbedded with clays, sands, and coals. Maximum formation gas was 74 units at 13894' MD. There were no shows. February 5, 1994 (13986' KD, 12615' TVD) Continue POOH. Lay down MWD tools and drilling jars. Pick up NB #30, Smith M21EP, jets: 2 12's, 1 13, new drilling jars and MWD tools. RIH, wash and ream thru tight hole area. Formation took no weight going in hole. Trip gas was 127 units. Drill ahead in siltstone and coal lithology to a depth of 14014' KD. Maximum formation gas seen was from 14007' MD, 104 units, and was a coal seam. At 14014' MD, 12638' TVD, the drill string became stuck while drilling. February 6, 1994 (14014' KD, 12638' TVD) Stuck pipe; free point February 7, 1994 (14014' KD, 12638' TVD) Fishing; run in with string shot, shoot pipe, leave top of fish at 13611' KD. POOH with fishing tools. February 8, 1994 (14014' KD, 12638' TVD) RIH with cementing tools. Set kick-off plug at top of fish and POOH. Lay down cementing equipment. Bit 31, HTC ATM-MG1 was run in on a conventional drilling assembly. February 9, 1994 (KD to be determined by KOP) Finish RIH to dress kick off plug. Wash and ream to MD 13457'. POOH. Stop with BHA only in hole to repair drawworks. Finish POOH and lay out drilling assembly. Pick up NB32, HYCALOG ST, 8.5" with a TFA of .55". Pick up Anadril MWD tools (GR and RES) and RIH to kick off. Encounter tight hole passing through casing shoe. Kelly-up and begin washing and reaming. At two stands past casing shoe, pipe became stuck. Circulate and work jars. February 10, 1994 (MD to be determined by KOP) Circulate and jar stuck pipe. RIH with freepoint tools on wireline. Tools malfunction. Kelly-up and work pipe. Pull free and trip two stands up into casing. Spot "Aqua-safe" pill at casing shoe and POOH. February 11, 1994 (~4D to be determined by KOP) Finish POOH. Lay down MWI) tools and drilling BHA. Pick up RRB 31, HTC ATM MC1, jetted with 3 14's and RIH with conventional BHA. Kelly-up at casing shoe. Wash and ream to 12362' MD. Rack kelly and run stands in to 13450' MD. Circulate bottoms up. Trip gas 131 units. POOH to casing shoe. Circulate. RIH to 13450' MD. Circulate bottoms up. Hole is not tight or taking weight. POOH. February 12, 1994 (MD to be determined by KOP) Finish POOH. Lay down BHA. Pick up RRB32, HYCALOG ST, TFA .55" and a kickoff BHA. Surface test Anadril "slim one" directional MWD and RIH. (NOTE: initial tests indicate malfunction in MWI). Trouble-shoot four hours before a sucessful test) February 13, 1994 (13457' MI), 12189' TVI)) Finish R!H to kickcff point at 13457' .~D. Control ~;~ four feet at an ROP of less than .5 FPH to establish "low-side" departure. Control drill to a depth of 13466' MD in a lithology thought to consist of claystone/siltstone. Drill samples consist of 95%-100% cement. There were no shows. February 14, 1994 (13466' MD, 12196' TVD) Continue control drilling at 1-2 FPH to establish kick off. Check shot at drill depth 13488' MD indicates 1/2 deg departure. Control drill to a depth of 13515' MD. Lithology as above; no shows. Check shot survey indicates 1/2 dog plus departure from previous hole angle. Pump slug and POOH. Lay down kick off tools. Pick up NB33, HYCALOG DS56H, 4xll jets. Surface test Anadril "slim-one" MWD tool (directional tool only, no GR/RES function). Test BOP equipment. RIH. Trip gas of 48 units was recorded. Drill to a depth of 13534' MD in a sandstone/siltstone lithology with occasional coals. There were no shows. February 15, 1994 (13534' MD, 12253'TVD) Drill ahead in a sandstone/siltstone lithology with several well- developed, mature coals, to a depth of 13681' MD, 12375' TVD. POOH for core seven. Lay down BHA. Pick up NCB 33, Eastman Christiansen SC777 8.5" corehead, TFA .60" and run in on a 60' 4" corebarrel with a conventional coring BHA. Maximum drill gas recorded was 200 units at 13601' MD. and was a coal seam. The upper part of the sunfish was a siltstone/sandstone system with fair to occasionally good porosity. Oil fluorescence was weak and dull. Cut fluorescence was rarely seen; weak and dull. No oil was seen. Drill gas peaks were 101 units, 36 units, and 29 units. Iso and normal butanes were seen in trace amounts. Pentanes were absent. February 16, 1994 (13681' MI), 12376' TVD) Continue RIH with tools for core 7. Kelly-up at 13650' KD and wash to bottom. Trip gas was 80 units. Begin coring at 0700. Core to a depth of' 13727' KD in a predominantly sandstone lithology, grading to siltstone in the lOwer part. Maximum drill gas recorded was 18 units at 13718' KD. Occasional good sands were seen. Associated fluoresence and cut fluoresence was of poor quality. While trace butanes were found, pentanes were absent. February 17, 1994 (13727' .WI), 12416' TVD) Continue coring to a depth of 13731' KD. POOH and lay down core, coring tools, coring BHA. Core 7 cut 50 feet with a 100% recovery. Core was not examined by mudloggers. Pick up RRB 32, HYCALOG DS56H, jetted with four elevens. RIH on a conventional steel BHA (no MWD, monel steel tools). Wash and ream cored interval. Trip gas was 80 units. Drill ahead to a depth of 13810' MI) in a predominantly clayey siltstone lithology with minor sands and occasional traces of volcanics and coal. Drillpipe became briefly stuck at a depth of 18755' MD, but was jarred loose within fifteen minutes. Maximum drill gas was seen at 13756' MI), 104 units, and was from a coal seam. February 18, 1994 (13810' KD, 12486' TVD) Drill ahead to a depth of 13941' MD in lithology similar to above. Circulate bottoms up and short trip to casing shoe. RIH and circulate bottoms up. Hole OK. Short trip gas 58 units. POOH. Rig up Schlumberger. February 19, 1994 (13941' MD, 12597' TVD) Continue rigging up Schlumberger and RIH with electric logs. First run is OK. Second run encounters slight overpull in lower hole section, but is run sucessfully. Big down Schlumberger. RIH with drilling tools and RRB 31 for clean out trip. Trip gas 94 units. Wash and ream tight hole near bottom. Pump sweep. February 20, 1994 (13941' KD 12597' TVD) POOH. Rig up Schlumberger and RIH with electric logs. Run three more electric logs. NOTE: SCHLUMBERGER LOG SUITE: Run 1, DIL/DIPOLE SONIC/SP/GR; Run 2, FDC/CNL/MICRO LOG/GR; Run 3, F~I;Run 4, RFT w/GR;Run 5, Sidewall Cores w/GR February 21, 1994 (13941' MD 12597' TVD) Finish logging run 5. Rig down Schlumberger. Pull wear ring and pressure test BOP equipment. Pick up drilling assembly and RRB 31. RIH for clean out trip. Wash and ream lower hole section. Circulate and condition mud for casing run. Trip gas was 294 units. POOH. Rig up casing crew. Pick up and run 49 joints 32# 7" butress-thread casing. Install TIW hanging tool. RIH on 5.5" drill pipe. NOTE: casing string length of 2091.82' allows for 301' of liner overlap inside 9 5/8" casing. February 22, 1994 (13941' MD 12597' TVD) Run liner and hanger in on 5.5" drillpipe to 9 5/8" casing shoe. Circulate volume of liner. Continue RIH with liner and hanger. Tag bottom at 13941' MD. No tight hole. Set liner 2' off bottom at 13939' MD. Top of liner is at 11836' MD. Circulate well to condition for cementing. Rig up and test Dowell. Cement casing with 675-sacks class ,,r,,~ mlxed~ tc 15.8 p~.~ Displace cement with rig pumps. Release hanging tool from liner, pull three stands, and reverse circulate volume of liner twice. Rig down Dowell. POOH. Pick up RRB 31 and RIH. Wash to 11636' MD. February 23, 1994 (13941' MD 12597' TVD) Continue wash and ream to top of liner. Circulate bottoms up. POOH. Lay down 6.5" BHA, 5" hevi-wate DP, and 80 joints 5" DP. Pick up 4.5" BHA, 3.5" hevi-wate, and 78 joints of 3.5" drill pipe. RIH with NB35, 5 7/8" Smith F-2, jetted with 3 15's. Wash, ream, and drill cement. February 24, 1994 (13941' MD 12597' TVD) Continue drilling cement to top of float equipment. Pressure test casing to Phillips specs. Drill float collar, cement, and guide shoe. Drill formation to 13947' MD. Circulate bottoms up. Run pressure integrity test EQMW 16.5 ppg. Circulate and raise mud weight to 13.8 ppg. POOH. Pick up NB36, Hycalog DS56H, 2 x 14 and 1 x 16 jets. RIH on mud motor with conventional BHA. Drill to 13949' MD in siltstone lithology. Trip gas nil. No shows. February 25, 1994 (13949' MD, 12600 TVD) Drill ahead in an alternating siltstone/clayey siltstone lithology interbedded with coal and trace sands. Maximum drill gas recorded was 125 units from a coal seam at 14045' MD. ROP averaged 6.9 fph. All drilling breaks were associated with coals. There were no shows. Drill to 14088' MD. February 26, 1994 (14088' MD, 12717' TVD) Drill ahead in a predominantly siltstone lithology, interbedded with clays, more frequent sands, and hard, mature coals. Maximum drill gas seen was 103 units at 14223' MI) and was from a coal. Show-type sands were conspiciously absent in this section. A cuttings sample obtained from 14120' KD showed fluorescence and poor cut from one fragment only. Gas reading was less than 20 units. Chromatography indicated C5 in one sample only, and then at less than 10 ppm. Deeper in the section, at 14225' b{I), one fragment only, from one sample only, showed poor fluorescence and very weak, slow crush cut. There was no affiliated gas increase on instruments. Drill to 14234'MI). NOTE: Sample quality very poor this section. Near constant back-reaming, to avoid sticking the drillstring, results in abundant coal slough in samples. February 27, 1994 (14234' MD, 12839' TVD) Drill ahead in a siltstone/claystcne l:t~ology ~ .... ~"~ with trace sands and thin coals to a depth of 14289' MI). Circulate thirty minutes and make 4 stand short trip to casing shoe, and immediatly back to bottom, there was no tight hole or drag. Drilling resumed within forty-five minutes. Bottoms up gas was measured at 2820 units. Chromatography indicated the presence of both butanes and pentanes. Drilling continued to a depth of 14310' .MD in lithology as described previously. At 14310' MD, fifteen-foot drilling break was encountered and circulated to surface. Sample evaluation, total gas recordings of 80 units, and chromatography all indicate the presence of an oil sand. POOH. (NOTE: For details, refer to show report # 4) February 28, 1994 (14325' ..~ID, 12915' TVD) Continue POOH. Pick up NCB 37, BHI SC776 5 7/8" corehead, and RIH w/ 60' core barrel. Stop at 7" casing shoe, circulate the well. Bottoms up gas of 604 units was recorded. RIH to bottom, begin coring at 10:30 k~. Trip gas off bottom was 1256 units, again disclosing butanes and pentanes. Core to a depth of 14354' MD. Based on drilled cuttings, lithology is predominantly unconsolidated sandstone with occassional consolidated. Siltstone became the dominant lithology as coring progressed. There were no shows, but butanes and pentanes persist in chromatography. Coring ROP was 1.9 to 5.9 fph. March 1, 1994 (14354' ..V~D, 12940' TVD) Continue coring in a siltstone lithology without shows to a depth of 14368' ~D. Penetration slowed to less than 1 fph, and the corehead lost torque. Pump slug and POOH. Core 7 cut 43 feet with 100% recovery. Core was not examined by mudloggers. Pick up and RIH with NB 38, SECURITY HZ23-26 with 2x12 and lxl4 jets. This bit was run on a monel BHA with Anadrill directional MWI). March 2, 1994 (14368' MD, 12940' TVD) Continue RIH. Wash and ream cored interval. Trip gas was 110 units. Drill ahead with ROP ranging from 5 to 10 fph. Lithology was predominantly siltstone with tuffaceous claystone. Anadrill MWD failed to give any realtime sUrvey data so a survey from the orientated core data was entered at 14445' MD to calculate TVD. This survey is not an official survey but is used as a best fit until a gyro survey is obtained. TVD is then backcalculated to 13621' MD, the last official survey, and forward as drilling progressed. March 3, 1994 (14489' MD, 13084' TVD) Drill ahead through claystone and siltstone with ROP less than 6 fph. A thin sandstone with associated coal bed was found at 14470' .MD. A very poor oil show was observed in the sandstone. Drilling continued. March 4, 1994 (~' ~ ,~o~, ~ ~ Drill ahead through claystone and siltstone with ROP averaging 6 fph. Occassional coal beds with a maximum ROP of 24 fph and a gas peak of 106 units, predominantly methane. Stop drilling at 14705' MD, circulate and condition hole to run wireline logs. March 5, 1994 (14705' MD, 13281' TVD) Continue to circulate and condition hole. A short trip to the 7" liner shoe produced a short trip gas of 109 units. POOH for wireline logs. Rig up Schlumberger and RIH. SCHLb~BERGER LOG SUITE: RUN 1, DIL/DIPOLE SONIC/SP/GR; RUN 2, LDT/CNL/GR; RUN 3, FMS/GR; RUN 4, CST/GR; RUN 5, RFT/GR March 6, 1994 (14705' ~ID, 13281' TVD) Continue running wireline logs. Pick up new BHA with Anadrill Mh~i) in "Multishot" mode. RIH for wiper trip. March 7, 1994 (14705' MI), 13281' TVD) Continue RIH for wiper trip. Run Anadrill multishot every 90 ft in open hole. Pick up kelly and circulate bottoms up. Trip gas 51 units. POOH run multishot every 90 ft in open hole. POOH. Rig up Schlumberger and RIH. Run 5, RFT LOGGING UNIT RELEASED AND RIGGED DOWN APPENDIX III SAMPLE SHIPMENTS SAMPLE SHIPMENT NO. 1 DATE: 11/22/93 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. 1D CARD BOXES 1C, 1D 2C, 2D INTERVAL 407' - 1410' 1410' - 2610' TOTAL 1 BOX DRYS WET SAMPLES (W) SET AND BOX NO lC 2C INTERVAL 407' - 1350' 1350' - 2610' TOTAL 2 BOXES WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. lA 2A 3A 4A 5A 6A INTERVAL 407' - 720' 720' - 1080' 1080' - 1380' 1380' - 1740' 1740' - 2130' 2130' - 2460' TOTAL 6 BOX GEOCHEM TOTAL 9 BOXES SHIPPED 11/22/93 BY BOAT SAMPLE SHIPMENT NO. 2 DATE: 11/30/93 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES INTERVAL TOTAL 0 BOX DRYS WET SAMPLES (W) SET AND BOX NO 3C 4C INTERVAL 2610' - 3360' 3360' - 4380' TOTAL 2 BOXES WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A7 A8 A9 Al0 All INTERVAL 2460' - 2820' 2820' - 3180' 3180' - 3540' 3540' - 3900' 3900' - 4260' TOTAL 5 BOX GEOCHEM TOTAL 7 BOXES SHIPPED 11/30/93 BY BOAT SAMPLE SHIPMENT NO. 3 DATE: 12/09/93 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES 3C, ~ 4C, 4D 5C, 5D 6C, 6D INTERVAL 2640' - 3810' 3810' - 4950' 4950' - 6150' 6150' - 7440' TOTAL 1 BOX DRYS WET SA~MPLES (W) SET AND BOX NO C5 C6 C7 C8 INTERVAL 4380' - 5340' 5340' - 6360' 6360' - 7140' 7140' - 7770' TOTAL 4 BOXES WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. Al2 A13 A14 A15 Al6 Al7 Al8 Al9 A20 A21 INTERVAL 4260' - 4620' 4620' - 4980' 4980' - 5340' 5340' - 5700' 5700' - 6060' 6060' - 6420' 6420' - 6780' 6780' - 7140' 7140' - 7500' 7500' - 7860' TOTAL 10 BOXES GEOCHEM TOTAL 15 BOXES SHIPPED BY BOAT 12/09/93 SAMPLE SHIPMENT NO. 4 DATE: 12/14/93 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHI PPI NG BOX NO. D3 CARD BOXES 7C, 7D INTERVAL ~A~' O09~' TOTAL 1 BOX DRYS WET SAMPLES (W) SET AND BOX NO C9 INTERVAL 7770' - 8930' TOTAL 1 BOX WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A22 A23 A24 INTERVAL 7860' - 8220' 8220' - 8580' 8580' - 8930' TOTAL 3 BOXES GEOCHEM TOTAL 5 BOXES SHIPPED BY BOAT 12/09/93 SAMPLE SHIPMENT NO. 5 DATE: 1/3/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D4 CARD BOXES ~o D8 C9,D9 C10,D10 Cll,Dll INTERVAL 8o9' o~ , ~v - 9~v0 9360' - 9700' 9700' - 10110' 10110' - 10540' TOTAL 1 BOX DRYS WET SAMPLES (W) SET AN-D BOX NO Cl0 DI(QFT) Ct! D2(QFT) C12 D3(QFT) C13 D4(QFT) C14 D5(QFT) INTERVAL 8930' - 9290' 9290' - 9640' 9640' - 9970' 9970' - 10260' 10260' - 10550' TOTAL 10 BOX WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A25 A26 A27 A28 INTERVAL 8930' - 9290' 9290' - 9650' 9650' - 10010' 10010' - 10370' TOTAL 4 BOXES GEOCHEM TOTAL 15 BOXES SHIPPED BY BOAT 1/3/94 SAMPLE SHIPMENT NO. 6 DATE: 1/10/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES INTERVAL TOTAL 0 BOX DRYS WET SAMPLES (W) SET AND BOX NO C15 D6(QFT) C16 DT(QFT) C17 D8(QFT) C18 D9(QFT) INTERVAL 10550' - 10790' 10790' - 11040' 11040' - 11360' 11360' - 11650' TOTAL 8 BOX WETS GEOCHEM S~%MPLES (GC) SET AND BOX NO. A29 A30 A31 A32 INTERVAL 10370' - 10730' 10730' - 11090' 11090' - 11450' 11450' - 11810' TOTAL 4 BOXES GEOCHEM TOTAL 12 BOXES SHIPPED BY BOAT 1/10/94 SAMPLE SHIPMENT NO. 7 DATE: 1/19/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTE@ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES INTERVAL D-5 WET SAMPLES (W) SET AND BOX NO C19 D10(QFT) C20 Dll(QFT) C12, D12 C13, D13 C14, D14 C15, D15 10540' - 10950' 10950' - 11400' 11400' - 11880' 11880' - 12290' TOTAL 1 BOX DRYS (8 CARD BOXES) INTERVAL 11650' - 12050' 12050' - 12290' TOTAL 4 BOX WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A33 INTERVAL 11810' - 12170' TOTAL 1 BOXES GEOCHEM TOTAL 6 BOXES SHIPPED BY HELICOPTER 1/19/94 SAMPLE SHIPMENT NO. 8 DATE: 1/24/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D-X WET SAMPLES (W) SET AND BOX NO C21, D12(QFT) CARD BOXES INTERVAL NONE SENT TOTAL 0 BOX DRYS (8 CARD BOXES) INTERVAL 12290' - 12590' TOTAL 2 BOX WETS GEOCHEM SAMPLES (CC) SET AND BOX NO. A34 INTERVAL 12170' - 12530' TOTAL 1 BOXES GEOCHEM TOTAL 3 BOXES SHIPPED BY HELICOPTER 1/24/94 SAMPLE SHIPMENT NO. 9 DATE: 2/3/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA WET SAMPLES (W) SET AND BOX NO C22, D13(QF?) C23, D14(QFT) C24, D15(QFT) INTERVAL 12590' - 13000' 13000' - 13430' 13430' - 13750' TOTAL 6 BOX WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A35 A36 A37 INTERVAL 12530' - 12890' 12890' - 13250' 13250' - 13610' TOTAL 3 BOXES GEOCHEM TOTAL 9 BOXES SHIPPED BY BOAT 2/3/94 SAMPLE SHIPMENT NO. 10 DATE: 2/8/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D6 WET SAMPLES (W) SET AND BOX NO C25, D16(QFT) GEOCHEM SIMPLES (GC) SET AND BOX NO. A38 A39 CARD BOXES C16,D16 C17,D17 C18,D18 C19,D19 INTERVAL 12290' - 12690' 12690' - 13350' 13350' - 13750' 13750' - 14010' TOTAL 1 BOX DRYS INTERVAL 13750' - 14010' TOTAL 2 BOX WETS INTERVAL 13610' - 13970' 13970' - 14010' TOTAL 2 BOXES GEOCHEM TOTAL 5 BOXES SHIPPED BY BOAT 2/8/94 SAMPLE SHIPMENT NO. 11 DATE: 3/4/94 TO: PHILLIPS PETROLEUM COMPANY PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D6 WET SAMPLES (W) SET AND BOX NO C26, D17(QFT) C27, DlS(QFT) C28, C29, D20(QFT) GEOCHEM SAMPLES SET AND BOX NO. A40 A41 A43 CARD BOXES C20,D20 C21,D21 C22,D22 INTERVAL 13460' - 14000' 14000' - 14600' 14600' - 14640' TOTAL 1 BOX DRYS INTERVAL 13460' - 13850' 13850' - 14200' 14200' - 14570' 14570' - 14660 TOTAL 7 BOX WETS INTERVAL 13460' - 13820' 13820' - 14180' 14540' - 14660' TOTAL 3 GEOCHEM TOTAL 11 BOXES SHIPPED BY HELICOPTER 3/4/94 SAMPLE SHIPMENT NO. 12 DATE: 3/7/94 TO: PHILLIPS PETROLEUM COMPA/~Uf PHILLIPS CORE STORAGE BUILDING 1401 14TH STREET BARTLESVILLE, OKLAHOMA 74004 ATTEN: BILL HOLMAN FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D9 WET SAMPLES (W) SET AND BOX NO D19(QFT) C30, D21(QFT) CARD BOXES C23,D23 INTERVAL 12290' - 12690' TOTAL 1 BOX DRYS INTERVAL 13750' - 14010' TOTAL 3 BOX WETS GEOCHEM SAMPLES (GC) SET AND BOX NO. A42 A44 INTERVAL 13610' - 13970' 13970' - 14010' TOTAL 2 BOXES GEOCHEM TOTAL 6 BOXES SHIPPED BY HELICOPTER 3/7/94 SAMPLE SHIPMENT NO. 1 DATE: 11/22/93 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. 1D WET SAMPLES (W) SET AND BOX NO A1 , B1 A2 , B2 GEOCHEM SAMPLES (GC) SET & BOX NO. B1 B2 B3 B4 B5 B6 B7 B8 B9 BIO Bll B12 CARD BOXES lA, lB 2A, 2B INTERVAL 407' - 1410' 1410' - 2610' TOTAL 1 BOX DRYS INTERVAL 407' - 1350' 1350' - 2610' TOTAL 4 BOXES WETS INTERVAL 407' - 570' 570' - 750' 750' - 930' 930' - 1110' 1110' - 1290' 1290' - 1440' 1440' - 1620' 1620' - 1800' 1800' - 1980' 1980' - 2160' 2160' - 2340' 2340' - 2520' TOTAL 12 BOXES GEOCHEM TOTAL 17 BOXES SHIPPED 11/22/93 BY BOAT SAMPLE SHIPMENT NO. 2 DATE: 11/30/93 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES INTERVAL WET SAMPLES (W) SET AND BOX NO A3 , B3 A4 , B4 GEOCHEM S.%MPLES (GC) SET & BOX NO. B13 B14 B15 B16 B17 B18 B19 B20 B21 B22 TOTAL 0 BOX DRYS INTERVAL 2610' - 3360' 3360' - 4380' TOTAL 4 BOXES WETS INTERVAL 2520' - 2700' 2700' - 2880' 2880' - 3060' 3060' - 3240' 3240' - 3450' 3450' - 3600' 3600' - 3780' 3780' - 3960' 3960' - 4140' 4140' - 4320' TOTAL 10 BOXES GEOCHEM TOTAL 14 BOXES SHIPPED 11/30/93 BY BOAT SAMPLE SHIPMENT NO. 3 DATE: 12/09/93 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D2 WET S~IPLES (W) SET AND BOX NO A5,B5 A6,B6 A7,B7 A8,B8 GEOCHEM SAMPLES (GC) SET & BOX NO. B23 B24 B25 B26 B27 B28 B29 B30 B31 B32 B33 B34 B35 CARD BOXES A3,B3 A4,B4 A5,B5 A6,B6 INTERVAL 2640' - 3810' 3810' - 4950' 4950' - 6150' 6150' - 7440' TOTAL 1 BOX DRYS INTERVAL 4380' - 5340' 5340' - 6360' 6360' - 7140' 7140' - 7770' TOTAL 8 BOXES WETS INTERVAL 4320' - 4500' 4500' - 4680' 4680' - 4860' 4860' - 5040' 5040'- 5220' 5220' - 5400' 5400' - 5580' 5580' - 5760' 5760' - 5940' 5940' - 6120' 6120' - 6300' 6300' - 6480' 6480' - 6660' GEOCHEM SAMPLES 12/09/93 CONTINUED B36 B37 B38 B39 B40 B41 B42 6660' - 6840' 6840' - 7050' 7050' - 7230' 7230' - 7410' 7410' - 7590' 7590' - 7770' 7770' - 7950' TOTAL 20 BOXES GEOCHEM TOTAL 29 BOXES SHIPPED BY BOAT ON 12/09/93 SAMPLE SHIPMENT N©. 4 DATE: 12/14/93 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: ~TIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES D~ ~ B7 WET SAMPLES (W) SET AND BOX NO A9, B9 GEOCHEM SAMPLES (GC) SET & BOX NO. B43 B44 B45 B46 B47 B48 INTERVAL ~A~' - 8930' TOTAL 1 BOX DRYS INTERVAL 7770' - 8930 TOTAL 1 BOXES WETS INTERVAL 7950' - 8130' 8130' - 8310' 8310' - 8490' 8490' - 8670' 8670' - 8850' 8850' - 8930' TOTAL 6 BOXES GEOCHEM TOTAL 8 BOXES SHIPPED BY BOAT ON 12/14/93 SAMPLE SHIPMENT NO. 5 DATE: 1/3/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE.,' SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D4 WET SAMPLES (W) SET AND BOX NO A10,B10 All,Bll A12,B12 A13,B13 A14,B14 GEOCHEM SAMPLES (GC) SET & BOX NO. B49 RS0 B51 B52 B53 B54 B55 B56 B57 CARD BOXES AE,B8 A9,B9 A10,B10 All,Bll INTERVAL $930' - 9360' 9360' - 9700' 9700' - 10110' 10110' - 10540' TOTAL 1 BOX DRYS INTERVAL 8930' - 9290' 9290' - 9640' 9640' - 9970' 9970' - 10260' 10260' - 10550' TOTAL 10 BOXES WETS INTERVAL 8930' - 9110' 9110' - 9290' 9290' - 9470' 9470' - 9650' 9650' - 9830' 9830' - 10010' 10010' - 10190' 10190' - 10370' 10370' - 10550' TOTAL 9 BOXES GEOCHEM TOTAL 20 BOXES SHIPPED BY BOAT ON 1/3/94 SAMPLE SHIPMENT NO. 6 DATE: 1/10/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES INTERVAL WET S;~MPLES (W) SET AND BOX NO A15,B15 A16,B16 A17,B17 A18,B18 GEOCHEM SAMPLES (GC) SET & BOX NO. B58 B59 B60 B61 B62 B63 B64 TOTAL 0 BOX DRYS INTERVAL 10550' - 10790' 10790' - 11040' 11040' - 11360' 11360' - 11650' TOTAL 8 BOXES WETS INTERVAL 10550' - 10730' 10730' - 10910' 10910' - 11090' 11090' - 11270' 11270' - 11450' 11450' - 11630' 11630' - 11810' TOTAL 7 BOXES GEOCHEM TOTAL 15 BOXES SHIPPED BY BOAT ON 1/10/94 SAMPLE SHIPMENT NO. 7 DATE: 1/19/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D-5 WET sAMPLES (W) SET AND BOX NO A19,B19 A20,B20 GEOCHEM SAMPLES (GC) SET & BOX NO. B65 B66 CARD BOXES Al2, B12 Al3, B13 Al4, B14 Al5, B15 INTERVAL 10540' - 10950' 10950' - 11400' 11400' - 11880' 11880' - 12290' TOTAL 1 BOX DRYS (8 CARD BOXES) INTERVAL 11650' - 12050' 12050' - 12290' TOTAL 4 BOXES WETS INTERVAL 11810' - 11990' 11990' - 12170' TOTAL 2 BOXES GEOCHEM TOTAL 7 BOXES SHIPPED BY HELICOPTER ON 1/19/94 SAMPLE SHIPMENT NO. 8 DATE: 1/24/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE.,. SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES D-6 Al6, B16 WET S~h~IPLES (W) SET AND BOX NO A21,B21 GEOCHEM SAMPLES (GC) SET & BOX NO. B67 B68 INTERVAL 12290' - 12590' TOTAL 1 BOX DRYS (2 CARD BOXES) INTERVAL 12290' - 12590' TOTAL 2 BOXES WETS INTERVAL 12170' - 12350' 12350' - 12530' TOTAL 2 BOXES GEOCHEM TOTAL 5 BOXES SHIPPED BY HELICOPTER ON 1/24/94 SAMPLE SHIPMENT NO. 9 DATE: 2/3/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA WET SAMPLES (W) SET A~ BOX NO A22,B22 A23,B23 A24,B24 GEOCHEM SAMPLES (GC) SET & BOX NO. B69 B70 BT1 B72 B73 B74 T l~Trl~ .~DX?AT 12590' - 13000' 13000' - 13430' 13430' - 13750' TOTAL 6 BOXES WETS INTERVAL 12530' - 12710' 12710' - 12890' 12890' - 13070' 13070' - 13250' 13250' - 13430' 13430' - 13610' TOTAL 6 BOXES GEOCHEM TOTAL 12 BOXES SHIPPED BY BOAT ON 2/3/94 SAMPLE SHIPMENT NO. 10 DATE: 2/8/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D7 WET SAMPLES (W) SET AND BOX NO A25,B25 GEOCHEM SAMPLES (GC) SET & BOX NO. B75 B76 B77 CARD BOXES A17,B17 A18,B18 A19,B19 INTERVAL 12590' - 13120' 13120' - 13750' 13750' - 14010' TOTAL 1 BOX DRYS INTERVAL 13750' - 14010' TOTAL 2 BOXES WET INTERVAL 13610' - 13790' 13790' - 13970' 13970' - 14010' TOTAL 3 BOXES GEOCHEM TOTAL 6 BOXES SHIPPED BY BOAT ON 2/8/94 S~PLE SHIPMENT NO. 11 DATE: 3/4/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: I~TIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. WET SAMPLES (W) SET AND BOX NO A26,B26 A27,B27 A28,B28 A29,B29 CARD BOXES A20,B20 A21,B21 INTERVAL 13460' - 14000' 14000' - 14640' TOTAL 1 BOX DRYS INTERVAL 13460' - 13850' 13850' - 14200' 14200' - 14570' 14570' - 14660' GEOCHEM SA~MPLES (GC) SET & BOX NO. B78 B79 B80 B81 B82 B83 B84 B85 B86 B87 TOTAL 8 BOXES WETS INTERVAL 13460' - 13580' 13580' - 13700' 13700' - 13820' 13820' - 13940 13940' - 14060' 14060' - 14180' 14180' - 14300' 14300' - 14420' 14420' - 14540' 14540' - 14660' TOTAL 10 BOXES GEOCHEM TOTAL 19 BOXES-SHIPPED BY HELICOPTER ON 3/4/94 SAMPLE SHIPMENT NO. 12 DATE: 3/7/94 TO: ARCO ALASKA INC. ARCO BAYVIEW FACILITY 619 EAST SHIP CREEK AVE., SUITE 104 ANCHORAGE , ALASKA, 99501 ATTN: MARTIN STANFORD FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D9 WET SAMPLES (W) SET AND BOX NO A30,B30 GEOCHEM SAMPLES (GC) SET & BOX NO. B88 CARD BOXES A22,B22 INTERVAL 14640' - 14705' TOTAL 1 BOX DRYS INTERVAL 14660' - 14705' TOTAL 2 BOXES WET INTERVAL 14660' - 14705' TOTAL 1 BOXES GEOCHEM TOTAL 4 BOXES SHIPPED BY HELICOPTER ON 3/7/94 SAMPLE SHIPMENT NO. 1 DATE: 11/22/93 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. 1 CARD BOXES !E 2E 3E INTERVAL 407' - 1170' 1170' - 2040' 2040' - 2610' TOTAL 1 BOX DRYS SHIPPED BY BOAT 11/22/93 SAMPLE SHIPMENT NO. 2 DATE: 12/14/93 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D2 CARD BOXES E4 E5 E6 E7 E8 E9 El0 INTERVAL 2643' '- 33~0' 3360' - 4110' 4110' - 4950 4950' - 5880' 5880' - 6720' 6720' - 7830' 7830' - 8930' TOTAL 1 BOX DRYS TOTAL 1 BOX DRY SAMPLES SHIPPED BY BOAT 12/14/93 SAMPLE SHIPMENT NO. 3 DATE: 1/10/94 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D3 CARD BOXES EI.~. El2 El3 El4 El5 El6 El7 INTERVAL 8930' - 9290' 9290' - 9590' 9590' - 9930' 9930' - 10540' 10540' - ~0820' 10820' - 11120' 11120' - 11400' TOTAL 1 BOX DRYS TOTAL 1 BOX DRY SAMPLES SHIPPED BY BOAT 1/10/94 SAMPLE SHIPMENT NO. 4 DATE: 2/8/94 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. D4 CARD BOXES El9 E20 E21 E22 E23 E24 E25 E26 INTERVAL 11400' '- 1173C' 11730' - 12040' 12040' - 12420' 12420' - 12690' 12690' - 13100' 13100' - 13520' 13520' - 13980' 13980' - 14010' TOTAL 1 BOX DRYS TOTAL 1 BOX DRY SAMPLES SHIPPED BY BOAT 2/8/94 SAMPLE SHIPMENT NO. 5 DATE: 3/4/94 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES E27 E28 E29 INTERVAL 13460' - 13860' 13860' - 14280' 14280' - 14660' TOTAL 1 BOX DRYS TOTAL 1 BOX DRY SAMPLES SHIPPED BY HELICOPTER 3/4/94 SAMPLE SHIPMENT NO. 6 DATE: 3/7/94 TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO}~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 FROM: BAKER HUGHES INTEQ PHILLIPS TYONEK PLATFORM COOK INLET ALASKA DRY SAMPLES (D) SHIPPING BOX NO. CARD BOXES E30 INTERVAL TOTAL 1 BOX DRYS TOTAL 1 BOX DRY S~PLES SHIPPED BY HELICOPTER 3/7/94 APPENDIX IV BIT RECORD BIT DATA RECORD SUNFISH ! 3 RUNI Bit,' {FR ,' TYPE ,' HIZE,' NOZZLE ,' 8TART', DRILLED ,' AVO ,' WOB ,' RP{ ,' PU{P,' SPN/UP{,' BIT CONDITION ' ' PRESSI 'I:0: D: L:B: U :0' E ' { ' ' ' ' SIZE ' DEPTH' FT. { HRS' EOP I xlO00, , , 1 I I I I I I I .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' i { HTC ' ATJ!5 ] 13,5 ,' TFA= 1,053 ' 248 I 158' 20.5 I 7.71 5/20' 30 ,' 1600'160/786, 12:2:WT: A:E: I :NO:BHA il I t I I .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 2,' REilI HTC { ATJ15 13,5 I TFA= 1.053 { 406 I 1891 { 27.5 { 68.7 { I5/25 { 140 ,' 1800 { 160/786 {3:2:CT: A:E: 4 :WT:BC .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 325 { 3.11104.8 ' 25 ' 140 ' 2500 '160/786 Ii:I:NO: A:E: 1 :NO:TD 31 2 ,' HTC ,' ATJI5 113.51TFA: 1.053 I 2297, , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 3 ' HRANT : OPENER ' 240' TFA= 1.491' 407' 1797 { 32.0' 56.1' 10/25 ' 30/60 ' 1650 '200/982'3:4:gG' H:E: 3 'ER:PR 1 I I ' I I i I I I I I I .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... ~ .......... + ...... + ......... + ....................... ' 2204 { 403 '11.5 { 35.0' I0/25 I 40/60 ' 22001180/884'2:2:CT: A:E: I :NO:TD 5,' 4 I URANT ,' OPENER I 24.0 { TFA= 1.491, , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 242.2' 60/70' 70/1004 2000'160/786 '2:2:WT: A:3' 2 :NO:BHA ' 5 { SNITH ' DSJC '17,5 { TFA= 1.05234 2602 { 775 { 3,2, , , , , 1 I I .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' TFA=l,0523 { 3382 I 1742 { 23,3 { 74.8 { 60/70 I 80/100 { 2500 4192/845 13:3:SS: A:E: I :WT:BHA 7{ 6 I SNITH { {FDSHC 417,5, .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ........................ ' 5124 ' I419 ' 41 2 ' 34,4 { 50/65 { 90/110 ' 2700 { 166/816 '3:3'WT: A:E:I/16:SS:BHA{ ' 7 ' STC ' {SDSHODCLI 17.5 { TFA= 1.0523, , , , , , 1 I I ' .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 6543 I 586 ' 30 9 ' 19 0 { 35/60' 100/120' 2700 ' 160/786 '2'2'SS: A:E: I :NO:BHA ' 8 ' SEC ' SS3350J4 ' 17.5 { TFA= 1.I167 , , , , , , l I I I ' ' .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 7129' 910 1501' 182 ' 40/70' 110/120' 2700'170/835 '3'3'FC: A'E: I :NO:BHA 10,' n. ,' SEC ,' SS3350J4,' 17.5 { TFA=1.5217, , . , . , , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 11 I I0 ,' SEC ,' SH335UJ4', 17.5 ,' TFA=l.5217', 8039,' 546 ,'37.7', I4.5', 40/70 I 90/100 I 2800', 170/825 ,'6:5'BT: {:F' I:WT:PR .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 40/601 90/100' 2800 I 85/835 13:3'WT: {:E: I :NO:TD 12,' 1i ,' STC I SDUHC ', 17.5 ,' TFA=l.5217,' 8585 { 345 { 30.6 { 11,3 , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' ~{.6 ' 50/60 ' 70/75 ' 1500 ' 90/630 12:2:N0: A:E: I :NO'BHA 13412 ,' REED ,' HPll ,' 12.25', TFA=I.O00 ,' 8930 I82 412.5, .. , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 14,'t°i~ ,~ HTC ,' {FDSHC ,' ,~..'° ~5', TVA=.. 0.5500,' 9112 ,' 748 ', 56.5 ', 13.2 ,' 40/45 ,' IHO ,' 2500 ,' 85/598 ,..'°'4:FC: A:E:I/1H:FC'BHA .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 9860 ' 744 ' 60.0' 11.4' 45/50 ' !00/120 ' 2700 ' 80/562 14:4:?C: A:E:I/1H:?C'BHA 15 ,' 14 '~ STC ,' {FDSHCL ,' 12.254 T~A=...5000 ,, , , , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 16,' ~ ,' STC I {FDSHCL ,' 12.251 TFA=.5100 ,' 10604,' 512,' 44.5', !I.5 ', 40/45', 100/120,'2700 ,'80/560 13:3:FC: A:E:!/16:FC:BHA .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 11116 ' 358 I 41.0 I 8.7' 45/55 ' 100/130 '3000 ' 85/600 15:6:WT: A:F:2/16'NO:BHAI 17,' i6 ,' HTC ,' ATXCP{I {12.25{ TFA=,5300 , , , , , , I .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 11474' 177 ' 28.5 I 5.2 ' 45/55' 90/I30' 3000' 85/600 12:2:FC: A:E:i/16:NO:BHAI 18 ,' I7 ,' STC I {SDOHODCLI 12.254 TFA= .5300 , , , , , , , .... + ..... + ........ + .......... + ...... + ............. +...,...+ ....... + ...... + ....... + ....... + .......... + ...... + ......... + .......................~ ' 11651 ' I91 { 21.5 ' 8.8 ' 4~/55' 95/I00 '3100 ' 85/600 12:2:N0: A:E:I/I6'NOBHAI 19,' 18 { STC ', ~FDSH ,' I2.5 { TFA=.5000 , , , , , , .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 20,' 19 ,' SEC ,' SS3350J4,' 12.5 ,' TFA=.5200 ,' 11842 ,' I14,' 7.0', 16.3 ,' 60 ', 100 ,' 3000 ,' 85/600 12:2:N0' A:E: I 'NO:BHAI + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ,' 2!I 20 { SEC I SS3358J4 I I2.5 ', TFA=.5200 ,' 11956 ,' 194,' 21.5 ,' 9.0 ,' 45/50 ,' 90 ,'3000 ,' 85/600 16:4:BT' {:E Z'WT:BHA{ + .... + ..... +_..' ..... + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... + ' 22' 2! ' STC ' SDUH ' 8.5' TFA= 3300 ' 12150 ' I35 ' I9,0' 7,I' 30/35 ' 80 ' 2700 '100/350 '4:4:FC: A:7: I I I I I I I I t I I I I { I I + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... { { 23{ 22 ,' EC ,'SC7120 ,' 8.5', TFA=.9500 ,'12285', 21', 6.0{ 3.5', 5/12', 50/60 ,'2000 ,' 90/318,'452WORN :PR, + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... , ' 12306 ' 99 ' 11.0' 9.0' 35/40 ' 90/I00 ' 2700 ' 100/351 '6:4:CT: {:5' I :WT:CP, ,' 24,' 23 ,' STC I {FDUH I 8.5 I TFA=.3300 , , , , , , , , , + .... + ..... + ........ + .......... + ...... + .... ~ ........ + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 25'24 ' EG ' HC777FO ' 8,5' TFA= 6000 '12405' 60' 20,0' 3,0'10/25' 50/60 '1400' 85/30 '20{WOENCUtFULLCOREI I I I i I I ' { I I I I I I I I ~ .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... { 126,' 25 ,' SEC {}U{44NU J 8.5 J TFA=.3300 ', 12465 I 151,' 20.0 J 7.5,' 35/40,' 90/100,' 2700,' I00/352,'8:7'WT: A:F: I :FC:PR, + .... + ..... +-- ...... + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 8.6 { 8/28 ' 100/140 ' 2700 ' 100/352 '5:7'WT: T:X: 0 :CT:BHAI ' 27' 26 ' HYC ' DB56H ' 8.5 ' TFA=.3700 J 12616 J 1012 4116 5 , , , , , I I I I I I ' (BIT RECORD PAUE 2) ' 13628 I 13 ' 3.5 I 4.0 I 5/20' 60/75 ' 2550 I 86/280 14:3:CT: A:I: I:WT:PR' 128127 ,' KC ', RC412 I 8.5 { TFA=.5000 , , , , , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' EC ' HC777FG ,' 8.5,' TFA=,6000 I 13641', 181 6.0 I 3,0 110/254 60/65 ] 25001 86/280 17:4:CT: S:X: I:NT:PE', 129 {HR24, , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 21' 5,0 I 4,0 I 10/30' 60/65 I 2500' 86/300 12:2:N0: A:X: I:NO:PR' 130128 {EC ,'SC777 ,' 8.5'TFA=, .6000 113659, , , , , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... 1314RRZOIEC {SC777 I 8.5,' TFA=.6000 ,' 13680 { 20 { 6.0 { 3.3 I 5/18 { 65/70 I 2660 { 106/372 13:3:N0: A:I: I :NO:PR', + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 286' 490 I 5.8' 6/30' I00/135' 2700' 106/372 '6:8'FC: A:X: I:NO:BHAI ,' 32 ,' 29 ,' HYC { D556H ,' 8.5,' TFA=.3700 I 13700, , . , , , , , + .... + ..... + ........ ~ .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + .......................+ ' 13986 ' 28 ' 25 ] 11.2' 5/16 ' 100/1104 2950 1106/372' LOST BIT IN HOLE ' ,' 33,' 30 ,' STC I {2iEP I 8.5 I TFA=.3500 , , , . , , , , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... ~ ......... + ....................... ' 12 I 20 I 60' 2/3 I 40/60 ' 24001106/373 ' DREHHSIDETRACKPLUO ' ' 34' 3I ' HTC ' AT~O1 ' 8,5 { TFA= 4500 I 13445, , , , , I I I I I e , , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ', 35 { 32 ,' ~C I ST I 8.5 I TFA= .5500 { STUCK PIPE AT 13362' ON WAY INTO HOLE, WORKED LOOSE, TRIPPED OUT ,' + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + .......................+ {36 {HR31 { HTU { AT~O1 { 8.5 { TFA= .4500 { WASH, REA{{ AND CONDITION HOLE, NO NEW FOOTAUE DRILLED + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 43.5 { I 3 { 0/25 { 80/110 ' 2700 '110/387'4:{:WT: A:X: '37 {HR32' ~C { ST { 8.5 { TFA= ,5500 { 13457 { 58, , , I I ~ I + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... I ' 38 ' 33 ' ~C ' DH56H ' 8,5 ' TFA= .3700' 13515 ' I66 ' 19.0 { 8.7' 10/22 ' 95/135 ' 2800' 110/387 12:I:WT: A:X: I :NO:CP, I I I I I I I I I I I I I + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + .......................+ ' 13681' 50' i9.0' 2.6'I0/20 { 70 '1450' 85/299 I7:?:WT: A:X: I:SS' '39 ' 34 ' EC ' SC777 ' 8,5 I TFA= 6000, , , , , , , { I i I I ' + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... + { 40 IRR33', HYC ,' DSS6H { 8.5 ,' TFA: .3700,' 13731 ,' 210,' I8.5 { I1,4i15/25', 90/125 ,' 2700,' 106/373:2:I:WT: A:X: I:NO:LOO] + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 13941 I NONE ' WIPER TRIP DURIN8 WIRELINE LOO RUN 12:2:WT: A:E: I :NO:LOU' ,' 41 iRR31{ HTC .,' ATW{O1 { 8.51TFA: OPEN, , , + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 42 ' 35 ' STC ' F2 ' 5.875' TFA= 5100 ' 13941 ' 6 ' 6.0 ' 1.0 ' 10/20 ' 70 ' 2000 ' 60/211 12:2:N0: A:E: I 'NO:PR, I I I I I I ' I { I I { I I I + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 13947 ' 378 ' 58.0 ' 5.9 ' 5/20 ' 2§0 ' 2600 ' 60/2!I 13:6:WT: A:X: I 'CT:CP, ' DS56H ' 5.875{ TFA= 4900 { , I , { ' ' ,' 43{36 I HYC , , . + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... ' 14325' 43' Z4.0' 1.9' 5/ZO ' 60/80 ' 2280 ' 45/158,3:v:WT' ~ ' A:X: I 'WT:PR' ' 44' 37 ' EC ' SC777 ' 5.8751TFA= 3500, , , , , , , , , t I I I { ' + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... { ' 14368 ' 337' 69,5 ' 4,9 I 6/20' 260/265 '3280 ' 65/229 '7:6:WT: A:X: 2 :HO:PR, ' 45' 38 ' SEC ' HZ2320 ' 5.8751TPA= 4900 , , , , , , , , I I I I I + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... { ' 14705' NONE ' WASH AND REA{ HOLE TO CONDITION FOR FINAL WIRELINE LOOS , ' 46' RE35: STC ' F2 ' 5.8751TFA= .5100 , , , I I { { + .... + ..... + ........ + .......... + ...... + ............. + ....... + ....... + ...... + ....... + ....... + .......... + ...... + ......... + ....................... APPENDIX V LOGS ~/-~ MEMORANDUM State uf Alaska Alaska Oil and Gas Conservation Commission TO:. THRU: David Joh.~~, Chairma~ Blair Wondzell, P. I. Supervisor FROM: Bobby Fost.zer,~''~ SUBJECT: Petroleum' Inspe'ctor DATE: FILE NO: March 7&8, 1994 CX81CHBD.doc Casing Shoe Plug Phillips Petro.- Sunfish#3 PTD # 93 - 76 - N. Cook Inlet Mondav, March,,1994: I traveled this date to Phillips' Tyonek Platform to witness the upcoming BOPE'~est, the subject of another repod. I arrived at the platform and met with Gary Sonnenberg, Phillips drilling foreman. Gary informed me that he had received word from his office to plug the well back to the casing shoe at 13,937'. I questioned him about the formation below the casing shoe and he said that no hydrocarbon bearing zones had been encountered. Gary and I talked about the setting of the cement retainer and I informed that AOGCC regulations stated that the retainer had to be set a minimum of 50' above the casing shoe unless approved by the Commission to otherwise. It was decided, and approved by Blair Wondzell, Senior AOGCC P.E., to set the retainer 25' above the shoe and pump 8.3 bbls. of 15.8 Class G cement ( 228' ) below the retainer instead of the required 100' and 2 bbls. ( 60' ) above the retainer. The setting of the retainer 25' Iow was to insure there was enough" rat hole" to drop the tubing conveyed perforating guns. Tuesday, March 8, 1994: The retainer was run and set with the E-Line unit at 13,916'. The drill pipe was run in the hole with the retainer sting-in tool and stung into the retainer. The annulus was pressured up to 1500 psig and the formation was broke down at 2350 psig. The sting-in tool was then pulled out of the retainer and the 12.3 bbls. of cement was pumped down the drill pipe with 5 bbls. of water ahead and behind followed by 220 bbls. of mud. The tool was stung into the retainer and 8.3 bbls of cement was pumped below the retainer at 1.5bbls./ min. with 2450 psig. The tool was unstung and 2bbis.( 60' ) of cement was placed on top of the retainer. Thursday, March 10,1994: I contacted the Phillips drilling foreman, Danny Simonton, this date and he informed me that he had tagged the cement plug 50' above the retainer and had pressure tested the plug and casing after circulating the 14.5ppg drilling mud out of the hole with sea water to 5000 psig and everything tested OK. Danny informed me that tubing was being run in preparation for the upcoming flow testing of the Sunfish sands. Page 2/2 Summary: I witnessed the successful setting of the 7" casing shoe plug on Phillips Petroleum Company's North Cook Inlet well Sunfish #3 Attachment MEMORANDU TO: David Johns n~, Chairma~ State o, Alaska Alaska Oil and Gas Conservation Commission DATE: March 7, 1994 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: Bobby Fostbr~ SUBJECT: Petroleum Inspector AX81CGBD.doc BOP Test - Pool 429 Phillips Petro. Sunfish #3 PTD# 93-76 - N. Cook Inlet Monday, March 6, 1994: I traveled to Phillips Petroleum's Nodh Cook Inlet Tyonek platform this date to witness the upcoming BOPE test. Tuesday, March 7, 1994: The BOPE test began at 1:00 AM and was concluded at 3:00AM. As the attached AOGCC BOPE test report show there were no failures. All of the equipment was in good repair and appeared to have had proper maintenance. Summary: I witnessed the satisfactory BOPE test on Phillips N.C.I. Sunfish # 3 being drilled by Pool Arctic 429. Test time 2 hours - No failures. Attachment: AX81CGBD:XLS STATE O~J ~.~,J4z~ tV,~lOIl~. ~fl~I~~NSEF BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: POOL ARCTIC Rig No. 429 PTD# 93-76 Rep.: Rig Rep.: Location: Sec. PHILLIPS PETROLEUM SUNFISH #3 7" Set @ 13,939' Weekly X Other DATE: 3/7/94 Rig Ph.# 776 - 6074 GARY SONNENBERG DARREL GREEN § T. 11N R. 9W Meridian D TEST DATA MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Drl. Rig OK Reserve Pit N la BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 500~3500 P 1 500~5000 I 500t5000 P I 500~5000 P 1 500~5000 P 500~5000 500~5000 P 1 2 N~A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Gas Detectors YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500~5000 P I 500~5000 P I 500~5000 P I 500~5000 P CHOKE MANIFOLD: No. Valves 17 No. Flanges Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 500~5000 P 38 500~5000 P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btrs: 6 @ 2100 3,000 P 1,400 P minutes 28 sec. minutes 50 sec. YES Remote: YES Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 24 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: GOOD TEST Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES NO X 24 HOUR NOTICE GIVEN YES NO X Waived By: Witnessed By: AX81CGBD.XLS BOBBY D. bOSIER MEMORANDUI' ,. .State of .Jaska Alaska Oil and Gas Conservation Commission TO: THRU: David John~, Chairman~ Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, dg~ SUBJECT: Petroleum Inspector DATE: FILE NO: January 24, 1994 AX8JAXBD.DOC BOP test Pool rig #429 Phillips well Sunfish #3 Sunfish PTD #93-76 Sunday, January 23, 1994: I traveled to Phillips petroleum Tyonek platform in the North Cook Inlet unit to witness the weekly BOP test on Pool rig #429. The rig was drilling ahead when I arrived so I made a cursory inspection and stood by until approximately 2100 hrs. At this time the rig crew was pulling out of the hole and we tested the choke manifold with all valves passing their pressure test. We stood by until the bottomhole assembly was disassembled and the test plug was set in the casing head. Monday, January 24, 1994: We concluded by testing the stack and the remainder of the BOPE. All equipment functioned properly and held it's pressure test. I found Darrell Greene's test procedure to be quick, but thorough, with all equipment receiving a positive test. The platform and rig were kept clean and orderly with all equipment having the appearance of regular maintenance. Summary: I witnessed the weekly BOP test on Pool rig #429 on Phillips petroleum Tyonek platform. Test time 2 1/4 hours, No failures. Attachment: AX8JAXBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Operator: Phillips Petroleum Well Name: Sunfish #3 Casing Size: *9 5/8 Set @ Test: Initial Weekly Rig No. 429 *12737 X Other DATE: PTD # 93-76 Rig Ph.# Rep.: Marc Babineaux January-24-1994 776-6074 Rig Rep.: Darrell Greene Location: Sec. 6 T. 11N R. 9W Meridian Seward MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/AI Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/3500 P 1 250~000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P 2 250/5000 P 2 250/5000 P N/A N/A N/AI MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 250/5000 P 42 250/5000 P 1 P Function Function ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 2250 Average 3,000 I P 1,450 P minutes 37 sec. minutes 52 sec. OK Remote: OK Psig. Number of Failures: 0 ,Test Time: 2 1/4 Hours. Number of valves tested 30 Repair or Replacement of Failed · Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AC)GCC Commission C)ffice 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: Outstanding Test / Rig Condition Very Good Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021 L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AX8JAXBD.XLS Louis R. Grimaldi MEMORANDUM TO: David Johnsto~~ Chairman,-~ S TA TE Ol A LA SKA ALASKA OiL AND GAS CONSER VA TION COMMISSION DA TE: 12-19-93 FILE NO: AXSJLSAD.DOC THR U: FR OM: Blair Wondzell P.I. Supervisor ~. ¢..'~,'" ~ou Grimaldi Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: BOP test Pool Rig # 429 Sunfish #3 Phillips Tyonek platform PTD #93-76 Saturday, December 18, 1993 I traveled to Phillip's Tyonek platform in North Cook Inlet to witness the initial BOP test on the 13 5\8 stack. Rig #429 is owned by Pool Arctic Alaska, and as in my previous inspections I found it to be in top shape. The Bop test was not begun until early the following morning. The test plug that was set in the casing head presented problems in that there was a persistent slight leak that took two times of pulling and resetting before a positive seal was accomplished. The rubber sealing element on the test plug was a tight fit and seemed to be damaged during installation in the stack. All equipment I observed functioned properly and held it's pressure test. In my experience with the Pool Arctic personnel in Cook Inlet I have found them to be professional Oil Field hands who take the extra step to insure their equipment is in top shape. SUMMARY; I witnessed the initial BOP test on the Phillip's Tyonek platform in North Cook Inlet. Forty Four components, No failures. Test time Four hours. Attachment: AXSJLSAD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 13 3/8 Test: Initial X Workover: Pool Arctic Rig No. 429 PTD # Phillips Petroleum Rep.: Sunfish #3 Rig Rep.: Set @ 8,900 Location: Sec. Weekly Other DATE: 12/19/93 93-76 Rig Ph.# 776-6074 Gary Sonnenburg/John Salario Gary Goerlich 6 T. 11N R. 9W Meridian Seward MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) DrI. Rig OK Reserve Pit N/A BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 1 500\5000 P 1 500\5000 P 1 500\5000 P 1 500~000 P 1 500\5000 P 2 500\5000 P 2 500~000 P NV~ N~, N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: Test Quan. Pressure P/F 1 500\5000 P 1 500\5000 P 1 500\5000 P 1 500\5000 P 17 Test Pressure P/F 500\5000 P 38 500\5000 P 1 P Check Valve ~lUD SYSTEM: Visual Alarm Trip Tank p P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 1850 Average 3,000 ! P 1,450 P minutes 50 sec. minutes 25 sec. OK Remote: OK Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 24 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: Good Test, Good Rig. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AX8JLSAD.XLS Louis R Grimaldi ALASKA OIL AND GAS WALTER J. HICKEL, GOVERNOR CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 22, 1993 D. C. Gill Drilling and Production Engineering Manager Phillips Petroleum Company Box 1967 Houston, TX 77251-1967 North Cook Inlet Sunfish No. 3 Revised Phillips Petroleum Company- Permit No. 93-76 Sur Loc Platform A leg 1, Slot 6, 1249'FNL, 980'FWL, Sec. 6, T11N, R9W, SM Btmhole Loc 4150'FSL, 1486'FWL, Sec. 31, T12N, R9W ~ 14150'TVD, SM Dear Mr. Gill: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated June 4, 1993 are in effect for this revision. David W. J~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc2 Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl ALASKA OIL AND~(~,,~"~:~N~"~~ON COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redriil Cl 113. Type pt well. Exploratory I~ Siratigrapnic Test [] Development Oil Re-Entry C DeepenFI Service ~ Oevelooement Gas ~ Single Zone ~ Multiole Zone 2. Name ot Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Petroleum Company 132 feet 3. Address 6. Property Designation Exploratory 6330 W. Loop South, Bellaire, TX. 77401 'ADL 17589 ~. Location of well at surface Platform A leg 1, 7. Umt or property Name 11. Type 8ond~,..~o^^c2s.o~ slot 6 1249 FNL, 980 FWL Sec 6-TllN-R9W North Cook Inlet Statewide . ,~ ,At top of productive interval 3150' FSL, 1360FWL 8. Well nurp~er Number Sec 31-T12N-RgW @ 11000' TVD Sunfish No. 3 41-00-524 At total depth 4150 FSL, 1486 ~ Sec 31 :9. Approximate spud date Amount T-12N-RgW @ 14150' TVD Nov. 19, 1993 $200,000 12. Oistance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed dept~tMo,,n~ tva' property line @Surface 8' Sunfish2 15350 MD 1486 feet @BHL 918 NCIU A-l[eet 5002 14150.TVD feet 16. To De completed for deviated we~ls 918 17. Anticipated pressure (,~. l0 **c 2s.03s Kickoff depth 830 feet Maximum hole angle24 ~ "'"""""""""' 3920 ,,,, ^, ,o,., ~.,,. rrvm 14150 18. Casing program Settincj Oeot~ s~ze Specifications Top Bottom Quantity of cement Hole Casing Weightt Grade Coupling Langtn MO TVD MO ,-VD (include stage data~ )riven 30" J457I B Welded 350 55 55 407 407 24 20" 169 ~-55 C-60 2545 55 55 2600 2500 ',e~ 2000sx tail 650.~x 17-1/2 13-3/8"1 72 ~80/C~,5 BTC 8845 55 55 ~900 8100 5600 sx in 3 sta~e.~ 12-1/4, 9-5/8", 53.5 ]~80 BTC 12095 55 55 12150 11000 5~0 ~ 8-1/2 I 7" I 32 L80 BTC 12950 11850 1075015350 14150 700 sx 19. To Oe completed for Rednll, Re-entry, and Oeepen 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 oo u ,o, RECEIVED Surface Intermediate DEC 1 3 1995 Production Liner Alaska 0il & 6as Cons. Commissior Perforatlon depth: measured . Anchorage true vertical 20. Attachments Filing fee ~ Property plat G BOP Sketch F"l Diverter Sketch ¢__., Drilling program G Drilling fluid program ~ Time v$ deptl'l pict ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements '..._%- 21. I hereby certify that the foregomg is true and correct to the best of my knowledge Commission Use Only ~..~- .~'~' 50-- g='~..R' "~ c~ ¢ ~'<:~ - -- for other requirements Conditions of approval Samples requirecl ~ Yes F~ No Mud log required ~ Yes [] No Hydrogen sulfide measures [] Yes ~' No Directional sur~ey reclu~recl ,~ Yes ~ No Required working pressure for BOPE ~2M; [] 3M; [] 5M; [] 10M; ~ 15M Other: driglrlal Signed By by order of Approved by ,}avid W, JohrlstorlI Commissioner the commission Date /o,~-C~- ~.~ Form 10-401 Rev. 12-1-85 Submit in triplicate ,, -RECEIVED Sta. Num. M.D. Feet Incl. Angle Deg. WELLPATH DATA Ai~s~Oi~&Gas~n~.~mmissio~ Sunfish No. 3 ~chorag~ Azi. Coordinates Vert. Angle +N,-S +E,-W TVD Sec. Deg. Feet Feet Feet Feet Closure Dist. Dire. Feet Deg. 10 11 12 13 14 15 16 '.~7 18 19 20 21 22 23 24 25 26 27 28 29 3O 31 32 33 34 35 36 37 38 39 4O 41 42 43 44 45 46 47 48 0 0.00 100 0.00 200 0.00 300 0.00 400 0.00 500 0.00 600 0.00 700 0.00 800 0.00 KOP, BUR 2 830 0.00 930 2.00 1030 4.0'0 1130 6.00 1230 8.00 1330 10.00 1430 12.00 1530 14.00 1630 16.00 1730 18.00 1830 20.00 1930 22.00 2030 24.00 EOB, ANG 24.5 2057 24.55 2157 24.55 2257 24.55 2357 24.55 2457 24.55 2557 24.55 2657 24.55 2757 24.55 2857 24.55 2957 24.55 3057 24.55 3157 24.55 3257 24.55 3357 24.55 3457 24.55 3557 24.55 3657 24.55 3757 24.55 3857 24.55 3957 24.55 4057 24.55 4157 24.55 4257 24.55 4357 24.55 4457 24.55 4557 24.55 0.00 0 0 0 0 5.00 0 0 100 0 5.00 0 0 200 0 5.00 0 0 300 0 5.00 0 0 400 0 5.O0 0 0 500 0 5.00 0 0 600 0 5.00 0 0 700 0 5.00 0 0 800 0 5.00 0 0 830 0 5.00 2 0 930 2 5.00 7 1 1030 7 5.00 16 1 1129 16 5.00 28- 2 1229 28 5.00 43 4 1327 44 5.00 62 5 1426 63 5.00 85 7 1523 85 5.00 111 10 1620 111 5.00 140 12 1715 140 5.00 172 15 1810 173 5.00 208 18 1903 209 5.00 247 22 1995 248 5.00 258 23 2020 259 5.00 299 26 2111 300 5.00 341 30 2202 342 5.00 382 33 2293 384 5.00 424 37 2384 425 5.00 465 41 2475 467 5.00 506 44 2566 508 5.00 548 48 2657 550 5.00 589 52 2748 591 5.00 630 55 2839 633 5.00 672 59 2930 674 5.00 713 62 3021 716 5.00 755 66 3112 757 5.00 796 70 3203 799 5.00 837 73 3294 841 5.00 879 77 3385 882 5.00 920 81 3476 924 5.00 962 84 3567 965 5.00 1003 88 3658 1007 5.00 1044 91 3748 1048 5.00 1086 95 3839 1090 5.00 1127 99 3930 1131 5.00 1168 102 4021 1173 5.00 1210 106 4112 1214 5.00 1251 109 4203 1256 5.00 1293 113 4294 1298 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 2 7 16 28 44 63 85 111 140 173 209 248 259 3OO 342 384 425 467 508 55O 591 633 674 716 757 799 841 882 924 965 1007 1048 1090 1131 1173 1214 1256 1298 0.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 Sta. Num. 49 5O 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 M.D. Feet 4657 4757 4857 4957 5057 5157 5257 5357 5457 5557 5657 5757 5857 5957 6057 6157 6257 6357 6457 6557 6657 6757 6857 6957 7057 7157 7257 7357 7457 7557 7657 7757 7857 7957 8O57 8157 8257 8357 8457 8557 8657 8757 8857 8957 9057 9157 9257 9357 9457 9557 Incl. Angle Deg. 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 24.55 Azi. Angle Deg. 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.O0 5.00 5.00 5.00 5.00 5.00 5.O0 5.00 5.00 5.O0 5.O0 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.O0 5.00 5.00 5.00 5.00 5.00 DEC 1 3 199 Oil & Gas Cons. Commission Anchorage WELLPATH DATA Sunfish No. 3 Coordinates +N,-S +E,-W TVD Feet Feet Feet Vert. Sec. Feet 1334 117 4385 1339 1375 120 4476 1381 1417 124 4567 1422 1458 128 4658 1464 1500 131 4749 1505 1541 135 4840 1547 1582 138 4931 1588 1624 142 5022 1630 1665 146 5113 1672 1707 149 5204 1713 1748 153 5295 1755 1789 157 5386 1796 1831 160 5477 1838 1872 164 5568 1879 1913 167 5659 1921 1955 171 5750 1962 1996 175 -5841 2004 2038 178 5932 2045 2079 182 6023 2087 2120 186 6113 2129 2162 189 6204 2170 2203 193 6295 2212 2245 196 6386 2253 2286 200 6477 2295 2327 204 6568 2336 2369 207 6659 2378 2410 211 6750 2419 2452 214 6841 2461 2493 218 6932 2502 2534 222 7023 2544 2576 225 7114 2586 2617 229 7205 2627 2658 233 7296 2669 2700 236 7387 2710 2741 240 7478 2752 2783 243 7569 2793 2824 247 7660 2835 2865 251 7751 2876 2907 254 7842 2918 2948 258 7933 2959 2990 262 8024 3001 3031 265 8115 3043 3072 269 8206 3084 3114 272 8297 3126 3155 276 8387 3167 3196 280 8478 3209 3238 283 8569 3250 3279 287 8660 3292 3321 291 8751 3333 3362 294 8842 3375 Closure Dist. Dire. Feet Deg. 1339 5.0 1381 5.0 1422 5.0 1464 5.0 1505 5.0 1547 5.0 1588 5.0 1630 5.0 1672 5.0 1713 5.0 1755 5.0 1796 5.0 1838 5.0 1879 5.0 1921 5.0 1962 5.0 2004 5.0 2045 5.0 2087 5.0 2129 5.0 2170 5.0 2212 5.0 2253 5.0 2295 5.0 2336 5.0 2378 5.0 2419 5.0 2461 5.0 2502 5.0 2544 5.0 2586 5.0 2627 5.0 2669 5.0 2710 5.0 2752 5.0 2793 5.0 2835 5.0 2876 5.0 2918 5.0 2959 5.0 3001 5.0 3043 5.0 3084 5.0 3126 5.0 3167 5.0 3209 5.0 3250 5.0 3292 5.0 3333 5.0 3375 5.0 Sta. Num. 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131. 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 Incl. M.D. Angle Feet Deg. I r_ glV gu DEC 1 3 1993 ~t~skaOii&Gas~ns.~mmi~ion An~or~e Azi. Coordinates Angle +N,-S +E,-W Deg. Feet Feet 9657 24.55 9757 24.55 9857 24.55 9957 24.55 10057 24.55 10157 24.55 10257 24.55 10357 24.55 10457 24.55 10557 24.55 10657 24.55 10757 24.55 10857 24.55 10957 24.55 11057 24.55 11157 24.55 11257 24.55 11357 24.55 11457 24.55 11557 24.55 11657 24.55 11757 24.55 11857 24.55 11957 24.55 12057 24.55 12157 24.55 12257 24.55 12357 24.55 12457 24.55 12557 24.55 12657 24.55 12757 24.55 12857 24.55 12957 24.55 13057 24.55 13157 24.55 13257 24.55 13357 24.55 13457 24.55 13557 24.55 13657 24.55 13757 24.55 13857 24.55 13957 24.55 13999 24.55 BOB, BUR 0, TFO 0, 14099 24.55 5. 14199 24.55 5. 14299 24.54 5. 14399 24.54 5. 5.00 3403 298 5.00 3445 301 5.00 3486 305 5.00 3528 309 5.00 3569 312 5.00 3610 316 5.00 3652 319 5.00 3693 323 5.00 3735 327 5.00 3776 330 5.00 3817 334 5.00 3859 338 5.00 3900 341 5.00 3941 345 5.00 3983 348 5.00 4024 352 5.00 4066 356 5.00 4107 359 5.00 4148 363 5.00 4190 367 5.00 4231 370 5.00 4273 374 5.00 4314 377 5.00 4355 381 5.00 4397 385 5.00 4438 388 5.00 4480 392 5.00 4521 396 5.00 4562 399 5.00 4604 403 5.00 4645 406 5.00 4686 410 5.00 4728 414 5.00 4769 417 5.00 4811 421 5.00 4852 424 5.00 4893 428 5.00 4935 432 5.00 4976 435 5.00 5018 439 5.00 5059 443 5.00 5100 446 5.00 5142 450 5.00 5183 453 5.O0 5200 455 WALK 0 00 5242 459 00 5283 462 00 5324 466 00 5366 469 WELLPATH DATA Sunfish No. 3 TVD Feet Vert Sec. Feet Closure Dist. Dire. Feet Deg. 8933 3416 3416 5.0 9024 3458 3458 5.0 9115 3500 3500 5.0 9206 3541 3541 5.0 9297 3583 3583 5.0 9388 3624 3624 5.0 9479 3666 3666 5.0 9570 3707 3707 5.0 9661 3749 3749 5.0 9752 3790 3790 5.0 9843 3832 3832 5.0 9934 3873 3873 5.0 10025 3915 3915 5.0 10116 3957 3957 5.0 10207 3998 3998 5.0 10298 4040 4040 5.0 10389 4081 4081 5.0 10480 4123 4123 5.0 10571 4164 4164 5.0 10662 4206 4206 5.0 10752 4247 4247 5.0 10843 4289 4289 5.0 10934 4330 4330 5.0 11025 4372 4372 5.0 11116 4414 4414 5.0 11207 4455 4455 5.0 11298 4497 4497 5.0 11389 4538 4538 5.0 11480 4580 4580 5.0 11571 4621 4621 5.0 11662 4663 4663 5.0 11753 4704 4704 5.0 11844 4746 4746 5.0 11935 4787 4787 5.0 12026 4829 4829 5.0 12117 4871 4871 5.0 12208 4912 4912 5.0 12299 4954 4954 5.0 12390 4995 4995 5.0 12481 5037 5037 5.0 12572 5078 5078 5.0 12663 5120 5120 5.0 12754 5161 5161 5.0 12845 5203 5203 5.0 12882 5220 5220 5.0 12973 5262 5262 5.0 13064 5303 5303 5.0 13155 5345 5345 5.0 13246 5386 5386 5.0 Sta Num 148 149 150 151 152 153 154 155 156 157 M.D. Feet 14499 14599 14699 14799 14899 14999 15099 15199 15299 TD 15399 Incl. Angle Deg. Azi. Angle Deg. Coordinates +N,-S +E,-W Feet Feet 24.54 5.00 5407 473 24.54 5.00 5449 477 24.54 5.00 5490 480 24.54 5.00 5531 484 24.54 5.00 5573 488 24.54 5.00 5614 491 24.53 5.00 5655 495 24.53 5.00 5697 498 24.53 5.00 5738 502 24.53 5.00 5780 506 WELLPATH DATA Sunfish No. 3 Vert TVD Sec. Feet Feet 13337 5428 13428 5469 13519 5511 13610 5552 13701 5594 13792 5636 13883 5677 13974 5719 14065 5760 14156 5802 Closure Dist. Dire. Feet Deg. 5428 5.0 5469 5.0 5511 5.0 5552 5.0 5594 5.0 5636 5.0 5677 5.0 5719 5.0 5760 5.0 5802 5.0 R C IVED DEC Alaska Oil & l~as Cons. Commission Anchorage PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 EXPLORATION AND PRODUCTION GROUP COMPANY December 3, 1993 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Alaska Oil and Gas Conservation Commi~ion 3001 Porcupine Drive Anchorage Alaska 99501 Attn: Bob Crandall In accordance with 20.AAC 25.015 (b) (1), attached are three copies of a revised Application for Permit to Drill (APD), form 10-401, to change the planned bottom hole location for the Suntr~sh No. 3 being drilled from Phillips Platform A (Tyonek) in the North Cook Inlet Unit. The location was changed based on the results of the Sunfish No. 2 and the newly acquired seismic data. A revised planned wellpath is attached. The well is planned to be drilled to a depth of 14150' TVD, 15300' TVD. The change in depth has changed the setting depth and cement volume for the 7" liner. The other casing strings to be set were not affected by the change in location or depth. Other items, including the drilling fluid program and BOP system, remain unchanged from the APD submitted in May 13, 1993. If you have any questions regarding this, please contact Dennis Morgan at (713) 669-2173. D. C. Gill ,,-" ~J Drilling and Pr~n Engineering Manager CC.' A. R. Lyons (r) W. L. Carrico M. L. Jones (r) D. R. Morgan J. F. Mitchell Gas Cons. commission Anchorage MEMORAND,,., State ._ Alaska Alaska Oil and Gas Conservation Commission David Johns _~3~L-''~', DATE: TO: Chairma~ THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: Doug Amos, 'P~-,.*5 ~ SUBJECT: Petroleum Inspector November 29, 1993 ax8hk2ad.doc BOPE Test Pool 429 Phillips Sunfish #3 Exploratory PTD No. 93-76 Saturday November 27, 1993: I traveled this date to Kenai and on to Phillips NCI Tyonek Platform Sunfish No. 3 Exploratory Well, to witness the BOPE test on Pool Rig 429. I arrived on the platform at 9:30 a.m.. The stack was still being nippled up at this time and I was informed that a wellbore survey would be performed before the BOPE test would be conducted. There were problems with the survey tools and the test was delayed further. Sunday November 28,1993: The testing commenced at 2:30 a.m. and was concluded at 10:00 a.m. As the attached AOGCC BOPE Test Report indicates, there were three flange leaks. After hammering the Mud Cross Flanges up four times and the Choke Line twice, the leaks were corrected. Other than the leaks, I found the Rig in good condition and all crew personnel knowledgeable about their equipment and our test procedures. _. Summary: I witnessed the BOPE test at Phillips Sunfish No. 3 Exploratory Well on Pool Arctic Rig 429, aboard the Tyonek Platform, 8 hour test time, 2 failures, 26 valves tested. . Attachment AX8HK2AD.XLS £ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Alaska Rig No. Operator: Phillips Tyonek NCI Platform Well Name: Sunfish No. 3 Casing Size: 20" Set @ 2,602 Ft. Test: Initial X Weekly Other 429 PTD # Rep.: Rig Rep.: Location' Sec. DATE: 11/28/93 93-76 Rig Ph.# 776-6073 / 6074 Ken May Darrell Greene 6 T. 11N. R. ,g W. Meridian Seward MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Test Pressure P/F 300/1,400 P 1 300 / 3, 000 P 0 N/A I 300/3,000 P I 300 / 3, 000 P 2 300/3,000 P/P I 300/3,000 P 0 N/A FLOOR SAFETY VALVES: Upper Kelly ! IBOP Lower Kelly / IBOP Ball Type Inside BOP CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure MUD SYSTEM' Visual Alarm Tdp Tank OK OK~ Pit Level Indicators OK ~ Flow Indicator OK OK Gas Detectors OK OK Test Quan. Pressure P/F 1 300/3,000 P I 300 / 3, 000 P 1 300 / 3, 000 P 1 300/3,000 P Test Pressure 17 300/3,000 48 300/3,000 300 / 3, 000 300/3,000 3,000 ] P 1,400 P P/F P P Pressure After Closure 200 psi Attained After Closure 0 minutes 27 sec. System Pressure Attained 2 minutes 49 sec. Blind Switch Covers: Master: Yes Remote: Yes Nitgn. Btl's: 6 ~ 1,900 Psig. NUmber Of'Fa'iiures: 2 ,Test Time: $.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within N/A 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: The Stack Choke Line Flange and the Upper and Lower Mud Cross Flanges Leaked. Ail Flange Leaks were repaired and retested during the course of this test. Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/93) STATE WITNESS REQUIRED? YES Yes NO 24 HOUR NOTICE GIVEN YES Yes NO Waived By: Witnessed By: AX8HK2AD.XLS Doug Amos STATE OF ALASKA ALAb~,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS / I / /.~'/,~ i 1. Typeof Request: Abandon__ Suspend__ Operafion shutdown __ Re-enter suspended well __ Alter cas n Repair well Plugging Time ex'tens,on Stimulate Change approved program ~ Pull tubing __ Vanance __ Pedorate __ Other __ 5. Type of Well: 6. Datum elevation (DF or KB) Development __ 13 2 feet 2. Name of Operator Phillips Petroleum Company Exploratory .,37__ 3. Address p. O. Box 1967 Houston. Texa.~ 77251-1967 4. Location of well atsudace Platform A leg 1 Se,¢ 6 - Ti1N-R9W At top of productive interval 3150' FSL, At effective depth 12043 ' ND, Attotal depth 4530' FSL, 14150' TVD, Stratigraphic __ Service __ Slot 6 1249' FNL 980' FWL 1360' FWL Sec 31-T12N-R9W @ 11000' TVD 1486' FWL, Sec 31-T12N-R9W @ 15400' MD (KB) Z UnitorPropedyname North Cook Inlet 8. Wellnumber Sunfish No. 3 93-76 9. Permit number 10. APl number 50-- 883-20090 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet 11. Field/Pool Exploratory Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural 350 Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured depth True vertical depth 30" Driven 407 407 l',~OV 2 2 ~303 Gas Cons. Commission Anchorago 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation November 17, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby certify ~,at the foregoing is true and correct to the best of my knowledge. ,/~/~ Title?~_~,-/.'.-,~,'"'~6' 'S~ ~ '' Signed ,~,¢¢?, .... /¢2-~'¢t¢,~'~/',;,'R~, /;"-4-~',,~- Date //,//~/~.¢ FOR OOMM~SION U ONLY ' Conditions of approval: Notify Commission so representative may witness IApprOval N°4~'.~,~".- ,~,~'.,'2 ~ /,- Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Based on the evaluation of the Sunfish No. 2 and the newly acquired seismic data, the bottomhole location will be moved approximately 2200' to the west of the previously planned location and deepened to 14150' TVD. The revised bottomhole location is 4530' FSL, 1486' FWL, section 31-T12N-R9W. A revised planned wellpath is attached. The only change to the planned casing program resulting from this revision will be to set the 7" production liner at the deeper TD of 14150' TVD, 15400' MD. The other casing points are not affected by this change. gas Gons. commission Anchorage Sta. Num. 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 3B 39 40 41 42 43 44 45 46 47 48 Incl. M.D. Angle Feet Deg. 0 0.00 100 0.00 200 0.00 300 0.00 400 0.00 500 0.00 600 0.00 7OO 0.00 800 0.00 KOP, BUR 2 830 0.00 930 2.00 1030 4.00 1130 6.00 1230 8.00 1330 10.00 1430 12.00 1530 14.00 1630 16.00 1730 18.00 1830 20.00 1930 22.00 2030 24.00 EOB, ANG 24.5 2057 24.55 2157 24.55 2257 24.55 2357 24.55 2457 24.55 2557 24.55 2657 24.55 2757 24.55 2857 24.55 2957 24.55 3057 24.55 3157 24.55 3257 24.55 3357 24.55 3457 24.55 3557 24.55 3657 24.55 3757 24.55 3857 24.55 3957 24.55 4057 24.55 4157 24.55 4257 24.55 4357 24.55 4457 24.55 4557 24.55 K LI IVl:U NOV 2 2 Oil & Qas Cons. Anchorage Azi. Coordinates Angle +N,-S +E,-W Deg. Feet Feet 0.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 0 0 5.00 2 0 5.00 7 1 5.00 16 1 5.00 28 2 5.00 43 4 5.00 62 5 5.00 85 7 5.00 111 10 5.00 140 12 5.00 172 15 5.00 208 18 5.00 247 22 5.00 258 23 5.00 299 26 5.00 341 30 5.00 382 33 5.00 424 37 5.00 465 41 5.00 506 44 5.00 548 48 5.00 589 52 5.00 630 55 5.00 672 59 5.00 713 62 5.00 755 66 5.00 796 70 5.00 837 73 5.00 879 77 5.00 920 81 5.00 962 84 5.00 1003 88 5.00 1044 91 5.00 1086 95 5.00 1127 99 5.00 1168 102 5.00 1210 106 5.00 1251 109 5.00 1293 113 WELLPATH DATA Sunfish No. 3 TVD Feet Vert. Sec. Feet 0 100 200 3O0 400 5OO 6O0 700 8OO 0 0 0 0 0 0 0 0 0 830 930 1030 1129 1229 1327 1426 1523 1620 1715 1810 1903 1995 0 2 7 16 28 44 63 85 111 140 173 209 248 2020 2111 2202 2293 2384 2475 2566 2657 2748 2839 2930 3021 3112 3203 3294 3385 3476 3567 3658 3748 3839 3930 4021 4112 4203 4294 259 3OO 342 384 425 467 5O8 55O 591 633 674 716 757 799 841 882 924 965 1007 1048 1090 1131 1173 1214 1256 1298 Closure Dist. Dire. Feet Deg. 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 2 7 16 28 44 63 85 111 140 173 209 248 259 3OO 342 384 425 467 5O8 550 591 633 674 716 757 799 841 882 924 965 1007 1048 1090 1131 1173 1214 1256 1298 0.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 Sta. Num. 49 5O 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 8O 81 82 83 84 85 86 87 88 89 9O 91 92 93 94 95 96 97 98 MoD. Feet 4657 4757 4857 4957 5057 5157 5257 5357 5457 5557 5657 5757 5857 5957 6057 6157 6257 6357 6457 6557 6657 6757 6857 6957 7057 7157 7257 7357 7457 7557 7657 7757 7857 7957 8057 8157 8257 8357 8457 8557 8657 8757 8857 8957 9057 9157 9257 9357 9457 9557 Incl. Angle Deg. f OV 2 2 Anchorage Azi. Coordinates Angle +N, -S +E, -W Deg. Feet Feet WELLPATH DATA Sunfish No. 3 TVD Feet Vert. Sec. Feet Closure Dist. Dire. Feet Deg. 24.55 5.00 1334 117 4385 1339 1339 5.0 24.55 5.00 1375 120 4476 1381 1381 5.0 24.55 5.00 1417 124 4567 1422 1422 5.0 24.55 5.00 1458 128 4658 1464 1464 5.0 24.55 5.00 1500 131 4749 1505 1505 5.0 24.55 5.00 1541 135 4840 1547 1547 5.0 24.55 5.00 1582 138 4931 1588 1588 5.0 24.55 5.00 1624 142 5022 1630 1630 5.0 24.55 5.00 1665 146 5113 1672 1672 5.0 24.55 5.00 1707 149 5204 1713 1713 5.0 24.55 5.00 1748 153 5295 1755 1755 5.0 24.55 5.00 1789 157 5386 1796 1796 5.0 24.55 5.00 1831 160 5477 1838 1838 5.0 24.55 5.00 1872 164 5568 1879 1879 5.0 24.55 5.00 1913 167 5659 1921 1921 5.0 24.55 5.00 1955 171 5750 1962 1962 5.0 24.55 5.00 1996 175 5841 2004 2004 5.0 24.55 5.00 2038 178 5932 2045 2045 5.0 24.55 5.00 2079 182 6023 2087 2087 5.0 24.55 5.00 2120 186 6113 2129 2129 5.0 24.55 5.00 2162 189 6204 2170 2170 5.0 24.55 5.00 2203 193 6295 2212 2212 5.0 24.55 5.00 2245 196 6386 2253 2253 5.0 24.55 5.00 2286 200 6477 2295 2295 5.0 24.55 5.00 2327 204 6568 2336 2336 5.0 24.55 5.00 2369 207 6659 2378 2378 5.0 24.55 5.00 2410 211 6750 2419 2419 5.0 24.55 5.00 2452 214 6841 2461 2461 5.0 24.55 5.00 2493 218 6932 2502 2502 5.0 24.55 5.00 2534 222 7023 2544 2544 5.0 24.55 5.00 2576 225 7114 2586 2586 5.0 24.55 5.00 2617 229 7205 2627 2627 5.0 24.55 5.00 2658 233 7296 2669 2669 5.0 24.55 5.00 2700 236 7387 2710 2710 5.0 24.55 5.00 2741 240 7478 2752 2752 5.0 24.55 5.00 2783 243 7569 2793 2793 5.0 24.55 5.00 2824 247 7660 2835 2835 5.0 24.55 5.00 2865 251 7751 2876 2876 5.0 24.55 5.00 2907 254 7842 2918 2918 5.0 24.55 5.00 2948 258 7933 2959 2959 5.0 24.55 5.00 2990 262 8024 3001 3001 5.0 24.55 5.00 3031 265 8115 3043 3043 5.0 24.55 5.00 3072 269 8206 3084 3084 5.0 24.55 5.00 3114 272 8297 3126 3126 5.0 24.55 5.00 3155 276 8387 3167 3167 5.0 24.55 5.00 3196 280 8478 3209 3209 5.0 24.55 5.00 3238 283 8569 3250 3250 5.0 24.55 5.00 3279 287 8660 3292 3292 5.0 24.55 5.00 3321 291 8751 3333 3333 5.0 24.55 5.00 3362 294 8842 3375 3375 5.0 Sta. Num. 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 Incl. M.D. Angle Feet Deg. 9657 24.55 9757 24.55 9857 24.55 9957 24.55 10057 24.55 10157 24.55 10257 24.55 10357 24.55 10457 24.55 10557 24.55 10657 24.55 10757 24.55 10857 24.55 10957 24.55 11057 24.55 11157 24.55 11257 24.55 11357 24.55 11457 24.55 11557 24.55 11657 24.55 11757 24.55 11857 24.55 11957 24.55 12057 24.55 12157 24.55 12257 24.55 12357 24.55 12457 24.55 12557 24.55 12657 24.55 12757 24.55 12857 24.55 12957 24.55 13057 24.55 13157 24.55 13257 24.55 13357 24.55 13457 24.55 13557 24.55 13657 24.55 13757 24.55 13857 24.55 13957 24.55 13999 24.55 _..REC£1VED NOV 22 ~ WEULPATH DATA ~!~t~O[i&GasCon$.Oommission Sunfish No. 3 Azi. Anchorage Coordinates Vert. Angle +N,-S +E,-W TVD Sec. Deg. Feet Feet Feet Feet 5.00 3403 298 8933 3416 5.00 3445 301 9024 3458 5.00 3486 305 9115 3500 5.00 3528 309 9206 3541 5.00 3569 312 9297 3583 5.00 3610 316 9388 3624 5.00 3652 319 9479 3666 5.00 3693 323 9570 3707 5.00 3735 327 9661 3749 5.00 3776 330 9752 3790 5.00 3817 334 9843 3832 5.00 3859 338 9934 3873 5.00 3900 341 10025 3915 5.00 3941 345 10116 3957 5.00 3983 348 10207 3998 5.00 4024 352 10298 4040 5.00 4066 356 10389 4081 5.00 4107 359 10480 4123 5.00 4148 363 10571 4164 5.00 4190 367 10662 4206 5.00 4231 370 10752 4247 5.00 4273 374 10843 4289 5.00 4314 377 10934 4330 5.00 4355 381 11025 4372 5.00 4397 385 11116 4414 5.00 4438 388 11207 4455 5.00 4480 392 11298 4497 5.00 4521 396 11389 4538 5.00 4562 399 11480 4580 5.00 4604 403 11571 4621 5.00 4645 406 11662 4663 5.00 4686 410 11753 4704 5.00 4728 414 11844 4746 5.00 4769 417 11935 4787 5.00 4811 421 12026 4829 5.00 4852 424 12117 4871 5.00 4893 428 12208 4912 5.00 4935 432 12299 4954 5.00 4976 435 12390 4995 5.00 5018 439 12481 5037 5.00 5059 443 12572 5078 5.00 5100 446 12663 5120 5.00 5142 450 12754 5161 5.00 5183 453 12845 5203 5.00 5200 455 12882 5220 BOB, BUR 0, TFO 0, WALK 0 144 14099 24.55 5.00 145 14199 24.55 5.00 146 14299 24.54 5.00 147 14399 24.54 5.00 5242 459 12973 5262 5283 462 13064 5303 5324 466 13155 5345 5366 469 13246 5386 Closure Dist. Dire. Feet Deg. 3416 5.0 3458 5.0 3500 5.0 3541 5.0 3583 5.0 3624 5.0 3666 5.0 3707 5.0 3749 5.0 3790 5.0 3832 5.0 3873 5.0 3915 5.0 3957 5.0 3998 5.0 4040 5.0 4081 5.0 4123 5.0 4164 5.0 4206 5.0 4247 5.0 4289 5.0 4330 5.0 4372 5.0 4414 5.0 4455 5.0 4497 5.0 4538 5.0 458O 5.O 4621 5.0 4663 5.0 4704 5.0 4746 5.0 4787 5.0 4829 5.0 4871 5.0 4912 5.0 4954 5.0 4995 5.0 5037 5.0 5078 5.0 5120 5.0 5161 5.0 5203 5.0 5220 5.0 5262 5.0 5303 5.0 5345 5.0 5386 5.0 Sta. Num. 148 149 150 151 152 153 154 155 156 157 M.D. Feet 14499 14599 14699 14799 14899 14999 15099 15199 15299 TD 15399 Incl. Angle Deg. Azi. Angle Deg. Coordinates +N,-S +E,-W Feet Feet 24.54 5.00 5407 473 24.54 5.00 5449 477 24.54 5.00 5490 480 24.54 5.00 5531 484 24.54 5.00 5573 488 24.54 5.00 5614 491 24.53 5.00 5655 495 24.53 5.00 5697 498 24.53 5.00 5738 502 24.53 5.00 5780 506 WELLPATH DATA Sunfish No. 3 Vert TVD Sec. Feet Feet 13337 5428 13428 5469 13519 5511 13610 5552 13701 5594 13792 5636 13883 5677 13974 5719 14065 5760 14156 5802 Closure Dist. Dire. Feet Deg. 5428 5.0 5469 5.0 5511 5.0 5552 5.0 5594 5.0 5636 5.0 5677 5.0 5719 5.0 5760 5.0 5802 5.0 R[CEIVED Oil & ~as Oons, ~ . · Co/nmlsslon .Anchorage MEMOR INDUM .. S TA TE O. .4 L4 OIL AND G~S CONSER FA TION COMMISSION TO: David Joh~ Chairman"'"-- DA TE: November 11,1993 FILE NO: E98JKSAD.DOC THRU: Blair Wondzell t,I ~l~'-~ P.I. Supervisor 0~ FROM: ~o~u Grimaldi Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: Dived. er Test Pool # 429 Phillips petroleum Sunfish #3 Sunfish prospect PTD # 93-76 Thursday November 19, 1993 I witnessed the Diverter test on Pool rig # 429, drilling Phillips exploratory well Sunfish #3 in North Cook Inlet. The rig was prepared to test when I arrived. The Dived. er assembly consisted of a thirty inch Hydril MSP Annular preventer, three 10 inch Knife valves on the vent lines which extended approximately 10 feet past the edge of the platform. The Dived. valves were plumbed in a fashion that the single valve on the North east line is connected (in reverse operation) of the outboard valve on the southwest line with the North east valve closed and the South west open. The annular preventer is connected to the inboard valve on the southwest line and this valve opens when the Diverter is operated. Alternate direction is accomplished by closing the outboard valve on the Southwest line which automatically opens the single valve on the Northeast line effectively changing direction of discharge. When actuated,the inboard vent valve on the Southwest line opened immediately ( the outboard valve was already open) the annular preventer closed within forty seconds. This is a good time for this size and type preventer. Ken May ( Phillips Rep. ) achieved this by routing two closing hydraulic lines to the preventer. The alternate vent was actuated and operated properly. Summary; I witnessed the Dived.er test on Pool rig # 429. All functions appeared to be in compliance. Attachment: E98JKSAD.XLS STATE OF ALASKA -~ ALASKA G,.-AND GAS CONSERVATION COU ..... $SION Diverter Systems Inspection Report Date: 11/19/93 Operation' Development Exploratory: X Drlg Contractor: Pool Arctic Rig No. 429 PTD # 93-76 Rig Ph. # 776-6074 Operator: Phillips Petroleum Oper. Rep.: Ken May Well Name: Sunfish #3 Rig Rep.: Gary Goerlich Location: Sec. 6 T. 11N R. 9W Merdian Seward MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3100 psig Housekeeping: OK (Gen.) Drlg. Rig: OK : Pressure After Closure: 1250 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: ~min' 32 sec. Systems Pressure Attained: 2 min. 50 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: Four Bottles Diverter Size: 30 in. 2500 Average psig Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 10 in. Trip Tank: X X Vent Line(s) Length: 103'& 31' ft. Mud Pits: X X Line(s) Bifurcated: No Flow Monitor: X X Line(s) Down Wind: Yes Line(s) Anchored: Yes GAS DETECTORS: Light Alarm Turns Targeted / Long Radius: N/A Methane X X Hydrogen Sulfide: X X .............. DIVERTER~ SCHEMATIC:..: ~.: :. ~:: ~ ..... ........ : :.:..~ Tie downs ~ Tie , "~ 103' 20' ~ 11'-~ Non Compliance Items None Repair Items Within Day (s) And contact the Inspector @ 659-3607 Remarks: Good setup, System function time forty seconds DislributJon orig. - Well File c- Oper/Rep c - Dalabase c -F~.~ [al~i~. 7/93 c - Inspector AOGCC REP.: E98JKSAD.XLS OPERATOR REP.: Louis R Grimaldi Ken May ALAS OIL AND GAS CONSERVATION COMIVii$$10N TO: Dave Johnsto~ Commissioner THRU: Blair Wondzell ~!~..~i~1~ P.I. Supervisor FROM: Lou Grimaldi P.I. DATE: 6-16-93 , FILENAME: iuzg6paa.doc SUBJECT: Pre Spud rig~bope inspection Rowan jackup Gilbert Roe (~ Rig tenders dock Nikiski WEDNESDAY 6-16-93 I made at the request of Arco company rep. Charley Dickson a pre spud rig inspection of the Gilbert Roe, which will be used at the,~unfish discovery this summer. I was accompanied on this inspection by Commissioner Babcock and P.I. Doug Amos. The rig is parked alongside the other jackup rig "Adriatic Eight" at the Rig tenders dock which we had to cross to gain access to the Gilbert Roe. £ This Rig is somewhat similar to the Adriatic Eight in that they are both built on the same type platform and the drilling equipment (although different types) is in approximately similar locations. I found the rig to be in excellent shape with evidence of a regular and on going maintenance program. There was one area that required some attention, this being the choke manifold. I noticed that there was just one discharge path, this leading to the gas buster. Although normally during well control all returns from the annulus would be put through the gas buster a alternate path should be available in case the gas buster plugs or high volumes are needed to achieve proper circulation. After discussing this with the Toolpusher and G.W. Craig (Arco rep) I was assured that this would be addressed before they spudded. All other equipment I observed was in very good shape and of sound design. I feel that this prespud inspection is good procedure and should possibly be a requirement before a new rig can start working in Alaska. SUMMARY; I made a prespud Rig\Bope inspection on the jackup rig Gilbed Roe at Rig tenders dock in Nikiski. 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 June 4,1993 D C Gill, Drlg & Prod Eng Mgr Phillips Petroleum Co 6330WLoop South Bellaire, TX 77401 Re: Well # Company Permit # Surf Loc Btmhole Loc Sunfish No. 3 Phillips Petroleum Company 93-76 1249'FNL, 980'FWL, Sec 6, T11N, R9W, SM 4150'FSL, 1550'FEL, Sec 31, T12N, R9W, SM Dear Mr Gill: Enclosed is the approved application for permit to drill the above referenced well. Your application for a variance to the setting depth of casing required b~' 20 AAC 25.030(c)(2) to allow setting 20-inch casing as deep as 2500 feet TVD is hereby approved. For this well Phillips is also exempted from the requirements of 20 AAC 25.065 relating to hydrogen sulfide unless hydrogen sulfide is detected dudng drilling operations. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the Nodh Slope pager at 659-3607. Yours very truly, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl Memorandum State of Alaska Oil and Gas £'.onser-~mfion C. onnnissicm To: Conmfission June 3, 1993 Fro: Staff Subj: Variance Requests- Phillips Sunfish No. 3 The Phillips request for exception to 20 ACC 25.030 (c)'2 is predicated on experience while drilling Sunfish 1, No~lh Foreland St. No. 1 and 12 development wells fi'om the Tyonek Platform. Drilling information fi'om the above referenced wells confnmed shallow hazards surveys which also showed no shallow gas or other hazards prior to drilling. Based on lack of sha'flow hazards, the staff recommends al~proval of the variance to casing setting requkements of 20 AAC 25.030 c(2), and support setting 20 :' to 2500' TVD in Sunfish No. 3. The variance to H2S requh'ements, 20 AAC 25.065, is reasonable in that there has been no e~,idence of H2S in the Sunfish 1 and North Foreland St. I wells. Phillips indicated that there will be monitoring equipment on board and in use to detect H2S and measures would be enacted flit is detected wtfiie drilling. · i PHILLIPS PETROLEUM COMPANY ,/O P, O, Box 1976 Houston, Texas 77251-1957 lPhone # Anchorage, Alaska 99501 6330 West Loop South Bellalre, Texas 77401 June 1, 199;3 Sunfish No. 3 Attn: Mike Minder AS per your request, attached are several pages from Phillips Casing and Tubing design manual. These pages show the burst, ~ollapse, and tension ratinge used in the applloation for permit to dr;Il the Gunfish No, 3, The di~repenoles in the burst ratings are due to ;onsidemtlon of APl leak resistance. As the attached shows, Phillips does not derate the pipe for leak re;Istanoe of the couplings, The design as proposed is adequate to meet the well requirements even if the pipe were to be derated for leak reslstanoe. The maximum potential surface pressure shown in the permit is based on 50% of ~he drilling mud being replaced by gas. This is a conservative approaoh in that the influx volume required for this to occur Is much larger than would be po~ible, even if the drillers were not paying affention. This woutd require an Influx volume of at least 500 barrels while drilling below the 13 3/8" caslng ~ 300 barrels while drilling below the 9 5/8" casing. Alarms are set on the pits to alert the driller of mu~h smaller gains than this. AlSo Included are pages outlining Phillips philosopy for thief zone, i.e. how far the fluld level could fall should oimulatlon be IosL The fracture gradients in the Cook Inlet are higher than was used in developing the Correlations found in Phillips design manual. This results in our design being somewhat more conservative for oollapse $ln~e the fluid would not be expected to fall a~, far as the 0orrelation$ would predi~, If you have additional question eoncerning the easing design or other aspects of the perm;t application for the Sunfish No, 3, please call me at (907) 778-6049 or (713) 669-2173 Regards, Dennis Morgan Gr. Drilling Engineering Spe~lalist RECEIVED JUN 0 1 199q Alaska Oil & Gas Cof~s. Anchorage PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION May 26, 1993 COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING State of Alaska Oil and Gas Conservation Commission Attn' Mr. Bob Crandall 3001 Porcupine Drive Anchorage, AK 99501 Application For Permit to Drill Sunfish Well No. 3 North Cook Inlet, Alaska Dear Mr. Crandall: Reference is made to our conversation of this date regarding the status of the Application for a Permit to Drill the Sunfish Well No. 3 to be drilled from the Phillips Tyonek Platform. At any time, operational difficulties may require the temporary shut down of drilling operations on the Sunfish Well No. 2 at which time Phillips, in order to avoid substantial rig stand-by charges, would wish to drill the Sunfish Well No. 3. Therefore, Phillips Petroleum Company requests that the Alaska Oil and Gas Conservation Commission proceed as quickly as possible with the approval of this Permit to Drill. If you have any questions on this matter, please contact the undersigned at (713) 669-3729. Very truly yours, CC: ARCO Alaska, Inc. Attn' J. M. Gregory P. O. Box 100360 Anchorage, AK 99510-0360 Phillips Petroleum Company Brett A. Butte'rfield General Landman PHILLIPS PETROLEUM COMPANY P. O. Box 1976 Houston, Texas 77251-1967 6330 West Loop South Bellalre, Texas 77401 May 21, 1993 Sunfish No. 3 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Bob Crandall The primary contact for periodic updates on the Sunfish No. 3 will be Dennis Morgan. Updates will be provided by telephone on a weekly basis. Should you require information concerning this well please contact Dennis at (713) 669-2173. Regards, D~Znnis Morgan~ Sr. Drilling Engineering Specialist PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY May 19, 1993 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING FAX AND OVERNIGHT MAIL Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. Bob Crandall FAX: (907) 276-7542 Application for Permit to Drill SurLfish Well No. 3 Surface Location: 1249'FNL 980'FWG Sec. 6-TllN-R9W, SM Bottomhole Location: 4150'FSL 1550'FEL Sec. 31-T12N-R9W, SM Upper Cook Inlet, Alaska Dear Mr. Crandall: Reference is made to the phone conversation of May 18, 1993 between Phillips Landman Brett A. Butterfield and yourself regarding the above captioned Permit Application. The Sunfish Well No. 3 will be drilled within the North Cook Inlet Unit, which is unitized as to all depths. The only working interest owners within the unit are ARCO Alaska, Inc. and Phillips Petroleum Company, both of which are participants in the subject well. On May 12, 1993 Notice of the Permit Application was sent to four parties in addition to ARCO, these parties being Royalty and Overriding Royalty Owners. Per the above referenced conversation these additional parties are not "Affected Parties" under the Alaska Administrative Code Title 20-Chapter 25, and should not have been sent the May 12, 1993 notice. As there are not Affected Owners which are not participating in the well Phillips Petroleum Company requests that the Alaska Oil and Gas Conservation Commission proceed with the review and approval process without the waiting period for "Affected Owners Notice". Application for Permit to Drill Sunfish Well No. 3 May 19, 1993 - page 2 If you have any questions on this matter please contact Mr. Brett A. Butterfield at (713)669-3729. Very truly yours, PHILLIPS PETROLEUM COMPANY D. C. Gill . ~_~.~r Drilling and Production Engineering Manager CC'. ARCO Alaska, Inc. Attn: J. M. Gregory Fax: (907) 263-4966 W. R. Gibson (r) D. Morgan J. E. Herndon (r) B. A. Butterfield A. R. Lyons (r) W. L. Carrico J. F. Mitchell DCG:BAB/lc: 0593.10 R£CEIVED /'tlaska Oil & Gas COns. Cornrnissior~ Anchorage May 12, 1993 PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 EXPLORATION AND PRODUCTION GROUP COMPANY BELLAIRE. TEXAS 6330 V",/EST LOOP SOUTH PHILLIPS BUILDING Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501 Attached are three copies of the Application for Permit to Drill (APD), form 10-401, for the Phillips-Arco Sunfish No. 3 to be drilled from Phillips Platform A (Tyonek) in the North Cook Inlet Unit. Phillips Petroleum will operate this well on behalf of itself and Arco Alaska, Inc. to further evaluate the Arco-Sunfish No. 1 discovery. Phillips will use Pool rig 429 to drill this well. This rig is currently working on the platform. As part of the application for permit to drill, Phillips Petroleum formally requests a variance to the setting depth of casing shown in 20. AAC 25.030(c)(2). It is requested that the maximum 1000' depth BML be extended to 2268' BML as shown on both the permit application and the wellbore diagram. This request is discussed in the attachments to the APD. We further request an exemption to the requirements in 20 AAC 25.065 relating to hydrogen sulfide. Hydrogen sulfide has not been encountered in any of the wells drilled on the North Cook Inlet Unit and is not expected in the Phillips - Arco Sunfish No.. 3. It is our intent to monitor for the presence of hydrogen sulfide while drilling the entire well. If hydrogen sulfide is detected, the commission will be notified and contingency equipment will be installed immediately. Attachments to the APD includes the information required under 20 AAC 25.005. This well will be a deviated well with its surface location on the Tyonek platform. Plats showing the planned wellpath are included in the attachments to the APD. A copy of the APD has been sent to the affected owners in accordance with 20 AAC 25.050(b)(2). AOGCC is requested to keep this application and the attachments confidential. If you have any questions or require additional information please contact Dennis Morgan at (713) 669-2173. CC: A. R. Lyons (r) W. L. Carrico W. R. Gibson (r) D. R. Morgan D. C. Gill Drilling and Production Engineering Manager ALASKA OIL AND GAS CONSERVATION COMMISSION -PERMIT TO DRILL 20 AAC 25.005 la. Type of wor~< iDr,ll ~.. Redrill F-J 1~ Type pt well. Exploratory (~ Slratigrapnm Test E] Develooment Oil ~ Re-Entry - DeepenC~ Service m~ Oevelooement Gas ~ Single Zone {~ Multiple Zone r--' . 2. Name of Operator 5. Datum Elevation (IDF or KB) 10. Field an(3 Pool Phillips Petroleum Company 132 feet 3. Address 6. Property Designation 6330 W.Loop South,Bellaire, TX 77401 APL 17589 Exploratory 4. Location of 'well at surface Platform A leg 1, 7. Umt or property Name 11. Type slot 6. 1249 FNL, 980 FWL Sec 6-TllN-R9W North Cook Inlet Statewide At top of productive interval 3650' FSL, 1800 8. Well hurdler Number FEL Sec 31-T12N-R9W @12280' TVD Sunfish No. 3 41-00-524 At total depth 4150 FSL, 1550 FEL Sec 31 9. Approximate spud date Amount T-12N-RgW @13350' TVD July 1, 1993 $200,000 12. Oistance to nearest 13. Distance to nearest well 14. Numoer of acres in property1 15. Proposed cleptni~o ~n,~ property line @Surface 8' Sunfish2 14800 MD 3730 feet @BHL 1690 NClU A-i~et 5002 13350 TVD teet '16. To oe completed for dewated wells 17. Anticipated pressure (,,, 2o.Ac ~.o3~ Kickoff cleotn 830 feet Maximum I~ole angle27 ' ...,,,,,,,. ,u,,,:, 3351 ,,,, A, ,o,,, ,~.,,. rrvm13350 feet 18. Casing program Settinc. I Oepm s~ze Sl3ecifications Top Bottom Quantity of cement Hole J Cas,ng We,gntjGrade{Cou~lingjl~ngtn MO TVD MD ,-VD (include stage data~ Drlven J 30" 1457 I B !W,e~l 350 ' 55 5,5 407 407 N/A 24 20" 169 ~-55 /(' '0 .. 2,500 C~ -[2545 55 55 2600 ~ead 2000sx tail 650s~ 17-1/2!13-3/8" 72 ~80/C~51B~C ~8845 55 55 8900 8100 6600 sx in 3 stages ~2-~/4! ~-~/s"l ~ I~~c tz209~, ~ ~ z2z~o zzooo' ~0 mx 1 did O Total depth: measured ! feet Plugs (measured) true vertical ~. feet E,fective depth: measured p.<~..{r ~. {~*:~'~"~e e t Junk(measured) true vert,cal ~,f~ ~e ~' feet Casing Length ~('"'S i ze Cemented Measured depth True Vertical depth Structural oo== RE£EI'VED Surface Production Liner Aiaska.0il & Gas Cons. Commission Perforation depth: measured Anch0rag~, true vertical 20. Attachments Filing fee ~, Property plat:,r.,~: BOP Sketch ~[ iDiverter Sketch ~ iDrilling program ~ iDr~lling fluid program ~ Time vs depth Dior ~ Refraction analysis ~ SeaDecl report ~ 20 AAC 25.050 reauirements ./ '" /"' '~ Commission Use Only Conditions of approval S,mp,es re,u.re~ ~, ~es ~ No Mud ,og re,..red ~ Ye. C Hydrogen sulfide measures r-I Yes ~ No iDirectional survey reclu~recl ~ Yes ~ No ~D' '-. ~eeu~ree wor~ng pressure for BOP6 ,_.~2~; J~ 3M; ~ ~M; ~ ~OM; Q ~SM __~...:_?:/~? -' Other: · 0y orcler of Approved by JHt(JlNAL SIGNED BY · Commissioner the commission Date,~.: / .~' Form 10.401 Rev. 12.1-85 SuDm~t in triplicate PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX ~957 NORTH AMERICA EXPLO.=:ATION AND PRODUCTION COMPANY May 12, 1993 BELLAIRE, TEXAS 6330 ?/EST LOOP SOUTH PHILLIPS BUILDING CERTIFIED MAIL RETURN RECEIFr REQUESTED Notice of Application for Well Spacing Exception ARCO Alaska, Inc. Attention: James R. Winegarner P.O. Box 100360 Anchorage, Alaska 99510-0360 Alaska Department of Natural Resources Attention: James E. Eason P.O. Box 107034 Anchorage, Alaska 99510-0734 Texaco, Inc. Attention: Tom L. Hazen 4800 Fournace Pl., Suite E 700 -Bel!-.~re, Texas 7740! Global Natural Resources, Inc. Attention: Kendal Kuiper 5310 Memorial Houston, Texas 77007 Phoenix Resources Company of North America Attention: Mark W. Anschutz 6525 North Meridian, Suite 100 Oklahoma City, Oklahoma 73116-1491 Gentlemen: Phillips Petroleum Company has proposed the drilling of the Phillips/ARCO Sunfish//3 well as a intentionally deviated well pursuant to the Alaska Administrative Code Title 20-Chapter 25.050. As an affected owner you were provided notice by my letter of October 7, 1992. The Phillips/ARCO Sunfish//3 will be drilled to 13,350' TVD, 14,800' MD from the Phillips Tyonek Platform, with a surface location of 1,249' FNL, 980' FWL of Section 6, Township 11 North, Range 9 West and a bottom hole location of 4,150' FSL, 1,550' FEL, Section 31, Township 12 North, Range 9 West, Upper Cook Inlet, Kenai Borough, Alaska. If you have any questions on this matter please contact the undersigned at (713) 669-3729. Very truly yours, BAB/lc:0593.04 PHILLIPS PETROLEUM COMPANY Brett A. Butt~rfield General Landman ARC:¢ ARCO, PHILLIPS 8-31-96 .~ PH [I.~ [ PS ADL-369101 I~ --- 3-31 -98 ;~,1~ ~ ~ ~ HB~ ADL-374081 "~ _ ARCO ADL-"~7590 ~ PHILLIPS ---- -- T I 3-31-98 . .' , I ,~,-;-~,~o~; ? I =- ' ~ I - I : , / I ~ ARCO ..~,~. SUNFISH #$ I I ,,,,,,,,,,~ ,-,~,,~ . . / · ,,,,~o. ~,.,,,._,~t'""""' ' i _- -- - .ADL-37831 ! ,; t. HBP _ !: i.,,,,,,!,,,,',,''' ___ ...... ,: ~, , ,, , ~ , =. I ~,'"i' "s~Tt;';;"~, ~ COOK 3-3~-98 I =_ I · '\, ' ~ INLET '---':'ir---'--"". r---! PH ILL [PS _- I A'RCO I ' --' ; 1 ADL-18740 I~i I HBP ,~"~ i i~ HBP : I ADL- 1 7589 I i- · ADL- 1 8 741 + + iIlII,,IH~ -- ~,,',,,-' ~11111111111111111 IIIIIIIIIIIIIIIII1~ I ' I '+"----~ .... i ......... t'- ,.,t--- '--- RIOW Rgw SUNFISH NO. 3 WELL PHILLIPS PETROLEUM COMPANY SURFACELOCATION: 1249' FNL ~ ~, ~,,': ~'~t,% i.~ SEC. 6,980'TIIN-R9wFWL COOK INLET BASIN SUNFISH NO. 3 WELL LOCATION · .2¥0. · .40pO SCALE (FEET) ,,.,.,0.~ BOTTOM HOLE LOCATION: ?,:', ?,.V ~ 'i ';';~;jO 4150' FSL Alaska Oil, & 6us Cons. '.,~'" ~s£c.~1. rt2N-R9W SUNFISH NO. 3 PLANNED DRILLING PROGRESS M E A S U R E D D E P T H 0 SG · :2500' TVD, :2600' MD . 13 3/8' C8(3 · 8100' TVD, 8900' MD 1 0 ~ 9 5/8' CSG · 11000' TVD, 12150' MD ~ TEST 1 TEST 3 7' LINER · 1:3350' TVD, 14. a00' MD TEST 2 SUSPEND -20 I I I 0 50 100 150 2OO DAYS 24" Hole for 20" casing DRILLING PROCEDURE 1. Skid rig over leg 1 slot 6. 2. Weld riser with 28" swage onto existing conductor casing. · Install Hydril 29 1/2" 500 psi MSP annular preventer, mud cross and 10" diverter lines. Function test annular preventer and diverter line valves. Pump water through both diverter lines to insure they are clear. NOTE: DIVERTER LINES ARE TO BE STRAIGHT. · RIH w/ 12 1/4" bit, steerable motor and BHA including MWD and drill 12 1/4" pilot hole to kick off point at 830' RKB. With the steerable motor the hole can be nudged in a northerly direction above the planned kick off point. Control drill to minimize risk of overloading hole with drilled solids. Make high vis sweeps as needed to clean hole. Note: The NCIU A-12 well was drilled from a surface location 6' south and 8' west of the Phillips-Arco Sunfish No. 3, and deviates to the south. As long as the Phillips-Arco Sunfish No. 3 does not deviate south or west there should be no proximity problems and no need to shut in A-12. The Phillips-Arco Sunfish No. 2 was drilled from a surface location 4' north and 7' west of the Sunfish No. 3 and deviates to the westnorthwest. The Sunfish No. 2 has not been completed. There should be no proximity problems with Sunfish No. 2 as long as Sunfish No. 3 does not deviate to the west. If the Sunfish No. 3 does show a tendency to drift to the south or west the kick-off point will be adjusted and the well nudged to the northeast. · At kickoff point, begin sliding to kick well off per directional plan. Drill to 20" casing point at ± 2500' TVD, ± 2600' MD. Note: This directional plan is based on a maximum build rate of 2°/100 ft. acceptable. Dog leg severity in excess of 5°/100 ft could cause both drillpipe fatigue and excessive torque and drag. To minimize the potential for these problems THE DOG LEG SEVERITY CAN NOT BE PERMITTED TO EXCEED 4°/'100 FT. CONTROL DRILL WHILE SLIDING TO MINIMIZE THE TENDENCY OF THE BHA TO BUILD ANGLE FASTER THAN DESIRED. A gyro steering tool should be considered to permit the survey instrument to be located closer to the bit than a magnetic tool such as a MWD tool would permit. Report surveys every 30' through the build section. 6. RIH w/ 24" hole opener and open hole to TD. Incorporate a MWD into the BHA to insure the hole opener follows the original well and to insure that the dog leg severity is below 4°/100 ft. Report surveys every 30' through the build section. · Circulate and condition hole for 20" casing. Spot a high vis pill in the hole prior to POOH for casing. · Run 20" 169 lb/ft K-55 casing to ± 2600' MD, see attached casing and cementing program. Fill each joint while RIH. Note: Open the drain valve on the riser if there are indications that the flow area between the 20" casing and the diverter is inadequate for the volume displaced by the 20" casing. · Land casing with casing at a convenient height above the rotary table. Install false rotary table. 10. RIH w/ stinger for stab in float collar on drillpipe. Stab into float collar. 11. Break circulation, check top of 20" to insure stinger is sealing into stab in collar. Circulate and condition for cementing reducing mud viscosity to minimum possible for cementing. Circulate until returns are clean. 12. Mix and pump lead slurry. Pump cement until returns are observed at surface. After cement returns are observed begin pumping tail slurry and displace to float collar with mud. Overdisplace by about 5 BBLS to insure cement has cleared DP and to minimize the cement volume to be drilled. Unsting from float collar, POOH 1 stand. Open drain on riser and drain and wash cement from riser. 13. POOH with DP. 14. WOC until surface samples are hard. 17 1/2" Hole for 13 3/8" casing 1. ND diverter lines. . Cut off 30" conductor casing and riser 5 inches above the production deck. Using the BOP cranes, pick up 29 1/2" annular and riser high enough to make a rough cut on the 20" casing. Make rough cut on 20" casing and lay down 20" casing stub. 3. Lay down the riser and mud cross. · Verify top of cement is above the top connection on the 20" casing, if it is not run 1" pipe into the 20" x 28" annulus and cement to surface. · Make final cut on 20" casing. Weld on 20" SOW X 20 3/4" 3M bradenhead with baseplate onto 20" casing. Use Hot-Hed for preheating. Test weld to 2000 psi. · Install 20 3/4" 3M riser, drilling spool, 20 3/4" double gate BOP and 21 1/4" 2M annular preventer. Test rams to 3000 psi and annular to 1400 psi. · RIH w/ 17 1/2" bit and BHA for drilling. Close pipe rams and test casing to 2000 psi for 30 minutes. 8. Drill out cement, float shoe and 10' of new hole. · Run leak off test to actual leak off or to 12 ppg equivalent whichever occurs first. 10. Drill 17 1/2" hole to 13 3/8" casing point at ± 8100' TVD, 8900' MD. Motor runs for course corrections should be avoided in this section of hole due to the low pore pressure in the Cook Inlet and Beluga sands. 11. Circulate and condition hole for logs 12. Log as directed 13. Circulate and condition hole for casing. 14. Make up mandrel casing hanger on a joint of 13 3/8" 72 lb/ft N-80 casing. Rig up casing crew. 15. Pick up and run 13 3/8" 72 lb/ft N-80 and C-95 casing to ± 8900' MD, see casing and cementing program. Stage tools should be installed 100' below the bottom Beluga sand that appears productive from log analysis and between the Cook Inlet B and Cook Inlet 1 sands. A FO cementer should be run approximately 200' above the 20" casing shoe. Fill each joint while RIH. Note: The FO cementer is present to permit a fourth stage cement job at some future point if excessive pressure is observed on the 13 3/8" x 20" annulus. Note: Air weight for this casing string is 641,000 lbs. 16. Land casing in casinghead. 17. Circulate and condition for cementing reducing mud viscosity to minimum possible for cementing. 18. Prepare to cement 13 3/8" casing. Mix and pump first stage cement job, displace with mud. Drop opening bomb for second stage cement job. Circulate and condition mud for second stage. While circulating refill bulk cement tanks. Mix and pump the second stage cement, displace with mud. The second stage will cover up to 500' above the top of the Cook Inlet sands. Drop opening bomb for third stage cement job. Circulate and condition mud for third stage. While circulating refill bulk tanks as needed for third stage cement job. Mix and pump third stage cement job, displace with mud. 19. POOH w/ landing joint, RIH, set and test packoff. 20. ND 20 3/4" riser and BOP. 12 1/4" Hole for 9 5/8" Casing 1. NU 20 3/4" 3M x 13 5/8" 5M casing spool 2. NU 13 5/8" 10M riser and BOP. Test BOP and riser to 5000 psi. Test annular to 3500 psi. 3. RIH w/ 12 1/4" mill tooth bit and drill out top stage tool. Test casing to 3700 psi. Drill out second stage tool and test casing to 3700 psi. Clean out to float collar. 4. Run cased hole logs as directed. 5. RIH w/ 12 1/4" bit and BHA for drilling, test 13 3/8" casing to 3700 psi (70% of burst) for 30 minutes. 6. Drill out cement, float shoe, and 10' of new hole. 7. Run leak off test to actual leak off. 8. Drill 12 1/4" hole to 9 5/8" casing point at ± 11,000~ TVD, 12,150' MD. The 9 5/8" casing is to be set ± 200' above the C sand. Note: Sands above the C sand are expected to be normally pressured. A sharp pressure transition is expected at the C sand. The pore pressure in the C sand is expected to be a 13.2 ppg EMW. 9. Circulate and condition hole for logs 10. Run open hole logs as directed. 11. Circulate and condition for casing. 12. Make up mandrel casing hanger on a joint of 9 5/8" casing. Rig up casing crew. 13. Run 9 5/8" 53.5 lb/ft N-80 casing and 9 7/8" 62.8 lb/ft Q-125 casing to ~ 12,150' MD, see casing and cementing program. Fill each joint while RIH until pick up weight approaches 600,000 lbs. Do not fill the remainder of the casing to permit the casing to float. Note: The 9 7/8" 62.8 lb/ft Q-125 casing should be run through the build section to provide additional tolerance to casing wear. Be prepared to change slip segments from 9 5/8" to 9 7/8" and back. Note: Air weight for this string is 661,000 pounds. Rig up the 500 ton elevators before running casing below the 13 3/8" casing shoe. 14. Land casing in casinghead. Install cementing head and fill remainder of casing. 15. Circulate and condition for cementing reducing mud viscosity to minimum possible for cementing. 16. Cement 9 5/8" casing. Top of cement to be 500' above top hydrocarbon zone. 17. POOH w/ landing joint, RIH, set and test packoff. 18. ND 13 5/8" riser and BOP. 8 1/2" Hole for 7" Liner 1. NU 13 5/8" 5M x 11" 10M tubing head. 2. NU 13 5/8" 10M riser and BOP. Test riser and BOP to 10,000 psi. Test annular preventer to 3500 psi. 3. Run cased hole logs as directed. 4. RIH w/ 8 1/2" bit and BHA for drilling. Test 9 5/8" casing to 5000 psi for 30 minutes. 5. Drill out cement, float shoe, and 10' of new hole. 6. Run formation leak off test to actual leak off. 7. Drill 8 1/2" hole to core point at the top of the C sand at ± 11200' TVD. A geologist will be on location to pick core point. Increase mud weight to 14 ppg while drilling to C sand. The pore pressure of the C sand is expected to be 13.2 ppg EMW. 8. Core the C sand as directed. 9. Drill 8 1/2" hole to core point at the top of the Sunfish sand at ± 12280' TVD. A geologist will be on location to pick core point. The pore pressure of the Sunfish sand in this northern portion of the field is uncertain. There is a possibility that its pore pressure is nearly normal as it is in the wells to the south. However the C sand is known to be abnormally pressured in the northern area but normally pressured in the south. Be prepared for the Sunfish pore pressure to be as low as 9.8 ppg EMW or as high as 14 ppg EMW. 10. Core the Sunfish sand. 11. Drill to the North Forelands sand at ± 12700 TVD'. Note: A core may be cut in the North Forelands sand. 12. Drill to TD at ~ 13350' TVD, ± 15000' MD. 12. Circulate and condition hole for logs. 13. Run open hole logs as directed. 14. Circulate and condition hole for 7" liner. 15. Run 7" 32 lb/ft L-8© liner on 5" DP. 16. Circulate and condition for cementing. Reciprocate pipe while circulating. Reduce mud viscosity to minimum possible for cementing. 17. Hang liner in 9 5/8" casing. 18 Mix and pump cement, bringing cement 200' above the top of the liner hanger. Note: Rotate liner while cementing. 19. Release from liner hanger and POOH. 20. RIH 8 1/2" bit and clean out to top of liner. 21. Pressure test liner top and 9 5/8" casing to 5000 psi. Note: Test pressure may be changed based on results of RFT data if available. 22. RIH w/ 5 7/8" bit, 4 3/4" DC's, 3 1/2" and 5" DP to clean out inside the liner. 23. Note: 24. 25. 26. 27. Pressure test 7" liner to 5000 psi. Test pressure may be changed based on results of RFT data if available. Run cased hole logs as directed. Conduct well test operations as required to evaluate potential hydrocarbon bearing intervals. After all testing is complete the well will be suspended pending a decision on the future utility of the wellbore. Set bridge plugs as follows: ae Set a cast iron bridge plug in the 7" casing within 50' of the top perforation in the well and spot 75' of cement on top of the bridge plug. S · Set a bridge plug in the 9 5/8" casing within 25' of the top of the 7" liner and spot 75' of cement on top of the bridge plug. Ce Set a bridge plug in the 9 5/8" casing at 300' and spot 100' of cement on top of the bridge plug. ND the 13 5/8" BOP and riser. Install blind flange on top of tubing head. PHILLIPS - ARCO SUNFISH NO. 3 CASING SCHEMATIC .:.:. COOK INLET 3300' TVD 3500' MD BELUGA 4400' TVD 4730' MD I:i:i: ..... ..... ..... ..... TYONEK 8100' TVD 8900' MD SUNFISH 12~80' TVD 1558O' MD :i:i::l :.:.:.: :.:.:. ::::::1 ::::::1 · . . ::::::1 :-:-:, Conductor Pile 30', 0.75' - 2.75" Well Pile · 175' BML, 407' RKB Surface Caaing 20' 169 Ib/ft K-55, 7_,TC ~..-~:~O · 2500' TVD, 2600' MD 15 3/8' T0C et leaet 500' TVD above hydrocarbon zonee Intermediate Casing 13 3/8' 72 I b/ft N-80 end c-gs, BTC · 8100' TVD, 8900' MD 9 5/B' TOC et leaet 500' TVD abOVe hydrocarbOn zones PrOduction Caai ng~j/ 9 5/8' 53.5 Ib/ft ~Z'-80 BTC · 11000' TVD, 12150' MD Production Liner 7' $2 I b/ft L-80 BTC · 13550' TVD, 14800' MD PRESSURE ANALYSIS Pore pressure predictions have been made based on the offset well information from other wells drilled in the area and the seismic data. The most important offset wells used in this analysis are the production wells on the platform for the shallow horizons, and the Shell North Cook Inlet State No. 1, Arco Sunfish No. 1, Arco- Phillips North Forelands State No. 1, and the Phillips-Arco Sunfish No. 2 wells recently drilled. The interval above 8100' TVD, ± 8900 MD will be the Cook Inlet and Beluga sands that are produced at the platform. The pressures in these sands have declined to a 5 - 6 ppg equivalent mud weight. Based on the results from the Arco Sunfish No. 1, the Arco-Phillips North Forelands State No. 1, the Phillips-Arco Sunfish No. 2 and the workovers on North Cook Inlet Unit A-9 and A-i, lost circulation is not expected to be a problem despite the low reservoir pressures. Due to the lenticular nature of the Beluga formation, there is the possiibilty of encountering a Beluga sand at virgin conditions. Virgin pressure in the Beluga interval was 8.5 - 9.5 ppg. The geologic interpretation for the interval below 8100' TVD is that the formations and pressures should be similar to those encountered in the Shell North Cook Inlet State No. 1. The interval between 8100' and the proposed 9 5/8" casing point at 11000' TVD, 12150' MD is essentially normally pressured. Mud weights will be dictated by the coal seams throughout this interval. There is a sharp pressure transition that occurs at the top of the C sand at ± 11200' TVD, ± 12360' MD,. Pore pressure will increase from 9.8 ppg to about 13.2 ppg during this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 15 ppg. ANTICIPATED SURFACE PRESSURE CALCULATIONS The following presents the information used in the calculation of maximum potential surface pressure for the various hole sections. Casing Setting Depth Rationale 30" 175' BML, 407' RKB Conductor pile, driven when platform was installed in 1968 20" 2268' BML, 2500' 'I-VD, This string of casing will top set the 2600' MD, Cook Inlet sands. It will provide a good anchor for the BOPE and provides an adequate fracture gradient for drilling to the 13 3/8" casing point. 13 3/8" 8100' TVD, 8900' MD Intermediate casing string to isolate the Cook Inlet and Beluga sands currently producing on the platform. 9 5/8" 11000' TVD, 12150' MD Intermediate/Production casing above C sand to provide an adequate fracture gradient to drill to total depth. 7" 13350' TVD, 15000' MD Production liner to isolate C sand, Sunfish sand and North Forelands sand for potential testing Casing Setting Fracture Pore Pressure Maximum Maximum Size Depth Gradient Gradient That Downhole Pressure Potential Surface (ppg) May Be That May Be Pressure Drilling Encountered Encountered (psi) (ppg) (psi) 30" 175' BML, 10 8.7 1130 205 405' RKB 20" 2500' 'I-VD, 14.8 9.0 3790 1100 2600' MD 13 3/8" 8100' TVD, 17.7 9.5 5434 2492 8900' MD 9 5/8" 11000' TVD, 18.0 14 9719 3351 12150' MD SUNFISH No. 3 PORE PRESSURE PREDICTIONS TVD 0 -2 -4 -6 -8 -10 -12 -14 -16 4 6 8 10 12 14 16 18 EQUIVALENT MUD WEIGHT 20 · Pore Pressure I Mud Weight ~< Frac Grad lent Procedure for determining maximum downhole pressure and maximum potential surface pressure Maximum Downhole Pressure is determined from the pore pressure predictions of the interval to be drilled below the subject casing. The pore pressure predictions were made from offset well data and the seismic data. The maximum potential surface pressure is determined to be the lesser of the fracture pressure of the formation at the subject casing shoe less a fluid gradient to surface or the bottomhole pressure of the intervals to be drilled less the gradient of the fluid produced from the formation. · · Drilling Below 30" Conductor Pile: Maximum Bottomhole Pressure (BHP): BHP = PP x 0.052 x Dd BHP = 8.7 x 0.052 x 2500 = 1130 psi Maximum potential surface pressure is based on the frac pressure at the shoe less a gas column to surface. At this shallow depth the gas gradient is about 0.015 psi/ft, and the frac gradient is estimated to be 10 ppg. MPSP = ((FG x 0.052) - GG)Dcs MPSP = ((10 x 0.052) - 0.015)405 = 205. psi Drilling Below Surface Casing: BHP = PP x 0.052 x Dd BHP = 9.0 x 0.052 x 8100 = 3790 psi This interval includes the Cook Inlet and Beluga sands that are produced on the platform. The shut in surface pressure as measured on the wells, 1100 psi, is less than the fracture pressure of the formation at the casing shoe. The shut in surface pressure determines the maximum potential surface pressure. . . Drilling Below 13 3/8" Intermediate Casing: BHP = PP x 0.052 x Dd BHP = 9.5 x 0.052 x 11000 = 5434 psi Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval could be gas, oil, or water. The maximum pressure is based on the assumption that the formation fluid is gas with a resulting formation fluid gradient of 0.015 psi/ft. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (MW x 0.052) (0.5 x Dd) - (FFG) (0.5 x Dd) MPSP = 5434 - (10 x 0.052)(0.5 x 11000) - (0.015)(0.5 x 11000) = 2492 psi ~ Drilling Below 9 5/8" Intermediate: BHP = PP x 0.052 x Dd BHP = 14 x 0.052 x 13350 = 9719 psi Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval is expected to be oil and gas. Based on test results the formation fluid pressure gradient is about 0.2 psi/ft. MPSP = BHP - (MW x 0.052) (0.5 x Dd) - (FFG) (0.5 x Dd) MPSP = 9719 - (14.5 x .052)(0.5 x 13350) - (0.2)(0.5 x 13350) = 3351 psi CASING DEPTH SETTING VARIANCE REQUEST Phillips Petroleum request a variance to the required setting depth of the conductor casing as specified in 20 AAC 25.030 (c) (2). In the case of the Phillips-Arco Sunfish No. 3 the planned casing is 20" 169 lb/ft K-55. The intended setting depth is 2250' below mud line. Phillips is requesting this variance based on the drilling information from the previous 13 wells drilled from this platform and the information gained from the Arco Sunfish No. 1 and the Arco-Phillips North Foreland St No. 1. The change in conductor setting depth will permit an optimized hole/casing program for reaching the objectives of the well. Arco Alaska conducted extensive shallow hazards surveys over the area in conjunction with the Arco Sunfish No. 1 and the Arco- Phillips North Forelands St No. 1. These surveys did not identify any hazards to a drilling program from the Tyonek platform. There have been no indications of anomalies above 3000' BML in the wells drilled from the platform, the Arco Sunfish No. 1 or the Arco-Phillips North Foreland St No. 1. The mud weights used in this interval on the recent wells have typically been below 9.0 ppg. The mud weight has been dictated by drilled solids rather than additions of barite. There was no indication of flow in any of the wells through this interval. A 12 1/4" pilot hole is planned for this well. This approach was followed on the Arco Sunfish No. 1 and the Arco-Phillips North Foreland St No. 1 and the Phillips-Arco Sunfish No. 2. This approach results in exposing a minimal wellbore area and a quicker reaction time to any potential flow. Mud flow into and out of the well will be monitored by two independent systems, the PVT system installed on the rig and the mudloggers. The diverter system to be utilized in drilling to the 20" casing point is described elsewhere in this application. A 21 1/4" diverter with 10" lines will be used. The diverter lines extend in straight runs from the spool. A 20 3/4" BOP stack will be used for drilling below the 20" casing. Further supporting this request is the following tabulation listing several wells in the Cook Inlet Area where the second casing string was set deeper than 1000' below mud line or ground level. The depths shown are TVD-RKB. Well String 1 String 2 String 3 Arco Fire Island # 1 30" @ 328' 20" @ 1685' 13 3/8" @ 7603' Stuart W. McArther RU #1 30" @ 127' 20" @ 2040' unknown Phillips NCIU A-12 30"@ 381' 20"@ 1990' 13 3/8" @ 6950' Arco-Phillips North Foreland St # 1 30" @ 316' 20" @ 2489' 13 5/8" @ 8498' Arco Funny River # 1 30" @ 60' 20" @ 2971' 13 3/8" @ 8312 Arco Beluga RU # 1 20"@ 95' 13 3/8" @ 2985' Phillips-Arco Sunfish # 2 30" @ 407' 20" @ 2482' 13 3/8" @ 7695' Proposed Philips-Arco Sunfish No. 3 30" @ 407 20" @ 2500' 13 3/8" @ 8100' CASING AND CEMENTING PROGRAM 20" Casing and Cementinq Proqram Hole Size : 24" Depth: 2500' TVD, 2600' MD Casing Specifications: (Top to Bottom) Pressure Torque Length Size & Description Tension Burst Co[lapse OPT MIN I MAX 2600' 20" 169 [b/ft 3910 2500 2272000 See Running DrilQuip C-60 Procedure Casing Accessories: Float Shoe : Conventional fill Float Collar and Loc: Stab in, 1 jt above shoe Centralizers and Loc: None Circ, mix, disp rate: Maximum Practical Slurry Composition: Lead Slurry Mixwater Slurry Weight Yield Thickening time Desired TOC Tail Slurry Mixwater Slurry Weight Yield Thickening time WOC before cutoff : 2000 sks Class G w/ 0.28 gallons per sack D-075, 0.2 gallons per sack D-077 and 0.05 gallons per sack D-047 : 11.7 gallons freshwater per sack : 12.5 ppg : 2.11 cu. ft. per sk : 7:40 hours : Surface D ~o~~/~,~./~,. : ~ sks Class G'cement w/ 0.25 gallons per sack D-077 and 0.050 gallons per sack D-047 : 4.8 gallons freshwater per sack : 15.8 ppg : 1.16 cu. ft. per sk : 3:30 hours : 8 hrs and until surface samples are hard Volumes are based on 50% excess over gage hole. Ail four bulk tanks on deck (3700 sacks) should be filled with neat Class G cement prior to beginning cement job. The bulk tank inside the pump room should be reserved for the tail slurry. If cement returns have not been observed before the bulk tanks on deck are empty, begin mixing the tail slurry with the cement in the pump room bulk tank. A top job will be performed if the top connection on the 20" is not covered by cement. 13 3/8" Casinq and Cementing Program Hole Size : 17 1/2" Depth: 8100' TVD, 8900' MD Casing Specifications: (Top to Bottom) Pressure Torque Length Size & Description iTens~on Burst Collapse OPT MIN MAX 3900' 13 3/8" 72 lb/ft 5380 2670 16610001 To base of N-80 Buttress TriangLe 5000' 13 3/8" 72 lb/ft 6390 2830 1893000 To base of C-95 Buttress Triangle Casing Accessories: Float Shoe : Conventional fill Float Collar and Loc: Conventional Fill Centralizers and Loc: Turbolators at center of 1st joint, across collars from jts 2 - 10, and every other joint between 7000' and 4000'. Stage tools : 100' below lowest Beluga productive interval, between Cook Inlet B and 1 sands and 200' above 20" shoe. Circ, mix, disp rate: Maximum Practical Slurry Composition: First Stage Lead Slurry Mixwater Slurry Weight Yield Thickening time : 1000 sks Class G w/ 1% D-079, 1.% D-065, 0.05 gal/sk D-047, : 11.8 gallons freshwater per sack : 12.5 ppg : 2.1 cu. ft. per sk : 10:30 hours Tail Slurry Mixwater Slurry Weight Yield Thickening time : 600 sks Class G cement w/ 0.05 gallons per sack D-047, 0.5% D-059, 0.4% D-65, 0.1% D-136, allons per sack D-080, 0.15 gallons per sack D-135, 0.25% SI, and 0.15 gallons per sack D-801. : 4.8 gallons freshwater per sack : 15.8 ppg : 1.16 cu. ft. per sk : 8:30 hours Second Stage Slurry Mixwater Slurry Weight Yield Thickening time Desired TOC : ~ sks Class G cement wi 0.1 gallons per sack D-047, 0.02 gallons per sack D-080, 0.1 gallons per sack D-135, 1.0 gallons per sack D-600 and 0.1 gallons per sack D-801. : 3.6 gallons freshwater per sack : 15.8 ppg : 1.17 cu. ft. per sk : 11:30 hours : Above Cook Inlet 1 sand Third Stage Slurry Mixwater Slurry Weight Yield Thickening time Desired TOC : 1000 sks Class G cement w/ 0.1 gallons per sack D-047, 0.02 gallons per sack D-080, 0.1 gallons per sack D-135, 1.0 gallons per sack D-600 and 0.02 gallons per sack D-801. : 3.6 gallons freshwater per sack : 15.8 ppg : 1.16 cu. ft. per sk : 8:00 hours : 3300' or at least 500' above top hydrocarbon interval Volumes are based on 50 % excess over gage hole. Actual volumes should be recalculated based on 20% over caliper. The lead slurry for the first stage should be the volume of cement in one of the bulk tanks on deck. Note that this slurry uses dry blend additives. Immediately after pumping the first stage blow any cement left in this bulk tank overboard and refill the tank and the tank used for the tail slurry on the first stage with neat Class G cement before starting the second stage. Refill the buik tanks as needed with neat Class G cement between the second and third stage cement jobs. 9 5/8" Casinq and Cementing Program Hole Size : 12 1/4" Depth: 11000' TVD, 12150' MD Casing Specifications: (Top to Bottom) Pressure Torque Length Size & Description Tension Burst Collapse OPT MIN MAX 900' 9 5/8" 53.5 lb/ft 7930 6620 1244000 To base of i~/~..~ Buttress Triangle 1150' 9 7/8" 62.8 lb/ft 15820 11140 1743000 To base of Q-125 Buttress Triangle 10100' 9 5/8" 53.5 lb/ft 7930 6620 1244000 To base of t~l~ Buttress Triangle Casing Accessories: Float Shoe : Conventional fill Float Collar and Loc: Conventional Fill Centralizers and Loc: Straight bladed rigid centralizers on shoe jt joint, 2nd, 3rd, 5th, 7th, 9th, llth, 13th, 15th, 17th, 19th, and 21st joints Circ, mix, disp rate: Maximum Practical Slurry Composition: Slurry Slurry Weight Yield Mix Water Thickening time Desired TOC : 650 Sx Class G cement w/ 0.1 gal/sk D-047, 0.014 gal/sk D-080, 0.1 gal/sk D-135, 1.0 gal/sk D-600 and 0.085 gal/sk D-801. : 15.8 ppg : 1.16 cu. ft. per sk : 3.79 gal/sk fresh water : + 6:53 hours : 11000' 7" Liner and Cementinq Program Hole Size : 8 1/2" Depth: 15000' TVD, 13350' MD Casing Specifications: (Top to Bottom) Pressure Torque Length Size & Description Tension Burst Collapse OPT MIN MAX 3200' 7" 32 lb/ft 9060 8610 738000 To base of L-80 Buttress Triangle Casing Accessories: Float Shoe : Conventional fill Float Collar and Loc: Combination landing collar and float collar Centralizers and Loc: Turbolators at center of 1st joint, across collars of next 5 jts and as appropriate through intervals to be tested Liner Hanger : Hydraulic set Circ, mix, disp rate: Maximum Practical Slurry Composition: 0' ~_~ .~.~. Slurry Slurry Weight Yield Thickening time Desired TOC : ~ Sx Class G cement w/ additives as needed : 15.8 ppg : 1.16 cu. ft. per sk : + 4:00 hours : Circulate cement to 200' above liner hanger Slurry details to be determined based on cement test results Well Control This well is to be drilled in accordance with Phillips Well Control Manual. The primary means of maintaining well control is the mud. The mud loggers will be monitoring the well and making pore pressure predictions to assist the mud engineer in maintaining the appropriate mud properties. This well will drill a significant amount of gas saturated coal and sand. This will result in high background gas readings. This readings are to be expected and ARE NOT indicative of increasing pore pressure. Mud weight should not be increased in attempts to suppress background gas. The viscosity of the mud should be kept as low as practical considering the hole cleaning requirements so that the drilled gas can break out of the mud at surface. Prior to each trip a mud check is to be made at the flowline to compare the properties of the mud returns with the properties of the mud in the pits. Mud weight and chlorides in and out should be in close agreement before tripping. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepancy between the actual and required fill up volume must be determined before continuing with the trip. The BOP equipment is to be used if the mud is no longer able to provide control of the well, i.e. in the event of a kick. Recommended practices for handling a kick are found in Phillips Well Control Manual. Well control drills are to be conducted with each crew as per Phillips Well Control Manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. The purpose of the drills is to insure that all personnel know what their responsibility is in the event of a kick. A copy of the Phillips kill sheet should be available in the drillers doghouse at all times. The prerecorded information on the kill sheet should be updated at least once per tour. BOP EQUIPMENT: Diverter System for drillinq below 30" conductor pile: A schematic drawing of the diverter is attached. The diverter system includes the following: 1. 21 1/4" 2M annular preventer · 21 1/4" 2M drilling spool with straight 10" diverter lines and automatically operated valves. 3. Riser welded to conductor pile Function test the annular preventer and the diverter valves after initial installation and once per day thereafter. Pump water through both lines to insure the lines are clear. BOPE for drillinq below 20" surface casinq: A schematic drawing of the BOP is attached. The BOPE includes the following: 1. 21 1/4" 2M annular preventer 2. Double Studded Adapter 21 1/4" 2M x 20 3/4" 3M 3. 20 3/4" 3M double gate blowout preventer with blind rams on top and 5" pipe rams on bottom 4. 20 3/4" 3M Drilling Spool 5. 20 3/4" 3M Riser 6. 20 3/4" 3M casing head After initial nipple up test the rams and the choke manifold to 3000 psi and the annular preventer to 1400 psi. Once per week, test the rams and choke manifold to 1500 psi, and the annular preventer to 1400 psi. Function test the blind rams on each trip out of the hole. Function test the remainder of the BOPE on a daily basis. BOPE for drilling below 13 3/8" Intermediate casinq 1. 13 5/8" 5M annular preventer 2. 13 5/8" 10M double gate preventer with variable rams on top and blind rams on bottom 3. 13 5/8" 10M drilling spool 4. 13 5/8" 10M ram preventer with 5" pipe rams installed. 5. 13 5/8" 10M riser 6. Adapter spool 13 5/8" 10M x 13 5/8" 5M 7. Casing spool with 13 5/8" 5M top flange After initial nipple up test the rams and the choke manifold to 5000 psi and the annular preventer to 3500 psi. Once per week, test the rams and choke manifold to 5000 psi, and the annular preventer to 3500 psi. Function test the blind rams on each trip out of the hole. Function test the remainder of the BOPE on a daily basis. BOPE for drillinq below 9 5/8" Intermediate casinq 1. 13 5/8" 5M annular preventer 2. 13 5/8" 10M double gate preventer with variable rams on top and blind rams on bottom 3. 13 5/8" 10M drilling spool 4. 13 5/8" ram preventer with 5" pipe rams installed. 5. 13 5/8" 10M riser 6. Adapter spool 13 5/8" 10M x 11" 10M 7. Casing spool with 11" 10M top flange After initial nipple up test the rams and the choke manifold to 10000 psi and the annular preventer to 3500 psi. Once per week, test the rams and choke manifold to 5000 psi, and the annular preventer to 3500 psi. Function test the blind rams on each trip out of the hole. Function test the remainder of the BOPE on a daily basis. SUNFISH NO. 3 DIVERTER SYSTEM 29 1/2' 500 PSI ANNULAR PREVENTER I RISER 1. ANNULAR NORMALLY OPEN 2. VALVES A AND C NORMALLY CLOSED 3. VALVE B NORMALLY OPEN 4. WHEN ANNULAR CLOSES, VALVE A AUTOMATICALLY OPENS 5. WHEN VALVE C OPENS, VALVE B AUTOMATICALLY CLOSES 6. VALVE B CAN BE ISOLATED TO REMAIN OPEN WHEN OPENING VALVE C 10" OIVERTER LIN~ 10' DIVER1'gR UN£ DIVERTER LINE ROUTINO PHILLIPS PL,~ TFORM TYONEK SUNFISH NO. 8 RISER AND BOP ARRANGEMENT DRILLING BELOW 20" CASING I I I I 2M ANNULAR PREVENTER KILL LI NE HCR VALVE GATE VALVE 3M BLIND RAMS 3M PIPE RAMS DRILLING SPOOL CHOKE LINE GATE VALVE HCR VALVE 20 3/4' 3M RISER CASING HEAD 20' SOW X 20 3/4' 3M SUNFISH NO. 3 RISER AND BOP ARRANGEMENT DRILLING BELOW 13 3/8" CASING I I 6M ANNULAR PREVENTER KILL LI NE HCR VALVE GATE VALVE [ 10M VARIABLE BORE PIPE RAMS 10M BLIND RAMS DRILLING SPOOL CHOKE LINE GATE '~,LVE HCR VALVE 5' 10M PIPE RAMS 13 $/8' 10M RISER ADAPTER 13 5/8' 5M X 13 5/8' 10M CASING SPOOL 20 3/4' 3M X 13 6/8' 6M SUNFISH NO. 3 RISER AND BOP ARRANGEMENT DRILLING BELOW 9 5/8" CASING I I I I 5M ANNULAR PREVENTER 10M VARIABLE BORE PIPE RAMS KILL LI NE HCR VALVE GATE ',~,LVE 10M BLIND RAMS DRILLING SPOOL CHOKE LINE GATE ',,~,LVE HCR VALVE 5' 10M PIPE RAMS 13 5/8' 10M RISER ADAPTER 11' 10M X 13 5/8' 10M TUBING HEAD 13 5/8' 5M X 11' 10M DRILLING FLUID PROGRAM Hole Section: Base of conductor pile to 2500' TVD, 2600' MD Hole Size: 12 1/4" pilot hole opened to 24" Casing Size: 20" Mud Type: Spud Mud Desired Mud Properties: Weight: Viscosity: PV: YP: Fluid loss: 8.8 - 9.2 ppg 100 - 150 sec/qt 20 - 30 35 - 50 No Control Spud well with mud consisting of prehydrated bentonite and fresh water. Use bentonite extenders as needed for good hole cleaning. Due to fast penetration rates and the large hole size, the solids content can increase rapidly. Run all solids control equipment to minimize buildup of drilled solids. If needed, add lime to assist in flocculating the drilled solids. Lost circulation and shallow gas are potential problems in this interval. An adequate stockpile of lost circulation material and weight material will be on board for use if needed. Initial treatment for losses should be to reduce the fluid loss of the mud. Hole Section: 2500' TVD, 2600' MD to 8100' TVD, 8900' MD Hole Size: 17 1/2" Casing Size: 13 3/8" Mud Type: Low Solids Desired Mud Properties: Weight: 8.5 - 10 ppg Viscosity: 40- 60 sec/qt PV: 12 - 18 YP: 12 - 16 Fluid loss: Below 6 pH: 8 - 9.5 Solids: < 8% Drill the 20" shoe with spud mud from the previous hole section. Treat cement contamination with soda ash. Drill ahead adding Drispac Plus and PHPA polymer to reduce fluid loss to desired range and as needed for hole stability. Add Desco-CF as needed for rheology control. This hole section includes the Cook Inlet and Beluga Sands produced on the platform. The reservoir pressure in these sands is 5 - 6 ppg equivalent mud weight. This results in the potential for differential sticking problems, for lost circulation problems, and for gas cutting of the mud. Take all possible precautions to minimize these potential problems, including minimizing time with the drillstring stationary, and maintaining the mud in good condition. There is the possibility of encountering a Beluga sand at virgin conditions. Virgin pore pressure in the Beluga could be as high as 9.5 ppg EMW. Due to fast penetration rates and the large hole size, the solids content can increase rapidly. Run all solids control equipment and maintain sufficient dilution to avoid a buildup of low gravity solids. If necessary control drill to avoid overloading the hole with drilled solids and to avoid excessive gas cutting. A significant amount of coal will be drilled in this interval. Soltex has been used with some success to minimize the potential problems caused by the coal seams. Add Soltex when needed due to tite hole problems and in response to difficulties with the coal seams. Increases in mud weight may also be required to stabilize the coals. Maintain pH as low as possible to help maintain the stability of the coal. Hole Section: 8100' TVD, 8900' MD to 11000' TVD, 12150' MD Hole Size: 12 1/4" Casing Size: 9 5/8" Mud Type: Polymer Desired Mud Properties: Weight: 9.5 - 12 ppg Viscosity: 40 - 60 sec/qt PV: 15 - 20 YP: 12 - 16 Fluid loss: 8 - 10 pH: 8 - 9.5 Solids: < 12% Drill the 13 3/8" shoe with mud from the previous hole section. Treat cement contamination with soda ash. Drill ahead maintaining properties in the desired range. Coals can be expected throughout this interval. Use soltex and mud weight as needed to stabilize the coals. Keep pH as low as possible to help maintain the stability of the coal. This hole section will include several normally pressured permeable sands. If mud weight is increased to stabilize coals the potential for differential sticking will increase. Take all appropriate precauttion to minimize the risk of differential sticking. Hole Section: 11000' TVD, 12150' MD to 13350' TVD, 15000' MD (TD) Hole Size: 8 1/2" Casinq Size: 7" Mud Type: Polymer Desired Mud Properties: Weight: 13.5 - 15 ppg Viscosity: 40 - 60 sec/qt PV: 15 - 25 YP: 10 - 20 Fluid loss: 4 - 6 pH: 8 - 9 Drill the 9 5/8" shoe with mud from the previous hole section. After conducting leak off test, begin adding barite as needed to increase mud weight to 13.5 ppg. Add potassium bromide at a concentration of 1.0 ppb as a tracer for core studies. Add Desco-CF as needed for rheological control and Soltex as needed for hole stability. The pore pressure in the C sand is expected to be 13.2 ppg EMW. The pore pressure below the C sand is expected to remain at 13.2 ppg, however, there is the possibility that some of the sands below the C sand will be normally pressured. This results in a high wisk of differential sticking. Take all appropriate precautions to minimize the differential sticking risk. Coals can be expected throughout this interval. Use soltex and mud weight as needed to stabilize the coals. DRILLING FLUID SYSTEM DESCRIPTION Mud storage capacities on Tyonek are as follows: Drill Water: 3600 barrels Pit Volume (Active System): approximately 1100 barrels Bulk Mud: Bulk tanks will be installed as needed to maintain a barite inventory adequate to raise mud weight by 1 ppg. Number of tanks may vary based on the hole volume and mud weight Solids control and other mud equipment will include the following: 2 Harrisburg linear motion shale shakers 1 desander with capacity of 1000 gpm 1 mud cleaner 1 centrifuge 1 Swaco vacuum type degasser 1 Mud-Gas Separator: Pool Arctic Alaska design 7 mud agitators, 10 HP each 1 Mixing Hopper: Geosource model 8900 Sidewinder. Pit Level Indicators: Totco visulogger system Mud testing equipment: Basic kit for weight, viscosity, rheology, filtration and titration A complete mud logging unit with all equipment needed per 20 AAC 25.033(e) (2) and 20 AAC 25.033(e)(3) DIRECTIONAL DRILLING PLAN TARGET The primary objective of this well is to penetrate the Sunfish Sand at a depth of 12280' TVD-RKB. The target at this depth is 4900' north and 2500' east of the surface location. The well will continue to the North Forelands secondary objective at 12700' TVD. The proposed wellpath and spider plots showing other wells in the area is attached. The only wells within 1/2 mile of any portion of this wellbore are the other wells on the platform. MWD tools will be used for directional surveys throughout the course of the well. Surveys should be reported at least every 90'. DIRECTIONAL PLAN Drill a vertical 12 1/4" hole to the desired kickoff point at 830'. At 830' kick the well off and build angle at a rate of 2°/100 ft. to a 27.1° angle. Drill ahead maintaining the 27.1° angle to TD. The vertical section for the well is on a 27° azimuth. Maintain directional control with the BHA. Sliding with a mud motor to correct direction should be avoided as much as possible due to the differential sticking risk posed by the various sands. I I I V 100o 350o 50oo 6OOO 65OO 700O 75OO 80O0 PHILLIPS PETROLEUM Structure : TYONEK Platform Field : North Cook Inlet CONDUCTOR SURVEY TIE-IN TVD=363 TMD=363 DEP=I 1.95 KOP TVD=700 TMD=700 DEP=8 5.90 9.89 2 DEG / 100' DOGLEG 13.89 17.88 21.88 25.88 EOC TVD=1927 TMD=1975 DEP=311 20" CSG PT TVD=2500 TMD=2615 DEP=598 N 27.03 DEG E 550 i'(T0 TARGET) · "PLANE OF PROPOSAL'" AVERAGE ANGLE 26.62 DEG 13 3/8" CSG PT TVD=8100 TMD=8880 DER=3405 _ _ COMPANY] 9500 10000_ 105 O0 _ - 1~o00_ 9 5/8" CSG PT TVD=lllO0 TMD=12236 DER=4909 _ 11500_ 12000. · TARGET TVD=12280 TMD=I3556 DEP=5501_~_ 12500. _ 13000_ 730 DEP=6027 '~'~-~ TD - 7" CS(; PT TVD=13330 TMD=I¢ 13500. ~_J t i i i I t i i 5oo o soo 1 ooo ~ soo 200o 2soo 300o 35oo ~oo 45oo Scale 1 : 250.00 Vertical Section on 27.03 azimuth with reference 0,00 N, 0,00 E from slot #1-6 Well : Sunfish#3 Location : Cook Inlet, Alaskai Created by : jones For: D MORGAN Dote plotted : 7-May-93 Plot Reference is Sunfish #3 Version #4. Coordinates ore in feet reference slot #1-6. j True Vertical Depths ore reference wellhead. BAKER HUGHES INTEQ ......... East -- > 0 400 800 1200 1600 2000 2400 2800 I I I I I I I I I I I I I I I I TARGET ]A/D=12280 TMD=13556 DEP=5501 NORTH 4900 EAST 2500 SURFACE LOCATION: 1249' FNL, 980' FWL SEC. 6. TllN, R9W 56OO - _5200 3600 ~3200 _ _2800 o 40o I I g 0 ~ca,e 1 : 10.00 E a S t -- -- > 40 20 O 20 40 60 80 1 O0 120 140 180 180 200 220 240 260 280 300 320 340 360 560. 5401 520~ 22OO PHILLIPS PETROLEUM COMPANY Structure : TYONEK Platform Well : Sunfish#5 Field : North Cook Inlet Location : Cook Inlet, Alaska 2200 2100 2400 _560 - _540 - -460 2100 2000 200 ---~ 20 ~2000 1900 1800 1600 1700 1800 1700 1 6O0 15O( 600 1 40O 1300 1500 120~ ,o 20 o 20 ,o so so ~ 00 Scale 1 - 10.00 1800 200 2100 2000 1900 1700, 1600 1500 1500 140[ 1400 300 200 )0 100 1800 1900 140 160 180 200 Eosf --> _340 1900 _280 - _260 Z - _240 - D'- _220 _ _200 _ _180 _ _160 120 20 o 220 240 260 280 300 320 340 360 PHILLIPS PETROLEUM COMPANY TYONEK Platform Sunfish~r5 slot #1-6 North Cook Inlet Cook Inlet, Alaska PROPOSAL LISTING by Eastman Teleco Your ref : Sunfish ~ Version #4 Our ref : prop789 License : Date printed : ?-May-93 Date created : 7-May-93 Last revised : ?-May-93 Field is centred on n61 4 48.679,w150 57 15.448 Structure is centred on n61 4 48.679,w150 57 15.448 Slot location is n61 4 36.383,w150 56 55.526 Slot Grid coordinates are N 2586730.377, E 331999.767 Slot local coordinates are 1248.70 S 980.03 E Reference North is True North Oil &Grc, s Cons, Col A~]chora~:le- PHILLIPS PETROLEUM COMPANY TYONEK P[atform, Sunfishfl3 North Cook Inlet,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : Sunfish fi5 Version #4 Last revised : 7-May-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 363.00 1.25 52.00 362.98 0.16 S 2.71 E 0.00 363.02 1.25 52.00 363.00 0.16 S 2.71 E 0.00 500.00 1.25 52.00 499.95 1.68 N 5.06 E 0.00 700.00 1.25 52,00 699.90 4.36 N 8.50 E 0.00 800.00 3.17 35.82 799.82 7.28 N 10.98 E 2.00 1.09 1.09 Conductor Survey Tie-In 3.80 7.75 KOP 11.47 900.00 5.15 31.94 899.56 13.33 N 14.97 E 2.00 1000.00 7.14 30.22 998.98 22.51 N 20.48 E 2.00 1100.00 9.14 29.24 1097.96 34.82 N 27.48 E 2.00 1200.00 11.14 28.61 1196.40 50.22 N 35.99 E 2.00 1300.00 13.13 28.17 1294.16 68.72 N 45.98 E 2.00 18.68 29.36 43.50 61.09 82.11 1400.00 15.13 27.85 1391.13 90.27 N 57.44 E 2.00 1500.00 17.13 27.60 1487.19 114.87 N 70.36 E 2.00 1600.00 19.13 27.40 1582.22 142.47 N 84.73 E 2.00 1700.00 21.13 27.24 1676.10 173.04 N 100.52 E 2.00 1800.00 23.13 27.10 1768.73 206.55 N 117.72 E 2.00 106.52 134.30 165.41 199.82 237.49 1900.00 25.13 26.98 1859.99 242.96 N 136.30 E 2.00 1974.90 26.62 26.91 1927.39 272.10 N 151.11 E 2.00 2000.00 26.62 26.91 1949.82 282.13 N 156.20 E 0.00 2500.00 26.62 26.91 2396.80 481.94 N 257.62 E 0.00 2615.44 26.62 26.91 2500.00 528.07 N 281.03 E 0.00 278.36 311.05 EOC 322.30 546.37 598.11 20" Csg Pt 3000.00 26.62 26.91 2843.78 681.75 N 359.03 E 0.00 3500.00 26.62 26.91 3290.76 881.56 N 460.45 E 0.00 4000.00 26.62 26.91 3737.74 1081.38 N 561.86 E 0.00 4500.00 26.62 26.91 4184.72 1281.19 N 663.28 E 0.00 5000.00 26.62 26.91 4631.69 1481.00 N 764.69 E 0.00 770.45 994.52 1218.60 1442.67 1666.75 5500.00 26.62 26.91 5078.67 1680.81 N 866.10 E 0.00 6000.00 26.62 26.91 5525.65 1880.62 N 967.52 E 0.00 6500.00 26.62 26.91 5972.63 2080.44 N 1068.93 E 0.00 7000.00 26.62 26.91 6419.61 2280.25 N 1170.35 E 0.00 7500.00 26.62 26.91 6866.59 2480.06 N 1271.76 E 0.00 1890.82 2114.90 2338.97 2563.04 2787.12 800D.O0 26.62 26.91 7313.57 2679.87 N 1373.18 E 0.00 8500.00 26.62 26.91 7760.55 2879.68 N 1474.59 E 0.00 8879.72 26.62 26.91 8100.00 3031.43 N 1551.61 E 0.00 9000.00 26.62 26.91 8207.53 3079.49 N 1576.00 E 0.00 9500.00 26.62 26.91 8654.51 3279.31 N 1677.42 E 0.00 3011.19 3235.27 3405.44 13 3/8" Csg Pt 3459.34 3683.42 10000,00 26.62 26.91 9101.49 3479.12 N 1778.83 E 0.00 10500.00 26.62 26.91 9548.46 3678.93 N 1880.25 E 0.00 11000.00 26.62 26.91 9995.44 3878.74 N 1981.66 E 0.00 11500.00 26.62 26.91 10442.42 4078.55 N 2083.08 E 0.00 12000.00 26.62 26.91 10889.40 4278.36 N 2184.49 E 0.00 3907.49 4131.57 4355.64 4579.72 4803.79 12235.58 26.62 26.91 11100.00 4372.51 N 2232.27 E 0.00 12500.00 26.62 26.91 11336.38 4478.18 N 2285.90 E 0.00 13000.00 26.62 26.91 11783.36 4677.99 N 2387.32 E 0.00 13500.00 26.62 26.91 12230.34 4877.80 N 2488.73 E 0.00 13555.55 26.62 26.91 12280.00 4900.00 N 2500.00 E 0.00 4909.37 9 5/8" Csg Pt 5027.86 5251.94 5476.01 5500.91 TARGET 14000.00 26.62 26.91 12677.32 507-/.61 N 2590.15 E 0.00 14500.00 26.62 26.91 13124.30 5277.42 N 2691.56 E 0.00 14730.10 26.62 26.91 13330.00 5369.38 N 2738.23 E 0.00 5700.09 5924.16 6027.28 TD - 7" Csg Pt AL[ data is in feet unless otherwise stated Coordinates from slot #1-6 and TVD from wellhead (132.00 Ft above mean sea level) Vertical section is from wellhead on azimuth 27.03 degrees. Declination is 0.00 degrees, Convergence is -0.84 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco PHILLIPS PETROLEUM COMPANY TYONEK Platform, Sunfish~r5 North Cook Inlet,Cook Inlet, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 2 Your ref : Sunfish ~r5 Version Last revised : 7-May-93 Co~ents in we[[path Comment 363.02 363.00 0.16 S 2.71E Conductor Survey Tie-in 700.00 699.90 4.36 N 8.50 E KOP 1974.90 1927.39 272.10 N 151.11E EOC 2615.44 2500.00 528.07 N 281.03 E 20" Csg Pt 8879.72 8100.00 3031.43 N 1551.61E 13 3/8" Csg Pt 12235.58 11100.00 4372.51N 2232.27 E 9 5/8" Csg Pt 13555.55 12280.00 4900.00 N 2500.00 E TARGET 14730.10 13330.00 5369.38 N 2738.23 E TD - 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 362.98 0.16S 2.71E 2615.44 2500.00 528.07N 281.03E 20" Csg n/a 362.98 0.16S 2.71E 8879.72 8100.00 3031.43N 1551.61E 13 3/8" Csg n/a 362.98 0.16S 2.71E 12235.58 11100.00 4372.51N 2232.27E 9 5/8" Csg n/a 362.98 0.16S 2.71E 14730.10 13330.00 5369.38N 2738.23E 7" Csg Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised SF ~r5 Vers. #4 not specified 12280.00 4900.00N 2500.00E 7-May-93 All data is in feet unless otherwise stated Coordinates from stot #1-6 and TVD from wellhead (132.00 Ft above mean sea level) Bottom hole distance is 6026.20 on azimuth 27.00 degrees from wellhead. Total Dogleg for we[lpath is 25.50 degrees. Vertical section is from wellhead on azimuth 27.03 degrees. Declination is 0.00 degrees, Convergence is -0.84 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco 12 10 --. FIGURE 10.; 0 2 4 6 8 10 12 14 16 DEPTH, THOUSAND FEET EXAMPLE OF MAXIMUM BURST CONDITION8 BASED ON MAXIMUM PORE PRESSURE i . _ 10.Z,1 Thief Surface and intermediate casin~s are rarely empby, Even with severe loss o~ c~cu~a~ion, t~e thie£ zone wiZ1 ;uppo~t a colu.qu'~ o~ mud ~o ;ome l~wl ~n the borehole. This level is called ~he thief mud level. Collapue design is based on having the internal "back up" of the mud column below the ~hie£ mud level, For design purposes, the thief mud level is the greater of 2000' or the decline specified in Figure 10-~, except where local experiance indicates that a greater drop in fluid level i9 likely. The percent fluid level decline of Figur~ 10-4 i~ based on a 0.~ psi/ft thief zone gradient wi=h the ~rop in fluid level limited to ~3~ of the total vertical depth. If Pmi < 11,5 lb/gal, then the following formula applies: (see Figure 10-5) Percen~ fluid level decline ~ 100 Percent fluid level decline = $3~ of the total vertical depth where: ~mi ' Inside mud density, lb/gal Casin~ Design 2 10-3 12/87 '---" FIGURE 10-4 ...... I I 32- 20- t8- % , x 1~o ~ FL4/IO t. EYEL DECLIIJE . MID'IT= ~EIII~II RIA, EB REGUIRE A tlIINIIIAIM ~000' FLUIO LEVEL 12- 10- 8 7 ii ii i i f I I J I t ! , , . ,i ....~.~mml~ mia_.T ..... r~.ll m immem~?a ...... ~1 e~. mm~&. ~ .... ~ ~..-- --. 9.ml~ I I I ! : , i I - i t [ , iii i i i , I I I I / I I I I I j L I / I I I ! ! I r ..... r ..... ~ ..... ~'z---~ .....T ..... ~ ..... ~ ..... ~ ..... ~ ..... ~ ..... f I I ! ./ I I ~ I I ! I I I / I I I I I I I ! ! I I/ I I I I I I ! I I/ I I I I '1 I t ...... I. ..... ~ ..... J. ..... G' ..... L ..... l. ..... - ..... ,~ ..... J ..... .I ..... -~ .... I I I ~I~ I I I I I ~ I -- I I I ~F I I [ I I I I I I I ,[1 I I I ~ I I I I I [ 4{I ! I I I ~ I I I I / I I i I I I i I I I I ~' I I I I I ~ I I I I I / / ~ I I I ! I I I I I I I / I I I I I d I I I I ~ I I I I I I I I I I ] I I I I I I I ! I I ~r I I I : I I '"""""+ ..... ~----- ~--~--4 ..... ~ .....~'~'''"i"""-'~ ..... ~1"'"""-I ....""~"'--- I I I/ I ! I I I I I I I I II i I I I I I I i I I II I I I ! I I ! I I I/ I ! I I I I I I ~ I I,/ I I I I I I I I ...... r ..... f' ..... ~t .... I- ..... F ..... ? ..... ~ ..... T ..... '~ ..... ~ ..... '~ ..... I I I! I I t I I I I I ~ I I I I ) I I ~ I ! I I I I I I I I I I ~] I I I I I ! I ! I ~1 I I I I I I I I ,. ,~ ,, i- f ..... +., i,....~.. &. -~ ..... 4 .....-~.... i. -l-&- - --fl ..... vlwllm- ..~ ..... -I--- - - I [ [ I I I I I I I f I I I j~ I I ii I I I I I ! , , / I ! ! t I I I I f ; I ! ! ; I I I I I . I I I I I I I I I I I I I I I I I I I I ! I I I I I I I I I I I I I I I , , I , ! ~ ~ I ~ ~ , I t j~ I I I I I I I I I I I I I I I I I I I I '"'~" ~ .... r ' "~-- ' ' ~ '"'~ ~ ~ ~'¢' ~'B"'~ - ! ..... ~r ..... ~1~ ~M--,i~ ..... ~- - - -- ~ ,.I ~ ,B -- -- - -i- - w ,,. ~ I II I I ! I I I I I I I Ijr I I i I I ~ I I i I tI I I I I I I I I I I I~ I I I I I I I I I I I~ J : I I I I I I I & ....+______..&~lli&.J ...../ ..... I______el~lllmll411' .... '4 .... ' Ill I "" I II "J ..... I ~ I I I I I r I I I Il t I I I I I I I I ~ I I I I I I ! I I r I I i i ~ i I I , , I . II till 8 9 I i ' ! ! ! I 10 11 12 13 L .....-4 --.. I I ! J i I 14 15 I I I I I r I i i ! ', , 16 17 18 19 INSIDE MUD DENSITY, LBS/GAL __1 .. PERCENT FLLRD LEVEL DECLINE V8 RECEIVED JUFJ 0 1 1993 MUD co.s. Commission Anchorage FIGURE 10-5 lin _. · 052 Proc INTERMEDIATE CASING "j MUD INSIDE CASING CAN DROP TO LEVEL Hll' DEPENDING UPON THE REBIEiTANCE GRADIENT OF THE THIEF ZONE. ,Omi HTi' ' PTL -' HTVD'- Hx GTZ : MUD DENSITY INSIOE CASING, LB/GAL MUD DENSITY OUTSIDE CASING, LB/GAL THIEF ZONE MUO LEVEL, FT COLLAPSE PRESSURE AT HTL, PSI TOTAL VERTICAL DEPTH, FT DISTANCE FROM THIEF ZONE MUD LEVT=I. TO TOTAL VERTICAL DEPTH, FT THIEF ZONE GRADIENT (A) HX ; GTZ HI'V9 · 052,0r~ GTZ HTVD . os; ~ . os= P., (C) PERCENT FLUID LEVEL DECLINE { G TZ/. OSZ 11 J ,o, 4 WHERE ~,.d IS LESS THAN 11.S LB/GAL, THE THIEF ZONE RESISTANCE GRADIENT, GTZ , IS TAKEN A8 0.4 PSI/FT. WHERE ~On~ IS GREATER THAN OR EOUAL TO 11, $ LB/GAL, THE THIEF ZONE MUD LEVEL' IS TAKEN TO BE 33% OF THE TOTAL VERTICAL DEPTH. ~LOST GIRCULATION ZONE RECEIVEP PERCENT FLUID LEVEL JU ,J 0 1 ]993 Alaska Oil & Gas (;or~s. (:or~)m~s~u~, DECh$NE SECTION 3 MINIMUM PERFORMANCE FORMULAS (See Section 3.4,. AP! Standard 5C3) API formulas are used for es=ablishin~ minimum performance, s~bjec~ to the exceptions noted in =he discussion thac follows. $,1 LEAK KESISTANCE Phillips does not reco~nize the API leak resistance formula as lmposln~ a definite internal pressure limitation. The leak resistance formula is ba~ed on a shrink fit equation, It is assumed that the leak resistance, limit is reached when the internal pressure reaches the pin and box contact pressure. The effects of the threads and thread dope are not considered. ~ven thou§h the API equation is the most practical one available, the results are no~ considered suffieiently reliable to use it a~ basis for a firm design limitation. The results from the Leak Resistant AFI Formula are listed at the bottom of Table ~-1 for informational purposes only, INTERNAL 3.2.1 Pipe BO~¥ Phillip~ uses ~he Barlow formula to de=ermine [he minimum performance ratine for in~ernal yield pressure, p _ 2YD D/t . . · 3,Z,l.la Bariow's formula can also be presented as the internal yield pressure a~ a percent of minimum yield strength. 2 L - D/t X 100 , . · $,2,1.1b API determines the internal yield pressure rating by usin§ the minimum wall thickness which is 87,5~ of nominal well thickness. The APZ ~3 formula ~or internal yield pressure is P - 0.875 ~ Ca,in§ Dssi§n Z ~.~/e? 3-1 12/87 TABLE 6-1-70 CASING - MINIMUM PERFORI4ANCE, PM 20 "OD PR~SS_U_REL.P_,~i ..... TEH$IQN, XO00 LBS (_KIP_&.) CASING INT~L YIELD - ' AP[- APl CRIT. Z.~AL AJ~A YIEI.~ ...... ....... eurrm.'ss3,, /LPlI PH'~'LLi'P~'COLL~SE JOIHT CRET JOINT CRIT SUPER -= ATLAS SIZE ¥&C (HXNI~H (N~XHAL RESX$- STRIHGTH,AREA STRE- AREA X (FJ) BRAD, ~___~?,T/FT GRADE NALL_...WAL.L)_.- WAL.I.) TARCE ST&CLTACIYI£LOiNaTH YIELDILINEL_~,_:_LX F~_.p._~,2! FL-4S 20 94.0 Fl-qq_,438 1530 ~7__~ .. §.~.0 ~8! - __8~_ - ....... Short Couplinq ._2,~50 2480 , , 581 .... _2P_ _~g~_,.O J-55 ,4 21i0 ,Z_410_ .520 .... ).8~ igC) 1235 1402 1480 - - ,.-- . . . ~.--- 1,06,5 ,EO0 2410 .,.2750 770 913 1056 1439 1595 1685 - -_~ - ...... 133o0 ,035 306.0 _~tagp .1490 ii92 1379i1879 2012 2125 - - . -. - ~ - _ . 169,0' ,812 3.~I0 4470 2500 '15521796 2176 2550 2272 -... ,- - . I - . Short CouplAnq ,, 3140 3420 . ,, Lonq Coupltnq., 3440 35~0 ........ ........ )utt Coup) inq 3380 ,3,550 .... ' ' · · m m 20 94,0 K-56 .488 ...... ~211(~" 2410 520 824 055 !~35 1479 1480 ...... 106,5 .500 __,1410 2750 770 960 1113 1439 1683 1685 ' . .~ .. . - I -- ..~, ~ m :133.0 .,,6,_35 3060 3490 1490 1253140), 1879 212~ 2125 ...... :I~_9.._0.*.. ,012 ~910 4470 'Z_~O_P._. ~i_I892!.~17._6_i2Q89.. 2272' "--~- - - - ' - - .__ Short Co,plinq i 52. 0 ............ . Lonq Coup1 tnq _..$~140 3530 _ Butt Coupl thoL _, ~380 35~0 .- -. ,. · --~- 2o 1_~3.0, c-_7..~i' ,635t 4170 4~0 1~00 LC0_3_~854 ~ 2[44 .... 2897 .... , - m m ~ I ~_hort Couplinq 44L0 .... ~.7_0~_-_ ........ Long Coup1 incl 4~0. 4950 .. ,_ Butt Coupl inq 40~0 4840 mi .... , ~.. 20 !133.0' ~))_0. ,~535 4450 5080 1600 .1691 /~.~jf~TJ._4._ Z0_~9....3P91 ...... ........ _.. 163,0' ,781 547.,.0~ 6~50 2770 21lZ ~4~Z 3106 ~1478 3305_ ..... · . !.Og_,_O_* ,812 5680 ._ 05~_ .... __3020 Z201 2545,3106 ~3010 3305 ..... _- 175,0' ,84.t ,,5_g00 6740 3270 2289 264713166 3728 3305 ..... _.. . ' !87.0' ,906 6340 ___7~5_0 3840 24681285455166 3728 ~3051 ...... ,. Short' Co;;pilin,q 4710 4980 . . -' '- _ "' ............... .... L o_n~_ _Co_u~ 1 in~ 6010. 5280 . ........ ., i .... Butt ¢ouDlinq .. 4gZO 5100 , , , { , , ....... ,mm ,, ...... APt Leak Resistance of Regular Coupling, J/K-5[jBd Hiqher G~ade Other 8-Round 2410 2100 Buttress 2320 2320 API *'Letter designations for this grade of casing will vary with different manufacturersD Coupl,ng ratings in this column a~, ba,e~ on inside diameter, d1. ,, E C E IV F Coupling ratings in this ~olumn are based on inside diametet, {dl-hs). API Buttress tension ratings apply to 5eel-Lock, VAH, Mannesmann BDS or Omega, and Atlas Bra~eL~jT~qaf5 except that the proprietary joints may not be as coupling limited as indicated for some heavy-w~lTe~ ~]993 tube~. Chec~ manufa¢turtr's lit~ratur~ f~r ~riti~]) arma$ of couplin]$. Alaska Oil & Gas Cons. Cemml~.ioi~ Anchorage ~[B[PRST) ~ - ~ THI ~ BU~ESS3 HY~ZJ : ' PHILLIPS~ COLL~SE ~INT "~IT ~IHTICRi~ ~[RI ATLAS SZZE TaC (~ZH~HUH (~N~ RESTS- ~RI~HO~ ~EA 5~E-:~ X (F J) UD ~[/~ G~ NALL N~L) ~ALL)__ T~CE 5T&C~C Y~ELD NGTH YIELD:L[HE ~C LX Fdp..J 6~ FL-aS ~2,0 ~4: ~aBO 6~.. 2570 1~9 -. 1423 16i0 t66t . . 12~ . 1188 . ~ ~.7. ,, ,~0~ ~ J 6940 34~ l~?O~ . 1627 165~ 1865 .... 1~60 . es.o,_ .6o~ [~q~ ~2~o ~ ]~ - t7~3~p~.29s~ .... ,~,~.L . ~,0a .GZ~ 6~01 7~ ~1~ 127.6~ . tT~ [98g 200~ .... ~16~.d .- I 96.~ .700 Zq3O 8370 _5570144q - 2992 22~S a~32 - ~ - - ., . _~,0' .7~9~, 7530 ~0 69~0 ~1 - 2049 227I ~03Z - ,T ' ' ~ ' ' 100,3' .,7~4 7~0 87~ .~.5[eO 1514 - 2079 ~293 2032 _-. - ._ 102.0~, ,743 77~ ~ 63~ 1533 - 2079 2293 203[ .... .Sho~t Coup 1 ~ 66~ 70~ ..... Cut: Coup1 ~ 6~ 68?0 ....... . ,. .. 77,0' ,6~ 5750 65~ 3~=~I~-Z' . ~1635 !1806.:1773 ,. _I . - :Z2~I , - ~,7' .~ 6070 ~0 J~.ZlBg - 1627 ItgOl ~6 - . . ~SgO - _ss,o* .~oa_,, ~o 727o ~ .~_~ .:~TnIz9~. ~5[ - -..- - [~6L, - .~ ~,0' __,625 6540 74~. =-. 41~ ~t2~ - ~17~ [2~41 2003 -,. - :~;.16:i,4 - gl.~, . ,660 69~, 7900 ~30 1~ ~. 187~ ~2149 20~T ..... ~2.5' .67~._ 7030 8~0 ;~3._,~3~4 - :lg07 21~ ,2032 - .: .. ~ .. ~_,,, .... 96,0* , .70p 7330 8370 G~]O [4~ - log2 ~2~ 12032 .. 98.0* .. ,7~9 7RgO ~_., 6~20 1~ - ~ .~3~ :203~ - - . . - 100.3* ,73~ 7~0 _ 87~ 6190 1531 - ZQ7~ 2376 2032 .... [o~.o,. .74~ ~8_~. ~ ~ ~s~ :,.zoT~ ~4~ 2o~2 .... J pl tn~ ~= 6~0 70~ ........ , I I _1 .... ~i .~_ ~ .,,._ .m. APl Leak Resistance of Regular Coupling. PSI P-IlO and Hiqher GraJe Other, a-Round 5Z20 4550 Buttress 49~0 4930 API '*Letter Uesi;nations for this grade of casing will vary with different mnufacturers Coupling rating~ in this column are based on inside diameter, d1, Coupling ratings in this column are based on inside dianmter. (dl-hs). AP[ Buttress tension ratings apply to Seal-Lock. YAM, Penresmann aDS or One, a, and Atlas Bradford except that the proprietary joints nay Aot be as coupling limited as indicated for some heavy wa)led tubes. Check manufacturer's lite.atur, far critical areas of couplln~s. [2/87 T~LE CASIHG - HINIHUM PERFORHANCE, PM 15 3/8" OD PRESSURE, P?~! l'l ~'[NSIONI 1000 CA~ING ~NT~L YIELD API API __ :RIT~CAL ~EA YIELD (BURST) _ 8RD THI:E~ RLm~t~ESS3. HY~I~ ~ PHILLIPSZ COLL~SE JOIN~ CRI) mjOIH) CR~- SU~ER ATLAS SIZE T&C {MINIMUM (N~IN~ RESIS- S~RFHGTH ~EA 'S~E-, ~EA X (FJ) B~, OD NT~T,~E WALL W~L) WALL) ?~:E 5T&C LT&C YIELD NGTH YIELD LIN6 MAC' ~ FJP 521 FL-4S 72,0 .81~ ~0~0 ~0 27~ 1142 . 1801 1797 1869 - . 1376 . 1336 - 77,0* .550 6_~P 7400 ~0 ,1Z31 - 17~6 1918 199~ - ~,7* ,~0 6~0 7810 36~ ~1305 . m1B30 E01~ 20~ - ~ - . 1653 - 85,D* .~8 7160 8180 4060 137q: - ~1927 2111 2196 .... 1~6 - __ .... 91,0' ,~0 7770 ~0 5~ 1501( - 2105 2282 2287 - - . ~,0' .700 .._~24~ 9420 ,,~ 1598~ - 2241 2413 m2287 ..... ~ . 98.Q~_. ,7~- ~70 96~ 6310 ~:' - 2305 2414 2287 - ' I ~ ' ' ~02,0' ,74~ 8750 1~ ~10 1701 - 2339 2414 2287 - ..- - .., - - . Short C~plinq _. 7520 7960 ~. .- ,. Bu~.. C~upl in~ 7~0 ~730 ............. ;13 ~/~ ~,0 C-~6 .480 5970 6820 2340 1114 - 1564 .1772 1847 - . 133~ - 1Z~9 . 22_~.., ,514 6390 7300 2830 I~Q~.-. 16go 1893 197~ - 80,7' .~0 72~0 8Z40 37~ 1375 · 1932 2125 2215 .... 1639 - ~.0'..,,.. ...... ,608 7560 ~0 41~.~ - 2034 2222 23~7__ ~ .... 1738 - ~.0' ...... 625 7770 ~ 443Q X~Z - 209~ 2281 2378 .... ~798 . - 92.5* .672 8~)Q_.~ 9~_5D ~450 ~1613 - 22~5 2444 2414 ...... 9~,0' .700 8700 99q0 6070 1685 - 2)65 2834 2~14 ...... gS,0* .~19 8~0 10210 64~ 1733 - ~433 2~34 E414 - - - ..%._ - . 31~.3' .734. gl~9 ...... ~0~30 ~20 177I - 2469 26)4 ~2414 - - .,-, - - . ~02,0' ,743 9240 105~ 7020 1794 - 2409 253~ 24~4 ...... Short C~plinq 7940 ~10 ..... - ~ ...... API Leak Resistance of Regular Coupling, PSI P-llO and Htqher Grade Other 8-Round 5220 Buttress 4930 4g~O *Non API **Letter designations for thts grade of casing wtll vary with different manufacturers1, Coupling ratings in this colun~ are based on inside diameter, d 2. Coupling ratings in this colum~ are b~sed on inside diameter, 3, API Buttress tension ratings apply to Seal-Lock, YAM, Mannesmann BDS or Omega, and Atlas Bradford TC 4-S except that the proprietary joints may not be as coupling limited as indicated for some heavy walled tubes, Check manufacturer's literature fo~ c~ittcal area~ of couplings. 12/87 TABLE 5-1-42 CASING - HIN~M PERFORI4A,NCE, PH . , , g 6/8 " O0 , PRESSIJRE, PSI- TENSION. [OQ~LBS CASING [NTF. flNAL YIELD ~ APl .... ~ ~iRIT~ ~EA YIELO~ ~I1 PHILLIPSg COLL~SE ~I~ ;mit ~INT CR[T SUPER ATL~ SIZE T&C (HINI~M (N~INA~ RESIn- ~~EA S~E- ~EA X (FJ) B~. _~ WT/~ ~E W~L W~L) )~L) T~CE ST&~.~IELD NGTH myIE~ LINE ~C LX PiP 5~[ FL-4S ,, 43,5 .4).~ ~)30 72)0 ,, ~810 - 813 8~ ~0~ 10~ 8~ - 74B 570 7]0 ,660 47.0 .472 ~70 )~0 4760 ,, - 893 g/6 1122 10~ 859 782 822 628 ~9 -, 53,5 ,546 .,.Tg~ 9~0 66~0 - 1047 1072 1~85 1244 g~ gQ~ g~ 7~ ~1 809,, _68,4' ,5gS ~., g8~O ~0 - ZiT[ 1179 [~ ~_ - - .~. .... 5g.4' ..... .~9 ~ 1~20 8250 - 1180 1~q9 ,1426 13~ - ZOO3 .... ~,,9' ,d72 9770 .. ~1170 g~O - 1~9 ~1 1563 1~ - ~70 . 70,3' ,~34 1~,~ [2200 1~270-, - 143}1146g-1166g 1~0 ~ 1281 ' ' 71.8' ..~0~ .~10 12470 ~0 1465 1502 1669 ~ .,- - -,,, - - , Butt C~]~q ~.,, ~300 ,. . ...... 4~,5 .4~6~6110 7230 ~610 - ,.~5 8~__m1074 1005 821 ' .=_745 570 7~0 550 47,0 ,472~~. 7850 4760 ' 90~ ~. ~151 10~ 869 76~ 8ZZ 626 ~ -- . ,-- 5~.5 .546 7~.. 9060 6620 ' ~ ~ ~9 I244 9~ 9~ 954 71~ 9}1 8~ 56,4* ,695 ~50 9890 7~0 ' 1167 1179 1~ 1~ .... , - ' 59,4* .609 ~ ~0120 8250 ' l~fl 1209 1475 1~80 ' l~l. ' ' ~ ' 5~,1' ,62~' 90~ ~0390 8660 ' 1230 12_~ ~6~1 14~4 ' ' ..' ' ' ' ..... 64.9* ,672 9770 11170 9~0 ' 1527 ~l ~615 1~0 -- 1170 .... -- -- ' -, .. 70.~* .73~ ~06~ 12200 11270 ~ ~}4 1469 1753 14~ ' 1~81 ' ' ,,-- ' 71,8' , .~,lOglO 12470 11~00 -- ~486 1502 ~767,,,]4~ ..... .... 75,~* ~797~ 1159Q,.. 13250 1Z160 ' 1~1 1~9~ ~757 14~ ' 1405 ,..-- -- ' - go~ Couplinq ~30 t0160 ....... _. eu~t Coupling ~30 g3qo ....... APl L~ak Resistance of Regular Coupling, PSI ~?llO and Hi~her Grade Other 8-Round gTlO Buttress glO0 gl60 *Non APl **Letter designations for this Grade of casing will vary with different ~anufacturers ~. Coupling ratings (n this colu~ are based on inside die.tar, d1. 2, Coupling ratings in this colum are bas~ on inside dtan~ter, 3, ~I Buttress tension ratings apply to Seal-L~ko VA.M, Mannesmnn BDS or Or. ga, a~ Atlas Bradford TC 4-S except that the proprietary Joints my not be ms c~pling limited as indicated for s~ heavy wall~ tuUes, Check ~nufactu~er's lltera~ for critical areas of c~plt~s. TABLE 5-1-22 CASING . MINIMUM PERFOrmANCE, PM 7 "00 , PR~$UREf P.~;! ... TENSION, ,IO00 tjt~5 (KI_P_$) i . i C~ZNG )N~ER~L Y~ELD APl API .~RJTZCAL ~A .~[ELD -. , (BIIRST) ~ ~1 .E~ BU~I',E}S3 H~ll ' ~Z[ PH[LLZPS;!COL~SE ~l~ CRZT JOINT CRIT sUpER ATLAS SIZE T&C (MINIHUM (N~[N~ RESIS- ,,STRENGTH ~EA S~E- ~EA X (FO) _7 EL0 C-7~ .~? ~940 6790 3~ = 41~ S~_ 55~- 49~ 49'~ - 362 {2~6) 34)"- _ Z~,O ,.~Z ~790 7760 .... 5ZZO - ~.4~ 4.50 631 566.__ 5~ _' 420 323 .406 386 29,0 ,408~ ~650 8740 6730 - ~Q2 517 707 6~. 641 - 48~ ~76 471 40~'- ~2.0 _. ,4~ ~.qO 9~ 8200 - ~_se2 779 692 60z 5]~, 556 4.~ ~ 442 35.0 ,49~ 9~0 10~70 9670 .- 703 647 833 ~gZ 671 571, 6~ 434 597 48a 3~,0 .~O 101aO Z4.570 10~0 _: 767 706 8~3 ._~92 724 ~28 66~. 493 ~54 ~2[. . ,, 41,0' ,590 110~ 12~0 I1~ - ~2 751 .~. 692 - 690 2~ 493 - 42.~. .62f 11720 13390 , 1~00 - ~4 ,~pI 8~3 69i - 73~ . ~ . . ~,o' ~0 12000 ~710 12460 -. 904 751 833 8~ ...... 46.0', ,670.1Z,5~ 14360 ..12~ - 904 75L 833 692 - 778 - 611 - 653 j9,5' ,73~ 136~ 15~!~ 1~10 - .~4; 751 833 692 - 851 - 63Q - 693 .. Lo~ C~u~J tnq ~ --~ ii i i i .,, Gutt C~plt~ 7930 8S~,_ ._. _ ~ l, ~t i .. ,_~ ~ -._ 2e.q .~2 7z40 8270 .... 5~0 - i~ 4~ .... ~ 60~ ~40' - 448 344 ~13 gg,o ,4~ 81~ 9330 7030 ,; ~7 552 7]8 87~ 577 - 517 40L 503 t27 32,0 ,453 g060 Z0350 8~0 - 66~ eZZ 7~z 7~.. 64~ 8;7 593 457 570 ~.. ,4~ gg~ ~ ~O~gO - 734 690 8~ 7~,, 716 609 652 463 63~ .. ~8,0 _,540 1~_ 123~0 11~90 .- ~1 753 833 7~ 772 670 712 5~ 698 ,. 4~,o, ,.~o 1~8~ z3~9o ~23~._ .- ~o ~ 8~ ~ - 7~_ 7~1 5~ - 605 42,7* ,625, ~25~: 14ZgO ~30t~ - ~4 80~ 833 ,.7~ . 785 . . . -'. , 46.0* .,,620 ~34~ 153~0 ~ - 904 ~ 8~ ~ - 8~ - 6.~2 - 697 __. 49,5. ,730 146~o 16690 ,,~4950 - ~4 801 8~3 738 - 908 - 6~ - 739 ._ Lonq C~1 inq .9240 9~0 Butt Couplinq 84~ 9110 . , ,, . , APl Leak Resistance of Regu]ar Coupling, PSI 8-Round 9520 Buttress 11790 *Non APl **Letter designations for this grade of casing will vary with different manufacturers 1. Coupling ratings in this colun~ are based on inside diameter, d1. Z. Coupling ratings in this colum~ are based on inside diameter, {dZ-hS). 3, AP[ Buttress tension ratings apply to Seal-Lock, VAH, F(annesmann BD~ or Omega, and At)as Bradford TC 4-S except that the proprietary joints may not be as coup)lng limited as i~tcated for'some'heavY wa)led tubes. Check manufacturer's literature for critical areas of couplings. / 12._ ! L-d~? Page 1 SUN_F~3.XL$ State: Alaska Borough: Well: Sunfish #3 Field: N.C,I. Unit St. Permit 93-76 Date 6/2/93 Engr: M. Minder Casing Interval Interval Size Bottom Top lA 30 407 55 2A 20 2500 55 3A 13.375 3900 55 4A 13.375 8100 55 5A 9.625 12095 55 6A 7 13350 10750 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Description ascription Tension Length Lbs Grade Thread Lbs 350 457 B Weld 0 2545 169 K-55 C-60 0 8845 72 N-80 BTC 0 5000 72 0-95 BTC $60000 12095 53.5 L-80 BTC 0 2950 32 L-80 8TC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ascription lB 219 3B 4B 519 6B 7B 8B 9B 10B Mud Hydrolytic Collapse Wieght Gradient Gradient ppg psi/It psi,/ft 9.2 0.478 0.378 10.0 0.520 0.420 I 0.0 0.520 0.420 10.0 0.520 0.420 12.0 0.624 0.524 15.0 0.780 0.680 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Cataloged psi Yield BDF 0N/A 1925 3400 1.8 2492 4930 2.0 2492 4930 2.0 3351 7930 2L4 3351 8460 2.$ 0 o #DIV/OI. 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/O.I 1C 2C 3C 4.C: 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs K/Lbs TDF 159.95 0 N/A 430.105 2689 6.25 276.84 1661 6.00 360 1893 5.26 647.083 1244 1.92 94.4 745 7.89 0 0 #DIV/OI 0 0 #DIVlO.i 0 0 #DIV/0.1 0 0 #DIV/O! Collapse Collapse Pr-Bot-Psi Resist. CDF 154 0 N/A 1050 2500 2.381 1638 2670 1.630 3402 2820 6338 6620 1.045 9078 8600 0.947 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 # DIV/O.I SFtI3CIviT.XLS State: Well: Field: State Permit .4b~a Sunfish #3 N.C.I. Unit 93-76 ER~ReeE Work S beet: Date: Cement Volume Calcdalion,~ 5/28/93 Ca~g Type Casing Size -inc~s Ca~g LenCh - Fee[ Hole Diarnete~ -Inches Cement- Sacks 111 Cement-Yield111 Cemer~ - Cdoic ft 111 Cement- Cubic tt ti1 Cement- Sacks 112 Cement- Y'~,ld 112 CemenI - Cubic ft 112 Cement- Cubic It 112 Cement-Sacks113 Cement-Y~d 113 Cement-Cubic ft ti3 Cement-Cubic it 113 Cement- Cubic it / Vol Cement- Fill Factor Cor~luct°r 0.000 0.000 0.000 11000 0.000 0.000 0.000 0.000 0.000 11000 11000 0.000 11.DIV/O! Sudace 20.000 2,545.000 24.000 2,000.000 2.110 4,220.000 4,220.000 650.000 1.160 754.D00 754. D08 O. O00 0.000 0.000 0.000 4,974.000 2.036 Liner 7.000 2,950.000 8.500 GO0. O00 1.160 GgG. O00 696.000 D. ODD O. OOO 0.000 0.000 696.000 1.861 Casing Type Casing Size -Inches Casing Depth- Fee[ Hole Diame[e~ -Inches Cemer¢: - Sacks 111 Cemer~ - Cubic ~t111 Cement-Cubic ft 111 Cement- Sacks 112 Cement- Yield 112 Cement-Cubic fl 112 Cement-Cubic it 112 Cement- Sacks 113 Cement-Y'~,ld 113 Cement- Cubic fl 113 Cement- Cubic ft ti3 Cement- Cubic It / Vol Cement-Interval ~I Top of Cement- Feet inte~mediate 111 0.000 0.000 11000 1100 0.00 1100 0.00 1100 0.00 1100 0.00 0.00 0.00 0.00 0.00 0.00 11DIVtO! I~DIV/O! Intermediate 112 13.375 8,900.000 17.500 1,000.00 2.10 2,100.00 2,100.00 1,G00.00 1.18 1,85600 1,858.00 3,700.00 1.17 4,329.00 4,329.00 8,285.00 11,927.31 -3,027.3 Production 9.625 12,150.000 12.250 650.00 1.16 754.00 754.00 0.00 0.00 0.00 1100 1100 0.00 0.00 0.00 754.00 2,407.55 9,742.5 Measured Depth ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru '8-~]TM [9 thru 13] (4) Casg [10 & 13] [14 thru 22] (5) BOPE [23' thru 28] (6) Other ~r 1~_~//~.._, '~2~ thru' 31] ' Company, 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4 Is well located proper distance from other wells ..................... 5 Is sufficient und~dicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ (7) Contact (8) Addl [32] 9~ 10. 11. 12. 13. 14. 15 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30 31 32. 33 geology' engineering: In TA~~/~ rev 6~93 jo/6.011 Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL[nber appropriate .......................................... Does well have a unique name & nL~nber ................................ Is conductor string provided ....................................... Will surface casing protect a~i zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STP~ATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly p~ogress data ...... Additional requirements ............................................. INITIAL GEOL I UNIT ON/OFF POOL CLASS STATUS AREAI f. SHORE Additional remarks: MERIDIAN' UM WELL TYPE' Exp~~' In j_, SM 7x,, Red r i 1 1__ Rev--,, ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 2 ) .,L, 0c ~./~C"_- ~ 2. [2 thru 8] 3. 4. . 6. 7 8 (3) Admin ~/~ ~./?A~ 9. ~'.C~(' ~'¢~-".~ 11. [10 & 13] 12. (4) Casg ~-2-?~ 14. [14 thru 22] 15. (5) BOPE /~. ~, ¢~,,//. ~.t& ~ ¢~ . [23 thru 28] [29 thrd '3i3 (7) Contact enDineering: MTM~//¢, RAD ~-~ BEW JDH,~.~~ ~ '-%? ~. geology' DWJ RPC.~. rev 12/92 jo/6.011 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Company YES Is permit fee attached ............................................... /~,,. Is well to be located in a defined pool .............................. Is we]] located proper distance from property line ................... Is well located 'proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... ~_ Is operator the only affected party .................................. Can permit be approved before 15-day wait Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... --~ Does well have a unique name @ nLrnber ................................ Is conductor string provided ..................................... ,... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on~ surface ............ Will cement tie in surface g intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel ]bore separation proposed ............................. ~ Is a diverter system required ........................................ //~ Is drilling fluid program schematic & list of equipment adequate ..... ,~ Are necessary diagrams & descriptions of diverter & BOPE attached .... /~// Does BOPE have sufficient pressure rating -- test to %¢~¢¢¢~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... -/ NO FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... ,. Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... ~/,.,~ ~,~'~ Name and phone ngrnber of contact to supply weekly progress data ...... t~. Additional requirements -- ,, / ' / Additional remarks' _ Redrill Rev 0 INITIAL GEOL UNIT ON/OFF POOL CbASS STATUS AREA ~ SHORE ,F / ' ' UN // i ...... '-" - MERIDTAFJ: SM ~ TYPE: Exp/Dev Inj . 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. Tame veri~ication List!n~ ;cbl~mberqer a!as~a Compute, DC Center 31-~aR-1994 12:P5 94103/31 PHILLIPS P~T~[tI, EIIM CO., NCIO SUNFISH ~3, lPI 50-883-~009o **** TAPE H EAD~;]R **** D ~, ',l'.' P = 94/03/31 OPI~IM : ~LIC T~PF Na.~.-~E : ~4120 PPEVI, OU8 TAPE CO~E~T ~ PH!bI,,!PS PE[TDf]I:.E~IM CO,, ~CIU St, INPISa ~3, API 50-883-20090 ,NCIU 6U~5i'FISH #3 5688320090 D!!IL!,IP8 PETF~OI, i;I.IM COaPAMY SCHbt!MBERGER i~Eb[,, SERVICerS 30-a,h,a-94 ?ND ST~I~IG 6 9W 1249 132.00 13i.00 ODE:I ttOl:El C~,SING DRiL!,ER8 STZK fID.~) SIZE (iN) DFCPT}-t (PT) ....... .... 750 I 3,375 ~g09.0 P AG~.;: ,',IS Tape Verification I.,ist!no, ;chlUmherger ,AlasKa Computinq Cent, er 31, -~i~-1.. 994 1,2:25 ~RD STRING ~.500 9,625 ~E~!ARKS: THI. g TS $ 1 ~ 1.34.0 13939,0 PAGE FT[.,F: }~E : EDIT V~RSION : OOJCOj, FTLF TYPE : [.,0 LIST F I I,.,E : F ~ L E ~: U ~i B E R: 1 I!1 tOO1 strin~sI De~th Shl,,~t. ed D ~ P T H 'I N C ~ E ~,~ E ~ T: n, 5 0 0 0 F ! L E $ U ~,~ ~ A R Y ~AS 1463~.n 9TE ~. 4670.0 ~g" .. , .. ,,iT 14~4n. 0 and clipped curves; all, runs merqed; STOP DF, PTH 260 2 260~,0 260~. ('.) 260~.0 121.40.0 .......... ~OUIVA!,E;HT P, ASET,INE I-)~ PT H ,~D~ CNTH 14~05.5 ~ 4a()~.5 ~4603.5 !4595.0 !4~9J.R 1.459!.5 14591,0 !45g~,5 14570,0 ~457.~.o !457~,~ !4~62,5 ~4550.5 14550.5 ~453~,5 14537.c 14537.0 1453o,~ 1452a.5 1452~,5 ~451a,0 14517,0 ~4517.0 ~4~04.0 !4504.0 !4504.~ ~44.76.C !4a-7~.5 14476.5 ~4a56.% 14456.~ 14456.0 ~4,~2!.o !4a27.5 1436P.0 !436~.~ !436~.5 !,434~.~ !4,34P.5 ( 'i342.5 !431! ,5 1.431~.0 no cased hole data, TaPe Verification Li. stins ;cblumberger ~.!,as~:a Co~put:!mg Center ~.4~50,0 1. 4263,0 ,I ,'1254,. 5 1 4757 o 5 4.4747.5 !, 4747,5 4 236,5 ~ 4,236.5 . 4~26,0 14~27,5 1. 4e 7o. s !3966,0 13966,0 ! 3027,5 13927,0 ,3917.o gl7.s 1377610 13775,0 ~ 375~, 5 ~ 3758,0 ~, 3738, ~ ~ 3736,0 ~ 372:1,0 13721.5 ~3714,5 ~3715.o ~. 3700, o !. 3700,0 ! 3651,5 13649,5 ~ 3630.5 ! 3605.0 13602,a 1.358Q,5 13596,0 ~ 3585,0 !35~ ,o 1 3~80.0 t, 3574,5 13{6g.5 ~3566.5 ~.3525,5 ! 392~{.0 ~3510,5 ~3497.5 ~349~.5 1346S, 5 ! 346.!, 5 !.3a41,5 !.3a4!,0 13434,~ !3434,0 !.3380.n 1338~,~ 1 338J ,0 ~.3390.0 ~ 3365.5 ~. 336'~. 5 13358.0 13355,5 ~3340,0 13339,5 ~.3314.,0 13313,5 ~.3~9a,0 ~3~93,5 ! 3770,5 13270,0 !3~40.0 ~3~40,5 1 3234,5 !3734,~ ~372~.~ 13227.~ 13176,0 13175.5 I 3~.59,5 t315~.n !3~37.5 ~3!.37.5 ~ 3o9~. 5 ! 3o98.0 ~,4263,0 14~57.5 !4P36,~ ~409t,'~ ~4027.5 !40.15 5 ~3927.0 139~7,5 13916 0 ~3775' 1, 375~' 0 .0 1374~,.5 13736,0 1372~..5 !3715.0 13700,0 1364~,5 ~,3628.0 13602.0 ~3586,0 1358~..0 1357~.5 13566.5 ~3524,0 ~3491.5 ~346~,5 1344~.0 ~343~.0 ~338~.5 13~63.5 13355,5 13~3~,5 ~3~13.5 ~3770,0 ~3~7.5 ~3~75.~ ~3~46.5 13~37.5 !3126.~ ~ 3098.0 13775.0 13758,0 13744,5 13736.0 1 .~ 72 ~ 5 1371,~.. :0 13700,0 1.3649,5 1362~,0 13586,0 !3581.0 ~3574,5 13566,5 !.35~a,0 ~350~.0 1349~,5 13485.0 13~64,5 13441,0 13434.0 13a23.0 13anl. O ~3380o0 ~3363,~ ~3355,5 ~3330.5 ~3313.$ 13~?0.0 13~40.5 13~34,5 13227.5 ~3~75,5 ~3158.0 13~37.5 ~3~26,5 ~309~.9 ,IS ?abe Ver!fi,,catl, on .[.,ist:!no ;chlu. m~erger Al, asKs Comput,i,r~q Ccitt:er t2:2.5 PAGE: 130'73,n 13072.0 1303!,5 13037.5 ~3015.~ ! 30(15.5 ! 3005.0 1 2994,0 12993,0 t 2951,0 1 ~50.5 1~921,0 !.2921,0 . ~ · 2 5o.5 12 50.o ~2~33,$ ..2913,0 12911.5 !277~,0 !.2776.5 12761,0 12760.0 !271~,o !~7:11,0 12686,5 !,,26[~6,0 1265'8,5 !265~,0 12630.0 12638,5 !2626,5 125g?,0 12g~6.5 12566.0 !.2565,g 12g4n,O !2539,q 12524,5 1252.4o0 12519.5 !2519,5 ~2504.5 !2504.0 l~dgg,o ~2,497.5 !240~.0 !240!.0 12393.0 !239~.~ ~2~83.5 ~371.0 !2369.5 !235~.5 1235a.5 ~2347.5 12346.0 !~320.5 !~330.~ ~.2307.5 !2296.0 !2~9~.~ 127a0.0 12289.5 12277.0 ~227~.R ~226~.5 ~226~.5 ~2245.0 !2245.n ~2737 n 12237.o 1~19~.n 12~47.g ~2!47.o !2!!o.5 !.2~.0 ~ 207~.g ~ 2075.0 !20~g.5 12045.o !2017.5 llQbT.0 13072,0 1,3037.5 13013.0 1,3005,0 1,2993.:0 12950.5 1292~,0 !289~.5 12870 0 ! 2.5o: o J2~33.0 12g1!,5 12776,5 12760,0 12711,0 12686.0 !265~,0 12638,5 12626,0 125~6.5 1~565,5 12539,0 1251g,5 1250a..0 12497.5 12397.5 !23~3,0 !2369,5 !235e.5 1234~,0 ~2330.5 12315,0 !230~.5 12296.0 !2~89.5 !227~,5 !2~37.0 !27~5.n ~2~47.0 ~2!~.5 ~2075.0 ~2045.¢? ~20~P.5 1~970.~ !195!,5 12075.0 ~201g.5 J19b~.5 1195a.5 11951,5 1..3072 0 ~303715 13013,0 13005.0 1...2~50 5 12898.5 12850.0 12833.0 12~18.5 1.2811,5 1.2776 5 12760 0 12711 0 12686 0 !265R O 12638.5 1.2~26,0 J2586.5 12565,5 1253'~ 0 !2524~0 1251q.5 !2504,0 12497.5 12449.0 12401,0 ~2392,5 12383,0 1236~.5 1235~,5 12346,0 12330.~ 12315,0 12304.5 1229~,0 12280,5 12276.5 12~65.~ 12245,0 12737.0 12215,0 ~2147.0 J211.9,5 12111.0 ,IS Tane Verifi. cat,~r.:r: Llst:i, nc: ;ch,l, umberqer A].a$1Ka Comput,!,no Center PAGEI 1.1~62.5 1J,. R 30.,~ .1. 1, ~ 31, ,, 0 !: ~781 ,5 11781 ~ 1746,~ ~.1746, ~. 168~.0 1168~,5 . t665,5 !~66~ 5 o tls4 .o t 5o9.o ~ l, 49,¢, 0 1. t494., 5 ~. I, 461.0 !, ~. d, 6~. 5 ~, 1421,5 !, 1422,0 . l ,to.5 ,41o.5 ~ 1378,0 ~1330,5 1 1321,0 !1321 t 1307.0 ! i 307, O ! 1277,C ~1277,5 11255,5 11214,5 !0966,0 !0a64..5 ~ 0~51_.5 ~ 0940.5 10945. K 10P61 .5 !.096n.5 ~.0779.0 ~0777.0 ~0760,5 !0767,5 1O762,5 !07~2.5 ~0732.K 10730,5 ~0726.5 ! 0726.0 t. 1 9 5 11S63,0 !.1781,5 ~.1746,5 11.721,5 1.1694,0 11665,5 ~1634,5 11581,5 1155~ o ~1494,5 11461,5 ~1378,5 ~. 134R 0 1.1347;0 ~1330,0 11321,5 11307,0 11277,5 !1~65,K ~.1255,0 ¢1213,0 11183,0 1.1140,0 ~.110~,0 ~-1057,5 ~ 0964.5 J 0Q49.5 .1 (.)~44.5 !0P87.5 t0~60.5 10777.0 10767.5 ~0762,5 ~.0730.5 ~.07~6,0 i 1923 o 5 .,!1 ,~63.0 11,9 31 o 0 11919.0 11~'03.5 {. 1746 5 ~.1694,0 11682,5 J.. 1634;5 11533,5 ~ 1518,0 1150~,0 ! 1494.5 11461.,5 I I452,0 ~1.410.5 ~.1378,5 11330,0 ~1307.0 ! 1294,0 q1777,5 ~1~55.0 !1183~0 1 1.105?.5 11045.5 1u9~4.5 1004~. 5 ! 09~.~.. 5 !()q23,~ I O887.5 ~0860,5 ~0777,0 ~0767.5 10762.5 ~0730,~ 10726,0 ;c~lumberqor AlasKa Co,Put.ina Center 31 -~(AR-!994 PAGE: 0707 o 5 !. 0707,0 0682.5 10680,0 067 6,0 0557, 0544,5 1.054~, 5 0527,0 ! (')52.~!, 0 0508,n ~0507,5 0462.0 10~60.5 i, 0~56,5 ~ 0456.0 1032.4. ~ 0300.0 ~.0~76,0 10~72,0 ~ 0269,5 '! 0266,0 0~5~,0 ~ 0~20,5 10219.5 ! 01.73,5 !0174,5 ~ 01.66,0 10166,0 ~0!51.5 ~0~49,0 ! 0131 ,0 ! 0026,0 ~. 002,~,, 5 99q0,5 9999,0 9979,~ 9077,0 9054,0 9953,0 9R7 3,5 9~73.0 9~ 36.0 9~35,5 OR31 .5 9~30.5 97B~.g 9787.0 9761,.5 9760.0 9725, O 9724.0 9683,0 9684.,5 9673 9~54.5 9611 ,5 9610,5 9603,5 960~,5 9570,5 957{~' K 957 ~ Q56~ .5 9561.0 9539.m 9536.0 9509 9~95.~ 949a'5 946~.5 9~69'0 9404. o 9407.5 9~76,o 9350.0 q34~.0 934?.0 9340.5 10707,0 10675.0 ~. 0644.0 1,0639.0 ! O557.5 ~0543,5 10524,0 ~0507.5 !.0474.5 !.0460'5 ~.0456,0 . 5 ~0323, 10300,5 ~,0~7~.0 ~.0~5~.,0 1021~.5 ~,0~90.5 1()~ 8~,0 ~o16~.0 10!,69.0 ~0130.0 10078.5 10O24.5 999~.0 9977.0 9953.0 9973:0 9935,5 9787,0 9760 0 g724[0 968g,~ 968~,5 967~..5 9610.5 9602.5 g57~,5 9561.0 95]6.0 9507.0 949~.5 9~81.0 9~69,0 9402,5 9~7~.,5 107D7,0 10675.0 10639,0 1,0557,5 1.0543,5 1052~,0 104 .,5 0460,5 1.0~56.0 1032~.5 10300,5 10266,0 1025:1.0 10~90.5 101.84.0 10174,5 1,0166.0 10140.0 10130.0 10078,5 !00~4 5 99 9977'0 995~,0 994~.0 9£73.0 9P35.5 9930 5 97~7~0 976~.,0 9724,0 96~9,5 96~.5 9671.5 9653.5 9610.5 960~,5 9576.g 95~g.5 9561,n 9536.0 9507.0 949~.5 9~81..0 943~.a 9a02.5 9374.5 934~.0 .;IS Ta~e veri. f,i. cation h~stina ;chlumherqer Alaska Cor, pt.,,t~nr~ Center PAGE: 9'316.5 93,t. 7.0 9310,0 9313.5 9297,0 9?95.5 9~67,0 9267,0 9245,0 9?46.0 9200,0 9!.9~,0 9~67.5 9~.67,0 9J44,0 9!44,0 909a,0 909g,0 905~,0 9058,5 9045,0 9043,0 . 26.6 8~25,n 8~05,5 8770.5 8770,0 8732,5 $731,5 8710,0 87¢i)9,5 8707.0 8707,0 868~,0 '8688,0 R662,0 8661,5 8655,5 8655,5 8627.5 8627.0 8607,5 8606,0 8603,0 960J,0 8592,0 8592°0 8570,0 ~562.a ~550,g ~55n.0 ~520.n ~52~.5 851~.5 851a.0 8507.0 ~490.5 8492,~ S486,5 ~87.0 8~8~.0 8a5~.5 8~.3¢.0 8434.5 8424.5 ~25.0 839g.n 8~9g.0 ~32~.0 8220.5 822o.~ 8204.5 R204.0 9317.0 9313'5 9295.5 9367,o 9246,0 9199,0 9!67,0 9~,44,0 9094.0 9058,5 9043 0 903.4,0 9019,5 9013'0 8964,5 8925,5 ~2,~,,6 8~95.5 8~ 0.0 25,0"~04,~ 8770,0 8731,5 8709,5 8707.0 8688,0 8661.5 8655.5 8627.0 8606.0 860~,0 8592,0 857e.0 8563,¢~ 8550,0 8528,5 8514.n 85O6.5 84.97,n 8a87.0 8481.0 8452.0 8a3~.5 ~425,0 8~98.0 836~.5 8]27.5 8325.0 829~.0 8260.5 8720.~ ~21.0.5 8~04.o ~!97.0 9317.0 9313.5 9295.5 92~7,0 9246.0 9199,0 9167.o 9J. 4A,O 909~,0 9058.5 9043,0 903~.0 9019,5 901,3.0 8964,5 8925,5 8924,0 8~95,5 8888.~ 8~70,0 8825,0 8~04.5 8770,0 87~ 5 8707,0 8688,0 866~,5 8655.5 8627.~ 8606.0 8601,0 8592,0 8570,0 85~3.0 8550.0 852~.5 8514.0 850~.~ 8.492.0 8487.0 8481,0 8~5~.0 8434.5 8425.0 839~.e 8327.5 8325.0 ~295.n 8260.5 8~20.5 ~?04.0 8192,0 ,,IS '?a~e Veri. ficat,]..on !..istino lchl~mberger ~.!..~asaa Com[~uti. no Center 3.t.-~A~-~. 994 12:25 81.10,5 8!:1.1,5 811!,5 8087,0 8088,0 808~,0 8n64,0 ~062,5 8062,5 805~,0 8n50,5 8050,5 8010.6 8017,5 92~,0 702~,0 792~,0 7~90,0 7898,5 7898.5 7~34on 7832.5 7796,0 7796.5 7796,5 776.5.5 7765,0 7765,0 773~,0 773~,5 7736,~ 7725.5 7725.0 7725,0 771.~,0 771~.0 7715,0 767 .0 767g'5 7678.5 7650.[ 765g.0 765g.0 7647,~ 76~,0.0 7640,0 7635,~ 76,34.5 7634.5 762!,o 76(39., 755g'5 7~50 n 7550 7552, , 5~ , 75~3,n 754~,5 7"~ 75i6,~ 7515o5 75].5,5 75'15.n 7~1~.5 7~l.~.5 7503,0 7502.0 7502,0 7474.K 7~73,5 7466,5 7465.0 7465,9 7457 {3 'I~5~ ... O.5 7456,~ 7416.0 7a~,5.0 74~5,0 7980.0 737Q.~ 7~7~.5 7~62.0 736?.0 7340.0 7~49,5 714~,5 732~,5 7~2~.0 712~. 731g.g 731.~.5 7319.5 7312.5 7¢1.?.5 7~12.5 7~6,n 7~86,5 7~71,% 727~.0 7~'73. 7756,5 7~57.5 7?57,5 722g,5 777~.0 7!96.5 7195.0 7195.0 717~,5 7!7!.5 7!7~.K 7~70.0 71b~.5 7~ 68.5 7~3~.~ 7t ~0.0 713o.0 7~04.5 7103.g 7096.5 7096.5 7096.5 704~.5 7n4~,0 704~.0 7034,.5 7n3~.0 7033.0 702~.0 702n.5 702g.$ 701,~.0 701¢,5 81.51.5 8t, 39,5 8119,5 8111.5 80~8.0 8062,5 8050,5 8017,5 8006.0 7~9~.5 783~.5 7796,5 7765.0 7736.5 7725.0 77~5 0 7640,0 763~,5 7621.0 76C8'0 7564.5 755~.0 7550.5 75~2.5 7515,5 751~,5 7507.0 747~.5 '1465.0 7456,5 7~15,0 7~79.5 7340.5 732!.0 7310.5 7312.5 7~6,5 797~,~ 7~57.5 7~28,0 7195.0 7171,5 7168.5 7130.0 7!03.5 7096.5 708~.0 7o41.0 7033.0 702~.~ 7014.5 ~IS Tape ver.t.,t!cat~.on Lj,,stinq ~cbl,mberqer Alaska Com~ut(n~ Ce~t~.r 699R.5 6998.5 6998,5 6¢~1S ~, 5 6g~i 7.0 6987, ~95~,5 695:2,0 6~59,0 94'3,0 6~42.5 6942.5 6026.5 6925.5 ~925,5 6~98"0 6~97,0 6~97.0 6~57,0 6~57,0 6~57.0 6~46,5 6~47,0 9~29 5 6~3~.0 6766, :~ 67&~, 5 6766. % 676~,0 6765,0 6765,0 6753,0 6754.0 6754,0 6692,5 6&93,5 669~,5 6571,5 6573.0 6573.0 652~,5 6530.5 6530,5 6475.5 6477,0 6477. n O 6467, n 6466,0 6467. 6~37:0 6a37.5 6373.5 6373,5 6373.5 6369,~ 636a 5 6.'36~,~ 6360.0 6160~5 ~360,5 633~,0 6334,0 6334.,0 6 o .o 6 o .5 63o .5 6~77.5 6~7~.0 0279.0 6~6~,5 6~69.0 6258.5 6260.0 6~bO.0 621~,0 6213,5 6~1.3.5 6993.5 6987,0 6980.0 6952.0 6942'5 6925.5 6~97.0 6957 0 6a47;0 6831.,9 6782 0 6766 5 6765 0 6754 O 6693 5 6573.0 6530.5 6477.0 b467.0 6437.5 6 3 '6 9.5 6360.5 6308,5 627g,~ 6~60.0 6~.77,0 6129.5 12:25 PAGE: 9 T~!~.,E; TYPE T~I~ T VALU DEFI II I II ~II I I i I I I m I I II I II I M I )I II I ~I I ~I~ I II~ I I Il I I ~II I I I I~ I I II I I I I m i I Ii II ii i I I I i i ii i M I IIImI~ I I III I I ~I III III I ~l~II~II I I I III II I IlIlI ~II~I I II IIII C~ PH1T,[,TPK PEmROLEt. I~ COMPANY ComDaDV N~me F'~' h;ORTH COOK !NJ,ET ~iel,.d Name ~ ~Ci!.! SUNFISH ~3 Well Name a~I~ 50-~8~-~0090 5p~ Serial Number FL 1~49' YNb g 9~0' F~L Field Location SWCT ~ Sectio~ k5~3~ 9W Range CO[j~,r ~iN~i County STAm A!..ASK~ State or Province ~.~aTT liSA Nation W!T~' HENPY Witness ~3ame SON 629408 Service Order Number pD~ ~?~ Permanent datum ,,IS Tame Verification hiSt!hq ;chlUmberc~er /~lasK, a Computlno Center 31-MAR-1994 1~:25 PAGE; 10 EPD PT O, Elevat.ion of Permane~.t Datum I.,~F gib Loo ~easured From .AP!) FT 1 32, ~bove Permanent Datom EwB FT 132, ~leVation o~ Kelly Bus~i.~g EDF ~"T 131 Elevate, on of Derrick Floor TDD ~T 1~765. Total DePth '- Driller T~L FT 14b~2, Total. De~tb - Lo~qer E~LI ~'"T 1~658, Bottom bog Interval TLI mT 260~. ToD Lo~ Interval DFT POLY~,IE~ $OLTEX Drtlli. ng Fluid Type D~D ~/C3 14~5 Dr~.,1],l~g Flutd Density Dry S ~,~ Dr!13,,lnq Flu~u' Viscosity D~L F3 4~2 Or1111na_Fl. ul.d Loss , R~S OH~'~, 1 02 ResistJ.~ItF of MUd Sample ~'~ST }.')Ef;F ~. ~ud..Sampte TemPerature" R~FS ~H~q;~,l 0.6600001 Resist~.vltv oi' ~Ud Fi. ltrate S .~"~,S~ ~,EC~F 52, ~ud Filtrate Sample Temperatt~ ~?CS oH~q 2,67 Resistiv]..tv of ~ud Cake Sampl .~tC,ST PElF 45, ~ud Cake SamPle Temperature rCS ]5:00 O5-~A~-g4 Time Circulation Stopped TLA~ O0: ~0 06-~AP-gg TI~E LOGGER ON BOTTO~ :~'~T nSGF 200, Temperature b ......... Bottom Ho,le .. . T/~B1L, E TYPE : CUPV lPT-Corrected Gamma De!ta-T compressIopal oe].ta-w Shear 0~LTa. T, RATT(] OF SHEAR T(] COHPR~SS,IONAL Phasnr Deed PesistlvitV ~hasor >~ledium ~esisttvltv Deep Induction Standard Processed Resistivity ~edi~m Induction Standard Processed Pesist~vIty Spherically Focussed Resistivity Spontaneous Potential Surface Tension Downhole "ud TemPerature uUD Resistivity ~ulk Density ne!ta Photnelectric Wactor One-Pad ~ali~er compensated ~e,]tron morosity, S~ ~<atrix, call & dead time corr. ~.'entron ~atio, Dead ~i~e Corrected ~eutrom Pati. on NoD-Dead time Correctea Corrgcted Near Detector (,onnt Pate ..,IS Tape V'ertfi. cation L1sttnq ;chlumberqer Alaska Computino Center CFTC Corrected ~ar 0etector Count Rate ~!NV ~icro-Inverse Resisttvit:v MNO~ ~icro-Norrnal Resistivity PAGE: mmm{mmmmmmmmmmmm~mmmmm{mmmmmmm ** SEi;T TYPE; - CHAN ** TD rlRr~i;)':? ~ LOG TYPE CLASS MUD ~/tI~B SA~P EhEtq CODE (HEX) DFPT F~ 6 o40~ On () I 1 $ 0 0 O0 ., ,: G~ BAS GAPJ 62°4~B O0 OOO OO 0 1 !. l ~ 68 OOO00OO000 DT I7)A,q U,q/F (-,2040B O0 O0c) O0 0 1 I ! ~. 6,~ D*5u nas Uglr 620408 On OOn OO 0 1 ! ~ 4. ~8 SCRg r)Ag ~2q.~0H U0 O0O O0 0 ! 1 ~ ~ 68 IDpw BTF OH~i~,~ 620408 0O 000 00 t,) 1 ! I 4 68 IuPu DT~ ONM'~ ~20403 On 000 O0 0 1 1 ! 4 68 lt,D DT~ [3 u ~4 ~ 62o40~ OD 00o Oo 0 1 1 i ~ 68 I!~ ~T~ (]H.~~i ~294ng O0 000 0o 0 1 ! 1 4 68 S F b n T ~ 9 ~ P,~ ",~ a 2 o ,! 0 a 0 ~ 00 n 0 o (.) 1 1 ! 4 68 Sv DT_~ '-lV 629408 ,,)O OOO on 0 ! ! ~. a 6g qd~Ng D'i'F bP, 62°40~ O0 OuO OO 0 1 ! 1. 4 68 T~ND n'J'E L~ ~20408 O0 OOO (.lc> 0 1 1 1. 4 68 'MINEu DT~ DEG" 62940~J 00 090 00 0 1 ! ~. 4 68 ~Eg ~TE OHi'q~~ 62°408 O0 OoO O0 O I ~. 1 a. 68 R~[t~ SL)~,~ G/C~ 62~408 OO OOO OO 0 1 1 ! 4 6a 0000o00000 0000000000 OEO0000000 0000000000 0000000000 O0000OO000 O00t)O00000 o000000000 000000o000 nooooooooo O00000OO00 O00OO00000 ~O000UO000 ,IS Ta~e v'er,!,fi, cati on Li,,$t,tn.q ;chlu.mberg¢r AlasKa Compt)tlnq Center 31. -t',~'A R.- 1994 12:25 PAGE: 1.2 D N ..... C,~b! S.i.) ~,~ IN 6294 NP,H! CNTH PI,,J'S 6294 C~&T C~,;~H 6294 N~AT C ~'~ T H 6294 CWTC C~H CPS 6294 M!NV ~L OH~4M 62~4 NNU~ f'~L ONM~ 6294 08 00 000 00 0 1 1, 1. 4 68 0000000000 08 O0 000 O0 0 I i 1. 4 68 n000000000 08 00 000 00 0 1 I ! a 68 0000000000 08 O0 000 00 0 1, ! ! ,4 68 000CIO00000 08 00 000 00 0 1, !. 1 4 68 0000000000 08 00 (DOn O0 0 i 1 ! ,4 68 O0000O0000 ~8 00 000 00 0 1 1 ! 4 68 0000000000 08 00 000 00 0 I !, !. 4, 68 0000000000 08 .00 000 O0 0 1 1. 1 ~ 68 0000000000 * * [) A T A * * DFPT 14670. OOO $CRa :PAS -999. 250 TEND. DT~? 861..697 D t~,HO. $ D ~;f' -999 ' 250 CDAT,CNTH -9~9. ~K0 ~,'117 N V, r.~ 1,,, -999. 250 DEPT. laSO0.000 $CRa.DAS 1.829 !L~.DTM 6.729 TFNm,DTE 960.977 [)~HO.SD~ -0.008 CDAT,C~H 2.420 uTNV.UL -999,250 D?PT. 13500. 000 S e" R ,'l .PAS i .775 TI.,H. D_TE 4. 867 TM,Nm. r)']) E 879. ~. 09 i)DHo. SP~ O. 01 6 L)WPT. 13000.Onn $CRI.DAS 1.74§ lLt~.f)~iE 4.473 TmNn. DT~ 9!7.~60 GR.D.AS -999. 250 PT. [.)&5 -999.250 DTSH.PAS l D D H. 'r) ~, E 5.26 g T ~ P H, ,. [; .I .... 5.203 ! h D. D T E S~b.[;~P ..... 5.777 SP,L)TE O. 375 T~;NS.DTE · ~ '~ ~ · ~ -, ~ MTR"~.L)Tt,,'] 1,95 323 RES DTE 0 267 R~{r')B SDN PEF.Sf)N -999~250 CAI, I,SDN -999.250 NPH!.CNTH MRAT.CNTH -999.~50 CNTC.CNTH -099.250 CFTC.CN'TH ~'4NQR. MI 999. 250 C,a. 1)~3 67.9.27 DT.DAS 74.681 DTSH.DAS iDPH.D~E 7.114 !MPH.DmE 6.~67 IDb. DTE SFJ_,. DTE 9.382 SP.D?E -16.750 TENS.DTE MT~M. !'.')T¥; !94.~82 ~R ES. I')TE 0.259 RHOB.SD~ PEP. Sr~f',; a.356 CA.!, 1 .SDN 5.~67 ,N'PH l .CNTH f,~N aT. C,,~'I H 2.al,~ C?fWC, Cf,~TH 4611 .?5O C~TC.CHwa ~NOR. ~I., -990. CR. [),tk5 3o.~8a. r>r. ohs 99.000 DTSH.DA,S ! DPH. [)TI.'; 7n.181 IMPH.OTE 04.556 ~Ln.gTE SFL,.DTE 43.538 SP.D~E -81..188 TENS.DTE MTEM.DTE 187.44& ~RES.D~E 0.255 PEF',SDN 6.234 CAI,I.SDr~ 7.~59 NPHI.C~TH 51R a'r. CMTn 4.~58 CNTC.Cr~TH 1890.~5o CFTC.CNTH ~!NOR. ~ I.., -999. 250 GR.DaS 30.43a DT. 0.5S 82.069 DTSH.DA$ I DP!t. I.)TE 5.427 IMPH.DTE 4.924 ILD.DTE SFG, D~'E '~. 750 SP.DTE 401 .n63 T~iNS. p'r~7 ~TK~. [)TE 1~2.~30 ~RES.DmE 0.253 R HOP,. ,S [3 ~.I P~F.SDr~ 5.~43 CALi.SPN 0.~25 i,;DH l .Cr~TH ~'R n'.C. CK'TH 2.187 C[,iTC. CNTH 4503.009 C~"J C.CN~H ~NtqR. ~![, 2.312 -999,.250 5221 6570:000 -999.250 -999.250 -999.250 136.561 6.973 6710.000 2.641 27.811 1926.922 1~5.500 65.321 6490.000 1.433 65.056 408.930 145.672 5.31.5 6725.000 2.520 !7.56U 2247.000 130.868 4.602 6700.000 2.552 ,'IS Wane Verification r, ist~,..na ;chlun.~berqer AlasKa Comput,J[n~ Center DEPT. 12000,000 GR, DA.S $CR~,DAS -.9~9.250 IL~,~. DT~< -909.250 SFL.DTE TEND. DTr~ ~ 308,1.~5 D~HO. SD~:~ 0.0?2 PEF. C~AT.CNTH 4.299 ~T'~V.t~b -909.250 DF:pT. 11500. SCR~ .DAS -999.250 IDPH.DTE lb~. r)TE -999. 250 TEND.DTE ].076.250 DPHn, Si)N 0.0 ] 9 PEF. SDi'~ C~AT.CN~H 4,209 NR,~T.CNTH N!Nv.'~b -999.25~ DFPT. 1 ! 0¢)0.0o0 (:R. Da5 SCR a. DAS -999. 250 IDP.H. DTg lh~,~. !)T~: -909. 250 SFI,,- DTE TFNm. DTE 10o7.679 UTE~.DTE DPHn. SD~ 0. O 4:8 PFF. SDN DEPT. 10500. 000 CR. DaS SCR/~. 9AS -999.2~() ID~H. L)TE I'Lw, . ,DT~. ., -9~9,2~0. S~'L,I.)TE TFND.~T~ 1121.250 ~.~TEM, DTE [)~F{O. ~[)N (). 105 PEF. SDN CRAT. CNTH ~. 209 NR AT. CNTH MT NV. ~.~[.~ -909. 250 ~'P. IOR. HL D~PT. 1090.0. 000 GR. [).aS S("R ~. DAS -909. 250 TDPH. [)TEl TFND. r)T~i 1136. 656 D~H~. SDS: 0. 998 PEF. C~AT.~NTH 4. 209 M T a V. ",' L, -909 .2g? '~ ~,.~ o a. a t,,, 3]-aAR-1994 12:25 3.635 CALl ~. ~,63 CNTC 2.042 55.537 DT..DAS 74.259 6.400 INPH.DTE 6.388 5.956 SP,DTE -3.696 149.78~ ~RES.:D?E 0.627 4..203 CAI..~I.,SDi~ 12,937 ,a,~62 Ci',jTC,CNTF~ 1.439,239 -999,25a 36,049 []T.DAS 74.802 9.0~3 I'~I~H.DTE R.253 6,604 SP.I)TE 1,1g 788 ~RES.I)TE 0.627 ' 2:9~5 CALi.SDN 15,516 4.262 CNTC.CNT}~ 1439.239 57.747 DT.D~5 73.969 13.422 Sp. OTE -39.997 3.~9~ C~,Ll..Sr~g 15,359 4.2(,~ CNTC.C~TH 143q.~3q -999.250 36,~13 DI::,DIS Sa,986 0,930 !MP~,DTE ~,q89 7.760 gP.DTE -~.324 !49.7~8 aRFS,DTE 0.627 4.0b,~ CALl.SON i7.604 4,~b9 Ct, iTC,CNT~ 143g,~39 -~9~.~5~ 53.00P PI.OAS 85.303 5.34? !F;PH.gTK 5.1.84 4.607 SP.OT~ -19.067 !.4~.7dg ~R~S.[)~ 0.627 A.2b~ CNTC.C~IT~ 143q.230 IbP. OTE TF, NS.DTE RI{OB. SDN NP~!I . C{9 q'H CFTC, CN'"H OTSF{.DAS ILD.DTE TENS.DTE NPHI.CNTH CFTC.CMTH DTSH.DAS RHOR.SDN CF'TC.O~T~{ DTS!q. DAS !LD.DTE NPHI.CN~H CFTC.CNTH DTSN.DAS TENS.DTF RHOB.SON C~TC.CNTH PAGE;: 13 13.71.6 2791.563 163.5!9 9,'0'30 6470.000 2.,400 37.156 762.373 131'-694 '999.,250 7009,500 2'542 27,0'39 344,465 128.867 -999.250 6369.844 2.541 14.935 344.465 I33.729 -999.250 6008.719 2.504 1.7.865 344.465 144.~15 -999.250 5910.875 2.442 22.620 344.465 150.872 -999.250 5538.000 2.4~0 33,011 3a4.465 .,IS Tape 'Verlfi, cati, on Ltsti, n~ ~chlumber~er AlasKa Compu, tJ[,nc Center DFP'r. 9500. 000 GR. D~,$ SCR~. DA$ -999. 250 !DPH, DTE T L ~. 9 T E - 9 ~ 9.250 8 P h. g T E TWND.DTE ~ I~4.000 D~HO. SD~ 0.092 PFF. SUN C~AT.CN'TH 4.299 NRAT,.CNTH '~JNV.'~L -999.250 D ~., P T 9000. O' 00 ~ R. D i T E N ~. D T E 1 1 fi 3 '0 O 0' ~ T ~ i4. D T g DPHO, SDt.; 0,043 PEF,SUN CR.6T.CNTH 4.299 MTNV.~L '999,250 D~PT. 8500. 000 GR. DAS SCRA.DAS 1,907 !DPH,DTE T~ND. UTE 957.656 MTE~. DTE D'PH~, SDN 0,054 PEF, CPAT,C~TH. 2,9~I ~TNV. ~.~L -999,250 ~NOR.ML SCRA.DA8 1.796 iDPi'~{. DTE ~t'.,~~, DTE 5.9 ~ () SVL.DTE TFNn.DTE 902.500 ~.~TE~4. DTE DPHO. SDN 0.0 ~ 9 PEF. 8DN CRAT.CNTH 3.081 N T t~ V. '~ I,.., -309.250 D~pm. 7500. 000 ~R. SCRA .DAS ! .951 T DPi.;. DTE TL~. DTE 9. ~ 33 SWL. DTE TEND,DTE 930,500 l')~Hq, SD~] O. 009 PEW, CnAW.Ct~TH 3. 109 ~P ~T. C~ DFPT. 7000.090 SCRA.DAS ~ .~63 IDPH.DTE TEN~.DT~ 989.219 ~,~T~M. DTE D~HB. 8D~ O. 005 PEF. 8DN CP AT. CNTH 2.83 ! NR,~T. CNTH ~TNV. UL -999. 250 ~N~R. Mb DEPT. &500. 000 GR. 8C~A .DAS 1.755 !L~. DT~ ~. ~9 SVL. TFND.hT~ 972 .~44 CPAT.CNTH 3.138 NRAT 31-~..{AR-! 9q4 1217.5 30. 770 DT. DA8 86. 623 10.320 I~,~PH. DTE 12.734 1,0.813 SD. DTE -20.016 1.49,788 ~RE8, L)TE 0,627 4 . ~ 34 C A !,~ 1 . 8 r)~:~ 1 ? 750 ~.~02 CNTC'CNTH 1439:239 -999.~50 3~, ]. 17 DT, OAS ~ ~. :, 280 9.08 ~ ~ ~,~ P H. D T g 7.96 7..fl67 SP,DTE -67. 335 149.788 ~RES,DTE 0.627 3,960 CALI,SDN 18.557 4,~62 CNTC,C~TH ~439.239 -999, ~50 57.61~ DT.DAS 86 4~5 1 o. 875 1 ~ ~ ~ · I) T g 9: 6.3 9.6~4 SP.DTE -27.~5~ 147.~75 MRES.DTE -0.051 3.3,3 ~ C.A I., 1.8 D ~ 999 250 -999.250 5~. 738 DT, [}AS 91.965 6.691 !MPH,DTE 6.426 6. 277 SP, DTE '44. 094 147.000 ~RES.DTE -0.054 3.98~ CALl .SDN -999.950 3.371. CNTC.CNTH 2423.~89 Sq. 049 DT. DAS 9~. 59.4 11,439 INPFt. DTE 10.391 10.77 ~ S~,DTE -49. 145.625 ~E$. DT.E -0.054 3.3~ CAI, 1.SgN -999.250 3.P6~ Ci, ITC.C~TH 243~ -a9o.~50 54.291 DT.DAS ~01.981 21.67~ I~s~H.DTE 20.41~ 13.37& SP.DTE -4~.666 143.625 HRES.D~E -0.055 3.34~ C~L1.SDN -999.250 ~.016 CNTC.CNTH 2679.000 5J .044 DT. DAS ~04. 889 9.~35 !MPH.DTE g.533 6. 595 BP. L)TE -40. 1,49.000 ~.~RES. DTE -0.056 3.~01 CALI.SDN -999.~50 3.33Q CNTC.CNTH 2~85.594 -99~.250 DTSH. DAS :! L D. D T E TFt~i S. DTF R H 0 B. 8 D NPHT CNTH c?'rc: DTS H, nAS iLD .DTE TEN S, DTE R!'!O~, SD~ NPHI.CNTH CFTC.CNTN DTSH .DAS ILD.DTE TENS.DTE RMOB. SDN ~ PHI . CNT~ CFTC.C~,~WH D. S~ DAS IhD, DTE TENS.DTE R~O~,SD~ CFTC.CNT~ DTSH. DAS TENS.DTE RMOB.SDN NPH~.C,~TH CFTC.C~T~ DTSN. DAS ILD.DTE TENS.DTE RHO~.SDN CFTC,C~TH DTSH.DAS !LD.DTE TENS.DIE ~H[]B.SDN NPHI .CNTH CwTC,CNTH PAGE: 1.4 -999o2..0 5180.000 2,210 40..870 344.465 16.4,2!.9 -999'250 ~955~375 2.493 ~5.643 344.465 i64,781 ~0,5i7 5043,961 2.513 9.40, 3 164.244 6,766 4780.000 2 76'1.609 180,680 11,039 4610.000 2,439 28,305 804,385 190.018 19.944 4345,594 2,376 24,224 958.531 184.109 9.650 413t-406 2,402 28 831 721:047 'rape Verification I,.,ist,i,,nq ;cblumberger AlasKa Computing Cemter D.F,.,P?. 6000,000 ~R,[)AS ,SCRA .PAS T b~. DTE TFND.DT~ 906.563 D~NO.SD~ 0'0 CDAT.CNT~ 3.388 ~RAT.CNTH ~INV. ~[, -999.250 ~,~Nf)R. ~'~ I .... DF. PT. 5500. SCRB, DAS 1 T b~ ~ ~Tg 5. T~ND.DTE 9~0.875 [)~,{~. SDN O. 054 PEF. SDN CRAT,CNTH 3,522 ~TNV,~L -999,250 ~MOR'M~ DFPT. 5000. 000 GR.DAS $~.RA.DhS 2.144 !OPH.D~E 'L~.DT~ 5. 8~9 o~Fb. DTE TENP.DTE 909.6~7 D~HO. S t'.) N 0,059 P~F. SDN CPAT:,CN~H 3.777 M!NV.gL -999.250 DF:PT. 4500. 000 SCR.A .D.AS 1.638 lPP}t. DT[C T[,~. DTE 6,676 SFL. DTE TFNn.DTF 892.000 C~AT, CN~H 3.5 ]7 NRAT. C~'f:~ ~NV, ~IL -999. 250 ~ ~'[3 R DFP'~. 4000. 009 GR. DaS SCRa.DA$ 2.257 TDPH.DTE T L~, DT~ ! 4.43 ~ SFD. DTE TFND. DTW ~ ~ ~, 000 ~fT~,~. OTE Dp HO. SDM -0.003 PF~F. SPa CPAT. CNTH 3. 558 ~R~T. cN'r~ M! NV. M[j -999. 250 DFPT. ..350(). 0 O0 CR. DAS SCR5 .DA.g 2.bl 8 TDPH. Dine ll.,~.' .t)Tgf ~ 3. 171 5FL,.'D~Ew T~N~. DT~ 8 P 5,765 ~TEi'l. D~f: [)PHO. SDN 0. 006 PFF. SDN C°AT. CNTH 3.4~ 9 NR i T. C~;Tg 31-~A~-1994 1,2:25 4 ~. 5 I. 7 P T. D a $ t.. 13,335 8.985 I ~I P H. t3 T E 7.999 6.1. 06 SP, DTE -55.806 1.39.738 '~R ES, DT~ -0 057 7.861 C.ALI.:SDN -999'~50. 3.799 CNTC. C~,ITH 24,76.500 -090.250 40.a04 UT.Da$ i02.~36 6.169 IMPH.DTE 5, 13 5.156 SP.D~g ~4.591 1. 37.,7~ ,.~RES. DTg 0.057 3.086 CAI.,1.$D~ -999.250 3.709 ChTC. C,~':r~ 2100.125 -99~o25~ 45.53? DT,DA$ 117,377 6.654 !MPH,DTE . 5.815 5 520 SP'DTE -33.,214 1,36~500 ~R ...... ~,[.)TE O, 058 ]'129 CA!.,I.$DN 4.103 C~TC,CNTIq 2025.56~ -999.250 46,801 DT'DAS 155.675 6.43~ IMPH.DTE 6.699 5.910 SP,.DTE -64.563 1.36.375 ~RE~.DTE -0 057 3.24~ CALI,.S~,N -999~750 3.744 CNTC.CNT~ 1947.g88 45.79~ Pr. DIS 1.24.1,12 1. g.672 ~MPH.DTE 15.391 11.~22 SP.DTE -50.375 !.34.~25 ~.~RE$.DTE -0.059 3.313 CAI. i.$DN -999.~50 3.~07 CNTC.C~Tg 1975.604 -40.208 DF.PAS 113.683 23.1b6 !~PN.DTE 16.666 15.771 SP.DTE -55.77~ ~3!.625 ,RW$.DTE -0.~60 3.1!1 CAI, I.$DN -999.~50 3.a63 CNTC.C~TN 2279.375 -qgq.250 3°.576 DT.DA$ !24.345 20.147 !NFiI.OTE 14.~16 12.257 SP.DTE -4~.089 13o.~25 ~R~S.D~E 3.0~0 CAI.,I.$DN -g99.P50 DTSH.DAS TLD.OYE TENS.DTE R~OB.SDN NPHI.CNTH CFTC.CNTH DTSH.DAS !LD.D~E TEN$.DTE NPH!.CNTH CFTC.CNTH DTSH.DAS ILD.DTE TFNS.DI>E NPHI.CNTH CmTC.CNTH DTSM.DAS I[,D'DTE TENS.DTM NPHI.CNTM DTS~.DAS ILD.DTM TMNS.DTE RNOB.SDN NPHI.CNTH CFTC.CNTH DTSN.DAS ILD.DTE TENS.DTE NPH!.CNTH CVTC.CNT~ 0TSU.DAS ILD.DTR TMNS.nlF NPHT.CNTH 3872~000 32.,5~2 772'813 201,,250 6,107 3622,922 31"267 .8~8 586.875 251 627 6 604 3368 844 2,354 39,~57 545, 44 25.4,939 6,305 3145.000 2.137 35.1,58 583.163 2~0.108 1.9.156 3000.000 2.218 35.547 575.416 297,605 21.998 2696.859 2.247 34.274 6~5.063 291.110 19.284 2510.500 2.192 38.487 558.5?2 ,IS Tane Vet!fi. cat,,oD ~chlumberoor Alaska ComPutino Center' MINv.~!]L -999.~50 ~ N~3R. ~iL -999.250 DFPT. ~6o2.0~0 CR. DB, S $~Ra.DA$ 2.951 !DPH.DTE T~ND. DTE 949. 509 ~T~. D~E, CPAT.CgTH 3.661 NR AT. C~IT}~ ** E~,!D OF DATA ** 36 . 72~ DT . 22.5~7 I~,IPH. DTE :1.6.547 SD. DTE 130 . 250 ~.357 CALl .SDN .B.g2o C[qTC,CMTH -990,Y50 133.735 DTSM.DAS 10.469 !LD.DTE -64. 750 TENS.DTE -0,060 R!..{OB, SDN -999.250 NOH!,CNTH ~09~.~9~ CFTC,CNT~ 394.678 27.044 2405.000 2 163 600.092 F!I,,F ~h~E ~ ~DI'T ,001 SERVICE ~ ~LI:C V~R$ION : 00~C01 DaT~ ~aX REC $IZ~ : !074 FILK TYPE : LO L~ST WILE **** FILE ~EADKR **** FII, K NA:~E : EDIT ,002 SERUICE : WLIC ¥'~RSIO~ : O0~C01 I:,)aT~ : 94/03/31 FTLK TYPE LAST ~I:,,E ~'TLF NEAD~R Deoth shi~ted ~nd clip~ed curves kor o~en hole loos run ~nto casinq. PASS NU~BER~' 2 # FILV LDWG T~t'~L CODE B~SKLT~;~ CLJP~'F KC)9 St~.!FT8: Sq,'h RT DEP"F N --:--7; .... 13-2~ . GRCH .~IS ?a~e Yer~.ficat:ion Listinq ;c~.],.umberg'er A!a~ka ComPutfno Center 3~-!4A~-!.994 12:25 # ~E~,~APKS: THIS FISE CONT,,~iNS TktE P(JPT!OM OF D~& (DIPDLE SONIC) TODL ~A~M~ PAY THAT LT8 FOR~.~AT OATA PAGE:. 17 C I',,,~ P H 1 L t,, ! P S P E T R 0 Fw NnRTH COOK INLET W~ NCIU SUNFISH AP,I ~,~ 50-88 R ~ N~ 9W N A T l U S.h $~i~' ~29408 PgA, T F, ~' D F T' 0, ~UD WT 132. ~O !:) ~T 14765, TnI ~T 1.4~82. BLI FT 14658, TLI mT 260~. DWT POLYMFR DmD C/C3 14.5 D~PU 9 4 ~ST ~ECF 7 ~, R~CS nH,4M 2. b7 ~CS~ ~EGF 45, TCS 15:00 ~ ~"~'r DE~F 206, Company Name Field Name Well N~me APl Serial Number Field Location Section Township ~anqe County State or Province Nation Witness Name Service Order Number Permanent datum Mlevatton of Permanent D~tum Lo~ Measured Fro~ Above Permanent Datum Elev~t. ion of Kelly BushiDq Flevatlon oi Derrlc~ Floor Total Deotb - nriller Total Fottom Lo~ Interval ToD ~OQ Interval Drillino Fluid Density Drilling Fluid ph 9ril!ing Fluid ~iscosit~ Dr~llin~ F!u~ Loss ~esistfvity of qud Sample '~ud Sample Te{~perature gesi~tivitv of ~ud Filtrate S ~u~ miltrate Sample Te~peratu Pesistiv~tv of ~ud Ca~e ~ud Cake Samole Temperature Time Circulation StOPPed TI"E LOG~EP O~ BOTTO~ Rot, tom !tale Temoerature ,I$ ~a~.e ver'!..ficati, on l.,ist'inq ;c~lt~mber~jer ~!.a~ka Co~Pt~ti, nq Cer~,ter 3,11 -~AR-1994 12:~5 PAGE ** DATA FGR~AT SPECIFIC2T!f)~! R~CO?D ** ** SET ~YPE - 64E~ ** I 66 n , . 2 66 3 73 4 66 5 6 13 66 0 1~ 65 16 6b 1 0 66 1 ** SE? ~YP~.:- CHAr'.~ ** lO ~Rr~ ~ LO(i; TYP~ CLaimS ~OD ~ItJ~B SA~P ~L~M CODE (H~X) ;~X ~ ;; ; ~ ~ ~ .... ~; ...... " DFP~ VT 62 n 3 ()~ 0 0 9., 6 . 0 nnoono0 .... GPCH ~AS G~PI ~20~06 O0 000 00 0 2 1, I 4 69 00O0000000 ** D~Th ** D~PT. la670.000 GRCH.D~S -990.250 ~ . ._ . _ -090 250 [ _~ . 14500 OOO GPC~ [)~S ..,. DMPv, 14000.COO a~C~.i.)~5 Tape Ver.~f.ic~tl. on ~,i. st]nO ;chlumberger AlasKa COmDHtlnc~ Cer~t,'er D E p T. ! 35 o 0, o 0 o G R C t,i. DWP?. 1 ,~000.000 ¢;RCH.i')t%S DEPT, 1~5o0,000 ~RCEI,))a5 D E p T. 12000.000 ~ R C a. DFP?. I ~. 000,000 ~RCH' D ~ P W, 10500,000 G R C ~{, D~p~'. 10000,O00 GRC~{:.D~8 [)~'PT. 9500,000 GRCb~.I.)A5 DFPT, 9000,000 (~RCg,DA5 DPP~, gS00,000 CRCH, D.~.S DFP ~. 7500. 000 ~RCH DFPT. 7000. 000 ~RCH DFDT. fiS00.000 ~RCH.DA~ DFPT. 6000. 000 GRC?{ D E P ~. 5500.000 ~ R c !:{ D~PT. ~000.00{~ GRCH DEPT. ~0o0. on0 gRCH D~p~ 3500 UO0 aRCH ' e - _ ~ , ,,.. D~;PT. 2602. C, OO CkCt~ 31 -099,~50 -999,250 -999,250 -999.250 -999,~50 -999,250 -999.~50 -999,~50 -990,~50 -099.250 -999.~50 -o90.250 -999.250 -~9~.250 -099.250 -999,950 -999.~50 1.,'2: 25 PAGE: 19 :iS wa~e Ver'i~.ic~t:io~ L~sttno ~chlumberqer A.!,asKa Computi~c~ Center PAGE: 2O * * 8VRVlCE V~RSI~},~ '~4' ~, X F T L F LAST FTL~ N,A~,~E ~ E!)TT ,003 SFRV!C~: : V~R S IO.~q : OOi, C01 D~TF ~ 04103131 F~LK TYPIC; : LO L~,ST FILE : FI [,,~ HE/~ D~TR FTL.w, w' [I~BKR 3 Curves oho log header 8at~ ~or eac~ run and tool strtnO In separate fi!,es~ ToO1 String ~1 ~o 8adlerochit run ~resent, e8 first (~r'imary deoth control strlno used to de~th s~t the Sadler ~nterval) followed by ~iles for other main mass tool strlnos per run, RI.~N NI.]MBE~: 1. FTLK SU ~.MARY VE~!DOR TFIO!., CODE', START DEPTH ................. .... P'l" ~; 8 q 1 6. O r,i)m .q_0FT:.4A~E VFR$IO!';: TIJOL 5TRTNC, (TOP TO P, tJTTr~!,.i1 2594.0 2594:,0 2594.0 1 131.5 13-DE0-93 14-DEC-93 8930,0 ~g00,O 2594,0 8900.0 mane Verf;fl. catf. on List, ina '~chlumberger Al, ask:a Comp,]ttno Center 3 ].-~,~AR-~ 994 1,2:25 2i TCC D~.E bDT LBT $ AUX!b~.,IARY G~q~A DIPObE SONIC DIPOL~ D!PObE SO~IC D 'I P 0 b E S 0 ~,~ I C P [{ A $ 0 P 1' ~,~ O U C'r I 0 N P~ASOP INDUCTI'ON NUCLEAR SERUIC[ CARTR DENSITY C OtC'PEN S A q'"~D NEUTRON AMS aA 952 AgE-AA TCC a !01 SGC SA 294 SGO-TAA SP,~C-AA 31 SMD~-AA 33 S~DX-aa 33 DIC-EC 4~ 8 DIS-HC 4~.i ~C E 79~ D~S C 3957 CNC-HA 108 ~.7,500 2602.0 259,q.0 ~OR~HOLE CONDITIf~$ i~!!D DR~'~glWY (LB/G): ~I,!D V!SCOSI~Y FLUID b[]~S (C3): RESISTIVITY (OH~H) ~T TE~(D~PATUPE (DEGF): ~UD ~T ~EASU~ED TEMP~R~T!IR~ MIlD :aT 8OTTO~ NOL~ '['~MPE;~ATUR5 (BflT): ~0O FILTRATE AT ~U~ ~II.,~'~AmE AT ~un CAKE ~m ~[~ CAKE ~ PHPA 9.~ 50.0 7.5 8.7 152.0 1,8.4..0 8OO 540 745 930 TOni.,, STA~{DOFR riM): D~qPTH cr~RPECTF',O. T,DT CALI~k;~ WAS BRr)KF~',~ A~L) IS NOT VAI,ID S LIS FORe, AT DATA 152.0 70.0 '11.. 0 ,.IS Ta..n..e VerlflcatJon Listin(~ ;chlUmber~ler Alaska Computin~ Ceoter 31-t~IAR,t 994 12:25 Tal..{LE TYP~ ~ CONG CN PH. ILbIPS PETROLEUN [rN NORTB~ COOK 1,~~ NCiU SgNFISH ADI*,~ 50-~83-~0090 F' 1,.., 1249 · F N b $~C* 6 R a !',:~ ~ 9 w COU~' KENAI STAT ALASKA N A. T 1 U S A WIT~,~ SON 629408 P'Oa~ ~l,~ g P D F T O, A ~ ['.~ FT 132, E~ ~..8 FT 132, EOF ~Y 13 1 Tnt) ~T 1.4 7' ~ 5, TDL ~T l.~,b~2, B?,I FT 14'6S~ , T[,I MT 2602. DFT P~LYMER [")r [~ C/C3 i 4.5 D r P. 9 D ~ L F 3 4. ~ R~q5 OHu~,~ I. 02 ~.qT DF. CF' 7 ~, '.'~ F S n H ~ ~ 9 ~ b 6 o o o o 1 ~wS~ DEi~F 52, [~tCS nH~,,~ 2,67 TCS 1.5100 05-~,IAR-q4 ~,~T DE~F 200, Company Name Field w e I 1 N a m e ~PI Serial Number ~ield Locatlon Section Townshi, D Range County .State or Province Nation witness ~ame Service Order ~umber Permanent datum Elevation oi Permanent Oatum Lo~ Measured From above Permanent Datum Elevation o~ Kelly Elevation of.Oerric~ Floor Total DePth - Drill. er Total De~t~ - Lo~ger ~ottom bo~ Interval ToD [,o~ Interval DrilllDq FlUid TyDe Drillinq Fluid Density Dr!llino Fluid Pb Qril!iu~ Fluid Viscosity Drillinq Fluid boss mesistlvity oi ~,~ud ~ud..Sa~Dle TemDerature ~esist!.vitv of ~ud F~ltrate S ~ud Wil. trate Sammle Temperatu Resist~,vity oi ~ud CaKe Samml ~ud Cake Sallie Temperature Wine Circulation Sto~ped TIME LOGCE~ ~N BOTTOM ~ottom Mole Temperature DFFT ........ ... ...................... DFPT. CID~ ~NO[~CTTO~,~ DEVP PwAS~P CO~:DUCTiViT? IDp~ Phosor [)eeo PesistlvJ. tV CT~P TNBiJC'[IO;<~ ~.~]p[~l?; P;~ASOq C(]~..;D[ICTIVITY I~P~ Pnosor ~'iedl. u~, uesist!.v~_ty CTL~ CondtJctit, ity il, Deep Standard Processed I~,b geon Tnduction Standard ProcesseO Resistivity .,IS war, e Yer'Iftcatlon [.,istin~ ;chlumberqer Alaska Computing. Copt. er 3!-~AP-~.9~4 !2:~5 23 C.. Co~duct: v t L }~l dum Standard Proc.. se ~edium Induction Standard ~rocessed Pesisttvlt. y Induction Calibrated FreouencY Tnduction Deep Q,talitv Factor Induction ~edlum Ot~a],,it, y Factor Dee~ IndireCt. ion Real, !nter~,ed~.ate Conductivity uct!,v [)ee~e,~i ~Inducti°n Quad Tt'~teymediate ~...,,, In~!..lction Real. Int. e?mediate (..ond3ct!v t¥ ~edium I.~duction Quad Intermediate Conductlvi. ty SFL ~e$istivlt, V $pont. a~eous Potential ~PI-Cor~ected gamn~a Surface Tenslon ~ud memperatu~e goad Tension Density Porosit.~ Rul< Densit.~ Delta ~hotoel. ect~ic Factor Ouallt~ control of lono spacln~ for LDT OualltV co~tyo! or5 ShOrt s~aci~§ ~or bDT Lo~q 8~acinq Co~'~uted Count Rate t,ong Upper 1-2 ~i~do~ Count ~ + Long bowe~ wl. ndo~ Count ~ate Litholog ~l, ndo~ Cou~t ~ate Short gpa¢in~ ~ Window Count Rate Short Spaclno ~ ~indo~ Count Rate Long $~aci~g Ri. qb voltage Short Spaclno ~ioh Voltage spat!no e-ss. tv LOng Smaci~q Bul.k i Dens tV ~.,ong tipper Bul~ Uens~tV ~Pl-Corrected Gamma Ray Surface TenSion ~ud Temperatt~re Compensate4 ~eutron Porosity, $8 ~at~ix, calJ & dead time corr, Paw Thermal ~eutron Ratio T~erma] ~e~]tron Porosity wner~al "eutron Patio Calibrated Neutron Porosity from a!% iDplicatiom Pro~ram ~AW mAo CNT CUUNT8 ~orrgcted Near Detector Count Rate Correcte~ Far Detector Count Rate ~P!-Corrected Gamma Pay Surfaco Tension ~,~UD Resistivity ~'~uH Temperature qeaG Tension UET,T~-T CO~PRESSTO~JAL HF ~IONOPOLE Tame Yeriflcation !..,istJ..n.~ ~chlumberger A]..as~a Co~putJ,,n~' Center 31.-MAR-1994 12:25 D~RP DELT,R-T CO~P~ESSIO~AL HF ~OMOPOt,,~ ~ECE',!VER (P&S) DTRD DELTA,'T CO~P~ESSIOMAL NF MONOPOLY% PECE!V~;R DTTo DELTA-T CO,PRESS!Off, AL PF MONOPOL~ TRANSMITTER DTTo OELTa-T COMPRESSIO%~Ab ~F MONOPOL.,E TRANS~!TTEP C~{RP COHERENCE CO~PRESSi'(:)~&!.., P&S %~[]DE RECEIVER C~4T~ COHERENCE CO~PRESSIO~Af.. P&S Mf:'{DE T~ANSN~ITTER DTMI. DEI.,,T~-T S.HF~R I~OWER 9IPOI~E MODE COUPENSATED !)W~1 DELT~-T SHEAP LOWE~ DIOO!,E ~ODK CO~PFNSA~E9 I')TR~ DELTA-T SHEAP LOWER DIDDI.,E MDD~; RECEIVER DT~ OELTA-T SH~AP I..,OWEP DIPOLE ~OD~'. CHB~. CO~4ERE~CE I.,OWE~ DIPOLE MODE ~ECE;TVFR P~ Po.!.sso~' $ ~atio RSHC ~ATIO S}tK&~ TO COMPRESSION~I., DELTA T GR 5PI-Corrected Gamr~a Ray 2¸4 FORMAT "K 7~ S.P....,C.TF'IC~TI[}M RECO~D ** 2 66 0 3 73 300 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 1~ 68 1~ 66 A 1~ 65 PT 15 66 6~ 1~ 66 I m ~m m ~lm m m m m m m m ,mm m ,m ~m m m mm m mm m m m m m m, mmmmm ** SET TYPE - CNAN ** C~D" DTK ¢~"HO 629408 ~0 OOO O0 0 3 1 I 4 6~ O000000OO0 IDPW DT~ [')MM~,~ 620409 O0 O00 00 0 3 ! 1 4 ~8 00060~0000 CIlia ~T~ MMHn 62940~ O0 000 O0 0 3 1 1 4 6~ O000000000 .,IS Tame Vert,t.i. catJon l, istir)q ;chlumberger AlasKa Computinq Cer~ter 31-~A~-1,994 !2:25 PAGE: 25 ID r)RDE~ ~ LOG TYPE CLASS MO[) NUmB SA~P ELE~ CODE, (HEX) IMP~ nTF ONa~ 629408 00 000 00 0 3 I 1 4 68 0000000000 C!L~ DT~ ~HO 629408 O0 000 00 0 3 1 1 4 6~ 0000000000 ILD OTE (]~i,~~ 62940~ O0 000 O0 O 3 1 1 4 6~ 0000000000 CTh~ ~T~ a~HO 629408 00 O00 00 0 3 1 1 4 68 0000000000 II,~ 9TE Oug~ 620408 o0 000 00 0 3 1 I 4 68 0000000000 I~RE r)T~ HZ 629408 00 000 00 ¢) 3 I ! 4 68 0000000000 Ir~O~ ~T~ 6294o8 O0 000 O0 0 3 1 1 4 68 O000OO0000 I~'O~ DTE 629408 O0 000 00 0 3 1 1 4 68 0000000000 IIRD DTE ~{MHO 629,408 00 00O 00 0 ) 1 1 4 68 0000000000 I~XD D:T~ ~,HO 62040~ 0() 000 O0 0 3 1 1 4 6~ O0O0O00000 ITRu DTF ~:,~q!3 6~0408 0L} 000 09 0 3 I I 4 68 0000000000 llX~ gTE: ),,i:~HO 620408 OO 000 O0 0 3 1 1 4 68 0000000000 a~l:~) 9T~ ~)a~X~ 629408 O0 000 O0 0 3 ! 1 4 6~ 0000000000 Sm 9T~ ~V 629408 00 000 0O 0 3 i I 4 6~ 0000000000 GQ BT~ GAPI 629408 09 000 00 0 3 1 1 4 69 0000000000 TENS DTE !..,,F) 62040~ 00 000 00 a 3 ~, 1 4 68 0000000000 NTE)" UTE DEGF' 620408 O0 00() 0O 0 3 1 1 4 6~ 0000000000 ~{~ES DTE OHa,~ 629408 O0 000 00 0 3 1 I 4 6~ 0000000000 ~,!TE~ OTE b~ 620408 00 O00 00 0 ) 1 I 4 68 00000000OO DVHI LPT PU 620408 O0 000 O0 0 3 1 1 4 68 O000000OO0 RuOB LD? G/C3 620408 00 000 00 0 3 1 1 4 6~ 0000000000 D~Hm LDT G/C3 629408 O0 000 O0 0 ] i 1 4 6~ 0000000000 P~F [.,D~ 62~40$ ~0 000 0() 0 3 1 I 4 68 ~000000000 QL8 LD'r 629408 00 000 00 0 3 1 1 4 6~ 0000000000 088 I,DT 629408 O0 000 00 0 ~ 1 I 4 68 0000000000 bM [,DT CPS 629408 00 000 00 0 3 1 1 4 68 000O000000 b!.l LDT CPS 62~408 00 000 00 0 3 1 I 4 69 000O000O0g h !., r,., l:') T C P 5 ~ 2 q 40 ~ 00 000 00 0 3 1 I 4 6 ~ 0000000000 LTT~ LDT CPS 629409 00 000 00 n 3 ! I 4 6~ 0000000000 SS1 [,Dm (iDS 629408 OO 000 O0 0 3 1 ! 4 ~8 0000000000 $~2 LOT C°S 929408 O0 000 00 O 3 1 1 4 68 0000000000 hShV LD? V 6294o8 00 OO0 cO 0 3 1 1 4 6~ 000n0o0n00 SS[~t! [~DT V 6~040B O0 OOO O0 0 3 1 1 4 6~ 0000000000 51Ra LO? G/C3 ~20408 o0 OO0 O0 r) 3 1 I 4 68 0000000900 £,SR~ [,,I)? G/C~ 629408 oO 090 OO 0 3 1 i 4 69 0000000~00 LURW LDT G/(:~ 629408 O0 00O 0O O 3 ! ! 4 68 0000000000 G~ ~,UT g~,P? 629400 nO 000 00 0 3 ! 1 4 6~ OOOOOOOOO0 TFNS LOT Ln ~294a~ 90 000 00 O 3 ~ 1 4 O? O000OO0000 ~Eu LOT DE(;~ ~2040B O0 000 O0 0 :) 1. 1 4 b9 0009000000 u~E5 *,Dm O[~. 620400 O0 000 O0 0 3 1 ! 4 68 0000000000 HTE~! [,DT bn 629408 n0 000 aC a 3 1 1 4 68 0009000000 r,iPNI tNT p!~ ~2940~ OO 000 O0 O 3 1 ! 4 6~ 0000000000 ~TNP CxT ~29408 O0 000 flu 0 3 1 1 4 68 0000000000 [ypu C[~T P!' 02940~ Of) 000 O0 0 3 1 1 4 68 O00000000O '!'¥R5 C~JT 62q408 O0 OOO 09 0 3 1 1 4 68 OOOO000000 (~¢~P CN~ P~J 62049~ O0 000 O0 0 3 1 t 4 6~ 0000000000 RCN* C,4T CPS 629400 or) 000 n0 0 3 1 t 4 68 0000000000 RC~T ~,T CD~ 62~4n8 nO gOO 0O o 3 1 1 4 6R 0000000000 CNTC CNT CPS 620408 gO 0O(} 00 0 3 1 I 4 68 0000000000 CFTC CNw CPS 629~0R n0 000 O0 0 3 1 1 4 6~ 000OO00OO0 C~ CNT GSFI ~294o8 nO 090 00 0 3 1 i 4 60 0000000000 ,I:S 'ra~e Verf, fi. catlon Listing ;chl, Ur~:~erger Ala~k.a Compt,]t~,n~ Ce,ter 26 ID ORDE~ ~ LOG TYPE CheSS ....... ....... .... T v: N ,~ L P, 629408 00 00 0 ~ES C~T (3N~ 6~9408 O0 000 O0 0 ~4TE~ CNT [)EGF 62o408 O0 000 O0 0 3 HTEN CNT L~ 629408 O0 000 O0 0 3 DT4D ~T~~ ~29408 00 000 00 0 3 DT4D !TP 6~9408 O0 000 O0 0 3 DTR° DT~ 620408 00 00O 00 0 3 DTRP ?TO ~29408 00 000 00 0 3 DTTD PT~ 629408 00 000 OO 0 3 DTT~ !TO 62~408 O0 000 oO 0 3 C~RD DS!' 620408 O0 000 O0 O 3 CHTP OSI 629408 00 000 O0 0 3 DTM} PTE US/F 629408 09 000 oO 0 3 O~! YTP US/W 629408 O0 ()00 00 0 3 D"'R~ PTE 629408 nO 000 O0 0 3 DTR~ !TP 62°.408 O0 000 O0 0 3 C~IR 1. DSI 62q408 0() 000 O0 0 P~ OS! 620408 O0 000 O0 0 3 ~$},{C DS! 629408 00 00O 0O 0 3 G~ DST G!PI 629408 O0 000 O0 0 3 ...-..........................--.,..,,....... 0 3 1 i 4 68 00 00000 I 4 68 0000000000 1 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 6~ 0000000000 1 I 4 68 0000000000 1 1 4 6~ 0000000000 1 I 4 6~ 0000000000 1 I 4 6~ 0000000000 1 ! 4 68 0000000000 I I 4 68 0000000000 1 1 4 6~ 0000000000 1 I 4 6~ 0000000000 ~ 1 4 ~ 0000000000 I I 4 6~ 0n00000000 I 1 4 6~ 0000000000 I 1 4 6~ 0000000000 1 1 4 6~ 0000000000 OMP?. 8932.500 CIOP.DTE 89.~13 Iw:PW.DTE 13.086 CIL[).DTE 97.~.25 TL[~.DTE 12.797 !F~E.D~: 20.000 IIRn.r~T~ n2.~,n8 IlXi). DTE 5.359 SFLI.T. OTV. 17.9 '] 1 SP. DTE -28. ~ 56 biTE". ~TE 147.750 ~ R~:S. DTE -O. 050 RFOB. T,,Dw 2.400 DRHO. bDT O. 1.73 ~SK. l,D'r O. 044: I.,S. bDT 50 !.. 750 EIT~. 1,[)~ 1.70.375 SS 1. Lr)T 313. SgNV.Lg'* 13~(;'. 000 S1RH. I.,DT 1. B G~. ~,[)* ~8 .B13 *~NS. LPT 3770.000 HT~~.t.,DT 51 3.000 ?3PT'~i.CNT 54. T~'R~ . C~,~? 4.551 ~]Pf~.CNT 56. CNTC. Cr:~· ~33~.235 CFTC.CrT ~Eg. CNT -0.059 ~T[~i,~. C~'T 1 47.750 DT4. P. I I'P -909. 250 r3'r¢ p. PTE -q99. 950 L)TTo. ITP -999.2~0 CdRP.L, SI -~q. 25n DTM1 .lip -999,250 O"[P 1, PT~j -q99,~50 Pr~ ,DSI -999,250 PS~C,DS! DEp'v, 8500.000 CIDP.DTE 93.43~ luPq.PTK 9,ol 7 C I !,.,O. I)"'~, 96.93~ Thu . nTV 9. 453 1FRE. D~E 2o. ~0n i!R~.~TE 8~. 875 !IYD.DTE 4.5,i7 SFLU. BT? 9.9~9 SP. DTE -27.703 ~TETM . DTF 147.875 ~ KEf&. UTE -0. O 51 IDPH.DTE 11.133 C!MP.DTE ILD.DTE 10.852 CILU.D'rE TDQF,DTE 3.000 IMQF.DTE IIR~.DTE 74.063 IIX~.DTE GR.DTE 68.813 TENS.DTE MTE~'o. DTE 513.000 DPHI,LDT PEF.LDT 3.324 I,.,U. bDT 460.750 [,I,.LDT SS2,bOT 426.250 LSRH.LD:r 9.~07 LrJRH.LOT ~TEY,LDT 147.750 MPES,LDT 9CNT.CUT 1389.126 RCFT.CNT Oa.Cr0'T 6~.a13 TR~S.CN~ ~TE~',~. C'~T 513.000 DT4P.PTE DT~F.ITP -99~.~50 DTTD.DT~ CHTP.DSI -q99.~50 bTh! .PTE DTRI.1TP -999.~5() CHR1.DSI ~k.OS! -q99.250 .I. PPH. UTE 10.695 C I.,',, P. T',T E i l,~). D"t'E 10.313 C!LU.DTE !IP.~, D'~E _100.063 I!X~,r3TE CP.DTE 57.7!° TENS.DTK HTE~.~. L)Th] qd3.nO0 DPHT.T,DT 76.375 78.125 2.000 8.195 3770.000 15.142 -0.01,1 271.250 1426.000 2.211 -0.050 56.3~9 2q~.b~3 3770.0~0 -909.250 -999.250 -999.250 -999.250 103.875 105.688 0.000 8.469 504O.0O0 8.468 ,,IS Tape 'Verification I,,istln~ ;chll]mberger Alaska ComDu'ttr'lq Center R !q Il ~. L D T 2.510 D R ~ O · b D T OSS.LDT -0.0~,0 SSHV.I, OT 1381.000 $1~H.LDT G~. LDO' S7.7 ~ 9 TE%~S. LDT ~ T E ~',~. L D T 943 ' O 0 O r~~ P ~ I. C':~ T TN~a.C~'T 3.007 C~T~. CMT 2599. 533 CFTC. C[~T ~ P.:S. C b~ ? -0.051, '4TE~. C~T DT4~, ITP 86.475 OTTP..~TP 88,593 Cd.~P. DSI 1 .ITP I64.7~1 DT~.DSI 0.310 ~S!'~C. DSI D F P w ~ 000.000 C i D 0. O T E TL~'.DT~ 6.676 IFRE.DTE I!RD.~TE 1~2.750 IIXD.DT.E ~FLU.OT~ 6. 363 SP.D~E ~'~TE~. DT F', 14.7.250 MR~:S,. DTE ~H[)B.LDT 2.490 DRNO. LD'/ OSS.LDW -0.0~8 LS. LDT L IT~. LDT ~9. 000 SS 1. I, OT SSHV.LDT 1380,000 SI~H.LDT (;P. LDT 64.178 TENS.LDT HTEaJ.bDT 954.000 ~.P~'~ I. C ~T T~'] R A. C~.~T 3.0~7 NPOR.CNT CNTC. CNT ~553.167 CFTC.CUT ~,~PES CNT -0 054 ~"TFM CNT I')TT~. !T¢ ~6.4~8 CHPP.DSI D~M1 .ITo 164.244 DTR 1,. PTF, P~.DS! 0.272 RS~C.DSi 7500.000 CIDP.DTE I ~"PH. DTF: 1.3.070 CIT:D.DTE DT? 11 ~qq IFPF i')TE · ... , ~ ITRD,DTF 74.1~8 I ~XD.!)TE ~'FW ~ 2.7 fl9 SP. DTE I,DT 2. 448 QRM~'3. !,,DT LDT -0.0 ~ 7 L5. L, DT LOT 100.938 S~i.LDT SShV.LDm !379.000 SXRH,LDT T~DT 66 313 TENS h . LDT ~ 0~6. 000 NP~I.C~;T C~,jl~ 2.9g 8 ~,~pmR.C~~t CNw 25~0.746 CKTC. ITP q2 594 DTPP PTE O~TD.!!~ 90.970 .TT~ 1~0.6~0 ~)TPI.PTE 31-!~AR-19~4 0.056 PEF.LDT 256.750 ~ ' ....... 2.303 L S P 27.240 ~ C ~,~ T. C N T 903. 587 GR.CNT 147,875 84. ~ 57 DT~ P. I'r p 0.076 1.~7,25~ 1 .907 CR.DSI 145.750 IDPH,DTE 1.44,625 IL, D,DTE 20.000 I D 0 F, O g E 9.469 !I~, DTE '44.125 .CR.. DTE '0,054 NTEN,DTE 0°006 PEF,L~T 313.250 5U,LDT ~36.500 6S2.bOT 2.430 LSRH.LDT 4785.000 MTEM.LDT 27,1.69 ~TNR.CMT 27.992 ~CNT.CUT 955. 079 GR. CN'r 97.50~ 9T~P. ~76.625 9TR1 .ITP 1 .786 GR.DM! 7~. 1.~3S IDPH.DTE ~0.875 ILD.DTE 20.000 I I.)OF. DTE .4.969 I IP?.{.DTE -~9.2Sl -0.054 HTEN.D~E 0.00o PFF.bDT ~39. 500 Ltl. LnT 2~ .500 SS2.bDT 4795.000 26.584 PT~ R.C~T 27.~80 ~C~T.C~T 86a.17~ ~45.375 ~TEN.CNT 94.217 DTPP.ITP 0.~37 CHTP.DSI %93.71~ 1 .951 GR.DSI 3 .396 366.000 2 ,434 3.308 2629.580 57.71,9 943 000 84 ~ ~ 57 0,~19 177.758 57.6!~ 6. ~59 6,910 0,000 .1. 41. 250 64.1.88 954.000 3.551 ~93.~50 346.000 ? 463 147:250 3.320 2651.716 64.!88 954 OOO 97,:502 0.891. 1,76.6~5 5~.738 17.773 17.352 79.~75 66.313 1036.000 3.324 31a.75o 35! .000 P.418 145.375 3.1.19 2593.015 66.313 1036.000 94.217 0.065 1.93.711 59.049 177.,:: 875 1.4~7,000 2.443 -0.051 26.281 864.255 5040.000 164.7~1 0.8~6 137,,2~0 i49:6 5 0,000 19,250 4'185.000 9,667 '0,,001 166,500 14~8,000 2,471 '0.054 ~7.,958 821.239 '4785,O60 91,965 ~6.,428 164.~4.4 0,8~7 76.500 84,250 0.000 7,211 4785.000 ~2.2~3 0 005 1427.000 2.4]0 -0.054 ~6.919 801.394 4785.000 92.594 90.970 180.781 0.311 I.,IS Tape Vert. fl. cation I,,ist!ncl >c~:lumber{~er .A.l, asK. a Comput,~,nq Center FI P?, 7000, () 00 C l D P, ,::, T E IL~,DTE 17,859 I'F~E,DTE IRD DT~ 4~.063 !IX0,DTE 8FBU~DTE ~3,2~2 8P.DTE "-"' · · ".' · ~':~ 0 ~ ~ L D ~ 2.389 D R ~,,I 0. L D T 088. [,,t~ ~ -0.023 t.,&. bDT LIT~, LDT 1.20,6~8 SS 1, bDT SSHV'.LDT I 378.000 S1RH,:L, BT G~. LDT 58.000 'tE~$.LDT HTE~:. LDT 997. 500 ~J~HI. C~T TMRa,CNT 2,8?5 ~POR.CNT CS~TC.CNT ~693,6~6 CF'TC.CMT ~'~P ES. C:siT -0.055 D'r4P. lTO 101,9~1 DT~P,PTE DTT¢. ~',rt> 103.973 CH~;~P.I)$I D?'~t.~TD J,,,0().018 P~.DSI' 0,298 RSHC.DSi D .w.,,PT. 65o0.0o0 CIDP.DTE IU'P~4.DTF 8.445 CII,,D. D?. E lLu. DTF~ '7.893 IFRE.DTE I IRD. DT~ 1 O1 · 9 38 I I. X0. OTE 8FLU, DT~ 7.332 S~. DTE ~E~'. OT~ la2.1~5 '~4RES. OTE R:~O~,I~DT 2,377 DRHO.LDT OSS, LD* -0. 009 LS. bDT LITt'l. [.,[)T I ~9.25¢ SS 1. LDT SSHV.LD* 1377.0o0 SI~H.LDT GP.LDT 5b.~56 TE~,~S. LDT HTpjN. [,DT 977. OO0 r'J P~ I. C~'JT T~aR5 .CNT 3.3~7 C~:TC. Ci,~* 21o7,530 CFTC.CUT ~ ES. CI'~T -0.05~ gT~.C~T DT4P.ITP 104.$gg DT~P.PTE DTTD, !'I'P 104.062 CH~P.D8I DTM1 .ITP 1~4.109 DTPl.PTE PP.DSr 0,260 ~SNC.DSI DW. PT. 6000.000 C.I~P. DTF. IuPu BTF 7,922 CILO.DTE ILk':DT~ ~.~41 !F'~E. DTE $~L'~, DTW 6.027 SP, OTE MTEw. DTF {, 39.751) ~RES., UW~5 RWQP. I.,DT 2.3 ? 3 DR HO. bDT 9S8.LDT -0,0~2 I,S.LDT LTT~. bDT 14?. 125 SS1. bDT SSHV.I,D, 1376.000 Sl RH.hn'r G~ . LO* 55. 500 TENS. I, DT HT'Et' . I,D~ 908.50C MPH.I.. CNT I'~:R a, CN~ 3. 398 NPOR. C~T Ct~TC . C~T 24~fl. 571 CFTC. Ct~T 31-}~,AR-1994 1,2:25 45,594 49,750 I 20,090 IDOF,DTE 3,355 II -42,719 GR,DTE - 0.055 H T E ~?~. D T g 0,005 375. 750 LU. LDT ~42,750 SS2,LDT 2. 346 4350,000 24,140 ~TNR, C~qT 24.471 RCN'I',CWT ~67,839 CR.CNT 1.43.625 ~{TEN.CNT 90.989 DTRP,.ITP 0,879 CHTP,DSI P0~.301 DTRi,ITP !.. 863 GR, PSI I IO. 000 !DPH. DTE 1 13.188 20,,000 IDOF.DTE 7.398 IIPM.DTE -41. 906 GR. DTE -0,056 HTEM,DTE O. 0 31 PEF. LOT .~ 1:,, ~. ~ 50 LO. LOT ~57.~00 SS2.LTT ~.~40 4!90.000 ~TE~.bDT 3P. 570 RTNR. CN'Y 3~. 47 ~ ~C~JT. 67 1.. 781 OR. C~T 142.125 ¢ITE~.). CNT 105.J17 DTRP. ITP 0.672 C~TP.DSI 197.180 DTRI,ITP 1.755 GR.[)SI 110.875 !DPH. 111 .063 II.I). DTE 20.000 IDOF.I)TE 9,44~; TI,~g. DTE -55.7 19 -0.057 ~!7'E.4. DTE ~. 014 PFF. hOT ~30. 250 L:j. bDT 254.250 SS2.LBT 2.734 T.,SRH, bDT 3~80.000 ~TE~,i. bDT 3P.733 mTrqR.CNT 33.1~! ~CNT.CNT 7o7.59~ GR.CWT 20. 4 0.000 53. 125 58.000 997 500 343.500 359,750 ~, 363 !4-3,625 ~.oos 2837.986 5~.000 997.500 9~.98~ 0.761 203. 301 9 086 ~:g28 0.000 1.1~ ~13 5s:656 977 000 3:3so 364.750 ,3'75 o 000 :2.326 !.42,1.25 3,724 29..80.918 56.656 ~77 000 0.71~ 197,1~0 5~ .044 9.016 q. O00 0.000 109.375 5.~.500 9()I~. 500 2.965 390,759 381.750 1 39,750 3,937 2~55.544 55.50n C I ~4 P. P T E CTL,~ DTE IIA~.DTE TENS. DTE o~! .LOT OLS, LDT L L. L O T bSHV. LOT LURH, I, DT M~ES.LDT T ~.,~ P Iq ' C ~T RCFT.C~T TENS.C~T DT4P.PTE DTT¢.PT~ DTa I .PTE PAGE: 28 48.875 55,938 0.00o 7 352 4350 000 15 819 0.017 204,000 1475.000 2,3?7 -0,055 4350,0 0 101,..981 103,973 190'018 0,941 126.813 0,000 6,063 4190,000 16.558 2Xg:750 1425.000 2.342 -0,056 32,408 622,749 4190,000 ~04,859 104.662 184.109 0.870 126,188 115.688 O.000 7.0~7 3880,000 !9.796 -0.017 230.500 1423.000 2.201 -0,057 31.463 713,5!6 3880.000 ,IS Tare Vet!fi. cation ~,ist, inn ~chlumberger AlasKa Computing Cent;er DT4P. tTP ! 3.335 DTRP.PTE D~':TP. ~TP 117,7~0 CH~P.DSI D~M1 .IT'~ 201.141 OT~I.P~E P~.DST 0.267 RS~C.DSI DDPT o 5500,000 I~PH DTF 4.945 C!I_9.0~E t' L ~ ~ D T E 4.953 ! F ~ E. t') ~ E IIRD.DTY 150.500 IIXD.DTE 8FL, TI.DTE 4. 570 8P.PTE ETE~.DTE 137.875 RHO~.I, DT 2.236 DRN[I.LDT 088. !,,DT 0.000 LS. LOT I,,ITH. 5DT 177.750 88.1. SSHV.LD~ 1375,000 8,t~a. I,,~T G~. [,DT 51.2~1 TEwS.LDT HTE~.LDT 923.000 TNR~,.CNT 3.~56 NPOR.CNT Ct~TC.CNm 20!8.195 CFTC.C~T '/,~ ES. CN~y -0.057 ~TE~.CNT I)T4P. ITP 102.5~6 9TRP.PTE DTTP. !Tt? 104.573 CHRP.DSI L)'rM 1. ITP 201. 250 9T~ 1 .PTE P~.OSI 0.3~5 RSHC.D8I DrPT. 5000.000 CIDP DTE I ~'~ p ;~. D T ~: 7.242 C T b~. U:'!3'~ 7.063 TFRE.DTE I~RD.DTE 116.500 !IXD.DTE S~'bU. DT~ 6,418 8P. [)~E ~TEV.DTM 136.500 MRFS.DTE RHtjn. I,,DT 2.330 DRHO.LPT OSS. !,DT -0. 003 L8.. LgT bTTw. LDT 135. 875 S81.. LDT S~HV. !,DT ! 375.000 GI~H.LDT C; ~. r,,['.) w ~8.844 TENS.LDT HTEN. T,DT 9~ 1. O00 TNRa .CNW 3. 340 ~POR. CNT C~ITC. C~qT ~056.715 CFTC. CNT DT4~.!TP 117.377 ~TPP.PTL DTT~. XT~ 108.4~0 CH~P. DSI L}T~ I .lTD 251..6~7 ~T~I.PTE Pn. DSI 0. 361 DFpT. 4509. 000 CIF~P. IuPW. m7'~ 6. 099 CILO. DTE T b ~,'..nTt< 6.67b TF~E. DTE SFb!t. %TM 5. 910 SP. MTE~.DTF 136.375 ~RFS.DTE bltTM . [,DT 191. 095 581. 3J-mA~-J,.994 12:25 1.39.750 HTE~.CMT 108'~90 DTRP.ITP 0.735 CHTP.O8i 214'~86 DTRI.ITP 1.775 GR.D8I 1,68.375 IDPH.DTE !69.250 I!,D. DT'E 20.000 !P0F. OTE 15.867 IIP~.DTE -43.750 GR.DTE -0.057 ~TEN.DTE 0.064 P~F.LDT 55~.500 I,L/,LDT 280,250 $82.bDT 2.00~ [.,SRM.LDT 3630.0(0'0 ~'T~',~'!.UDT 37.341 RTNR.CNT 40.067 ~cwlr. C~,T 554,.236 GR.CNT 137 8~5 HT~N.C~T !00~4 9 9TRP.ITP 0.733 CHTP.DSI 214.~84 UT~I.ITP 1.963 G~.DSI 13~, .750 IDPH.DTE 131.750 ILD.DTE 20.000 !.DOF.DTE 9.03! II~a. DTE -34. 875 GR. DTE -0. 058 HTF~. 0.038 PEF.LDT a 37. ~50 I.,U. bDT 252.500 582.b~T 2. ! ~O LSRH. bDT 35S5.000 HTFH.bDT 31 .859 PTt~R. CNT 3! .474 9CMT. C~'T 5~0.~1~ CR.CNT ! 36.500 ~TE~. C~%= ~26.~73 DTRP.ITP 0.~12 CHTP.DSI !55.250 T l)P i-4. £.)TE 1 bfi. 500 I I_,.r_~. D~E 20.000 IDQF.OTE 12.7~1 IIPM.DTE -64.563 CR. DWE -0.057 HTY,~. UTE 0. O 13 P~F. bDT 6o3.soo bU.bUT 2o6.250 SS2.GDT 908.500 10~. 890 0.955 214.oa6 .48. 517 5.034 5.9O2 0 000 51.2@1 923.000 3 .,O69 ,~07,000 16.25 0 137.~75 3.983 201~.700 923,000 ~00~499 0 594 ~14~984 49.~04 7 582 . 7.586 0.000 !33.625 40.94~ 961..000 3.182 396.000 383.750 ~.~79 136.500 3.550 237~.173 48.~44 96!.00~ ~26.~7~ 0.577 26~.002 45.532 6.438 6.305 n. OO9 !41.25~ 46.063 ~92.00o 3.242 542.000 402.250 DT4P.PTE DTTP..PTE OTMI.PTE CHRI.DSI CIMP.DTE C ? b~. OTE IIXM.DTE TEN 8. o'rE DPHT.I..DT O.L,$. LDT LL.LDT bSHV.LDT L[JR~!. LDT MPES. TNPH.CNT RCFT.CNT TENS.CNT DT4P. PTF OTTP. PTF~ DTM 1. PTF~ CHRI .DSI PAGE:, 29 11.3.335 117'780 201,.:i41 0.954 202.000 201.750 0.000 10.609 3630.000 25.081 -0.014 299.250 1423.000 2.158 -0.057 38.3!.9 534.474 3630.000 102.5B6 104.573 201.250 0.91,6 138.000 141'500 0.000 7.809 35B5.000 19.012 0.017 239.1~5 1420.000 2.295 -0.058 35.807 595.659 35~5.000 ~7,377 108.480 251.6~7 0.741 149.250 149.625 O.OOO 14.836 3145.000 31.090 0.008 332,750 1420.000 lis TaPe Verl, ft. ceti. on ListJnq 'c~l~berqer AlasKa ComPutfnc Center S $ H V, l. ¢ T ~! 373 · 000 $ GP,LDT 46,063 TENS,. LDT H T E ~. L D T 8 q 2 ' 000 N P ~ I. C ~ T T N R a. C ?*'T 3.537 CNTC,C~T 1947.888 CFTC.CNT OT4D,ITP 1,55,O75 DTPP,PTE DTT~. ITP 153. 163 CH ,D~I ITP ~54 939 DTRi.P" P~ Oat 0 203 , .C DSI D ~ P T. 4000.000 C I D P. 1,) T E ,, I ~P[~ DTE !5,133 I~R~.BT~ 50.344 IIXD.,DTE SFL~, UTE ! !,. 750 SP. DTE; 'RHUB. BDT 2. 195 DRHO. I..,DT O85. LDT O, 015 LS. bDT SSHV,LDT 1.373.000 G ~. L () T 45 · 063 T E; ~S. L 9 T . CNT 3 707 MPOR, C[~T C~TC.CN* P057.764 CFTC.CNT DT4P.~T¢ 124,1!2 ~T~P,PTE OTTO. TT'P 1~2.833 CdI'~P. DSI D~I, !T~ 2~o, 1,08 Br~l .PVE PP,DST 0.378 RSHC.DSI l.[) E p W 3500. 000 CI DP.. DTE ~iP~DTE 13.906 C'ILD. DTE l!.,~. UT~ 13.805 IF~E,DTE ITRD.DTE 51.281 SFL~*, DTE ~ 3.859 SP. M'Er.nTt 131.750 ~RES. bTE R*~[ln. ~. DT 2.1,19 DRHf]. I.,9T OSS. ~,DT -0. 009 I..,S. bit[~. bDT 201.1 ~5 SS1. LDT SSHV.I~DT ]371.000 SlPH.!~gT awE~'. I,DT 8 ~ 3. 500 vPHI. C~IT T~,~ ~ .Cp,:* 3. 550 C~;TP.Cf;T ~073.174 CFTC.C,0T Cq~Eg. Cb T -O.060 b~T~ f-d. C ~i T DT4~.ITp i!3,6~3 9TPP. DTTD.!TD 1~ 6,051 CH~p. [)'~ i .lTD 2~7.~0b DTRi.PTE PP.DSI 0.~5 9FPT. 3000.000 !uPW.DTE 14.305 C'ILD.DTE TL~,~Tw 13.922 ITRn.DTF 47.906 IIXD.D~E 3!,-~A~-1994 12:~5 2. 053 LSRH.LOT 31.45.000 ,qTE~!.bDT 35.158 RT~,~R. CNT 33.540 ;~C~T. C~,~T 5~3. 163 GR.CNT 136.375 HTEN.CNT 158. I 8~ DT~P. O. 918 CHTP. DSI I .639 ~R.DSI 54.656 !DPH.DTE 56.43~ ILD.DTE 20 00O I170,., -50. 906 GR. DTE '0.059 HTEN,. DTE '0.006 PEF,k, DT 522,500 248.000 SS2.LDT 2885.000 ~,~TE~!. LDT '3~.281 ~TNR.CNT 35.,.,2~ ~CNT 605, ~25 13g,000 HTEN.CN'T !25,399 DTRP, ITP 0.967 CHTP.DSI ~97.qSg DT~I,ITP 2.257 GR.DSI 54,656 IDPH.DTE 57 063 ILD.DTE 20~000 IDOF. i)~E 4.i52 !IR~'!.D~E -O, 060 HTEN. 0.OOl PEF, bDT 611. 000 I.~. LDT ~57.750 SS2.hDT 9.096 l.,S~, bDT 2695.000 35.40~ ~T~.CNT 587. ~8~ GH. CqT J 3!.750 HT~N.C~T ~ 1 I. 3 I 5 DTRP. 0.62~ CHTP.DSI -990. 250 ~TR 1. ITP 2.619 51 ,156 53.500 20. 000 9..l 09 2.105 136.375 3.74.4 2020.52,4 46,063 892.000 159.188 0.913 771.529 46.B8~ 1~.281 17.703 6~.188 45.063 ~93 500 ~80.000 ~77.000 2.182 3.91,7 2082.700 4~ 063 893i500 125392 0.952 297,988 45,292 17.516 0.000 6g.625 48.250 ~83.500 3.97? 555.q00 394.250 2.102 ]31.750 2165.464 48.250 88~.500 0.390 316.373 4n.20B 19.531 0.O00 6P.06~ LURH. LDT ~,! ~ E S ' LDT T I~,! p H. C [,.i T RCFT. CNT T[{~N S , CNT DT4 P. PTE DTT P. PTE DT~ ~ · PTE CHR1 CI~-~P,DTE C ! L ~. TENS. DTE DPH!.LDT ~ L,, S. L D T b t.,. !'.., D T hSHV. LDT !., l.t R H. L D Y t~ES RCFT.Ct~T TE.NS.CNT DT4P. 'PTE DTTP, PTE DTM 1.. PTE CWR ~.. DST CIt4P. DTE C !b~. PTM IM'QF.DTE TENS. UTE I)PHI. OhS. LDT bL. USHV. LDT M~ES, LUT RCFT.CNT TEb~S .C~* 9TGP.DTE DTTP.PTE DTM ~. CHP, 1 CIgP.DTE CTBU.BTE IlXU.DTE 2.121 -0 05'1 33~.459 54,2.282 3145.000 155.675 153.163 254.939 66.000 71.875 0.000 20.406 28B5.000 ~7.592 -0.014 282.500 1420,000 2.188 -0:,059 34..401 569,531 2885,000 1.24,112 122,833 2~0.108 0.861. 71.~75 72~375 0,000 13.641 2095.000 32.171 -0.008 333.500 14~.000 2.109 -0.06o 36.444 555.393 2695,000 113.683 116.051 -999.250 0,537 69.875 71,813 0.000 14,883 .!IS Ta~e Ver!f!.cat!,oD Listi. na ;ch,lt?mber~!~r Alaska Comptltinq Center Sr;'LU. DT,,F, 12. 305 SP. DIE MTE;~. DTF. 130.6~5 RF'O~. L[)T 2.195 DR~O.LDT OS~. LDT '0.019 bS.LDT L~T~4. [,., D ~ SSHV.LDT ~ 371,.000 S1RH.LDT G~,LDT 40'000 TEht$:' bD~f ~i.'r E~ . I.,[)T 91..2.500 N'P}~I. CNT R ~ . C N' * 3.663 M p ~,q R. ~ ~ T CNTC,CNT !959.703 CF C,. C~IT DT4P. TIP 124.345 DTRP. PT~; D*TD. TIP 1~5.401 . ""v . M1 !I: 29I 110 DTR1, PR.DST t> ~ P'r ? 541 ' 5 o O C ! 13 p. D T IuPW:DI'E' ~ -9~9.250 CIi.,D.DTE; lLU.nTE -909.250 TF~E.DWE IIRn DT~ -909.250 IIXD.,DTE S~l.,!~'D'TE -999 250 SP DTE MTE~. DT~ -999. 250 MRES. DIE RMO~,.I,DT -999.250 DRNO.bDT OSS. LDT -999. 250 I..$. LDT bTTP. LDT -999. 250 SSI. bDT SSHV.LDT -9~9.250 S1Pfl.bBT G~. !,.,DT -909.250 TE~S. LDT H'FE~. I~DT -999.250 MPHI.CNT T~,,tR~, .C~'4. -999.250 ~YPOR.C~,~T CWTC.C[~T -9°9.250 CFTC.CNT MPES.CHT -999.250 DT4~.iTP -9q9.250 DTPP.PTE DTTD.TT~ -9o9.259 CFt~P.DSI D~I.. !Tm 320.293 DTP!.PTE P~.DS'I -909.250 ~S~C.DSI **** FT !,,E T R A I [:[~2P **** S~,RV !CF_, : ~'blC VFR,~IaN : O01CO1 !)~T~ ~' o4/03/31 ;~aX NEC SIZE ! 1 094 1.2:25 -47. 656 GR. DTE -0. 060 -0.002 PEF.LDT 537.000 !.,U. b~T 251.1.25 85'2. BDT 2600,000 MTEX,hDT 37.,!66 ~TNR.CNT 1,30 625 HT~N,C T 123.?~8 DTRP.iTP 0.96K C~,)TP.DSI 309.560 DTRI .ITP ?. 341 GR. -999.250 !DPH.DTE -999.9.50 ILO.DIE -o99.250 IDOF.DTE -999.9.$0 TIRM.DTE -999. 250 G.P..DTE -999.250 HTEN.DTE -999,~50 PEF.LDT -999. 250 LU. BDT -999.250 SS2.LDT -099. 250 !.,SRH. BDT -999.P50 RT~.CNT -99~.~50 ~C~;T.CWT -990.~50 GR.C~T -090. -O99.~50 r)T~P. ITP -~9~.~50 46 o i 215oo 3.082 495. 500 384,.750 2.'! 70 !30.625 1984.696 46.000 91.,P.500 3 288 120:963 309. 560 39.57~ -999.250 2999'250 099.250 -999.250 -999.250 -999.250 99.~50 -099.250 -999.250 -999.250 -999.~50 -999.~50 -o99.~50 337.709 -990.250 TE N,S,. DTF. DPk~! .LDT ObS. LOT Ll.,. LSHV. r.,,D ~ L I.,IR ~. bDT MR ES. LOT T~PH, CNT T R N S ~ ~ N T DTTP,PTE IPT~ 1..PIE C'IMP.DTE C I L ~. P T E I ~'~, 0 F. r?TE I IX,SI. DT~: T~,NS. UTE I')~H Y , t,DT OhS.bDT b!.,. ~,DT LSHV . I,,DT LURH. LOT MR ES. LDT TNP~.CNT RCFT.CNT TENS. CNT DT4P.PT%? DWT°.PTg CHR~ ,DSI PAGE: 31 2600.000 28.181 -0.021 2~9.250 1419'000 2.172 '0.060 35'766 54,~ 562 2600:000 124.345 195.401 291.!10 0,903 -999.250 -99~:250 '99 250 -9~9.250 -999.250 -999.250 -999 250 -9992250 "999,250 -999.250 -999.250 -999.250 -909'250 -999.250 -999.250 -999.250 -999.250 0.000 ;,IS ~a~e Verif~cation ;chlumberg'er AlasKa Computtne Center 31-~AP-1994 1,2:25 32 S~:RVICZ : ~L~C D~TE : 94/07/31 ~'~AX REC SIZE : ~.0~4 F'IbF ~Y'PE L~S~ FILE RAW (]PEN' WOLE aAI, N PASS Curves and log header data ior each run and tool stri. nq In separate iii. es; Tool String ~I fo Sadl~roc~,it. run ~resent'ed first', (primary depth contro,l st. rin~ used to deDth shift t,~e'Sadler interval) followed bY fi.les for other main ~)ass tool strln~s ~)er run,~ DFJPTH I~4C~EMENT: 0.5000 V'E'4DOR TOOL COD['; START DEPTH ....... ..... ............... o '12 ~ 0 a., 0 !211,4,0 ~2!14,0 CN $ # LOG HE~DER DATA S [.)F"PW i ~ E '~IME CTRCU[,ATIr)N TD I~G~E',~ (~T): · [)P LOC TN~E~V~L I,OGGING RPFED (FDHd) T(]f]!,., 5'rR~C (TOP V~r,-:DOP TOOL C[~[)~7 ~:Otgl, ~YPE T c c DSI i)Si STOP DEPTH 8900.0 8900.0 Bgo0.o mmmmmmmmm AIIXILLI~Y AUXJ bl,Ih~{¥ I'ELF~ETP ~ CARTCTE, GE G~A ~y ChRTR![;GE DIPOLF SON.lC D%POL~ D!POL~ $UNIC PlPObE J. 3-OAN-94 2230 12-JAN-g4 12o0 13-JAt';-94 !,21.50,0 12~.33,0 gqO0.n 12104,0 TOOL TCC B 1057 SGC SA 55'1 SGD-TA~ SP~C-A~ ~$IJ-BA SNDX-A~ .,IS ~'ame verii!cat.l,,on L:i,$ti. nm ~chlumherr.~er Alaska Computl. no Cer~ter 31-~A.R-199~ ~2:25 DTE D.. TM bDT CN'f S PNA$OR INDUCTION PHASOR TNDUCT!ON NUCt~EAR $~RVICE C~RTR. DENSITY SONDE AND CASING DATA DRII..,I,.~R8 C.AS,I~'G DEPTH (FT)t !,.,OGGERS CASING D'gPTN P, OR EHO[,.,E CONDITIONS ~"UD TYPE: ~4 t..I D DENSITY ?4UD VISCOSITY (S): FI..,'t~D LOSS (C3): F~ A.X I ~ U~>i RECORDED R~S~STIV[TY (OH~M) AT TEMP~;~ATUPE (DEGF): ~,~t,JD AT ~OTTO~ ~4UO FII.,TRATE AT (~T) ~[,,ID FILTRATE AT g[.lP CAKE AT TOOL ~¥P~,; (~;P'!TUER~.~Ab OR THERMAL): · OOL STANDOFW (!N): DIC 41a DIS 42!. ~SC 773 ORS C 19o8 CNTN 340 :1. 2.25 0 8900,0 80O0,0 55.0 7.2 8 0 2,040 51.0 0,694 163,0 1,290 5!.o 0.439 ~.63.0 2,1~0 5~,0 PE:r~ARKS: RA~; !rlgI.,[.'. DgTA FR. Oi,~ RUN 2 ~ATA HAS ~,~OT BEEN DEPTH. C~RRECTED. TLB ~Nn ~[,~ BATA [']N FIELO TAPES FOR Rl. tf,,~ ~2 ARE NOT VAI,1D AND THER~FORF NOT PRESENTED I~ THTS FILE, S bTS FORMAT DATA TaBlE TYPE : CO,TS TUNI VALU DEFI ........................ ' ........... .... ..... J .............................. ~'~! NF~RTH CQFIF !!'.J[,h;T Field ~ame W~ NCII~ SLJ~F!$N #3 Well Name AmI~ 50-g$t-2009o !PI Serial ~umber f"l., 124o' F~![. & gao' PHI, wield [,ocation $~CT 6 Section TqW~ llh TowBsbt. p ,,IS 'rave Ver~f:icat!.on .~chlumherqer AlasKa Comoutino Center WIT~ SON PDA? VT VT ~T ~'T ~1C3 D v b [' 3 M~T DEGF R~C~ O.H~M r~ C S T D E ~ F TCS TI, Am ~ange County State or Province Nat, ion Witness ~ame Servl. ce Order Number Permanent datum ~levation of Permanent Datum Lo~ ~eas~red From ~bov~ Permanent. Datum Elevation of Kelly Bushin~ Elevat onl of D~rricK Floor Total ~eoth - nrlller Total DePth - booqer 9w KENAI ALASKA 629408 mi, ~ O, 132, 1 32, 1.47~5, 1,4682. 14658, 2602. POLYNER $OLTE~ 7 , 0 ~60o0ol 2,o~ 15: O0 00:30 06-~AP-94 200 , Eot, tom bo Interval, TOp [,oa lqn'terval Orll],i6~ F.l. ui.d Type Drilling Fluid Density Drill. lng Fluid Ph Dril!ln~ Flui~ Viscosit,~ Dr!l!i.n~ Fluid boss ~esisti~itY oi ~iu~ Sample ~lud Sample Temperature Resist!vi. tV of ~:~ud Fll.trate S ~'ud Filtrate Sample Temperatu Reslstlv~,ty of Mud CaKe Sampl ~ud Cake Sample Temperature Time Circulation StODped '~IME LOGGER ON BOTTO~ ~ottom Hole Temperature T~.B!,E TYPE : CUPv INDUC'!'I~Jt: UEFP PNASOP CU~'DUCTIViTi Phasor Dee~ Resistivity TN_~U('T![)~,! ~EDIt]~ F~ASOU CONDI~CTIVITY Phasor ~ledtum ~esi. stivity ~nductlom Calibrated Freouenc~ }mductio~ ~eep [~uality Factor ~nOuctio~ ~edlum ~ual itv Factor meep Imduction Real Intermediate Cmnduct!vltv ~eep [mductlon Oumd Tntermed!ate Conduct~v!tv ~e~ium Induction Rea!. Intermediate C~nductiv]tV ue~i,~m In~uction [4uad Intermediate Co~duct~.vttV SFL ~esistIvitv Unaveraged Spont. ame~us Pote~tla! hPI-Oorrected Gamma PaV Surtace Vens~om ~,IS Tane veri. ficat, i. on l,isti, nc~ ~.chlumberger h!asKa Comput. I. nq Cehter 35 ~,Un ~esl. st Iv.itV Head Tension ~ul~ Dens:it¥ Del. ta ~hotoe!.ect:ric Factor oua:l, ltV contro.'l o~:~ ],.onq spacing for LOT Oualit. v control, on short spacing I~Ong SDacj, Dq C'o~Dut. ed Count Pate bong l.J~%::)eri-2 Wlndow Co!Iht Rate (LUI+LU2) Long Lower Window Count Pate [~i. tholog %~indow Cou~t Pate Short Spac.!.nq 1 window Cot]hr Rate ,Short 8DaCJ, Dq 2 Window Count: Rate Long ~ ~Dacing Bi. gh Voltage Short Spaclnq Wi~h ~oltaoe Short Spac.],.no ~ Dens~tV Long Sr~ac.ing BU]..~ Density [.,o~q l...IDper Bulk Den. sitV Ce 1. inet ~P!-Corrected Gamma Surface Tension MUd ~emperature ~'~UD ResistiVity Head Tension Comnensated Neutron PorosZtV, SS Hatrix, calf & ~ead time tort, ~aw Thermal ~,~eutron ~atio Thermal Neutron Porosity Thermal Neutron ~atio Calibrated ~eutron ~oroslty f:rom ~]n ~nplication ProGram RAW ~'AR CNW CO~INTS Corrected Near Detector Count Rate Corr~ctea ~ar Oetector Count. ~PI-Correcte~ ~amma Pav Surface ~UD ~esist~v!tv ~ud Temperature ~eaci Tens ion DELTA-T CO~FPESS~O~AI., ~F ,'~fl~;OFOL, F qECE. TVER (P&S) DELTA-~ Cg',~P~ESSIO~A}, PF MONOPF]LF: Ti~NS~'ITTE ~ELTh-T Cg~P~ESSIONAL UF MQNOP~LE TRh{,~S~4TTTER (Pgs) CO~EPF, NCE C{]~P~.E:SST'L)~.}.~L P&g k~npE, R=CEIVEjP COH?]RE~CE CO~PRESS~(.)~!., P&S ~[)DE 'IRANS~ITT~7~ Poisson'~ qatio PAGE: 36 ** 8E'~T TY.. g CHA ,~iANF 8FRV UNIT $gRV'IC~ P I A I API FIr,E NUMmi NU S ... R R PROCESS ID ORDEP ~ LO(; TYPF CheSS ~[ID NU~B .... SA, ~p~ EL.~iM CODE CHEX.. ) [3 ~: P T F T 62 o 4 o ~:~ O 0 0 n 0 00 0 4 ~ ! 4 6 ~ CTDP DTE ~i~HO 62n409 O0 000 n0 O 4 1 1 4 6R 'IDpt~ DTE 0~,~4 6294a~ 00 000 00 0 ~ ! i 4 6~ CT~V DTV ~z~iin 620,t0B O0 000 OO 0 4 I ! 4 6~ I~'PH DTF O~a~~ ~'29408 O0 I.)O0 O0 0 4 1 ! 4 68 Ir~ nw~i a~ 6204n~ n,~ , _ ........... ,, OOO O0 0 4 1 I 4 6R Ir, Or D-T~ 62940a O0 OOO O0 n 4 1 1 4 68 IUQ~ ~TE 620408 O0 O00 O0 n 4 I I 4 6~ ITRn UTE ~,t~H~ ~2q4qg 00 000 o0 0 4, I I 4 68 i!XO DT= V.~HO ~20408 00 000 00 n a. ! 1 4 b8 ITR~ r)T~ ~'HP a294n8 O0 000 00 0 4 1 1 4 68 IiXv riTE hs~i,tO 6294n8 O0 000 0O 0 a 1 1 4 6P ~bT, UTS r3H;qv ~294n~ 90 00[, o0 0 ~. 1 I 4 68 Sv UT~ ~V 629408 nO OOO O0 O 4 ! I 4 68 G~ nTp GAPT 62040~ no OhO oo 0 4 i 1 4 6~ T~tlS O'.!7 ~ !,.,~ A29408 OO 0o0 oO n 4 ]. 1 4 6B I. iTE~ UTE D~TGW 62o4~ 00 0n0 n0 n .l 1 1 4 6~ MFES ~Tr OH~'..' ~20409 O0 0n0 o0 0 4 1 ! 4 ~B 000000000~ 0000000000 O000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 0000000000 0OO0000000 0000000000 0000000000 0000000000 0000000O00 00000o0000 ~IS Tape Verl. ficatio. !,lstino ~c~lumberger Alaska Comptltin¢~ Center 3J-~R-1994 12:~5 3¸7 ~ Sr:RV tJ Iq~ V aPI ~P'! A I ~ H T E ~.~ D T ~ b B 629408 00 0 o 0 o 0 0 RHO~ LOT G.IC3 629408 O0 000 O0 0 D~Hn ~[?T GIC] 62~408 O0 000 O0 0 P E F ! :, 0 T 629408 00 000 00 0 [) I.,,S LDT 62040g O0 000 00 0 ~88 l.,,~* 629408 00 ~.,'. 000 o0 0 bS t,,DT CPS 629408 O0 000 O0 0 L ~ ~ I., I ) T C PS ~ 2 g 4 o 8 00 000 00 0 L ~ CPS 629498 90 OOO O0 0 t, ITH ~DT CPS 62o40~ 00 000 O0 0 581 LDT CPS ~20408 00 000 00 0 , ~ ...... ~ ,.. S ..... 2 LD* CPS 629408 00 0o0 n0 e L S H v ~. [:'~, ? V 6294 O ~ 00 000 00 0 8SNV tbT V 620408 00 000 O0 0 SJR~t !,[')T qlC3 62940~ 00 000 00 0 b.~.R ~ LDT (';/C3 62940B O0 000 oO 0 , .., ... % I '~ "~ I,l~.~[* [.,[...r (:,,/L3 620408 O0 000 O0 0 C~I,,; LDT Itc~ 620408 00 000 00 0 G ~ 1.,'0 g G .a p I 62 O 408 00 0 o 0 00 0 '1'~ u s LDT L,[; ~29408 O0 000 O0 0 M~E'm t~O~ DEGF 629408 00 000 00 0 NPE,S LOT OHMm 629408 0() 000 O0 0 tqTEU [,;DT 'bi} 620408 O0 000 O0 0 NPhT CNT P[~ 629408 o0 000 00 0 RTNP CNT 629408 00 000 00 0 Tt~P~ CNT .p t..I 62~408 O0 000 00 O T~,a CNW 620408 00 000 00 0 NPOP CiqT pl.l 620408 O0 000 00 0 ~CNT CN~ CPS ~2o4:0B O0 000 O0 0 RCF· CNT CPS 62°408 00 000 00 o C~TC CNT C~S 629408 00 000 O0 0 CFTC C~,!~ CPS 629408 00 000 O0 0 T~N,~ C ~',,i T [,g 620408 O0 000 09 ~ aPE:S CN~ O~H~ 62~408 00 0O0 O0 o NTE;v CNT DEGr ~29408 O0 000 O0 0 H* E~'~ CNT bn 62°408 O0 000 0(') 0 D~4~ ~I'E 629408 no 000 0O 0 t.,~ 4. IT= 629408 O0 00() O0 0 D*R~ PT? 62o40~ O0 000 o0 0 DTP~ TTP 62~40g 0(.) 000 00 O D~T ~ tTP 62040[~ 00 000 O0 O C~R~ DST 62940~ 00 ooo O0 n CYtI:~ DS! 629408 O0 000 O0 0 [')T ~.~ ? PTF ~29408 O0 OOC~ O0 .0 I)T~ ~ IT~ 62~408 oO 000 O0 0 DT~? oT~7 620408 nO 0n0 00 0 [)~R9 TTP 620408 O0 000 oO 0 PP DST: 629408 00 000 O0 0 4 4 4 ,~, 4 4 4, 4 4 4 4 4. 4 4. 4 4 4 4 4 ..,5 4 4 4 4 4 4 'I L [.1 u B ~:! tJ ~! ~ 81 Z E ~ r 0 C g s $ .,, U'm ¢ $ .A ~ p E b E N C 0 D f H E X ) 1 i 4 6~ 0000000000 ! I 4 68 0000000000 ! 1 4, 68 0000000000 I 1 4 6a 0000000000 ! I 4 68 0000000000 1 1 4 68 O000000OO0 1 I 4 6~ 0000000000 1, 1, 4 68 0000000000 1 1, 4 68 0000000000 ! 1 4, 6~ 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 I ! 4 68 O00OOOOO00 1 I 4 6~ 0000000000 1 1 4 6~ O00OO00000 I 1 4 68 00OO000000 1. i 4 68 0000000000 1 1 .4 6~ 0000000000 I I 4 6~ 0000000000 1 ~ 4 68 0000000000 I 1 4 09 0000000000 1. I 4 69 0000000000 1 1 4 6~ 0000000000 1 1 4 69 0000000000 ! .1 4 6a 0000000000 1 1 4 68 O00OO00000 1 I 4 6~ 0000000000 I ! 4 6o 0000000000 I 1 4 b~ 0000000000 1 t 4 68 0000000000 1 i 4 69 O00OO0000n ! 1 4 6~ 0000000000 i I 4 68 0000000000 ! 1 4 6~ ooo0000noo 1 I 4 6n 0000000000 1 1 4 68 0000000000 I 1 4 6e 0000000000 1, I 4 6~ 00oo0o0noo 1 1 4 6R 000000on00 I I 4 68 0000000000 i I 4 6? O000000000 1 1 4 68 O0OnOOO000 1 I 4 6~ 0000000n00 1 ! 4 68 OOOO000000 1 t 4 68 0000000000 ! 1 4 6q 0000000000 ! 1 4 6~ ,:)O000nO0(~O 1 1 4 6~ 0000000000 ! 1 4 68 0o00000000 ! 1 4 98 O0000OO00O I 1 4 68 0o00000000 ,~'IS Tace verification listt, no ;chlumher'~er AlasKa Comp~lt,i. ng Ce~t;ex' 3!-~AR-1994 12:25 AGE: 38 DEPT. 12194.000 CiDP.DTE -~56.000 IDPN.DTE 12.453 CI~,tP. OT~7 IMPW.DT~ 9.609 IFRE.DTE 20.000 !DQF.DTE 3.000 I~QF.DTE I~'RD DT~ -257.750 IIXD.DTE -460.750 ~IR~. DTE -869.500 S. VLI~. :9~1;E 13.172 S~, .DWE -18.219,, GR.DTE 95.:125 i~'Eu. D'r~l 149.7~8 ~RES.DTE 0.627 HTEN,DTE 22.109 DRHO.SDT 0.064 PEF.LDT d.520 OI,$. bDT 0.091 OSS.LDT L ,S . b D T 220 . 000 L tJ ,. L, D.;[~ 218 ] 75 !,., 1,,. b p T 11. 0 . 875 SS~ ..LDT 56.6~5 SS2.bD 96:~75 LSHV. LDT 1,263. 000 5SHV.LDT S1RW.LDT 4.863 '[~SR !"]' ' l~D T 2.635 LI,!RH. bDT 2.672 CALl .LDT G~.LDT 95.125 TENS.GDT 3575.000 ~TEa.hOT 149.788 ~RES.LDT HTE~I.!,DT ~2.109 NP~I.C~<~T 39.9~6 RTNR.CNT 4.262 TbIR,~.C~',~T 4.2 9 NPOR CNT 5~ 629 RCNI,.CYT 1432 451 RCFT.CNT CNTC.CM~ ~439'239 CFTC.CNT 3~4.465 GR.CMT 95.125 TENS.C~,IT q~ES. CN'T 0.697 ~TK~4.C ~,'T 149.788 HTEb'. C~IT 2~. 1(~9 DT4P.PTE DT4D, ITP -999.250 DTRP.PTE -~99.~50 DTRP.ITP -999.250 DTTP.PTE DTT~ ITP -999 250 CHPP.DS'I -QgQ 250 ~HTP.DSI 999.250 -9o9' ........... " .... "' ' .... .259 DT~2.PTE -~99.250 ~)TR2.ITP -999.250 CHR2.DS!' PR. DS! -999. 250 GR.DSI -q99. 250 D~pT. 12000.000 CIDP.DTE -~56.000 ?DPH.DTE 5.766 CIMP.BTE I~PW.DTE 5.895 'IFR E. !.')?E 20.000 !DQF.DTE 0.000 IIRD.DT~ -257.750 IIXD.DTE -460.750 !IRM.DTE -a69.5()0 IIX~I.DT~ Sw[,,~ .'DTE 5.367 SP.DTE -3.91~ CR.DTE 60.094 TF.Ib,}S. 9T F', MTn;,'. DTW 14-9.7~8 MR. ES. DTE 0.627 HT~:N. OTE 12,t3.000 RNO~. LI.')T !.'.)~ h o. !.,[)T 0.0~4 PEF.LPT .t.047 OLS.bDT 0.09! QSS.LDT La.!,9~ 220.000 [.,U. bDT 218.375 LL,. bDT ~ lO.a'75 PI'T~i.bDT ~81 .LDT 56.6~5 SS2. Lr)T 96.375 [,SNV. bDT 1263.000 SSHV.LDT S1RH.T,DT 4.863 LSRH.LDT 2.635 LtI~H.L~T 2.672 C~bI.LDT HTE~. ~,{')T !2a3.000 ~PHI.C~T 28.60~ PTNR.CNT 4:.~62 T%IPH.CNT ,r,,~ a .ca~ a.~o9 MPOR.CNT 52.620 ~CNT. C~3T 1432.451 RCFT. C~qT C~'TC. c~,~* 1439.239 CFTC.CN? 34~:.465 GR.CNT 60.094 TENS.CNT ),i ~ E.~ .CNT 0.697 UTK~I.CNT l~9.789 ~T~'TN. C~'T 1243.000 OT4P.PTE DT4P.ITP 74.259 DTPP.PTE 76.95~ DTRP.ITP 76.05~ DTTP.~TE D'rTm. ITD 71.565 CH~P.DSI 0.919 CFiTF'. DS l 0.966 DT~2.PTE DTN?. I'l'P 131.6o4 DT~2.PTE 135.349 DTR2.ITP !35.34g P~. DS~ 0. 267 CR. DSI 55.537 Owp? i!50O.OOC, CInP.DTE -256.000 IDPH.DTE ~.273 CIMP.DTF. I MPF~: D-.TF 8.3~9 IFRE.DTE 20.000 IDOF..DTE 0.000 I'Ik~. ~T~ -257.750 IIXD.DTE -460.750 I IR~. [')TE -8~9.500 I!XU.BTE MTEU.D!'E 149.7~8 URES.D~E 0.~27 ~TEN.P~E 1084.000 DPH~. I.,DT 0.019 PEF.LPT 3.000 (~1,5. bDT 0.09l OSS.L9T LP, I,[;,T 220.000 LU. L, DT 2i~.375 T.fh. I,DT 110.875 L, ITH.LDT -870,500 2.000 -802,. 500 3575 .:000 I', 799 '0.156 23 484 x o ooo 12.2,,50 0'. 62'1 52.037 301,862 3575.000 - 999,2:50 -999. 250 -999,250 -870-500 0.000 -B02.500 7065.000 2.538 -0.t56 23.4~4 1301.000 12.750 0.627 52.037 301.862 7065.000 74.259 71.566 131.694 0.957 -870.500 0.000 -802.500 6365.000 2.547 -0.156 23.4~4 ,I$ Tare Vet!fi. cation Listing ;chlumberoer AlasKa ComputIno, Center DEPT. 11000.000 CIDP.DTE I~P,q. DTF .~. 2.242 IFRE. D~r,E: ITRO.DTF, -257.750 !iXD.DTE S~r!,U. DTE ! 4. 328 SP, DTE NTE~.Y)TE 149.7~8 ~RES. DTE DPH~. LDT 0. ()! 3 PEF. LDT bS. LDT 2~0. 000 ~,U. LOT SSI .LDT 56.625 582. bD't $~ RI'{. LDT 4.863 LSRH.LOT GR.LDT 61.063 'rE~S. LDT H'rE~, LD· ] 102.000 NPHI,CNT TNR~ .CNT. 4.299 ~POR,.C~ T C~,~TC. C~T 1439 239 ~tP ES. CN'~' 0.627 qTEM.C~;~T DT4m. ITP 73.969 'OTPP.PTE DTTP.ITD 73.138 CHPP.DSI I)~ P. T T~ 13],729 DTP2. PT~] P~. PSI O. 2~0 GR. D8I D~TPT. 10500.000 C!DP.DTE I~4PW. DTE 8.9~5 TFPE. DTE] I ~'R.O. DTE -257.750 8FLU. nT~ 7.734 SP. DWE DnH~.T...D~ O. 1 n8 PFF. bDT L~ . r,D~ 2~0. 581 .T.,O· 56.625 SS2.LDT SJRH.LD~ 4.86~ !.,8PH. LDT G~.L[,~ 37.1~5 TEt~8.LDT HTE~. T,Dn' I 106.~00 NPMI.CNT C~TC.CNT !439.239 CFTC.C~'r MP[jS. CNT 0. ~7 ~,iTF~. C~T DT4P.ITP ~0.98~ nTPP.PT~; D?TD.ITD 75.9~9 CHPP.DS1 DT~9. ITP 1~ 4.4-~ 5 DTP2. PTE PP. DST 0.27 31-~Are-1994, 17::25 96.375 1,8HV. hOT 2.635 I,,URH. LOT 1 ~.75 ~1. PTNR.CNT 52.62~ ~CNT.C~T 344..4a5 GR.CNT 1,~9,788 H~.,..,'~,~' E .CNT 7~. ~ 77 DT~P.ITP 0,9~8 CHTP.DSI 38,50~ DTR2,ITP 36.049 -256.000 IDPH.DTE 20.000 IDOF'. O~E -460.750 tlP~q. OTE -37.031 GR.DTE 0.627 HTFN.OTE 3.010 ~IE, 375 l,,b, bDT 96.375 I,,, 8 H V. L O T P,635 LUPH.LDT 6005.000 ~.TEt,,i. bDT 20.~64 ~T~ ~. C~,]T 52.629 RCNT.CNT 344.465 GR.C'NT ~4g.78P HTEN.CNT 74.799 OT~P. ITP 0.95~ CHTP.DSI 141.633 ~TR2. ITP 57.747 -256.000 !I)P.H. DTE 2 C). 000 -460.750 ,TIR~.OTE -7.5160.627 ;iTEN, DTE ~.~.21 OLS.hOT 21 ~:~. 375 [,L. bDT 96.375 [,8~V. bDT 2.635 LU~g. LDT 5870.000 MTEM.bDT 27.286 R'I'~R. CqT bP.62~ PC~'T. C~,~T 34~.A65 GR .CNT 1.49.7~ ~6.007 UTNP.I~p o.ga~ CMTP,DSI ~b6.39g DT~{2. ITP 36.613 -256.000 IDPit. DTE 2n.o00 -460.750 iIP:q. DTE -1 ~. O78 Gk. DTE 0.627 1263.000 2.67~ ]49.788 1,43~. 451, 42.5,31 1.084.000 7 P. ,177 0.953 138.5O8 13..~98 0.000 -869.500 6J,,.063 1.],02.000 0.091 !1.0.8'15 1263.000 2.672 !49.788 1432.451 6 ~. 063 110P .000 7A.799 0.824 141.63] 9.805 0. O00 -869.500 37.125 1106.000 0.091 110.g75 1~63. 000 2.67? 14q.788 4.2O2 143'2.. 451. 37,125 1106.o00 ~6.067 0.055 157.471 5.277 n.no0 -~69.500 56.006 1~79,n00 8SHV.LDT CALt,LDT MRES.LDT TMPN.CNT RCFT.CNT T~NS,CNT DT4P-PTE DTTP.PTE DTM2,PTE CHR2.DSI CI~P.DTE iTX~.DTE RNOB.LDT OSS.LDT LITH.LDw 88HV.LDT CALI.LDT MRES.LDT TNPH.CNT RCFT.CNT TENS.CNT DT4P.PTE DTTP,PTE DTM~.PTE CI~P.OTE TFNS.DTF RHOB.LDT OS$.LDT b!T~,LDT $SHV.LDT CALl.bDT NRES.LDT TwPH.CqT RCFT.CNT TEN$.CNT DT~P.PTE DTTP.PTE DT~,PTE CHR2.DS? CIMP.DTE iMWF.DTE ITX~.DTE TENS.DTE PAGE: 39 13o .Ooo 15.516 0,627 52,037 301.862 6365.000 74,802 77,427 128.867 0,971 -870'.500 0,.000 -802,500 6005,000 2,505 ~0.1,56 3;484 1301.0:00 15.422 0.627 52.037 301,862 600~ 000 7 ~969 73.!38 133,.7~9 0.970 -870.500 0.000 -802.500 5870.000 2.445 -0.156 23.484 1301.000 16.906 0.677 52.037 301.~62 5870.000 ~0.986 75.909 143.469 0.320 -870.500 0.000 -802.500 5615.000 2.470 ~IS Ta~e VerJ, flcatiom Llstino ;cblumber(~er AlasKa ComputIno Center D ~ ~-~ 0. [, D ? 0.094 P E F. L P T ~S!.LD? 56.675 8$2.bDT S ! 'R~'~. LDT 4.863 LSRi'{. LDT G~. LDT 56.90O HTE~;. LDT 1179.000 NP~I. C~T T ~ R a,. C N ~ 4.299 N p 0 R. C N T C ~ T C, C N T 1.439.2 '39 C F T c ' C MnE;~,CN~T 0.e, 27 UT~a,CNT DT4~, I'TP 85.303 DTPP.,PTE; DTTP.]TP ~8.!00 DT}¢~. !TP 150.872 DT~2,PTE PP.DSI 0.265 GR.DSi DFPT. 9500.000 CiDP.DTE I~PH.DTE 9.8!3 ITRn.'DT~] -257.750 IIWD.!)TE S ~.' [,,U, DT~ 7,273 S.P, I)TE MTE~.DTE I49.7~8 ~RES.DTE [)RH~, LDT O. 052 PFF. bDT t, S. 5 D T 2 ~ 0.00 0 t, U. I,,, O T SSi S1R~.LDT 4.863 LS~H.LOT G~.LDT 47.406 TE~S. bDT H TE~,~. Li,')T 11~1.000 MPHi.CN'T TNR~.C;'~T 4.299 NPOR.CN'I, CNTC,CN~ 1439.239 CFTC. C'~T DT4D.iTP 86.623 DTRP.PTE D~Tm.!TD ~0.8~1 CHPP.DSI bTM~.!TP 161,7~1 DTP2.P~E PP. DST' O. 299 GR.L)8t DKPT. OOOO,O00 CIDP.DTE I%~Pw. DT~] 7,906 I TRD. DT~ -257. 750 IlXD. DTE SFL~. D'.r~ 7. 250 F~Ty~ .9%~7 149.788 DPHO. LDT O. 034 PFF. LDT L~. L9~ 220. OhO LO. bDT SS1.LDT K6.625 SS2.LDT S 1 PM. !.[)T 4. 863 T,SR ~,l. LP.T G~.LDT 53.0~4 TE~JS. LDT HTE~'. l,DW 1 ! 90. O ~0 NPH!. C~T T,R t. CN · 4.299 ~POR. C~ T C~'TC. Ck~T ~ 439.239 CFTC.CMT NPE5. CNT 0.6~7 ~,!TEb. CNT I)T4m. I TP 81.2 ~0 DTPP. PTfj 9T~'P. T TP 7 b. 797 CHPP. DS I Ow~?. T'I'D 164.219 ~TR2.PTE PP. DST 0,339 3J-~AR-~994 12:25 1 a. 375 LL.:bDT 96. 375 LSNV. bDT 2,635 f, U ~ H. b P T 32.644 ~Tr,~R.CNT ~ 2.629 ~ c N 'r. C N T 82.506 DTRP.ITP 0,q50 CI.tTP. DSI 156.603 BTP2.!TP 53.0o8 -256.000 !DP[i.DTE 20.000 IDOF.DWE '460.750 I IPI'~'. DTE - 19. 406 GR, gTE 0.627 !"tTE ~,J. DTE 5.066 OLS.bDT 218. 375 I,,b. LDT 96.375 5300 0~0 ~TE~. bDT 34~ ~ ~TN~.CNT 5~.629 RCMT.CNT 344. 465 Ga. CNT 140.78a H'I'K~. CNT 88.557 9T~P.ITP 0.842 CIiTP. DSI 1 ~6. 359 39.770 -256.000 !I)PH.DTE 20.000 TpOF.DWE -4b0.750 TI. Pa. D'~E -66.625 0.627 HTF!~.DTE ~.434 OLS.LDT 21~. ~75 Lb.bDT 96.375 LS}iV.LOT 2.~3~ LURH.LQT 506o.000 ~TK~q. L, DT 26.670 PTNR.CNT 5~.629 qC~T.CNT 344.465 85.7~3 QTRF.ITP 0.~66 CH~'P.PSI -999.~50 nTP2.ITP 31.117 0.091. 1263. 000 2.672 !,40.788 4.262 i432.451 56. 906 I ~ 79.000 82.5O6 156'603 10.219 0.000 -869.500 47.406 1181.000 0.091 110.875 1263.000 ~ 67~ ~.262 1432.451. 47.406 1,!81.000 :ooO !66.359 10.313 n. O00 -969.500 53.09,~, O.091 J. 10.875 !263.000 2.67~ ~49.788 4.~6~ 1437.451 53.09~- !19o.o00 85.703 0.891 1~0.188 OSS.LDT LITM.LDT SSBV.LDT CAbI.LDT M R ES. I,DT TNPH ,CNT RCFT ,CNT TF~NS.CNT DT4P.FTE OTTP.PTE CHR~.DSi ClMP.DTE I~QF.oTE IIXU.DTE TENS,DTE R;tOB,LDT OSS.LDT L!TH.LDT $SHV.LDT C~L!.LDT ~RES.LDT TNPH.CNT RCFT,CNT TENS.CNT DT4P.PTE D~TP.PTE DwM2.PTE C}tR2.D$I CIMP.DTE I~QF.DTE £IIM.DTE TENS. DTF RHf!n. LI)T OSS. I, DT L Y TH. LDT SSHV.!,D? CALl .LDT MP~iS. LDT TNP~ .CN? ~CFT.CST DT4P.PTE DTTP.DTF CMR2.DST PAGE: 40 -0.156 23'484 1301.000 ~4.063 0.6~7 52.037 301.862 5615.000 8' 303 I50.872 0.967 -870.500 0.000 -802,500 5300,000 2.278 -0'156 23.48.4 1.301,*000 1.3.5~3, 0.6~7 52.037 301 862 5300:00O 86,623. -999..250 161.781 0.'720 -870.500 0.000 -802.500 5060.000 2.486 -0.156 23.4~4 1301.000 19.328 0.6~7 52.037 301,~62 5060.000 81.2~0 76.797 -999.250 0.000 Tape Ver:~f!.cat.ion Listtno ;cblumbercler Alaska Comput!nc3 Center t') E P T. 8795.000 C I,~pw. pTE I 950.000 I I RD. DT~ -257. 750 SFL,.DT~ 0.448 ~TE~., '!E 149 788 M~ES DTE .... ~ ~ ~ ~ . LS.LgT 220.000 LU. SS! .LDT 56.625 SS2.LDT S 1 R H. L P T 4.863 L 6 R H · L ~ T G~. I.,DT ~8..5~1 TE~,5. LDT HTEN.LDT ~,0o4.000 NPNI',,CNT T ~'~R. ,~,. C N ~ 4.299 N p 0 R. C N T " ' C ~.~ T (,,, N T C. C N' T ~ 4.39.2 ] 9 CF T C. C ~.~: 'I~ ~ES.CNT 0.6~7 ~TE~4.. DT4P. ITO -999.250 DTPP.PTE DTT~.~TP -999.250 CHPP.DSI p~ :DST -999.2,~0 (;R.DSI 31-MAP-'1994 12:25 PAGE: 4! - 256.000 ! P P ~:[. !) T E 1950.000 C .T. M P. D T E - 870 ,. :500. 20.00 <) ~ D (:) ~'. [) T E 0.000 1 ~:~ <'~ ~. D '.t'~ E 0.000 -460.750 !In~,~.DTE -869.500 iI:X~.DTE -802.500 -18~.625 GR.DTE 28.531 TENS.DTE 4695.000 '~ T ' 0,627 !4T~N.[) ~,, ],094,000 RMO~,.T...DT 1.59.4 17.938 OT,S. LT)T 0.091 OSS'LDT -0. 156 21R.375 L[, [..['1 110.875 LI']"[I.I.,,D~ 23.484 96. ] 7 s [, S H V. b D T 1263.000 6 $ ~,~: V. L O T 1301.000 2.635 LLiRIi. [...~DT 2 672 C.U [,,I. I, DT 12,000 4695.000 ~ TEl,1. i'.,DT 140[788 M~ES.LDT 0.627 47 783 ~TNR.~,~, 4, 262 TYPH CNT 52.037 N' CNT 1432 ,45t RCFT.CNT 301.862 52.629 ~C.,.~. . 3,4.4.465 G R. C N T 29.5 ] 1 "',r ~.: N $. C N T 46 g 5.000 ~4g'788 HTEN.CNT ~094.000 DT4P.PTE -999'250 ,. I~p -ggq.:~50 DTTm ~TF -999 250 -09o ~50 DT~P. ....... .. -q99.250 Ci,{TP. DS'I' -~.250 DTM2.PTF -999.250 -099.250 9TR2.ITP -999.~50 CHR2.DSI -999.250 -099.250 F!I.,1F NA~E: : EDIT SFRVlCE : D~T~ : 94103131 ~'iaX REC S?'ZE ~ 1024 FTLF TYPE : LaST FILE **** FTL~ ~EAOER FTI. W NA~E : FDIT .005 SFRVICE : WI, TC VFRglGN : nO!C01 D~T~ : 0410313]. FTLF TYPE: b~Sm FILE : FTLw ;{Fi aOEk FTL~ ~!,'.l ~, i~R 5 RAw OPE.~] q[.]l.~ M.AI~! PASS Curves and log header data for gadlerochit ru, mresented first interval) followed DY files for P~SS NI.JUB~R: 2 each run and tool string ir~ separate files; Tool String #l fo (primary ~euth control strln~ used to depth shlft the Sadler other ma.!p pass tool strings per run. WaDe Verification List',.i.n~ ;chlumberg~r A..lasKa Comput~,nq Center 31-~a~-!.994 12:25 PAGE: 42 0.5000 VENDOR TOOL CODE START DEPTH 13914'0 D'J' I!'~ 139t .~. 0 t. DT !3920.0 CNT i 3920,0 DATE I.,O(,;~ED: 80FTWA~E V~RSION: T I ~,iE CIRCULATION ?[) D~ILLKR CFT): TD LOGGEq(FT): · O~L STRING fTOP TO VF~,tDOR TOOb CODE ICC [)S I 9TF; DIE b P T LDT C~,~T # STOP DEPTH :1.2,.0 12126,o 12126,o 12126,0 12140,0 C ARTR l CakTR, NFUTRO~ EHO[,E ANO Ca$I.'~G D~!I,L~R$ C~SING bEPTfi bOGCE~S C~SI["~G DEPTN C DFG~'); 1.9-FE8-94 6C0 490 !700 18-FEB-g4 0230 19-FEB-94 1.394!,0 !.39~,0 ~2126,0 ...301..4,0 A~i~-AA 874 SGC SA 557 SGD-TAA SPIC-AA. 3! 8~Pk-A~ 33 8SIJ-~A 33 SNDX-AA 33 DIC E3 418 DIS ~6 421. ~:~SC ~ 7'13 D~$ C ! 9o~ C~T t.ia 340 9.625 !21.37.0 !.21.2.~.0 r:',O I, y Tv ER 13.5 184.0 SOT,YKX .,IS Ta~e ver. i~icst.t, on List!nO ;chlumberge:r Alaska Compnti. n° Center 3,!,-~AR-I 9q4 12:25 1 · 060 0. 197 1'5~0 TOO.b S?AtlDOF~~" fIN): ~.E~ARKS: R.,A%~! FIELD DATA FKOi~ Rt..!f~3, DATA HAS NOT SEEN [,)FPTH CORDL~CTFD. $ LIS FORMAT UA'FA 63.0 184.0 51...0 PAGE: 43 TYPE : CONS CN P,M]LT,[,~'P,q P~TROi.,~UN COMPANY F~,~ NO~.T},t COOK INLET ~u NCIU SiJMFYSH ~3 APIw 50-8 83-g0090 FL 1249' fiND g 980' SFCT TOW {,t 1 ~ ~ S~A~ ALASKA ~i ~ T ! O S A SON 6 ~ 940 ~ PDA~ Ct~D W~' 0, L~'F KB AP!.) FT 132. EwB ~T 132. EDF mT 131. TD[) ~T 14~05, T~L ~I 14692. B[,I ~T 14658, TLI t'T 260~. D~ POLYME~ 5OLTEX DrD G/C3 14,5 Dmp~ 9.4 f)~V S 65, D~L F3 Company Name FleldName 'Well Name API Serial Number Field Location Section Tow~%ShlP Range ~oqnty State or Province ~atlon witness Name Service ~rder Number Permanent datum Elevation of Permanent Datum Lo~ ~easured From Above Permanent Datum Elevation of Kelly ~ushlnq ~levation of Derric~ Floor Total DeOth- Driller Total neoth- Logger Bottom Goo i~terval TOD f,oo Interval Drtllinq Fluid Type Orflll. nq Fluid Density Orillinq Fluid Ph Prtlli-q Fluid Viscosity Qr~llinq Fl.u~.d LoSs ]t8 Tane Ver,ificatlon List!hq -~chlumberqer ~!asK'a Computfn0 Center 12:25 PAGE: 44: T I! N '? V A L U [) E F I R~S .~H~4~ 1'07 Pesist. vitv.i of Mud Sample 72. ~ud.SamP!e Temperature ~esistivity of Mud Filtrate S ~ud Flltrate Sample 'TemPeratu ~esi, st:ivltv of ~tud CaKe Sampl, t~ud Cake Sample Temperature Ti me Circulation Stopped Bottom Hole Temperature T~BI?[C TVPM : CLiPV OEF~ ~e INDUCTION DEE[' PgASO~ CONDUCTIVITY pn. asor Deep ~es~sti. vttv INO{.JfiTTOtl ~EDIIJF~ PH,ASO~ CON[)t.iCTIVI~TY Phaser ~edl. um ~eslst.ivi. tV Conductivity i[, l)eep Standard Processed Oeep I,4t. lction Standard Processed Resistivity Condt.lctivlty Ib ~ediu~ Standard Processed ~edlum Induction Standard Processed Pesist~.vitv Induction neep Quality F'a~qt. or Induction ~.~eOium (.~ual ty actor Be~r~ Imductl. on Ueal Intermediate Cor~ductl. vlty ¢eep Induction Quad Intermediate Conductivity uedium Induction ~eal Intera, edlate Conductivity uedlum Induction Ouad ~ntermeOtate Conduct~vftY SFI, Pesistivlty UnaveroqeO Spontaneous Potential .~PT-Cor.rect ed G~rnmm Surface Tension uu4 Temperature gUn PeslSttvItV ~ead Ten~lon gulk Density Delta Photoe!ect~ic Factor Oualitv control of lone spaclna for LDT Oualtt9 control, on short spacing ior bg'l' Long Soacinq ComDLlted COUl'lt ~ate l, ong Upper 1-2 Window Count Pate [,Onq Lower Window Count Pate t.,itholog ~dow Count Pate Snort gpacino 1 windo~ Count Rate Short Spac.l. na 2 Window Count Rat~ r..oDg Spacing .Hiqh Voltaqe Shot~ S~ac~na Nigh Voltaae gnort Spacina ~ Dens,tV Long 5pacinq Bulk ,IS Tape 'Verlft. catlon Listln~ ;chlumberqer A,lasks C..omputi..nq Center 3 !-~,:~ g~- 1. 904 12:25 45 DEF..T .... . .... ... ..... .... ..... ....... ..... .... Gn ~PI.-Corrected Gamma T E N g ~ U T i. . ......... ,~ r~ace ens O- i4TE~ ~Ud Temperature ~'{" E,~ ~ 1,~ D Resist~v~.ty HTE~ ~4ead I'ension ?~PF~I Compensate~ Neutro~ Porosity, SS ~'~atri. x, call & dead ti. me tort, RTN~ ~aw Thermal Netltron~ ~.atio TgJ'P'''; Tnerma! ~;eu. tron Porosity T~Ra Whermal ~eutrom Patio C~].ibratect NP{3P Neutron Porosity from ail Application Proc~ram RCFT RAW FAP CNT COUNTS C~TC Corrected ~ear bet,ct, or Count ~ate C~TC Correct. ed ~ar oetector Cou~t G~ ~P~-Cor'rected Gamma Pay T~Ns Surface Tension HTE:~~ ~4ead Tension DT4~ f)ELTA-~ CO'~ P ~'ESS ~ O~I'A L !'.'.) · P, ~ DEI.,T,~.-T C ('.'~ ~ P R f;SS ! O ~fA. l., D~i~ DE[.,TA-T SH~AR I, OWE9 l>IoO[.,E ~40DE COM.PEN.gATED [)TR~ mE[,T~-T SHEAP I..,UWEP DIPOLE M~D~ RE;CEIV~R ~')TR~ DEI,T.~-T SH~AP r,owE~ DlPoT. E.; PP POissO.'S Patio G~ ~PI-Corrected Gamma GP ~PT-Corrected Gamma ~,iCA l. f,arqe Arm TEaS Surface ~enslon ~.!~ ES ~On Resist ~.v~.tV f.; TE~' ~ud Wemoerature HT~3 ~ead Iension b.~' 1%~ ~,'Icro-Tnverse %~m ~icro-Norm~ !. · ~I$ T~!De V'er~i~I.¢a.t'!on I..,ist!.ncl ;chl,3mberger ~,!~ska Co~ut,',i.~ Center 31-~,~,AP lqq4 1 '-~'25 PAGE~ ** "~hT~ F~P,~{~T SPECIFIC~TTON ~[;;CORD 2 66 3 73 32~ 4 66 5 66 6 73 7 65 8 68 0,5 9 65 11 66 1.~ 68 1~ 66 O !,4 65 FT 15 66 68 ~6 66 0 66 1. N~P,E SERV UN'IT.. ,..SEP.¥!CEI I PI FILE. MT.J~ NUMB. S Z EPR PROCE~.5 '" .......... 77'"'5; ....... '""; ........ ;'"; ....... ' ..... ' .......... ..... ' "'"' D F ;:, · 6 408 00 00 n 0 1 1 4 6 ~ ,, 00000000 CTDP D'TE M~-~HO 62940B O0 0~0 O0 0 5 i 1 4 68 0000000000 IOpu DT~ OHMb~ 62o408 O0 00O 00 0 5 1 CTNm DTE MMHf~ 620408 O0 000 00 0 5 I~P;~ UTE OHia~ 629408 O0 000 O0 0 C/L~ UTE a~t,to 629408 nO 00(.) O0 O IT.,D DTF 0 W ~"', ~ ~2~408 OO 090 00 0 5 1. 1 4 6~ CTI,,~ UTE ~,i~i,i~ 629408 00 000 00 O 5 1 1 4 69 ILM DI~ OHM~ 620408 00 On0 00 0 5 1 '[DO~ ~'!F~ 629408 O0 OOO O0 0 5 1 1 4 68 I~9~ ~'!'~ 62~4n8 O0 000 O0 0 5 1 1 4 I!R~ hie MMHf] 629408 no 000 O0 0 5 I!l~ UTE ~;t~HO 620i08 O0 O00 OO 0 q 1 I 4 68 .[TR~; DT~ ?vHO 629408 0(.) 0DO O0 0 I!lv DTE ~HO 62940~ O0 000 00 S~LT~ OT~ OH~ 62~,108 O0 OOU n0 n 5 1 1 4 68 MY nTV MV 629408 00 000 0O 0 5 1 1 4 67 G~ riTE G~,PI 62~408 Oo 000 O0 n 5 1 1 4 TFNS D'I~ bn 629408 nO 0GO OO 0 5 1 1 4 6~ ;~TF:~ DT~ DEGF 629408 O0 0c, O O0 0 5 1 1 4 6~ ~,~E~ DTE OHMu 620408 09 HTE~: DT~: b~ 62940A O0 000 O0 0 5 1 I 4 R~Un T, DT G/C3 62°i0~ ~0 00O a0 0 D~Hn T:DT G/C3 629~08 00 00O O0 0 $ ! 1 4 68 D~F T,DT 62o40~ O0 L<Ls [.,L)T 62~408 O0 OOU O0 0 5 1 1 4 68 000000000~ 0000000000 OnO000000o 0000000000 OOCO000000 0000000000 0000000000 O000000000 0000000000 0000000000 O000000000 O00000000O 0000000000 0000000000 0000000000 ooonooooo0 O000000000 0000000000 onoooo0000 0000000000 on00000000 O0000OO000 oO00000000 0000000000 46 ,iS Ta~e Verificati. on Listinq ;chit;tuber<Jet AlasKa Co-purl, ne CeDter 3t-~'AR-J. 994:12:25 4¸7 T D L$ LOT CPS L U I, [) T C P 8 LL LDT CPS b ~ 'I'~'~ LI)~ CPS SS 1. LDT CPS LgHV LDT V SIRH LDT G/C3 LSR~ LDT G/C3 .[.,U R~,~ LDT G/C3 C.~LI t.., D~ G~ LDT GaPI T~N~ LDT MT'E ~" LDT DEGF ~ES LDT OHM~ NnH. I C~T PU RTN¢ C~T :'{'N p~ C~T PU NP[]~ C~~ ~CHT C['~T CP~ RCF'~ C ~",l T CoS C~TC C~T CPS C~TC CtqT CPS G~ CS~T GaPI ...... ~ .t4TE~ Ck'T DEGF HTE~~ CN~ DT4~ PTF DT4~ DTRo PTF Ti)~Rp TTP DmTP PTF CUTm DSt DT~I PTF US/F !.)t~ TTP US/F C~R~ P~ RS~C 9SI Gp DSI G~PI G~ ~L,T G.~PI ~C~I, uL~ .l~~ T~¢S ~'Lm Of.4t)EP # L[..')G TYPE CLASS MOD h'U~,IB ~'9',408 ''''''''''''''''''''''''''''' O0 000 oO , 5 1 1 4 6~ O0 000 O0 0 O0 629408 O0 000 O0 O 5 1 I 4 68 0000()0()000 620408 O0 000 00 0 5 1 1 4 6$ OOO00OO000 620408 00 000 00 0 5 1 '1 4 69 0000000000 ~29408 0(') 000 0() 0 5 1 1 4 68 0.000000000 62 O 408 00 000 00 0 5 1 I 4 68 0000000000 620 4! 0 ~ 00 000 00 0 5 1 t 4 68 0000000000 629408 O0 000 O0 0 5 1 1 4 68 0000000000 620408 00 000 00 0 5 1. 1 4 68 0000000000 629408 00 000 00 0 ~ J. i 4 69 0000000000 620408 00 000 00 () 5 1 1 4 6~ ()000000000 629408 O0 000 O0 0 5 1, I 4 68 ()000000000 629408 00 000 O0 0 5 1 1 4 6~ 0000000000 620408 O0 ()00 O0 0 5 1 1. 4 68 0000000000 629408 00 000 O0 0 5 1, i 4 6~ 0000000000 629408 0(> 000 O0 0 5 1 I 4 68 0000000000 629 408 00 0 o 0 t.~ 0 0 5 1.. I 4 6 g 0000000000 620408 OO 0O0 O0 0 5 ! I 4 6g 0000000000 ~20408 O0 000 O0 0 $ 1 1 ,t 6~ 0000000.000 629408 O0 000 00 0 5 1 1 4 6.9. 0000000000 629408 O0 000 O0 0 5 1 1 4 6,q 0000000000 620,t08 O0 000 O0 0 5 1 1 4 P8 0000000000 629,408 00 000 O0 O 5 1 I 4 6~ 0000000000 629408 00 000 00 0 5 I 1 4 68 0000000000 620409 00 OOO O0 0 5 1 1 4 6,9, 0000000000 629408 O0 000 O0 O 5 1, 1 4 68 0000000000 629408 00 000 00 0 5 1 1 4 6P 0000000000 629408 O0 000 oO o 5 1 I 4 6~ 9000000000 62940~ O0 000 O0 0 ~ 1 1 4 6~ 0000000000 62940.8 O0 000 OO 0 5 1 1 4 6~ O00000000O 62o408 O0 000 O0 0 5 1 1 4 68 0000000000 62o408 00 000 O0 0 5 t 1 4 6p. 0000000000 620408 O0 000 O0 0 5 I 1 4 6~ 0000000000 c~2o. 408 O0 000 O0 n 9 1 1 4 6S 0000000000 620408 O0 OeO O0 O 5 1 1 4 6~ 0000000000 62940F.' O0 000 O0 0 5 ] 1 4 68 O00OO00000 62940~. 00 000 O0 0 5 1 1 4 bg 0000000000 6294n.~ O0 000 00 0 5 !, 1 4 68 0000000000 ~204o8 O0 000 O0 o 5 1 1 4 6~ 0000000000 629408 O0 000 00 0 ~ 1 1 4 bR o00OO00000 ~20408 0O 000 O0 o 5 il. 1 4 68 0OO0000000 ~29408 O0 000 oO C 5 1 1 4 69 O0t)O000000 ~2a4n8 oo 000 O0 0 5 1 1 4 o~ 0000000000 629408 O0 000 O0 0 5 1, 1 4 62 0OO000000O 629408 00 000 00 0 5 1 I 4 69 0000000000 6294O8. n0 0o0 O0 0 5 1 1 4 b8 0000000000 629408 00 000 00 C' 5 1 1 4 68 000fi000000 629408 O0 OOO O0 0 5 J_ I 4 6;~ OOOO00000a. 629408 O0 ()nO 00 0 5 1 1 4 6~ 0000000000 6204n8 O0 OOO O0 O 5 I 1 4 bR 0000000000 620408 no OOO nO C, 5 i .t 4 68 00000o0000 ,I',$ Tame Verification Listi, riq ~chlumberger AlasKa Comput~,n<~ CeDter !2:25 PAGE: 48 N ~ .... U !? $~RV!CE API t,,~PI ~?',:ll ~ .. Fi U NU~B SIZE REP~ .-.....,.....,,,--....-...... ..... . .... .......... ........ ..................,,,......... r4FE~ ~ T ~ 629408 O0 000 O0 0 5 1 1. 4 68 0000000 MTE~ ~LT DEGF 620408 O0 000 O0 0 5 1 1 4 68 0000000000 .t4 TE ~ ~LT LB 629408 O0 000 O0 0 5 1 I 4 68 0000000000 B~IIN ~LT OgMM 629408 O0 000 O0 0 5 1 1 4 69 0000000000 B~NO ~!LT Ou~'i~ 629408 O0 000 O0 0 5 ~, ',1 4 6~ 0000000000 * '* D ~ T h * * DF.'.P T. 13939. 000. C" D "I F. DTE 88.765 !DPH . OTC 1,1 .266, C!aP . DTE IL~.DT~ 9.513 'IDQF.r.)~E; 0.000 !MOF.i)~E 0 000 I!RO.D~.., IIX~.DT~ !.0 179 !:I:,~'M.O L 9~ 485 IIX.M,O~E -34 169 SP.DTE 450.750 GR.i')~E 27.~,78 TENS.DTE 3215 900 ~T~:~,~.DTE M'~ES . ~TE 0 . 249 HTEN , 6~E 119 , 735 ~ ~,-10 B , BDT -999 ~ 250 DRblO PE~,LDT -999.2S0 OLS,LDT -999.250 OSS,[.~BT -999; 250 LS.LDT [,,!!. LDT -999.250 LL.LDT -999.250 l.,, I TH, [~DT -999.250 SSI.LDT SS2.LDT -999.250 LSgV. LDT -999 250 SSHV.LD~ -999.250 S ! RH. I..,DT bSRM. !.,,DT -999.250 LU'RH. LDT -999:250 CAI,,I. bD~ -999.250 G~.LOT - . ' D~ -099.~50 ~RES LDT HTEN bDT TENS.I,,,DT 999 250 ~TEM.L I -999.250 NPH!.CNT -999.250 ~TNR.CNT -999.~50 T~qPa. C?,tT 999 ~50 . ,, . . N.[ 2999: !V~{:)~.CNT -999 250 RCNT C~T -g99.~50 ~CFT.C'" .. C~TC. CN'T -999.250 GR.CNT -099.250 TENS.CNT 990 250 MRES.CNT MTE~ CNT -999 250 HT~M CHT 999 ~50 ~Tgp.pTE ~999[~50 DT4P DTRP. PTE'. -999.250 9TRP. ITP -999.~50 9TTP.PT~ -999.250 DTTP.'ITP C~RP.9S! -999.250 CHTP.DSI -999.~50 DT~I.PTE -999.~50 DTM1 .ITP DTRI .PTM -999.250 UTRI.ITP -99q.250 C}..i~ 1. DS I -999.250 PR.DS! RSHC.DS7 -909.250 ~R.DSI -999.250 GR.MLT -099.250 MCAL.ULT TFNS.~[,T -9e9.250 g R ES.. ~',~I~T -099.~50 ~ '1'~.: h~, ~4 [,T -99g.250 HTF, N.~LT B~ I ~. ~i,T -9o9.250 BbiNO. aI,T -99~. 250 DEPT. 13500.000 CIDP.DTE 1 84.280 IDPH.DTE 5.427 CI~iP.DTE IuPM.DTE 4.92,! CII,D.DTE 18a.153 ILD.O~E 5.315 CIb~.~.DIF ILV.DTE 't.867 IDOF.DTE O.OOO I ~'~OF. ~]'YE 0.000 IIRD.DTE 8V:DT~ 461.063 dR. [)TE 36.633 TENS.DTE 6725.000 .~ITEU: DTE ;~PE~.DT~ 0.253 HTE~J.DTE ~79.~U9 RFOB.bDT 2.537 DRHO.LDT ~Er.I,DT g.371 OLS. I,,DT 0.01~ OSS.L9T 0.037 LS.LDT L,~ ~,DT 272.500 LL.LnI _1.47.500 LITt!.I~DT 70.625 SS1.LDT · 589:LDT 310.009 LSHV.LDT 1265.000 SSHV.LDT 1306.000 sigH.LOT LSR~.I, DT 2.525 LU~H.LDT 9.543 CAL[.LD'r 10.133 GR.LDT TFNS.LD· 6560.000 [~'rE~,l. LOT ! E5.O00 ukES. i, DT 0.244 HTEN. I,DT 'NOHT.CNT 20.176 R'fNR. CNT ~.3b~ T~ P~..t. cN'r 21.0~4 TNRA.CNT NPO~.CNT 21.5~5 gCMT.C~;T 4306.329 RCF'r. C~T 1755.109 C~J'[C.CNT Cw~e. C~,~T 1921.307 CR.CK, T 34.~19 T h.'.N S. C~'E 6560.o0~ ~IRES.CNT V~Eu.CNT ~5.000 HTEN.C*,'T 90~.000 DT4P.PTE 82.059 OT4P.ITP D~RD.DT~: -999.2K0 DT~P.iTP 77.343 nTTP.PTE 83.644. DTTP.ITP C~'~m. DSI 0.000 CHTP.DSi 0.038 9T~I.PTE !45.672 DT~I.!TP DTRI .mTn: 146.572 DTPl.ITP lq6.522 CHPl.O~I 0.058 PP.BSI R-SH.C. DS% 1.775 GR.DSI 30.430 GR. ~!,T 3~.219 MCA!.,."LT I03.129 105.11.4 81.289 B.llO 184.408 '999.250 :999,250 999.250 -999,250 -999,250 -999,2~0 2999 250 9091250 -999.250 -999.250 -999.250 -9~g.250 -999.250 -909.250 -999.250 203.091 205.483 159.768 4.750 182.230 0.009 283.750 244.250 2.488 34.2~9 908.000 2.2~8 4179.0~5 0,244 82.069 ~3.644 145.672 0.268 ]0.~72 ,,IS Tac~e Verlf,i, cation Listi, DO ~chlumberqer' Alaska Comp,,]ti,,~g Cente! ~pT 13000.000 IL~,'. DT~ 4.473 IDOF.DTE I. IXD.DT~ 9.~70 !IP}4.DTE ~ R E', $. DT~: 0. 257 F!TEN. DTE; 9EF. LD7 4. 164 fiLS. LDT .b~. ~,DT 269.500 LL. LDT SSP. ~.],OT ~J,l..OOO LSHV.LDT LSRM. I,,,,gT 2.545 LURH.bDT T E N S. l, O T 67 ~ 0.000 ~ T E ~f. L ~ T NPH.?.CNT 14.0~5 ~TNR.CNT NPO~.CNT 16.575 ~CNT.CNT CWTC, CNT ~6~2,8~5 GR, C~'T .... . , 9 t r ~, ~. '~TE~{ CNT 17 .150 OTRD.PT~ 74.806 DTRP,ITP CHR~,DSI 0.969 CMTP,DSI D~RI,.PT~ 132.992 DTPl.I?P R,qHC, DSl !. · 749 GR,:DSI TF~"~$. ~ bT 67~0.00C ~,IRES,. M, LT Bu!~.~L,T 1.479 DMPT. 12500.000 CIDP..DTE IuP':{. DTE 8.030 CILD.OTE ! L.v,. D'I!F 8.2~2 !DOF.DTE I!X.n. DTE -1.b31 !I~M.DTE SP. DT~ 465. 500 GR. Y,i~E~.DT~ 0.262 }'~TEN. DTE PEF. LDT 10. 7~9 OL5.. LDT [,Il. I,[,)T 344. 500 l,b. BDT SS?.LDT 319.750 LSMV. I.,~T LSRM.LDT 2.397 T~NS. T..,DT 6345.000 ~T~g.LDT N~HT.CrgT 34.446 ~TMR.CS~T ;~OO~.CNT 37.1a7 ~CNT'.CNT CFTC, C~'4T 802, 155 eR. CUT biTE~ . C{"~ 17~. 337 DTRD.PTE 98.954 DT~P. IT'P CuRD.PSI 0.896 CHTP.OSI DTR1 .DTK 171.65b BTRI.ITP NSHC. OS ! 1. 765 eR. DSI TFN~. u[,T 63~5. 000 ~!¢ES. ~I,T [~ I ~. ~L,T 2.443 ~ ~,lO. MLT DEPT. 1200().OOU CIDP.DTE IU. Pw.nTK 1990.000 CILD.Dq"E ILu. !~T~, 1950. 000 IDOF. I l X~. ~TK -33u. 860 I IRaq. DTE Sm. DTW 3~0.8 ~ES. DTF 0.265 HTEN.DTE ~SW. LL, T -909. 250 t)L$. bDT LIT. T,I)T -999. 250 LL. LT'>T 31-MA~-I q°4 1P:25 ~.40~ 210.5.54: I D P tl. D T E 217. ~8~ I1.,9. DTE 0.0()0 I MO?. DTE ~09 91~ !IXM.'i)TE q17.~60 ,HOB.LDT -0.018 0SS.bDT 139.625 I IT,H.LDT 1~60.000 ~'~ . oo 'V LDT 2. 551 CALI, bDT 179. 150 ~RF, 5. LDT ~.074 TNPH.CNT ~89.371 ~CWT.CNT 27.328 TENS.CS]T 871.500 9T4P.PTE 74.B06 DTTP,PTE 0.962 DT~i ,PTE 132.92~ CHPl ~. 154 110.3B7 IDPH.DTE 1.10.746 ILO.OTE 0.000 IMQF. O'rE !1,4 985 T, IXi~'i.DTE 441757 TEb'!5. DTE 967.682 RHOG..LDT -0.023 ()SS.bDT 183.~75 LITH.LDT 1964.000 SS~V.LDT ~.94~ TNPH.C~T 34.563 255.O00 DT4P.PTE a.cT~ %TM1 .PTE 171.656 CN~I 41. 570 GR. MLT O. 756 ~TF~,';. MLr ~.74~ 1 S 5.0 () 0 4.7,49 4 -24.844 6700.000 2.549 0.013 64 938 1 o6: I ~. 273 0.~49 16.~26 2473. ~00 6780. OOO 74.836 74.866 130.868 0.971 27328 9.059 9.030 0.000 -31.311 6470.000 0.042 70.563 17106.000 13.766 0.256 33.09o 786.564 6345.000 9~.. 649 1~6. 343 163.51~ 0.035 34.563 176.337 13.636 1~..374 a. OOn 696.433 6340.000 -999.750 -999.750 -990.~50 ~i 7! E; N. ~ L T CT~D.DTE C!LU.PTE IIRD.PT.w. SFL, U. DTK ',iTEv .DTF [,S. LOT SS1..LOT PAGE: 49 9os.0Oo 220..~50 223. 79 1~6,' 85 .4.2~2 X7~:~7302 274'500 2]38,250 2 535 871.500 1.895 5087.907 74 74 866 130 868 0.257 ~1.8~8 871.500 124.537 121.629 98.642 9.089 175..159 -0'004 356.250 246.~5 2.400 34.563 855,000 3.2~2 2492.169 0.250 92.649 ~6.343 163.5~9 0,264 ~2.594 855.000 -265.833 -243.090 62.412 0.505 172.528 :909 250 999:250 -999,250 ,IS Wape V'er~fication L,i.$ti. nq ',chlumhero~r Al, a~ka Comput.~nO Cent:er $$2.LDT -999.250 LSHV.!,DT .LSRH.LDT -999.2..50 LURH.bDT TENS.LDT -999.2S0 ~'TEM'. BDT N~E!. C~.~ T -999.250 RT~R. C~,~T hOO~.CNT -999.250 RC~T.C~'T CFTC, CNT -999' 250 GR,C~T MwE~.CMT -999,250 MTEP~,CNT DTRP.PTE 73,630 DTRP, ITP CW~V DS! 0,9°3 CHTP.DSI RSHC.DSI 1.7~9 GR'DSI T~NS. ,~I[,T 999 OFPT. 11 941,000 CIDP.gTE I u p H. D '1:7 M - !999.2 .,50 C I L D. D T IL~ riTE -9~9,250 !DOF DTF. i~X.m,DTE -999.250 IIR~q. Dmg SP. DTE -9~9.'250 GR. DIE MRES, DTF, -9~9,250 HTF PEF, LDT -999. 250 (}I,S. LDT L U, I.., D T - 999,250 [, h, L D T SS?, bDT -999. 250 b S R ~. !.,, D · - 999.250 L U R H. L D T TENS. I.,PT -999. 250 ~TE~q. bDT NPHI.CNT -909.250 RTNR.C~!T 'N~O~. C~T -999.250 RCh'T.CNT ..... C~T -999,250 gR.C C~Tr, ...... igTE[,. CNT -999. 250 HTE~.CN'I D,~RP. P'TE 76.1~4 DT~P.ITP CHR¢. DS'I 0,994 CHTP.DSI DTR1 .PT~7 la, 5.260 DTR! .ITP RSHC. 981 -9o9- 250 GR.DSt T~..$. ~i~T -909.259 ~RES. ~,'~,T ~IN. VI~T -909.250 TR~!r. EP **** F~UIT .005 wL!C 001 CO1 o4103/31 1024 -999.250 $3HV.LDT -999.250 CgI.,I.LDT -999.250 ~RES.LDT -999.~50 ThPH.CNT -999.~50 RC~ToCNT -099.250 -999,~50 DT4P,PTg 73.630 DTTP.PTE 0 ~8~ nT~l. Tr 1.33~282 CH~i.OSI -999,250 CR,aLT -999,250 -999.P59 -999.250 -999.250 -999.250 -099.250 -999.250 -999.250 75,662 77,694 133 082 -999,250 -999.250 -999 250 I'DPH.DTE -999.250 -099'250 I 1,.,0. DIE -999 250 -999' 250 'laOF DTE -09~' . .... . ..... .250 -999 250 !I×~:,t:)T£ -999.250 -n99~250 TENS.DIE -990 250 -999.250 RHOi~,hDT -o99 2so Oss. L,a'r -9¢9 ~50 .2~0 SSHV.LOT -999 r -999 -999.~50 CA[,I.PDT -999'250 . , -999.250 MRE8 b...l. 999.250 -999,250 TNPH.CNT :999,250 -999.250 RCFToC~T -999.250 -999,250 TEN$.CNT -999.,250 -999,250 DT4P,PTE -999,250 76,~.2.i DT?P,PTE -999,250 -999.~b0 DT~I.PTE I45,028 1~5o2~0 C~RI.[)SI 0,953 -999.~50 GR.}~LT -999.250 -~99.250 ~TF'd.bILT -999.250 -999.P50 CIMP.DTE CI'Lg.DTE IIRD,DTF SFBU,DTE M'TE~,DTF LS.I,DT $$i,LDT $1, RH:.LDT GR.LOT TNRA.CNT CMTC,CNT ~ES.CNT DT4P.ITP DTTP.ITP OTMI.ITP PR.DSI gCAL.~LT HTEM.~I,T PAGE: 50 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 75,662 77,694 133,0~2 0,261 -999,250 -999.250 -999.25O -999 250 '999i25O -9992.50 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999.250 -999.~50 -999.250 -999.250 145.02~ -999.250 -909.250 -999.250 ~I~ Tace Verification List{no ~chlumberc2{~r Alaska ComPutl, nO Center 31-~AR-!gg4 12:25 51 S~VlCE : wLIC 'VERSIgN : DST~ ~ 94/ 3/31. [4'"ILF TYPE : LO LAST FILE : FTLE N U'~BER 6 Curves anO log header data for esc~ run and tool st, rln~ ~J.n separate fi. les; Tool StrlnU ~{ fo ~adlerochit rub presented first (primary depth coatrol str.lnq used to fleD'th Shift the Sadler {nterval) fol].o~ed Dy fi3es for other main Dass tool. strlnos ~er rur'~. D~PTH I~IC~E;~E','~{T: 0.~667 FTL~? VENDOR TOOL CODE START DEPTH " .............. TSg Tg .... . , T ~,3914.0 13920 . 0 ~.3920.0 UL~ LOG HKADE~ ~ATE LOGGED SOF']?~APE VERSION: TI~E CI'RCUL~TION E~IDED: TI,~E', [,OGGE~ ON ~TTOM: · D D~ i[.,L~R ~D LOGGE~ (r;T): ~OP ~OVTO~q T,OCGING SP~iEn (FPHR) TOOL STRTNC (TOP TO BOTTOm4) VKNDOP TOOL C~D~ T~OT., TYP~] A ICC G G STOP DEPTH ~,212 12126.0 ~2126,0 12~.40,0 ~9-F'EB-94 6CO a9n '1700 18-FEB-94 0230 lo-FEB-g4 1394~.0 1302~,0 121.26.0 ~39~4.0 A~-AA WCC B SGC SA 557 SGD-TA~ SP~C-AA 3l :IS Tare Ver'tfIcat!on LiStin~ ;chlumberger A!as~:$ Computing (,.enter 3 I-.~IAR-! 994 1.2:25 C~T S AMD CASING DATA D~ILLERS CASING DEPTH LOGGERS C~SING DEPTM (FT): .P, 0 R t~i;F10 l., E CONDITI[}NS MUD DENSITY (I.,}.:~/G): MUD VISCOSITY (S): ~ U D ,P H: Ft. UID bOSS (C3): ~,&X!]~l.l~ RECORDED TEMP~iRATIJRE (~..)EGF) ~ ~ES!STIVIT'Y (O}t~;q) ~T TEMPERAT[.tRk; (DEGF): ~,~[JD .~T M~ASIJPED TEuP~RATURE f~%T): UUB AT BOTTOm4 NOI,,,~'; TE'~PEr¢,ATGRE: uUD WlLTPATE AT ~UB CAKE' AT ;'~'E!.!'r P O N TOni',.,, TOOl[., TYPE (EPIT~EPMAL Or.~ aaTriX: ~TPlX DE~,~SI TY: Hf36~' COPRECTIO~'i TOnL STAND'F? (IN): SMDX-AA 33 DIC E~ 418 DiS ['~8 421 NSC E 773 ORS C CNT ~.A 3,40 UhT ~ 26 9,625 !2137,0 12t26,0 POLY[~ER SO[,.,TEX 13.5 65.0 4.5 ~84.0 1.060 63.0 0,3a8 184.0 0,6~6 48.0 0,197 184.0 1,560 51..0 DEPT~i CORRECTED. THIS F!bE CON'I'AIMS HI PCS ~TCRO LOG $ LTl ~'flRUAT nATA PAGE: 52 TaBI.E l'YpW : CONS TI!!'; ?. VAI, U DEFI ~,~ ..... DN .[, P l~. m compaBv. . ame F~ NnRTh CO[jK INLET Field ~ame W~: NCIU StJNFIS~ ~3 Well ]~ame a~I~J 50-883-?0090 apI Serial Nutaber F!, 1~o' F~,b & 9~o' ~I, ~ield [,ocation 5~C~ 6 Section ,IS Wane verif;~.cat~.on Listing ~chlumberger Alaska Compute. rig Center 31-~qAR-]. 994 1~:25 FT FT ~.~T ~T ~T FT ~1C3 At.,AS~,~ USA 62940~ 0, 132, 132, 131. 14705, 1~58, 2607. PO[,,YMER 14,5 q~ 1 O? 7~. TOWN COUN EOF TOD TDL Bt, I DFT D~V $ DwL F3 ~S nH~M ~'ST DEGF R~FS OHM~ 0.6600o01 ~¥~'ST OECF 52. MrST OEGF 4.~. TCS 15:00 T~,A~ 00:30 06-~AP-9,~ BMT DEGF 200, DEF! ~ownship Range Connty State or Province watlon ~itness Service Order M~mber Permanent datum Elevation o~ Permanent Datum Loo Measured From .~bove Permaner~t Datum El. evatio~ of Kelly Bushing EleVatIoD of Derric~ Floor Total De~th - Driller Total Deot~ - Logger BOtt, om Loq Interval' Log Interval~ T°~I,liB, oDr~ B"lujO Orl, llln~ Flu~.,O Density Dr~.llim~ Fluid Pb Drlllin~ Fl.u~d Orlllimq, Fl.u!d Loss ~eslstlvfty o~ Mud ~ud Sa~pte Temperature ~eslstf. vlt? o~ Mud F11trete ~ud Filtrate Sample Tem~er~tu Resistivity of ~ud Cake Samml ~ud Cake S~m~le Temperature Time Circulation Stomped TIME LOGGER ON BOTTO~ 8otto~ ~ole Temperature Ti~B?,E TYPl? : CI)I~V ~.I ..... ta~e Verification .bistinq ;chl. UmberRer AlasKa Comput!,n,~ Center 12:25 DATA. FCtR~,~AT SPEC~FTi'C.,%T!ON RECORD ** SET TYPE", - 64E~ **' I 66 0 2 66 3 7 3 12 4 66 5 66 6 73 7 65 8 68 0,!.66 9 65 11. 66 i~ 68 ~,,~ 66 14 65 !5 66 6~ 16 66 1 0 66 ** SET TYPE -CH DPpT FT 629408 n ~NO ~SLT OHM~ ~2q408 0 AN ** . I ~'PT APl bPI F'II..,E ,,F~ Nt~ ~ LOG TYPE C[,I$$ ~OD NU~B SA,~P EL, E~ CODE (HEX) 0 000 O0 0 6 1. 1 ~ 68 0000000000 0 000 O0 0 6 1 I 4 68 0000000000 0 000 O0 0 6 1 1 4 6~ 0000000000 mm#mmmmm~memmmM~mNmmmmm#mmmmmMm~mmmm#mmmmmmemmm#m*memmmmmmm 54 ** DATA ** DFPT. 13828,834 DMpm. 13500.00b D~PT. !300(3.009 Dr'PT. 12500.000 l)rpT. 12097.000 ~ I,t l N. y:, [, T 0.395 B ~ N O. ~ I., T 0. B 72 R H l N, ~,i/.,'I' 2.109 RNI"~ O. HLJ/. 2.402 Rb'~I N. ~LT 2.443 Ri~ N (~. ~-!LT 2.742 ~ b~ ~ ,%1, b~[..T 0.2~7 ~,', ~'0. ~; LT 0.22a ,IS Tame Vertftcation bisti, n~ ;cblumherger Al. asKa Computing Center 31-MAR-1994 1,2:75 PAGE;; '55 **** .FI b~ T.RA i LE:R VMRSION D~.TF ~q~X EEC SIZe1 ~ ~024 FILE TYPE : LO b~S~ FILE F~I..,F N,A,~E : EDIT ,007 VFR$iOa ~ 00:1 CO 1. DaT~ i 94/03/31 ~AX R~C SIZE : !024 FILE TYPE : LG ,RAW OPEN HOL~] MAIN PASS Curves and 1o0 header data lor each run and tool st. rl.n~ l,n se~>arat..e files; ToOl .String ~l, fo Sadlerochit run vresented first. (primary depth control st, rl. nq use~i to demth shiit the Sadler in, terval) followed by files for other maid ~oss tool strings ~er run, TOOT, STRI'MG NI..I~BER: 2 P~S8 ~,3U~BMR: 2 D~pTH I NC~E~E~T: 0,5000 FILM SUMMARY VENDOR TOOL CODP: START DEDT~T DSI ,0 ~TE ~ 467 ~-. 0 CNT # LOG HFADEP DATA KOrTWADE VERSION: TI~ CTRCUT,ATION ?I~ LOGCEP ON 80TTO~: TD TOP T,(]f; TN~E~VAI. (FT): ~OT~'O~ bOG i~TERVAL T,(,)~GTNC SP~g~ ?Onb STRTNG (TOP TO BOTTOM) VENDO~ "T:OOL Ct.lDO. TOO!, TyP~ 13026,0 13q26,0 13926.~ 13926,0 6C0 49O 1500 05-~AP-94 0030 14705.0 146a~.5 ~3926,0 1467~.0 ,,IS Ta~e Veri~ication !,,isti,nq ;chlumberger AlasKa Comput,t,n~ Center 31-~AR-!994 1~:~5 C; R DS I DTE DTE L DT LDT Ct~T $ [)'I POLE SONIC DIPOL~ SONIC DIPOLE DIPOD~ SONIC PHASO~ P~ASOR NUCI...,E~}~ S~RVICE CARTB~, DENSITY SONDE CO~CDEMSAT~D NEtJTRUN OPEM F{[)T.,E BIT SIZE (IN): DRILb~R$ CASING DEPTH (FT): LOGGERS CaSI~.aG DE',DT~I (FT) ~¢UD DE?OSITY ([.;B/G): MUD V;SCOSITY (S): FLUID LOSS (C3): ~'~AX, IMt,I~'~ RF]CORDED TE~PERaT~RE (DFGF): ~FS!STIVlTY (OHHH) ~UD AT MFASURED TE~P~]R~TI]RE "UD AT M~T'rO~ 5~OI, B.; TF~DERATUPE (~HT): ~U9 FI[.,TPATE AT (~T): ~UD CAK~; AT ~UQ CAKE AT ME~ITRO~,~ TOOL myt~g (~PIT~EPMAL OR ~hTRIY: ~AT~IY DE~,3SITY: Hr]b~ CORRECTION (IN): TO~L STA~DOFF ( &ME-AA TCC B SGC $ A SGD-TAA 8P ~C,,AA 31. S~'~DR-AA 33 ,SSIJ-~3A 33 St.'! DX~ a~, 33 ~IC EB 41.8 DIS HB 421 tqSC E 007 DRS C ~9~4 CNT 14A 340 5.875 139:39.0 1,3926.0 PO!,~'¥~ga SO!.,TEX 14,5 65.0 9,4 4.2 200.0 1.020 73 0 o..3 ,4 oo: o 0.660 52.0 O. 1RS 200.0 2,670 4,.5.0 ~EYAPKS: R~m FIET,D o~'rA FROh R.I~N ~, DATA HAS I,.~OI 6FEN D~i PTH CnRRECTED. S bTM FO~HAT DATA Ichlumberger AlasKa ComptltIng Center 31-~A9-!994 1,2125 CN PHILLIPS PETROL,~TU,~ CO~'PANY [;'K~ N ORTI-t COOK Fb 1~,4~' F~L & 980' SECT 6 C~UN KENAI ST ~T AL,ASK a NATT USA S~N 62940~ PDA~ ~.L'.~ A P D ~ T 132 ~ E~ ~T 132, TDD rT 1,~765. TUb ~T 14682. F~!.,I VT 14658. TLI ~:*T 2602. D~T PObY~E~ D~"O G/C3 14,5 O~pH 9.4 Dry $ 65, D~t, ~'3 4,2 R~S OHm~ I, 02 ~ST DEqF 73, R"F'$ OH ~q O. ~600001 ~ST DEqF 52, ~_. . ,.. · TCS 15:00 05-r~AD-94 TLAD O0: 30 06-MA~-94 P, HT DEGF 200, Co~Dan~ Name Fiel,~ a~e Well ~,!ame ~P! Serial Nu~ber Field Location Section Towns~ip ~ange COtlDty State or Province Nation Witness Name Servlce order Number Permanent datum Elevation of Permament Datum l.,o~ Measured From Above Permanent Datum Elevation o~ Kelly 10ushing Mlevatlon of Derrick Floor Total DePth - ~riller Total, DePth - Logger Bottom Log Interval ToD LoQ Interval Drtl],in~ Fl. uld Type, Drilll, ma Fluid Density Drilling FlU~.d Ph Dr~ll. ing Fluld Viscos~t¥ Qrl, llinq F1Bld boss Resistivity of Mud SamPle ~ud Sample Temperature Resistlv!tY of Mud Filtrate S ~ud Filtrate Sample Temperatu ~esisttvlty o~ ~ud Cake Samml ~ud Cake Sample Temperature Time Circulation Stopped TI"E LOGGER ON MOTTO~ Bottom Mole Temperature T,[Bt, E '.T/YPW. : f'llRV CIDP CT~D I~pu CILD I[,O Deoth INDUCTION r)g~P PHASOR CDNDfICWlVITY Phasor Deed Resistivity INDUCTIOn! ug~iIlg PHASOD CONDUCTIVITY Paasor Medium Resistive, tV Cond~lctl, vit¥ IL Deep Standard Processed Deep Induction Standard Processed Resistive. tV ,I.S Ta~.e verification Listfnq ichlumberger Alaska Computing Center 31-'~AR-1.994 12:25 PAGg: 58 DEF! 'CI ~ ondu i ¥ IL Medium St ndard Proce . ILM ~edium Indt~ct. ion Standard Processed ResistJ. vitY '.[nductloo Deep t'~u. alitv Factor Induction ~edtu. m Oualit¥ Factor Deep Induction Rea.1 Intermediate Conductiv~..tV Bee~ Induction Ouad Intermediate Conduc'tivt~ ~ed um Indtlction Rea! ~;nt'ermed.J..ate Conduct!. ty ~'edium !ndt~ction Quad Tr~termedlate Corlduct!vitY SF5 Reslst]..v~tv Unaveraged SDor~taneo~ls Potential .~,.PI-Correcte. d gamma Ray $orface Tens]on gud Temperature ~UD Reslstl. v~.ty ~ead T,nsion ~,tt !. k Density Delta photoe].ectric Factor Ouaiity control of lon~ spac]na' for LDT Quality control on short spaciDg T.,onq SDaclng Convoluted Co~lrtt Rate Long U~per 1-~ Window Count Rate Lon~ Lower ~J, ndow Count ~ate [,ithol. og wlndow Co%~Dt Rate Short Spacl. no ~ Window Count Rate Short SPacJ..nQ ~ Window Count Rate Sh orr S~ac~ns ~1ah Voltaoe Short. Spaclna 10ensttv LOng SDacln{] Stalk Dens].ty [,ona Upper B~3].k Dens,tV Cal.fDer APl-Corrected Gamma Ray ~urface TensiOn ~tld Temperature ~UD ~esist~v~tV ~ead ~fension Compensated ~]eutron Porosity, SS ~'~atrix, call & dead t~me corr. ~aw Thermal ~.Yeutron :at~o T~rma] Neutron Porosity Thermal ~eutron Patio Calibrated ~.~eutron Porosity from ~r, APulication P~W ~:E~R CNT COUNT,~ PAW FAP CNT Corrected Mear r)et~cfor Count_ Pate Corrected ~ar Detector Count Rate ~PI-Correct, ed ~amma Pay surface Tensiom ~UD .esist].vlty ~u~ Temperature We~d 'Iension DF,[.,T~-ff' COYPRESSI[.}NAI, NF .~Oi~OpOL, E CO~PF~'SATE. U n- ' C U ~ P ................. .,,tS Ta,~e V~t~.~Ication [,lstinq,. ;chlumberger AlasKa Computing Cepter 31..-MAR-1. 994 12:25 DTRP BELTA-T CO~PRF, SS!O~,~A[, MF MONOPOhE RECEIVER. DTRm DELTA-T COMPRES~.~ON'AL HF ~ONOPObE PECE',IVER DTTm OELTA-T ~O~PRESSIONAL NF MONOPOb~: TRANS~I'rTEiR CF~R" COHERE;NCF CO~PRESSIO~AI, P&8 ~ODg ,RECEIVEP CPTP COHF, PENCE COMPRESSIONAL P&8 ~ODE': TRANSMITTER DTM1 DE[.,TE,-T SHEA. P LOWER DiPOI,E ~ODE CU~PE~NSATE~ DT~ DELTA-T SHEAP LOWER DIOOLE MOD'~ CO~"PENSATgD DTR1 OgbTA-V SHE.AP LOWE~ DIPOLE MOD~ RECEIVER C~Rt COHERENCE LOWER DIPO[.,E MODE RECEIVER PP Poisson's Patio RS~,~C PATIO SHEAR TO CO~PRKSSIONAL DEL, TAT G~ ~Pl-Corrected Gamma Ray PAGE: 59 ** DATA FORMAT SPECIFICATION RECORD 3 73 ?96 4 66 5 66 6 73 7 65 8 a8 9 65 FT' 1! 66 1~ 68 13 66 14 65 15 ~6 68 1~ 66 0 66 mmmmmmmmmmmmmmmmmmmmmmmmm~mmmm ** SET TYPE - CHAN ** ......~=~,, ' .......................... ~,, ~=~4o~ oot,o;";.,., ;'"V .... ; ..... 7.'" ....... -4;; .... I~P;; OT~ OH~" 629408 O0 000 O0 0 7 1 1 4 6~ O0()O00000O CT~m DTE ~i~HO G2g40g O0 000 mO 0 7 i 1 4 6R o00OO~OOOO 'I~Pu DTK (._igN~ 629408 O0 UOC O0 O 7 1 1 4 6g (,,O000CO00O Tame Verification ~ChlUmberger Alaska Comput.!n~ Center PAGe;.:' 6O C T L,~ OTE ibm DTE I~Q? DTE I f. RD DTE IIXn Ill~ DTF, Sp DTE Gv DT~ TENS DTT MTEU DTE HTE~' ~On LDT D~H~ LDT PFF LDT Q 5 S L D T OSS LDT bg LDT LU LDT L f., L D T bI'r~ LDT S S 2 !., D T 5SHV t.,DT SSNV LDT $! Rw LDT b~tR~ CALI LDT G~ LDT TFNS ~'~ P g~ LDT ~ T E f'.~ T', [J · ~m~T C{,~T RTND RCNT CNT RCFT CNT CNTC CNT C~'TC CNT GP CNT TENS CNT MVHO 629:4(8 O0 000 O0 OHMM 629408 O0 000 O0 62o408 O0 000 O0 620408 0,0 00 i,} 00 ~HO 629408 00 O00 00 '~i ~'~ H O 62 o 408 00 000 00 .f~.,i ~' H 0 629408 O0 000 O0 ~HO 629408 O0 000 O0 014 M f.,,'~ 62~408 O0 000 O0 MV 6294,08 00 000 00 GAPI 629408 O0 000 O0 [.,B 62'~408 O0 000 O0 OEGF 629408 O0 000 O0 £) H Iv, ~ 629408 O0 OOO O0 LB 629408 O0 000 O0 G/C3 629408 O0 000 O0 G/C3 629408: O0 000 O0 620,408 O0 000 O0 629408 O0 000 00 629408 O0 000 0() CPS 629408 O0 00() 0() CPS 620408 00 000 nO CPS &29408 O0 000 O0 C P $ 620408 00 000 00 CPS 620408 O0 000 OO CPS 629408 00 000 00 V 629408 00 000 00 V 62~40~ O0 000 00 GtC~ 620408 O0 000 O0 G/C3 6,2o4n8 nO G/C3 629408 O0 000 00 iN 629408 O0 000 O0 GAP! 629408 O0 000 O0 LB 620408 O0 OOO 00 OEG~' 62q405 nO 000 O0 OHMN~ 620408 n0 00O O0 [.,~ 6,204-08 O0 OOO O0 PU 620408 O0 ()00 O0 62~408 O0 000 O0 Pi..! 620408 O0 000 O0 62940a 90 000 pu 629408 CPS 6204.08 O0 000 O0 CvS 620408 O0 000 O0 C~S 6{20408 O0 000 O0 C~S 629408 O0 000 O0 c,,, {P! 6204.08. . 0(.'} 000 OO I.,B 629408 O0 000 O0 OMMF. 620408 O0 000 0 7 1 1 4 6 .~ 0000000000 0 7 I I 4 68. 000O000000 0 7 1 1 4 b~~ O000000000 0 7 1, I 4 6 O 00 () 0000000 0 7 1 I ,t 6~ 0000000000 0 7 1 1 4 6~ 0000000000 0 7 I I 4 6~ O0000oo00o 0 7 1 I 4 6 a' 0000000000 0 7 t 1 4 6 ~ (.) 000000000 0 7 I I 4 68 0000000000 0 7 ,1 1 4 68 0000000000 0 7 1 1 4 6~ 0000000000 0 7 1 1 4 69 O0000000OO 0 7 1 1 4 6.8 O0000OO000 0 7 1 1 4 6~ 00()0000000 0 7 1 I 4 6*] 0000000000 0 7 I 1 4 6 ~, 00000000 () 0 0 7 1 1 4 6 g 000 00 0 0 0 (,) 0 O 7 1 I 4 6~ O00OO00000 O 7 1 .I 4 68 0000000000 0 7 1 1, 4 69 O00OO00000 0 7 1 1 4 6~ 0000000000 0 7 1 1 4 60 0000000000 0 7 I I 4 68 0000000 ~00 0 7 ! 1 4 6q 0000000000 0 7 1 i 4 6~ 0000000000 0 7 1 I 4 68 0000000000 0 v 1 1 4 6g O0000OO000 0 7 1. i 4 68 O000000000 0 7 ! 1 4 69 0000000000 n 7 I 1 4 69 O00OOOO000 O 7 1 1 4 68 (;,000000000 0 7 1 1 4 68 0000000000 0 7 .t 1 4 69 0O000 ~ 0000 0 7 1 1 4 68 O00OO00000 0 7 1 1 4 69 o0000o000o 0 7 i t 4 6~ 0O0O0o0nor) 0 7 1 I 4 6R 0000000000 0 7 ! 1 4 68 0000000000 0 7 1 t 4 68 OOCO000000 0 7 1 I 4 O~ 0000000000 0 7 1 1 4 68 0000000000 0 7 1 ! 4 6g O0000nO000 0 7 1 I 4 69 O000000nOO O 7 ! 1 4 68 0000000000 0 7 1 1 4 68 O000000000 0 7 1 1 4 6¢, O00OUO0000 0 7 1 I 4 6.8 0000000000 O 7 1 I 4 68 00000000O0 .~IS Taoe Verlflcat!on Listing ;Chlumberger AlasKa Compu. ttno Center 31 -~!AR-1994 12:25 MTE~ DT4P PTE OT4P TTP DTRO PTE DTRD DTTP DTTP ITP CNRm C~TP DT~! DT~ DTR~ P~ DST RDER # hOG ~Y[ E CI,~$$ ~OD DEGF 620408 O0 000 00 LB 620408 00 000 00 0 629408 00 000 00 0 62940~ 00 000 00 0 629408 O0 000 00 0 62940~ O0 000 00 0 629408 00 000 00 0 629408 O0 000 O0 0 620408 O0 000 00 0 ~29408 O0 000 O0 0 US/F 62~40B 00 000 00 0 US/F 62940B 00 000 00 0 62g408 0(,) 000 00 629408 00 000 00 0 629408 O0 OOO O0 0 629408 00 900 O0 0 62040~ 00 000 00 0 GAP! 629408 00 000 00 0 'I E N i} ~i ~!i N U M.a S i Z E ~ P P ~ O C E $ S N U M i.:~ $ A ~ P E 1,, ~ a C 0 D E ( H E X ) 7 I I 4 6~ O000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 I 4 6~ 0000000000 7 I 1 4 68 00O0000000 7 1 1 4 69 0000000000 7 1 1 4 68 0000000000 7 1 1 4 60 0000000000 7 1 1 4 0a 0000000000 . ~ 7 I 1 4 o 0000000000 7 1 I 4 6~ 0t~00000000 7 1 't 4 6 o i> ~ 06000000 7 1 t 4 6 ~ 0000 (:) 00 O 00 7 1 I 4 69 ()OOC000000 7 1 I 4 6~ 0000000000 7 I i 4 68 00000000O0 7 1 1 4 6~ {9000000000 7 1 I 4 6a 0000000000 14702.000 6.708 6.61.2 15.605 0,267 -999.250 -999.250 -9~9,250 -9q9,250 -9~9,250 -999.2~0 -909.250 -999.250 -9~9.250 -999.250 -909.250 -9~9.250 -9~9.250 1¢500.000 6.867 6.729 8.008 -16.750 0.25~ 4.39l 2~1.000 CIDP.DTE CIL[),DTE IDOF.DTE GR.DTE HTEN.DTE OLS. BDT I,h. LnT t,S~{ v, L~T L U P H. L 0 T UTFa. LDT RTNR.CNT PC~*T.C~:T GR,C~T DTPP.DSI CHTP.DSI DTPl.iTP GR.DSI 1,89.435 IDPH.DTE 5 279 ClMP DTE !.91.453 I[.,[). UTE 5."~2t Clb," :DTE 0,000 !MoF,gTa 0.000 i?RD.DTE ~,4~.697 IIX;4. DTE 11.632 8FhU.DT~ 6~ .312 TENS. DTE 3455,0(.)0 MTEM.DTE -27.J. 8] ~HOb' b[)T -q99.~50 DRH. O. LDT -990.~50 OSS.bDT -~99.250 GS.LDT -q9~.250 [,IT~t.LDT -999.250 SS~.LDT -q99.~50 SS~']. bDT -999.250 -09o. 250 CA!,I. L~T -o99. 250 G~. -o99.~50 'HRES, BDT -q99.~50 HTE~I.LDT -~99.~5~ TNPb. CNT -999.250 T~!RA. C~'~T -O99.950 RCFT'. C~!T -999.250 C~TC.CNT -09o.~50 TENS.C~IT -q99.~50 MRES.CNT -~99.250 DT4P.PTE -999.950 DT4P.ITP -099.~50 DTTP.PTE -~9q.250 DTTO.ITP -OgO. ~50 DT~'! 1 .PTE -999. ~50 DTM1 .ITP -99o.~50 CH~I.DSI -Q99.~50 PR.D&I -~9o.~50 140.5'16 IDPri. DTE 7.114 CI~P.DTE 1.43.406 ILE'.DTE 6.973 C!L~.DTE O.OOO I MO [". 0"'E 0.000 I!RD.DTE 140.229 ! IX;.:,. DTE 3.350 SFLIJ.DTE b3.674 TENG.DTE 671.0,000 ~TE~.OTE ~60.n77 ~HOB.bDT 2.639 [)PHO.LDT -0,005 QSS.LDT 0,015 LS,LDT 1i7.250 I, I T~,i. b{)'r 50.656 SS! .LDT 149 070 166,067 6 358 195i323 -999 250 2909 250 999~250 -999.250 -999,250 -999,250 -999,250 -999.250 99.250 -999.250 -999.250 -999.250 145.621 148.603 123.451 @.382 194.8~2 -0.009 232.750 233.500 ,;I$ TaPe Verl,f,l.!.cati, on Li !chlumberqer Alaska Comp st~q utino Center $S~. D~ 281.500 LS;'{V.bDT bS R}~,. [.,[',) ? 2.652 LURH.LDT T~N'S. T.,DT 6150.000 ~T~,~. LOT h~oOP CN:T 27.6B6 KCNT C.. t CWTC. C~T 19~5.6~9 GR. CNT MTE".CNT 197.4~8 HT~N.CWT DTRP,PTE -999.250 DT~P.DSI CHR. P.DST 0.000 CHTP.DSI DTR1, 'PT~ 136.561 DTRi.ITP RSBC.DSI 1.8~9 GR.DSI !L~.DT~ 63.7~3 TDOF.DTE .I~XD.DT~ -0.379 IIRM.DTE SD. DTE -~ 1.1 ~8 ~R. DTE ~ fe E'.$. DT~ 0.255 ~EF'. l.,,b T 4.9 ~4, QL8. bDT LI!. LDT 1494,000 I,~. LDT SS2.LDT 349.250 t,$F~V:. LDT ,l,.,,$ RW. L DT 1.568 LUPH. bDT 'r~,~s. I,,f.~T 665o.00o ~T~:~ hOT ¢~PH~ .C~T 65.27~ RTNR~CNT NDO~.CNT 70.607 RCNT.CNT C~TC.CNT 407.[,91 GR.CMT ~'~TE~. CNT 190,5! 3 H'rFN. C~T [)~RP.PT~ 100.412 DT~P.DSI CHRP.DSI 0.9~. J, C}~TP.DSI OTR~ .DTE 106.406 DTRI.ITP P~HC.DSI 1.957 aR.DSI .O~PT. 13657.500 CIDP.DTE: I~PH.DTE -999.250 CILD.DTE I!,~.9T~ -999.250 IDOF.DTE .[ IX'D.DT~ -909.250 IIgM.DTE Sm. DTE -999. 250 r,lP E;S. ~)TE -999.259 ~TFN.DTE ~:w. LDT -999. 250 0 !.,S. LET l,ft. LDT -999. 250 Lb. LOT SS~. I.,[)T -999.250 I..,SR". LO· -909.250 f.,t.lP H. I,~T TENS. LDT -999. 250 ~TFM. LDT ~',',oH l. ChiT -909. 250 PTNR. N o(.)p. C?';~ -9o9.2~0 RCNT. C~T CmTC. C~.,~ -999. 250 ~wE~.C~.~T -999. 250 ~TEN.C~T [)TRD.DT~ -909,250 DTPP.DSI CHRm.DS[ -999,250 CHTP.DSi 9T~ .DT~ -999.250 DT~I.ITP R~HC. nST -999.2KO GR. 3 I-~,:AR-1994 12:25 1641.0 O0 SS ~{';i". bDT 2.660 CALI.L!)T 197.48g 2.61,3 'rNPi-i. CNT 4806. ! 51 77. i 8~ ~ENS. CNT 903. 500 DT4¢, 74.908 DTTP.PTE O.OOO DT~!I, .PTE !36.561 CHRI.DSI 14.24q IDP~'~.. DTE 15. 309 ILg. OTE O.OOO 14.930 30.765 TENS.DTE q47.656 0,027 OSS.Lr~T R10.500 163~.000 SS~V.bDT 1..601 CALI.LDT 19n.513 ~R~S.bDT 4.~67 ~NPi:i. CNT 1994.014 RCFT.C~T 33.406 TEN6.CgT 83~.5{)0 UT4P.PTE 100.412 DTTP.PTE ~96.406 CHPl.DSi 39.5~4 -999.25f) IDPH.DTE -999.250 I[,D. DTE -090.~50 !NOF. D'VE -99Q.~50 II~q. DTE -999.750 TENS.DTE -099.~50 ~HOE;. 5DT -999.250 QSS.LDI -999.250 I.,IT~. LOT -ggq.~50 SSHV.LgT -090.~50 CAI,I.LD'~ -999.~50 -099. ~50 '999. ~50 TE~iS. -999.250 DT4P.PTE -099.~50 PTTP.PTE -099.250 168~.000 5.867 0 ?54: 1792.g50 6150,000 -990 ~50 136.5~1 0.81.9 70.181 65.32~ 0.000 -5.536 6490,000 1.. 4, ~ .4 0.0 37 387. 500 1678 0()0 7[664: 0 254 376.355 6650.009 99 900 99~3~ 19~.500 0.885 -999.25~ -999.~50 -999.~50 -999.~50 -990.250 -999.~50 -99o.250 -qgg,250 -999.250 -999,250 -999.250 -o9o.~5o -99q.~50 -n9q. ?50 -~99.25~ { . "l (.... 1 R H. L D T H ~' E ~. LOT N R.I , C N T CIVTC, CNT RES. CNT DT4P . l"r:P DTTP.ITP DT~ I, ! TP PR.PSI I N P. P T E IL~. DTE iIRD.DTE F L U. D T E TE;~a. DTE L ,S. L D "';' ! aH. LDT GP . LDT HTEM, LDT CWq:C.CNT ~B;S. CNT DT4D.ITP DTTP.ITP o'r~; 1,. ! TP PR .DSI CI~P.DTE CIL~,DTM IIRD.DTE SMLU. 9TE DRHO.LDT LS. LDT SS ~, LDT SIRH,LDT GR. LDT hTE~. LDT CNTC.Cr~T DTqP. DTT~. ITP D~~ 1. I TP PAGE: 62 ,688 7 .188 803,500 2.419 4613,374 0.254 74.681 7~.554 13 .561 0.287 15.490 15.678 1,3.734 43.538 187~446 -0,127 1557.000 241.375 1 92O 33~406 834.500 4.639 1903.750 0.254 99.900 99,:388 195,500 0.323 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1,28.566 -999.250 .~IS Tame Veri. ff!cation !.,lsttno ;ChlumberoerAlaska ComputinO Center 31-?~AR-199.4 1'2:25 PAGE: 63 **** FI[,E '~RAILEP **** FTI,~ ~A~E : EDiT .007 5~RVICE : FLIC D~T~ : 94103/31 ~,'~X REC 8~ZE : ~024 FI[,,~ ~Y'PE : LO LAST FILE : **** FILE HEADER FIL~ NA~,~E : EDIT .008 VFRSION : O0~COI D~,T~ : 94t03/]1 ~AX RKC SIZE ~ ~.024 FTI..,F TYPE : LO L,~$~ FILE FiLF ~.EI~ DER [.')P~:]N HOLE REPKAT PAS:lES Curves and lo~ header data ~!or each pass, tool. st.~:.'~no, and run i~ separate tiles, TOOL SI'~I.~,~G NUMBER: .9.. P~ .SS DE'PWH I,";C~E~.!E~:T: 0.5000 V~]~?DOR TOOl, CUDE SThR~ DEPTN DTE 8ql6.e ~.D~ 8~8a.0 b~G H~AhER DATA ~AT~: bmg~gD: SOVTWA~E VERSION rIt~g CIRCULATION ENDED: TI~E bOG~EP ON BOITOb: ~D I)RIL!..,~R (FT~: · D .bOGGE~(FT): TO° LOG ~N~ERVAL (FT): ~OTTU~ L~G I~T _ TOOL STRING (Trip TO BOTTOM) VENQOR TOOb COD~ TOO[, TYPE AUXILLI~RY ~EAS. STOP DEPTH 25~14.0 259a,0 259a.0 2594.m ..... .,IS wade VerlflcatJ. on List.tho ;chlumberger AlasKa ComPu. tln0 Center' 3J.-MAR-1994 17;75 64 AI~XT, LLI ARY TELMMF,',TPY C~RmR.~DGE G,aM~A RAY CAR. TRI[;GE GAM~A DIPOLE SO~,~ I C DIPOLE SONIC DIPOLE SONIC DIPOLE SOrbIC .PHASOR INDUCTION P~.~ABO~ ! N'DUCTIO~.~ NUCLEAR SFRVICE CSRTR, DENSITY SONDE COMPEMSAT:~D NF. UTRON AND CASING DATA M,D TYPF: MUD DENSITY (LB/G): FLUID LOSS (C3): ~AX7~U~ RECORDED TE~.~PERA'.rURE (DEGF): ~ES!STIVIWY (OH~q'[~'~) AT TEMPERAT[]RE (DEGF): ~Ur) AT BOTT0~ HOLE TV~PERATURE ~U~ FILTRATE AT ~UD FILTP.ATE AT ~{.JD CAKE AT ~0~) CAKE AT (b~T): AME-AA TCC B 101 SGC SA 294 SGD-TAA SPAC-A.A 31. $ ~ D R - A ~ 3 3 $S!J-8~ 78 SMDX-AA 33 DIC-EC 418 DI$-~!C 421 ~SC ~] 799 DR$ C 3957 CNC-HA 108 1,7 50'0~ 2go2 o 2594:0 PHPA 9,8 50,0 7,5 8.7 152.0 TOOL TYPE (EPTTHEPH~L OP TI4ER~4AI,..,): M~TPlX: M~TPI% DENSITY: HOL~ COPR~CTION (!N): WOOL STA~DOFF (I~3): DE~,~APKS: F;A~ F!EI,D DATA WROM R~N 1 [,O~FR REPEAT, LIS FOX,fAT ~ATA 71,0 .,IS Ta~e Verificat~.on bist,f.n~ ;chlumberger Alaska Computino (Tenter T,~BI,.iE TYPK .' CONS TUN! VALU DEFI C ~ P H i b b I F'S P E T R O i'.~ ~:: U ,~'; C O ~4 p a N Y C o m p a n v N a m e 5' ~' 'W~ Amiw 50-883-20090 FL 1~4.9' FNb & 98~" F~[., $~:C~ 6 R ~ N ~ 9 W S~AT AT,ASKA N A T i U S A W l TN H MN RY SON b294()~ POAT I.., a F a P D f?:W6 ~T 132, E~F ~T 131 V~r) ~'T 14785. TLI ~'I' 2602. I.)~T PO[.,YMER. 80bTEX D~D G/C3 14,5 D~P" 9,4 [)~V 8 6 5, D~[, F3 4,2 k~8 OH~,~ 1 O2 l'4ST DEGF 7 ~. ~"FS, OH~ O.e6OOOOl 'a ~C~ 0 H~-~ 2,67 ICG J5100 O5-~.:aR-q4 TI,AP ~HT r)gcF 200 Field Name Well Name ~PI Serial Number Field Location Sect I on. To~nshlp :Range County State or Province Nation Witness Na~e Service Order '".!umber Permanent datum Elevation of. Permanent Datum Log ~easured From Above Per~ane~t Datam Elevation of Nelly Elevation of Derrick' Floor Total Depth - Driller Total. Depth Bottom bog I~terval ~o¢ !..,o, I'nterval Dr'lllln~ Fluid Type Orillin, FlUI. d Density Orllling F!ut, o Pb Drilling Flu!ti Viscosity 9r!l!.inq Fi.u.~,:~ bOSS Pesistivl. ty of t4ud Sample ~"ttl~ Sample l'ei;~c,erature :;'esis::~vit. v r~!:. Mud Filtrate S ~'~:~ :"iltr,--:ve :Sample TemPeratu ~esj.<t!v!t.v of Mud CaKe Sampl ~ud Cake Sample Temperature Time Circulation Stooped TI~{~; LOGGER ON BOTTOM Bottom Mole Temperature TYPE '. CURV ClOP TNDI.ICTION DEFF PHASOP CONDUCTIVITY IOpU Phasor Dee~ Resistivity (]THO INDLICTION ~EDI, U~ PHASO~ CONI.)'I~CTIVITY i~,~P~ Phasor aedium Resistivity CTL~ Conductivity IL Deep Standard Processed II.,D Bees Induction Standard Processea Resistivity ,IS Tam, e VerliJ. catJ..on I:istine ~cblumber¢:ler Alask:a Compu. tJ. De Center PAGES' 66 Conductivity IL ~!editl:m Standard Processed ~edlllm Induction Standar~ Processed Resistivity Yflductlo~ Calibrated Fre~uenc~ !nduct~on Deep Quality Factor InductloD ~edlum Ot.]al. lt? Factor Dee;, Induction Real. Inter,ocli. ate Cond:uctlvit~ Deep In~uctio~ Ot~ad Int. ermed~ate Conduct~vft¥ nedlum I~ductlon Real Intermediate ConductOr ~edium I~ductlon Quad Inter~ledlate Conductivity SFL ~esistlvity Unaveraqed S~>ontaneous Potential. APT-Corrected Gamma Ray Surface Tension ~ud Temperatl~re ~tJD Resistivity ~ead Tension Density Porosity BUlK Density Delta R~O Photoelectric Factor Oual~tv control., of lone spac'lnq for LDT 0ual~tV control on short spacing ior bDT [,o~g Spacing Computed Count Rate Lonq t3p~er 1-2 Wi. ndow Count. Pate t,o~g Lower ~J. ndow Count Pate bltholoq Window Count Rate ~hort Spaclno ~ Window Count Rate Snort Spac~no 2 Wi~dow Count Rate Lon9 $pacinq High Voltaoe Short Mpacina High Voltaae Short.' SPac~.n~ ! Density Lo~q SpaclDq Bulk Density bonn UDper bulk De~sttv ca.liner ~FI-Corrected Gamma Pav Surface TensJon ~ud wemperature uUD Resistivity wead Tension Compensate~ Neutron ~oroslty, SS ~atri×, calI , ~ead time tort, Raw Thermal Meutrom Patio Thermal ~.3eutron Porosity Thermal ~eutron Patio calibrate~ Neutron Porosity trom an ADp!ication Proaram RAW NEaR CNT COUNTS ~Aw ~AR CNT CUUNTS Corrected Near Detector Count ~ate Corrected Far Detector Count Rate ~PI-Corrected Camma Rav Surface Tension ~UD mesist.~v!ty ~'~ud Temperature ~ead Tension .~iS !r'aoe verl, flcat.t.o~ Listi. no ;chlumber(,]'er Alaska Co~Putlno Center .. AC, E,: 67 DEF! [)TgP DE~,T~-T CO.~P~ESS~[tNAI, HF ~t~DNOPOLE CO~:PENSATED DT4v DELTA-T CO~PRESSIONAL V{F ~tONOPOI..,E CO~P~NSATED DTRD DEI,,TA-T COMPRESS!ONAL HF ~'!f~NOPObE OTT~ DELTA-T CO~PeESE.;IO~'AL HF ~'!f~NOPgl:.,g DTT~ 9ELT.A-T CO~PRESS~Of',~AI,, ~F' ~NOP~L,E TRANSNITTER C~RD C05'~EREMCV CO~PRES$IONA[., P&S UODE; RECEIVER C~TP COHE~ENC~7 COt'~PPESSIONA!'..~ P&S ~ODE TRAN&MITT~]R [)T~ DELT.~-T SH~'~AR LOWER DIPOLE MO[)K COMPENSATED l.)~'~ DELTA-T SHEAR LOWER DIP()LE ~10[)~ CO~.~[PENRATED D'rRI OELTA-T SHEAR LOWE~ DID[?L~i MODF RECEI'~ER DTR~ DELT.A-T SHEAR' LOWE~ DIPE)[,E MODE RECEIVER C'HRI CONEPENCE [,,,OWE~ DIPOLe; ~OOE PP POisson's Ratio RAHC RATIO SHEAR TO COMPRFSSIONAL DELTA T GR A. PI-Correc/ed Gamma Rav ,, ** SET TYPE - 64F, B ** TYPE REPR CODE V'A I,,UE 2 66 0 5 66 6 73 7 65 ~ 68 0,5 ~2 1~ 66 !4 65 FT !6 66 1 ** S~_:T TYPE - CHA~.i ** !P flF"O~ ~ bOG TYP5 CLASS MOD NUmB S , ~ ~b~'-"~ ~f]~: fHFX) mm mi ~ mmmmmmmm mmm ~mmmmmmmmm m mmmmlmM Mmmm mmmmmmmM ~ ,,,, -- ,mm mmm m mm mm mmmmmm *mm m DFPT 2040~ 00 00() 0 . ~ 4 ~ OOOO o0o IbPw ~TR CIHMM 62a40~ O0 OOO O0 0 ~ 1 1 4 68 OOOO0000,.:'- :~IS Taoe Ver,ifJcation Li~ti, nq ;chlU~,ber,~er Alaska Comp,,ltfr~q Center 31 -NAP-.1994 2: 25 PAGE: 68 ORDER # bOG TYPE CLASS MOD NtJ~,B S.i:~:i: !:':~ EbEM CODE (HEX) C!MV hTn t~MHn 629408 00 000 00 0 8 IPIP~ DIR OHN~ 629408 00 000 O0 0 8 C~[,n DT~ MMHO 629408 O0 000 O0 O 8 !LD OT~ O~:~ 620408 00 000 00 0 8 CI.L~~ 9T~ i.~.HO 629408 O0 000 O0 0 8 iL~ DTR OH~4~ 629408 O0 000 O0 0 8 I~R~ hT~ HZ 62q408 O0 000 O0 0 8 I~OP DT~ 629408 O0 000 O0 0 8 IUQ~ DT~ 6~9408 O0 000 O0 0 8 IlRn DTR M~H0 ~2q't08 00 000 00 0 8 ITXD BTR MMHO 629408 O0 (}O0 O0 0 8 ITR~ DT~ M:MttC 629408 O0 000 O0 0 8 IIX.~ DTR M~Mn 629408 O0 000 O0 0 g ~P DTR NV 629.~08 O0 000 00 0 8 G~ r)I'~ GAPI 620408 00 00O 00 0 g T~$ DTR bB 629408 00 000 O0 0 9 MTEw DT~ D~GF 620408 O0 000 O0 o 8 ~,:~RES DTR OHM~ 620408 00 000 O0 0 ~ HTE5~ DTP L~ 629408 O0 000 O0 O ~ DPH! LDR p!~ 629408 O0 000 OO 0 a .~uOg I,D~ G/C3 620.408 00 00o 00 o ~ D~HO LDR G/C3 629A08 O0 000 O0 0 ~ PFF LOP 629408 O0 000 oo 0 8 o~,s LD~ 620408 O0 000 00 0 g QMS [.,[')~ 62940,8 O0 00O O0 o 8 bS !.,, O ¢ CPS 62040g O0 000 O0 O 8 bT~ I.,,D ~ CPS 620408 O0 000 O0 0 ~ LI., LDP CPS 629.40 ~': O0 000 O0 0 8 I.., ! TT¢ LDP CPS 62040~ Oo 000 oO o 8 SS1 LDR C~$ ~2940~ O0 000 O0 n ~ SS2 LD~ CPS 629408 O0 0o0 oO 0 ~ LSHV LD~ V 629408 nO ooe O0 0 ~ SSHV [,DR V 629408 O0 000 O0 0 ~ S~ LD~ G/C3 62~40~ 00 000 00 0 $ LSRn LD~ G/C3 629408 00 000 00 0 ~ I.,~IRu LD~ G/C3 629409 OO 0o0 O0 0 9 C ~. 1., r I,[.)R IN 620408 nO GOO O0 0 n GP I_,O~ G~PT 62a408 O0 000 O0 0 8 TFr,~ g I,DP LB 62940~ O0 000 O0 0 ~ NTE~ LDR DFGP 62040g O0 000 O0 0 P uPES LDR OHM~ 629408 O0 OfiO O0 0 8 HTE~ LDR LB ~20409 00 000 00 0 8 r,, PH TCNR pTI A20408 O0 000 O0 0 n TNpu C t's' ~ PU 629408 O0 000 O0 0 8 T~)Ra CNR 629408 O0 000 n0 0 8 N~/)p CNR PU 629,}09 O0 OOO O0 n R ~CNT C,,iR CPS ~2qiog nO 00o O0 0 ~ RCF'~ CNP CPS 62q~08 O0 000 O0 0 8 C ~,ITC Cr~P CPS 620408 O0 000 O0 0 ~ I I 1 ! 1 ! 1 1 1 1 I 1 1 1 1 1 : :: 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! 1 1 1 1 1 1 1 1 1 1 4 68 1 4 68 1. 4 6~ 1 4 68 I 4 68 I 4 68 1 4 68 1 4 68. i. 4 6~ 1 4 68 1 4 6~ 1 4 68 ,l 4 68 1 4 68 I ,4 68 1 4 68 I 4 68 I 4 68 i 4 68 1 4 68 1 4 69 1 4 68 I 4 68 I 4 68 1 4 6~ 1 4 68 I 4 b~ 1 4 6~ 1 4 6~ 1 4 6~ 1 4 6~ 1 4 b~ 1 4 6g 1 4 6n 1 ~ 6~ I 4 68 ~ z',. ~:, ;: ] 4 68 1 4 6~ I 4 68 1 4 68 1 4 68 00000000 ::? 00000000 .,.; 0 0 0 00 0 0 0 :'~' 00000000~.,.:'o 0 0 0 00 0 0 0 <:.: n, 00000000!:~'; 00000000..<; '7 00000000 ':..', 00000000 t:: 00000000~..' ¢ 00000000 ~:.:~ 00000000~,~;: 0000000O~';'" 0000000O(' O0000000 (.;('": 00000000 v OO000000c"2~ 00000000~ r' 00000000 (~' ~'~ 000 n 0000 ::.: 00000000'.:' ~":~ O0000000',r: 00 () 00000": (> 00000000'r: '~ 00000000,:: 000~0000~ 00000000: ,' 00000000.~ :' 00000000...' 00000000 00000000~ 00000000,..~' 000O0000. :' 00000000," O000000O;.'" 00000000,. ~ 0000000~... :' 0000O000:' :" 00000000 U000u(,,.¢O '. .. '-~(' C O (. o t'¢'(.,n oOonOnooo0 OOO0000000 0000000000 O0000000UO O0000nO000 ,,'IS 7a~e Verification bisti..Dq ;c.hlumberqer Alaska Com'ptlt!no Center 69 NAMF $ F.,R V UNIT ,~BRV'ICE APl P F ORDER # bO(; T YPF CLA~S MOD NUM6 SA~P ......................,........,.,,,..,,....,...... ....... .. C~TC CNR CP6 629408 00 G~ C~ GAPI 629408 O0 000 O0 0 8 1 1 T~NS CI<,R LB 629408 00 000 O0 0 ~RE,~ CN'~ OHM~,I: 620408 00 000 00 0 ~ 1 1 hlTE~q CNP. DEG:F 629408 O0 000 O0 0 HTEN CN~ LB 629408 O0 000 O0 0 DT4P P~'E 620408 O0 000 0 DT4P 'T~P 629408 O0 000 0() 0 8 1 1 OTR. o PT~': 629408 O0 000 O0 0 D~RP ITP 629408 O0 000 O0 0 DTI'v PTE 629408 O0 000 O0 0 8 I 1 DTTm 'I'lP 620408 O0 000 O0 0 8 C~RP DSI 629408 O0 000 O0 0 8 C ~ :'l?P DSI 629408 O0 000 O0 0 [.)T~ 1 PTE US/F 629408 O0 000 O0 0 8 1 DT~I IT~ US/w 629408 O0 ()00 O0 0 DTR1. PTE 629408 O0 000 O0 0 8 1 D~R~, ITP 6'20408 O0 000 O0 0 CHR1 DS! 629408 O0 000 O0 0 ~O . 1 ¢~ DS! 62,, 408 O0 00o O0 0 RS f:.t C B5!: 629408 O0 000 O0 0 8 1 1, .,,hEM CODE (HE×) ~,''''''4 ..... ;;''''''''''''''''0000000000 4 6~ 4 69 4 68 4 4 68 4 68 4 68 4 68 4 68 4 4 68 4 08 4 68 4 58 4 ,,:, 6 ill 4. "~:~:~ 0000000000 0000000000 0000000000 0000000000 0000000000 0O00000000 0000000000 O000OO0000 0000000000 0000000000 0000000000 O000000000 "0000000000 0000000000 4,, 000 O 0000 (,>, 0 D~PT. 8977.000 CIDP.DTR !,3~.000 l~P~ DT~ 6.887 CILD.DTR 14o.375 II'.i'".OTR !'t,U:DTp 6.785 IF~E.DTR 20.000 z~R~.¢:r~ 123.5~3 !I×[)'DmR 9 7~9 llFJq. Om~ SWL, I!.DT~ 6.902 $¢.[)TR -5~:5~ Ck. OTR dTEU,DT~ 147.875 gR~$.DTR -0,052 HTF¢~.DTR R~O~,L[)~ 2,299 DRHO.LDR 0.173 OSS.~,D~ O.0~3 t,S.bDg 606.500 I:i;.LDR LTT~.LD9 207.000 SS1.LDR 321.750 S$2.LDR 5S~¥.LDQ 1379.000 S1RH.LDR 1.779 CSbI.!..DP 14.~80 GR.LDR 87.625 )~PES.LDg -0.052 HT~N.LD~ -51.250 TvP~.CN~ ~9.077 TNRA.CNP 3.004 RCFT.CNP 7~9.8~9 CNTC.CNR 2287.389 CF?'C.CNR T~Ng.CN~ 4220.000 MRES.CNR -0.052 UTF~r~.C~R DT4m. PT~ -999.250 DT4P.iTP -q99.250 9TTO.D'rE -909.250 DTTP.ITP -~9q.250 CHFP.DSI DT~.I.P?~ -909.250 DTMi,!TP -o99,250 OT[~.~.PTE CNR~.DST -999,250 PR,D$I -999.750 OW¢*. 8614.5q0 CI~)P,DTR -999.250 IVD~! DTR -999 250 CII,D.D~R -qgo 250 I~'.!~ 9TR , ~ .- . ........... . , . · TL,~.DT~ -999.250 !FRE.DTR -o99.250 ID' ?.OTR ITR~.DT~ -999.250 7.238 CI[~P.Oi'R 7.117 CILg.DT~ 3.000 139,000 ITX~,D'I'~ 87.625 TKNS.DT~ -6~.759 DPBI.LD~ 3.135 OLS.!,D~ 555.509 ~41.750 LSHV.LDR ~.105 LI,IRN.I,D~ 4220.000 ~T~.L[)~ 29 706 RTNP.CNP 29~077 RC~T.CNP 772.226 GP.C~R 1.47.8'75 HTE~.CNR -o99.250 DTRP,ITP -999,250 C~TP,D$I -999,250 DT~,ITP -099.750 GR.D8I -q99,250 CINP,DTR -990,250 C!L~,DTR -q99,750 IMOF,DTP -999,250 lTkM.n'rP 145.125 147.250 2,000 9.8?3 4220,000 21,261 -0.018 328.750 1424.000 2.109 147.875 3.215 2377.9~0 87.6~5 -61.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 ~'iS Ta~e Yerl, fication l.,istin~ ~chlu~er~[~er Alaska Co~putf, ng Center S?L!!.DTR -999 250 !;iTE~, DTR -999~250 M.RES.~DTR -999.250 R ~ 0 ~ b [> 9 999.250 D R H 0 b D R - 999, ~ 50 P':';'" 5 D R L] T~, LD~ -999.250 SSi .LDR -999. 250 S ::<.~.,...~DR SS~HV, LDR -999,250 S1RH,.bDR -999,250 LS :~.,. ~ :~. I~D R (:ALI. f..DR -999,:250 ~4RES. LDR '999,250 HT~N, LDR -999,250 N P ~':. ,":'[: .CNR Tk~PH.CNR -999,250 TNRA,CNR -999,~50 NP~:. ;[.~.':.CNR RCFT. ~.NR .... -9~9. 250 CNTC T~NS,CgR -999,250 ~R~$. CS~R -999.250 DT4m. PTF. -999.250 OT.4P, :ITP -999,250 9 T ?:~'.~::.~. P T E [)TT~.DT~ -999'250 ~TTP' ITP -q99.250 f) T M ~. ~ T ~: 152.39.4 D T ~ 1 I · P ~ 52.394 D T ~'? ::~'. P T E CgRq,~S'T 0 934 . . . D $ I' , - 9 9 END OF DATA -999.250 TE[ i$. DTR 999. 250 [)PHI.LDR -999.7,50 LL.LDR -999.250 LSHV.LD -999,250 LURH.LD -999 STE .LD -999 -999 -999 -999 -999 -999 1.60 -999 250 RTNR.CNR 250 RCNT.CNR 250 ~{TEN.CNR 250 DTRP.ITP 250 CHTP.D5I ~8! DTRI.XTP 25O PAGE: 70 -999. 50 -999,~50 -999,250 -999,250 -999.,250 -999,250 -999,250 -999,250 -999,~50 -999,250 -999, '999.250 .160.381 999,250 **** FILE TRAILER **** FIL~ NAME : ~DIT ,008 SFRVICE ~ FDIC D~T~ : 94/03/3! ~X REC SIZE ! ~0~4 FIL~ T~PE ~ LO LAST F~!.,E : **** FILE ~EADER **** FtLw NA~g : EDIT ,009 SERVICE : FDIC DaT~ : 94/03/31 ~X REC SIZE : 1024 FILE TYPE : LO baST FII,E Curves and loq header data for each ~ass, tool strinq, and run in separate files. ToOl, ST~ING NI.IMBE~: 2 P~SS ~U~BER: l DFPTH I~!CR~MENT: 0.5000 VENDOR TOO[, CODE START DEPT~4 STOP DEPTH Cblumberoer AlaSKa Computi On CeDter 31-MAR-1994 12:25 PAGE:. 71 DTE $ H E A DATE S O F T '.rIME 'rI~E TD L BOTT V 12104.0 12125.0 12.1~4.0 12114,0 DER DATA bOGGED; WARE CIRCULATION ENDED: LOGGER ON BOTTOM: RIbbER LOG INTERVAL (FT)~ OM LOG INTERVAL (FT): ING SPEED (FPHR): 89t)0.0 8900.0 8900,0 TRING (TOP DOR TOOL CODE TO BOTTON) TOOL TYPE A~X, IL~,'IaRY DIPOLE SONIC DIPCi[~E SONIC DIPOLE SGWlC PHA$OR INDUCTION PHASOR INDUCTION NUC[,Es, R SKRViCEi CARTN, DENSITY S ri N DI{; CO. MPENSAT~TD NFOTI~ON EHOLE AF!O CA,SING DATA (.)PEN HOLE blt $IZ~ (IN): DRiLt, F. RS CASI~,~G DF. PTH (~"r): L~GG~].PS CASING DEPTN eFT): EMOLE CONDITIONS TYP~: DE[,,SITY (L~/G): VISCOSITY ($): ;,;~XIMiIM RFiCORDED TEr,~PERATiI~F~ (DEGF): MUD AT MEASURED TE~P~R~TLIRE ~OD AT BOTTO~~ ~OLE, TF~mERATURE, (~T): ~LID WI~,TPAT~ AT u,jD CAKE AT (?,T) ~OD CAFE AT 1057 AA -A~ ,-AA 419 a2! 7 7 3 .... q 19 0 8 3~(.) 1. 2,2 50 51 .0 ~63.0 51.0 163.0 51.0 .,,lis Ta~.~e Veriflcat.!on I.,1. stin~ ~Chlumberger Al. aska Comput,,tnq,' Center PAGE: 72 NE!ITRO~ TOOL ~001, TYPE }iObE C[)RRECTION (I~): TOOL STANDOFF PEr, ARKS: RAW FIELD DAT~ ~RO~ DATA HAS NOT i~EEN $ LT8 FORiZ.AT DATA TYPE : CONS C,~ F ~'"' A P IN S~tCT COL.I~J STAT NATI PDA~ 6: P D T D D D~T O ~ D R~,~S A~FST ~ C S T TUN ! ~T FT FT rT WY C,/C3 F3 nEGF DEGF 6 lin ALASKA USA hENRY 132; 131 14682, 14658, 2602. FOLY~E~ ~4.5 9.4 65. 4.2 1.0 7~. 0 2,6 1.5; ? 600001 DEFI Com"a F~e~d ~el.i Field Sectt. Towns Range n~ Name ame Name O~ County StateNation or Prov,lnce Witness Name Service Order,,',dumber Permanent EleYatioD of i("iermanent Datum Log ~easured ~!~rom Above Perp~a. Den~ Datum Elevation Of ~-ell¥ Bushing Elevation of ~.,erric~ Floor Total Depth - !.)tiller Total DePth - 1,ogger Bottom £~o~ In%erval ToD Log Interval Orl. i!i~C~ Fl. ui.d Type Oriil. inq F1,;i~ Density f'>rJl]_ j.:,~ ~ ,uiri. 'Viscosity ~ ~r'. , ,. ,'.:~u LOSS ~esJ. St:ivJt'.y oi Mud Sample ~u,-~ Sa~,~.le ie~,perature ~es~stivitv oi aud Filtrate S aud Filtrate SamPle Temperatu Resistivity of Mud Cake SamDl ~ud Cake 6ample Temperature Time Circulation 6topped ,1',$ "ra~e Verl:[~,catlo~ LiSting ;c~lum'~eroer Alaska Computing. Center 31.-~AR-!994 PAGE: 73 TUtti VAbU DEF! ~!,A~ 00:30 ()6-~AR-9,<:f~ TI~E hOGGER 0.!~ BOTTOM BHT DEaF 200, Dot, tom aole Temperature TYPE : CURV DeDth !NDtjCTIO~.! DE~qP PMASOR CONDUCTIVITY Pnasor Oeep Resisttvl. t ¥ I~:~DUCTI. O~,i aED1UM PHASO~ CO~s~UCTIVlTY Pnasor ~edtum Reslst~.vitY Conductivity Il, Deep Standard Processed Oeep Inductio~ Standard Processed Resist'.ivit:.v Co~ductivit~ I'b Mediu~:~ 5taDdard 'processed gediu~ I~du~tion Standard Processed ResistJ. vl. tY !nductio~ Calibrated Induction Deep Qualit~ f'actor I:nd%Ictio~ '6~ediu~ Quality f'actor Deep Inductio~l Real !~%t. ermediat, e Conductivity Ueep i,duction Qu~d Inter~ledlate Conductivi~ ~ediu~ Induction Real. Int. erme~late Cond~cti tY ~edium lm~uction Quad Intermediate Conduct~vit. y 8f'I.., Resistivity U~averaged Spontaneous Potential. ~PI-Corrected Gamma Ray Suriace Tension ~{ t].d Temperature ~LJD ~es stivitv Head Tension Bulk Oensity ~e .1 ta Photoelectric Factor 0uaiJ. ty control of long spacir~o for bDT Odality contro! on short spacing ~or ~OT ~,ong Spacing Computed Connt Rate Long Upper 1-2 ~in~ow Count Rate Long bo,'er ~indowCount Rate Lit~olog {~indo~ Count Rate Sh~rt S~acin~ ~ Window Cou~t Rate snort Spac~n~ 2 Windo~ Count Rate [.onq S~acing High Voltage Snort Spaci6g High Voltage Snort Spacing ~ Dens~tv Long Smacin9 Bulk Dens]tV bong Umoer ~ul~ DensitF Caliper ~PI-Corrected Gamma PaY surface Tension ~ud Temperature ~U~ ~esistivity ,I$ Taoe Ver.lf.lca'tJ. on [,ist.l~ng ichlUm, berger AlasKa Computing Center' 3!-MAR-1994 ,i ~2: 25 DEI'"I HT~:~ Head T n la s on ,~F....!. Compensated Neutron Porosity, SS ,matrix, cal, i~ & dead ti. me corr, RT;~ ~aw Thermal. Neutron ~atto TP".IPN Thermal. Neutron morosit'~ TNR~ Thermal Neutron Ratio Ca!ibrate~ NPO~ Neutron Porosity from an Application Pro~ra~ RC~'~ ~AW FAR CN~ COUNTS C~)'TC Corrected Near Detector Count Rate C~"TC Corrected ~"ar Detector Count Rate GR ~PT-Corrected Gamma Ray T~{,~$ Surface Tension ~'~ R ETS ~UD Reslstiv~..t~ }.'~T g ~ ~d Temperature ~.~'r E ~ 'Head Tension OT4P D]ELTA-T COMPRESSIONAb NE MONOPOLE CO~PENSATE",~' DT4P DELT.A-T CO~PRESSI'ONAL HF MONOPOGE CO~PE~SATE:~'~ DTRP DELTA-T COMPRESSIONAI., HF MONOPOLE RECEIVER DTRP DELTA-T C~PRESSIOMAt, HF MONOPOLE RECEIVER OTTP DELTA-T COMPRESSIONAt, HF MONOPOLE TRANS~ITTE?.~ OTTP Df[~I, TA-T CO~4PRESSIONAL HF ~ONOPOLE TRANSMITTEr:.. C~'{Rn COHERENCE CO~PRES6'IONAb P&S MODE RECEI. VER CSTm COHERENCE CO~PRESSIONAL P&S MODE TPAN6MITTER L)TM9 DELTA-T SHE,AR (JPPER DIPOLE MODE COMPENS.ATEO DTM2 DCLTA-T SMEAR UPPER DIPOLE MODE COMPENSATED DTR2 DELTA-T Se{EAR UPPER DIPOLE M. OOE RfiCE.IVER C~fR7 COHERENCE tIPPER DIPOLE NODE RECE'IV~TR PP POisson's ~atio (;~ fi~PI-Corrected Gamma Ray PAGE:' 74 DATA FnR~AT SPECIFICATION REC[)~D ** ** SET TYPE - 64E~ ** TyP~ REP~ CODE VADU~ 2 66 0 3 73 296 g 66 ~ 73 7 65 8 ~6 0,5 9 65 11 66 I~ 66 13 60 0 Tame VerifJ. cation D, istinq ;chlumberqer AlasKa Computinq Center PAGE: 75 .... YPE REPR CODE · '14 ~5 15 66 68 16 66 0 66 ** SET N~F SERV UNIT ~D O~PT FT CTDP Ol,~ CIMP DLR ILD Ob~ OH~ 1, F'R E P h ~ t,'~ Z I.P~F iIRO DI.,R ~HO IIAD DDR gMHO IIR'~ DLR kuHO I~?~~,~ DL~ 6P DL~ G~ DL~ GAPI '~TEU DLR DEGF ~OB LL~ G/C3 i)~ ~-i 0 I, UP G/C3 OLS I.,L,~ QgS L~ I.,L, ~ CPS LU Lh~ C~S ~L LLR CPS LTTH I_,L~ CP3 5S1 LL~ CP~ 5S2 L~R CPS L,~Hv LLR V S$8V LL, R SIRu t.,L,R i.,~ R~ LL, P G/C3 GP I L,R G~PI TYmE- C~AN ** S~RV'ICE API AP1 APl AP1 ORDER # bOG TYPE CbASS MOD 629408 O0 000 O0 0 9 629408 O0 000 O0 0 629408 O0 000 O0 0 629408 O0 000 O0 0 629408 OO 000 00 0 629408 O0 OOO O0 0 629408 O0 000 O0 0 629408 O0 000 O0 0 629408 O0 000 O0 0 629408 O0 000 OO 0 629408 O0 000 O0 0 629408 O0 000 O0 0 620408 O0 000 O0 0 620408 O0 000 O0 0 629408 O0 00© O0 0 629408 O0 000 O0 0 629408 O0 000 O0 0 629408 O0 000 O0 0 6294~$ O0 000 O0 0 629408 O0 000 O0 0 629408 O0 OOU nO 0 629408 O0 ()00 O0 0 620408 O0 000 O0 0 ~20408 oo 000 O0 0 629~08 O0 000 O0 0 629~08 O0 000 O0 0 6294n8 O0 00o O0 0 629408 O0 000 O0 0 620408 O0 000 O0 0 629,~8 O0 000 O0 0 6299n8 O0 000 O0 0 629408 nO 000 O0 0 629~n~ O0 000 O0 ~29~08 0() 000 fig 629408 O0 O00 O0 ~294o8 nO 000 O0 629408 O0 000 OO 0 620408 n{') 000 nO 0 ~2q408 O0 000 O0 6204n~ O0 000 O0 0 62q40~ nO 000 O0 O 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 g 9 9 9 g~ 8 S .~"~ i:.. ~i .... . "'., 1 .i 4 o~ OoVOCO0000 1 1 ~ 08 0000000000 I i 4 68 0000000000 1 I 4: 68 0000000000 I I ~ 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1, 1 4 68 0000000000 I ~ 4 68 0000000000 I 1 ~ 68 0000000000 1 i 4 68 0000000000 i I 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 i 1 4 68 0000000000 i i 4 68 0000000000 i I 4 68 0000000000 1 i ,4 68 0000000000 I 1 4 68 0000000000 1, I 4 68 0000000000 1 1 4 6~ 000000000o 1 1 4 68 0000000000 1, 1 4 68 O000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I q ~8 000o000000 1 t 4 68 0000000000 1 ~ 4 6e o000000000 1 i 4 ~8 o000000000 1 I 4 68 000o000000 i I 4 08 0000000000 i 1 4 08 O000000000 1 I 4 68 O00OO0000n 1 1 4 68 0000000000 1 I 4 6~ 0000000000 i i 4 b~ 0000000000 1 1 4 68 0000000000 1 i 4 6~ 0000000000 1 I q 6~ 0000000000 1 1 4 b$ O000000nOn verification Li,$ttnq 31-~aR-! 994 ,C!~lu;~berqer ~lask~ Co~put,tn~ Center' 76 TEr~S LLR bB 629408 O0 00!) O0 0 9 I i 4 68 g'r~]~ LLR DEGF 629408 O0 000 O0 0 9 I I 4 68 'a~E~S LL~ OHM~ 629408 O0 000 O0 0 9 1 i 4 68 HTEN L, LP [,B 629408 O0 000 O0 0 9 1 1 4 6S ~;PH~ Cb~ PU 629408 O0 O00 O0 0 9 i I 4 6~ a T.,~ ~ CL, R 62940~ O0 000 O0 0 9 1 I 4 68 TN Pt'! C t,,~ P ptl 62940~ O0 009 00 O 9 I I i 6t 'r a;, ~ ~ CLP 629408 O0 000 O0 0 9 I t ~t 69 NPiJ~~ CibR Pit 629.108 O0 000 O0 0 9 I I 4 6~ ~Ca~ CL~ CPS 629408 O0 O00 O0 0 9 i i 4 68 RCFT CL~ CPS 629408 o0 000 O0 0 9 I S 4 68 C6~TC CLR CP6 629408 O0 GO0 O0 0 9 I I 4 68 C~TC C,b~ CPS 629408 O0 000 O0 0 9 1 1 4 68 (;~ CLR GAPi 629408 O0 000 O0 0 9 i I 4 68 TFNS CLR LB 620408 O0 000 O0 0 9 1 t 4 68 ;V~TE~ C,[.~ DEGF &2940~', O0 000 O0 0 9 i 1 4 08 d TE ~." CL~ L}3 629408 O0 000 O0 0 9 1 I 4 68 DT4P PI~ 629408 00 000 O0 0 ~ 1 I 4 69 DT4P ITP 629408 0() 000 O0 0 9 1 I 4 68 DTRP DTE 629408 O0 000 O0 0 9 1. i 4 68 OTRP !TP 629408 00 000 O0 O 9 I I 4 68 I)TT~ PI'~ 629408 O0 000 O0 0 9 1 I 4 68 bTT~ ITP 629408 O0 000 nO 0 9 I l, 4 68 C'." ti~ OSI 629408 O0 000 O0 0 0 1 1 4 68 C l '.' '~ . , ,t.,!,,~ ~S'l 62o.a('~$ oo ooo oo o ~ 1 I 4 60 ~'.)'r ~ ~ PTE 62940~; OO OOC, 0(,, 0 9 ~. 1 4 68 L)~Y~ II:P 62940~ O0 000 O0 0 9 I ~ 4 6~ ~')~ ? P'I'~ ~q406 no 000 O0 0 9 i ~ 4 ~8 Cr4R9 PST 52~,408 O0 000 O0 0 q 1 i 4 6g P~ ~Sl 629408 O0 000 O0 0 9 1 i ~ 6~ g~ DST g~P! 62040~ O0 OOO O0 ~ q 1 1 4 6~ 00000000;.:<'! 000000001~?~ 000000001~,:~ O0000000<;i"~ 00000000~,.'~> 00000000~><'" 00000000,'~'~ 00000000,,?,~', 00000000:~<,: 00000000;~ 00000000<~::', 00000000,>,~', 00000000<~"' 00000000, ~ 00000000,,,,,'~ 00000000,,~'~ 00000000<~:" 00000000 00000000:,'~ 00000000:~~: O00OO000 00000000 0000000~ 00000000 00000000 00000000 00000000 00000000 OVpT. 12105.500 ClPP. DL, R TL~.DLP 10.OOO l [.'R g, L,I.,R iTRD.DLP 73.9~8 IIXD.DI.R ~{VLTI. nb~ 13. ~ SP, OI, R ;~TE~' ~b~ 159.013 ~RES.DI,R b~dn, I,LP O. 039 PEF. I,,S. !_,i., P 11o5.000 I,j. bl.~' SS 1. L,L~ 303. OhO 882. LI,R S I Rw . ~,I.,R I. 041 LSPH. gl,a G~.I,LP 69.563 TENS.LLR H ~r a~::'. L,L~ -25.813 ~PHI. C!,F< T~'~I.CbR 2.717 NPOR. CI.,~ 80. zl3g IDF s. DI.,R 17.430 C I?.!P. 9L.~ 82.625 I! .... '.DLR 12.094 CIL~.DDR 2n.oo0 Ii)C ~ .DLR 3.000 6.020 lip .OLR 94.56! IlXa. DbR -14.266 C.,' .DL~ 69.56~ T~NS.DLR lnO0.O00 O'l S. LL, R -0.025 QSS. [,[.,~ 1067.000 I ~.,. bLR 571.500 L!I'N.LL~ 4i9.000 b3). ',:.bl,a 1258.000 5SHV.I..,I,,~ 1.742 LIIF~,,.Li,~ 1.765 CAL, T.Li, R 3920,000 lt~T~': ..LLR !59.013 35.685 RT~' ,,. CLR 2.~66 27.53~ RC:' ~'. CLk 3199.857 RC~'T.CbR 9S.O00 99.938 2.000 0.371 3920.000 1,772 0.089 246.87b ~294.000 12.250 0,539 27.532 1098,216 ~IS TaPe VerJficati, o~ Listt,.no ;cblumberger ~lasKa Compl,ltin, g Center 250 DT~P. PTg 999.25 250 CH~P.DSI -999. 250 250 DTR2.PTE '999 250 25() gR.OSI -q9g 250 0 ~': P T. 12000.000 C I l 1., ~. ['.> L R 5.953 l F R E. 0 L R I!'~P.DL~ 16().250 IIXD.DLR S v L U. P L P 5.945 S P. D L R DR~O.I.,bR O. 105 PEF.bI.,R i,,,~ , LLD 3 ',!. 9 , 250 La. LLR SS i.I.bD 278.000 ~-~ ~ k H. 1 ,L, R 2.22 3 I,, S R H. i',, I.,, R G~. LLR 53.7 ~ 9 TEFo, bT,,R , ~ . '~ [ T Ra.Ci.,R 2.799 NPOR.CI, R .... ~ . . "'~ *~ ~ . C;~'I"C.CbR 2708 394 C~"C CT,R Fi ~ Eo ~ . C l',~ R 0.533 M T L'T4D. ITP 72. 752 PT 'DtTp,, · ., . !TP 72.344 C~a~P.DSI ~" ~ ..... a . DT~q~ TTP 1~6 905 DTR2 pP,DoI 0. 303 ~R.DSI D ~ P T, 11 t~ 56.000 C I D P, i) L R i {~ Pt~. DI.,R -999.250 IL'~ Dt,R -999.256 IFRE IIRD.DbR -999.2.,0 I%XD DI.,R SWLI). DLR -999. 250 SP. D!,R .F~[]~.DL~ -999. 256 i)P }tO. I.,LD -999. 250 PEF. i..,~. T, LR -999. 250 I..,0. ~51. [.,LR -999.250 SS2.LL~ '" 1R~ T,LR -999.250 GD. I.,l:..~ R -999.250 TEiNS. L!,,A H T E ~;. I. I,~ R - 9 q 9.2 5 O ~,T p H 1:. C I., R TK~R n. CLR -909,250 5, PCIR,CLR C~'rC. ~bm -999.250 CF'T C. C!.,~ ,',; ~ H' ~. CLR -909.25v ,.~ .[ E ,'4. CfR l)T,!p. T TP -9Q9.250 3TI'D. ITP -999.250 CHPP.O3I [>T(< 9. T TP 131.84q g'~ 2. PTE F'~. DST -999.25U ** Eh[',; OF DATA 179.500 84.250 1'20.000 13.070 -3. 994 0.533 4.25B 30g 000 344: b~l 5. 000 27.419 3O .544 980.09.1 1,58.900 7 3. ! 60 0.92..8, ,t4o. 344 53.719 -999.250 -q99.250 -99q,250 -999,250 -090,250 -999.250 -099.250 -999.25o -099,~50 -999.250 -999.7b0 -999.2~0 -.Q90.250 -999.2b0 7~.2~8 0.9U7 134,274 -q90.250 H TF, , C LR D T F' ?. I T P D T F, 2. I W p 69.563 -25.~13 -999 250 -999:250 -999.250 5.566 C!~P.. DLR 5.422 CILN.DL, R 1 58.125 IIX~.DLR 53.719 T ~: I,~ S, D i,, R 1076.000 a H' 0 B. I,, I.,, P 0.02I O"$ LbR 16~.875 LITH.I,,LR 1261, .000 SSi,iV. I.,.bR 2.445 C l L I. I.,, L R 1, 5 B. 900 M R ~; $. L L a 2.96 O T 'N P H. C h R 2760. 302 RCFT.CLR 53,719 TENS.CI{R 1076~000 DT4P.P E 7 3. 100 K, TTP. PTE O. 075 r~v2, PT~ ,.i ,a. n . 3 ,.,~ ,',: , ...... ~. ,, .> . c 9 g ., ~ ~ "~ "'; . "7" ,l*, l~' .,,, ""' -5' 5 !',.. '2,5, L: -999.25u -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -~99. 250 -999.250 -~99.250 78.248 -999.250 1.]4,274 P A G 7 7 999.250 '999'250 250 '999,,5 "999,2,.0 161.625. 167,875 0,000 7.141. 6815,000 2.557 0.062 74.563 ~.295,000 12.680 0:.533 29,804 942.652 6815.000 72.752 72°344 136,905 0.964 -999,.250 -999.250 -999.250 -999.250 -999 250 -999i250 -999 250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 131.844 0,967 ,IS Tape Ver.!.fi, cat!on I-.,ist~.nq ;chlumberger A].as~a Comput,.~n~ Center 31.-MAR- !. 994, PAGE: **** FILM TRAILE~ **** FILM ~!A~E : EDIT ,009 S~]RVICE : FL!C a~X aEC ~!'ZE : ~024 FT[..,~ TYPE : LO **** F I [,F, HE/~DF~ **** FTbE NA~E ,' EO!T ,0:10 $~RviCEi : FhlC VERSION : O0~.COl DIT~i : 94/03/31 MIX aEC S!Z~ : 1024 FILE TYPE : [., ~ ST FILE Curves and log header data ~or each ~ass~ tool str.i.n~, and run in separate 1 0.5000 VEMDO~ TOOL CODE ST~RT PEPTN SlOP P8~ 1 3oi ~. 0 1212a. o ...... - ~TE 1391.4,0 12126 I.DT I 3920.0 12126.0 CaT 13920,0 12126.0 'x~ I,T 1.3~8(). 0 121 40.0 LgG HEA~;~ ~ATA SOFTWARE V'F~RSION: TI,.'E CTRCOLATION ENDF]D: TIrE LOGGER TD OPlLLRR (PT1: mD LOGG~ER(P'T) TOP LOG TNTEPV~L (~T): t. OC(;i. NG SPEED (FP~;~) · UOL STRING (TaP T~ BOTTO/4) '~ENr~c~ ~Ont., CnDK TOOT, TYP~.; ,'.15 Ta.~e. Verification L. istina :ChlumbergerAl. aska Computing Center 31-~AR-!994 ,: ?:25 79 TC:C GR PSI DS].'.' D$I DTB LDT AUX.T. LLIARY MEAS, :I'ELEMETR~" CARTRIDGE GAMMA RAY GA ~'A RAY D~POLE SOWlC DIPOLE SOniC DIPOLE SONIC DIPOLE SONIC P~ ~S(:,P INDUe~'' .~UCLE~R SERviCg C~RTR, DENSITY Co~fPE~,~S ~TED M IC~:J LOG POREHOIJE A~i~D CASING DATA OPEN MOLE k~!T SIZE (IN): DRILLERS CASING DEPTH LOGGEPS CASIN~ DEPTM (FT): P,{JP EWOI,,E CONDITIONS MUD TYPE: ~.~UD DENSITY (LB/G): Mill) VISCOSITY (S): FLUID bOSS (C3): ~OD AT MEAS'ORED TE~PF, RATI~RE ~t.l~[~ AT BOTTO~ HOLE TENP~.]RATI..II~E MOD FII.,'I.'~AT~; ~:T ~'Or) CAKE; AT (~;T): ~L~ CAKE AT STANDOFF (iN): ".E'~.~ARKS: R.~t: FIELD DATA FROM RUN 3 LO~ER REPEAT, PArA HAS N[]T B~E~ DEPTN CCRRECTED, LIS F~R:',~AT ~ATA h~:~ ..... ?",h 874 'II C C SGC ,~:.A 557 SGD ....... ':'.AA S P A ::.:,' $ a I>- A A 3 3 SS,l :,~-6A 33 BlS N S C '< 7 7 3 ORS ~:" 1908 CNT ~A 340 ~I..,T /" 26 POE'",' I ER SOLTEX 8,, .184 ,. ' 1..i~"O 63.O 0.,~:'9 184.0 0.'"":':6 48.0 0.:':'.'7 1,84.0 1,V::':.) 51.0 chlumberger AlasKa Co~putj. n~ Cen..ter 31-.~q. At~-1994 :?:?5 PAGE." .80 T/~BI~E TYPE : CON'S F~ NORTt,t C JOE INLET Fiei, d Name ~ NCiU SUNF:ISt.~ ~3 Well Name APIN 50-883-20090 AP1 Serial Nuaber F~ 1249' f"[~l~ & 980' FWL Field Location SECT 6 Section T O ~ ',: 11 N T' o w n s n i p t~ ~ ~ 9~ Range C 0 U'~,~ KENI I Cotlatv STAT AI.,ASKA State or Province N a T 'I U S a N a t 1 o n ~ !T~,~ ~E~ Y Witness ~:ame SON 629408 Service Order ~umber PDAT ~ I.., v, Permanent datum EPD WT 0. Elevation oi Permanen~ Datum L~F' KB Log ~easured From A~t':) ~"!~ 132. ADove Permanent Datum EKB FY 132, Elevation o~ ~el].,Y .Bush:i:n~ EDF ~T 131 Elevation o~ Derrlc~ Floo~ ']:~DD FT 14765. Total Depth - Driller T~:L vT i46~2. Total Depth bI,,I FT 14658, BOttom bog Interval TI,I FT 2602. Top Log Interval DFT POhYMER 8OhTEX Drilling Fluid Type,. !.)KD ~/C3 14,5 Drilling Fluid Density F'p~ 9.4' 9rilling Fluid Ph O~"V' S bS. Drill, lng Fluid ViscoSitY [:)~'I.,, ~3 4,2 Drlll. ino F].uta boss a~S []H~~,,, 1.O~ Resistivity of Mud SamPle ,:~ST DEGF 73. ~u4 Sample Temperature RuFS Od~ 0 6600001 Resistivity oi Mu~ Kilt:rate S ~FST D~GF 5~. ~ud Kl..lt~ate Sample Temperatu RuCS oa~:~ 2,67 Resistivity of ~ud Ca~e Sampl ~,~C~T nEGF 45. ~ud Cake Sample Temperature TCS 1K:OO 05-MA~-94 Time Circulation Stopped ~I.,A~ 00:~0 06-~i~-9~: TI~E LOGGER O~ ~OTTO~ 6UT DEGF 200. Bottom Hole Temperature [.,~"pT IOP~ CIiqP CTLD l'>emth TNnUCTION DEEP PNASUR CONDt]CTIVITY Pnasor [)oep Re$istlvJ. tv IN!)UCTION ?~EDILJN, PHASUI~ CL)NDI. ICTI. V.iTY Phasor ~:edt, Um Reslstiv!,ty Conductivity 1t, Deep &tankard Processed ~eeD In~ct.i, on Standard Processed Resistivity ,,IS Ta~e ~ertitcation bistinq ;chl. um~er~er A!a~ka Co%Putino Center 31-MAR-~994 :~2:25 PAGE: induction Standard Processed ~eslst(vitv 'Tnduct!on Deep ~ual.ity Factor Induction ~ediulT~ Oua!ity F'actor Deep Ind~ct~o~ ~eal !~ter~ecllate Conductivity Deed Inauct. ion eua(~. ~ntermedlat. e ConductIvltv :~ediur0 IDduct.iOn Real Intermediate Conductiv] ~:,~edium InductioD (~uad Intermediate Conducti. vit;v SFL Resistivity llnavera~ed Spont, ar~eous Potential '" APl-Corrected Gamma f~av suriace Tension ~u,d TemperatuI"e ~leed Tension Bt.11k. Density Del ta Phot~elect.ric Factor Oual tv control., o~ lonfl spac~.n~ for Ouali5y control on short sDaclng ~or bon~ ~¢ac~ ~ Co uted Count. ~ate bon~ Upper i-2 .. ndow Count Rate (LUI+LU2) LODg Lo,er W~.ndow Count Rate !.,Jt.[~olog W~ndow Count Rate Short Spacina ]~ Mi~dow Count ~ate Short Spac~na 2 win~ow Count Rate Long Spacimq"High Voltage Sho~t Soacifiq Hioh 'V'oltaqe Short. SpaCinq I Density l..,ong Spacing Bulk Density Bong' U~per 6ulk Oens~..ty Cal iper &PI-Correcte¢ Gamma Surface Tens ion ~ud Temperature ~UD Pesistivity Head Tension Compensated ~eutron Porosity, SS t..'iatrix, cali ~. dead ttme corr. aaw Tqermal ~,~eutron Patio Thermal N. eutr-on Porosity · her~al ~,~eutron ~atio Calibrated ~eutron Porosity fro~ an aDp].icat, lon ~.~ NEAR CNT C(1U PAW ~'~%R CNT CL,]UNT5 Corrected ~.~ear Detector Count Pate Corrected Far Detector Count Rate AP!-Corrected Gamma Ray Surface Tension F~UD ~esist~VitV ~*ud Temperature ~ead Tension DE[,TA-~ COHPRESSTO~IAT., ~¢ ~!r']aOp~LF CG~PENSATED fP&S) .,IS. ?ape Ver!flc~tion. Listi. n~ ;c~lu~.h. erger Alaska ComPutfDU Center D~FI b ? R ~ ... _ .. T ~ - 'r C.O.P. g $ S I U N A L B' F R .... DTRP DEY..,TA-T CO['PRESSIO~';~AL JIF' MONOPOLE RECEIVER DTTP DELTA-T COUPRESSI[)NAL HF MONOPOLE TRA~'~SMITTER DTTP DELTA-T CO~PRESSIO¢'~AL 8F MONOPOLE TR.AkSMITTE'~ C~'~R¢ COHEREr~CE C[)~RESS!ON~L P&S I~ODE RECEIVE~ C[tT~ COHE~E~:CE C['.)gP~ESSIONA[., P&S ~ODE T~ANS~iTT~R OX'~'~ DEI,TA-T $~iEAR LOWER DIPOL~ MODE COMPENSATED [;TF~I DEI.,Tg-T S~AR LOWER DIPOLE MODE COmPENSaTED DTR] DEb".r~-T SHEAR LOWER DIPOLE MODE RE;CEI~ER C'~R~. C(~!4.E~ENCE I,t.]WER DIPOBE MODE RECEIVER '~ p o '..ofss n s Rat, lo RSHC PATIO SHFAR TO C~NPRESSIONII,., i)~]l,,..~T,& T G~ IPI-Corrected ~amma Ray G~ aP~-Corrected Gamma RaV MCAI~ t.,aroe Arm T'~]iq S Surface Tensio. ~! ~ ~';S ~fOD ~esistivity .,~ T "' ~ '~ .... ~UO Temperature ~TE~: ~ead Tension ~:~ ~ .l~ ~t. cro-Inverse :i.~No ~icro-Normal PAGE: ¸82 path FORMAT SPECIFICATION RECOPD ** ** SET TYPE - 64ED ** 1 66 0 2 66 0 3 73 328 4 66 1 5 66 ~ 73 7 65 8 6~ 0.5 9 65 Fi 11 66 3 17 68 ~3 66 0 i 4 65 15 66 68 0 ~ h 1. ~IS ~aDe '~'er..ff:.IC.~t:l. On UiStlnq ;chlumberger AlasKa ComlPutinc~ Center 3 J -tv~AR- !. 994 !2:25 PAGE: 83 ** SET T)IPE - C!,~AN ** -,--,--,-,---,,---,,,,,,------ ........ .--.-.---...-.-,,-.-....-.-.. ..... . .... '~N E V IT E APi .~PI APl API FILE N :~ ~,~U~B SIZK, REPR .R ES ID ORDER # LOG TYPE CLASS ~QD NUmB SA~P EI.~E~q CODE (HEX) ''''''''''''''''''''''''~ FT 629 08 .... 00''''''000 00'''''''0 ..... ~ 9 ''~'' ........... 1 4 "' ..... 68 '''~;~;''''''""000000 CIDD l>.I:,:R M~,',HO 629408 O0 000 O0 0 ]IDP},~ DbR ClP, MN 629408 O0 ()00 O0 0 ~,0 CI~qP r~[.~ .~HO 629408 O0 000 O0 o I~P~ DL~ ClWMg 629408 O0 000 O0 0 10 i 1 4 68 C~LB DLR M~'HO 629408 O0 000 O0 0 I!,D DLR OH ~t N~. 629408 O0 000 O0 0 10 CIL~ DL~ ~MHO 629408 O0 000 O0 0 10 I!,N [)LR OHMP 629408 O0 000 O0 0 10 1 I P~) F DLR 629408 O0 000 O0 0 I~Ow O[,R 629408 0O 000 00 o IlaD DI,,R ~MH~ 629408 O0 000 O0 0 10 1 1 4 68 I~ DLR t4~i0 629408 O0 000 O0 0 10 1 I 4 II'R~: DLR ~?~HO 629408 00 GO0 00 0 10 1 I 4 68 I!'X~ Oi.,,R ~g:HO 629408 O0 000 O0 0 10 1. 1 4 68 SFL~ D'bR [])a~ 629408 00 000 O0 o SP DL~ :,iV 629408 O0 OOO O0 0 I 0 I I 4 68 I.;~ DLR GAPI 620408 O0 000 O0 0 !0 I 1 4 68 T~NS DL, R LB 629408 O0 000 O0 0 10 1 M'PE~ DL~ DEGF 62940~ O0 000 O0 0 10 1 1, 4 68 N~RES Dh~ O~lg~ 62940~ O0 OOO O0 0 10 1 I 4 68 HTE~ ()b~ bB 629408 O0 000 O0 fl 10 1 1 q 68 R~40~ I.,D~ G/C3 629408 O0 000 O0 0 10 1 1 4 6~ DPH~ I_,D¢ G/C3 629408 O0 000 O0 0 10 1 I 4 68 PEF" [,D~ 629408 O0 GO0 O0 0 10 1. 1 4 68 Q[.,S t,D~ ~294OG O0 000 O0 0 OSS LDR 62~4o8 O0 000 O0 .[,,S ~,DR C¢5 62~408 O0 000 O0 0 1.0 1 .[.,U I.,D~ CPS 629408 O0 000 nO 0 10 1 1 4 68 LL Li.)R CP~ 629408 O0 000 00 0 LITW /.,DP CPS 62940~ O0 000 O0 0 10 I 1 4 68 SS1 I,D~ CPS 629406 O0 OOO O0 0 10 1 1. 4 6a 852 LGR CPS 629408 O0 000 O0 0 1. 0 1 i 4 68 SS~V LDR V 629408 O0 000 O0 0 10 Si. RH LOP G/C3 629408 O0 000 O0 0 10 1 i 4 6~ .!.,SR~ Li)~ G/C3 620408 O0 000 no 0 lO 1 i 4 bt~ T,DR G/C3 629408 O0 000 O0 0 1.0 1 1. ~ 6~ CILI r.,DR I~] 62~408 nO 000 O0 0 !0 1. 1 4 08 (]4~ LDP GAPI 62940~ O0 OOO OD C. lO TFN,c l,DP LB 620408 O0 000 O0 O lO 1 ! 4 b8 ~;~TL'~ LOP L)EGF A2940~ O0 GO0 O0 0 !0 1. I 4 6R ~.~PE~ I,DP [)~b~ 6204nb O0 0~0 O0 n 10 1 1 tiT~]N [.,OP j~P 6294n8 ~() OeO O0 0 I 0 1 k. v r.I r Ct.~R PU 62o40~ 0(') uO0 O0 ~ 10 1 1. .1 68 RT,~ C~R ~2o408 O0 OOO O0 0 10 l'~p~ C~,P P[.~ 62940G O0 000 O0 0 !0 i 1 4 T~R~ C;',,P 62q408 O0 000 O0 0 10 ~ ~ 4 68 N~(')V Cr',,P ["~ 62q~n8 O0 000 O0 0 ~0 1 ~ 4 oB ~ C r'~* C>:P CPS 629408 au 000 no o ~0 1 Tame Vertflcatlon I, isti. nq ;chlumberqer AlasKa Computl. no Center 31-MAR-1994 t2:~g PAGE: ~4 ,~ 'w'RV UNIT T~ ORDE~ ~ bOG TYP RCF~ Ci~R CPS 629408 O0 O0 C N",F C CN~ CPS 629408 O0 000 CFTC CN~ CPS 629408 oO 000 GP C,?{, R G,~PI 629408 00' 000 ".t' ~ N S ci~a bB 629408 O0 000 M~ES CaR OHMM 629408 O0 000 a'rE,.~ CN'P DEGP 629408 O0 000 H~EN CaR LB 629408 O0 000 DTgP PT~ 629408 O0 000 oT4'o ITP 6~ 408 00 000 DTRp PTE 620408 00 000 DTRP ITP 629408 O0 000 }')TTp PTE 629408 O0 000 DTTP !TP 629408 00 000 C~{}{P DS'I 629408 O0 0O0 CNTP DSI 629408 00 000 DTM1 PTPl liS/F 629408 O0 000 DTN~! :!'TP ~StF 629408 O0 O0O ,t:> w t'~ ~ P T E 629408 00 00 ~,)~ ~', ~ PTE 629408 00 Cu~,4 ~. DS1 629408 O0 000 PP PS1 620a08 O0 000 RSHC DS! 629408 O0 ()00 GP D5I GAP! 629~08 00 000 Gp Yi I.,, P GAPI 62040~ O0 000 aCAL ~/,R IN 629408 O0 O00 'I' ~','~ $ ~LP bB 629408 O0 000 0~°E;~ ~'LP OHMM 629408 O0 000 :,"~'E~ ~i.,P DEGF 629408 00 000 aVEr s,t,,, P LB 629~08 00 000 · o GriMM 620408 O0 B~NO ~}.,P OH~V,~ 629408 00 000 mm mm mm mmm .mmmmmm~mmmmmmmmmm.mmmemmmm 00 0 10 I 1 4 68 0000000000 00 0 10 1 I 4 08 0000000000 00 0 10 I :1 4 6 ,,q. 000 o 000000 00 0 ~ 0 1 1 ,4 68 000o000o00 O0 o 10 1 :1 4 oa 00o000000o O0 0 10 I i 4 6~ 00o0000000 00 0 !, 0 1 I ,4 ~ 8 () 000 000000 00 0 1, 0 I i 4 68 000000000 o 00 0 10 I 1 q 6 '8 0000000000 O0 O 10 I 1 4 ~8 0000000000 00 0 1. 0 1 1 4 68 000000 C) 000 00 0 10 I i 4 68 000000()000 00 0 1, 0 1. ,1 4 68 0000000000 00 0 10 1 1 4, 68 00000000 O 0 . . "~ . O0 0 ! 0 I 1, 4 ot 00000000o0 00 0 10 I i 4 08 O000000000 O0 0 !,.0 I I 4 6a 0000000000 O0 0 1 0 1 1, 4 68 0000000000 O0 0 10 1 I 4 68 0000000000 O0 6 10 i 1 4 6~ 0000000000 00 0 i 0 1 ~. 4. 6 ~ 0000000000 O0 0 !. 0 1 ~ 4 6~ O00OO00000 O0 0 10 1. i 4 68 0000000000 O0 o 10 1, I 4 69 0000000000 O0 0 10 I I ~ 6~ O000000000 00 0 10 I 1. ,4 6 ~ O 00 O 00000 n o0 0 10 I I 4 69 0000000000 00 0 I0 1, l 4 oS 00000000(),~ O0 0 ! 0 1 I 4 O~ dO00000000 nO 0 10 1 1 4 6~ 0000000000 D~PT. 139~2.000 CIDP.DLR i," PU. n.L,P 9.760 CIL, O.DLR T. b.~. DL~ 9. 575 IDOF.DI, R 7 XD. DLR -1 O. 267 TIPM. DI, R SP. ~L,P 441. 500 G~.DI,R ~PES. ~bR 0.249 OEF. [,i.>~ -999. 250 O[,S. LDR LI~. LDR -9~9. 250 .~S~. [.,f'~P -999. 250 T,SH'V. LDt< !,qRW.I,DP -999.250 I,UPH,LDR '_I_' ~'/~ ~. T.,OP -9o9. 250 MTEM. 'GD~ mOP. C{"~ ~ -999.25u RCNT. CN C~TC. C~ P -999. 250 89 009 IDPS, :.'... :; ' '>3S '" ~' ; : ;:' .- . - ~. e ' ,,, ~ - ' ,,, 91..t06 ILb. :i.,: ; :'". ~',~7 0.000 I ~.I O F. :..,,~ ~., t-, C . ,.': ~ ,. 65.946 TENS. 0f,~ 302n. o00 -b2.533 RHO~;.LPR -990.250 bf~r3. LDP -999.250 dS6.LPa -999.250 LS.Li)R -~99.250 I.,IT~. iaPk -99Q.250 85! .LOR -999.2b0 SSHV'. LDt< =ogo.2bO 8 ! kit. [,,DP -090.250 CA[,.I. LF:R -99q.~5C, GR.LOP -999.250 MkE,S. ada -999.250 -99q.2bO TNPM.CNR -99o.250 -99n.250 PCFI'. C;OR -99q.)50 -99q 2'-in TE:~}S. CN'R 99Q.950 - e ~ . . . ~ . . .. ~ 102.456 104.438 81.501 8.131 184.299 '999.250 '999.250 '999.250 '999.250 '999.250 '999.250 -999.25U -999.25O -999°250 " · e'rl fication Listlnc! ..IS rant. V ;cl~l, Um/~erger Alaska Computi..n(] CeDi;er DFPT 13506.500 CIDP.DLR I ~ P w .: n b ~ - 999.250 C ! L ~*' . D 1.., ~ - 999.250 5 P. D ,& R -999.25 {) G MRES. DbR -999,250 HTEN, DE::F. L D -999. 250 SS~. I.,,D~ -999.250 !..,SHY. bDR T ~ a S. L D a - 999.25 0 ~ T E M. i.., D R ~'~ P H !'. C ~',~ R - 999.25 O R T N R. C N 'P 0 ~' C "' ' ;' "N T. R . . ..... ~,R -999.250 C w' ~I C. C a 'R - 999.250 ,,! T E;. C ~ R - 999.2, 50 H T D T R ~ . P T ~ - 999.250 D T 'R P. I T P C~R.D. DS; -999.250 CHTP.DSi O,~l..;:--3E -999.250 DTRI.PTE RS~iC. D8I -999. 250 CR. DSI 'I'~NS. ',~ I,, ~ -999.250 B~i~ ~,~ t., ~' -999.250 . ,, ~ **** F TI.,E 'rkA II,E~ **** ;~ F' R v 'l'.i C ~.: : Fh!C VKRg t 0~,', : O01COl D 5'I'F : o4/03/31 ~,~a,X R~:C SIZ~ : 1024 FTI'.,~' TyPE : T,U L~ST rILE : **** FILE HEADER **** FTLr ?.lauE : EDIT .0 5rRvlCW : FLIC PFKS!~i'~ : 00ICO1 o~'r[' : o4103/31 FILF TyP~; : h ~ 5 · F 'i L E : 3 I.-~aAR-199.4 :12:25 -999.P50 -999.250 -999,250 -999,250 -999,250 -999.250 -~99.250 .I[)P~,OLR -999,250 -999.250 I[.,D,DI~R -999'250 -~99,250 ~MOF.OLR -999,250 -999.~50 IIX,~.DLR -999,250 -999.250 TE~$.:DLR -999 250 -ggg.250 ~HOB.GDa -999:,250 -999.750 aS6.aDR -999.25a -999.250 bIT!i.LDR -999.250 -999.250 88HV.bDR -999.250 -99a,250 CAt. I.bDa 999.250 -999,250 "R~S.LDR 2999.250 -990,250 T~"PH CNR 999 250 ..... ~*~ -999o250 RCFT.CNR :9991250 -099.250 'r~::N6.CNR ~999,250 -099.250 DT4P.PTE 999,250 -99~.250 DTTP,PTE 999.250 -990.250 DT~I,.PTE -999.250 -999.250 CH~I,DSi -999.~50 22.531 GR.MbR -999.250 -99~,250 ~TE~,MLR -999.250 -990.250 PAGE: 85 -999.250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 '999.250 2 '999.250 -999, 50 -999,250 ~999,250 -999,250 -999~250 -999,250 -999,250 -999 !50 -999:50 -999 50 -999,250 -999,250 -999,250 -999,250 .,IS Tan, e refill, cation ~cblumberaer Alaska Co~.~Puti..nq Center 3 !-~.~AR-1994 12,'25 P~GE~ 86 Curves an~ loq ~eader ~at.a ~or each ~ass, tool st'rin~, and run in separate fl. les., TOOI, STRING pASs, NO~.~BER: [)~PT'H INCRE~EMTI 0.J,.667 FT I.,F St.J~N ~RY VF;Nt'.)OR TOOL CODE 8TA.~T DEPTH , 1 14,0 DTE 13914,0 T.,,DT l. 3920,0 ~b~ hOG H'~ADER DATA DAT~: [.,OGLED ~ [J F' T W A P g V F, TIME CIRCULATION E~DED: TD LOGGEP(FT) mOP 1.,O~ INTEPVA[, (F'T) P, OT'!'O~ bOG INTERVAL (FT): !,OGG!NG SPEED (FPHR) TOOl.., STR.[NG (T~P TO BOTTOM) V~OO~ ~OOb COP~ TOOl, TYPE A TCC GR G~ DS I DS I I~DT C~T mmmm AUX ]'LT,,I ~,.R Y ~4EAS o T E1..~7!'4 K TP ~ CARTR ti')CE GAMNA .FIAY CARTRIDGE GAM~A C I P~]/,~ SO~IC DIPOGE ,~UNIC DIPOL~ SONIC DIPOL~ SONIC PHASOR INDUCTION PHASOP INDUCTION ~UCLE.SR SERVICE CARmR, DEi~S [TY SONDE COMPEHS~'FEb t'JEUT~ON MTCPO bOG STOP DEPTH 1212~.,0 1,2126,0 12126,0 1.214.0,0 ! 9 - F E B- 94 6C0 490 1700 1B-FEB-94 0230 Ig-FEB-94 ~. 394 ~. 0 i. 392 a. 0 ~2126,0 ~3914,0 ¢{IDE~U[,E AND Cg. SINC DA*A OPEN ~O!.,E BIT SIZE DRII, LFiR8 CASING DEPTH (FI): [jOGGERS CAS!NC DEP'fN T O 0 t., r~l U !~ B E R Ah!~i-Aa mCC B SGC Sa 557 S G O -T .A ~ SP.~C-A ~ 31 S?,Dt.:- A ~ 33 DIS H3 421 NSC E 773 ORS C ~ 908 C N T H A 340 Mt,T A q , 121.37.0 121 x.f..0 Verification Listl, nQ ~chlumberg'er A,l. aska Computing Center !.2:25 .~,{.}'P E H O[,E CONDI TlOi',!$ ~UD .i~e, UO DENSITY (LB/G): ~'.~D VISCOSITY (S): FI, UID bOSS (C]): P~,AXIMI,IM RECORDED TENPF~R~TUR~ RESISTIVITY (oa~a) ~T ~OD ~T 2EASORED TffJ~P'~RATI:IRE ~OP AT BOTTO~ ~IUD FILTRATE AT ( ~tj'D FILTRATe; AT i~[J9 CAKE AT fl!T): ~UD CAKE A~ (S~T) ,~ EU'F RO ~.~ TOOL TOOL TYPE (EPTTFIER~AL f~. ATRIX: ;~ATR IX DLNSITY: ~i ~'.') b ~ COrRECTiON STANDOFF P,E~ARKS: RAW FIELD DATA FROIq RUH 3 LO,~FR REPEAT H! RESOLUTION ;qLT. [)AT~ ~AS ~IOT BEE~,:t DEPTH CORRECTED, POL. Yi~'~!ER SOLTEX 13.5 65. ~ 8,0 4.5 1.060 03.0 l'J: 9 ?,. a 4: o 1.560 51.0 PAGE: 87 CONS 'I'll ih I VAI,U DEFI C~'~ PHiLbJ'.PS P[;TROL~d~t' CO~!'P~NY ?'~: NORTH COOK .~N mCIH SUNFISH ~3 a~!.~' 50-883-20090 FT, 1249' ~'NL ~ 980' SFC· 6 cnu ~ K F ~,~ A I STAT ALASKA N n T T t.J S A Sn,'~ 629.~0B E,m:j ~'T 0. ~;vE. ~T 132. 'I'~0 ~T 1 a, 705. CompamV Mame Field ~ame Well APl Serial Number Field Location Section TOWDSh~D Ranqe Couatv State or Province aation ~itness ~iame Servlc~ Order ~,~umber Permanent datum ~levatton of Permanent Datum Lo~ ~easured Fro~ ~oove Uermanent Datu~ ~levat. ion of Kelly BushiDg Elevation ol Oerric~ F],oor Total. ~eoth - Driller ~IS ma~e Ver!,flcat,ion Llstlng~ 31-MAg~-~.gg4 12:25 PAGE: 88 ;chlumberger AlasKa ComPuti. no Center ,roi, FT !46~2. Total DeDth - Logger aL1 FT 14~58, t~ottoa, Log I~t:erval TLi FT 2602. ToD Lo~ Interval D~T PObY{ViER SOLTE~ Orill. in~ Flol. d Type, D~D G/C3 14,5 Orilli..no Fl, uid Densit~ D~'~ 9 4 Orillind Flui. a Pb [)FL F3 4 Drilling F.lui~ boss ~$ OH~M 1.O~ aesisti. P.Ity of. ~ud Sample ~,tST DEaF 73, mud Sample Te~r~Derature ~$ OH'~M ~6600001 Resistivi..tV of: Mud Filtrate S ~FST DEGF 5z, ~ud Filtrate SamPle Temperatu R~CS OH~ 2.67 gesistl, vitY of Nud CaKe Sampl ~CST DEGf' qS, ~ud Ca~e Sample Temperature TCS 1.5:00 05-~,~AP-94 Time Circulation S~opped T[.~A~~,, 00:30 06-~AR-94 Ti~E LOGGfR Ct~,~ SOT t:~HT DEGF 200. 13ottom Hole Temperature T,t~bI,,'E TYPE : CUPV ** DATA FOR'~A? SPECIFICATION RECORD ** SET ?YPE - Oa, EB ** TY~ RMP~ Ct)DE 1. 66 .. 2 66 0 3 73 .12 4 66 5 66 6 73 7 65 9 65 F~' 11 6~ lP 66 15 66 l& 66 1 .,I.,.q. Ta~e V~rif.icatiom List.f. nq P A (; E ,, ~9 0 66 1 ** SET ~D ORDER ' ~ ~-''-' '--'',~,. .... .. E T F T 6294()8 r) o 00() O0 0 11 ! 1 4 6~ ,, ~ ....' '~ I..,. 0 ~ ~'4 2940 *: * D .a, T ~ * * .0 ~ P ~r, 13941 · 334 B iq I N o M L R o. 3 1, 3 g a .~' [3. !q [., R 0 o 818 ** END O? PA'fA ** FILE NA~.~Ei :. El)IT ,0!1 SERVICE~ = ~bTC VERSION D A 7.'~ : 94/0.3/31 ~.~'X. REC sIg~ : 1024 FII.,,F TYPE **** FI[,F FTLF NA['E : EDIT .012 S[~:.RV ICE : WLIC 'VERSIO~ : 001C01 b A I.'F = 94/03/31 ~aX R~C STZV : 1.074 [rTLF TYPE : LO L~ST FILE [3PE~.{ HOI,E REPFAT PASSES Curves and lo~ header data for each r)ass, tool st:rin~, and run in se[)arate files. .,IS TaDe Yerifl. catlon Listlno ~ch],umberqer .Alask'a Computi. no Center PAGE: 90 TOOL STPlNG NUMBER: DEPTH .I: ~!'C~E~!EN1: 0,5000 VENDOR TOOL Ct)DE STIRT DEPTH SI 1462~ . 0 ~'l'E 14674, !~ D T 1, 46 b 8 . 0 CaT 1465~,0 LOG HFADER DATA ~AT}i; LOGGED: SOFTWARE VERS! Of~i TI','~E CIRCULATION EMI)ED: TIME bOG.r, ER Oi,,l TD DP, I:LLER (FT): vD I,,,OG~ER (FT); ~OP !,..,OG INTEPV,~L (FTJ: nOTTO~.fi LOG IMTERVAL TOOL STRING (TOP TO BOTTO~,~) VENDOR TOOL CODE a '.~$ L:, T E L P ~' C~T S ~(]FE~OLE AND CASING DATA ['~PE~~ WOLE bi3 SIZE (l~): DRILLERS CASI~,~G !)EPTt~ LOG(iEP5 C~$!NG De.P']'~! (KT): n f.~P E~OI,~', ,~HE, VISCOSITY tS): FI..,L~TD LOSS (C3) 1,3926.0 1,3926.0 13926,0 13926.0 A'I.IXILLI ~ kY 'I'ELEMET~Y CARTRIDGE G~MMA R~Y C.hRT~IDGE G~M~A RAY DTPO~ SOMiC DIPOLE SOMIC DIPOL? $O~iif, DIPOLE 80~IC PHASOP PUASO~ INDUCTIOM ,~L}CI.,E~R 6FRVIC~: C~RTR. DENSITY SflNDE Cf)~PENSAI'ED ~!~UTRON 05-~iAR-94 6C0 490 ~500 05-~AR-94 00.30 06-~AR-94 14705,0 1.4682.5 13926.0 14674,0 A~E-AA TCC ~ SGC S.A SGD-T~A $?AC-AI 31. SM~R-A~ ]3 S~Ij-BA 33 S~DX-AA 33 ~iC ga DIS HS 421 ~5C M q07 r)RS C ?984 5. 13939.0 13026.0 14.5 65. O 9,4 4.2: ,chlumberger A,]..aska Computir:,~ Center RESISTIVITY ~IJD AT ~EASIJRED TE~PER~TURE ~4UD FII~T~ATL AT :qBD F'ILT[~ATE AT (8HT): ~l. JU CAKE AT ~:tJ~ CAKE AT 2 0 0.0 I, 020 0,394 0,660 O. 1..88 2,670 nENA~KS: RA~ FIELD D~TA FROM RI.IN 4 [.,O~ER REPEAT, DAT~ NAS ~,~OT BEFN DEPTH CORPECTED. $ l,..,'I5 FOR~,~.AT DATA. 73,0 200.0 52.0 200.0 45.0 PAGe: 91 WN &CIU SONFISH #3 APlh? 50-E83-20090 FL 1240' [';"",tL ~ 9~0' FWL SE'C,V TO~,~ 1, 1 ~'~ R ~ ~'~C 9W CoUN 5'~AT AI.,ASEA 1~ ~ T T U S A ~v l T t,' ~ E N p y P['A~ L ~ F K R ADD ~T 1. 32, E~ PI' 132. ~O PT 14705. TnL PT 14~82. 61,I PT 14658. Tt,l ~%' 26(.'~. OFT POLYb~ER SOLTEX DWD C/~3 14.5 t)WpW 9,4 Well Name lPI Serial Number Flel~ Location Section Township Range County State or Province Nation witness Name Service Order Number Permanent dat%lm Elevation of Permanent Datum l,o~ Measured From ADore Permanent Datum Elevation oI Kelly Sushi~q Elevation. of Derrick Floor Total Depth - Driller Total Depth - Logger Bottom boq Interval ToD [.o~ Interval Drilling F]ut~ TYOe~ Drill. in0 Fluid Density Or~lli.g Fl.~lid Ph Oriilinq F!.ui~ Viscosity ..,IS Tare Ver.t..fJ~cat!on Listi. n~ {cbl,..~.~erqer Alaska Co~pu~tnq Center 3 ~ -~tI~A~--~ 994 12;25 brtlli~o FlU. Id boss ResistiVity of i~iud aar~ple MUd SamPle TemPerature Resisti~itv of ~{uO Fl,ltrate ~Ud, Filtrate 8ample Temperatu Resistiulty of Mud Cake Sampl ~ud Cake Sample Temperature' Time Circulation Sto~ped TI~E LOGGER ON BOTTOM gottom Hole Temperature T~BLE TYPE : CURV D ~ P TDeDth C I'. D .IDpH CT!VD I C!L~ I, .., b IDOF I ~ 0 F ITeM 'p F; F L S L L (.~ T T u Ss2 bSHV SS!~V INDUCTT,'O~ DEEP PHA, SOP C[)~3D!tCTIVITY ~nasor Deep ~esistl¥itV [,,C,~IO ~'E][)IUM PHASOR CONDIICT'IVI Y' Pnasor Sedium Resistlvi,.tF COnductivity IL Dee~ Standard Processed Deep Indu. ctJ, on Standard Processea Resistivity Cond~ctivitv IL ~edium Standard Processed Nedltlm InduCtion Standard Processed Resistivity !n~ucti. on Dee~ Oua,li[~ Factor Induction ~ed uD~ Guo ty Factor Deed Induction Real Intermediate Conductivity Dee~ Induction Quad Tnt. erDle,~iat, e Conducttvit~ ~ed u~,~ Induct. ton Real IntermeOlate Conductiv tV ~edium In~.uction ~uad !ntermealate Conductivity SFL Resistl. Vf.t~ Hnaver. aqed Spont. a~eous Po entJal a. Pl-Correct ed Gamma Surface Tenslo~ ~ud Temperature ~U~ ~eslstivitv Uead Tension au]_K Density 9e l ta photoelectric Factor 9ualitv co..trol of lone spact, no for LvT 0ual. itv control on short s~acin~ I:or L~T Lo~q $~acinO Computed Count ~ate I,om~ Upper 1-2 ~indo~' Count Fate (I.,UI+LU?) I, onq Lo~r ~t~dow CoiJnt: ~ate l, lt~oloo v{Jndow Count ~ate Short $6aci~o 1 window Count. Rat e Snort, Spacin~ 2 winaow Count Rate LonQ St:acid9' Hiqb Voltage ~nort Spacln~ High Voltaoe S{~ort SpacinQ 1 Density ~I8. Tape verIflcatJ, on I.,istlno ;chlumberger AlasKa Computing Center 994 1. 2: 25 D E F C ~ [.,,, ] Cai~ ~e~' G~ IPl-Cotrected Gamma Ray TENS Surtace Tens ion ~TEu ~ud TemPerature MRES ~[.ID Resist,~.vlty HTE~,~ Head Tension ~PHI Compensated Neutron Poros,ity, SS .~:~atrix, calJ. & dead tl~e corr., RTN~ Raw Thermal, Neutron Ratio 'I'~']P~{ Thee. ma,1 ~eutron Porosity a I ~ Thermal. ~eutron Ratio C 1].,brate~ ~'~POR ~eutron Porosity irom an ~pl.,lcation Pro(~ram Rc~w RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS C~.~'rC Corrected ~,~ear Oetector Count ~at:e C~TC Corrected ~'ar Detector Coumt Rate G~ ~PI-Corrected Gamma Ray TE~Js Surface Tension ,~ES ~UD ~eslstl, vi, ty MTE~ ~tld Temperatt~re HTE~ Head Tension i)~4, P DELT.~-T CO~P~ES6IONAL HF MONOPOLE C0~PE~SATED fP&S) DT4P DEI.,T~-T C(',]~PRESSIONAI,, HF MON'OPOLE DTRP DELYA-T C{"]~PPESSIONAL HF ~O~OPOLE PLC~VER (P&8) OTRP D~]LTA-T CO~P~gSSIONAL HF MO~q[3POL~ RECeiVER (P&S) OT',I.'P D[;!,T~-T CO~PR~]SSIOI',*AI,, i~F P,/3NOPOLE TRANSMITTER (P&$) DTTP DELTA-T CO~PRES&I0~AL HF MONOPOI.,,E CN[~P COHERE~ICE CO~FRESSIONAL P&S ~ODE RECEIVER C~TV COHEPE~CE CO~PRESSIO~AL P&$ ~50DE TRAN$~ITTER D~4~ DEI.,T~-T 8HEAP LOWER OfPC)b~; F~ODE CG~'PE&SATED DTR1 DELTA-T SMEAR LOWER DIPOLE ~,00~ ~f;CEIV~R OwR! DE[,,TA-T SHEA~ LOWER DIPOLE ~(OOK RECEI~'ER CHR!. COHERL~:CF LOWEP DIvOI..,E ~ODE RECEIVER pR Polsson's Ratio RSH'C RATI~ SHE.~'R TO COHDR~SSIONAL DFLTA T Gm API-Corrected Gamma PAGE: 93 ** nAT~ FORUA? 8PFCIFTC~TIO~ P~,;Ct,]PD ** ** Sf;T TYPE - ~4EE ** TYPE R~PR CUD~ V'AL!1E 1 66 ~ 2 6~ 0 3 73 29~ ,I$ 'ra~e ver, if'.!.c~tfon l..,i, st~r~ :chlumberger Alas~.a Computino Centex' 3 .I-~AR-,1. 994 12:25 P~GE{ 94 ** SET TYPE - CMAN ** N~MF SER, V U~!IT SERVICE APl ID ORDER ~ bOG TYPE CLASS · 6. 8 O0 000 O0 CIDD D[..,R M~14~ 629408 O0 000 O0 IDPF DLR OP:i~ 629408 O0 000 O0 CIM~ DLP M~HO 629408 O0 0o0 O0 I~PH DbR O~IMM 629408 O0 000 OO CILD DLP M~{O 629408 O0 000 O0 I!,D DLR UH~ 629408 O0 000 O0 CTL~ D[,,R M~HO 629408 O0 OOG (lO iLM DLR OM~ 629408 O0 000 O0 IDGF DLR 629408 O0 000 00 iuOF DL~ 629408 O0 000 O0 iIRD DLR ~}~HO 629408 O0 OEO O0 ll×D DLR g~hf) 629408 O0 OOO O0 I'Ix~ nl.,P ~HC, 629408 O0 000 00 SFL!' DI.,R O)~a~ 629408 nO OaO O0 s~ DLR ~V 6294,08 OO oo0 Gm BG~ GaPI 62940B OO 000 O0 ~TE~ DL, R DEGF 620408 O0 000 ~E$ Dto~ OH~ ~20408 O0 000 O0 HTE~! DLR LB 629408 O0 000 O0 RMOB [.,bP G/C3 620408 ~0 0~0 nO D~am [.,l,P G/C3 629408 00 000 O0 CEF I,~P 629405 Ol.,8 LL~ 62~408 O$S I..,OR 629,%08 00 (~n0 oo [.,g LL~ CPS 629~o~ LU L.bR CPS ~29~O8 00 000 BI, LL~ C~$ ~2o408 nO OOu O0 LITU L[,~ CPS 620~08 O0 OflO O0 SS1 I_,L~ CPS ~2q4o~ O0 000 O0 8S2 LI.~ CP,% 629400 O0 000 00 NU 12 12 12 1.2 12 12 12 1.2 12 12 12 12 12 12 1.2 12 12 !2 12 12 12 12 12 12 1.2 12 12 12 12 12 12 12 PI FIbE N!l~b NUM~ SIZE REPR PROCESS ~q B $ g ~ P E [, E a C 0 D E { H E X ) '''l''' ......... 1 ,4'''''''''''''''''''''''68 OO O0 000 1 1 4 b8 000000000o 1 ~ 4 b~ 0000000000 1 I 4 68 0000000000 1, 1 4 6~ OOOO000000 1. I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 i ~ 68 0000000000 i 1. 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 ~ 68 ooO0000000 1 1 4 68 o000000000 1 l, 4 08 o00oo00000 1 ~ ~ 68 oo00000000 1 1 4 68 0o00000o00 I I 4 68 o000o00000 1 1 4 68 oo000o0000 1. 1 ~ 68 0000000000 1 1 4 68 O0ooooo000 1 I q 68 00o0000000 I I 4 68 0000000000 1 i 4 6~ 0000000000 1 1. 4 68 000o000o00 1 1 4 08 000oo00000 1 t 4 68 00000000o0 1 1 4 68 0000000O0O l 1 4 b8 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1. 4 ~ 00000000o0 1 1 4 68 0oo0000000 Tape Vert, fl. cat],on Listina ;chlumberger AlasKa Comput'ih~ Center P A G E a SERV Li C AP][ API PI API F ? D 0 R D E R :~ .... L ~ V 2 ,, ,t 0 00 O 00 0 $ $'2. v LLR V 62940B O0 000 O0 0 $1R{~ [,L~. G/C3 62940~ 00 ()00 00 0 LSRN L.LR G/C3 629408 O0 000 O0 0 L!IR~ [..,I.,,R G/C3 629408 00 000 o0 0 C~LI LLR IN 629408 O0 000 00 0 GR I.,LR GAPI 629408 O0 000 00 0 I'~NS LLR LB 629408 00 000 00 0 ~ITE~ LLR [.)EGF 620408 00 000 00 0 ~PES LLR O'!,~.l~q 629408 O0 000 O0 i. tTEN LLR LP, 629408 00 000 00 0 aPH! CL~ pl.~ 629408 O0 OOO 00 0 RT g~ CL~ 629408 00 000 00 0 TNP~ CLR pl! 629408 00 000 O0 o TNR~ CLX' 620408 O0 000 00. 0 NPOP CBR pll 629408 O0 000 00 0 RCNT CLR CPS 629408 00 000 O0 0 RCFm CL~ CPS 629408 O0 000 O0 0 C~TC CLP CPS 620408 00 000 00 0 CFTC CLR CD6 629408 O0 000 O(j 0 G~ CLR GA P I'. 629408 00 000 O0 0 TENS CLR l,,, ¢, 629408 00 000 00 aRES CLP O}.id~ 62940S 00 000 O0 n Y~TE~' CLR DEGF 629408 00 000 00 0 hT~J CLR D~ 629408 00 000 00 0 DT4P P~E 62~40~ 00 000 00 0 DT4P ITP 629408 00 000 00 DTRD PTE 629408 00 000 O0 0 t~,> ~ RD lTD 620406 O0 000 00 DTTP ~TC 629408 00 000 O0 0 DTTP ITP 629i08 00 00O 00 0 CHRP [)SI 629408 00 000 ~0 0 C[~'rv DST 629~o6 nO 000 O0 0 DT~4!. PTE US/~ &2~408 O0 OoO nO 0 BT,~. !TP bS/P 620409 O0 000 i.;,~a 1 PT~ 629408 O0 000 00 0 DTRJ ITP 620408 O0 000 O0 0 CUR1 mst 6294n8 OO 000 O0 0 P~ ~SI &'2o408 0 RSH¢ DST 62q408 O0 000 O0 0 GR ~SI G~PT ~29408 00 000 00 0 [,]1~ 8 S.A~4P EL, E[~ CODE: (:HE;() ~'''~ ..... ''i ...... 4:'''''''''''''''''''''''bO 0000'" 0000 12 1, i 4 68, 0000000000 1. 2 1 i 4 08 00000000 () 0 12 I I 4 68 0000000000 12 1 t 4. o8 0000000000 12 1 1 4 68 0000000000 12 1 1. 4 oB 0000000000 J, 2 1 1 4 68 0000000000 12 1 1 4 68 000n000000 1,2 I. ), 4 68 00000000O0 12 I 1 4 68 0000000000 12 :1 1 4 68 0000000000 !,.2 1 1 4 68 0000000000 12 1 :~ 4 68 0000000000 12 1 1 4 68 0000000000 12 1 1 ~ 68 (}000000000 12 I I 4 6~ 0000000000 12 1, 1 4 fi8 0000000000 !,2 :! I 4 68 0000000000 12 1, 1 4 68 0000000000 12 1 1 4 ~8 0000000000 !,2 1 1 ~ t>8 0000000000 1,2 1 ' I .4 08 0000000000 12 1 I 4 6~ 00000o000o 12 I I 4 68 0000000000 12 1. 1 4 68 0000000000 1,2 I I 4 6~ On00000000 12 1. I 4 68 oooc)o00000 1.2 1. 1 4: 6~ 0000000000 12 1 i 4 68 OOO0000000 12 1. i ~ t~8 oo0o0o0000 12 I 1 4 68 0000000000 12 I t 4 68 0o00000000 12 1. 1 4 6~ 0noo0o0000 12 I i 4 6~ 0o00oo000o 12 1 i 4 68 oOOOoooooo 12 1 .t 4 68 0o0o000000 _12 i I 4 88 0oo00o0000 12 1 I 4 e, 8 0o0o000000 1.2 1 1 4 68 O000000OO0 12 1 1 q 68 0000000000 189.633 IDPi~.DLR 5.273 CIMP.DLR 91.652 .I1,0. DL~ 5.9.18 CILM.DLR O.OOO TNOF.DLR O.O00 IYRD.Oi,,P 147,57;~ I i X,'.'~. DLR 3.940 5F[,U. D'bP 56.151 TF:~.rS. Di, R 3250.0u0 iv,'r E~. Pi,P 148.944 151,112 166,230 6,382 195,2!6 ;,IS Tape Verlfi. cation Listi, nq >chlt,~mherqer Al, asK8 C. ompu. tina Center MPES. D I.., .~ 0. 269 PE?.f,,,b~ 5.998 gLS. LLR L~. Li.., ~ 302.500 Lb. LLR SS2.LLR 24:6.750 bSHV'hLR LSRFf. LLR 2. 492 ¢~PH~'CL:~ 25.219 RT~R.CLR .RDOD.CLR 22.485 RCNT.CLR CFTC.CL~ 2603. 851 GR,CLR ~qTE~,CLR 197.825 gTEN,CLR DTRP.PTE -999.250 DTRP.ITP CNRD.DSI -999.250 CHTP.DSI OTR1 .PTE -9q9,250 DT~I.ITP RSiqC.DS! -999.250 GR. DS DFpT. 14500.000 i~PN. Pb~ 0.801, CILD.D[,R !L~.DLR 6.6~8 ! DOF. DI,,.,R IIXD.DhR 7.790 6~, OLR '26,125 GR, DLR ~PES.DLR 0.263 HTEN.DLR PEF. LLR 5.1 i 3 OLS. i.,LR LII. LLR 2 ]O. 375 LL. $ 5 ~. I, i,.,, ~ 280.750 b LSR[{. L[.,~ 2. 660 TPNS. I.,L~ 62~5.000 i~P~!.CL, R 26.599 RTNR.CI, R NPOP CL~ 26.601 RCNT.CLR C ~' ~ C ~ C i'., R 1848.509 6 R. C. 1.., R i)TRt>. PTE 71.8~3 DTPp. ITP CMRD.DST 0.929 CHTP.DS! DTk], .PI'E 134.5,!7 DTRI.ITP R.~HC. PSI 1 · 857 6R.DSI DEP~'. 14380.000 CIDP.D!,,R I,,~PH. I')LR -999.25(~ IL,". DLP -999.25(; IO0~'. OI,R 1 TXE~. DLR -909. 250 I SD. :3~,R -~g~. 250 GR. iqPE~.DbP -909.250 PEv. I,:L~ -999. 250 Ml_,S. LI,R LU. LLR -999. 250 LL. Li.,R SS?. I, LP -999. 250 f_,S ~V'. LLR LSRH.LL~ -9~9.250 TE~S. I,I.,, P -909. 250 ~4'f E N. LLR b',PHT .CLR -999.250 PTNR.CI,R NPOP.CLR -9~9.250 P C N'~. Cl., F', CFTC. CLP -999. 250 Ca. CEa b~'rE'~ . CLP -999.250 HT g~. o~aP.PTF -9q9.250 DTPP.ITP C~RP.nSI -999.250 CHTP.DSI [)~a~ .~'tE -9~9.250 DTPl. I~P RSHC. DS f -999. 250 GR. C',$I 31-~AR-! 994 12:25 '8.,1,64 RHOB.bI, R '0.1.42 QSS. L, LR 1. 32.250 51 T a, L I.,, ~ 1,642.000 ~,477 197.825 ~,~ ,a E 5. i,., I.,, R 2.23! Tt~PH.CLR 5604.~18 RCF"I'. CLR 77.6[48 TENS.,CL~ -29.547 ~T4F.PTE -999.250 OTTP.PTE -999.250 DT~ 1..PTE -999.250 Ctt~? 1 .DSi '999.250 14:0.566 1DPF!. Df,.,R 143.222 I I,,,,D. DI, R 0,000 141.092 !I, Xb~. DIoR 64. !. 81. T 1:.; N 5.0 I., R 95~ .628 ~HO6. bLR -0.025 gSS.LLR 113.750 LITt'i. LLR 1641.000 SSH'V. L[,R 2.662 CALl. ht.,R 197.038 ~ES.bbR 2.518 TNP~. C[,,R 46~3.~86 RCFT'CLR 69. 625 'ff~:~5. CLR 759.500 DT4P.PTE '7 !. ~ 23 O'r T P. P T E 0.000 DTN1 .PTE !34,5.47 CHPl,,.DS I -o99,250 -999. 250 ILD. DLR -o9~. 25O -999.250 TE;NS. 9LR -999.~50 -099. 250 QS5. LLR -999.2b0 I, ITd. bf.,R -999.250 S5~V. LI.,R -~99.~50 C~Li.LL~ -q99.2~0 TNPH.CI,R -o99.~50 ~CFI.CLR -990.250 TE~S.CLR 'q99.250 DT4P. PT.E '990.250 DTTP.PTE -~9~.250 nTvl ,PTE -999.250 CHPl,DSI 2.413 , . 26.~ ~Ig 167 7.0 0 0 5.824 GR.LB~ 0 ' 268 H T E N. L ia R 22 485 2452:451 C N+I'C Ci~R 3755. 000 -999.~50 DT4P -999. 250 r>T'rP.ITP . 999.~50 -999.~50 PP.DSI 7.11,4 6 982 0: 000 3,325 65'15. 000 6 .{ 0 2.003 O. 45.1.56 ,. 7 2 3 0.255 27.225 1793.314: 6285.000 72.470 -999.250 .1,34.547 0.855 -999.250 -999.250 -999.250 -999.250 -999.~50 -q99,250 -99q.~50 -999.250 -999.250 -999.~50 -99~.~50 -999.~50 -999,250 -999.250 -999.250 -990.250 -999.~50 -999.?50 CINP..DLR CIL~.~R IIRD. L~ ~TE~. DRHO.LL, R 81. R H. I,, L, a GR. 'r~R~.CLR C~'IC.CL¢ ~RES.CLP DT4P.ITP DTTP.ITP PAGE: 96 -0.077 283.500 236.625 2.582 77.688 -,29.547 2,067 5360:.834 0,:268 '999"250 '999.250 '999.2'50 '999,250 147'040 149.526 123.250 194,225 '0.014 229-.000 229.500 2.717 69,625 759.500 '2,330 4383.14! 0.255 72.470 74.413 134.547 0.296 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ,IS Tape ~erift,.catlon ,Listlnq :chlumberger AlasKa ComputJ, ng Center 3!-~R-~994 12:25 PAGE: 97 FIL~ ~It~E : EOIT .012 $~VICE : FL!C VER$IO~ : 00lC01 D~'I,E : FI[.,E TYPE : LO b~$T FILE : **** FILE [4EADER **** SERVICE', : VLIC V ~R S !:.,n~q : O0~COi D,~T~ : 04103131 FILE FT[,,~ NU,~.~BER 13 Rata~ O[,>Er,~ ~O[..,E REPEAT PASSES Curves a.d l,.oq ineaeer data for each ~ass, tool str!a~, and ru~ t~ separate flies. D~F'r~ INCPE~ENT: O,500U FTL;' vEt,;OnR T/I(.]T, CODE ~TART DEP'rH r)SI 12104,0 12~25.0 12~14.0 12~14.0 r~TF C ~',~ T KCF'.FWA~E VERSIn. N: TI~E C!RCtJLAT i f]~:i · l.) LOGGEP(FT): ~tnP LOG INTERVAL nOTT~ LnG I~'.['~:RVAI, STOP OEP?~i $900,0 8900,0 ~900,0 13-dAN-9A CP 3S.2 2230 l~-dh~-g4 1200 13-dAN-94 121.5o.n 12133,0 ~OC!O.O 12104.0 lis 'fa. De Yerificati, on lchlumberoer Alasi~a Comput. fn~ Cent:er 31,,~aAR-1994 i2:~5 PAGE: 98 I.,OGG!I:tG SPEED (FPHR): VENDOR TOOD CODE TOOL T~PE AN'S A[~X! [,Li ARY TCC TF, L~,~: ETR Y CARTR~OGE GP (;A'~A RAY CARTRTOG.E GR G A~ ~A RAY DS.I O I POl,.,~ SONIC i)$I 'iDIPOh~ DSI D I POi:,,E SONIC OSi DIPOLE SONIC DYE PHA,~OR INDUCTION i') T f'; PgASOR !NDUCTIO~ bDT ~C!,~;,~R 5ERVI. Cg C.a, RTR, L~T b K, ~',! S l T I" 50,~ DE C~4 T C O ~ P E ~,~ S A .[ E L ,;'~ E t) W R n ~ LOGGERS CASTNG DiSPT~ fFT): BORgffOLg CONDITIONS :~ [,! D TYPE: P, UD VISCOSI~rY (S) FI, dID h~SS (C3} :~%aXT~l!'~ R~C[)RD~]D TE~PFRAT!)R~7 (DKGF): RESISTiViTY (OFIM)'~'i) AT TE~4PE",RATLiPE (DECF'): ~UD AT 60'.,['TO~,~ H(31..,E TEMPERATURE. tF~H'I'J~ ~UD WILTRATg AT ~UD FI~,T~ATE AT '~(.,ID CAKE AT &~UD CAKE AT TOOL TYP~2 (F.,PTT~ER~,~AI, OR THER~Af,): H A 'I7 R ! X: F~ATPlX D~MSTTY: TOOL PE~.APKS: RA;,e FIEI,D D~-TA FRPF~ KIlN 2 bPPKk i)bTA ~AS ~OT BEEN DEPTH C~RECTK[), I_,!~S FOR~,~AT DATA TOOh N l.l ~,q BEI~ TCC g 1057 SGC SA 557 SGD-TAA. SPAC-AA S ~,~ O R -A A DIC 41~ ~,)SC 773 DRS C 1908 CNTff 340 !.2.250 89O9.O 8900.0 POI, Y~ER 55.0 7.2 8.0 163.0 2. O4O 51.. C) 0,694 163.0 1.20.0 51.0 O. 439 1 t~3 0 2.180 51:0 ,IS Taoe veri. flcation Listino ,chlumber:g'er alaska Computin.q Center 31.-MAR-~ 994 PAGe: gg TABLE TYPE ~ CONS T U N T V A [~ Lt O E F I C~ :L, .M C,. ~i?ANY )reDan lame FN NO[~TH COOK INLET WN ~C.IU SONF,T. SH #3 APlN 50-883-20090 SECT R~N~ 9W STAT ALASKA :~ a T ! b S A ~ !T~.J SON 6 294 08 APO ?T 132, E~ ~T 132, g D F ~' T 1 31 '.FBD ~T 14715, TDL FT 14~2, .bLI ~T 1.4658, TLI ~'T 2602, DF'T PObYaE~ SOLTEX Orrt) (;/C3 14 5 DFV S 65~ DFL P3 4 R m $ 0 H ~ ~ 1 0 M S T ~ fi; G F 7 .~. 2 R.~Cg OHu~ 2.67 '.rCs 15:00 0 5 -~AP-q,4 TLA~ 00:30 o6-~.(AR-94 Fi, eld ~ame APl Serial Nu[~ber Field bocation Section Township Range County State or Province ~:;atl, on ~itness Name Service Order Number Permanent datum Elevation of Permanent Datum LoQ ~easured From ElevatI. on O~ KellI Elevatio~ of pert ¢~ F1 or Tota! [)e~th -Orill. er Total Depth - LoDger Bottom [.,o~ ~nterva~ Top boo Interval Drl..llinq FlUid Type Drilling Fl~i~ Density Drilling Flaia ~h .ri, lli~q Flul~ Viscosity Drillin Fluid boss Resistl.~tty oi Mud:Sam~le ,~ud Sample Temperature Resistivity o~ MUd Filtrate ~ud. F1].trate Sample Temperatu Resistivity ol Mud CaKe Sampl ~ud Cake Sample Temperature Time Circulation Sto~ped TIME LOGGgR ON BOTTO~ Bottom Hole TemDerature T~EI, E; TYP~ : CUPV DEFT DFF'm CT'DP IDpH CTMP I~DH Ir,D neoth TNDUCTIgN OEFP PHhSOP CDrd[.jItCTJVI. T¥ Phaser Deep CeslstIvi. tv INDUCTTON MEDIUh P~IAS()~ CO~J[)~c'rlViT~] Pnasor ~'~edlu~ Pesistivi. tV Cond,~ctivity IL Deed &tandard Processed t~ee~ Tnduction Standard Processed Resistivity Verification Listino chlumb, ert3er AlasKa Computing Center ~AG~ 100 Conductivity 1!.,~ ~edi, u!:'i~ Standard Processed ~.~ediu¢ I'~duction Standard Processed Reslst. ivi.,ty lnductJ, on Calibrated Freou. encv Induction Deep Ouolity Factor rn,~uct..ioD ~edium ~uallt~ ~"sctor ~eeD Induction Real. Int~r'meOlate Conductivity Deed I'nOuction O,]ad Intermediate Coaducti. v.itY ~.~ediu:m induction Real ?ntermeOiate CondUctivitY ?~edium Induction Ouad Intermeoi. ate Conductivity SFL ~esist:ivltg Unaveraqed Spontaneous Potential ~PT-Corrected (;aroma Ray Surface Tension ~ud Temperatt.lr'e ~UD ResistiVity Head Tension Bulk Density De ! ta Photoelectric Factor Ouali. tv control of lon~ spacinq for Oual. itv control, on short spacing' for bDT Long 5pa. cinq ComPuted Cot~nt ea.t'.e long t,]~er i-2 ~lndow Count Rate Long Bower ~t. ndow Count Pate ~,it. nolog ~indo~ Count. Rate Si"~ort SpacinQ I window Count Rate Snort Spaci. n~ 2 Window Count Rate I.,o~g 5~acinO High Voltage Short: Spacl. no Hlqh Voltaoe Short Spacino ~ Density LOnq SDacJ. nq Bulk Density [,O~q UDDer Bulk Oenst tV Caliper [Pt-Corrected Camma Surtace u~d Temperature '~'¢n ~es sti. v]tv Head Tens ion Compensated ~!eutro~ Porosity, SS ~,atri~, cal. i & deaO time corr, Ra~, Thermal. Neutrom Ratio Thermal Neutron Porosity Thermal ~,{eutron Ratio Calibrated ~eurron Porosity from aD Application Proorap~ RAW ~JE,~R CNI' RAW FAR Char COUhT~ Corrected Near Detector Count Fate Corrected Far Detector' Count Rate AP'I-Correcte~ Gamma Ray Surface Tension ~'~UD Resistivity D'~ LI .J Temperature Head Ter~sion ~IS 'ran.,e Ver!f.tcat.f. on Listir'~O blumberoer .A]~sKe Computinc~ Center D~R.P DELT,~-T C(]~P~ESSION'A[~ HF ~tONOPOLE DT'!'P DELT.A-T CO¢4P~ESSIONAL NF ~.{~NOPOI.,,E TR&NS~'I"TER DTTP DELT.~-T CO~PRESSIOMAI., ~F ~(3fN'OPOLE T~ihI~SMITTER C}4T~ COf4ERENCE CO~PRESSIONAL P&$ MODE O?.~q2 DEI.,T~,-T MI.:iEAR UPPER DIPOLE NODE COMPENSATED f)T~.{? DELT&-T SHEAR UPPER DIPOLE MODE CO~PENSATED OTR? DELT&.-T SHEAR UPPER DIPOi,E MODE RECEIVER DTRP DELT,~-T SHEAW UPPER DIPO[,,E ~ODE RECEIVER C~R? COME~ENCE UPPER DIPfJLE MODE PP Po!ssor~'s Patio GP ~,P!-Corrected Gamma Pay ** DATA FOR'I~AT SPECIFICATION ~E(~O~l) ** ** SET TYPE - b4E~ ** TYPE REPR CODE; ~ALU5 I 6 6 0 ~ 66 0 3 73 296 4 66 5 66 6 73 7 8 68 0,5 9 6 5 FT 1]. 66 3 13 66 0 !5 66 k6 6~ 0 ~6 ** ,q.E~r T'fr'E - Cf4h~i *~ m ~_ i i i ill Ii mm m mmml mm~lmmmmmmm~mI~/mimmm m ~m m imm ~mmm tmmm_ ID PRDEP ~ b~G TYPE CLASS M(;D NU~[.~ SAMP ELE~ CODE (HE:X) OF'PT FT 62~408 O0 000 O0 0 13 I. 1 4 68 O0000OO00n CTI?P OUR ~'~'t~O 629408 O0 OOO O0 ~ 13 1 i 4 69 0000000000 IDP!~ DUR OHMs1 620408 O0 OOO O0 0 13 ) 1 4 o~ 0000000000 C[~IP D(.lP ~',;~rt(1 62Q4h8 O0 0('.0 O0 O 13 1 1 4 6~ O00000000O i"P~ OL,;i OH,~v &2~)408 O0 000 nO 0 ~3 i i 4 6~ 0000000000 Tape verlfl, catlon I,istino ;cbl, umberger l%lasKa Computinq Center 3 I,,,~,~,AP- 1, 9~ 4 l?:25 PA~E: 1 O2 .,..SER li ! ........ APl . A.P. ORDER ~ bOG TYPE CLfiSS 6 408 00 00 00 .... bP OH 6 9408 O0 000 O0 Clb~ DUP ~.~o 62~408 00 000 00 IFaV OUr HZ 629408 O0 000 O0 IDO~ DO? 620408 O0 000 O0 imO~' DUR 62~408 O0 000 O0 .iIBO DUR ~M.~.~O 629408 00 000 O0 ilxO DOP ~4~HO 62940~ nO 000 O0 .IIR~ DOR ;~!Mi:tD 629408 00 000 O0 ilX.~'~ DLi~ aMHO 629408 00 (.)0() 00 8~1,~,1..t DU~ ' O[i~vtM 629408 O0 OOO O0 SD r)UR . j~V 62q408 O0 000 00 GR Dt~R GAPI 629408 O0 000 O0 I.~.S r)!,.'~ LB 62 408 O0 000 O0 ~TE~ DI~R DEiGF 629408 O0 000 O0 ~PE;S D.l. lR O}.I~M 629408 O0 000 00 t~., ~.,, ': D 0 ~ b'8 629408 00 000 0 RM(.)B [.,UR G/C3 629408 O0 000 O0 DPHG LLIR G/C] 629408 O0 (.)OO O0 p E F I., U P 62 q 4 o 8 00 000 00 '" T ~ [.,~ ..,,,: o b 0 P 62 ~ 408 00 000 O 0 OSS I,[,j R 629408 O0 000 0() DS I.~UR CPS 629408 O0 000 O0 1,.~ t.., U ~ CPS 62o408 O0 00(; O0 b !., !., U P C P 5 629408 n 0 000 00 h'r T*~ l.,t~ r CPS 62~408 nO 000 O0 ~S1, [.,UR CP~ 620408 00 000 00 SS2 T,UR CPS 629408 00 0()0 O0 LSHV I.., 0 R 9 620408 O0 000 O0 5S~V !.., [.} ~ V 62940~ O0 OOO O0 ~I. RM I,!.jR G/C3 629408 ~0 000 O0 l.,g~b' LUR G/C3 62~408 O0 000 O0 L)~R~ [,;J~ G/C3 ~2o408 O0 C)O0 oo CALT l, t)' P ikt 620408 O0 000 O0 1':~ ~ S t,tjp L,P: ~29408 oO 000 O0 i~TF:m I'.,t]~ DEG,' 629408 O0 0o0 O0 Y,P~,K t:UP OH'4~ 62¢408 O0 0o0 O0 HTEt: I_,UP b~ 62~408 O0 000 O0 xPH~ CUR Pit' 620408 O0 000 O0 RTNP CLIP 629408 OD OOo O0 'imP~ CUR PI) 620408 Oo 00~ O0 T[:~ ~, C,.i~ 629408 O0 (')nO oo NPl]~ C ii' ¢' P[_I 62~<,08 O0 O00 nO R C t,~ ~'CoR Ct'8 62~40~ O0 000 O0 RCF'~ Ct,~ Ct~S 62o408 O0 000 CO C~TC CUP CPS 620408 O0 000 O0 ,3~ COP G~F'I 62o40E o0 ()OO O0 'r~S CdP hg 629408 O0 000 O0 ~ 0 D ~ O 'M g 8 A ~ P E b E iq C 0 D E (,', ~.i E X ) 0 .. 'l. t 4 6 O0 0000000 0 13 I 1 4 68 0000000000 I 3 1.3 1.3 13 13 1.3 13 1.3 !3 1.3 13 13 13 13 1.3 1.3 13 13 1.3 13 1..3 13 13 13 13 !3 13 13 13 13 13 1_3 13 13 13 1.3 13 13 13 !.3 13 13 13 13 1.3 13 13 .1.3 68 68 68 68 68 68 68 68 68 68 68 6~ 68 68 68 68 6~ 68 68 68 68 68 68 68 68 6~ o8 6~ 6~. 6~ 0000000000 O0000OO000 O0000000OO 0000000000 O0000OO000 0000000000 0000000000 O00nO00000 0o0000o000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000OO0000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOO000000 O0000000UO UO00000000 0000000000 O0000000OO O000000OO0 O000000000 O000000000 OOOO000000 0000000000 O000000000 0000000000 OOt)O000000 OOO0000000 0000000000 OOO0000000 0000000000 OOOO000000 0000000000 OOO0000000 0000000000 O0000oO000 0o000o0000 ono00oO000 ooooooooon 6oOOO0000n 0000()00000 0000000090 :IS Ta~e Verlf.i. cat!.on Li, st,l,,nc 31-gAR-194,4, 12.:,25 ,chluK~berqer AlasKa Computi, nQ Center I0 ORD.E~ ~ bOG TYPE Cb.~.S8 ~TE~' C'UR DEGF' 629408 O0 OOO O0 0 ~3 1 i 4 6~ 0000000000 hmg~ CUP I,,,B 629408 00 000 O0 0 13 1 1 4 6~ 0000000000 DT4P PTE 62~a08 00 000 00 0 13 l, 1 4 6~ 0000000000 PT4~ ITP 629408 O0 000 00 0 1,3 1 I 4. 68 000O000000 DTRv rTE 62940~ O0 000 O0 0 13 1 1. 4 6~ 0000000000 [)9'R~ ,ITP 629408 0(,) 000 00 0 13 I 1 4 b8 0000000000 DTTP PT~7 62040~ O0 0()0 00 0 13 I ! 4 6B 0000000000 DTTP !TP 629408 00 0o0 0() 0 13 1 I 4 68 0000O00O00 C~Rm DSI 629408 00 000 OO 0 13 1, 1 4 b8 0000000000 CH'.!' P D. Sl' 62940~ 00 000 00 0 13 1 1 4 68 0000000000 OTM2 PTE 629408 00 000 00 0 13 1 1 4 68 0000000O00 i.:)Ta? I. TP 620408 O0 000 0() 0 13 i 1 /i ba 0000000000 DTR2 PTE ~20t08 O0 000 00 0 !3 I I 4 6~ 000fi()00000 DTR9 'ITP 620408 00 000 00 0 ~.3 I i 4 68 0000000000 gl{R2 DSI ~2~408 O0 000 O0 0 1.3 1 I 4 e8 0000000000 P~ DS! 629408 00 ()00 00 0 1. 3 1 I 4 68 0000O00000 103 * * D .t~ T l * * DEPT. 91o5o50o CIDP.DUR -2PL.0(10 I t,)P i:.i. [)il R 14.992 CIMP.DUR I~p~t. DUR 11..016 CII 0,DUR -25fi.250 I,[,O. DUR 1950.000 1. h'. P O R 1950.000 I F ~ .E. D i~'R 20.000 I D ~} ~:. D t! a 3.000 I ~ ~: F. D t) R 'I!RD.DLtR -257,750 !IXD.DUR -4eo.75n T !RM.. DU.R -969.500 SVb!t.DUP 14,4,1% SP. DI'~R -56.~19 CR.DUR 95.432 TENS.OUR ~,'iTE~ ~(.I~ 1.49 7~6 ~tRES OIiR 0 627 HTEN DUR 705 5UO RH()B.I.,UR DP.~O. LU~ 0.037 PEF.LUR 20.3b~ Q! S.LItR 0.091 O88. LU'R aS,t,O~: 2~0.00o hij. bl.~ 21a.375 I,!~..BUR 110.875 hi I H. I..,UR SS~ .L(J~ 56.6~5 SS2.LI~R 96.375 [..,SH'V. LUR 1268.000 SSHV.LUR SIR. ti ~,~i~ 4.863 I..S~H LUR 2 63~ l,U~h i.,UR 2 672 CALl LUR m m o - · m - m - ~q~E]S.CU~ f,.6?7 ~TEa.CIIR 14.9.7~ ~t~ E~",i. CUR 705.500 DT4P. p'rE OT4e.!Tp -909.2BO DTPP.PTE -999.250 DTPP.iTP -999.250 OTTP.PTE OTTP. l'rp -999.250 citRp. [)$,[ -99~.25o CHTP. {)SI -99~.~5o 0TA2.PTE DT~.TTP -909.250 DTR'2. P~E -q99.2b0 DTR2.1TP -999.250 CHR2.DSI FR. DS ~ -999.2~(,:, GR. OSi -q99.250 OWPT. oU00.O00 C I PP. L)I.! i4 -256.000 IDPd. OUR 10.680 CIN:P.DUP .l. UPg. BU~ 7.969 C II,0. [',UR -256.2b0 ] I,D.DUR 1950.000 CILg.DUP T b~". Dt..~ ~ 1.'~U.O00 IFPE.OtlR 20.OuO ID~F.DUR 0.000 IUGF.DUR ITRm. BOR -257.750 IIXO.D~E -46n.7b0 IIR/i. DUR -869.500 I I X ~. E,'O'R SFLI~,DU~ 7.047 SP. I'3~ -'15.313 G~.OUR o3.906 7ENS.DUR c,~iTE~a. PUP 149.7a8 ~1RFS.DU~ 0.627 7iTF,~. OUR ~123.000 R~OB.LUR !'ID ~. [,U P 0,039 PFF. Lt.)'R 3.270 OLS. [,~UR 0.091 OSS.I,UR Lg.LUR 22o.00Q [.,(]. LIiR 21~.3'75 L!.,. bUR 110.875 f,I'l'H. 1,0R '870,500 '850,500 2.000 '802,500 3455.000 2,55O '0.156 23.4B4 !315,000 12.250 0,627 52.037 301.862 3455.000 -999.250 -999.250 -999.250 -999,250 -870.500 -856,500 0.000 -802,500 4935,000 2.493 -0,156 23.484 ,IS ~ave. Vet.if.icat!.on bist. f. nn ~chJ. umberger Alaska Computing Center (;~. ~,U~ 63.906 TEN~.LUR H~EN. LOR 1. 123.000 UP~I. CU TN~{a.COP 4.299 NPOR.CUR ~..) ~ 4 P, I T V 78,096 D T ~ P. P T E DTT'O.!Tp 74.179 CHRP.DSI DTM~.ITD 294,448 DTR2-PTE PP. D8 .I 0. ~3 1 GR. DSI DE:PT. 8'704.500 i'IRD.Db'~ -257.750 IIXO.bUR $~L~. D{JP 0.439 SP' {4TE;'~'. DUR 149,7~8 DPHO. LUR -1. 082 PEF.bUR b S. I, 0 R 2 2 ("'. 0 0 0 l., .. . oo2. LI~R G~. I.,U~ ~7.875 TENS. L[,IR t, tTEM. LO'9 109~.000 'M PHI.. CUF, C'P;'}'C,CU~ 1439.239 CFT .CUR M R~]S. CtJ~ 0. 027 D~/4~, l'l'P -909.250 DTRP.PTE OTTD, T~{'O -999.250 }7;,T~ ~. ! ~'P -999.250 O'i[J~ 2, PTE PP. DS I -909. 250 GR. [)S 31-!',4A~-1994 1.2:25 -256.000 IDP!.'J. OUR -256.250 ILO.OUR 20.000 II,)OF, OUR -460.750 '! ,.I R iq. OUR - 194:. 250 GR. DUR 0. 627 HTE6i, OUR 2 1,. ,406 ('~ I.,S, 21 ~..375 L b. b ~.t R 96.375 [,,, 5 }4 V. t,,,{l R 2.635 I, L{ R ~. b U R 47 O 0.0 O 0 ~ T ~ Y~. L, U R 53,913 RTNR.CUR 52 629 RC~T ~,.Jd 344. 465 GR. CUR -999.250 DTPP. ITP -u90.250 CHTP.DSI -99~.250 DTR2.ITP -999.250 1268. 2 .,,.672 149.788 4.~6~ 1432.45~ 63.906 ~!23'000 82.01,3 0. g03 243,,436 1950. 000 1950.000 O.OOO -809.500 27.975 1098.000 0.09!. tl, 0 f475 1268i000 ,'2.., 672 1.49.788 4 1, 432:451 27.8'15 1098.000 -999.250 -999.250 -999.~50 CI~P.DUR ,I,~QF,DUR IIXS.OOR TENS.OUR RHOB.LUR CALl .LUR ~PES. LUR RCFT.COR TE~S CUF~ DTaP ~ PTE DTTP.PTE DTg2 .PTE CHR2. 104 1315.000 0.627 301..862 4935.000 78,096 74,179 224,448 0,426 -870.500 -856.~00 0 00 -802 500 4760 000 1,558 -0.156 23.484 1315.000 12,0:00 0.627 52.037 301.862 4760.000 -999.250 -999.250 -999.250 -999.250 tis T.aDe Ver~,fi. catJ~on Listl~.nQ ichlurnber(jer AlasKa Computin~ Center 994 PAGE: 105 **** FILE I~iE Al)ER **** FIh~ N.A{~E : EDIT ,0.!.4 g~Rvl;eg : VERSION : O0~CO1 j.'j) A T ? : 94103/31 F~IjE T~PE : LO ~ [.! E A l) E R Curves and log .header data for each pass, tool OPlP~H INCPE~6~,'~TI 0.5000 ..... T ' P S" P D ....... DS]: ........... ''''' i];;X~; .... '~;'~''''',. 2 ,0 BTS~ 13914,0 ! 2 ~. 2~, 0 I..DT 13920, n 1.21. 26,0 C~'qT 13920.0 !. 2~.26.0 'Ul.,* ! 3880,0 I 2m 40.0 # LOG T T T T H[<ADER O A'~'.A ATP.; LOGCED: ,,.}VT WAR E VERSION I~'E; C T RCOI,AT I Oi\i, I~,'E bOGC, IEP Cltj bfPTTO.~:l: L) DRIL.LP.~ (~-~i"): 0 bOC;figP (FI): OP LOG OTTfi~ LOG INT~iRVAL (FT): OCGTN(; SP'~ED (FPH~): b STRTi'~G (.['._ TO nOTTO,q) A~S DL Y MEGS, A~S AUXIL[~I ARY YEAS. TCC I'~LE~T~ Y C~ ~TR IDGI,.; ~P GA~q~A 'Rg, Y C~RTRIDGE GR GA ~ ~.~ A RAY DSi DIPOLE S~UIC PSi DIPOLE SONIC OSI DIPOLE gO~IC D~E PHASOP I,'~DUC'I.'TO~ st:r'.Ino, an~ run 1. 9-FEB-94 6CO 490 1.700 :[ 8-FEB-94 0230 lq-FEB-94 13941°0 13928.0 13914.0 in separate ,IS ?ape V'erifi. cat..ion I, ist.i, nq' ,chlumberger Alaska Computino Cent,.er 31,-~AR-! 994 12:75 [) T E L 'D T I., D T $ P ~' a S (] R I, !:4 D U C TI 0 i\iUCLEhR SERVICE; [)ENSiTY SONDE ~OREHOLE AD,'~D CA$'IN~ DATA t')RILbERS CASING DEPTH CPT): ,'r', [":~P E It O [, E CONDITIONS !ql.ID TYPE: ~411D DENSITY (LB/G): ~l.lt,) pH: FLUID bOSS (C3) RESTSTIrVITY (Oi't~a) AT T~aP~:RATURa (DEGF): 6.q'UD F'iI.,,TRATE AT ~UD CAKE A,T (NT): ~OO CAKE AT ~EUTRO'S T O r~ !,,,, v,,~TRIX DENSTTY: i,~OLE COP, R~;CTiON (IN): oE:~ARKS: R5~I FIELD DaT~ PRO~,'~ RII~i 3 UPPER REPEAT, Oh~'A ;4AS NOT REF~N DEPTFt CftRPf]C'i'ED, LT~ FOR~,~AT DATA D],$ H£,, 421 NSC E 773 gAS C 1908 9.625 !.2137,0 1,21,26.0 POLY~¢ER $OLTEX 13,5 ~5.0 4.5 1,84.0 1.060 63 0 0,388 1,84;0 0,686 48.0 0,197 1,84.0 1,560 51.0 PAGE: 106 CN PNII,L!PS P~,.',~Rr~]I..,t<U~ C[),~PANY ComDaD. V Name F',~ mDRTH COOK li~LE,'r Field Name ~.1 ~,,CI~1 SUNFTS~t ~3 Well Name apl~ 50-8t:;3-~0090 APl Serial Number F'I, 12~q' ~.~[, ~ 9BO' Fw[., Field Location SFC~ t~ Sect ion T9 w ~.~ 1 l~ Townsni p R a ;",~ C 9t,,~ R ang'e CObN KE,~ ~ I County 15 !faDe Ver,,~,f:.f. catJ. on List:t, nq ;chl~.~mberger AlasKa Computing Ce~t:,er P A G g: 1 0 7 State o:r Province ~iation Witness ~,!ame Service Order Number Permanent datum Elevat].on of, Permanent Datum Log ~teasured From Above Permanent Datum glevat]..o~ of, Kel]..Y Busbi~q Elevation o~ Derrick Floor Total, Depth - Driller Total. Depth -Loqger ~ottom bo~.interval ToP I,,oo In~;erva! Dr'tll, i~q Flu,id TyDe Drilling Fl. ulo Ph Orllligg Flu1.0 boss ~esistlPi. tY o~ Mud Sample ~ud S~ple Temperature, Resistivity o~ Mud Filtrate ~ud Filtrate Sample Temperat9 Resistivl. t~ pt ~Ud Cake Sam~A ~'ud Cake Sample Temperature Time Circulation Sto~ped TIME bOGGER ON BOTTO~ (.Sw~ D~F 200, Bottom Hole Temperature TAbLe] ~¥PF : COPV Depth I(~,nUeT~O~.~ PEEP P~IA,qOP, CO~.~DIICTZVIT¥ Phasor Deed Resistivity ~NDUC'?!Oi'4 ~E]DIIi~ P~IARtl{~ COM()~ICTIViTY Pnasor ~,ed]um Resistivity Conductivity IL Deep Standard Processed Deeo Induction Standard Process.o Resistivity Conductivity IL ~edlum Standard Processed ~edi,]m induction Standard Processea ~esistivitY Induction Deep Gualitv Factor IBduction ~aedi~lm Oua].ity Factor Deed Induction Real Intermediate COndUctivitY Deed InO~lctio~ ~tlad Interr,%ed~ate Cond~ictlv~.t.V ~edi,]q'~ Induction Real Intermediate Conduct~vitV ~edi~],% Induction Qtlad l~termedJ, ate CoBdtlct!.v~ty SFI, ~esistivItv l~naveraQeO Spontaneous Potential ~PT-Correct. e~ Gamma Pay ,iS Ta~e Veri. fica'Ci, on Listi. no .chi, umber(jet Alaska Computind Center' 1.2125 I'~ $ Surface Tenslo~ ~,~T E~~' ~ud '~emp~rature MPES MUn ~,esist !,vitv DTgP [)~!.,T~-T C[)~'PR~;SS![]P,IA!, gF MONOPOb~', [)T4P D~]!,TA-T COb!PaESSIONA!,, ~F D ... R,P OELT.A-T CO~,IP~ESS 1'~4~ .,. D · T ~ g E !, 'i~ ,{ - T C 0 ~'~ P ~ E S S I 0 ~,I'A L ~ F ~ O OTa! DEI, TA-T ShRA. R LOW'ER DIPOLE aODE CO~PE~SATEO DTR1 OELT~-T S~JEAR LOWER DIPOLE C~-t'R1. COI.4ERENCE I.,OW~jR DIPOLE MO,D~ P~ Poisson's ~at i.o RSHC RATIf] Si. lEAP T0 CoaPRF';SSION!I, DELTA (;;~ Apl-Corrected ~amma RaV PA~E: ** r~AFA Ff'.tR~Am SP~CIFICgTION ~ECi3~t) ** IS Tape Ver'if,.~cation l~ist!nq chlumbercler A],ask. a ComputJ..n...h C~MP DUR ~.HO 62940~ CTbD i)[)~ ~tYH~ 629(~08 ILD DU~ 0},; M t~ 629409 I [,~i~ DLiR OH ~'~ ~ 629408 iDQ~ DUR 629408 I~GF Drip 62940B IIX~ DOn f~hO 629,408 $~'I..,U DUR L]HN~ 629~08 aP O'{j~ ?~V 629408 GP D!.,} R GhPI 629408 T ~ N S D i,)R L, P, 6204 o 8 ~'.'~'TE;~~ DUR DEGW 629408 t~TEM DUR [,~. 629408 DT4P PTE Dw4P ITP 6294~B DTRP gTE f1294n8 DTRP %TP ~402 '[~TT P PT~ 629408 0TTP I'JTP CHRP nSl 62~40~ CHTp DST 629408 [)TA~! P'rE USIF 629408 DT~,,1 T'!:'P US/~ 629408 [,)~R! P::i?F 6294nb DTR ~ TTP ~29408 CHR 1 DST 629408 P~ DST 629409 RSHC DST 62~408 mmmmmmm.mimmlmlmmmimI.im.m Center 12:25 , A P 1 A P I F IL t.,, k; ~ B N U S 1. Z E R i~;'P R p,p, 0 ¢ ~.: S CLASS MOD NUi',!B SA'MP ELEM CODE (HEX) 00 o 1.~ 1 1 4 68 0000000000 00 0 14 1 1 4 68 0000000000 O0 0 1,4 1 1, 4 68 0000000000 O0 0 1.4 1. 1 4 68 0000000000 O0 0 14 I I 4 6~ 0000000000 00 0 1.4 i 1 4 68 0000000000 O0 0 14 I I 4 68 0000000000 00 0 !.4 1 1 4 68 0000000000 O0 0 14 1 I 4 68 0000000000 O0 o !,4 I 1 4 68 0000000o00 O0 0 14 1 1 4 68 0000000000 00 0 !.4 1. 1 4 68 0000000000 O0 0 !,4 1 I 4 68 0000000000 00 0 14 1 I 4 68 0000000000 O0 0 14 1 1 4 68 0000000000 O0 0 14 1 1 4 68 0000000000 O0 O 1,4 i 1 4: 08 O000000000 O0 0 14 1 1. 4 68 00O0000000 O0 0 14 1. I 4 68 O000000000 O0 0 14 I 1 4 68 O000000OO0 00 0 !.4 1 1 4 68 00O0000000 O0 0 14 1 :1 4 6~ 0000000000 00 0 1,4 i 1 4 68 0000000000 O0 0 14 1, 1 4 68 0.000000000 00 0 14 1. 1 4 08 0000000000 oo 0 1.4 1 1. 4 68 O000000000 O0 0 14 1 i 4 68 0000000000 nO 0 14 1 1 4 68 0000000000 00 0 14 I i 4 68 0000000000 O0 0 14 1 1. 4 68 0000000000 nO n 14 1 1 4 ~8 0000000o00 O0 o 14 1. 1. 4 6~ 00o0000000 oo 0 14 1 I 4 69 0000000000 00 0 14 I 1 4 6~ 0000000000 O0 0 14 1 I 4 68 0000000000 O0 0 14 1. i 4 66 0000000000 OO 0 14 I. I 4 O~ 0000000000 O0 0 14 1. 1 4 68 0000000000 109 L)FPT. 12401. OOO CI DP. DIIK IuP~. PdP ! 5. 278 C,ILD. DtIR T b ~'~ . r:tiP ~. 4.914 I [)OF. [JUii 1TX~. DI.J~ -~. 0~8 TIRM. DUR 3D. ~Up 464.813 GR. Oi.~R F,~ P E: ,~, P U R 0,26 ~ H T E N. 1') I) ~. L,,'Ta~ PTE 909.2c ' . .. . . - . .... L, 9~RP.imP 55.326 IDPH,DUR 1G,075 CIMP,DUR 57.30! II.,D.OUR 17,452 CIL~.DUR 0.00O IMOF.OUR 0,000 IIRO.DUR 63.624 !IXM.DLIR -32,525 5FLU.DuR 2!.820 TENS,OUR 3455,000 MTE;,~.nUP 602.993 DT4P,PT£ -999,250 DT4P,ITP -99q,250 DTTP,PTE -c99,250 OT'I:P.ITP 65,452 67,049 51,667 50,046 172,'728 -999,250 -999,250 IS Ta~e Veri. f. lcatlon I.,istlno chlumberger Alaska Computino Center C ~"~ R m, D S ! - 999.250 C f:i T P, D $ I I)TR~ .PTK -5}99,2~0 DT.P 1, ITP DFPT. 12058..500 CIDP.DUR I,~,PH. DUR -999.250 CILD.DUR Ib~ DOR -999 2 .... o 'IDOF DUR i!XO' '' ' , D U 'P - 999, :250 I I R M., D U R BP. [')llP - ~() ~" 250 GR. DI.)'R ........ ~ ' " ~ ~' . U DTRo. PTF. 69.52,3 DTPP.ITP C. ~'~ R P. D 51 0.95 ~ C H T P. D DTR1 .DTE 1t2.269 DTR1 .ITP RSE~C. PSI -999. 250 31-MAR-1994 12:25 -999.250 DT~I,PTE -999,250 CI. iRI,DSI -999. -999,250 IDPH.DUI~ -999.2b0 IbD'DU'R -999.250 TMQF'OUR -ggo.~O IIX~,.OUR -999.250 TEN$.DUR -q99.2~0 DT4F.PTE; 69.523 DTTP.PTE -~99.250 DT~I.P:TE 132.269 CHR1,DSI -q99,250 -~99,250 ~999 250 999:250 -999.250 -~99.250 -999 250 -999:250 -999.250 132.070 0.940 DTMI.ITP PR.DSI P AGE: 110 ' 999, ::~ 5 0 -999.2,50 -999'.~250 -999.250 -999.250 :999,250 999:':.~50 -999,~50 132.070 -999,250 S~RVIrE : FLTC V'~RS IO~?q : O0~.COl U,aTK : 94103131. MaX R~C 8IZK ~ }0~,4 F)Lr TYPE La, St Fib~ FTLF D, iU~MR 15 RA~ OPE~~ HOI.,E REPKAT PASSFS Curves add lnq hea~er data for O Fl P · H. I ~,~ C P F, ~,~ k N 'I: 0.5 0 0 0 FIB~ VE~:DrlR TnOT, COt)F: START nSI 14622.0 each pass, tool strlnq, STOP OEPTh Jig26.0 r u n in separate files. IS Taoe Verification Listinq chlumberger AlasKa ComPut. inq Center 31-~AR-!994 12:75 PAGE: 111 !.,DT J, 4659.0 i 3926.0 C~T 1465~. 0 13926.0 LOG HEADER DATA ~ATE LOGGED: SOFT ~IAR ~: VERSiOi'4 T I ~ g C I '~ C U L a T I T.I~E LOGGER ON BOTTO~: TO DRILLER (FT] TD bOGGER (FT) · OP LOG !BTERVAh Bt3TTOM L:OG INTERVAL (FT)~ !..,[)GG I N G SPEED T fl 0 !..~ STRING 'qENDOR TOO[, CODE TOOL TYPE A~qS Y ~gAS, A~S AU ! bl,,i AF, Y TCC G'R G,A~}~ RAY CART.RI~)GE GR GAt~MA RAY DSi [) I PO/,[~ SONIC OMI OIPOLE SONIC OSI OIPf)bE SONIC OSI DIPOLE SO~iC DTE PMASOR INDUCTIOM i)TE P~{ASOR LDT NUCI,EAR SERVICE CARTE, [,~T DENSITY SONDE hop i)RII,I.,~RS CASING D~PT~{ LOGGF,~S CASING Df, PT~t (FT): 05-NAR,,'94, 6C0 490 1500 002~0 06-~AR-94 14705.0. 14682,5 13926.0 14674°0 T[~O.[~ NI.!~BEP AME-AA TCC B SGC S A SGD-TAA SPAC-AA 31. $~DR-A:~ S~DX~AA 33 DIC E3 ,4~ DIS US 421 NSC g 007 C~'~IT ~lA 340 .1..3. 30.0 13926.0 q::O TYPE: POLYMER S9[,TEX ~!.I~) DENSITY (LB/G): 1,4.5 ~v:o0 VISCOSI*Y (S) ~'[~[JT[} L~ (C3): 4.2 ~%~XI,~U,q RFC[lADED TE~IPERATU~{F kFSTSTIVITY (OH~M) AT 'rE~.PfCRATORg (DE~F): '~dn h:f ~o'rTo~ ~[{[,E 'I'g~PERAT~J~[' (nH'T): ().39~ ~00.0 uUD ~[I.,!'~ATE hT (ST): 0,660 52.0 udD F~LTRATE AT (3NT3: 0.1~8 200.0 '-'UD CAWS:.', AW (MT): 2.670 45.0 I'S ~aoe Ver!,~i, cation Listi..nc, chlumberDer Al. asKo Computi. nq Center ~ATRI×: M~TRI'.X DENS~'T¥: PE~AP S: R~'~,~ FTEL[:, D.tT,~ FRO~::i RUt~ 4 [,~PPEa REPEAT, I)lYa MAS NOT BEE~ DEPTH COERECTEO, ~ '. L, IS FOR~IAT ~,A. a PAGE: 112 T~6!,,,E TYPF', : C0~5 Al 0 DEF! CN PHII,[,IFS PETkObEU~ COMPANY FN NORTH COOK ~1 N'CI 1} SONFI'SH AP ',1M' 50-a83-20090 SFCT S T A T A L h S K h SDN 62940~ PDAT iv, l,,~ E~p F'I~ 0. APO FT 132 , EK6 FT 132, E~' FT 131. 'fPp ~T 14705, :rnI. ~T 14. b~2. Bl,I ~T 1405~ . TI, I PT 260~. DFT PObYNER $OI.~TEX 1.) F [", C/C3 I. 4.5 Dr~ S b5. nFL F3 4.2 R u F S 9 fl ~ ,'~ 0 6 6 o 0 (:) 0 1 ~.~ C Sm D ~.:G F 4S. TCS 15:00 TLAP, 00130 96-MAP-94 ompanv Name ~leld ~ame Well Name API Serial Number Field l.,ocation Section Township Range County' State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum Lo~ ~easured From Above Permanent Datum Elevation of Kelly ~usbing Elevat!.on o~ OerricK Floor Total DePth - Driller Total, De~th - I.,o~Der Bottom Log Interval TOp [.,oo Interval Dri. llina Fluid ~ype Drilling Fluia Density Priilin9 Fluia Ph Drilling Fluid Viscosity Drilling Flula boss 'Resistivity of Mud Sample Mud Sample Temperature Resistivity o~ MuO Filtrate S ~ud Filtrate ~am~le Temperatu Resistivity of Mud Ca~e Sampl ~ud Cake Sample Temperature Time Circulation 5topped TI~,; LOGGER ON BOTTO~ lis TaPe Verification [.,istin9 chlumberDer Alaska Comptltl. n<~ C. enter 31 -~AR-1994 12:25 PAG~ ~ 1 ! 3 VA! ~i' I)EF I' TUb ! DgGY 200, Bottom Hole Temperature ,, DEPT IDPH Clap CILD ILD~ Ci' b,' G~ PE~ L 'T T W S~HV G~ ! ~?,~ n t! C T I 0 ~ ~. g ~ P P H A S 0 ~ C 0 ~ !) ~' C T I V I T Y Phasor Oeeo Reslstt, vitv !NDUCTIOM ME~It.;b~ PHA,$~,)~ COMDUCTIVIT~ ~aas~r ~",~edl, u~ ~esistivj. ty Conductivity IL Deep f~t, andard processed ,. Proces Oeep InduCtion StandarO se~ Resistivity conductivity lb Mediu~ Standard Processed .e~ium Ir~duCt, ion Standard Processed ~esist. i, vlty !nduetio~ Deep OualitV Factor lnduct!,on ~edl'u~','~ Oualit~ Factor Deep I, ndt~ct, tot~ Real Int, ermeaiate Conductivlt'.y Dee~, i~d~ct, i, on (~uad Intermediate ~ed'iua I~d~lcti, on kea!, Tnt. erm~diate Conducti, vitv ~ediu~'~ I~du. ctio~ Ouad lntermediat, e Co~,ducti, vitv SFI ~'esist, ivitv ItnaveraqeO Spontaneous Potential .API-Corrected Gamma RaV Suriace Tension ~ud Te~perature ~UD Pesistivity wend Tension 2ul~ Der:,si. ty Delta Pnotoel. ectric Factor OualItV control of lonq spec.ln~ for OualftY control, on short. SOaCiDg tar t. DT LOng SPocin~ Comouted Cout~t pate l,ono Upper 1-2 Wi. ndow Count ~ate l.,om9 Lower ~].Ddow Count Rate Li. tholoq ~!I~dow Count ~ate S~lort Spacir,~ ~ windo'~ Count Snort spaci, o~ 9 winnow Count Rate l.on~ smacl~9 High Snort Spool. aa Hj.~n Voltage Snort spacl, m~ 1 Density Lonc~ S~aci. n~ ~ulk ~ems].tV Lomq Upper ~lk Denst. tv ~a!imer APT-Corrected Gamma .%~rtace Tension ~'~ud Te~erature ~Uo ~esist!v~t? Ilead Tensiot~ Comoe~sated ~,eutron Porosity, S5 Yatrix, call ~ dead ti. me corr, ;chl. u~berqer .~]aska Computtn.~ Cent;er R°rNP Raw Thermal,Ne r n ~ iOut o at TMPH Thermal,. Neutron Porosj, ty TNR~ :~herma] K!etttron Ratio Cal~hr. ated :N~O~ Neutron Porosity .[rom an APplicatiOD P'roqra~ RCNT RAW ~,~i:L~R CNT COONTS RCFT RAW FAR CNT COUNTS C~tTC Corrected Near Detector Count Pate CFTC Correcte~ ~sr Detector Cou~t Rate G~ APl-Corrected Gamma ~.aV TEhiS Surf. ace Tension ~PES ~UD Resistivity ,'~ T ~'; ~'~ ~ud Temperature HTES~ Head TensioD DT4P DELT~-T C(']~PRESS I[]NAL DTRP DELTA-T CO'~.PR ESS i[).a AL DTTD DELTA-T CO~PRES51 [.i:~iA!., DTTD DELTA.-T CO~PRE:SblONA!,., HF CHRD C[.)HERENCE CO~PRESSIONAL D&S ~aODE'. R.~CEIVER C!-!TD CO}!ERENCF CO~PRESSTONAL D&S ~(:)DE TRANSHITTER o'r~,,~l DEI,,I'a-T SHEAR I.,OwEiR DIPOLE MObF, CG~PENSATED OT~'~t DgI.,TA-W SHEAR LOW~,;R DIPOLE ~'~O[)~:: CO~{PENSATED [)q'R~ DELTA-T SM. EAR LOWER DIPOI,.,[: ~ODE RECEIVER [,)TR~ D~LT~-T SHEAR [,OWED DIPOLE ~,,ODE RECEIVER CHRI COH}:':RE~,ICE I,OW~ DIP(TiLE MODE DEC~;.IVER P~: Poisson's Patio RSHC RATIn SdFAR TO COI~DRESSIONAL i.)E[,TA T Gp APl-Corrected Gamma PAGE: 114 ** PA?A FOR.Am SPECIFICATION DECORD ** :1 66 O 2 66 3 73 296 ~ 66 5 66 6 73 7 65 b 6a 0,5 9 65 13 66 q ,IS Tape Ver.lf, J. cat.~on ListIno ,cblumberqer Alaska ComPuttnq Center' CIDD Crb~.~ IL¥~ iT~,D OUR IIR'~ iTX~ DtJP 5Vb~; Dt.i~ SP DbR TENS ~.4 T E u ~PES DUR ~H0n l., i.j P OLS 'b 1) T, U R LF. L T T t~ L O P S S 2 L LSHV SSHV ChGT S ~ I C g A P i ~ P I ORDER ~ LOG TYPE FT 629408 00 000 ~q ~* 1',~ 0 62O,,%08 O0 000 OHM~ 629408 00 000 ~ ,~'.H O 629408 00 000 [.) H M ~' 629408 00 000 aSHO 629408 O0 000 M~IH 0 62~40~ O0 000 [) H i'~ ~ 629408 00 000 629408 O0 000 fi29~08 0O 000 M'~ }:{ 0 629408 00 000 )1'~'~ B ~ 629408 00 000 ,k~ '~,~ ~,i 0 629~08 o0 000 0 H b~. ~' 629¢08 O0 MV 62°..408 O0 OOv GhPI 629408 O0 000 LB 629408 O0 000 O~:(;r 620408 O0 G/C3 629408 O0 G/C3 62~/I08 O0 000 62 ~ 408 c) 0 t) 00 629408 O0 000 62940~ 00 000 Ct~S ~2940g 00 000 CPS 62040~ O0 000 CP~ 62o408 O0 OOO C~S 629408 O0 CPS 629,%08 00 000 g 6204c~8 O0 000 V 62o408 O0 00~) G/C:~ 620~08 nO G/C3 629,q08 O0 OC)O G/C3 62~40g O0 000 ir,,) 62gqn~ O0 000 G~,PI r42o408 O0 LB 6294(%8 !.)EGF 62°.408 O0 OoO 00 0 00 0 00 0 00 0 00 0 00 0 O0 0 00 0 O0 0 00 0 00 0 00 0 00 0 O0 0 O0 0 00 0 00 ('} O0 0 00 n 0 O 0 O0 0 O0 O0 0 0 O 0 ~0 O0 0 0() f) 00 0 00 0 c) o 0 O0 C,O O0 Ou 0 O0 OD Nt,I~B 8A. MP E.UEa CODE 15 1 1 4 be 0000000000 15 I i 4 68 O000000000 15 1 l, ~ 68 0000000000 !,5 I 1. ~ 68 OOOO000000 15 1 I 4 b8 0000000000 15 1 1 4 08 0000000000 15 1 1 4 68 0000000000 !5 i 1 ~ 68 0000000000 1,5 ! i 4 68 0000000000 15 1., I 4 6~ O00000000O 15 1 1 4 68 0000000000 15 I t 4 68 0000000000 15 1 1 4 68 0000000000 15 l. I 4 6~ 0000000000 1.5 }, i 4 08 0000000000 !5 1 I 4 b~ 0000000000 15 I I 4 6~ 0000000000 15 1 I 4 08 0000000000 15 I i 4 68 0000000000 15 1 1 4 68 0000000000 15 1, 1 ~ b~ 0000000000 15 1 I 4 68 0000000000 15 i, i q 68 0000000000 15 1 1 4 b9 0000000000 15 I 1 4 68 u000000000 15 1. 1 4 68 0000000000 15 1 I 4 08 O0000OO000 15 1. 1 4 6~ 0000000000 15 1 1 4 bR 0000000000 15 1 1 4 oR 0000000000 15 I 1 4 b~ 0000000000 1.5 I 1 4 6~ OOO0000000 1.5 I :t 4 o~ 0000000000 lb 1 1 4 OR 0000000000 15 I 1 4 6R 0000000000 1.5 1 1 4 08 O00000000o !5 1, 1 4 b8 0000000000 lb i ~ 4 O@ 0000000000 15 1 1 4 68 0000000000 15 1 1 4 6~ 0000000000 15 1 i 4 09 0000000000 15 1 1 4 68 GOO0000000 'rave veri. flcation Listi.,no ;chl, t)rrbero~r ~.lasKa. Computino Cer~ter 31.-~AR-1994 12:~5 PAGE: 116 LOR LB 629408 O0 O0 C t.~ ~ p !1 629408 00 00 C~..} R R29408 O0 C U ~ p !~ 629.408 00 00 CL,)~ 629408 O0 0oo COR pi) 620408 O0 0o0 CU~ CPS 629408 oo 000 COR CP& 629408 O0 OOO C U ~ C P 5 62 .) 408 00 0 o 0 COR CPS 629408 O0 ()00 CUR GAPI 629408 C 'U ~ L, B 620408 C~.i~ L)~ ~',t M 620408 O0 000 CL)R [)EG~ 629408 O0 000 CbR LB 629408 O0 GO0 PT~ 629408 O0 000 ITP 629408 O0 000 PTK 629408 O0 000 I '.i3 P 629408 00 000 PTE 62q,08 O0 000 IYP 629408 O0 DSI 629408 O0 0o0 DSI 629408 O0 000 PT~: !,tStP 629408 OO O00 TI'P I.;S/P 620408 O0 000 l T P 629,4 0 8 0 t) o o 0 05! 620408 nO oo0 DSI ~20408 O0 000 DSI GAPI 62q408 00 .... A P 1 A [,' T F I I,,~ E ,13 LJ h~ :~ S 1 Z i::; R [,.,; P R. P R O E S PE Cb <' K .... o 0 o o ! 5 1 i ,,.%. 6 ~ 00 (.) 0000000 0 O0 0 15 1 I 4 6~ 0000000000 0 00 0 ] 5 1. i 4 68 0000000000 0 O0 0 15 I I 4 68 O00000000o 0 O0 o 1. 5 1 I 4 ~8 000o000000 O0 0 ~,5 1 1 4 68 0000000000 O0 0 1, 5 1 I 4 68 0000000000 O0 0 ,,1, 5 1 1 4 68 0000000000 O0 o 1.5 I i 4 68 0000000000 O0 0 1.5 i I 4 68 0000000000 O0 0 15 ]. 1 4 6@ 0000000000 O0 0 15 1 I 4 68 0000000000 oo 0 1,5 1 i 4 68 O000000000 O0 0 15 1 I 4 68 0000000000 O0 0 1.5 I 1 4 6a o000000000 O0 0 15 I t 4 68 0000000000 O0 0 15 1, I 4 6q 0000000000 O0 0 !,5 1 1 4 09 00000o0o00 O0 0 15 1 1 4 68 0000000000 O0 o 15 I 1 ~* 68 0000000000 O0 0 ! 5 1 1 4 ~8 000o000000 O0 o J 5 1 I 4 68 0000000000 O0 0 1 5 1 1 4 68 0000000000 00 0 ! 5 i I 4 bS 0000000000 O0 0 15 I 1 4 6R 0000000000 O0 0 1 5 1 I 4 68 0o00000000 oO o 15 i ~ 4 o8 0000000000 0o n I 5 1. 1 4 08 0000000000 oo o 1. 5 I 1 4 68 O00OO00000 OO 0 15 1 1 4 68 0o00000000 O0 o 1.5 1 1 4 6R 000o000000 1425(!.00u 5.693 5.019 !2.591 0.000 C). 259 -909 . 250 -999.2,50 -9a9.250 -909.250 -9°'9. 250 -999. 250 -9~9.25(.3 -9q9.250 CIPP.DI.tR C I [, £; IOOF T I q ,q H T E: N kURd ~'FEt4. LI:R ~T~a.ct:~ n C t,; T ! bo. RSO TDPH.DUR 5.529 CIMP.DUP 183.320 ILS.OUR 5.455 0.000 I~{OF. L ,!R o. OOO iTRD.DUR ].{~7.595 IIXq. DUR 4. 324 8FLU.DU~ - o - . . · .... · , .~ ' · 4~:~.564 Pt. lnE5. L,t. IR -999.P5~ DPHO.I,U~ -099.250 OSS.LIIR -990.250 i.,S.I,U~ -999.9b0 !.,ITH. LUa -~9Q.~50 -099.250 SSHV. ~'(la -qgg. 250 51RH. LUR -999.250 CALl .LtIR -999.250 -999.~b0 ~kES.LUR -~99.P50 -a99.2~0 ~NPH.CtJR -999.250 TNRA.CUR -09°.250 TL:t'~G. Ct. IR -099.250 M~ES.CU~ 175.667 177.956 159,373 5.921 188.225 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 ,IS Tape VerifJcatJ,.o, l:,ist!nq ;chlumberger AlasKa Com,,r,~tltlnO Cer:ter MTE~.C[JP -999.250 Dw~P. p'<r~: -999.250 DTRP. CHRP.[)~ [ -999.250 CHTP.[>SI DT'R~ .PTE -909.250 RSHC, DS! -909. 250 GR. .DB~pT. 13829.000 CIDP.DUR i "~ P,. D U P - 9 q 9.250 C I L D. D u R !hu.Ol)¢ -9¢9.250 IOOF .DUR ITXD.DOR -999.250 IIR,~.i)UN SP. D[IP -909. 250 dR. OUR ~4uES. rCUP -999.250 HTEi~,. DllR PEr. LUR -999. 250 (.~ !~S. l~[,~' ~ L~). LtJR -999. 250 LL. bUR ,~S?. LOP -999.250 LSR}{. L[tR -999.250 LUR~!.LUR TE~4S.I:UR -999.250 ~DdI.CUP -999.250 [;:DOP. Ctj P -9~9,250 RCNT.CIIR C~TC. Ct~P -9q9. 250 GR. CUR LT~¢. p:r~: -999. 250 OTRP. ITP C:"~:¢.¢St -909.250 CH'rP.DSl L, TR 1 . OT~' -9q9. 250 hTR 1. aSS~. DS I -909. 250 GR. DS! 3:~-I,,iAR-~,994 12:25 12. ,4, 04 14. I 94 0.000 '? ~.,; 0 F ' il) U R 12,713 l iX~. DiIR 9 5 8.4 7 4 P H 0 ~. h U R 0.050 520,000 [,, ITFt. BUR 1634'o0o SS}iV.bUR 1~9.837 1.953.054 RCFT.CIIR 4I ,406 99S.500 9T,4P.PTE 1:,1,0.R96 0.000 :DY~I .PTE !95.53! -999.~50 -999.~50 -099.~50 -999.250 80.621, 70.,451 0.0O0 -7.225 6430.000 1'612 0.~01 179.750 1677.000 7.754 0.26 0 60.26,3 402.868 6320.000 11,0.333 -999.250 194.594 0,797 -q99.~bO IDP{{.OUR -999.~50 -999.250 !LO,DUR -999.250 -999.~b0 IMOF.DUR -99o.250 -999.~50 IIX~!.DUR =999.~50 -~99,950 TENS.DUR -999.25~ -999.~50 PHOB.LUR -999.250 -999.~50 OS8.LIIR -990.250 -999.~50 LITH.LUR -999.250 -99~.2b0 SSHW.LitR -999o~50 -999.250 CALI.LUR -999.250 -99q.~0 ~RES.bUR -999.~50 -999.~$0 TNPh. CUR -999.~50 -999.250 PCFT.CUR -999.~50 -999.250 TENS.CUR -999.~50 -990.250 DTd, P.PmE -999.~50 -099.250 DTTP.PTE -999.250 -~99.~b0 DTMI.PTE -g99.250 ~41.50B CH~I.OSI 0.000 -n99.~50 DT4D.ITP DTTP.ITP DTgl.ITP PR.DSI C!~P.DUR CILM.DOR ,IIR, D,DD¢ SFLU.DtiR MTEM.DUR DRHO~I,,UR LS.LUR SSl.hU~ $ 1 RH . LOR ii'rE ~, LUR CNTC.CU~ ~PES.CUR DT4P . ITP DTTP. I TP DT~ 1.1 TP P~.DSI C!~P.DUR C!L~.DUR i!RD.DOR SFhU.DUR MTE;~.DDR DRHO.LUR LS.I, OR $$1.L~ $1RH.LUR GR.I.,bR HTE~.t, UR C~'TC.CUR ~KES.CU~ DT4P.ITP DTI'P.I~P DTkl.I~P P~.DS! PAGE: 117 -999.250 -999.25O -999.250 -999.250 12,409 13 349 1,3 09.1 39 579 187,787 '0.197 990,500 222,250 2.236 41.~06 99B. O0 4.~90 1904.036 0.260 11,0.333 108.644 194.594 0.263 '999,250 '999,250 '999 250 '999:250 '999,250 '999,250 '999,250 '999.250 '999.250 '999.250 '999.250 '999'250 '999'.250 '999.250 '999.250 '999,250 141.503 -999.250 I$ Ta~e v'er~f]cat~,,o~ List]nc~ cblu~berc~er A],.ask. a Comptlti. ng CenLer 31-,g'!AP- ] 994 12:25 P A(;:E: 11. 8 **** REEL I.:) A T ~ : ~ 4 / 0 3 t 3 1. OPICI~ : Fb!C REEL ~,~.A.~,~E : 04120 pREV :!'{][~,~, PEEL, : C~I~[5~:I' : PHILLIPS PETPL..II~E;I!~ Cf],~ NCIU 8UNWISH ~3, AP1 50-883-20090
