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Home My WebLink About198-141PLUGG!~-= & LO~ATiON CLE~A_~CE REPORT Sta~a cf Alaska .~A~ 0iL & GA~ C~NS~TION C~HHISSION '.:=a~...-----_--~ ..... - T: : =. iDT >'TO. ~_e well -'=~, and-cerumen: o: utu=~inq, well head Ox sua:us,, and. !oca=iun clearance - :rcvi~e loc. clear. Co~e · o PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 14, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-125 (98-141 / 300-066) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the P&A operations on 1D-125. If you have any questions regarding this matter, please contact me at 265-6120 or Brian Noel at 265- 6979. Sincerely, G. C. A]vord Drilling Engineering Supervisor PA1 Drilling GCA/skad STATE OF ALASKA ~- ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil F~ Gas [--1 Suspended I~1 Abandoned ['~ Service F1 2. Name of Operator .7. Permit Number Phillips Alaska, Inc. 98-141 /300-066 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22904-00 ~~ -~: - ~-'~i[ 9. Unit or Lease Name 4. Location of weft at surface 286' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM ; ~--~i Kuparuk River Unit At Top Producing Interval~)'-'~-~ ! 10. Well Number 1612' FNL, 1833' FWL, Sec. 23, T11N, R10E, UM ~.~~ 1D-125 At Total Depth~'~[' ' 11. Field and Pool 1741' FNL, 1636' FWL, Sec. 23, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 41 feetI ADL 25650 ALK 468 West Sak Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 6, 1998 August 9, 1998 April 3, 2000 (P&A'd) I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 5795' MD/4201'TVD 5685' MD/4097'TVD YES FI No []I N/A feetMD 1960' (approx) 22. Type Electric or Other Logs Run N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 272 sx AS II 5.5"x 15.5# L-80 Surface 5009' 8.5" 593 bbls AS III & 94 bbls Class G 3.5" 9.3# L-80 Surface 5779' 8.5" (included above) set bridge plug @ 4708' in 5.5" and set cement retainer @ 4955' in 3.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" cut and pull 4936' N/A * Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Squeezed 10 bbls cement below retainer ~_7. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test , Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE S ID E Submit in duplicate 29. NAME Top of West Sak Sand West Sak Base GEOLOGIC MARKERS- MEAS. DEPTH 5113' 5563' TRUE VERT. DEPTH 3561' 3982' 30. FO RMATIO N TESTS Include interval tested, pressure data, ail fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Summary of 1 D-125 Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed ,~,r,~,...d~. ~ Title Drilling Enqineering Supervisor Date / Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 PHILLIPS Alaska, Inc. '(UPARUK RIVER UNIT WELL SERVICE REPORT 1D-125(4-1)) WELL JOB SCOPE JOB NUMBER 1 D-125 DRILLING SUPPORT-CAPITAL 0320001904.3 DATE O4/O3/OO DAY 2 DALLY WORK CEMENT P&A OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~ Yes O No _:1 ._~"~ :_Yes O NoI DS'BIGGERSTAFF Initial Tbg IFinal Tbg I Initial IA I Final IA Initial OA IFinal OA ITTL Size 200PSII 50PSII 75PSI 75PSI 0PSI 0PSII 3.500 " UNIT NUMBER UNIT#6 SUPERVISOR RENNIE MEn ID I Depth 2.992" I 0 FT DAILY SUMMARY PLACED 10 BBLS CEMENT BELOW RETAINER AT 4955' (8 BBL IN FORMATION, 2 BBL IN TUBING). ALL PUMPING DONE THROUGH STINGER (FOUND POST-JOB THAT CIRC SUB BALL DID NOT GET TO BHA). LEFT TUBING FULL OF DIESEL. [Cement-Poly Squeeze] TIME 07:00 08:45 09:30 10:00 10:20 10:35 10:55 11:30 11:45 12:00 13:30 LOG ENTRY MIRU DOWELL CT #6 BIGGERSTAFF/DONOHO/PETERSEN ,PT CT TO 3500 PSI. TEST PLATE LEAKED. REPLACED O-RING, 2ND PT SUCCESSFUL. PT LUBRICATOR TO 3500 PSI. SAFETY MEETING. 3 DOW, 1 ARCO, 2 APC, 1 HES. RIG ON LOCATION. .PT HARDLINE TO 3500 PSI. RIH W/HES STINGER, XO, XO, CIRC SUB (5/8" BALL), XO, STAB, WT, MHA W/3/4" BALL DISCONNECT. COIL IS 14,000 FT OF 1.75" X .109" W/454,000 RUNNING FEET. VALVE CREW ON LOCATION TO GREASE LEAKING VALVE ON REVERSE-OUT SKID. STOP RIH. VALVES GREASED. CONTINUE RIH. · AT 3900'. BEGIN PUMPING SLICK SW AT 1.2 BPM THRU COIL. TAKING RETURNS TO TIGER. DOW CMT CREW ON-SITE, BEGIN SPOTTING UP. 32 BBL SLICK SW AWAY, WTR AT NOZZLE. AT 4650' RUNNING IN HOLE. WT CHKS. 8000# UP, 1800# DOWN AT 4850'. WAITING ON CEMENT AND WATER TO-FINISH UP ON NORDIC. CONTINUE PUMPING MIN RATE. bCEMENT AND WATER ON LOCATION. 67 BBL AWAY. SHUT DOWN PUMP, RIH. STING INTO RETAINER AT 4923' CTM, PUT 5000# DOWN WT. PUT 500 PSI ON BACKSIDE, HELD GOOD. 13:55 ESTABLISH INJECTION RATE INTO PERFS: 1 BPM @ 1950 PSI, 1.25 BPM @ 2150 PSI, 1.5 BPM @ 2500 PSI. TIME LOG ENTRY 14:10 UNSTING TO CIRCULATE DIESEL TO SURFACE HARDLINE. PUMP 13 BBL DIESEL, 50 BBL H20. 14:35 FP SURFACE LINES, STING INTO RETAINER. PUT 5000# DOWN & 500 PSI ON BACKSIDE. 14:45 SAFETY MEETING: 2 ARCO, 1 HES, 3 DOW CT, 4 DOW CMT, 2 APC. 14:55 ,JBACKSIDE PRESSURE BLED OFF TO 150 PSI, PUT 500 PSI ON AGAIN. 15:05 "~PUMP 4.7 BBL H20 SPACER, 9.9 BBL CEMENT, 5.5 BBL WATER, 26.5 BBL BIO. WELLHEAD PRESSURE JlNCREASED SLOWLY FROM 500 PSI TO 1550 PSI THRUOUT PUMPING. WHEN PUMPING CMT INTO FORM, /PUMP PRESSURE ROSE TO 2500 PSI THEN HELD STEADY. 16:20 I UNSTING WITH -0.3 BBL CMT IN COIL. SHUT DOWN CEMENTERS. LINE UP WATER W/CT PUMP, TAKING RETURNS TO OPEN TOP. HOLD 1500 PSI WHP, POH SLOWLY. DROP 5/8" BALL TO OPEN ClRC SUB. 16:30 REDUCE WHP TO 1000 PSI TO RIH. RIH TO 4917' (6' OFF PLUG), MAKE 2 SHORT TRIPS ON BIO. 16:45 I GOT THIN CMT RETURNS ON TIME, RETURNS CLEANED UP. GETTING 1/1 RETURNS. BALL ARRIVED ON I TIME, RIH TO 4917' AND INCREASE RATE TO 2.2 BPM. 17:00 "I,,~EGIN PUMPING 80 BBL OF CEMENTERS' WASH WATER @ 1.7 BPM, RECIPROCATING. 18:00 SWITCH TO DIESEL, PUMPING 1.8 BPM. SWITCH RETURNS TO TIGER TANK. 18:20 DIESEL AT NOZZLE. BEGIN POOH FROM 4917' CTM @ 80%.- 18:50 AT SURFACE. RDMO. WELL HAS DIESEL TO 4917' CTM (4949' ELM). FIND THAT 5/8" BALL IS NOT IN BHA- MUST HAVE GOT HELD UP IN CT. POSSIBLY HELD UP IN SIGNIFICANT DENT IN CTOBSERVED -50' ABOVE BHA. THUS, ALL PUMPING WAS DONE THRU STINGER. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(1D-125(W4-6)) WELL JOB SCOPE JOB NUiVlBER " 1 D-125 DRILLING SUPPORT-EXP WORKOVER 0320001904.3 DATE DALLY WORK UNIT NUMBER 04/04/00 CUT TBG 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 YES YES SWS-SPENCER HUNT FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE AK0064 18WSTF7SC $8,652.00 $70,378.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 50 PSI 50 PSI 50 PSII 10 PSI 0 PSI DAILY SUMMARY CUT TBG AT 4936' MD USING 2-1/4" GOEX SUPER (JET) CUTTER. TIME 09:30 10:30 11:00 11'15 12:15 13:15 13:55 14:15 15:00 16:00 LOG ENTRY MIRU. TEST CCL, GUN AT SURFACE. OK. PJSM. DISCUSS JET CUTTER SAFETY ISSUES, MUSTER AREA, RADIO SILENCE REQUIREMENT, WELLBORE CONDITION. CALL FOR RADIO SILENCE. HEAVY ACTIVITY ON DRILLSITE - NOTIFY ALL PERSONNEL ON DS OF RADIO SILENCE. DISCUSS RADIO SILENCE WITH NORDIC 3 CO MAN. PT TOOLS. PT FAILED LEAKING FROM VALVE ON LUBRICATOR (NOT TREE CAP). REPLACE VALVE. PT 'TOOLS OK. RIH W/MH-22, AH-38, 2 WEIGHT BARS, CCL, SAFE AH-ESIC, XO, SHOCK ABSORBER, GOEX JET CUTTER. CCL- JET CUTTER=50.5". 'AT PRODUCTION MANDREL. TIE IN TO MANDREL AND 14' JOINT. : LOG INTO POSITION, FIRE GUN AT 4936.1' MD. 200# TENSION DROP. POOH. .- -OOH. BEGIN RD. CONFIRM JET CUTTER FIRED. RELEASE RADIO SILENCE. NOTIFY ALL PERSONNEL ON DS TO RESUME RADIO USAGE. RDMO. 6~7/00 Schlumberger NO. 214 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1L-20A 20223 CB L/PS P/SCMT 000511 1 2C-02 L4 t ~.- LEAK DETECTION LOG 000521 I 1 2C-03 ¥ LEAK DETECTION LOG 000529 1 1 3K-04j INJECTION PROFILE W/PSP 000521 I 1 30-06 WATER INJECTION PROFILE 000528 I 1 1 D-125 PERF RECORD W/STATIC BHP 000530 1 1 SIGNED: (~ DATE: .JUN ] ;5 2000 Alaska O~ & (~as Cons. u0mmissl0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Than~dmrage 4-- 6--OO~ £:37Ph~A~CO ALASKA~ Il'lC WEST SAK 1 D-125 Injector Proposed Abandonment 16" Conductor @ 80' ~ TAM Pod Cmllar @ 1034' ARCO Alaska, Inc, APt#: 50-029-22904 Original RKB: 111' Directiona~ KOP -- 500' I~ax Angle = 64.90 Deg @ 2979' Avg Angle Thru W.Sak = 20 Beg Depths are Parker 245 RKB Baker ¥,~indow f~aster Whipstock' run on bottom trip anchor. 5-1/2" 15.5# L-80 BTCM @ 5009' 5-1/2" Baker Bridge Plug set on drill pipe @ +/~4720' MD. E;ZSV set et +/-4955' (t~iddle 6' pup joint above D nipple et 49~8' Squeeze Perfs 5090' - 5095' (Above West Sak D sand) Post squeeze, milled cem®l to 5185' CTM, stuck motor/mill, sheared off, unable to recover fish (top @ 5155' CTM) 3-1/2" 9.3# L-80 EUE 8RD-Mod @ 5779' EZSV set at 5427' Squeeze Pars 5445'. 5450' (West Sak Al irrterval) PBTD @ 5685' MD BDN 3/14/00 Well Compliance Report File on Left side of folder 198-141-0 MD 05795- TVD 04201 Microfilm Roll / - KUPARUK RIV U WSAK lDO5 50- 029-22904-00 PHILLIPS ALASKA 1NC Completion Date: /87q~98 Completed Status: 1WINJ Current: P&A Roll 2 / -- Name D 8782 L CBL/SCMT L DGR/EWR4-MD L DGR/EWR4-TVD L PERF L SCMT-PSP Interval Sent Received T/C/D SPERRY MPT/GR/EWR4 OH 10/21/98 10/22/98 FINAL 4850-5650 ? CH 5 3/12/99 3/18/99 't~ 121-5795~"-~/~/~'L-7~7 ~//~/¢~ OH 10/21/98 10/22/98 F/..EIN'AL 121-'4201 ~ OH 10/21/98 10/22/98 ~ 4370-5520~ CH 5 6/7/00 6/13/00 FINAL BE(C) 4850-5650 2/20/997 CH 5 6/8/99 6/16/99 R SRVY CALC /_qrgh~I 0-5795. OH 6/23/99 12/17/99 R SRVYRPT {~RRY 0-5795. OH 9/2/98 9/3/98 / Daily Well Ops ff,/.~ __ff~/q/t Are Dry Ditch Samples Required? yes ~___~_And Received?.~.es--m~ Was the well cored? yes ~_._.____ Analysis Description Received? yes_~ Sample Sei# --~-' Comments: I Tuesday, August 01, 2000 Page 1 of 1 STATE OF ALASKA --__ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _X Suspend _ Operational shutdown Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other_ Change approved program _ Pull tubing _ Variance_ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ 41 RKB feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service __X Kuparuk River Unit 4. Location of well at surface ¢~ ,/' ,~ 8. Well number 286' FNL, 599' FEL, Sec. 23, T11N, R10E, UM 1D-125 At top of productive interval 9. Permit number / approval number 1612' FNL, 1833' FWL, Sec. 23, T11N, R10E, UM 98-141 ¢ At effective depth 10. APl number 50-029-22904 ¢ At total depth 11. Field / Pool 1741' FNL, 1636' FWL, Sec. 23, T11 N, R10E, UM Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total depth: measured 5795' ¢"" feet Plugs (measured) true vertical 4201' '~ feet Effective depth: measured 5685' feet Junk(measured) O R I G! NAL true vedical 4097' feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 272 sx AS II 121' 121' Surface 4968' 5.5"X 593 bbls AS III & 94 bbls Class G 5009' 3465' Surface 5738' 3.5" (included above) 5779' 4186' Intermediate Production Perforation depth: measured 5445'-5450', 5090'-5095' !' ~'~ ~ !~''~ ~ '~''. / true vertical 3872'~3876', 3540'-3545' . · · Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 5017' .--: . ::'.. ': :.::;~: !..~i;-~ Packers & SSSV (type & measured depth) N/A 13. Attachments Description summary of proposal ~X Detailed operations program__ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: March 20, 2000 16. If,~proposal was verbally approved Oil __ Gas ~ Suspended X Name Date approved Service ~ 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Questions? Call Brian Noel265-6979 Signed /~.~-~ ~. ~.(~ Title: Drilling EngineeringSupervisor Date ~['~-I Chip Air'rd Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness~,,%/ Test*~J~- Approval no,~~ Plug integri,z ¢,~, BOP Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- t~ ~ )p,~(.StNAL SIGNF-D BY Approved by order of the Commission ~;~(~b~rt N r'~hristensO-n- ' ....,.,¢,o , Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE WEST SAK 1D-125 Injector Current Condition 16" Conductor @ 8O' ~ TAM Port Collar @ 1034' ARCO Alaska, Inc. APl#: 50-029-22904 Original RKB: 111' G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down Directional KOP = 500' Max Angle = 64.90 Deg @ 2979' Avg Angle Thru W.Sak = 20 Deg F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface 5-1/2" 15.5# L-80 BTCM @ 5OO9' 3-1/2" 9.3# L-80 EUE 8RD-Mod @ 5779' E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV @ 4900' D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.813" No-Go profile @ 4958' B. I jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator @ 5003' IBaker 5-1/2" XO, BTC x LTC Baker XO Coupling w/Iocator shoulder, LTC x SBE Baker 5" OD x 4" ID Seal Bore Extension Baker XO, SBE x 3-1/2" EUE 8RD Squeeze Perfs 5090' - 5095' (Above West Sak D sand) Post squeeze, milled cement to 5185' CTM, stuck motor/mill, sheared off, unable to recover fish (top @ 5155' CTM) EZSV set at 5427' Squeeze Perfs 5445' - 5450' (West Sak A1 interval) PBTD @ 5685' MD RECEIVED 16 2000 Alaska Oil & Gas Cons. BDN 3/14/00 : .. WEST SAK 1D-125 Injector Proposed Abandonment ARco Alaska, Inc. APl#: 50-029-22904 Original RKB: 111' 16" Conductor @ 80' J TAM Port Collar @ 1034' Depths are Parker 245 RKB Directional KOP = 500' Max Angle = 64.90 Deg @ 2979' Avg Angle Thru W.Sak = 20 Deg 5-1/2" Baker 'Window Master Whipstock' run on bottom trip anchor. 5-1/2" Baker Bridge Plug set on drill pipe @ +/-4720' MD. 5-1/2" 15.5# L-80 BTCM @ 5OO9' 3-1/2" 9,3# L-80 EUE 8RD-Mod @ 5779' EZSV set at +/-4955' (Middle 6' pup joint above D nipple at 4958' Squeeze Perfs 5090' - 5095' (Above West Sak D sand) Post squeeze, milled cement to 5185' CTM, stuck motor/mill, sheared off, unable to recover fish (top @ 5155' CTM) RECEIVED EZSV set at 5427' Squeeze Perfs 5445' - 5450' (West Sak A1 interval) PBTD @ 5685' MD 1 6 2000 Alaska 0il & {3as Cons. 6emmi~)n Aacf~orage BDN 3/14/00 West Sak 1D-125 Pre-Rig Work Status: This well is an injector drilled by Parker 245 in August 1998. Primary cement job had poor bond on the 3-1/2" casing across the West Sak sands. Remedial squeeze work was completed in April-May 1999. The CT motor and mill became stuck when drilling out the cement and numerous attempts to recover the fish were unsuccessful. Top of the fish is +/-5155' CTM. WSR's on 5/29/99 and 8/20/99 noted the upper squeeze perfs were leaking. Workover is planned to cut window +/- 4700 RKB and drill a sidetrack replacement wellbore. If tubing is not restricted by cement sheath, coiled tubing will be used to P&A well prior to rig moving in. . . RU slickline unit. RIH, drift 3-1/2" tubing to 'DS' nipple at 4958' RKB to verify that EZSV can be set. Attempt to establish injection into the upper squeeze perfs at 5090-5095' MD. Pressure test 5-1/2" casing to 3500 psi for 30 min. Note: If tubing restriction prevents running EZSV deep enough or injection rates too Iow, discuss CT P&A options with town engineer before proceeding. RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. Tie-in CTU depth with RKB depth and flag coil. Run and set EZSV at +/- 4955' MD (middle of 6' pup joint) just above 'DS' nipple. Squeeze at least 10 bbls of 15.8 ppg Class G cement below retainer. (2 bbl for the 3-1/2" volume below the retainer down to top of fish at 5155' MD + minimum 8 bbls into perfs.) If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and thoroughly circulate any excess cement from well (dummy valve will need to be pulled from the mandrel at 4900' RKB). Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. RU slickline unit. Bleed annulus pressure to 0 psi. Pressure test tubing above EZSV to 2500 psi for 30 min. Slowly bleed tubing pressure to 0 psi and monitor casing pressure for build-up. (Test to verify isolation of the perfs). 4. RIH and pull 1" DV from mandrel at 4900' RKB, leaving an open pocket. . RU E-line and cut 3-1/2" tubing at +/-4935' RKB (middle of full joint tubing below mandrel). Set BPV in tubing and install VR plug in annulus valve. Prepare location for Nordic 3. BDN 3/14/00 R£C£1VF..D ,MAR ! 6 .000 Alaska 0il & Gas 6o~s. 6omr~i~0~ 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI"i'N: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 U.~ ~_. 99239 CBT W/PSP/SCMT 990221 1 1C-18 99243 CBT W/PSP/SCMT 990402 1 1 D. 132 ~ ~ ~_. 99248 SCMT 990216 1 1D-125 99249 CBT W/PSP/SCMT 990220 1 1 D-114 ~,.~. i ~ .... 99246 CBT W/PSP/SCMT 990421 1 1 D- 128 99247 SCMT 990215 1 1 D- 122 L.~. ~ ¢.-. 99244 CBT W/PSP/SCMT 990226 1 1D- 111 l,t, ~ 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 6c ~ ¢. 99242 SCMT 990122 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 3/12199 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12431 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date Blueline Sepia 1 E-36 MEMORY GR/CCL 990304 I 1 1 G-07 PRODUCTION PROFILE W/PSP 990218 1 1 ,.. 1 D-122 C B L/SCMT 990226 1 1 ,. 1D-125 CBLW PSP/SCMT 990220 1 1 .. 2L-323 CBLW PSPISCMT 990221 1 1 2L-323 PRESS/TEMP SURVEY 990223 1 1 2N-320 CBL/SCMT 990303 I 1 . 2N-345 PRODUCTION PROFILE (PSP) 990227 1 1 ,. ,. ., ,.. SiGNE~/~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Oil & Gas Cons. Commm~ion ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24,1999 Mr. Robert W. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-125 (Permit No. 98-141) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-125. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineering Supervisor AAI Drilling GLA/skad RECEIVED DEC 17 1999 011 & ~s Con~, Commls~ior~ Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPQRT AND LOG 1 Status of Well Classification of Service Well OIL [--] GAS E~ SUSPENDED [] ABANDONED~ SERVICE Injector 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface At Top Producing Interval i/_~ 1612' FNL, 1833' FWL, Sec. 23, T11N, R10E, UM At Total Depth 1741' FNL, 1636' FWL, Sec. 23, Tll N, R710E, UM ........... .~ '7 Permit Number 98-141 8 APl Number 50-029-22.904 9 Unit or Lease Name Kuparuk River Unit 10 Well Number 1D-125 11 Field and Pool KUPARUK RIVER West Sak Oil Pool 15 Water Depth, if offshore ~16 No. of Completions NA feet. M~L~[, 1 Depth where SSSV set I 21 Thickness of permafrost NA teet MD ! 1960 APPROX ,. · 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 41', Pad 70' I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D, Reached i 14 Date Comp., Susp. or Aband. 06.Aug-98._' 09-Au~-98 [ 12-Au~-98... 17 Total Depth (MD+WD) 18 Plug Back Depth (MD+TVD) .19 Directional Survey 120 122 Type Electric or Other Logs Run IGR/ResJNeu/Dens. CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5/t H-40 SURF. 121' 24" 5.5" x 15.5# L-80 SURF. 5009' 8.5" 3,5" 9.3# L-80 SURF. 5779' 8.5" 24 Perforations open to Production (MD+TVD of Top and BoB, om and interval, size and number) 5445'-5450' MD 3872'-3876' TVD. 6 spt 5090'-5095' MD 3540'-3545'TVD 6 spf J~7ate First Production 272 sx AS II 593 bbls ASlll & 94 bbls Class G (included a~ove) 25 SIZE 3,5" 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC TUBING RECORD DEPTH SET (MD) !PACKER SET (MD~ 5017' { N/A DEPTH iNTERVAL (MD.). 5445'-5450', 5090~-5095' AMO..Ur'.NT & KIND OF MATER~A.L USED Isee attachments PRODUCTION TEST IMethod i Date of Test I Hours Tested FIOWpress.TUbing Casing Pressure of Operation (Flowing, gas lift, etc.) i PRODUCTION FOtOIL-BBL ITEST PERiOI: I .... ICALCULATED IOIL-BBL 124-HOUR RATE: I Injector GAS-MCF GAS-MCF WATER-BBI WATER-BB[ ! CHOKE SIZE ] GAS-OIL F:LATIO I I OIL GRAVITY-APl (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips ana presence of oil, gas or water. Submit core chips. N/A ORIGINAL RECEIVED DEC 17 1999 &GasC0ns. Com Anchorage Submit in 0uplic~te Form 10-407 Rev. 7-1 ~ CONT!NIJED ON REVERSE SIDE GEOLOGIC MARKERS 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, NAME Top West Sak Sand West Sak Base MEAS DEPTH 5113' 5563' TRUE VERT. DEPTH 3561' 3982' GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Ddlli. n. g Reports, Dire.ct!onal Survey, 32. I hereby certify' thst the foregoing ;s true and correct to the best of my knowledge Title i~ [~ I'~,-~,,~,- ~.',-~ ~?v. DATE Prepared'by Na~e/Nurrfber i Sharon AIIsup~Drake/263-461 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' C!assification 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 othen~ise 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 2!: Indicate whether from ground love! (GL) or other elevation (DF, KB, otc.). 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 !n- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/26/99 ARCO ALASKA_ INC. WELL SUMMARY REPORT Page: 1 WELL:iD-125 WELL ID: AK9621 TYPE: AFC: AK9621 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/06/98 START COMP: RIG:RIG # 245 BLOCK: FINAL: WI: 0% SECURITY:0 A?I NUMBER: 50-029-22904-00 08/06/98 (D1) TD: 528' (528) SUPV:FRED HERBERT 08/07/98 (D2) TD: 3506'(2978) SUPV:FRED HERBERT 08/08/98 (D3) TD: 5686'(2180) SUPV:FRED HERBERT 08/09/98 (D4) TD: 5686'( 0) SUPV:FRED HERBERT 08/10/98 (D5) TD: 5686'( 0) SUPV:FRED HERBERT 08/11/98 (D6) TD: 5795'(109) SUPV:FRED HERBERT MW: 8.9 VISC: 300 PV/YP: 45/56 DRILLING APIWL: 6.5 Move to 1D-125. NU diverter system and test. Drilling 8.5" hole from 121' to 528' MW: 9.5 ViSC: 283 PV/YP: 48/59 CIRC BTTMS UP APIWL: 4.8 Drilling 8.5" hole from 528' to 3506' POOH for bit, swabbing @ 2846'. Packed off @ 2782'. Work pipe out with top drive. Possible gravel up hole sloughing in. MW: 9.5 VISC: 200 PV/YP: 44/58 CIRC & COND MUD AT TD 5975' APiWL: 4.0 Drilling 8.5" hole from 3506' to 5686' Ream MW: 9.7 VISC: 290 PV/YP: 59/80 APIWL: 4.3 Drilling 8.5" hole from 5686' to 5795'. Pump pill & POOH to 4800' started swabbing, attempt to pump out stands, no circ packed off. RIH wash to bottom. Large amount of gravel in returns. POOH, pump out, packed off & lost returns @ 4700' Work pipe (rotate and recip) can't get returns, can't go down. Circ& spot barotrol pill from 1987' to surface. Ream from 2725' to 4393' no losses in mud volume. MW: 9.7 VISC: 450 PV/YP: 58/92 APIWL: 4.4 TRIP IN WITH COMBO TOOL TO CMT THRU TAM COLLAR Wash and ream from 4393' to 5795'. Lost 73 bbls. Run 5.5" x 3.5" casing. MW: 9.6 VISC: 78 PV/YP: 25/30 DISPLACE WELL WATER & 3% KCL APIWL: 4.8 Cement 1st and 2nd stage casing. RIH w/3.5" tubing. ND diverter and NU BOPE and test to 300/3000 psi. Date: 1/26/99 Page: 2 ARCO ALASKA INC. WELL SUMMARY REPORT 08/12/98 (D7) TD: 5795'( 0) SUPV:FRED HERBERT 5~: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED FROM 1D-125 @ 1530 HRS 8/12/98 APIWL: 0.0 Run 3.5" tubing. Freeze protect well. ND BOPE. Released rig from 1D-125 @ 1530 hrs. 8/12/98. RECEIVED DEC 1 7 1999 ~ Oil & Ges Cons. Anchorage ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D.-125(W4-6)) WELL 1 D-125 DATE 04/04/99 DAY 1 FIELD ESTIMATE JOB SCOPE PERFORATIONS-E-LINE DALLY WORK PERF SQZ HOLES - SET EZSV CMT RETAINER OPERATION COMPLETE I SUCCESSFUL. YES I YES AFC# CC# AK9621 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann 200 PSI 0 PSi 0 PS! JOB NUMBER 0219991725.2 UNIT NUMBER 8345 KEY PERSON SUPERVISOR SWS-STEPH ENSON KOLSTAD Signed Final Inner Ann 1 0 PSI 1 Initial OuterAnn { 0 PSi I Final Outer Ann 0 PSI DAILY SUMMARY PERF SQZ HOLES 5445'-5450' AND 5090'-5095' WITH 2 1/8" 2006 PJ/HMX/6 SPF/60 DEG PHASING RUN W/CCL - SET EZSV CEMENT RETAINER WITH BAKER 10 CONVENTIONAL SETTING TOOL RUN W/COL - TAG 5676' PRE PERF Perf, [Tag, Tree Valve Problem] TIME I LOG ENTRY 08:15 I MIRU SWS 08:20 RD SWS - TREE CAP FLANGEW ITH 3.5" OTIS CONNECTION LEAKING - DISCOVERED SWS CAP O-RING GROOVE IS 1/16" DEEPER THAN TREE CAP PLUG O-RING GROOVE - HAVE ENCOUNTERED THIS PROBLEM ON 1D PAD BEFORE - TALKED WITH VETTCO GREY WELL HEAD REP - WAIT ON DIFFERENT TREE CAP FLANGE FROM VALVE SHOP. 12:30 FLANGE UP DIFFERENT TREE CAP TO WELL HEAD - RU SWS WITH 2 1/8" 2006 PJ/HMX/6 SPF/60 DEG PHASING 20' GUN WITH ONLY 5' LOADED - RIH 13:00 TAG PBTD AT 5676' 13:18 TIE IN TO LOWER INTERVAL USING CCL- 17' FROM MID CCL TO TOP SHOT 13:25 PERF 5445'-5450' WITH 2 1/8" 2006 PJ/HMX/6 SPF/60 DEG PHAS!NG 20' GUN WITH ONLY 5' LOADED - POOH 14:10 CCH WITH 1ST GUN - ALL SHOTS FIRED - PU 2 1/8" 2006 PJ/HMX/6 SPF/60 DEG PHASING 20' GUN WITH ONLY 5' LOADED FOR 2ND PERF INTERVAL FROM 5090'-5095' 14:42 RIH WITH 2ND PERF GUN 15:30 TIE IN TO GLM FOR 2ND PERF INTERVAL 15:40 PERF 5090'-5095' WITH 2 1/8" 2006 PJ/HMX/6 SPF/60 DEG PHASING 20' GUN WITH ONLY 5' LOADED - 30 LB DROP IN LINE TENSION - WHP=0 AFTER SHOOTING - POOH 16:15 LD 2ND GUN - ALL SHOTS FIRED - PU AND RIH W/EZSV CEMENT RETAINER WITH BAKER 10 CONVENTIONAL SETTING TOOL AND CCL - PRESSURES T/iA/CA= 0/0/NA PSI 17:10 TIE IN TO GLM AT 4900'- SET DOWN AT BTM OF GLM 2 TIMES TRYING TO GET THROUGH - GOT THROUGH 3RD TRY - STOP AT 5600' AND LOG UP TO GET ON DEPTH RECEIVED DEC 17 1999 Alas Oil & Gas Cons. Com dsslofl AnchoraDe TIME 17:30 18:30 LOG ENTRY SET EZSV- BTM OF ELEMENT AT 5435' - 50 LB TENSION DROP - WAIT 5 MIN - PUH AND LOG COLLARS TO MAKE SURE STILL ON DEPTH - RIH AND TAG TOP OF EZSV AT 5426,5 (BTM OF ELEMENT STILL AT 5435' - GOOD SET)- POOH RDMO SWS t Date 04/04/99 Upcoming F- Well Na 1D-125 Job Num 021999i725.2 Service Type ELECTRIC LINE Unit 8345 Desc of Work PERF SQZ HOLES - SET EZSV CMT RETAINER Supervisor KOLSTAD Contractor Key Perso SWS-STEPHENSON Campier ~' Successful F~ Accident r'- Initial Tbg Press 200 Injury r- Initial Int Csg Press 0 Spill F- Initial Out Csg Press 0 Summary AFC AK9621 0 Prop 18WSTF7S, Uploaded to Sen Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERF SQZ HOLES 5445'-,5450' AND 5090'-5095' WITH 2" HC 2006 PJ HMX CHARGES/6 SPF/60 DEG PHASING RUN W/CCL - SET CEMENT RETAINER WITH BAKER 10 CONVENTIONAL SEIE!NG TOOL RUN W/CCL - TAG :¢576' PRE PERF Perf, ['rag, Tree Valve Problem] Date printed: 05/04/99 at: 16:02:38 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-125(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-125 CEMENT SQUEEZE 0321990647~8 DATE 04/29/99 DAY 1 FIELD ESTIMATE DAILY WORK CTU CIRCULATION SQUEEZE OPERATION COMPLETE I SUCCESSFUL NO I YES AFC# CC# AK9621 25WS1D6DL Initial Tbg Press Final Tbg Press Initial Inner Ann 100 PSI 100 PSI 100 PSI DAILY SUMMARY UNIT NUMBER UNIT #3 KEY PERSON SUPERVISOR DS-NEWELL LIGENZA Signed Fin,~l Inner1 ooAnnps! I Initial Outer oAnnpsl I Final Outer Ann 0 PSi CIRCULATED KCL WASH THROUGH PERFS PER PROCEDURE. CLEAN RETURNS. ESTABLISHED ONE BPM RATE. RATES ABOVE ONE BPM LEAKED OFF. READY TO CIRCULATE CEMENT TOMORROW. [Cement-Pol¥ Squeeze] TIME LOG ENTRY 07:00 MIRU DS CTU. STAND-BY FOR HALLIBURTON / RADIUS. SPECIAL STINGER FOR CEMENT RETAINER. 11:00 MAKE UP RADIUS TS; COIL CONNECTOR, BLANK CHECKS, 3 CROSS OVERS. HALLIBURTON STINGER. TGSM WITH SCHLUMBERGER ELINE. PERFORATING ON NEAR BY WELL. RADIO SILENCE WHEN THEY ARE WITH IN 200' OF SURFACE. 13:00 PRESSURE TEST LUBE/BOPS/HARD LINES TO 4000 PSI. !3:20 START IN HOLE. TUBING PRESSURE IS 100 PSI. STOP AT 5000'. STAND BY FOR REPLACEMENT PUMP. 14:15 START PUMPING 1 BPM DOWN ANNULAR AREA TAKING RETURNS UP COIL. WH 960 PSI, RETURN 45 PSI. GETTING 1 FOR 1. 15:00 SWITCHED TO DS PUMP TRUCK INJECTING SURFACTANT AT0.1 GAL/BBL..7 BPM = 450 PSi WH, 50 PSI RETURN. ONE FOR ONE1.1 BPM =1135 PSI WH, 60 PSi RETURNS. ONE FOR ONE.1.5 BPM = 1280 PSI WH, 60 PSI RETURNS. 1.2 BPM RETURNS. 15:25 SHUT DOWN PUMP. RUN DOWN TO RETAINER. SET DOWN AT 5413' CTM 5435' RKB. START PUMPING AT 0.5 BPM 500 PSI WH. / 50 PSi RETURNS. ONE FOR ONE.1.0 BPM, 985 PSI WH, 58 PSI RETURNS. ONE FOR ONE.INCREASED TO 1.5 BPM, SAW IMMEDIATE LEAK OFF. DROPPED BACK DOWN TO 1.0 BPM RATE. 17:10 TOTAL OF 96.5 BBLS REVERSE PUMPED. SHUT DOWN PUMP. SWITCHED TO PUMPING DOWN COIL TAKING RETURNS UP TUBING. LAST THIRTY BBLS CAME BACK CLEAN. MOST OF THIS PHASE WE REClEVED ONE FOR ONE RETURNS. LAST TWENTY SIX BBLS PUMPED WE RETURNED TWENTY. 18:40 PUMPED 72 BBLS DOWN COIL AT .5 BPM, COIL AT 450 PSI..75 BPM AT 750 PSI AND.1.0 BPM AT 1400 PSI. CLEAN RETURNS. ONE FOR ONE RETURNS UP TO ONE BPM RATE. PULL UP TO 3000'. DISPLACE COIL AND TUBING WITH DIESEL. 19:45 ON SURFACE, ALL LINES FREEZE PROTECTED. RD DS CTU FOR TONIGHT. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-125(W4~6)) _ WELL JOB SCOPE JOB NUMBER ......... DATE DAILY WORK UNIT NUMI: 04/30/99 CIRCULATE CEMENT SQUEEZE UNIT #3 DAY" OP'I~RATION COMPLETE I SUCCESSFUL KE~ PERSON "' SUPERVIS~ 1 YESI NO DS-NEWELL Li~ FIELD AFt# CC# Signed ESTIMAT AK9621 25WS1 D6DL !NZA Final Outer Ann 0 PSi DAILY SUMMARY PUMPED CIRCULATION CEMENT SQUEEZE PER PROCEDURE. WHILE PULLING UP WE TOPPED OUT AT 4988'. AFTER CIRCULATING IN BOTH DIRECTIONS AND MOVING UP AND DOWN SEVERAL TIMES WE WERE ABLE TO PULL FREE. FOUND A PIECE OF SEAL RUBBER AROUND STINGER. TOP PORTION OF CEMENT JOB PUMPED AWAY AND CONTAMINATED WITH DIESEL AND KCL WATER,[Ceme..n.t-PoI¥ Squeeze] TiME LOG ENTRY 07:30 MIRU DS CTU AND DS CEMENT PUMPER. 08:30 TGSM, E-LINE PERFORATING ON PAD. MET AND DISCUSSED OPERATION AND RADIO USAGE. DISCUSSED WIND DIRECTION, EVAC LOCATION. PUMP SCHEDULE. 09:00 PRESSURE TEST TO 4,000 PSI. RIH W RADIUS CONNECTS)R, BLANK CHECKS, 3 - X-OVERS. HALLIBURTON EZ DRILL STINGER. 09:25 STARTED PUMPING KCL AT 1 BPM TO DISPLACE DIESEL OUT OF COIL. STOP AT 3000' TO COMPLETE DISPLACEMENT. 10:20 WT CHECK AT 5200', PUMPING ONE BPM, 13,000 #, SHUT DOWN PUMP W/64 BBLS OF KCL PUMPED. 10:30 SET STINGER. PUMP ONE BPM KCL TO ESTABLISH PRESSURES. 1255 PSI DOWN COIL, 50 PSI WH. SHUT DOWN PUMP 11:30 11:45 NO DISTINCT DIFFERENCE IN PRESSURE WHEN STINGER IS SET OR ABOVE RETAINER. SET DOWN IN RETAINER PUMPING MINIMUM RATE. SAW NO PRESSURE SPIKE. NO rvIARKS ON BOTTOM OF STINGER AFTER YESTERDAYS WASH. DISCUSSED POTENTIAL OF NOT BEING SET IN RETAINER. RESULTS OF DIRTY RETURNS YESTERDAY WITH THE SAME PRESSURES SEEN TODAY, THE DECISION WAS MADE TO PROCEDE WITH PUMPING CEMENT. STARTED PUMPING 10 BBLS OF FRESH WATER. PUMP CEMENT STAGE TO 30 BBLS, SHUT DOWN PUMP, PULL OUT OF RETAINER. RESUME PUMPING. LAY IN 3 BBLS OF CEMENT. STOP AT 5050'. SHUT IN CHOKE AND SQUEEZE 10 BBLS OF CEMENT IN'r'o TOP PERFS. 3 BBLS OF FRESH WATER BETWEEM CEMENT AND KCL. TIME LOG ENTRY 13:30 LAST OF CEMENT OUT OF THE NOZZLE. POH AT 115 FPM. OPEN CHOKE. HUNG UP AT 4988'. MOVE DOWN AND PULL UP. CONSISTANTLY STOP AT SAME LOCATION. PULLED UP TO 32,000#. 13:45 OUT OF KCL, SWITCHED TO DIESEL DOWN ANNULAR AREA. TAKING RETURNS UP THE COIL. ATTEMPTED TO PULL UP SIX TIMES. NO CHANGE. ORDERED ANOTHER TRANSPORT OF DIESEL. 14:30 GETTING CEMENT IN RETURNS. 14:55 CLEAN DIESEL IN RETURNS. 15:30 16:00 RAN OUT OF FLUIDS. STANDING BY. ABLE TO MOVE UP / DOWN, AND CIRCULATE IN BOTH DIRECTIONS. DIESEL TRANSPORT ARRIVED. START PUMPING DOWN THE COIL AT 2 BPM. PULLED UP TO 32000# AND PULLED FREE. POH. 18:00 ON SURFACE. FOUND A PIECE OF RUBBER WRAPPED AROUND STINGER. RDMO DS CTU. ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~ K1(1D-125(W4-6)) WELL JOB NUMBER 1 D-125 0321990647.8 DATE DAILY WORK UNIT NUMBER 05/23/99 RESQUEEZE UNIT #3 DAY 4 FIELD ESTIMATE JOb SCOPE CEMENT SQUEEZE OPERATION COMPLETE SUCCESSFUL YES YES AFC# CC# AK9621 25WSl D6DL KEY PERSON DS-NEWELL SUPERVISOR FERGUSON Signed Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PS! 0 PSI! 0 PSIi 0 PSI DAILY SUMMARY RU DOWELL COIL AND CEMENTERS, RIH TO 5175 FT. CIRCULATE 2 BBLS ABOVE NOZZLE AND PU TO 5000 FT. SQUEEZE 21 BBLS CEMENT BEHIND PIPE WHILE PU AND LEAVE EST. CEMENT TOP AT 4140 FT. POH AND SPOT DIESEL CAP FROM 2500 FT TO SURFACE.[Cement-Poly Squeeze] , TIME LOG ENTRY 07:45 ARRIVE LOCATION. DOWELL CTU AND CEMENTERS RIGGED UP 07:50 HOLD SAFETY MEETING 08:05 RIH WITH COIL 08:40 WT CHK AT 2958 FT IS 10,000#'S 08:50 BEGIN DISPLACING DIESEL FROM COIL WITH SLICK SEAWATER, TAKING RETURNS TO TANKS 09:15 RECHECK INJECTIVITY. 0.9 BPM AT 1200 PSI 09:25 TAG AT 5180 FT, PU 5 FT 09:40 PT CEMENT LINES TO 4000 PSi. COiL VOLUME IS 32.1 BBLS 09:55 LEAD CEMENT WITH 5 BBLS WATER AT 1 BPM, NOZZLE AT 5175 FT. 10:06 START CEMENTDOWN COIL AT 1 BPM TAKING RETURNS TO TANKS 10:45 PUMP 22.1 BBLS CEMENT, TAKE 1 BBL ABOVE NOZZLE, PU TO 5060 FT, PUMP ADDITIONAL BBL AND S! CHOKE. PU TO 5000 FT AND CONTINUE TO SQZ CEMENT AT 1360 PSI WHP 11:00 PU AT 100 FPM PUMPING MIN RATES OF 0.25 BPM WITH WATER 11:02 SQZ AWAY 21 BBLS CEMENT BEHIND PIPE. EST TOC iN TBG IS AT 4140 FT 11:05 SWITCH TO DIESEL TO LAY IN FREEZE PROTECT CAP 11:15 PU TO 2500 FT TO LAY IN DIESEL CAP 12:30 !3:00 POOH LAYING IN DIESEL 1:1 OUT OF HOLE WITH COIL. RD AND RELEASE DOWELL RECEIVED D£C 7 lggg 0it & Gas Co~s. Commission Anchorage 0 I:t I I_1_ I I~1G S IE I::!~1 r- E S 02-Sep-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-125 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,795.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ,.~ . i.I iiiii ii i i i ii i iiiiiii i i .r.~,l~l[ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99487 Sidetrack No.. ....... Page _1___ of _3___ Company ARCO ALASKA, INC. Rig Contractor & No. PARKER -245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D-125/H2 Survey Section Name Definitive Survey BHI Rep. II I I II I IIII WELL DATA _. Target'rVD ..................... .(..F~. ............... TargetCoord. N/S ................. SlotCoord. N/S ..... -2____~._:_0~)_. ........ Grid Correction ...... _0:_.0~_. ........ Depths Measured From: RKB~ MSLiiii SS!;-' Target Description ....................... Target Coord. E/W Slot Coord. E/W -599.00 Magn. Declination 27.420 Calculation Method MINIMUM CURVATURE Target Direction ..... ~_O1 .......... Build~Walk\DL per: 100fti~ 30m~'-I 1Om ~" Vert. Sec. Azim. 244.93 Magn. to Map Corr. 27.420 Map North to: OTHER ii i i i i i i i SURVEY DATA Survey Survey Incl. Hole Course Vertical r Total Coordinate Build Rate Walk Rate Date Tool Depth i Angle Direction Length TVD Section -"N(~)i ~(-i .... ~:(-~-) ~{'-)- DL Build (+) Right (+) Comment Type . IFT~ (DDI ~.ODI i~:q'l (FT) .... c . (r,'-) {FT1 liner mO ~q Drop (-1 Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT .... oo-"i ........... ............................ 06-AUG-98; MWD : 121.00 ' 0.00 ' 0.00 121.00 . 0.00 0.00 ; 0.00 0.00 0.00 ' ~63/4"MACH 1C-AKO-1.4 DEG. 06-AUG-98I MWD! 172.00I 1.00i 2.00,, 51.00 172.00I -0.20 0.44 ! 0.02 1.96 1.96i i*****GYRO***** ...................... ~ .......... -{- ........ ~ i .............. ~ ................ -~ ................................... ~ ......................... t ........... ~ .......... ~ -;- .......... 06-AUG-98 i MWD i 379.71 ! 0.20 i 30.94 ~ 89 21 379 69 ~ -O88 I 2.76 I -03~ 065 i -054 ......... ' ....... .-~ ............. .-,- ...... $ ....... i .... '-' ............ '~-. ~ ............. '-- ~ ........... ~ .......... ;_.L'; ' ~ - -'-' -I ....... ._i__ ........................................................... 06-AUG-9ST MWD 471,93 0.67 I 235.48 i 92.22 471 91 I -0.48 j 2.59 i -0.68 0.93 f 0.51 ................. 07'AUG'98 It' ................... MWD'-~ 562.21 t ..... 3.551 254.681-;- ...................... ;-- ....................................................................... 90.28 562.12 2.79 1.551 -3.81 3.24 3'19/~r ............................................................................. ...... ' ........... , ------'1--- ............. + ........... ; ....... - ................. T ' ' j ' 07-AUG-98 { MWD 743.18 9.30 260.46 i 91.49 741.72 23.51 -1,84 -25.09 2.25 OT-AUG-98 MVVD 833.30 12.63 258.61 t 90.12 830.19 40.10 -4.99 -41,93 3.72 3,70 -2.05 ...........| 07-AUG-98 MWD 924.58 20.16 254.20 91.28 917.70 65.36 -11.26 -66,89 8.36 8.25 -4.83 07-AUG-~98 MWD 1014.86 26. i 8 250.97 90.28 1000.66 100.55 -22.00 -100.72 6.81 6.67 -3.58 07-AUG-98 MWD 1107.77 29.57 251.97 92.91 1082,78 143,70 -35.78 -141.91 3.68 3,65 1.08 07-AUG-98 MwD 1196.98 32.88 251.40 89.21 ' 1159.05 ' 189.62 -50.32 -185.80 3.73 3.71 -0.64 !, 07-AUG-98 MWD 1288.65 36.52 249.18 91.67 1234.41 241.56 -67.96 -234.90 4.20 3.97 -2.42 07-AUG..98 MWD 1380.01 42.20 247.56 91.36 1305.02 299.37 -89.35 -288.71 6.32 I 6.22. -1.77 ,9 .24 1370.64 .70 - 14.18 - 7.01 4.05 3.95 . O7-AUG-98 MWD 1562.22 50.62 244.77 90.97 1431.25 430.50 -142.26 -408.73 5.45 5.30 -1.74 , 07-AUG-98 MWD 1652.79 55.97 245.22 90.57 1485.36 503.09 -172.93 -474.51 5.92 5.91 .0.50 07-AUG-98 MWD , 1746.69 60.95 . 244.03 93.90 1534.~7 583.09 -207.24 -546.79 5.41 5.30 -1.27 07-AUG-98 MWD 1842.93 63.38 242.90 96.24 1579.40 668.15 -245.26 -622.91 2.73 2.52 -1.17 07~AUG-98 MWD 2125.05 61.93 242.43 282.12 1708.99 918.55 -360.33 -845.52 0.53 -0.51 .-0.17 07-AUG-98 MWD 2406.78 64.22 243.59 281.73 1836.56 1169.57 -474.29 -1069.35 0.89 0.81 0.41 07-AUG-98 MWD 2689.92 6'2.94 245.76 283.14 1982.55 1423.11 -582.77 -1298.51 0.82 -0.45 0.77 i iiiii i i illllll iiiii ii i i ii iii i i ................ KS .i EET .... SURVEY CALCULATION AND FIELD WOR Job.o. 0450-99487 Sidetrack No. Page 2 of 3 Company ARCO ALASKA, INC, Rig Contractor & No. PARKER - 245__ Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D-125/H2 Survey Section Name Definitive Survey BHI Rep. _ ............ WELL DATA Target TVD ................. _(.F~__ ........... Target Coord. N/S ..... Slot Coord. N/S ..... :_ _2~,_ :. _00. .... Grid Correction .... _0..._.07.0 ........... Depths Measured From: RKB ~ USE i? SST Target Description ......................... Target Coord. E/W ................ Slot Coord. ENV .. .-_5_97._.0~._ Magn. Declination ...... ~2.7;.4.2? ..... Calculation Method M!NIMUH ..C_UR..VA.,,,.T. UR.~.. Target Direction ......... cD.D!. . Build~.Walk\DL per: 100ft:~ 30m~.~: 10m?: Vert, Sec. Azim. 244:9~ Magn. to Map Corr. 27.4_20' Map North to: OTHER ...... ii i i i ii i iiii i __ SURVEY DATA · · Survey Survey Incl. Hole Course '] Total Coordinate Build Rate ' Walk Rate ' Vertical ........ Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD ~ Section N(+) / S(-) Fi+') '/W(-)' DL Type ' ~FT~ ~or)t loo~ [FTI (F~ ~FTI It:T? ' I'Per 100 FTc' Drop (-) Left(;) ............ 07-AUG-98 MWD 2978.93 64·90 247.83 289.01 2089.61 · 1682.52 -685.00 · -1537.08 0.93 0.68 0.72 6 3/4"MACH 1C-AKO-1.2 DEG. 07-AUG-98; MWD' 3261.42:62.90 243.35, 282.49 2213.94 i 1936.09 -789.72 i -1768.0;~......... ; . 59 .... -C~.'Z'I ; --1.~59 ' ................... r ....................................... T .................. ? ..................... ....................... ' ............ ~ ................ ? ................ ' 2257.92 i 2019.78 -827.78" -1842.62 ' 1.48; -1.29 , -0.81 ...': 07-AUG-98 I MWD|,.,-,=,~ i59.43 i 243.11 i 92.68 2303.48 ! 2100.43 -864.62 '! -1914.42 2.48" -2.43 ; 0.57 .~- ! , . 08-AUG-981MWDI 3539.41 j 55.71 ' 2352:1~-'1 2176,94 -899.42 ~ -1982.61 -,~:i1~ ~4.10 i -0.34' 08-AUG-9S~'''MwD' ' t i 242.S0i 90.72 , . ~~ ...... ' 3635,61 : 53,68': 243,651. 96.20 2407.71 i 2255.41 -934.79 ' --~-2~,~'~'~-- . 2.23 -2.11 0.88 ......................... ~ ...... , .......... I .................................. 08-AUG-98 MWD 3733.63 !52.44 243.10 98.02 2466.62 2333.72 -969.90 -2122.73 1,34 -1.27 -0.56 ....... ~ ...... ~ ........ r ........ 08-AUG-98 MWD 3828.77 150.20 243.31 95.14 2526.08 2407.95 -1003.38 i -2189,02 2.36 -2.35 0.22 08-AUG-98 MWD 3923.80 48,86 244.18 95.03 2587.76 2480.23 -1035.36 I -2253.85 , 1.57 -1.41 0.92 08-AUG-98 MWD 4018.60 46.63 245,23 94.80 2651,50 2550.39 -1065.35 -2317.28 2.49 -2.35 1.11 ._ . 08-AUG-98 MWD 4113.42 44.37 245.41 94.82 2717,95 2618.01 -1093.59 -2378.73 2.39 -2.38 0.19 ...... .......... 08-AUG-98 MWD 4209.12 41.69 244.66 95.70 . 2787.91 2683131 -1121.14 -2437.93 2~85 -2.80 -0.78 -- 08-AUG-98 MWD 4300.98 39.63 244,72 91.86 2857,59 2743.16 -1146.73 -2492.03 , 2,24 -2.24 0.07 ., 08-AUG;98 MWD 4398.21 37.10 244.73 97,23 2933.81 2803,50 -1172.49 -2546.60 2.60 ~2.60 0.01 ..... - 08-AUG-98 MWD. 4493.32 34;79 244.91 95.11 3010~81 2859.33 -1196.25 -2597,12 2.43 -2.43 O. 19 -- 08-AUG-98 MWD 4588.~ 1 32,15 244.44 94.79 3089,87 2911.60 -1218.60 -2644.37 2.80 -2.79 -0.50 ..... -. ....... 08-AUG-98 MWD . 4684;09 29.98 244.47 95.98 3172,08 2961.12 -1239.96 -2689.05 2,26 -2.26 0.03 ,. ~ , --~ - ...... 08-AUG-98 MWD 4779.98 27.36 242,56 95.89 32r"~.21 3007.10 -1260.44 -2730.24 2.1~9 -2.73 -1.99 ~ . 08-AUG-98 MWD 4875.40 25.06 241.48 95.42 3341.81 3049.19 -1280.20 -2767.46 2.46 -2.41 -1,13 , ....... .......... 08-AUG-98 MWD 4989.68 22.28 241.69 94.28 3428.16 3086.97 -1298.21 -2800.74 2.95 -2.95 0.22 ................. 08'AUG-98 MWD 5158, 87 21.2i 238.,0,3 189.19 3603.89 3156,82 -1332.88 -2861.63 0.78 -0.57 -1.46 .... · ~ .......... ~ ..... 08-AUG-98 MWD 5,346.47 20.76 238. i 4 187.60 3779.04 3223.58 -1367.94 -2918.94 0.28 -0,24 -0.42 .......... ............ 08-AUG-98 MWD 5535.93 19,54 235.50 189.46 3956.91 3288.18 -1403.62 -2973.57 0.80 -0.64 -1.39 ....... . , 09-AUG-98 MWD 5734.91 19.49 234.62 1 98.98 4144.46 3353.67 -1441.68 -,.3028.06 O. 15 -0.03 -0.44 ± [1111 i £ i I ii ii ii i iml ii ii i i ~ i ii ii i · i i iii iii ii i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99487 Sidetrack No. Page __3_ .... of 3 Company ARCO ALaSKa, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK R~/ER UNIT Well Name & No. PAD 1D/1D-125/H2 Survey Section Name Definitive Surve,~ BHI Rep. WELL DATA ,--~ Target TVD ...................... !...FT)_. .......... Target Coord. N/S ................ Slot Coord. N/S _...'.._2_86_-..0~3_ ........ Grid Correction __ 0.000 Depths Measured From: RKB ~ MSL; i SS~ Target Description .............................. Target Coord. E/W ..................... Slot Coord. E/W . ..~5_.9_.9.:00 ...... Uagn. Declination ...... 2_7.._4..2_0. .... Calculation Method M..I_.N. IMU_M' _CU.R~_!AT.._URE Target Direction .... tDDI ..... Build\Walk\DL per: lOOft;~, 30m! ~ 1Om". Vert. Sec. Azim.. 244.93 Magn. to Map Corr. 27.420 .. Map North to: OTHER " SURVI~YDATA ........ Total Coordinate Build Rate , Walk Rate · Survey Survey Incl. Hole Course Vertical ....... Build (+) Right (+) Comment Date , Tool Depth Angle Direction Length TVD Section N(+) / S(.) E(+) / W(-) DI_ Type ' (;Ti tDD) tDD) tF'T~ i. iFl'l {FT~ il:TI (Per 100 ~r~ Drop (-) . Left (-) og-AUG-98 MWD 5795.00 19.49 234,62 60.09 4201.10 3373.39 -1453.29 -3044.41 0.00 0~00 0.00 CLO.DIST=3373.49 AZ1=244.48 .. ................ ~ ........ -- ................. r ................................................ i ................ '=7 .................. : ................ . ...................... ? .......... i ........... .......... ':' ' * : __ , I [ I I n I [ Il lB[ [ [ 111111 PI I Kuparuk Unit Kuparuk ID ~D-125 ORIGINAL SURVEY REPORT 27 August, 1998 Your Ref: AP1-500292290400 Last Survey 09-August-98 Job# AKMMS0324 KBE - 111.80' Sla~,r~r~-surq DRILLING SERVICES Survey Reft svy62 Sperry-Sun Drilling Services Survey Report for 1D-125 Your Ref: API-500292290400 Kuparuk Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft), (ft) 0.00 0.000 0.000 -111.80 0.00 0.00 N 0,00 E 5959379,35 N 560490.59 E 0.00 121.00 0.000 0.000 9.20 121.00 0.00 N 0.00 E 5959379.35 N 560490.59 E 0.000 0.00 172.00 1.000 2.000 60.20 172.00 0.44 N 0.02 E 5959379.79 N 560490.60 E 1.961 -0.20 290.50 0.680 338.610 178.68 290.48 2,13 N 0.20 W 5959381.48 N 560490,37 E 0.391 -0.72 379.71 0.200 30.940 267.89 379.69 2.76 N 0.32 W 5959382.11 N 560490.25 E 0.650 -0.88 471.93 0.670 235.480 360.11 471.91 562.21 3.550 254.680 450,32 562.12 651.69 7.240 262.760 539.39 651.19 743.18 9.300 260.460 629.92 741.72 833.30 12.630 258.610 718.39 830.19 2.59 N 0.68W 5959381.94 N 560489.89 E 0.928 -0.48 1.55 N 3.81W 5959380.87 N 560486.77 E 3.241 2.79 0.11N 12.08W 5959379.36 N 560478.51 E 4.200 10.89 1,84 S 25.09W 5959377.31N 560465.52 E 2.280 23.51 4.99 S 41.93W 5959374.02 N 560448.70 E 3.715 40.10 924.58 20.160 254.200 805.89 917.69 1014,86 26.180 250.970 888.86 1000.66 1107.77 29.570 251.970 970.98 1082.78 1196.98 32.880 251.400 1047.25 1159.05 1288.65 36.520 249.180 1122.61 1234.41 11.26 S 66.89W 5959367.55 N 560423.79 E 8.356 65,36 22.00 S 100.72W 5959356.54 N 560390.05 E 6.813 100.55 35.78 S 141.90W 5959342.43 N 560348.98 E 3.683 143.70 50.32 S 185.80W 5959327.54N 560305.20 E 3.725 189.62 67.96 S 234.90W 5959309.50 N 560256.25 E 4.203 241.56 1380,01 42.200 247,560 1193.22 1305.02 89.35 S 288.71W 5959287.68 N 560202,61 E 6.318 299.37 1471.25 45.800 246.350 1258.84 1370.64 114.18 S 347.01W 5959262.38 N 560144,51 E 4.052 362.70 1562.22 50.620 244,770 1319.45 1431.25 142.26 S 408.73W 5959233.80 N 560083,02 E 5.454 430.50 1652.79 55.970 245.220 1373.56 1485.36 172.93 S 474.51W 5959202.60 N 560017,48 E 5.920 503.09 1746.69 60.950 244.030 1422.67 1534.47 207.24 S 546.79W 5959167.72 N 559945,49 E 5.412 583.09 1842.93 63.380 242.900 1467.60 1579.40 245.26 S 622.91W 5959129.08 N 559869.67 E 2.730 668.15 2125.05 61.930 242.430 1597.19 1708.99 360.33 S 845.52W 5959012.23 N 559647.99 E 0.535 918.55 2406.78 64.220 243.590 1724.76 1836.56 474.29 S 1069.35W 5958896.47 N 559425,10 E 0.892 1169.57 2689,92 62.940 245.760 1850.75 1962.55 582.77 S 1298.51W 5958786.15 N 559196.81 E 0.822 1423.11 2978.93 64.900 247.830 1977.81 2089.61 685.00 S 1537.08W 5958682.00 N 558959.07 E 0.935 1682.52 3261.42 62.900 243.350 2102.14 2213.94 789.72 S 1768.03W 5958575.42 N 558728.98 E 1.590 1936.09 3356.01 61.680 242.580 2146.12 2257.92 827.78 S 1842.62W 5958536.77 N 558654.69 E 1.477 2019.78 3448.69 59.430 243.110 2191.68 2303.48 864,62 S 1914.42W 5958499.35 N 558583.19 E 2.478 2100.43 3539.41 55.710 242.800 2240.32 2352.12 899.42 S 1982.61W 5958464.00 N 558515.28 E 4.111 2176.94 3635.61 53.680 243.650 2295.91 2407.71 934.79 S 2052.70W 5958428.06 N 558445.49 E 2.230 2255.41 Kuparuk 1D Con§hued... 27 August, 1998 - 16:19 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-125 Your Ref: API-500292290400 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl, Azim, Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3733.63 52.440 243.100 2354.82 2466.62 969.90 S 2122.73W 5958392.40 N 558375.74 E 3828.77 50.200 243.310 2414.28 2526.08 1003.38 S 2189.02W 5958358.38 N 558309.72 E 3923.80 48.860 244.180 2475.96 2587.76 1035.36 S 2253.85W 5958325.88 N 558245.15 E 4018.60 46.630 245,230 2539.70 2651.50 1065.35 S 2317.28W 5958295.38 N 558181.96 E 4113.42 44.370 245.410 2606.15 2717,95 1093.59 S 2378.73W 5958266.65 N 558120.74 E 4209.12 41.690 244.660 2676.10 2787.90 1121.14 S 2437.93W 5958238.62 N 558061.76 E 4300.98 39.630 244.720 2745.79 2857.59 1146.73 $ 2492.03W 5958212.60 N 558007.87 E 4398.21 37.100 244.730 2822.01 2933.81 1172.49 S 2546.60W 5958186.40 N 557953.51E 4493.32 34.790 244.910 2899.01 3010.81 1196.25 S 2597.12W 5958162.24 N 557903.18 E 4588.11 32.150 244.440 2978.07 3089.87 1218.60 S 2644.37W 5958139.50 N 557856.11E 4684.09 29.980 244.470 3060.28 3172.08 1239.96 S 2689.05W 5958117.79 N 557811.60 E 4779.98 27.360 242.560 3144.41 3256.21 1260.44 S 2730.24W 5958096.97 N 557770.59 E 4875.40 25.060 241.480 3230.01 3341.81 1280.19 S 2767.46W 5958076.92 N 557733.53 E 4969.68 22.280 241.690 3316.35 3428.15 1298.21S 2800.74W 5958058.64 N 557700.39 E 5158.87 21.210 238.930 3492.08 3603.88 1332.88 S 2861.63W 5958023.48 N 557639.78 E 5346.47 20.760 238.140 3667.24 3779.04 1367.94 S 2918.94W 5957987.95 N 557582.76 E 5535.93 19.540 235.500 3845.11 3956.91 1403.62 S 2973.57W 5957951.84N 557528.41E 5734.91 19.490 234.620 4032.66 4144.46 1441.68 S 3028.06W 5957913.34N 557474.23 E 5795.00 19.490 234.620 4089.30 4201.10 1453.29 S 3044.41W 5957901.60 N 557457.98 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to ~-ell. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ff. Vertical Section is from Well and calculated along an Azimuth of 244.930° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5795.00ft., The Bottom Hole Displacement is 3373.50ft., in the Direction of 244.482° (True). Dogleg Rate (°/lOOft) 1,342 2.361 1.573 2.491 2.387 2,851 2.243 2,602 2.431 2.798 2.261 2.894 2.462 2.950 0.782 0,283 0.803 0.15o 0.ooo Vertical Section (ft) 2333.72 2407.95 2480.23 2550.39 2618.01 2683.31 2743.16 2803.50 2859.33 2911.60 2961.12 3007.10 3049.19 3086.97 3156.82 3223.58 3288.18 3353.67 3373.39 Comment Projected Survey Kuparuk 1D Continued... 27 August, 1998 - 16:19 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D. 125 Your Ref: AP1-500292290400 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 5795.OO Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4201.10 1453.29 S 3044.41 W Comment Tie-on Survey Projected Survey 27 August, 1998 - 16:19 - 4 - DrillQuest .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _. Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ -~me extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 41.9', Pad 70' feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__x Kuparuk River Field 4. Location of well at surface 8. Well number 286' FNL, 599' FEL, SEC. 23, T11N, R10E, UM 1D-125 At top of productive interval 9. Permit number / approval number 1641' FNL, 1784' FWL, SEC. 23, TllN, R10E, UM 98-141 At effective depth 10. APl number 50-029-22904 At total depth 11. Field / Pool 1715' FNL, 1633' FWL, SEC. 23, T11N, R10E, UM West Sak Oil Pool 12. Present well condition summary Total depth: measured 5685 feet Plugs (measured) PBTD tagged @ 5685' MD (01/22/1999) true vertical 4097feet 0~ :' ~ ;~-~ L Effective depth: measured 5685 feet Junk (measured) [ ~' ~'~-~' ~ true vertical 4097 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 121' 16' 200 cubic ft Coldset 121' 121' Production 5008' 5-1/2" 6os sx Arcticset III 5008' 3464' 771' 3-1/2" 425 Sx Class G & 60 Sx AS I 5779' 4186' Perforation depth: measured NONE : ' ; ' ' ' , :; '., . . .: ~ . true vertical ,:' ;: , ~:. :; '.. . . Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg @5006' MD.r.~ ~;.~:~;~~ ~ ~ ~ ~.;. ~ :r:, ~:~ ~ :.:~ ~ ; : : Packers & SSSV (type & measured depth) 5-1/2" x 3-1/2" Baker GBH-22 Packer @ 5006' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: March 22, 1999 16. If proposal was verbally approved Oil__ Gas__ Suspended __ Name of approver Date approved Service: Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Niznik @ 263.4561. Signed ~"~~ ")'1'1 . ~ Title: AAI Wellwork Design & Optimization Supervisor Date 3/, Erin Oba Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: PlugNOtify Commission so representative may witneSSintegdty __ BOP Test ~ Location clearance __ I Appr°val n°'~ Mechanical Integrify Test ~'/ Subsequent torm required 10- ./-~ ~. ~'t~ t,.. ~ ~0'~[.~ r~. ~<~" :J~IGINAL SIGNED-BY t~,,e~o,~. , Robert N. Approved by order of the Commission Chdstenson _C?~missioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-125 Circulation Squeeze Primary Objective Note: Primary objective is to provide isolation between the D, B, and A zones by circulating and squeezing cement across the zones of interest. 1. RU Slickline and drift / tag. 2. RU E-Line. Shoot circulation holes from 5450' - 5452' and from 5094' - 5096'. Run Halliburton EZSV Cement Retainer and set at 5440'. 3. RU CTU. PT coil, BOP's, and hard lines to 4000 psi. Sting into retainer @ 5440'. Pump / circulate 35 bbls cement behind pipe from 5094' - 5452'. Pull out of hole. 4. Wait on cement 3 days. 5. Mill/FCO to retainer at 5440', new PBTD. ,._ ARCO ,a,~ ...... ...... Calculations Chart QHAHTY LITHO PRINTING. ANCHORAGE. AK (907) 5&,¢~743 159-5881 ARCO Alaska, Gas Lift Mandrel/Dummy Valve 1 ¢9004901, OD:4.725) Tubing (0-5017, OD:3.500, ID:2.992) Production (0-5008, OD:5.500, Wt:15.00) NIP (4958-4959, OD:4.550) SBE (5006-5007, OD:4.000) ~rlC. '~' GKA 1D-125 SSSV Type: I NONE Orig Completion: i J Angle e TD: 119 deg e 5795 Reference Log: Ref Log D'~': Last Update: 2~24~99 Last Tag: 15682 TD: 15795 ~i8 I I Last Tag Date: Max H°le Angle: 65 dig ~ 2979 I I Size I ToP I~ttO~ TV~ W~ ........ i Grade i Thread 16.ooo I o ...... I 121 121 62.58 I H-4O I ..... WELDED 5.500 I 0 I 5008 3464 "15.00 I L-80 "'1 BTCM......... 3:500 I 5008 I 5779 4186 9.30 ] L-80 SiZe I Top I B'ott°m J TVD Thread 3.500 j 0 J 5017 J 3~ EUE Vlv Description ID NiP 'DS' NOGO 2.812 SBE BAKER GBH-22 W/12' SEALS 3.000 Production (5OO8-5779, 0D:3.500, Wt:9.30) ,5 4 .3 2 i 1' '1 COILED TUB]NO UN/.T BOP EOU]PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAUS 3. 5000 'PSI4 1/6" HYD~ULIC SLIPS 4, $000 PSI 4 1/6" SHEAR RAMS 5. 50CK)'PSI4 1/6" BLIND RAJAS 5000 PSI 4 1/1~" STUFFING BOX 4 H]REL ]NE BOP EOU ! PHENT I. $000 PSI ?" .WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELIN[ RAMS (VARIABLE siZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" IrLOW TUBE PACK-OFF Slm ! .r, j-sun ri !:! I I_1_ I IM G S I:::: I:! ~/I r- I::: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-125, AK-MM-80324 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22904-00 RECEIVED OCT 2£ 1995 Alaska 0~ ~ ~as ~ons. ~mm~on 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 0 F! I //I I~ I::S SEFI~JICE S WELL LOG TRANSM1TFAL To: State of Alaska October 21, 1998 Alaska Oil and Gas Conservation Cornrn. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-125, AK-MM-80324 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~, Anchorage, AK 99518 1D.-125: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22904-00 2"x 5" TVD Resistivity & Cranarta Ray Logs: 50-029-22904-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia OCT 2_ 998 Alaska O[i ~ ":--~,~.~ ¢~n.~. Commission Anchorqe 5631 Silverado Way, Suite (3 · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 :-QNY KNOWLES, GOVERNOR .~LAS~ OIL A~ND GAS CONSERVATION COMMISSION JuN' 29. 1998 3301 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: 907) 279-1433 =AX: ~07~ 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 .Anchorage, AK 99510-0360 Kuparuk Rivcr [,."nit 1 D- 125 ,ARCO Alaska. Inc. Permit No. 98-141 Sur. Loc. 286'FNL 599'FEL. Scc. 23, T1 IN. RIOE. UM Btmnhole Loc. 1715'FNL. 1633'1%VL Sec. 23. T1 iN. RIOE. UM Dear N'lr. McKav: Enclosed is thc approved application tbr permit to drill thc above referenced well. .Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1 D- 125. Plcasc note that any disposal of fluids generated from this drilling operation which arc pumped down thc surface/production casing annulus of a permitted existing ,,yeti on Drill Site ID must comply xvith thc requirements and limitations of 20 AAC 25.080. .&pproval of this permit to drill docs not authorize disposal of drilling xx'astc in a volume greater than 35.000 barrels through thc annular space of a single xvcll or for a period longer than one year. Thc permit to drill docs not exempt you from obtaining additional permits required by law from othcr governmental agencies, and docs not authorize conducting drilling opcranons until all other required permitting determinations arc made. Bloxvout prevention equipment (BOPE) must bc tested II1 accordance xx'ith 20 .AAC 2! ~)35. Sufficient notice/approx~matcly 24 hours) must bc given to alloy,' a representative or'thc Commission to xvitncss a test of BOPE installed prior to drilling ncxv hole. Notice may be given by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. S' Robert N. Christenson. P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosurcs CC' Department of Fish &Gamc. Habitat Section xv/o cncl. Department of Environmcntal Conscrx'atlon xv/o cnci. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Reddll I lb TypeofWell Exploratory E] StratigraphicTest [] Development Oil Re-Entry DeepenI Service X Development Gas C~ SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 286' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1641' FNL, 1784' FWL, Sec. 23, T11N, R10E, UM 1D-125 #U-630610 At total depth 9. Approximate spud date Amount 1715' FNL, 1633' FWL, Sec. 23, T11 N, R10E, UM 8/4/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-124 5729' MD 1633' @ TD feet 15' @ 100 feet 2560 4133' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 62.68° Maximum surface 1381 psig At total depth 1815 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' +_200 CF 8.5" 5.5" x 15.5# L-80 BTC 5688' 41' 41' 5729' 4133' 608 Sx Arcticset III, 3.5" 9.3# EUE 8rd 425 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet 0 R i Gi[,~IAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°~fdacU;t°' RECEIVED Intermediate Production LinerJUL 17 1998 Perforation depth: measured true vertical A~a$~(a 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements X 21. I her~hat the foregoing is true~ to the best of my knowledge Signed'-~/~~ ~~/~~'" Title'~"~S/h~¢~Sand~s~ea/~~y' Date (,,,\ Commission Use Only Permit Number IAPInumber " IApprovaldate A.,, .,,.~ I See cover letter for ~:~'.,//~',,,2 50- ~_- .~-- ~_~,Z._ ¢~ ~/) '1"'~'" ~' ~ other requirements Conditions of'approval Samples required [- Yes r~l No Mud Icg required E~ Yes J~ No Hydrogen sulfidemeasures [~Yes [~No Directional surveyrequired .~Yes BI No Required workingpressureforBOPEi_J[--~2M j~ aM [~ 5M ~] 10M [~ 15M Other: ORIGINAL SIGNED BY by order of 7""<;~/ /~2g Approved by D..~....., ,,, ,-, ..... Commissioner the commission Date --"" Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor July 16, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-125 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a monobore injection well using a 5 Y2" x 3 ~" tapered casing string, with 3- 1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-125, such as shallow gas. There have been ten (10) Kuparuk wells and (16) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is August 10, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Scott Goldberg Operations Drilling Engineer CC: West Sak 1D-125 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill, Case and Completion Plan for West Sak 1D-125 (H2) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 5 Y2" casing _+1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is close to the surface, a top job may be performed in lieu of utilizing the port collar. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test . Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Before stinging into seal bore, freeze protect well with enough diesel to cover Permafrost. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig. 10. If necessary, rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 11. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 12. Rig up E-line unit and RIH with through-tubing perforating guns. ECE VED 1 D-125 (H2) Page 1 jUL 17 tg S Alaska 0ii & Gas_Cons. Commission 6/98, v.1 13. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 14. Install back pressure valve, shut in and secure well. JUL ]7 i998 Alaska 0il & 8as Cons. Com~ission Anchorage 1 D-125 (H2) Page 2 SG, 07/16/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-125 (H2) Drillinq Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-125 (H2) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D-125 (H2) Page I SG,07/14/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7' ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,524' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3945 ft)(0.46 - 0.11 psi/ft) = 1381 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 5-1/2" 15.5# LB0 BTO casing to be used has a burst rating of 7,000 psi; 7'0 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-125 (H2) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-125 (H2) is WS 1D-124. As designed, the minimum distance between the two wells would be 15.0' at 100' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-125 (H2) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 1 D-125 (H2) Page 2 SG,07/14/98,v.1 West ak 1D-125 (H2)Injector ComP tion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' TAM International 5-1/2" Ported Collar Stnd. Grade BTC Threads set +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 4981' MD / 3431' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 4981' MD / 3431' TVD) to (+/- 5729' MD / 4133' TVD) G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD~Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up I!aker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands TAB, 6/11/98, v.1 created by ~.ch For: BROCKWAY Date plotted: 5-Jun-98 P~o~ Reference is ~J 1D-125/H2 Vers. ~5. Ca~dlnotes ore in feet relerence eot ~125. r~e Medical Depths ore reference RKB (Perker 244.93 AZIMUTH 3198' (TO TARGET) ,**Plone of Proposal*** 300 300 60O 900 1200 1500 1800 2100 2400 27O0 3000 3300 3600 3900 4200 3OO RKB ELEVATION: 111' /A 'R C 0 A1as k aw: Structure : Pad 1D I1:125 Field : Kuporuk River Unlf Location : North Slope, Alas 3300 <- West (feet) 3000 2700 2400 21 O0 1800 1500 1200 900 600 300 0 I I I I I ~ I I I I i I I I I I I I q I ~l?O ~ Az Begin Tur~ ESTIMATED - - _ SURFACE LOCATION: 286' FNL, 599' FEL ~/'EOC SEC. 23, Tl lN, RIOE ff.~/~ Bose Permafrost gin Angle Drop ~ ~p Ugnu Sonds / ./¥~Top West Sok Sonds/ EOD ~.~' ITARGET - West Sok A3 ~ /Base West Sok Sands L~-u"~---/TD - Casing Pt KOP TVD=500 TMD=500 DEP=O 5.00 BEGIN TURN TO TARGET TVD=699 TMD=700 DEP=16 14.58 19.36 24.2,3 29.14 DLS: 5.00 dog per 100 fi 34.08 39.03 45.99 48.95 55.93 EOC TVD=1538 TMD=1776 DEP=624 B/ PERMAFROST TVD=I630 TMD=1976 DEP=801 TO LOCATION: 1715' FNL, 1633' FWL SEC. 23, T11N, RIOE MAXIMUM ANGLE 62.68 DEG BEGIN ANGLE DROP TVD=2272 TMD=3374 DEP=2043 62.03 57.03 52.03 49.53 47.03 44.53 42.03 39.53 T/ UGNU SNDS TVD=2954 TMD=4433 OEP=2841 37.03 34.53 32.03 29.53 27.03 24.53 22.03 T/ W SAK SNDS/EOD TVD=3524 TMD=5081 OEP=3145 TARGET - A3 TVD=3670 TMD=5237 DEP=31 TARGET ANGLE 20 DEG B/ W SAK SNDS TVD=3945 TMD=5529 DEP=5298 TI) - CSG PT TVD=4133 TMD=5729 DEP=3367~'~ TARGET LOCATION: 1641' FNL, 1784' FWL SEC. 23, TllN, RIOE TARGET TVD=3670 TMD=5237 DEP=3198 SOUTH 1355 WEST 2897 DLS: 2.50 dog per 100 ft I 5600 i i i I i I i I iI i I I i I I I Ii I I i I 0 500 600 900 1200 1500 1800 21 O0 2400 2700 3000 3300 Verticol Section (feet) -> Azimuth 244.93 with reference 0.00 N, 0.00 E from slot #125 300 60O 90O 1200 1500 1800 0 I v ~ .nc~ For: BROCKWAY- Dote plotted : 5-Ju.-98 Reference i= ~ 10--125/H2 Vets. ~5, C~d;noles ore ;n teet reference slot ~125. Venice1 Dept~s ore reference RKB (Porker 140 120 10o 40 I_ 'R C 0 Alaska, Structure: Pad lO Well: 125 Field : Kuparuk River Unit Location : North Slope, Alas 1100 ............... 1000 ......................... 900 .......................... 800 <- West (feet) ~ 240 220 200 180 160 140 120 100 80 60 40 20 0 20 40 60 I I I I ¢ I I I f I [ I I I I I I I I I I I I I I 500 ~40 1000 1200 1`300 ~'soo ~20 9OO 500 1100 300 700 1400 100 900 50~ 1600 1700 ~0 500 600 70O 2O0O 1,300 14O0 5O0 8OO 40 2O ~ 2O 0 60 I V 8O 200 1 O0 120 ~"' 140 160 1600 1300 1500 140~ 000 180 200 [~ " /' 220 300/' 240 1100 ./ ./ ./ /' / · /"' 1100...'/'/ ¢00/' /' .,,.'1000 .- 1200 500 20 1100 600 300 ~ 0 2200 ......... '",~'00 20 CD 0 600 .-'~'~00 40 ,300..-' ...~ 500 /- .,.ebo 500 ......... 1000 0 · -I~ -~--. 110 60 .--' 4~-5oo I 8O V -- 1200 500-~-.~. 300 800"~..~ 900 1 O0 1 400'~"""-]\ 000 500 '~ '"%, 11 O0 1 2O X 'x 500 ",, ..___.~ '., 1200 '\ 40 .-'~00 ./ .- 1200// " 2600 /' ." 800 /500 ..~ ' // .' 160( /" ,," _500 160 1 O0 ./ / 500..~ .;/"600 ,,'~-'~00700 800 ....'/'/" 90 0~'"' O0 '~500--- 180 200 ,,' /,," - -- .~500 ,'~'~00 10~_ /,'" ~ 200 ) ,//,,,, J~/,/,,O U /' ~00.~00 ,," //'-7oo /' .... e 2~o 1 oo .,.,' 11oo//' /¢ooTM " (~ 240 .............. 'o 'o 'o 24-0 220 200 180 160 140 120 100 8 ./~/.6 O 40 2 0 2 40 60 <- West (feet) by fm=~ For: BROCKWAY Oote plotted : 5-Jun-98 Reference is ¥~ 10-125/H2 Vers. ~5. C~ord;notes ore in feet reference sIo[ ~125. Ve~ol Oepths ore ref~ence RK~ (P~rker 24O 2OO 16O 120 80 40 "-'" 80 120 -I.-- 0 16o I V 200 240 280 320 36O 4O0 44O 480 52O I 'RCO Alaska, InOq] Structure : Pad lO Well: 125 Field : Kuparuk River Unit Location : North Slope, AloskoJ <- West (feet) 800 760 720 680 640 600 560 520 480 440 400 ,360 520' 280 240 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 I I I I ~2 4OO ""'"'~2500 1700 .............................. 1600 ................... 1500 ............................ 1400 ................ 1300 ............... 900 ............... ~-~-3--' ...................................... ..................................... ~-'~'~'~ ................... 2000~.-- .... ~'400 ........ 3 000 2100 ~ ..-'""'" -'""' ........ ...'"'"fl'~°° ,../' 2200 ~ ..... ~'500 .... /' .., 1 000 ~/" ...... r~oo ...... %200 ,-"'" ,--" 11 O0 .//' ,,'"'~400 ..... . ...... .............. ooy/p ......... /7 ~oo/~ ....... ,. oo. ~.. // /" / / 3~C~6 Z ./ /1,500 '/' i'~00 1100// 4~ ,.// .......... // ,,.'(2oq..-'" 7oo -~:f:::-/"'/'" ///11/1600 i i i i i I i I i I i I i I i i i i Ii I I I i i I I i I i i 800 760 720 680 640 600 560 520 480 440 400 360 ,320 280 240 200 <- West (feet) 240 2OO 180 120 80 40 40 8o L/") 0 12o 160 -4- I 200 V 240 280 320 360 400 440 480 520 c,~ote~ ~ f;n~ For: BROCKWAY Dete olotted: 5-Jun-98 Pl~t Reference is Y~ 10-125/H2 Vers. ~5, Cae~dinales are in feet reference slat ~1125. True Vertical Oept~e ore reference RKB (Parker i~2~3). aska, Inc. Structure : Ped 1D Well: 125 [Field : Kuperuk River Unit Locofion : North Slope, Alosk <- West (feet) Anchorage 2200 2100 2000 t900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 500 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 [ ~00 ~2200 2100 ~ ............. 2000 2o0 ........................ 19oo 18oo ............................... 1700 1 O0 100 20O 300 4OO 50O -4-- Q~ 600 -*- 700 0 80O V 900 1000 .--'%oo 1100 ~'"' 1200 1300 1400 5100 3900 37~,~ 4100 /-'"~ Alaska Oil & ¢~as Cons. Commission 1300 1400 1500 ........ ' 1600 .......... - 1700 ........ - 1800 ........ - 1900 ...................... 2000 ................. 2200~./-'~ 2100 ................ 2300_.,~ 2 oo 2800 17oo 2900 1800 .--" ~ ...-"' ......... ..-~oo 1900~.--"' " ..-"" ..-"~500 2000 ..--" 1500 1 6OO 2100 ..--""" ' ..-" 1600 2200 ..-" '" 1700 .. 2300.......-' ...-"~800 1 500/.;? 1800 ..-'"' .--"'"' ,;;;;;?;;;,,;;-'/" 2400.....-'" ....: ....... ...~'900 ....-' 1600 .;;' 1900 / 1700 1800 '*' 1900 .¢¢~'800 // 2100 2000 200 1 O0 100 2OO 300 400 5OO 600 700 800 9OO 1000 / 1 lO0 ,., / 77oo,,; ,/1500 2800,," 1200 / / 2900 / ., i000,"' 1300 / 00/' 600 0,? 1 1400 5500,," 3800 ,,' 4200 ,,' /" 1500 · "1700 ,? · / 2200 #..,.,,,?'"' ,'?'"'~ 900 2300./;/' 1600 1700 600 700 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 <- West (feet) I V C~ot,~ ~ ,t.~. For: BROCk'WAY 0otc 0lotted : S-Jun-g8 P~ot Re~erence ~s ~ 1D-125/H2 Vers. ~5. Ca~dlnotes are in leer reference stat ~125. r~e Vertical Depths are relate.ce RKO (Perker gO0 ~ 100o --*-- 1100 0 1200 I V as Inc. · Structure: Pad 1D II 125 J Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 100 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 lOO .............. ~ 200 200 300 ............... ~5~- 300 400 .............. ~'-- 400 50O ---~'""~3500 500 ~9003700 [~4~00 600 600 700 700 800 -~ 800 230~ .... ..j~ ........... ..-'%oo 2500 .--' 2700 .--' ............ .- 3100 3300 3700 .-'~" '"' 390t .... --~ ....- 1400 41 O0 .-'"' 1400 1500 .--'"" 1500 .... '%oo ..-/ 2300/, /5'51oo 1800 (:~::'"" 1800 2500#,-'.// 1§0o 2000 ,.."~,./' 2000 !~'53oo 2100 , , , , , , , , , , , , , ~ , , , , , , , ~ , ~ , , , , , ~ , 2100 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 <- West (feet) 900 1000 1100 '-~ 2O0 I V ARCO Alaska In :Structure: Pad 10 I1:125 Field : Kuparuk River Unit Locafion : North Slope, WELL PROFILE DA FA ..... Point ..... UD I~c Oir TVD North Eaat V. S~ct Oeg/100 ~e on 0.00 O. OO270,00 O.O0 0.00 0.0~3 O.OO 0.00 KOP 500.00 O.00 270.0051~0.00 O.130 O.O(~ 0.O0 0.~ Been Turn to Tar§et 700.00 10,00 270.00698.990.(~ -17.41 15.77 End of Build/Turn 1776.01 62.65 244.001538.31 -226.47 -552.6062Z~.67 5.0~ End cf Ho!d 3.373.9162.66 244,002271.59 -648.93 -1856.58 2043.20 O.0~ End of Orcp/Tum5081.25 20.00 244.003524.00 -1332.03 -2848.92 3144.94 2.5(1 Target WS 1D-H2 Rvad 2 5236.62 20.00 244.005670,00 -I,].55,55 -2696.68 3196.07 O.0~ End of Hold 5529.27 20.00 244.005945,00 -1399.21 -2986.64 3295.15 O.0~ 0. & End of Hold 5729.27 20.00 2~!..00 4132.94 -1429.20 -.504§.11 3366.54 O.0~ TRUE NORTH 0 330 350 10 340 ~,~,~,,, 20 320 510 300 Created by finch For: BROCKWAY Dote ploffed: 5-dun-~8 Plot Reference is V/S 10-125/H2 Vets. i~5. Coordinetes ore in feet reference slot fl25. True Vertical Depths ore reference RKB (Parker ~245), 1100 100 1100 100 29O 280 ~00 8O 27O 90 260 ~oo~ O0 250 240 · 220 / / / / / ,,,"21 o i1700 120 50_0 700 )11 O0 '---. 500 200 ~1 1 60 n~d 90 180 170 Normal Plane Travelling Cyli er - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 125 slot #125 Kuparuk River Unit North Slope, Alaska 3~D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref = WS 1D-125/H2 Vets. #5 Our ref = prop2200 ~icense = Date printed = 5-Jun-98 Date created = 16-Apr-97 Last revised ~ 5-Ju~-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 17 58.503,w149 30 36.370 Slot Grid ooord/nates are N 5959378.698, E 560490.285 Slot local coordinates are 286.00 S 599.00 W Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Report is limlted to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path PMSS <556-7024'>,,9,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <0-8610'>,,6,Pad 1D P~MS <O-8930~>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <O-9783'>,,2,Pad 1D PGMS <O-8365~m,,1,Pad 1D 1D-D Version #2,,1D-D,Pad 1D 1D-F Version #2,,1D-F,Pad 1D 1D-B Version #3,,1D-B,Pad 1D TOTCO SuL-vey,,WS-8,Pad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D WS 1D-158/L11 Vets. #1,,158,Pad 1D WS 1D-141/A11 Vers. #1,,141,Pad 1D WS 1D-142/B10 Vets. #1,,142,Pad 1D WS 1D-140/A9 Vers. #1,,140,Pad 1D WS 1D-139/B8 Vets. #1,,139,Pad 1D WS 1D-143/C9 Vets. #1,,143,Pad 1D WS 1D-144/D8 Vets. #1,,144,Pad 1D WS 1D-145/Cll Vets. #1,,145,Pad 1D WS 1D-146/D10 Vets. #1,,146,Pad 1D WS 1D-147/E9 Vets. #1,,147,Pad 1D WS 1D-148/E11 Vets. #1,,148,Pad 1D WS 1D-149/F8 Vets. #1,,149,Pad 1D Closest approach with 3-D Last revised Distance 29-Apr-98 150.0 6-Nov-97 197.0 13-Nov-97 77.0 13-Nov-97 42.5 4-Aug-92 162.2 4-Aug-92 283.0 4-Aug-92 402.8 10-Dec-97 522.6 24-Nov-97 62.0 24-Nov-97 181.1 24-Nov-97 92.0 21-May-98 312.9 27-May-98 257.0 27-May-98 333.5 27-May-98 180.0 27-May-98 182.9 27-May-98 178.4 15-Apr-97 178.0 15-Apr-97 186.9 15-Apr-97 192.0 15-Apr-97 198.1 15-Apr-97 205.2 15-Apr-97 213.0 15oApr-97 221.6 15-Apr-97 230.9 Minimum Distance method M.D. Diverging from M.D. 120.0 : 120.0 .f 440.0 440.0 20.0 600.0 300.0 300.0 600.0 600.0 20.0 600.1 420.0 420.0 575.0 575.0 575.0 575.0 600.1 600.1 575.0 575.0 1016.4 1016.4 550.0 550.0 260.0 260.0 260.0 260.0 300.0 300.0 360.0 360.0 260.0 260.0 400.0 400.0 SO0.O 500.0 300.0 300.0 400.0 400.0 500.0 4366.7 300.0 300.0 500.0 500.0 w$ 1D- 152 WS 1D- 150 WS 1D- 153 WS LD- 154 WS 1D-155 WS WS 1D- 157 WS 1D- 159 WS 1D- 160 WS 1D-161 WS 1D- 138 WS 1D- 151 WS 1D- 107 WS 1D- 102 WS 1D-103 WS 1D- 104 WS 1D- 101 WS 1D- 108 WS 1D- 110 WS 1D- 111 WS 1D- 112 WS 1D- 113 WS 1D- 114 /G9 Vers. #1,,152,~, 1D IF10 Vets. #1,,150,Pad 1D /H10 Vets. #1,,153,Pad 1D /Jll Vets. #1,,154,Pad 1D IH8 Vets. #1,,155,Pad 1D ~J9 Vets. #1,,156,Pad 1D 'K10 Vets. #1,,157,Pad 1D ~L9 Vets. #1,,159,Pad 1D 'KS Vets. #1,,160,Pad 1D 'L7 Vets. #1,,161,Pad 1D 'K6 Vets. #1,,138,Pad 1D 'Gll Vets. #1,,151,Pad 1D 'B4 Vets. #1,,107,Pad 1D /AS Vets. /B6 Vets. /AT Vets ;C5 Vets ~A3 Vets ~C3 Vets /B2 Vets /Al Vets ~C1 Vets ~D2 Vers #3,,102,Pad 1D #3,,103,Pad 1D #3,,104,Pad 1D #3,,101,Pad 1D #4,,108,Pad 1D #4,,110,Pad 1D #4,,111,Pad 1D #4,,112,Pad 1D #4,,113,Pad 1D #4,,114,Pad 1D WS 1D-116~E1 Vets. PMSS <0-5047'>,,124,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <381-6092'>,,105,Pa~ 1D PMSS <0-5126'>,,106,Pa~ 1D #4,,116,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <0-5205'>,,117,Pa~ 1D PMSS <0-5142 >,,liS,Pad 1D PMSS <0-4590 >,,ilS,Pad 1D PMSS <0-4515 >,,119,Pad 1D PMSS <0-4530 >,,120,Pad 1D PMSS <0-4414 >,,121,Pad 1D PMSS <0-5462 >,,129,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D WS 1D-128/K2 Vers. #3,,128,Pa~ 1D WS 1D-131/L3 Vets. #3,,131,Pad 1D WS 1D-132/K4 Vets. #3,,132,Pad 1D WS 1D-134/L5 Vers. #3,,134,Pad 1D WS 1D-123/G1 Vers. #4,,123,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D WS 1D-122/F2 Vers. #4,,122,Pa~ 1D 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 2-Ju~-98 2-J%u~-98 2-Jun- 98 2-Jun-98 2-Jun-98 2-jun-98 2-Jun- 98 2-Jun-98 2-Jun-98 2-JLu~-98 2-Ju~-98 2-Jun- 98 2-Jun-98 2-Ju~-98 2-Jun-98 2 - JLul- 98 2-J%u~- 98 2-Ju~-98 2-Jun- 98 2-Jun-98 2-Jun-98 28-Apr-98 27-May-98 1-Jun-98 27-May-98 27-May-98 27-F~ay-98 2-Jun-98 27-May-98 5-Jun-98 261.8 240.7 273.0 284.5 296.4 308.5 320.9 346.3 359.2 372.3 287.0 251.0 373.0 463.0 448.0 433.0 478.0 360.0 330.0 315.0 270.0 255.0 240.0 210.0 15.0 119.9 239.5 162.1 419.5 390.0 345.0 195.0 225.0 179.3 135.0 120.0 105.0 104.3 270.0 30.0 45.0 135.0 150.0 225.0 74.0 15.0 90.0 400.0 300.0 300.0 300.0 400.0 300.0 300.0 260.0 300.0 300.0 320.0 300.0 300.0 280.0 280.0 280.0 28O.0 28O.0 280.0 280.0 300.0 280.0 260.0 380.0 100.0 420.0 600.1 340.0 280.0 100.0 100.0 100.0 180.0 4~o.o 100.0 100.0 100.0 300.0 100.0 240.0 500.0 240.0 240.0 300.0 460.0 300.0 380.0 400.0 300.0 300.0 300.0 400.0 300.0 300.0 260.0 300.0 300.0 320.0 5162.1 300.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 300.0 280.0 260.0 380.0 100.0 420.0 600.1 340.0 280.0 100.0 100.0 100.0 180.0 460.0 100.0 100.0 100.0 300.0 100.0 240.0 500.0 240.0 240.0 300.0 460.0 5729.3 380.0 .)" DIVERTER SCHEM. .TIC Kuparuk River Unit West Sak Operations DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20" - 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line Will Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20"-2000 psi Annular Preventer i~ E E!V ~ b Alaska 0il & Gas Cons, Commission Anchorage TAB, 06/12/98, v.2 .... -5/8" 5000 psi BOP St Kuparuk River Unit West Sak Operations -Injector Wells 5 4 3 2 I 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.2 DESCRIPTION PER ~-~,:~tJl K98017A CS O£SCRIPTION NO TES I. COORDINATES SHOWIV ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATIONS 5H014¢1 ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWIV ARE TRUE. 2.. BASIS OF LOCATIONS AIvD' ELEVATIONS ARE D,S. 1-D MONUMENTS PER LHD AND ASSOCIATES. $. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 23. TOWNSHIP 11 NORTH. RANGE 10 EAST, U.M. 4. DATES OF SURVEY: 6/9/98, FIELD BK. LgB-45, PCS. 21-25; AND 6/I2/98, FIELD BK. L98-45, PCS. 47-48. 5. DRILL SITE l-O GRID NORTH IS ROTATED 00' 01' 05" I/FEET FROM A.S.P. ZONE 4 GRID NORTH. 6. 5ES DRAWING NSK-.7.5'I FOR AS-BUILT LOCATIONS OF CONDUCTORS I-8; CEA-DIOX-6104DIO FOR CONDUCTORS 105,106,109,115, I 17-12I, 124,129,130,13..7 & 1.:75; AND CEA-DIDX-6104DI3 FOR CONDUCTORS 9 & I0. lB WEST SAK-1 THIS SURVEY VICIN! TY MA P SCALE: 1" = I MILE INo. 125 I26 127 128, 132 Sec. 23, T. 11 N., R.!.0 E. Y X Lot. Long. 5,959,,779.35 5, 959, 36.7. 92 5,959,,748.96 5,959,,7.74.14 5,959,244. 05 5, 959, 229. 2,7 5, 959,153. 84 560, 490. 59 560, 490. 68 560, 490. 67 560, 490. 58 560, 490. 74 560, 490. 64 560, 490. 8,3 70' 70' 17' 58.358' 70' 17' 58.210" 70' 17' 58. 065' 70" 17" 57.179'" 70' 17' 57. 70" 17' 56.291'" 149' JO' 36.361" 149' JO' 36.362" 149' JO' J6. J66' 149' ..,TO' J6.`772" 149' ,70' ..76.389'" 149' JO' .76..795' 149' .30' ..76.407' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND TH,4T ALL DIMENSIONS ,4ND OTHER DETAILS ARE CORRECT AS OF JUNE 13, 1998. % ARCO Alaska, Inc. LOUNSBURY & ASSOCIATES. INC. E,~NEERS PLANNERS SURVEYORS AREA' l0 MODULE' XX DRILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-BUILT LOCATIONS CEA-D1DX-6104D15 ISHEET:2 OF 2 ]REV: UNIT · D1 REV DATE BY CK APP ~ _ OESCRIPTION REV ~/_r' CPF, I · I _ , 105 2 i ~o~ . ~ SUR~ 111 ~ ~s e ''~ ~ ~ ! ~CINI~ MAP 117 ~ ~8 ~ 4 ~ SCALE: 1"= I MILE 120~ 119 122T 121 125 . 'i 127J 126 128 I Q 6 ; j 12g ~0~~ 132 Q 7 , ; ~. LEGEND SEE SHEET ~ 2 FOR NOTES ~0 LO~TION INFORMATION o EX~SF~NO CONOUCFO~S ~ LOUNSBURY ~ '~S-aU~L r CONOUCFO~ LOCA DON~'~'~/J) ~ e ASSOC~BS. INC. AREA' 1D M~ULE XX UNIT' ~ DRILL Sl~ 1-D ARCO Alaska, Inc. ~ST SAK PHASE lB - ~LL CONDUCtoRS AS-CUreT oc o.s LK6104015 6/15/98 CEA-D1DX-610~15 1 OF 2 1 · WELL PERMIT CHECKLIST FIELD & POOL L.{ 0[ O ,/¢,- (.3 COMPANY ~ V'(. r,..O WELL NAME \~. ¢,,,L,~ I i~ -t ~,~ ~- PROGRAM: exp [] dev [] redrll [] serv I~wellbore seg Il ann. disposal para req II INIT CLASS ~ g' ~¢~ 1 ~ t/~,3 GEOL AREA ~ O~(.) UNIT# I I I (o ¢J ON/OFF SHORE d) ~'1 ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17· CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved· . . 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... ~'1 N 24. Drilling fluid program schematic & equip list adequate ..... )'~ N 25. DOPEs, do they meet regulation ................ ~'l N APPR DATE 26. DOPE press rating appropriate; test to ~O~O psig. ~'1 N (:1~ '~P,~I~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~'~ N 28. Work will occur without operation shutdown ........... ~'~ N 29. Is presence of H2S gas probable ................. Y,...) N // GEOLOGY ~. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31· Data presented on potential overpressure zones ....... Y ,.N'" 32. Seismic analysis of shallow gas zones· . ........... /Y-/N ~,,~ 34. Con, tact.nam, e/phon,e.for weekly progress reports ........ .." Y N i~/ AT 33. Seabed condition survey (if off-shore) ............. /Y N ?/D~ lexp,ora,oryon,y, ---- IIA--~L~L ~.. With proper cementing records, this plan -~ -- (A) will contain waste in a suitable receivin__q.zgne; ....... Y N "APPR DATE (B) will not contaminate f~se drilling waste . . . Y N ~o'7 ~¢,__~bt]~ ,'~-~"'~ ~,-.~6z~_-/--. -,. L~i~_.'..% t.,~..:'Ii~-L.~ ~)'C to..s~to surface' - (C) Will--n/cai integrity of the well used for disposal· Y N ~11 not damage producing formation or impair recovery from a Y N ~ pool; and .... -'. L~,leas~%~9,~ot¢ that an)-disposal of'fluids genera, ted from this d~:illing operation (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N which are pumped down thc surface/production casing armulus ora permitted existing well on G EOI..~jG¥: ENGINEERING: UIC/Annular COMMISSION: JDH_~-'~''' . RNC co -~.~-~5- M:chel~list rev 05/29/98 dlf: C:\rnsoffice\wordian\diana\checklir;I Drill Site I-D must comply, with thc rcquiremcnts and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a period longer than one year.~ 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. Sperry-Sun Dril~ ~ 'g Services LIS Scan '~. ±ity Tue Oct 13 13:07:09 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SA/<) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 1 AK-MM-80324 P. SMITH F. HERBERT 1D-125 500292290400 ARCO ALASE3~, INC. SPERRY-SUN DRILLING SERVICES 13-0CT-98 MWD RUN 2 A_K-MM- 80324 P. SMITH F. HERBERT 23 liN 10E 286 599 .00 111.90 7O .3O OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING , 3RD STRING PRODUCTION STRING REMARKS: 8 · 500 5795 . 0 '~- ~ 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. MWD IS PDC. 3. MWD RUNS 1 & 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. WELL 1D-125 REACHED A TOTAL DEPTH OF 5795'MD, 4201'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDD = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 83.5 5757 0 RPM 83 5 5757 0 RPS 83 5 5757 0 RPX 83 5 5757 0 GR 91 5 5764 5 FET 121 0 5757 0 ROP 123 0 5795 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3506.0 2 3506.0 5795.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 83.5 8 6006 0 6708 0 7286 0 7913 0 3393 10 3428 0 0702 First Max Mean Nsam Reading 5795 2939.25 11424 83.5 144.317 72.1901 11347 91.5 2000 56.9772 11348 83.5 2000 61.6966 11348 83.5 2000 67.5381 11348 83.5 2000 80.7831 11348 83.5 876.729 296.359 11345 123 16.4584 0.362971 11273 121 Last Reading 5795 5764.5 5757 5757 5757 5757 5795 5757 First Reading For Entire File .......... 83.5 Last Reading For Entire File ........... 5795 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLTMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 83.5 83 5 83 5 83 5 91 5 121 0 123 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3467.5 3467.5 3467.5 3467.5 3475.5 3467.5 3506.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AATD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 07-AUG-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3506.0 121.0 3506.0 .0 64.9 TOOL NUMBER P1067CRG6 P1067CRG6 8.500 8.5 LSND 9.50 283.0 8.4 350 4.8 MUD AT MEASURED TEMPF-~TURE (MT): MUD AT MAX CIRCULATIi £ERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 4.270 6.300 5.500 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 API 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 83.5 8 6006 0 6708 0 7286 0 7913 0 3393 39 9848 0 0764 Max Mean Nsam 3506.5 1795 6847 138.234 67.8651 6769 2000 88.7878 6769 2000 96.528 6769 2000 106.611 6769 2000 128.674 6769 622.517 304.918 6768 0.9752 0.228861 6694 First Reading 83.5 91.5 83.5 83.5 83.5 83.5 123 121 Last Reading 3506.5 3475.5 3467.5 3467.5 3467.5 3467.5 3506.5 3467.5 First Reading For Entire File .......... 83.5 Last Reading For Entire File ........... 3506.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LQ Nextr File Name ........... S £B. 003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3468.0 3468 0 3468 0 3468 0 3468 0 3476 0 3507 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 5757 5764 5795 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 5757 0 5757 0 5757 0 5757 0 0 5 0 09-AUG-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 5795.0 3506.0 5795.0 19.5 55.7 TOOL NUMBER P1067CRG6 P1067CRG6 8.500 8.5 LSND 9.50 MI/D VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (0HMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MLrD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 200.0 8.4 350 .1 2.500 1.810 2.700 1.750 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 36.5 Name DEPT GR RPX RPS RPM RPD ROP FET Min 3468 28.833 1 4883 1 5288 1 5186 1 5158 10 3428 0 0702 First Max Mean Nsam Reading 5795 4631.5 4655 3468 144.317 78.585 4578 3476 101.675 9.95272 4579 3468 84.4614 10.2064 4579 3468 79.0574 9.77712 4579 3468 81.8211 9.98786 4579 3468 876.729 283.702 4577 3507 16.4584 0.559025 4579 3468 Last Reading 5795 5764.5 5757 5757 5757 5757 5795 5757 First Reading For Entire File .......... 3468 Last Reading For Entire File ........... 5795 File Trailer Service name ............. ? LIB.003 Service Sub Level Name..., Version Number ........... 1.0.0 Date of Generation ....... 98/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File