Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
198-113
( Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 1 , 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 REC' E 1\ 'E- r') . § 1_." ..~,.. JUN 0 72004 Alaska Oil & Gas COilS. Conl:~'":Ss¡C;¡ Anchorage Subject: Well Completion Report for 2N-345 (APD # 198-113/304-041) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the Kuparuk well 2N-345. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, \ ~ <.~ \ L--- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RE(~E\VEJ.) ( STATE OF ALASKA If JUN 0 1 ~LGÜ4 ALASKA OIL AND GAS CONSERVATION COMMISSION mission WELL COMPLETION OR RECOMPLETION REPQB1bmfDCf.ro~rn¡~ ' Oil 0 Gas U Plugged 0 Abandoned [2] Suspended 0 WAG 0 1b. Well c'asl~m,\\~': ::~,~ 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 No. of Completions - Other - Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 1a. Well Status: GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: At Top Productive Horizon: 5911866 5911423 5911427 5. Date Comp., Susp., or Aband.: May 6.2004 6. Date Spudded: July 7, 1998 7. Date TD Reached: July 15, 1998 8. KB Elevation (ft): 28' RKB, Pad 121' 9. Plug Back Depth (MD + TVD): 5458' MD I 3837' TVD 10. Total Depth (MD + TVD): 7432' MD / 5633' TVD 16. Property Designation: ADL 375074 ,/ 198-113 / 304-041 13. API Number: 50-103-20264-00 14. Well Name and Number: ~ 144' FNL, 1113' FEL, Sec. 3, T9N, R7E, UM 2N-345 607' FNL, 268' FWL, Sec. 3, T9N, R7E, UM 15. Field/Pool(s): Kuparuk River Field Tam Oil Pool 600' FNL, 267' FWL, Sec. 3, T9N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460479 y- TPI: x- 456578 y- Total Depth: x- 456576 y- 18. Directional Survey: Yes 0 NoL::J Total Depth: 21. Logs Run: 22. CASING SIZE 16" WT. PER FT. 62.5# 29.7# 15.5# 9.3# GRADE H-40 L-80 L-80 L-80 7.625" 5.5" 3.5" Zone- 4 Zone- 4 Zone- 4 11. Depth where SSSV set: Landing Nipple @ 531' 19. Water Depth, if Offshore: N/A 17. Land Use Permit: ALK 4293 20. Thickness of Permafrost: feet MSL 1050' MD CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 2789' 28' 2306' 28' 6762' 28' 4963' 6750' 7255' 4951' 5456' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" 9 cu yds High Early 9.875" 40 sx ASIIILW, 240 sx Class G 6.75" 42 bbls Class G 6.75" included above 24. cement retainer @ 6950' MD TUBING RECORD DEPTH SET (MD) n/a none 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): peris squeezed off 26. Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure press. 27. psi SIZE n/a PACKER SET ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6825'-6933' 2.5 bbls 25. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Abandoned GAS-MCF Production for OIL-BBL CHOKE SIZE IGAS-Oll RATIO WATER-BBL Test Period --> Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 24-Hour Rate -> CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none", ~~9 ~ Cf\l\ c. bi°'-\ m~~ ~ '( It ú-~'< NONE RItIiS 8ft Form 10-407 Revised 12/2003 P~A j"¿:':>':::7;~Tf!ëiT1 . OoS::..",.~-~.~ I --_Á~ ,¡ .~J~-., '., ~ AUM 1 4 1001\ CONTINUED ON REVERSE C)Q'G1NAL GF 28. 29. { GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". n/a N/A RE.CE\\lED j\)~ 0 1 L\)\1~ I\.\as\a Gi\ & Gas C.O\\~, I:,\\¡(\(\,¡SS\\\\\ ~"t"o~~Iið~ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed N~ " - R~~dV Thomas Signature \ ~ " ~ Title: P~one Kuparuk Drilling Team Leader 2..~ )6 8 Sù Date 6 (, (D r Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 ~ ConocoPhillips Alaska, Inc. 2N-345 API: 501032026400 SSSV Type: NIPPLE NIP (531-532, OD:3.500) TUBING (0-6762, 00:3.500, 10:2.992) :>ROOUCTION (0-6762, 00:5.500, Wt:15.50) SLEEVE-C (6652-6653, 00:3.500) TUBING (6006-6762, 00:3.500) Gas Lift MandrelNalve 1 (6701-6702, NIP (6755-6756, OD:3.500) SEAL (6762-6763, 00:5.500) LINER (6762-7255, 00:3.500, Wt:9.30) Retainer (6950-6951, 00:3.500) Perf (7054-7072) Perf (7078-7085) Perf (7105-7145) SHOE (7254-7255, OD:3.500) - ~ I.... Annular Fluid: DSUSW 7.1/8.5 ppg Reference Log: Last Tag: 7151 Last Tag Date: 3/14/2004 Casing String - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7054 - 7072 5255 - 5273 7078 - 7085 5279 - 5286 5306 - 5346 7105 - 7145 Size 16.000 7.625 5.500 3.500 { Well Type: PROD Orig 7/19/1998 Completion: Last W/O: Ref Log Date: TD: 7432 ftKB Max Hole Angle: 59 deg (ã) 2755 Top 0 0 0 6762 Bottom 6762 TVD 4963 KRU 2N-345 Zone Status Ft SPF 18 4 7 4 Angle (â> TS: deç¡ (éi) Angle @ TD: 0 deg @ 7432 Rev Reason: Pull OV, Chemical TBG cut Last Update: 3/20/2004 Bottom 108 2789 6762 7255 TVD Wt Grade Thread 108 62.58 H-40 WELDED 2306 29.70 L-80 BTC 4963 15.50 L-80 MOD 5456 9.30 L-80 EUE Wt I Grade I Thread 9.30 L-80 EUE 40 4 Date Type Comment 2/14/1999 APERF 21/2" HC, DP, 60 deg. phase 2/14/1999 APERF 21/2" HC, DP, 60 deg. phase 7/21/1998 IPERF 21/2" HC, BH, 180 PH, 90 ORIENT Gas Lift.. MändrelslValves St I MD I TVD I Man I Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date I Vlv 1 6701 4902 CA~~O KBG CAMCO OV 1.0 INT 0.000 0 3/1~~~04 C~~t 1. 1/2 OF OV PULLED, BROKE APART Other(plugs,i.éQulp.,".etc:J).;¡JEWELRY Depth TVD Type 531 531 NIP 6006 4241 TBG CUT 6006 4241 TUBING 6652 4853 SLEEVE-C 6755 4956 NIP 6762 4963 SEAL 6950 5151 Retainer 7254 5455 SHOE Description ID 2.875 2.992 2.992 2.813 2.750 2.985 0.000 2.985 CAMCO 'DS' NIPPLE CHEMICAL TUBING CUT (PRE-WORKOVER) 3/15/2004 ORIGINAL COMPLETION BAKER CMU - CLOSED 9/26/2000 CAMCO 'D' NIPPLE BAKER 5.5" CASING SEAL ASSY. 80-40 EZSV CEMENT RETAINER, set 3/6/2004 Note Cut parafin 200' - 1700' ,I \ 3N-345 Well Events Summary Date Summary 02/26/04 GAUGED TBG TO 2.72" TO 7151' RKB, NO PROBLEMS. DISPLACED TBG WI DSL & PERFORMED INJECTIVITY TEST. PUMPED 25 BBL EACH @ 2 BPM/1550 PSI, 3 BPM/1700 PSI, 4 BPM/1800 PSI. 0 [Tag] 03106/04 SET EZSV CEMENT RETAINER AT 6950' RKB. USED MICRO SMART ELECTRONIC TIMING DEVICE TO SET. (TIED INTO 2.75 D NIPPLE FOR CORRECTION.) SBHP AT 6950' MD IS 3151 PSI. TEMPERATURE IS 133 DEGREES.D [Pressure Data] 03/12/04 TAGGED EZSV AT 6933' CTMD PUMPED 12.5 BBLS THRU EZSV THEN LAYED IN 2.5 BBLS ACROSS THE TOP LEFT TOP OF CEMENT AT 6825'CTMD THE WELL WAS LEFT SHUT IN AND ¡/ FREEZE PROTECTED FROM 2500' WITH SLICK DIESELD [Cement-Poly Squeeze] 03/13/04 CARRY-OVER FROM LATE NIGHT PREVIOUS DAY 03/14/04 MITTBG TO 1589 PSI, AFTER 30 MIN TBG @ 1519 PSI (GOOD TEST) IA/OA HELD @ 800 PSI & 120 PSI, TAGGED CEMENT PLUG W/2.73" GR @ 6858' RKB, BLED TBG/IA/OA TO 0 PSI, ATTEMPT TO OPEN CMU UNSUCESSFULL, PULLED OV @ 6701' RKB (VALVE CAME APART 1/2 RETRIEVED), PUMPED 205 BBLS SW, 5 BBLS DIESEL @ 4 BPM DOWN TBG, PUMPED 52 BBLS DIESEL @ 4 BPM DOWN lA, U-TUBE TBG/IA TO Ea. LEFT WELL LOADED WITH SEAWATER W/DIESEL CAP IN BOTH TBG AND IA TO 2500' RKB. DRIFT TBG W/10' X 2.7" TO 6000'. WELL IS READY FOR ElL CHEM CUT. 03/15/04 CHEMICAL CUT TUBING AT 6006' USING 25/8" CUTTER ASSY. FIRED STRING SHOT PRIOR TO CUTTER TO CLEAN PIPE. TOOLS SAT DOWN EARLY AT 2300' - FINALLY FIRED AFTER REMOVING TWO CENTRALIZERS. TAGGED TOC AT 6855'. BLEEDING LOW PRESSURE GAS FROM WHE BETWEEN RUNS. 05/22/04 DUMMY GUN DRIFT TO 8053' SLM. 1" SOY NOT IN GLM #3. SET 1" DGLV. PT TBG/CSG TO 2500 PSI. GOOD TEST. [Fish, GL V] \ ~' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7fT/1998 End: Group: 513/2004 07:30 - 09:00 1.50 MOVE DMOB DEMOB 09:00 - 00:00 15.00 MOVE MOVE DEMOB 5/4/2004 00:00 - 07:30 7.50 MOVE MOVE MOVE 07:30 - 10:30 3.00 MOVE RURD MOVE 10:30 - 12:00 1.50 WELCTL NUND DECOMP 12:00 - 13:00 1.00 WELCTL NUND DECOMP 13:00 - 14:30 1.50 WELCTL OTHR DECOMP 14:30 - 16:00 1.50 WELCTL CIRC DECOMP 16:00 - 17:00 1.00 WELCTL NUND DECOMP 17:00 - 17:30 0.50 WELCTL NUND DECOMP 17:30 - 20:00 2.50 WELCTL NUND DECOMP 20:00 - 00:00 4.00 WELCTL NUND DECOMP 5/5/2004 00:00 - 01 :00 1.00 WELCTL NUND DECOMP 01 :00 - 03:30 2.50 WELCTL OTHR DECOMP 03:30 - 08:30 5.00 WELCTL BOPE DECOMP 08:30 - 10:00 1.50 RIGMNT RSRV DECOMP 10:00 - 10:30 0.50 WELCTL NUND DECOMP 10:30 - 12:00 1.50 ABANDf\ WLHD DECOMP 12:00 - 13:00 1.00 ABANDf\ CIRC DECOMP 13:00 - 13:30 0.50 ABANDf\ RTRV DECOMP 13:30 - 14:30 1.00 ABANDf\ OTHR DECOMP 14:30 - 15:00 0.50 ABAND£\ OTHR DECOMP 15:00 - 20:30 5.50 ABANDf\ RTRV DECOMP 20:30 - 00:00 3.50 WELCTL NUND DECOMP 5/6/2004 00:00 - 01 :15 1.25 WELCTL NUND ABANDN 01 :15 - 01 :30 0.25 LOG SFTY ABANDN 01:30 - 03:15 1.75 LOG ELOG ABANDN 03:15 - 06:00 2.75 LOG ELOG ABANDN 06:00 - 06:30 0.50 RIGMNT RSRV ABANDN 06:30 - 08:15 1.75 WELCTL EaRP ABANDN 08:15 - 09:00 0.75 WELCTL BOPE ABANDN 09:00 - 11 :30 2.50 DRILL PULD PROD 11 :30 - 12:00 0.50 DRILL OTHR PROD 12:00 - 16:30 4.50 DRILL PULD PROD 16:30 - 17:30 1.00 DRILL CIRC PROD 17:30 - 18:30 1.00 DRILL DEaT PROD Move rig off well 2T -218 and move to end of pad. Perform welding operations in cellar. Clean well site. Move off pad @ 09:00 hrs 5/3/2004 Move rig from 2T pad to 2N pad. Stop @ 23:00 hrs and check lug bolts. Wait at 2 mile turnoff from 17:30 hrs to 18:30 hrs for crew change. Check lug bolts @ 00:45 hours. Continue moving to 2N. Stop every mile tro check lug nuts. Pull onto pad @ 04:45. Pull over well @ 06:00 and line up. Spot sub Rig up tarps and handi-berm. Hang riser. Run comm line from camp to rig. Spot cuttings tank. Accept rig @ 10:30 hrs 5/4/2004. Pull VR plugs. N/U flanges on annulus valves RlU lubricator and pull BPV RlU to displace freeze protect from well. Take on water for rig pits Displace freeze protect from well Blow down and rig down circulating equipment. Pull tree cap Install two-way check N/D tree and adapter flange. Remove tree from cellar for shipping Remove adapter spool from BOPE. N/U BOPE and riser Finish N/U riser Change saver sub to 2-7/8" AOH. Remove grabber and install cylinder shim Body test BOPE and test all BOPE to 250/5000 psi-annular 250/3500 ps. Jeff Jones, AOGCC, waived witnessing BOP test. Cut and slip drilling line Pull two-way check M/U landing joint and screw into hanger. Pull hanger. Pulled tight 20' up. Pump 35 bbl water and displace well wi mud UD landing jt. and tubing hanger RlU floor to stand back 3-1/2" tubing and service rig Put rig on highline power @ 15:00 hrs 5/5/2004 POOH wi 3-1/2" production tubing and stand back in derrick. Recovered hanger wi pup (3.40'), 191 jts of tubing (5959.14'), 1 cut jt. (14.36'), "D" nipple (1.58'). RKB to LLDS=26.30' Top of fish @ 6004.78' R/U and bleed off 9-5/8" x 5-1/2" annulus. Change out 5-1/2" packoff Finish changing 5-1/2" packoff. Test to 5000 psi-OK. Set wear ring RlU e-line and hold safety meeting. RIH wi 4.812" gauge ring and junk basket to 5950' POOH M/U Baker K-1 CIBP and RIH. Set @ 5458' wlm. POOH and RID e-line Set make-up torque on top driVe to 5700 ft-Ibs. Set drilling torque limit @ 5200 ft-Ibs Pull wear ring. Change bottom PR's to 2-7/8" and install test plug Test door seals to 3500 psi and pull test plug. Set wear ring M/U BHA #1: mills DC's, xo's and HWDP Change handling tools to 2-7/8" d.p. P/U 2-7/8" d.p and RIH. Tag @ 5451' dpm Circ and condition mud. P/U= 73k, S/O= 50k,Rot=53k, Torque= 4200 ft-Ibs, 4 bpm @ 2200 psi RlU and test casing to 3500 psi for 30 minutes. Pressure to 3240 psi in 30 minutes. Test bottom PR's to 250/3500 psi wI casing test v Printed: 5/26/2004 3:58:39 PM y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 4,2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we1l2N-345 (PTD 1981130). The request regards a plug and abandon in preparation for a sidetrack. Please call Marie McConnell or me at 659-7224, or Guy Schwartz at 265-6958 if you have any questions. Sincerely, 7~éDqj Jerry Dethlefs Problem Well Supervisor Attachments RECEfVED FEB 0 9 2004 Alaska Oil & Gas Cons.,Cmnmission Anchorage O~\G\NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D 1. Type of Request: 0 D D Suspend D Repair well D Pull Tubing D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 149' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7432' 5633' 7135' Casing Length CONDUCTOR SURFACE 108' 2640' PRODUCTION LINER 6613' 493' ") l ~Ú,\ Perforation Depth MD (ft): 7054' -7072', 7078' - 7085',7105' -7145' Packers and SSSV Type: no packer SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Perforate D Stimulate D 4. Current Well Class: Development Stratigraphic 0 D Exploratory D Service D ø Ð~ *-0'-\ ~y Variance D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Annular Disp. D Other D 198-113 6. API Number: 50-103-20264-00 9. Well Name and Number: 2N-345 10. Field/Pool(s): Kuparuk River Field / Tarn Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Tubing Size: 3-1/2" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Contact: Title: Phone 659-7224 Commission Use Only Perforation Depth TVD (ft): 5255' - 5273', 5279' - 5286', 5306' - 5346' Packers and SSSV MD (ft) Seal Assembly at 6762' No SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Size MD TVD Burst Collapse 16" 108' 108' 7-5/8" 2789' 2306' 5-1/2" 6762' 4963' 3-1/2" 7255' 5456' Tubing Grade: L-80 Tubing MD (ft): 6762' 2/1 0/2004 Date: Signature Service D Plugged D WINJ D Abandoned D WDSPL D Guy Schwartz @ 265-6958 Problem Well Supervisor Date -:z. Sundry Number: 0'0";- Location Clearan~ Eb E I VED . 11 _il FEe 0 9 2004 Alaska Oil & Gas Cons. Cmnmission Anchou'age Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ,l8' BOP Test D Mechanical Integrity Test D Other: Approved by: , .,:Øf~l. COMMISSIONER BY ORDER OF THE COMMISSION ORIG\NAL Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk We1l2N-345 (PTD 1981130) SUNDRY NOTICE 10-403 REQUEST 2/4/04 From: Guy Schwartz Date: 2-3-04 To: Tom Maunder (AOGCC) Subject: 2N-345 P & A As per our conversation regarding the 2N-345 producer well and upcoming sidetrack to a new bottom hole location.. .the following is a summary of the reasons for abandoning existing wellbore and a brief review of the procedure we will follow to P & A the well. 2N-345 is a problem producer in the Tarn Field, exhibiting thief-like behavior. Originally completed in 1998, 2N-345 produced 800 BOPD with manageable water cut and FGOR. However, once water injection was introduced in the Tarn Field in the summer of 1999, 2N-345 started to produce essentially all water or all gas. As this was the only problem producer in the field, extensive technical work has been conducted to identify the source and a solution of the problem. Unfortunately, the exact cause of the problem has not been identified and 2N-345 has been shut in for 2 years. Therefore, the decision has been made to sidetrack 2N-345 to a new bottom hole location approximately 1000' to the northwest. Prior to the planned sidetrack, the existing wellbore will be P & A'd in the 3 Y2" liner section and the new well will be sidetracked out the original wellbore at a depth of about 5900' md. Procedure for P & A for 2N-345 is as follows: 1. Dummy off GLV @ 6701' ..... MIT tubing and IA. 2. Verify tag with Slickline / drift 3.5" tubing and liner for cement retainer. 3. Rig up CTU: RIH with 3.5" cement retainer. Set at depth of 6950'. 4. Pressure Test retainer from surface to 2500 psi. 5. RIH with CTU and sting back into retainer.. .Squeeze off perforations with Class G cement. 6. Pullout of retainer and lay in cement to 6900' (50' above retainer). 7. Wait 24 hrs for cement to set. MIT against cement plug ... have AOGCC witness present. 8. Chemical cut tubing at 6000' md .... Sidetrack rig to set CIBP and whipstock. NIP (531-532, 00:3,500) TUBING (0-6762, 00:3,500, 10:2,992) °ROOUCTION (0-6762, 00:5,500, Wt:15,50) Gas Lift mdrellOummy Valve 1 (6701-6702, 00:4,725) NIP (6755-6756, 00:3,500) SEAL (6762-6763, 00:5,500) LINER (6762-7255, 00:3,500, Wt:9,30) Perf (7054-7072) Perf (7078-7085) Perf (7105-7145) SHOE (7254-7255, 00:3,500) 7078 - 7085 5279 5286 7105 - 7145 5306 - 5346 KRU 2N-345 Well T e: PROD Orig 7/19/1998 Com letion: Last W/O: Rev Reason: Pull gauges Last U date: 1/30/2004 Size 16,000 7,625 5,500 3,500 !Vo 108 2306 4963 5456 Wt 62.58 29,70 15.50 9.30 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC MOD EUE Thread EUE Zone Status Comment 2 1/2" HC, DP, 60 deg. hase 2 1/2" HC, DP, 60 deg. ., hase 7/21/1998 IPERF 21/2" HC, BH, 180 PH, 90 ORIENT 7 4 2/14/1999 40 4 Man Type I V Mfr I KBG I CAMCO Vlv Cmn! DescripUon 10 2.875 2.813 2.750 2.985 2.985 CAMCO 'OS' NIPPLE BAKER CMU - CLOSED 9/26/2000 CAMCO '0' NIPPLE BAKER 5.5" CASING SEAL ASSY. 80-40 Re: Tam Annular Injection- Phase 3 - - PTDs #98 -100" #98 -113 • Subject: Re: Tarn Annular Injection- Phase 3 - - P1Ds #98 -103 an #98 -113 • Date: Tue, 21 Nov 2000 09:32:21 -1000 From: "Brian D Noel" <BNOEL @ppco.com> To: tom_maunder@admin.state.ak.us by Brian D Noel /PPCO on 11/21/2000 09:32 AM To: Brian D Noel /PPCO @Phillips cc: Subject: Re: Tarn Annular Injection- Phase 3 - - PTDs #98 -103 and #98 -113 Brian, FYI. Tom Forwarded by Tom J Brassfield /PPCO on 11/21/2000 09:56 AM Blair Wondzell <blair_wondzell @admin.state.ak.us> on 05/17/2000 10:04:16 AM To: Tom J Brassfield /AAI /ARCO@Arco cc: Randy L. Thomas /AAI /ARCO@Arco, Paul Mazzolini /AAI /ARCO @Arco, Sharon Allsup- Drake /AAI /ARCO@Arco, Nabors 19E Company Man /AAI /ARCO @Arco, aogcc north slope address <aogcc_prudhoe _bay @admin. state.ak.us> Subject: Re: Tarn Annular Injection- Phase 3 - - PTDs #98 -103 and #98 -113 • StAtiNED APR 0 201' Tom, I've looked at the well files and reviewed the approved 10 -403s for annular disposal. The approvals are still valid provided: 1) they have not reached the 35,000 barrel limit unless a larger volume was approcved; or 2) unless the annuli of a specific well has been closed Tom, in the future where you have approval for annular disposal and there is remaining capacity, you could just send me an e-mail of intent to dispose, then give the well name, the PTD #, the 403 approval no., the disposal volume available, and approximately when you plan to start disposal. If you have additional questions, please contact me. Sincerely, Blair Wondzell, 5/17/00. Tom J Brassfield wrote: > Blair, as we discussed today we have several wells at the Tarn 2N Pad which • were > approved for annular disposal in 98/99. Nabors 19E is moving to 2N 347 this > week and we have two specific wells which we are interested in using for annular > injection at this time: 2N 341 & 2N 345. Specifics are as follows: 1 of 2 11/21/00 9:42 AM Re: Tam Annular Injection- Phase 3 - - PTDs #98 -1 d #98 -113 • > 2N 341- Annular injection Sundry 403 approved 7/17/98. Approval No. • Our 398u3. > O records indicate that we have not used this well for annular injection In > the past. > 2N 345- Annular injection Sundry 403 approved 8/28/98. Approval No. 398 -217. > Our records indicate that we have not used this well for annular injection in > the past. > As we start Phase 3 drilling at Tarn, there are other annuli Mich have Sundry > approvals and injection volumes less than the 35,000 bbls. Are these existing > Sundry approvals still valid? > Thanks, Tom • • 2of2 11/21/00 9:42 AM Well Compliance R P°rt File on Left side of folder .... 198-113-0 MD 07431 Microfilm Roll KUPARUK RIV U TARN 2N-345 50- 103-20264-00 PHILLIPS ALASKAINC TYD 0Y633 Completion Date: /98 Completed Status: 1-OIL Current: / Roll 2 / Name c 9493 D 8772 L CNTD L DEFT-PSP L DGR/CNP/SLD-MD L DGR/CNP/SLD-TVD L DGR/EWR4-MD L DGR/EWR4-TVD L DSI L DSI-SSTVD L DSSI L PROD-PSP L PROD-SPIN/TEM/ L SCMT L WFL-PSP R D1R SRVY Interval 1 SCHLUM CNTD 1/20/00 CH ~" SPERRY MPT/GR/EWR4/CNP/SED OH {~AL 1000-6750 1/20/00 CH ~,~4N~L 6900-7140 11/4/99 CH ~ 2320-7431 ~ [~ qO/C~ OH ~ 2311-5632 OH ~2~ 2320-7431 OH ~2/~' 2311-5632 'X / OH / /~AL BL(C) 2750-7400 / on C~AL 2790-7398~ OH ~INAL 2791-7398 ~ill~o/c{~ OH F~INAL 6900-7140 11/4/99. CH 70000 30 ~tq~L BE(C) 6700-7138,1/17/00 CH Z4~NAL 3000-7140 11/4/99 CH g-~'a~RY 108.-7432. OH T 8622~,..3~' SCHLUM DSI/FMS Daily Well Ops~/(l/~t~ Was the well cored? yes Comments: Sent Received T/C/D 4/10/00 4/10/00 11/4/98 11/4/98 5 4/10/00 4/10/00 c O 9 3 5 11/18/99 11/30/99 O(~ 3 11/4/98 11/4/98 11/4/98 11/4/98 11/4/98 11/4/98 11/4/98 11/4/98 7/31/98 7/31/98 7/31/98 7/31/98 8/20/98 8/27/98 5 11/18/99 11/30/99 ~'_~ 5 3/12/99 3/18/99 {~)~ 5 1/27/00 2/4/00 5 12/15/99 12/29/99 O~ '~ 8/19/98 8/21/98 OH 8/20/98 8/27/98 Are Dry Ditch Samples Required? yes ~_ And Receivedg~yvr-m~-- Analysis Description Rece[~Sample Tuesday, August 01,2000 Page 1 of 1 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121361 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk 4/10/00 Well Job # Log Description Date BL Sepia CD 2N-345 .]~c~ctc(~ 20056 CNTD 000120 I I 1 , ,, .nFFFIVI:D APR 10 000 SIGN DATE: Alaska 0ii & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you, 1 ~27~00 Scblmberger N0.121137 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-26 20054 SCMT 000118 1 2N-345 20053 SCMT 000117 1 1R-01A JEWELRY LOG W/PSP & SCMT 000108 I 1 2M-18 ~,.\ r.._ LEAK DETECTION LOG 000105 I 1 1D-111 U.~ C.. INJECTION PROFILE W/PSP 000104 I 1 1D-114 INJECTION PROFILE WlPSP 000104 I 1 1 D-122 INJECTION PROFILE 000106 I 1 1 D-128 INJECTION PROFILE 000105 I 1 1D-130 ',,,,- INJECTION PROFILE 000107 I 1 , , , ........... n _r ;' ~ ! \! _[: _r~_ . '~,,~ ,' . . /! . 'i i~ l s~G"E -, _~/~, ) ,i~,,/ DATE: FEB 04 2000 ~'/'~tto Gas C0~s. O0m~issi0n / Please si~n and return one ~op~ o~ thi~ transmitt $herri, at the abo~e address or ~ax to {007} 5~1-8a~ 7. man~ ~ou. 12/15/99 Schlumberger NO. 121024 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 1C-02 GEN~LRY LOG 991208 I 1 1F-06 LM (.-.- PRODUCTION PROFILE W/PSP 991206 I 1 1G-17 STATIC BOTTO~ HOLE 991207 I 1 2A-03 Ut ~ INACTION PROFILE W/PSP 991204 I 1 2N-345 ~L/PSP/RST 99110~ I 1 2X-04 ~t ~ MI INJECTION PROFILE 991201 I 1 3M-08 PRODUCTION PROFILE W/PSP 991205 I 1 3M-13 GAS LI~ SURVEY W/PSP 991201 I 1 3N-04 ~ INJECTION PROFILE W/PSP 991208 I I SIGNE DATE: / Naska Oil & Gas Cons. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Schlumberger NO. 12948 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 1D-12 PERFORATION RECORD & SBHP 991105 I 1 ,, 2F-16 blt eL__. INJECTION PROFILE 991108 I 1 2M-15 PRODUCTION PROFILE 991110 I 1 2M-21 PRODUCTION PROFILE 991109 I 1 2N-345 PRODUCTION PROFILE W/PSP 991104 I 1 2N-345 DEFT W/PSP 991104 I 1 1O-~ iq bt, lC- 99404 SCUT 991004 I 1 1 SIGNED: .... 1.. DATE: ~ 011 & Gas Cons. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 11/18/99 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 4, 1998 2N-345, AK-MM-80282 1 LDWG formatted Disc with verification listing. API#: 50-103-20264-00 PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING ~ ATFACHED COPY OF THE TRANSMITYAL LETTER TO ~ ATYENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · ~ ,: ..3 ~ .~ ": :~0' = Signed: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 0 F! I L-I--I IM [~ SEFI~Yl I-- E 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 November 4, 1998 2N-345, AK-MM-80282 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, ~G, Anchorage, AK 99518 2N-345: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20264-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20264-00 2"x 5"MD Neutron & Density Logs: 50-103-20264-00 2" x 5" TVD Neutron & Density Logs: 50-103-202(M-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia NOV 0,, ~993 Anch, orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A I'~r~r Ind,,e~l',4~e Inr, /~rmrnn~nw STATE OF ALASKA .._~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _~. 28' RKB 3. Address: Exploratory ~ 7. Unit or Property: P,O. Box 100360 Stratagrapic _~. Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 144' FNL, 1113' FEL, Sec 3, T9N, RTE, UM 2N-345 At top of productive interval: 9. Permit number/approval number: 607' FNL, 268' FWL, Sec 3, T9N, R7E, UM 98-113/399-147 At effective depth: 10. APl number: 601' FNL, 267' FWL, Sec 3, T9N, R7E, UM EO-029-20264-00 At total depth: 11. Field/Pool: 600' FNL, 267' F--WL, Sec 3, T9N, RTE, UM Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total Depth: measured 7431 feet Plugs (measured) None true vertical 5633 feet Effective Deptl measured 7255 feet Junk (measured) None true vertical 5456 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" .9 cu yds High Early 108' 108' Surface 2760' 7,625" 40 Sx AS III & 2789' 2306' 240 Sx Class G w/42 BBL Class G top job Production 6732' 5,5" 42 bbl Class G 6700' 4961' Liner 655' 3,5" Included in above 7415' 5616' Perforation Depth measured 7105'-7145' true vertical 5306'-5346' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/E, L-80 EUE @ 6778' Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 6760'; SSSV: None, nipple @ 531' 13. Stimulation or cement squeeze summary ~_~"~,; N/A Intervals treated (measured) N/A ~:.. Treatment description including volumes used and final pressure Installed jet pump in production well from 9/7/99 to 10/1/99. 14. Representilive Daily Average Production or Injection Data Oil~Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Oil rate varies from 9 to 3900 depending on amount of paraffin in wellbore Prior to well operation 24 95 0 507 366 Approximate average, water is power fluid used Subsequent to operation 694 253 2113 1634 386 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title: Production Engineering Supervisor Date Form 10-404 R~ 16/15/88 SUBMIT IN DUPLICATE Re: Tam RA Injection Subject: Re: Tarn RA Injection Date: Wed, 05 Apr 2000 15:11:01 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER@mail.aai.arco.com> Lamont, Thanks for the data. As we discussed, I think this request should be by a 10-403. Contingent on your furnishing a 403 to this office by Monday, April 10, I am giving you verbal approval so that the work can start this weekend. Blair Wondzell, 4/5/00. Lamont C Frazer wrote: Blair, As per our phone dls~ussion on 4/4/00, we are seeking AOGCC approval to inject RA maueriat in the £uuer annulus of Tarn injectors 2N-325 and 2N-321A as par.t of an ongoing program us diagnose ho~,¢ injection fluids are being urodu~--~ .... 2N-3~5. ---~ your convenience, the =_~,~i~--~i_~_.. e-mail messaGe~ on chis subject and a brief update of recent data collection activities are provided belo~. Da~a Collection Um~a~e - Gas ~_racers indicate that a small fraction of Mi injection from wells £N-325, 2N-331 and 2N-321A is transported to 2N-345 wi'~hin a few days. The logging progra~ outlined be£o~,¢ has not provided any indication of out of zone injection, wi~h one exception the CNL run in injector 2N-321A indicated that the Iceberg interval in the ne=_--~,vellbore region of this injector has increased its gas/MI sa~urar_ion since Eke ;yell ~¢as drilled. At this uoint in time, it remains unclear as to how :-jection fluids are being ~ransported to 2N-345. _==~r~ stimu=ated producer 2N-345 Schema.-_ics of !njec-crs 2Z, J-321A & 2N-325 and £ ...... ~ are a-so shown be!c;..'. Logs suggest good cement bonding up to the crossover in 2~,J-32f. (Cement kcnding above the crossover is un.%nown.) Logs suggest tha~ ......... nt bonding prior to 2FI-32ZA and 2)7-345 '-_~uh have some degradation ~- reac?.ing their crossovers. Producer Logging * Production - DEFT (£:¥-345.t - ['?ater Flow -c7 (2N-345) * Sehind Pipe Flow Evaluation - CNL (2~-345) - t.loise '2N-5 ' ~.) -Cement Evai~aiion Log (2N-345) > Injec-_or Loggzng > ~ ?~ater Znjeczion > -Spinners (£'_?-S07, 2N-321A, £~f-325, 2N-332 ~. £N-343) > - Temperature .:'2N-321A, 2N-325 & 2N-343) > - ~orax ?3<L (~:?-325 & 2N-343) > - '._.!ear-Ne-,_!kcre Iodine i31 RA Tracer (2N-322A, 2N-325 & 2N-343) Gas injection -Spinners (2~?-307, 2N-321A, 2N-325, 2N-352 & 2N-343) - ENL (27-321', 2N-325 & 2~,~-33!) (Embodied image :~c~.-ei ~o file: uici7230.pcx) 1 of 3 4/5/00 3:11 PM Re: Tam RA Injection Proposal The RA injection proposal is two-fold. First, v. ze plan to inject RA mauerial (i.e., Iodine !31, which has a half-life of 8.5 days) down the surface casing by producEion casing annulus o5 injectors 2N-321A and 27.!-325. The purpose of this is to identify the "weak zone" that breaks d~zn during annular pump-ins. (This will be the zone t~qat cuttings are injected into during annular disposal operations.) This informaui©n will be used 5o help formuia-e drilling plans of future wells. ~Je know that t~qis "weak zone" is not transporting injected .._,_=~uids to 2N-345. ?~e can Dump diesel into the "weak zone" aE pressures that range between 700 psi and 1200 psi. After compiee_ing pumping operations, ~he outer annulus pressures bleed down. If the "~,eak zone" were ~ra£sporting injection fluids, it would be az an elevated pressure (~3000 psi). ,~his elevated pressure is not consistent ~Jith the relatively low pressure outer annulus pump-ins and subsequent pressure b!eed-oSfs. Second, we DiSh Uo injec~ solid RA tagged .oarticles (i.e., _~qtimony and Scandium, which have half-lives in the 60 - ~0 days range) into the outer annulus and Ehen lee gravity allow these parEicles to settle. The purpose of this is to identify the deepest point that is in hydraulic sommunication with the outer annulus. This information will also be used to help formulate drilling plans of future wells. If you have ~nv~ ouesUions, ~r would like additional information on ~' ~n~s subject, ulease contact either mvsel_= (263-4530) or Rvan S~amD (265-6806) ~-e would welcome an opportunity Eo meet with you to discuss the matzer in more detail. Sincerely, Lamont Frazer AAI Tarn Reservoir Engineer ............ Forwarded by Lamont C Frazer/~=a._I/ARCO on 04/05/2000 09:08 >AM Lamont C Frazer 01/11/2000 04:14 PM To: Blair :z?ondzeil~admin.szate.ak. us cc: Ryan ~ StramD/~_qI/ARCC.'~ARCO Subject: Tarn injection Blair, As per our phone discussion en 1/10/00, this e-mai! message provides a brief descriuuion outlining events relating to the production of injected fluids in Tarn Droducer £~¥-3z5. The reason for al~re-',~g the ...... this ituation is that it > ?s possible that out of zone injection may be involved in --~e transDorE > of injected fluids to 2N-345. > Background >AAI initiated Tarn MI :~ 'ec ~ :~9 uion during late ?98. .z~ ;vaeer injection test -,vas > conduczed during zhe summer cf ?99. At the Eime of the test, no Tarn producer > had experienced 5'II breakzhrough. After approxima[elv three weeks of ~,vaEer > injection, water mroduction :.,'as observed in 2~,f-345. ~rater -racers suggested > [[qaE 2~'~-321A, and uossibly 2:~-325, z~ere communicating ;vith p. roducer 2N-345. > (See ne~ pay map below for ;.~ell locations.) Given that (1) no previous MI > breakthrough had been deEeczed, (2) the quick water breakE[qrough time, and (3) > the location of in~eczur 2~-321A relative to producer 2N-3z_5, communication > ~hrough the reservoir was diSficult to explain. One possibility ~zas that .~he 2 of 3 4/5/00 3:12 PM Re: Tarn RA Injection transport path of injecred fluids to 2N-345 involved channeling up the outside 2N-321A?s casing, through a shallow zone (where 2N-32tA and 2N-325 wellbores are closer together), and down the outside of 2N-345?s casing to its open uerforarions. A variery of injection logs and production logs were subsequenrty run; however, they ali 5ailed to deEect channeling. Furthermore, there were no elevated pressures in ihe annuli of any Tarn wells indicaring communication with injected fluids. Afrer completing the :..'arer injection test, MI injecSion at Tarn was resumed. Well tests on 2N-345 ¢iere closely monitored for any sign of MI breakthrough. MI breakthrough in 2N-345 has recenrly been confirmed. Ongoing Diagnosis A comprehensive plan has been developed to help understand the transport path of injected fluids to 2N-345. Ongoing activities include (1) additional logging, (2) use of gas tracers and (3) attemmEing to inject into the outer annuli of Tarn wells to determin~ *.vhether they remain open to shallow 'horizons. if you have any questicns, or would like additional information on this subject, uiease contact either .~yself (263-4530) or Ryan Stramp (265-6806). ~e would :¢elcome an opportunity to meet with you to discuss the matter in more detail. Sincerely, Lamont Frazer .~.I Tarn Reservoir Engineer (Embedded image moved ~o file: ~icO0589.pcx) Name: pic! 7230.pcx pic17230.pcy. Type: PCX image Document ( app l i ca u i on /x -unknown -c3n Eon t - r ype-PCXIma ge . Documen ~ ) Encoding: base64 Name: picO~589.~cx picOO589.pcx Type: PCX image Document ( ~?_m i i ca r i on /x - unknown -cs n ten t - E S~oe-PCXImage . Documen t) Encodin7: base64 3 of 3 4/5/00 3:12 PM 2N-321A ( 2N-325 ( 2N-345 , ::':,<'<>}~,. r , I ""f;';' , ' : ' " ,';" ',",',':':'''',',',',',''',''', t' ~:l:::::':::':: ,. :,~;t~#,:::::::::,':::,:! :~¡ ~h \Nest Sak ì. , 11 1060'-1800' ~; ) ,. Tabasco \ 2350'-2360' -"'\ ~\ t., i . ..! '. --'- . ,", : ~:;t.. f ,.J''" '--....}' :" '-- '~n:--""" ",----" I' , . . , I 1 I I I l i i ! i \ I 't , \ ì 'I I ! , I ~ \ \. i \ I i ~ I ~. ,! .~ .,' i I~ . ~ . Iceberg 410tY..4300: ¡: ':::- "..". .. I . ~ . ;::"~.! Bermuda 4900t -51 oot :.' ..'!...... , . i i \ \ I ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~on, Chairmar¢' DATE: July 8, 1998 THRU: Blair WondzelI,c¢~ P. I. Supervisor-' ~?c? FROM: Larry Wade, ¢~~'/¢lI1~ SUBJECT: Petroleum Inspector FILE NO: .DOC Diverter Inspection Doyon 141 KRU 2N-345 PTD 98-113 July 8,1998: I drove to Tarn to witness a diverter function test on Doyon 141. We had to cycle the bag a couple of times because' it was dirty. The road to Tarn is starting to harden up but the pad is still soft because of all the equipment and stuff on the pad. SUMMARY: I witnessed a diverter function test on Doyon 141,0 failures, 1.5 hours. Attachments: ebwgghfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: L,/Development Drlg Contractor: Do¥on, Rig No. 141 PTD # Operator: ARCO Oper. Rep.: Ray Sprin~er Well Name: 2N-345 Rig Rep.: Pat Krupa Location: Sec. 3 T. 9N R. 7E Merdian Umiat Date: 7/7/98 X Exploratory: 98-113 Rig Ph. # 659-7170 MISC. INSPECTIONS: Location Gen.: ok Well Sign: X Housekeeping: ok (Gen.) Drlg. Rig: ok Reserve Pit: n/a Flare Pit: n/a DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: 20 in. X 20 ~' in. 70 -"ft. n/a X X n/a ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig Pressure After Closure: 2100 psig 200 psi Attained After Closure: min. 30 sec. Systems Pressure Attained: 2 min. 10 sec. Nitrogen Bottles: 2150, 2150, 2050 2150, 2150 psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: X X Mud Pits: X X Flow Monitor: X X GAS DETECTORS: Light Alarm Methane X Hydrogen Sulfide: X X Wind direction substructure Norh Non Compliance Items Remarks: Repair Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c -Inspector AOGCC REP.: Larry Wade OPERATOR REP.: Ray Springer DVTRINSP. XLT (REV. 1/28/97) L.G. ebwgghfe.xls Report prepared 7/10/98 "~'" STATE OF ALASKA r4-¢=~,¢~1¢.~ 5us~,~.,1,-re,~ ALASKA OIL AND GAS CONSERVATION COMMISSION AcP~r..c¢/~o,~Su¢..~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well _ Plugging __ Time extension __ Stimulate _ Change approved program__ Pull tubing__ Variance__ Perforate_ Other X Annular Iniection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~X ARCO Alaska, Inc. Exploratory _ 28' RKB feet 3. Address Stratigraphic_ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 144' FNL, 1113' FFL, Sec. 3, T9N, RTF, UM 2N-345 At top of productive interval 9. Permit number ?? FNL, ?? FEL, Sec., T9N, R7E, UM 98-113 At effective depth 10. APl number 50-103-20264 At total depth 11. Field/Pool 600' FNL, 267' FWL, Sec. 3, T9N, R7E, UM Kuparuk River/Tarn Pool 12. Present well condition summary Total Depth: measured 7431 feet Plugs (measured) None (approx) true vertical 5633 feet Effective depth: measured 7255 feet Junk (measured) (approx) true vertical 5456 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" 9 yds High Farly 108' 108' Surface 2761' 7.625" 40 sx AS IIILW, 2789' 2306' Intermediate 240 SX Class S Production 7387' 5.5"x3.5" 42 bbls Class G 7415' 5616' Liner Perforation depth: measured 7105'-7145' true vertical 5306'-5346' Tubing (size, grade, and measured depth) 3.5", 9.3#, 8rd EUE @ 6778' Packers and SSSV (type and measured depth) Baker Csg Seal Receptacle (CAR) @ 6760', no SSSV 13. Attachments Description summary of proposal__ Detailed operation program ~ BOP sketch __ Contact Tom Brassfield at 265-6377 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation 15. Status of well classification as: August 1998 Oil Gas _ Suspended 16. If proposal was verbally approved Na ~e of approver Date approved Service 17. I he eby certify th _a~il~c~egoing is true and,c,orrec~o the ~bes. t of my kn(~v~ed.ge. Signed M~,~,,&,.~ J j'~qI"~IVI.K'"~ Title Tarn I~rilling Team Leader Date %,,.~[ " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness lAPpreval Plug integrity_ BOP Test_ Location clearance I , Mechanical Integrity Test_ Subsequent form require ~ ~- Original Signed By oO~q David W. Johnston ,,,ro.e, t.e o,der o, Co. ,ss,o. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Cementing Details Well Name: 2N-345 Report Date: 07/11/98 Report Number: 6 Ri~l Name: DOYON 141 AFC No.: AK9509 Field: TARN · Centralizers State type used, intervals covered and spacing Comments: 31 GEMOCO BOW SPRING CENT OVER STOP CLRS BTM 2 SHOE JI'S & ON JTS EITHER SIDE STAGE CLR, JTS 3-12 ABOVE FLT CLR & EVERY 3RD JT F/SURFACE TO STAGE CLR. Mud Weight: Pr(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 21 18 16 12 CUT VIS F,m~4 TO 45 LARGE Gels before: Gels after: Total Volume Circulated: , QUANTITY OF PEA GRAVEL ' BOTH STAGES. 5/6 3/4 2 HOLE VOLUMES Wash 0 Type: Volume: Weight: Comments: Water 30 BBL Spacer 0 Type: Volume: Weight: Comments: ARCO 30 10.5 B-45 Lead Cement 0 Type: I Mix wtr temp: No· of Sacks: I Weight: Yield: Comments: AS III LWI 70 40 I Additives: ,3.5% NaCl,30% GYP,. 51)% SPHERES,1.5% CaCl2, 1.5%D79 EX'rENDER, .4% D46 DEFOAMER Tall Cement 0 , Type: Mix wtr tamp: No. of Sacks: Weight: Yield: Comments: G 70 240 15.7 1.15 Additives: 1% CaCl2, .3 % D65, .2% D46 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 3.5 3.5 80 BUMPED PLUGS @ CALC DISPLACEMENT, DV STAGE Reciprocation length: Reciprocation speed: Str. Wt. Down: 10' 1/MIN 65 COLLAR CLOSED @ CALC DISP. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: Calculated top of cement: I CP: Bumped plug: Floats held: CMT @ STAGE CLR 20 BBL EXCESS WHEN STAGEI Date:7110/98 YES YES CLR OPEN AND CIRC TO SURFACE. Time:0045 Remarks:2ND STAGE, CMT TO SURFACE, LOST RETURNS, BROACHED AROUND CELLAR ON 2N-345. UNSEATED MANDREL HANGER & WASHED OUT HANGER F/BELOW LARGE QUANTITY OF PEA GRAVEL DURING CIRC BEFORE CEMENTING 2ND STAGE. DV STAGE TOOL OPENED @ 2850 PSI. 2N.345 CONDUCTOR & CELLAR PREVIOUSLY BROACHED & CEMENTED WHILE DRILUNG 2N-343. THIS FORM NEEDS MODIFICATION F/2-STAGE CEMENTING OPERATIONS. i ICement Company: DS IRig Contractor: DOYON IApproved By: R.W. SPRINGER Casing Detail 7-5/8" Surface Casina ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: TARN 2N-345 DATE: 7/9/98 1 OF 1 PAGES # ITEMS jts. 31-65 Lock B Lock A )ts. 3-30 jts 1-2 COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to Pad = 29.25' TOPS Above RKB 7 5/8" Landing Joint 34' aA. 29.25 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.70 29.25 7 5/8", 29.7#, L-80 BTC-MOD 1435.24 31.95 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) JT. #72 42.80 1467.19 Gemeco 7 5/8" Stage Collar (BAKERLOK) 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) JT. #71 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jt #3, BAKEI Gemeco Float Collar 7 5/8", 29.7#, L-80 BTC-MOD Gemeco Float Shoe 31 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, 71, 72 over stop collars 2.70 1509.99 42.77 1512.69 1146.58 1555.46 1.25 84.43 1.49 and over casing collars on Jts. 3 thru 12 and over collars of jts. 2702.04 2703.29 2787.72 2789.21 15,18,21,24,27,30,36,39,42,45,48,51,54,57,60, and 63 Joints 66-70 (5 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 80K# Up, 65K# Dn, 20k# Blocks. Ran 67 oints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: R. W. SPRINGER CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N 345 Supervisor: M. Cunningham/R.W. Springer Date: 7/10/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.5 ppg Hole Depth: 2,320' TVD 780 psi LOT: (0.052 x 2,320') Fluid Pumped = 0.7 bbl 7 5/8", 29.7 ppf, L-80, BTC 2,820' TMD 2,320' TVD EMW = Leak-off Press. + MW 0.052 x TVD + 9.5 ppg EMW = 16.0 ppg Pump output = 0.1010 bps 3,300 psi j 3,2oo,,, I ;[~,; I ~ ..~..~. 4`..,.+..+ 3,100 psi, ............. -+ .4-~ 4-, q-, t .... .+~+, ~4-~ 4-. -.I ...... .] t-' ,-~- -4`. ~-+ ~+ ,4-. .4-. q-, -:-,-[,-' ,4`- ,4`, -4,. -+, 3,000 psi 2,900 psi 2,800 psi 2,700 psi -- 2,~00 psi 2,500 ¢~1 -- 2,400 psi 2,300 ps1 -- 2,200 psi 2J00 2,000 1,900 psi 1 1,800 psi -- -- -- 1,700 psi 1,600 psij e -- 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi ----j[-- -- 1,000 psit -- -- 9o0 psi ~. '-~- LEAK-OFF TEST 800 psi 700 psi F;'~ :";:'";':'-' '-::~.:~ .::'.:.:': .... --a--CASING TEST 600 psi / 5oo p,i...... :'." LOT SHUT IN TIME 400 p~i· 300 psi ,~ '":*:'"' CASING TEST SHUT IN TIME 200 psi-- /I 10~_ psiPSi ~i I __ .~'" TIME LINE 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 48 48 50 52 54 56 58 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE J_ .................. k .................. 0 stks 0 psi 2 stks 40 psi ........................ ~-~-~-~ ......... -~-~-~-~ ..... ........................ ~-~-~-~ ......... -¢~-~-~ ..... 7 stks 780 psi , .................. .4- .................. ~ .................. , , , ! S.UT ,. T,~E S.UT ,. PRESSURE .... ~Tb"~i~'"'T ....................... ?'~'O'~i ..... .... 'l'.'b"rBifi'"'T ...................... 't;iiJ'~'&l ..... 2.0min : , 730 ps, 3.0min I ~ 730 psi ..... ~..'b"~iB'''''t .................. ;'"'?iiii'~'~l ..... ..... ~:~"a~'"'T: .................. i----t-~-~-~ ..... .... i~.'b"F~iB'"'T .................. ['"7'iJi'~'~l ..... .... 7.'b"r~l~-''-T .................. r----t'iiJ-~'~l ..... ............ ~ ..... + .................. r ............. ~ .... ..... ~-9.._m.?.....: .................. L..._Tj_.o..?.s_., .... 9,0 min : : 700 ps~ .... 'l'~.'d"~ir~"'* .................. ;'"'?i~ii'~'~l .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................................... 1 ,. .................. k .................. i' .................. j ........................ __O_~.t.k.?_ .... j ..... ..O_.p..s.! ...... 2 stks j 70 psi ........................ -~-~i~- .... i .... ~'~'~'~'['"i ........................ -~-~i~- .... ~ .... ~'~'~'i~'r"',, ........................ -~-~i~- .... 1---f,-4~--~-~i--', ........................ ?.2._?_t..k..'_._.L._3:_°_.°..°. , ...................................... i .................. ': , , ,. .................. · .................. ~, .................. ...................................... I .................. : I ' ................... ~ .................. I .................. l "' ................. ' .................. l .................. 4 , , ...................................... J~ ................... ...................................... i ................... I ' SHUT IN TIME~ SHUT IN PRESSURE .... 'o;u%'i~ .......................... ..........~.o ~-~ ........................... ~',-~i~'-i,'~i'" 3.0 min 3,000 psi .... '2l;~'~-i~ ........................... .... '8;~'~'i'~ ........................... ~',~ii~'-~'~i"~ .... ._7._o..~?. .... : ...................... i 8.0min 2,960 psi ! ["'"Si~'~T~ .......................... '~','~**'-i,'~r",' [---~-o:u-~---r ...................... ,','~ir~'~r'~, i .................. ' ..................................... i F .................. t .................. ~ ................... . ..................................... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N 345 Supervisor: M. Cunningham/R.W. Springer Date: 7/10198 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.5 ppg Hole Depth: 3,779' TVD 855 psi + 9.5 ppg EMW LOT = (0.052 x 3,779') = 13.9 ppg Fluid Pumped = 4.0 bbl Fluid bled back= 1.8 bbl 7 518", 29.7 ppf, L-80, BTC 2,820' TMD 2,320' TVD EMW = Leak-off Press. + MW 0.052 x TVD Pump output = 0.1010 bps 3,100 psi --~ 3,000 psi --' 2,900 psi --jr-, ,~, '&' ').' ~,- ,~- ~T-.~ :~ -:k. ~. 2,800 psi I __ 2,700 psi 2,600 psi I 2,500 psi 2,4O0 psi 2,300 psi 2,200 psi 2,100 ps! 1,900 ~*i 1,800 psi -- 1,700 psi -- -- -- 1,600 psi -- 1,500 psi 1,400 psi 1,300 psi .-- 1,200 psi -- 1,100 psi -- 1,000 psi ~ -- -- 900 psi I~ __ ..m.. LEAK-OFF TEST 000 psi ~ ~ - '"~ICASING TEST 700 psi 600 psi 500 psi 400 psi I 300psi ~r ~=~, ~.~ %%~ =~ .......... LOTSHUT IN TIME 200 psi ~~ -- ---~.- CASING TEST SHUT IN TIME lOO psi /-; --~- TIME LINE 0 psi ~.i~ 0 2 4 8 e 10 12 14 16 18 20 22 24 2G 28 30 32 34 38 38 40 42 44 48 48 50 52 54 56 58 60 62 64 86 Ge 70 72 74 76 78 80 82 84 B6 eu stk slk stk stk stk stk stk stk stk stk stk stk stk stk sik stk stk stk stk stk stk stk stk stk stk stk stk sIk s~k stk stk stk sIk stk stk stk stk stk stk sJk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .................. ~ .................. I. .................. ~ 0 stks , 0 psi ...................... -~-~-~'f~; ....... ',~'i~'a .... ....................... -~-;f-~-f~ ........ -~-~-j,-a .... ...................... -~-~-t-~ ........ -~-~-/,-a .... ~. 20stks , 475psm 30 stks 455 psm 32 stks 385 psi ....................... -~;c~-f~ ........ -~-~-~-a .... ....................... '~'{'~] .... [''''4l~l~'{] ...................... -~-;-f~ .... [----,T~-/,-a .... .................. T'":4~'~'f~ .... r'"~'/,'a .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................................... 1 .................. 0 stks i 0 psi ........................ ">'~' .... i ..... ~,-o--~;~ .... i ........................ -a-~t~- .... i .... ~'~'i~'r"i ........................ -a-~ii~- .... ~ .... t-a~-~-r-q ........................ -~-~i~- .... ~---~-~-~-~--=r-~ i /IitV~l i ~2~tks ~ 3,000 ...................................... J .................. ...................................... 4 .................. 4 I SHUT IN TIME I SHUT IN PRESSURE .... 'Oi~'~l~ .... ' .................. !'"~'7O~'~"i ............ ~ ......................... 4 ............... =--~ 1.0 mmn ~ S,O00 SHUT IN TIME ! '-mr' ...................................... SHUT IN PRESSURE 3.0 min .... 'a:o'~'~ ....................... i'"~','~'-/,'~i"i .... '~:O'~'F~ .... r .................. F"~;'~"F~i"~ ............ -. ...... ' .................. 4 ............... :---{ 6.0 mln : 2,980 .... -?:o-~-i~ .... ! ................... I---~-,-~¥~--/,-~i--I ,,,'----~:o-~-i-~ ....................... i'"~','~'-~'~i"i F'"'~:o'~'i'~ ....................... i'"~','~K-F~i"i ["TO:O'~;~'",,' .................. ]---~;-~--~-~r-~ F .................. I. .................. ~ .................. L .................. L .................. ~ .................. ," NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Xe:Jet Pump Approval Request Subject: Re: Jet Pump Approval Request Date: Thu, 15 Jul 1999 15:58:48 -0800 From: ]3 lair Wondz¢ll <]3 lair_Wondzell~admin, stat¢.ak.us> To: Erickson&Versteeg <N1177~mail.aai.arco.com> CC: Dobson&Sloan <N 1127~mail.aai.arco.com>, Beck&Zuspan <N 1052~mail.aai.arco.com>, Ryan L Stramp <RSTRAMP~mail.aai.arco.com>, Goldmann&Hill <N 1297~mail.aai.arco.com> Hans, Thanks for visiting with me this afternoon on this situation. As I understand that you have only two pipelines to Tarn, one for production and the other for lift gas or injection. Since you will need the line for injection, if the for four subject wells are to be lifted during the test it will have to be with the jet pumps, powered by water. We agree this is a reasonable approach and that your efforts should reduce casing corrision to an acceptable level. Therefore testing jet pumps powered by injection water during the Tarn water injection test is acceptable. Blair Wondzell, 7/15/99 Erickson&Versteeg wrote: Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-__~335, 2N-337___A, and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn Mt header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by. annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (~ 90 days), and the iow annulus injection rate 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils~year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils~year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659- 7687 i of I 7/15/99 4:00 PM Jet P. ump Approval Request Subject: Jet Pump Approval Request Date: Tue, 13 Jul 1999 16:27:19-0900 From: "Erickson&Versteeg" <N1177~mail.aai.arco.com> To: blair_wondzell@admin, state.ak.us CC: "Dobson&Sloan" <N 1127~mail.aai.arco.com>, "Beck&Zuspan" <N 1052@mail.aai.arco.com>, "Ryan L Stramp" <RSTRAMP~mail.aai.arco.com>, "Goldmann&Hill" <N 1297 @mail.aai.arco.com> Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A, and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn MI header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (~ 90 days), and the low annulus injection rate (~ 2,000 bwpd), the existing schedule for chemical treating of injection water is expected 'to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of I 7/13/99 4:52 PM STATE OF ALASKA _.. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Alter casing __ Change approved program _~X_ Suspend __ Repair well __ Pull tubing __ Operation Shutdown__ Reenter suspended well__ Plugging __ Time extension __ Variance __ Perforate __ Stimulate __ Other __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 144' FNL, 1113' FEL, Sec 3, T9N, R7E, UM At top of productive interval: 607' FNL, 268' FWL, Sec 3, T9N, R7E, UM At effective depth: 601' FNL, 267' F-WL, Sec 3, T9N, R7E, UM At total depth: 600' FNL, 267' FWL, Sec 3, T9N, R7E, UM 5. Type of Well: Development X._.~. Exploratory ~ Stratagrapic ~ Service ~ 6. Datum of elavation (DF or KB) 28' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-345 9. Permit number: 98-113 10. APl number: 50-103-20264-00 11. Field/Pool: Kuparuk River Field/Tarn Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical 7431 feet Plugs (measured) none 5633 feet Effective Depth: measured 7255 feet Junk (measured) none true vertical 5456 feet Casing Length Size Cemented Conductor 80' 16" 9 cu yds High Early Surface 2760' 7-5/8" 40sx AS III, 240sx CG, Production 6732' 5.5" 42 bbls Class G Liner 655' 3.5" Included above Measured depth Trueverticaldepth 108' 108' 2789' 2306' 6760' 4961' 7415' 5616' Perforation Depth measured 7105'-7145' true vertical 5306'-5346' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, EUE tubing @ 6778' MD. Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 6760' MD; SSSV: None, nipple @ 531' MD. 13. Attachments Description summary of proposal _X Detailed operations program ORIGIN,AL 14. Estimated date for commencing operation 15. Status of well classification as: Convert to Water Injector for approx 60 days Oil _X Gas __ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Suspended__ Signed ' /F//v Title: Production Engineering Supervisor FOR COMMISSION USE ONLY Date ~/'~/~ ~' Conditions of approve: ~otify · ' ' so Comlss~on representitive may witness Plug integrety __ / BOP test __ Location clearance __ Mechanical integrety test_~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Hev 06/15/88 OR,GINAL SIGNED BY Robert N. Chdstenson SUBMII IN IHIPLICA1E Attachment #1 2N-345 Request for Variance Approval is requested to inject KRU produced water into Tarn production Well 2N-345 for the 60 day period from August 15, 1999 to October 15, 1999. The test will be used to simulate water breakthrough on a fracture stimulated production well. The data will assist the ongoing evaluation of the Tam Reservoir for a water-alternating miscible gas recovery mechanism. A variance is requested of AOGCC 20 ACC 25.030 requiring that a cement evaluation log be performed on injection wells. Well 2N-345 was completed as a producer and will be returned to production service after the water injection test. The primary cement job saw full returns during displacement of the cement as documented in the attached reports. The tubing x production casing annulus will be tested for MIT compliance prior to initiating injection. Cement bond logs conducted on seven Tam injection wells showed good to excellent bond. Well 2N-345 was cemented with a similar program. The test strategy will be to maintain injection below the fracture gradient. The surface injection pressure will be kept below approximately 750 psi. which should result in injection rates less than 1000 BWPD. Maintaining the integrity of the existing fracture stimulation is critical for reservoir analysis. A pre-injection pressure build-up test was completed on 7/17/99. A pressure build-up test will be conducted after the well is returned to production. This data will be available to the Commission upon request. ARCO Alaska, Inc. Cementing Details Well Name: 2N-345 ' Report Date: 07118/98 Report Number. '1 Rig Name: DOYON 14t AFC No.: AK 9509 Field: TARN 5-1/2 X3-1/Z' 6-3/4 0 7414 7256 , I C, entrallzers State type used, intervals covered and spacing Comments: 20~ 3-112X6-1/2 STRAIGHT BLADE CENT ALL 20 JTS 3-1/2, '11~ 5-1/2 X 6-3/4 GEMOCO CENT ON BTM 11 JTS 5-1/2, 16~ 5-t/2 X6-1/2 CENTERING GUIDES ON SURFACE TO 278~' , Mud Weight: PV(pdor cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.0 22 t 8I 21 15 57 VIS BEFORE Gels before: Gels after. Total Volume Circulated: 41 VIS AFTER 7111 518 35O BBL Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 BBL , , , , Spacer 0 Type: Volume: Weight: Comments: ARCO 40 12.0 , Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 70 42 BBLI '15.8 1.17 Additives: Tall Cement 0 Type: Mix wfl' temp: J No. of Sacks: I Weight: Yield: Comments: , , Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WL Up: Comments: 2 2 125 , Reciprocation length: Reciprocation speed: Str. Wt. Down: Theoretical Displacement: Actual Displacement: : Str. Wt. in mud: 164.1 164.6 Calculated top of cement: I CP: Bumped plug: I Floats held: Date:T118FJ8 YESI NO ~me:0230 Remarks:LOST 170 BBL MUD WHILE ClRC & COND. BUMPED PLUGS BUT FLOATS DID NOT HOLD. WELL CONTINUED TO FLOW, SHUT ANNULAR &WAITED 4-1/2 HR. NO PRESSURE ON CASING, 1 '10 PSI ON CASING OPENED UP ANNULAR AND ALLOWED TO FLOW UNTIL FLOW MANAGEABLE (> .1 BPM) Cement Company: Rig Contractor: Approved By: DS DOYON R.W. SPRINGER / _ 4b, Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 11.625 I AK9509 07118/98 13 07107/98 09:00:00 Rig Relase - hfs: Well: 2N-345 Depth (MD/TVD) 743t/5633 Prev Depth MD: 743t Progress: 0 C~'ntmctor: DOYON ! Daily Cost $ 240478 Cum Cost $1175441 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 5-1/2 x~1/2" Next Csg: Shoe Test: 16.0 ppg E.M.W.F.I.T. Operation At 0600: RIG RELEASED- MOVING TO 2N-313 Upcoming Operations: FINISH MOVE & SPUD ! I~ID TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL Diesel/Brine N T,ST' 0711 07110/98 WEIGHT ROT VV'I' SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL PPg VISCOSITY PU VVT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP SO VVT TYPE TYPE TYPE " ::. i: :: ;;'"" ~&?#A '.'[~.~ :; :: ~ ".: ~' GELS AVG DRAG SERIAL NO SERIAL NO ~fOLUME FUEl_ USED 1300 II APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WA'rER USED - 350 07118/98 BBLS S6LIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL :'/: :~-:':::? :.-? !-! ~._W~. ~i; f:":'.~ '::::; HOLE VOLUME PUMP PRES ADTIAST ADT/AST ~OURCE WELL TEMP °F 38 Obbl 26001 I I =1 ~ M.T PUMP NO WO. 2 WO. ~ RA~ ~.~) W~ND SP~D 4 ~111 ~h LINER SZ RPM 1 RPM 1 PRESSURE (ps~ WIND DIRECTION 45~ 61611 LGS SPM I TFA TFA INJECTION FLUIDS CHILL FACTOR °F 38.00 % 65 I I I Water Base Muds 1089 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2 0 2751 i I IIIII IIIII 5 69 DALLY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $soo III _o ~ERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $~3e~ III III III 11~ COMPANY MUD WT GR^OE GRADE TOT FOR WELL (hbo SERWCE BAROID 1o.ol I I III III t71~ PERSONNEL TOTAL 47 '~ME I ~NO HOL~,, S i ~C~ I ' ~,SC-CT, I~O~S~ i:: :: ~; ;;-~;~~F~,,'~o0o~'~-;!; ; ': :~;,: 00:00 02:30 2.50 CEMENT PROD Casing and CONTINUE ClRC, LO~T TOTAL OF 170 BBL MUD -5~ % Cementing RETURNS -PJSM & PUMP 10 BBL H20, 20 BBL ARCO PREFLUSH, 40 BBL ARCO SPACER, DROP PLUG, 42 BBL CMT ~ t5.8 PPG, DROP PLUG, 20 BBL H20, DISPLACE W/SEAWATER USING RIG PUMPS, BUMPED PLUGS ~ CALC DISPLACEMENT PARTIAL GOING TO FULL RETURNS DURING DISPLACEMENT OF CMT. 02:30 07:00 4.50 PRB_CJOB PROD Casing and FLOATS NOT HOLDING, ANNULUS FLOWING- SHUT Cementing ANNULAR & WOC 07:00 08:30 1.50 PRB_CJOB PROD Casing and BLEED OFF PRESSURE & ALLOW TO FLOW- 25 BBL GAIN- Cementing MONITOR WELL 08:30 09:00 0.50 CEMENT PROD Casing and RIG DOWN CEMENTING HEAD & LANDING JOINT. Cementing 09:00 11:00 2.00 CASG PROD Casing and INSTALL PACKOFF & TEST TO 5K Cemen'dng 11:00 17:30 6.50 RUN_.COMP COMP Completion R/U & RUN 3-1/2" COMPLETION. 17:30 t8:30 t .00 RUN_COMP COMP Casing and M/U CIRC HEAD, SPACE OUT- M/U PUP- TBG HGR- Cementing LANDING JT. 18:30 19:00 0.50 EVAL COMP Evaluation TEST CASING TO 3500 PSI/30 MIN. 19:00 20:00 1.00 OTHER COMP Other PUMP 55 BBL DIESEL DOWN 'rBG & ALLOW TO U-TUBE F/FREEZE PROTECTION. 20:00 20:30 0.50 OTHER COMP Completion LAND TBG RILDS 20:30 22:00 ~ .50 EVAL COMP Completion TEST TBG TO 3500 P$1/~ 0 MIN- TEST ANNULUS TO SAME- LAY DOWN LANDING JT. 22:00 23:00 1.00 NU_ND COMP Completion NIPPLE DOWN BOPE New Daily Drilling Report Page 1 ARCO Alaska, Inc. r . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 19, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-345 (Permit No. 98-113) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-345. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad RECEIVED AUG 27 1998 Alaska Oil & Sas Cons. Commission Anchorage 8~2O/98 GeoQuest 500 w. International AJrpor~ Fload Anchorage, AK 99518-1199 AI'rN: Sherrle NO. 11454 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool (Open Hole) Well Job # Log Description Date BL RF Sepia Color US Print Tape KRU 2N-345 ~ :~'Z.'Z.- 98412 DSI 980716 I I 1 , ,, , , , , ,, , , , , , ,, SIGNED: ~~~, DATE: ., Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. F_ EIVED RC AUG 27 19 8 Naska Oil & Gas ConS. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well tl '~ ~ ~ ~, ,~ ;'"' s s. .o o s .v,o AUG 2 Name of Operator 7 Pe~it Num~r 0il & Cons. t ARCO Naska, Inc 98-113 3 Addre~ 8 APl Number P.O. Box 100360, ~orage, AK ~51~0360 5~103-2~ 4 Location of well at sudace 9 Un~ or Le~e N~e 144'~L, 1113'FEL, Sec. 3, T9N, R7E, UM ~ ~;:;;'"~'[ ~',';~J ; ":~ ~- Kupamk River Unit , ', ;-~ c ~ ~ 10 Well Number At Top Producing Inte~al /;,_., ~. . ~ j .~c[. ~.~r, '~ 11 Fi~d~dPool 60~' FNL, 267' ~L, Sec. 3, T9N, R7E, UM :' ............ ~ ,*~. - Kup~k River 5 Elevation in f~t (indicate KB, DF, etc.) ~ 6 Le~e D~igna~ and Sefi~ No. Tam Oil P~I RKB 28', Pad 121'~ ADL 375074 ~K 4293 12 Date Spudded 13 Date T.D. Rea~ed 14 Date Comp., S~p. or ~d. ~15 Water De~, if o~hore J16 No. of Com~efio~ I 07-Ju1-98 1~Jul-98 18-Ju1-98 NA feet MSL~ 1 17 Total Depth (MD+~D) 18 Plug Back D~th (MD+~D) 19 Dire~ion~ Su~ey 20 Dep~ ~ere SSSV set 21 ~ic~ of 7431' MD & 5633' ~D 7255' MD & ~56' ~D YES ~ NO ~ NA feet MD 10~ APPROX ~ T~e Ele~dc or ~her Lo~ Run G~Res, G~CCL 23 CASING, LINER ~D CEMENTING RECORD S~ING DEP~ MD CASING SIZE ~ GR~E TOP BTM HOLE Sl~ CEMENT RECORD 16' 62.58~ H-40 SURF. 108' 24' 9 cu.y~ High EaHy 7.625' 29.7~ L-80 SURF. 2789' 9~875' 40 sx ASlII LW, 240 sx Cla~ G 5.5' x 15.5~ L-80 SURF. 67~ 6.75' 42 ~ls ~a~ G 3.5' 9.3~ L-80 6760' 741~ 6.75' (included above) 24 Pedoratio~ open to Produ~ion (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEP~ S~ (MD) PACKER S~ (MD) 3.5' 6~8' 6760' (CSR) 7105'-7145' MD 5306'-5346' ~D 4 spf 26 ACID, ~C~RE, CEME~ SQUE~E, ~C DEPTH INTERV~ (MD) AMOUNT & KIND OF MATERIAL USED 7105'-7145' pump~ 20129~ of 1~18 propp~t w/ 182~0~ a~ 10 p~ at ~e pe~. Dato First Produ~ion Meth~ of O~rafion (~o~n~, ~as fi~, otc.) ~98 Uff Gas Date of T~t Houm Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO ~7/98 11.00 TEST PERIOI: 697 ~2~ 0 176~ 1764 Row Tubing Casing Pr~sure C~CU~TED OIL-BBL GA~MCF WATER-BBL OIL GRAVIS-APl {~) Pr~s. 3~ 0 24-HOUR ~TE: ]52] 26~ 0 39.7° 28 CORE DATA Bdef d~cdption of lithology, portia, fra~ur~, appar~t dips and presence of oil, gas or water. Su~ core ~ips. WA ommCs h n Form 10~407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Reservoir fr3) 6952' 5153' Base Reservoir (T2) 7146' 5347' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 3'2. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 7/24/98 ARCO ALASKA INC. WELL SLIMMARY REPORT Page: 1 WELL:2N-345 RIG:RIG # 141 WELL_ID: AK9509 TYPE: AFC: AK9509 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:07/07/98 START COMP: FINAL:07/19/98 WI: 0% SECURITY:0 API NUMBER: 50-103-20264-00 07/06/98 (D1) MW: 0.0 VISC: TD: 0'( 0) Moving rig SUPV:DPB Moving from to 2N-345 0 PV/YP: 0/ 0 APIWL: 0.0 07/07/98 (D2) TD: 266' (266) SUPV:RWS MW: 9.5 VISC: 124 PV/YP: 40/42 Drilling @ 705' APIWL: 8.5 Accept rig @ 0900 hrs. 7/7/98. Wash and drill cement in conductor from 38' to 108' Drilled from 108'-266' 07/08/98 (D3) TD: 2510' (2244) SUPV: RWS MW: 10.2 VISC: 65 PV/YP: 20/25 at casing point, POH APIWL: 5.5 Drilled from 266'- 2510'. Maximum gas 3500 units w/initial cuttings to surface. Maximum gas cut to 9.8 ppg after gas buster. 07/09/98 (D4) TD: 2800' (290) SUPV: RWS MW: 10.2 VISC: 45 PV/YP: 18/12 nippling up BOPE APIWL: 4.8 Continue drilling from 2510' to 2800'. Pump lo-hi vis sweeps. Wiper trip from 2800' to 1215' Run 7-5/8" casing. Pump first stage cement. Begin to pump second stage cement, packing off of hanger w/gravel, lost returns. Broached hanger reduce pump rate, wash hanger area, restored circ and lead cement to surface. 07/10/98 (D5) TD: 2800'( SUPV:RWS 0) MW: 9.5 VISC: 45 PV/YP: 15/11 RIH w/drilling assembly APIWL: 7.0 Finish cementing, cement to surface. N/D diverter system. N/U BOPE and test. Drill and ream cement to 2323' Drill and ream float equipment and cement from 2623' to 2766' 07/11/98 (D6) TD: 2820' ( 20) SUPV:RWS MW: 9.5 VISC: 48 PV/YP: 15/15 M/U BHA & RIH APIWL: 7.0 07/12/98 (D7) TD: 4151' (1331) SUPV:RWS Drilled from 2766'-2820' cement, shoe and 20' new hole. Perform FIT to 16.0 ppg EMW. POH, no bit. Attempt to fish bit. MW: 9.5 VISC: 49 PV/YP: 16/16 Drilling @ 4900' APIWL: 6.2 Continue RIH chase fish to stage collar @ 1509'. Chase fish to 2820'. POH w/fish. Drilled from 2820' to 4151' 07/13/98 (D8) TD: 5373' (1222) SUPV:RWS MW: 9.5 VISC: 48 PV/YP: 14/19 DRILLING @ 5819' APIWL: 5.5 Drilled from 4151' to 5373' Perform LOT, 16.0 ppg EMW. Making connection, well flowing, shut well in. Attempt to kill. Circ w/partial returns while moving pipe. Shut in well. Monitor pressure and build volume. Circ hole volume after bleeding off pressure and opening well. Monitor well, well flowing. Monitor well. 07/14/98 (D9) TD: 6846' (1473) SUPV:RWS MW: 9.6 VISC: 46 PV/YP: 13/15 Drilling @ 7194' Drilled from 5373' to 6846' APIWL: 5.0 07/15/98 (D10) TD: 7431' (585) SUPV:RWS MW: 10.0 VISC: 48 PV/YP: 19/19 APIWL: 4.6 Attempt to W/L log, unable to get out of casing Drilled from 6846' to 7431'. Pump lo-hi vis sweeps and circ hole clean. Well flowing. Wiper trip to 2699' Slight flow at shoe. 07/16/98 (Dll) TD: 7431' ( 0) SUPV:RWS MW: 10.0 VISC: 49 PV/YP: 18/20 Circ bottoms up after wipertrip APIWL: 4.8 E-line run, unable to go past shoe. RIH to log. RIH w/side wall cores. 07/17/98 (D12) TD: 7431' ( 0) SUPV: R.W. SPRINGER 07/18/98 (D13) TD: 7431'( 0) SUPV:R.W. SPRINGER MW: 10.0 VISC: 47 PV/YP: 18/15 WOC Run 3.5" x 5.5" casing. MW: 0.0 VISC: 0 PV/YP: 0/ 0 Freeze Protect well Circ and condition. Lost returns. Pump cement. Floats not holding, annulus flowing. Install packoff and test to 5000~. Run 3.5" completion. Freeze protect. ND BOPE, NU tree. APIWL: 4.8 APIWL: 0.0 07/19/98 (D14) TD: 7431'( 0) SUPV:R.W. SPRINGER MW: 0.0 VISC: RIG RELEASED TO 2N-313 0 PV/YP: 0/ 0 APIWL: 0.0 Test packoff to 5000~. Freeze protect well. Release rig @ 0300 hrs. 7/19/98 End of WellSummary for Well:AK9509 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-345(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 2N-345 PERFORATE, PERF SUPPORT 0719981448.5 DATE DAILY WORK UNIT NUMBER 07/21/98 PERFORATE NEW TARN WELL 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES STEPHENSON JONES FIELD AFC# CC# Signed ESTIMATE K85116 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann J Final Outer Ann 1000 PSI 25 PSI 580 PSI 620 PSII 50 PSII 50 PSI DAILY SUMMARY ISWS RAN 2.5" GUN, WRONG CHARGES. RAN GR/CCL JEWERLY LOG WHILE WAITING ON CORRECT GUNS. RAN & PERFED FROM 7105' TO 7145' W/2.5" HC, BH, 4 SPF, 180 DEG PHASED, 90 DEG ORIENT IN 2 RUNS.[Perf] TIME LOG ENTRY 07:30 SWS MIRU, HELD TGSM. LRS RU & PRESS TEST TBG & LINER TO 2500 PSI FOR 15 MIN, GOOD. MU 20' - 2.5" HC. PT LUB TO 3000#. 10:15 RIH W/20'- 2.5" HC, 4 SPF, DP, 180 DEG PHASED, 90 DEG ORIENT, SAFE FIRE, MPD, GUN GR, CCL. WRONG GUN, SHOULD BE BIG HOLE CHARGES. 11:20 POH & LADI DOWN GUN. 12:30 MU TOOLS & PT LUB TO 3000#. RIH W/GR/CCL & RAN GR/CCL JEWELRY LOG FROM 7250' TO 6600'. CORR TO SPERRY SUN ROP/DGR/EWR4 LOG 7-16-98. POH & LD TOOLS. RAN WHILE WAITING ON NEW GUNS 14:45 MU 20' - 2.5" HC GUN & PT LUB TO 3000#. 15:15 MIH W/20'- 2.5" HC, BH, 4SPF, 180 DEG PHASED, 90 DEG ORIENT, SAFE FIRE, MPD, CCL. CORR TO SWS JEWERLY LOG 7-21-98. PERF FROM 7125' TO 7145' W/350 PSI WHP. 17:00 POH & LD GUN, ALL SHOTS FIRED. 18:00 MU 20' GUN & PT LUB TO 3000#. MIH W/20' - 2.5" HC GUN AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 7105' TO 7125' W/350 PSI WHP. 19:45 POH & LD GUN, ALL SHOTS FIRED. 20:45 RIG DOWN. 21:30 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~[ WELL SERVICE REPORT '' K1(2N-345(W4-6)) WELL JOB SCOPE JOB NUMBER ' 2N-345 FRAC, FRAC SUPPORT 0724980851.3 DATE DAILY WORK UNIT NUMBER 07/23/98 FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-YOKUM RIGGS FIELD AFC# CC# Signed ESTIMATE AK9509 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 280 PSI 180 PSI 501 PSI 500 PSII 45 PSI 50 PSI DALLY SUMMARY [Frac-Refrac]PUMPED FRAC PER PROCEDURE W/50 # XL GW AT AN AVG. RATE OF 20 BPM AND PRESSURE OF 2400 #. SCREENED OUT 81 BBL INTO THE LAST STAGE. PUMPED 201296 # OF 12/18 PROPANT W/182950 # AND 10 PPG AT THE PERFS. LEFT 18000 # PROP IN 3.5" PIPE TOP TO BOTTOM. 2700 # BHP. PUMPED THE 3RD, 4TH, 5TH AND 6TH STAGES WITH RA TRACER 'rIME LOG ENTRY 08:55 09:25 MIRU HOLD SAFETY MEETING ( 17 PEOPLE ON LOCATION) PT LINES TO 12300 # PUMPED BREAKDOWN STAGE @ 40 BPM AND 5300 #. WENT TO 20 BPM W/50 # XL GW SHUT DOWN TO MONITOR PRESSURE. 10:30 PUMPED DATA FRAC @ 40 BPM AND 4674 # WENT TO 20 BPM AND 2508 # W/50 # XL GW SHUT DOWN TO ADJUST PAD. 13:20 PUMPED FRAC W/ADJUSTED PAD OF 375 BBL, 300 OF LINER FLUID AND 75 OF 50 # XL GW. 2750 # PRESSURE. PUMPED SB124 AMTIMMONY IN STAGES 3 AND 4 SC46 SCANDIUMIN STAGE 5 AND IR192 LRIDIUM IN STAGE6 14:30 SCREENED OUT 81 BBL INTO THE LAST STAGE. PUMPED 201296 # OF 12/18 PROPANT W/182950 # AND 10 PPG AT PERFS. LEFT 18000 # PROP IN THE 3.5" PIPE TOP TO BOTTOM 2700 # BHP. 15:15 RDMO DS. CHECK WELL OK From ~&12A&k0S ARCO ALAS~, INC. KUPARUK RIVER UNIT DOYON 141 2N-345 50-103-20264-00 AK-MM-80282 to 19072634566 at 07/15/98 10:28a SPERRY-SUN DRILLING SERVICES (TARN POOL) Pg 001/003 JULY, 1998 MagUTM VALUES: DECLINATION= 26.87 ° DIP ANGLE= 80.44° TOTAL FIELD STRENGTH= 57225nT DATE OF MAGNETIC DATA= 07/07/98 ARCO 2N-345 i5/Jul/1998 MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICJtL DOG FEET SECTION LEG 108.00 0.00 0.00 184.10 0.35 333.70 282.32 0.52 324.18 368.16 0.66 328.62 458.51 0.74 297.75 108.00 0.00 184.10 0.21 N 282.32 0.84 N 368.15 1.58 N 458.50 2.29 N 0.00 0.00 0.00 0.10 W 0.08 0.46 0.50 W 0.39 0.19 0.98 W 0.79 0.17 1.77 W 1.49 0.42 518.10 0.89 289.12 610.40 '4.17 249.67 700.04 8.32 240.63 789.79 11.20 243.49 881.40 11.96 242.49 518.08 2.62 N 610.28 1.69 N 699.37 2.62 S 787.81 9.70 S 877.56 18.06 S 2.55 W 2.22 0.32 6.37 W 6.13 3.82 15.08 W 15.29 4.74 28.55 W 29.49 3.25 44.93 W 46.74 0.86 973.86 15.40 240.27 1063.17 19.33 236.29 1154.11 21.13 234.62 1241.90 23.33 233.75 1339.72 25.56 234.25 967.38 28.57 S 1052.61 42.66 S 1137.94 60.51 S 1219.20 79.95 S 1308.24 103.74 S 64.09 W 67.01 3.76 86.69 W 91.11 4.59 112.58 W 118.92 2.08 139.50 W 147.95 2.53 172.25 W 183.27 2.29 1435.21 28.82 239.65 1529.77 30.85 244.18 1623.23 32.77 249.59 1 717.84 34 . 46 252.90 1809.99 37.34 256.90 1393.18 127.41 S 1475.21 149.49 S 1554.65 168.76 S 1633.44 185.56 S 1708.09 199.56 S 208.85 W 222.40 4.28 250.35 W 266.21 3.21 295.64 W 313.45 3.68 345.23 W 364.67 2.63 397.39 W 418.12 4.03 1903.60 40.81 261.12 1997.74 43.92 262.32 2092.01 47.86 2~4.7~ 2185.57 52.40 266.94 2280.03 54.26 267.44 1780.76 210.73 S 1850.31 219.84 S 1915.92 297.40 1975.89 232.55 S 2032.30 236.26 S 455.29 W 476.93 4.67 518.06 W 540.33 3.41 585.29 W 607.99 4.57 656.89 W 679.70 5.17 732.56 W 755.28 2.01 2373.36 56.63 267.42 2467.42 57.00 269.85 2561.50 57.93 265.44 2656.79 58.49 266.51 2755.44 59.13 264.99 2085.23 239.71 S 2136.72 241.58 S 2187.33 244.86 S 2237.53 250.54 S 2288.62 256.80 S 809.34 W 831.93 2.54 888.03 W 910.29 2.20 967.25 W 989.34 4.07 1048.04 W 1070.25 1.12 1132.19 W 1154.55 1.47 2855.05 59.11 264.06 2947.97 56.47 264.23 3041.34 55.71 264.07 3536.32 55.81 263.45 3231.00 55.63 263.29 2339.75 264.95 S 2389.27 272.97 S 2441.36 280.87 S 2494.80 289.41 S 2548.13 298.44 S 1217.29 W 1240.02 0.80 1295.49 W 1318.62 2.85 1372.58 W 1396.10 0.83 1450.63 W 1474.61 0.55 1528.34 W 1552.85 0.24 From to 19072634566 at 07/15/98 10:28a Pg 002/003 .. ~k0S ARCO ALASKA, INC. KUPARUK RIVER UNIT DOYON 141 2N-34~ S0-10.q-90)~;~-00 SPERRY-SUN DRILLING SERVICES (TARN POOL) JULY, 1998 MagUTM VALUES: DECLINATION= 26.87° DIP AN~LE~ 80.44" TOTA?. ~TRT.D RTRRN~TN DATR OF MA~NETTC DATA- 07/07/9~ ARCO 2N-345 15/Jul/1998 MEASURED ANGLE DIRECTION DEPTH DEG DEG V1ZRT~Ckt ~T~TUDE DEPTH FEET D~.PARTUR~ V~RT~CkL DOG FEET SECT I ON LEG 3324.99 55.63 264.11 3416.00 55.75 263.89 3512.75 54.02 263.93 3605.53 53.71 262.87 3700.09 53.73 263.62 2601.19 306.95 S 2652.49 314.81 S 2708.14 323.21 S 2762.85 331.82 S 2818.81 340.78 S 1605.45 W 1630.42 0.72 1680.22 W 1705.59 0.24 1758.91 W 1784.72 1.79 1833.34 W 1859.65 0.98 1909.04 W 1935.88 0.64 3794.90 54.20 263.56 2874.58 349.34 S 3885.19 54.44 263.90 2927.25 357.35 S 3978.19 53.41 266.54 2982.01 363.63 S 4075.50 52.61 266.54 3040.56 368.32 S 4168.59 52.63 267.27 3097.08 372.31 S 1985.23 W 2012.55 0.50 2058.13 W 2085.89 0.41 2133.02 W 2161.00 2.55 2210.61 W 2238.59 0.82 2284.47 W 2312.41 0.62 4260.98 54.86 265.27 3151.72 377.17 S 4353.00 56.13 266.78 3203.84 382.42 S 4447.07 55.58 265.92 3256.65 387.38 S 4542.13 55.23 265.11 3310.62 393.50 S 4636.26 54.73 266.46 3364.64 399.16 S 2358.80 W 2386.80 2.98 2434.45 W 2462.54 1.93 2512.14 W 2540.28 0.96 2590.15 W 2618.46 0.79 2667.03 W 2695.47 1.29 4731.17 55.75 268.97 3418.75 402.26 S 4824.30 55.25 267.19 3471.51 404.83 S 4919.58 54.44 267.39 3526.37 408.51 S 5014.74 56.29 267.18 3580.45 412.22 S 5109.13 55.59 266.86 3633.31 416.29 S 2744.93 W 2773.20 2.42 2821.63 W 2849.67 1.66 2899.44 W 2927.37 0.87 2977.65 W 3005.47 1.95 3055.74 W 3083.50 0.79 5202.86 54.83 265.99 3686.79 421.09 S 5299.99 54.44 266.25 3743.01 426.45 S 5390.82 53.89 266.67 3796.19 430.99 S 5487.40 51.04 265.67 3855.02 436.10 S 5580.11 47.68 265.89 3915.40 441.27 S 3132.57 W 3160.35 1.11 3211.59 W 3239.46 0.46 3285.09 W 3312.98 0.71 3361.49 W 3389.46 3.06 3431.64 W 3459.73 3.63 5674.44 44.24 266.18 3980.96 445.97 S 5768.13 41.43 265.99 4049.66 450.31 S 5861.84 38.18 267.52 4121.64 453.74 S 5955.87 33.20 266.69 4197.99 456.48 S 6050.90 27.53 266.86 4279.95 459.19 S 3499.28 W 3527.45 3.65 3562.82 W 3591.06 3.00 3622.70 W 3650.93 3.62 3677.47 W 3705.64 5.32 3725.42 W 3753.57 5.97 6140.01 23.95 266.09 4360.20 461.55 S 6232.37 20.84 264.49 4445.59 464.41 S 6326.53 17.26 264.53 4534.58 467.35 S 6422.55 13.55 268.87 4627.13 468.93 S 6519.90 10.00 276.33 4722.42 468.22 S 3764.04 W 3792.20 4.03 3799.10 W 3827.35 3.43 3829.69 W 3858.08 3.80 3855.12 W 3883.52 4.04 3874.93 W 3903.11 3.96 From to 19072634566 at 07/15/98 10:28a Pg 003/003 :k0S ARCO ALASKA, INC. KUPARUKRIVER UNIT DOYON 141 2N-345 50-103-20264-00 AK-MM-80282 SPERRY-SUN DRILLING SERVICES (TARN POOL) JULY, 1998 MagUTM VALUES: DECLINATION= 26.87° DIP ANGLE= 80.44° TOTAL FIELD STRENGTH= 57225nT DATE OF MAGNETIC DATA= 07/07/98 ARCO 2N-345 15/Jul/1998 MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG 6609.49 6.60 273.85 4811.06 467.02 S 6705.06 2.25 278.48 4906.33 466.37 S 6802.71 0.86 326.63 5003.94 465.48 S 6896.83 0.97 334.51 5098.05 464.17 S 6991.08 0.94 355.56 5192.29 462.68 S 3887.81 W 3915.75 3.82 3895.14 W 3922.96 4.56 3897.44 W 3925.14 1.84 3898.18 W 3925.71 0.18 3898.58 W 3925.94 0.37 7075.59 0.79 328.56 5276.79 461.49 S 7180.42 1.08 333.85 5381.60 459.99 S 7273.82 0.38 294.42 5475.00 459.07 S 7356.77 0.28 235.57 5557.94 459.07 S 7432.00 0.28 235.57 5633.17 459.28 S 3898.94 W 3926.15 0.51 3899.75 W 3926.78 0.29 3900.42 W 3927.34 0.88 3900.84 W 3927.75 0.40 3901.14 W 3928.08 0.00 STATE OF ALASKA ..... ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Alter casing __ Change approved program __ Suspend __ Repair well __ Pull tubing __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 144' FNL, 1113' FEL, Sec 3, T9N, R7E, UM At top of productive interval: 607' FNL, 268' FWL, Sec 3, T9N, R7E, UM At effective depth: 601' FNL, 267' FWL, Sec 3, T9N, R7E, UM At total depth: 600' FNL, 267' FWL, Sec 3, T9N, R7E, UM Operation Shutdown __ Reenter suspended well __ Plugging __ Time extension __ Variance X Perforate__ Stimulate __ Other__ 5. Type of Well: Development X~ Exploratory ~ Stratagrapic ..~ Service ~ $. Datum of elavation (DF or KB) 28' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-345 9. Permit number: 98-113 10. APl number: 50-103-20264-00 11. Field/Pooh Kuparuk River Field/Tarn Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical 7431 feet Plugs (measured) none 5633 feet Effective Depth: measured true vertical 7255 feet Junk (measured) none 5456 feet Casing Length Conductor 80' Surface 2760' Production 6732' Size Cemented 16" 9 cu yds High Early 7-5/8" 40sx AS III, 240sx CG, 5.5" 42 bbls Class G Measured depth Truevedicaldepth 108' 108' 2789' 2306' 6760' 4961' Liner 655' 3.5" Included above 7415' 5616' Perforation Depth measured 7105'-7145' true vertical 5306'-5346' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, EUE tubing @ 6778' MD. Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 6760' MD; SSSV: None, nipple @ 531' MD. 13. Attachments Description summary of proposal _X Detailed operations program__ BOP sketch_ 14. Estimated date for commencing operation 115. Status of well classification as: Install jet pump in well - July, 1999 J Oil _X Gas __ I 16. If proposal was verbally approved Blair Wondzell 7/15/99J Name of approver Date approvedl Service 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Suspended__ Title: Production Engineering Supervisor FOR COMMISSION USE ONLY IConc~tk~n.~,,CLr~'~pproval: Notify Comission so representitive may witness "J~ ~ -C~ Plug integrety __ BOP test__ Location clearance__ Mechanical integrety test__ Subsequent form required 10- '/"~,~"~, ~ .)P, IGINAL SIGNED'BY IApproved by order of the Comm ssion ~obert N Chdstensorl I-orm 10-403 Hev 06/15/88 Commissioner SUBMI] IN I Attachment 1 Install Jet Pump Tarn Well 2N-345 The water injection test at drill site 2N provides an opportunity to utilize injection water as a power fluid source for a jet pump installation in production Well 2N-345. The jet pump will be used to establish stable production prior to shutting in the well for a pressure build-up. The jet pump is a reverse circulation pump, and "hard line" with a check valve will tie the injection header to the production annulus. The jet pump will be installed in the production tubing at an open sliding sleeve at 6652', which will result in tubing by annulus communication. A variance for Well 2N-345 is requested for the 90 day period from July 15, 1999 to October 15, 1999 to complete the PBU and test the jet pump application. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the low annulus injection rate (- 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-I'N: Sherrie NO. 11388 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/31/98 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia Color Print ~KRU 2N-345 98376 DSl 980'/16 1 KRU 2N-345 98376 DS:[ SS'Z'VZ) 980'/16 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Juno 11. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drilling Tcam Lcadcr ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2N-345 ARCO Alaska, Inc. Permit No.: 98-113 Sur. Loc.: 143'FNL. 1113'FEL. Sec. 3. T9N. R7E. UM Btmholc Loc: 604'FNL, 283'FWL, Sec. 3, T9N. R7E. UM Dear Mr. Mazzolini: Encloscd is thc approved application for pcrmit to drill thc above referenced well. The pcrmit to drill does not cxcmpt you from obtaining additional pcrnfits required by law from other governmental agcncics, and does not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Approval of am~ular disposal of drilling wastes is contmgcnt on obtaining a well cemented surface casing confirmcd by a valid Formation Intcgrits.' Test (FIT). Cementing records, FIT data,, and any CQLs must be sublnittcd to thc Commission on form 10-403 to ensure the requirements of 20 AAC 25.080 are met prior to initiating disposal operations. Blowout prevention cquipmcnt (BOPE) must be tcstcd in accordancc with 20 AAC 25.035. Sufficient noticc (approximatcly 24 hours) of the BOPE test pcrformcd before drilling below the surface casing shoe must bc given so that a rcprcsentativc of thc Commission max' witness the test. Notice ma5' be given by contacting the Commission pctrolcum field inspector on the North Chairman BY ORDER OF THE COMMISSION dlf/cnclosures cc~ Dcpar:~ncnt of Fish & Game. Habitat Section xv/o cncl. Dcpartmcnt of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Ddll X Redrill E I lb. TypeofWell Exploratory [~ StratigraphicTest [~ Development Oil X Re-Entry r- Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4293 ADL 375074'~'' 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 143' FNL 1,113' FEL Sec 3 T9N R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 604' FNL, 283' FWL Sec. 3, T9N, R7E, UM 2N 345 #U-630610 At total depth 9. Approximate spud date Amount 604' FNL, 283' FWL Sec. 3, T9N, R7E, UM 6115198 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property lineI 2N 343 MD 7,346' 604' @ target feet -1,000' feet 2,560 'I'VD 5,532' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 56° Maximum surface 1,656 psig At total depth (TVD) 2,425 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx Permafrost Cement 9-7/8" 7-5/8" 29.7 ppf L-80 BTC-Mod 2,880' 28' 28' 2,880' 2,300' 1. 50 sxAS3L, 240 sx CIG 2. 250 sx AS3L, 60 sx AS 1 63,4'' 5Y2" 15.5 ppf L-80 LTC-Mod 6,758' 28' 28' 6,758' 4,944' 200 sx CIG 63,4'' 3Y2" 9.3 ppf L-80 8rd EUE 588' 6,758' 4,944' 7,346' 5,532' (included above) 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) ,., ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth i'~n~ !tii~°lr RECEIVED Intermediate Production : Liner Perforation depth: measured true vert ca Alaska 0ii & Gas Cons. C, ommi.ssio ' Anch~a.~e 20. Attachments Filing fee X Property plat I~ BOP Sketch X uiv~rterSketch X Ddlling program X Drilling fluid program X Time vs depth plot I-~ Refraction analysis r~: Seabed report Fi 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~/'p~ ~'/~~~ Title Drilling Team Leader Date ! ~ ~ Commission Use Only Permit Number I APl number [ Approval date ~J'~"/t 3 50- | ~3 - 2[ ~. fe~ _..,// ~/ See cover letter for other requirements Conditions of approval Samples required E! Yes ,~ No Mud Icg required [~ Yes [~ No Hydrogen sulfide measures []Yes ~ No Directional survey required [~+ Yes E~ No Required working pressure for BOPE E] 2M [~,3M E,' 5M ~ 10M E,' 15M Other: '~ ' ; , I '~- · 0nc,ne,, S gned By David W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO KRU 2N 345 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS ¼ I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / USA 13-5/8" 5,000 psi WP ...~1 L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom CHOKE LINE ~~0 psi WP OCT ~~ MANUAL GATE VALVE h13-5/8" 5,000 psi WP DRILLING SPOOL '~~ w/two 3" 5,000 psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe Cons, 0orr, missio~ Anohorage Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) 345 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permafrost~::::::: 1,216' MD :!:!:!:i Stage :i:i:i:i ~-~-~.~ Collar .:.:.:. 1,475' MD :::::: ,o,,,,.. .,,.,,o, ,,,,.,., ,,.,..,, Top of ....,..., West Sak 1,263' MD :!:i:!:i: Base of West Sak 2,145' MD 7-5/8" Surface Casing at 2,88O' MD Top of Cement at 6,200' MD 5-1/2" Production Casing at 6,758' MD 3-1/2" Production Casing at 7,346' MD .:.:.:-:.:.: :::::::::::: :::::::::::: :::::::::::: .:.:.:.:.:.: ... i:i: .. :.:.:.: :.1. ::;::::::::: :::::::::::: :::::::::::: :::::::::::: :::::::::::: :::i:i: :.:.:.: ,., ¥:::.: :::.::.: ::::.:.: i:i::::: 9-7/8" iiiiiiiiHole ..-...% ::i:i:i: 6-3/4" Hole Conductor Casing Size / Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 20" hole Volume Calculations: (135 If) (0.7854 cf/If) (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slurr7 Yield 0.93 cf/sx Surface Casing excess 7-5/8" in 9-7/8" hole Stage 1: Volume (605 If) (0.2148 cf/If) (1.45) = 188 cf Lead (188 cf) /(4.42 cf/sx) = 43 sx Tail (800 If) (0.2148 cf/If) (1.45) = 249 cf shoe joint vol 21 cf + (249 cf) /(1.15 cf/sx) = 237 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCl2) + 1.5% D79 (ext.)+ 0.4% D46 (defoam.) Tail (CIG cmt + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 188 cf or 50 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 249 cf or 240 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing Stage 2: Vol. Lead Tail excess (1,216 If) (0.2148 cf/If) (4.00) = 1,045 cf (109 If) (0.2148 cf/If) (1.45) = 34 cf (1,078 cf) /(4.42 cf/sx) = 244 sx (0 If) (0.2148 cf/If) (4.00) = 0 cf (150 If) (0.2148 cf/If) (1.45) = 47 cf (47 cf) /(0.93 cf/sx) = 50 sx System: Lead (Amtic Set 3 Lite cement + 3.5% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,078 cf or 250 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size ! Hole Size 5-1/2" and 3-1/2" in 6-3/4" hole Depth: 7,346' Top of 3-1/2" casing 6,758' Top of Cement 6,200' Excess Calculated: 50% BHT (Static): 160~ F 130~ F BHT (Cbc): excess Volume around 5-1/2" (558 If) (0.0835 cf/If) (1.50) = 70 cf Volume around 3-1/2" (588 If) (0.1817 cf/if) (1.50) = 160 cf 230 cf shoe joint vol 4 cf + (230 cf) /(1.20 cf/sx) = 195 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% D800 (ret.) Slurry Volume: 230 cf or 200 sx Slurry Weight 15.8 ppg C/ass G Slurry Yield 1.20 cf/sx Thickenin~l Time 3.5 - 4.5 hours 6/5/98 - ARCO Alaska, Inc. -- GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 345 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (2,880'+ MD 2,300' TVD) according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. AOGCC Casing Test Pressure Criteria: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (2,300' TVD) * (0.25 psi/ft) = 575 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (6, 450 psi) = 4,515 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 63,4`' hole to TD (7,346' MD 5,532' TVD) according to directional plan. Run LWD logging equipment. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 51/~'' L-80 LTC Csg X 3Y2" L-80 8rd EUE Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. AOGCC Casing Test Pressure Criteria: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (5,532' TVD) * (0.25 psi/ft) = 1,383 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (7,000 psi) = 4,900 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (10,160 psi) = 7,112 psi 10. Run 31/2'' L-80 8rd EUD Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Shut in and secure well. 2N 345 mlp, 06/08/98 r ARCO Alaska, Inc. 13. Clean location, RD and move to next well on 2N pad. Well will be left ready for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 7-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. 2N 345 mlp, 06/08/98 --~ ARCO Alaska, Inc. --~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 345 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~l point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 __.10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Degasser *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 16.0 ppg EMW (0,83 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,656 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.83 - 0.11) = 1,656 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. 2N 345 mlp, 06/08/98 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 345 is 2N 343 about 1,000' southwest. Drillinq Area Risks: The primary risk in the 2N 345 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.5-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations- Incidental fluids developed from drilling operations will be either injected into a nearby annulus or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 345 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 345 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no Underground Sources of Drinking Water (USDW's) open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales, The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi 2N 345 mlp, 06/08/98 - ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/2" 15.5 L-80 3 LTC-M 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ,_E.~.pe_c..t.ed.....~?r.?ati_o...n....~..o.....p? Sub Sea TVD MD Permafrost 1,050' 1 199' 1,216' West Sak 1,094' 1 243' 1,263' ..............................................................................................................................................................W. Sak Base --1-~-~:~'-~ ...... ~'-C~-C~'~- ...... -~;-:i-'~-,~~-- C80 (Tabasco/K-10) 2,317' 2,466' 3,074' C50 (K-5) 3,604' 3,753' 5,352' C40 3,771' 3,920' 5,617' T4 (Cairn Interval) 4,889' 5,038' 6,852' T3 (Top Bermuda Interval/top 4,995' 5,144' 6,958' ............................................... .r_ Target (Midpoint T2 T3) 5,089' 5,238' 7,052' ........... ........ ........................... ....................... i , , , C35 (K-3) , 5,268 5,417 7,231 TD ~ 5,400 ~ 5,532 ~ 7,346 GL 121' Sub 28' 149' 2N 345 mlp, 06/08/98 [ AI CO Alaska, D~ ¢~tt~d : ,t-Jun-g8 / ~,o,,,, ...... ,, a4~v,,,~o, t~. /Field : Torn Development Field Location : North Slope. Aloska .3900 3600 3.300 .3000 2700 2400 2100 1800 1500 1200 900 600 .300 0 300 t I I ' ' ' [ I I ~ t [ I I I I ! I i 600 400 TARGa/TO LOCATION: I SURFACE LGCATiON: ~ 600 ] 604' FNL, 283' FWL I 143' FNL, 1113' FEL SEC. 3, TgN, R7E SEC. 3, TgN, R7E L ~ T~GET O J , RKB ELEVATION: 149' ~D=5238 ' i / TM0=7052 / [ SOUTH ~61 i KOP TVD=600 TMD:600 DEP:O ~ [ ~.00 DL5: ~.0~ deg per ~0 ft ~ooi~ ~.oo'~ oo 263.24 AZIMUTH i ENO INiTiAL BU~LO ~0=1090 TM0=I~00 0EP=72 . . ~200~ %22 86~/ PERMAFROST W0=1199 TMO=~2~6 0EP=~06 ~ / / ¥2~.02 T/ W SAK SNDS ~D=1243 TM0=1263 DEP=120 ***Plone of Prcposci--- ~ ~29 56z ~ ~'~' ~$: 4.00 de~ ~er 100 ,t 16°°/ ~o.o7 ~ ~7.¢0 B/ W SAK SNDS ~D=1940 TMD=2145 OEP=655 ~ ~5'07~C ~D=lgSO TMD=2214 DEP=68g 2OO0 7 5/8" CSG ~1 ~=2300 r~=2780 ~[~=1155 2~0~ 3074 ~[w 2800 ~ ~ MAXIMUM ANGLE 55.~ DEG 3600 ] ~O~ -~5552 DEP=5275 j ~~Mo~ DE~88 % 52.00 j C40 ~D=3920 TMD=56~7 DEP=3480~4.00 4000 ~LS 4400 48OO ~ 4.00 ~D~~6758 DEP=3911 ~D~58 ~=6852 DEP=3911 ~D=69~ DEP=3~ 52oo TARGET - MID BEAMUDA ?VD=SE38 T~D=?05g DgP=391 c;~ ~=~,~ T~O=z=;~ ~s,=~11 ~ TARGET ANGLE ~D - CSG PT ~=5532 ~A~=7346 DgP=391t~ ~oo t VERTICAL / 400 0 400 800 ~ 200 ~ 600 2000 2400 2800 3200 5600 4000 VerficolSection (feet)-> Azimuth 263.24 with reference 0.00 N, 0.00 E from slot //345 40 4O 8O 120 "--" 160 .,.i-,- 0 200 I V 240 280 320 .360 40O 440 Created by finch For: PRESTR]DGE1 Dote plotted : 4-Jun-98 Plot Reference is 54-5 Version ~6. I J Coordinot ..... in, ............. lot ~345. ARCO Alaska, Inc. Structure : Tarn Drill Site 2N Well : .345 Field : Torn Development Field Location : North Slope, Alaska West (feet) 760 720 680 640 600 560 520 480 440 400 560 320 280 240 200 160 120 80 40 0 40 80 I I I t I I I I I I I I I I I I I I I I I J I I I I I I I I I t I I I I I I I I I I ~ ...... t ?-?-°- ............... 9oo 1500 167. ............................................... ¢~ --'5 .......................................... s S°~o~"~°~ ~ ,~oo ).~.p..+Bo"~oo/~oo,;"~°° ,~oo ~oo ..... ~_o_.o.o_ .................. .;~%%~o~oo/~oo,,,~oo 1800 1.6._0__0_ ................. 1.~,~;'go0 .../ US~O0 .,,,'" t/~ 2200 ~.O~p_ ................. 2600 2tg-q ...................... - ............. ~'~'~ 'i'~'oo / "" / ~oo .... ~?-? ....... ?'" _ ....... ~_~.~ ....... ~-~-~- ..... ~oo ,~oo ,,oo .-ll;O ,~oo .,..~oo/~oo ............... ~'~ ~3-~' ..... '~000 :~ ........'~'~b'C~'" 2200 .- ...... / /1000/ ,' ......... .............. /1200 .,x'~ ]uu/ .t' 1300 ................. '17oo ~ ..,,,' / / .......... ............. , -~ ................ '~'~ ................... ~oo ....' / ..,,.i'~oo ~ ..~:~;o /;%0 .,,-'" ........... .,. ........ ,,~__. ,.,,-(~oo .... '--1 i '----l"m------T ..... -]---I ...... I .... 1 ........ 1 .... -[ i T-'---I-----I ..... l ........ I ....... I ...... 1 ...... r ..... -I ....... ~ .... '-I ........ q ...... I ...... I ..... [-----T ..... I' i I .... -T--'---I---"--I ...... r--'f .... 'T ......... 1 ........ I ....... r ....... l ...... r---'-- 760 720 680 640 6(30 560 520 4BO 440 400 360 520 280 24.0 200 160 120 80 40 0 40 80 <- West (feet) 120 Cf) 0 16O 200 I 240 V 28O 320 ,360 400 440 ICrcoted by finch For: PRESTI{IDGE Date plotted : 4-Jun-98 Plot Reference is 34-5 Version ~6, Coordinates ore in feet reference slot ~345. ARCO ][ne. Structure : Torn Drill Site 2N Well : .345 Field : Torn Development Field Location : North Slope, Alaska <- West (feet) 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 400 I { I I I I I I I ] [ I I [ I I I I I i I I I I I I [ I I [ I I I I I I I I I I I I ,"~-~ 1900 ~. ............... 1 600 .~....__._~- ~- .................................. 1500 - ~ 1800 ~oo ......................................... j_!_o__o_ 2200 ................................ 1300 200 :~ .............. 2100 ........................... 2000 1900 .................................................... 1800 1700 ............................................................... 600 1500 lO0 .................................................. J_,Lq_o_.__<~ ..................... 17oo .................... -~)-~ ..... 2700 ........................... f~-66 ....... 39oo ~6o0 ,~:~oo ................................. 2000 4aaa 4.700 ?_??-----?~ ..... :::::-%~-~ ..... ~ ........ 5100 ............ ff.'.f:f ...... '-;-~,~" 3300 ,.,~ uu ....... ' ......... 7 ~uu ........ .......... .; ......... 3 O0 ................. 5200 4700 ...... ::::::::;-~gV,--' 41 O0 3900 ............. %-a7;~- ........ 2100 2000 .~- r~l nn .... _.=;::z:::;---;-[~,~ ..,~uu ....................... z~uu ~ ~ ~' ~.~ .......... ,~,~vu ..................... 2400 / ~....,~ - 4900 ................... ~_'~00 2500 - 1700 ........ - ............ =~-a~ ...... 27o0 .... 3200 ...... - .................. ~900 :Z o,suu ........ ~.-'"":~-,'A-;, ...... 3000 ~ 1800 ~ ..................... . ...... ,¢, uu ~~-~-1900 /"' .... . ........... ~ 2000 .............. 1900 1900 ......... 600 .... '~' . ........' ~ 2000 2000 ...... r ......... ~2100 ............ '"'-""-2200 700 21 O0 .................... ~~--2200 ,.,....,/"~ ............... .,.,.-~ 2300 ..,.,.,.-" 800 2200 .............. .~..--~- 2400 .......,..""' 2500 ..-"' I I 1 r-----r-- i -r'--- i r-~-i ¥--'--1 ..... T--'---l-"'- i I i---I r'-"-q----i- i i l ..... l .... T 1 T~---'"I~-- i i i i 1----'T'----I r~r--"-I ['----'1 .... 1---- 2700 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1,500 1400 1300 1200 1100 lO00 900 800 700 600 <- West (feet) lDO 200 300 400 400 300 200 100 100 0 200 ~ Q) 3OO 400 I v 500 6OO 700 8OO 9OO 300 200 100 100 200 300 400 500 60O 7OO 800 900 1000 Creoted b7 finch For: PRESTPdl)GEI Dote plotted : 4-Jun-9§ Plot Reference is ,345 Version J6. I Coordlnotes ore in feet reference slot ~345. I ARCO A]taska, Structure : Torn Drill Site 2N Well : 345 Field : Tarn Development Field Location : North Slope, Alaska <- Wes~r (feet) 4500 4400 4300 4200 4100 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 I I I I I I I I I I I I I I I JI I I I I I I II I I I I I I I I I I I I I I I I I 2300 2500 ........................................................................ 2700 ..................................................................... ................. 3500 330.C/ ........ 3700 .......................................... ~ ............................................. 4100 3g00 ................................. ...... 2:s.°-2--.4-?-?P- ............................................ ...,--'"" / / ,/ ,. 2900 ~ 3300.~ ,, / 35o¢~~// / i i i i i i r i f I i i i-- i i --~ i--~ f ..... f T i --T--i i ~ .... i i '--7~ i r 7--WT--I [ i i 4500 4400 4300 4200 4100 ~000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 <- West (feet) 300 2OO 1 O0 100 2OO 0 300 -~- 5oo v 6OO 700 8OO 1000 9OO WELL ..... Pcm,' ..... !n~ c~ O.OO xOP 6GO.O0 [E~d c~ 9~ 1 ~co.oo iBe~/n Turn/ CcnSnue Bund 12C0.00 iEnd cf 9u;~d~?n 2214.03 End of H~d 5367.86 E~d ~ O?~p 6757.8~ rcr~=~ 3~5 ~v~d ~-~un- 7C51.86 ~End ~ Hdd 71+5.85 !r.D. & End cf ~lO 73~5.85 ARC 0 Al '-' aska, Inc. Structure : Tarn Drill Site 2N Well : 346 Feld : Tern Development Field Location : North Slope, Alaska PROFILE DATA ilo Oir ~ North East O.C0 O.CO O.QO O.O0 0.00 o.co 250.c06o0.00 O.co 0.o0 20,00 2~0. C0 1069.91-55.55-~6.17 20.00 250.o01183.88-77.61-92.37 55.60 265.82lgBO.30-225.~§ -666.63 55,60 265.823762. tl -4t5.19 -3261.99 O.O0 265.824SI44'.(]0 -46~.57 0.C0 265.825238.00-460.57 --3885.48 0.00 265.825532.00-4 r~3.57 --J883.~ 0,C0 26582 5532.00-450.57 -3885.'~8 v. Sect Oeg/IC0 o.0o o.o0 o.co o.co 72.25 4.00 I o0.86 0.Co 688.57 4.CO 3288.19 0.C0 3910.69 4.0(] 3910.69 0.00 3910.69 0.00 3910.69 0.00 540 32O ~~':Z.. 1700 310 .......... 35O TRUE NORTH 0 10 2O 150 300 29O 28~, 27O 260 50 1aa o¢ote, by ~. For: PRESTRIDGE Cote c~otteO f 4-Jun-98 Plot Reference ~s 345 Vets[on ~§. Coc, rdim3tes ore in feet referee slot ~346. Tr~e Vertical Depths cra reference RKB (C~on 7OO :ao 21oi, / 70 80 cO iO0 250 240 230 220 17(: · · ,/ 200 Normal Plane Travelling Cylinder - Feet 50O ',, i20 · ,, '~ 1700 130% 140 150 160 180 170 All depths shown are Measured depths on Reference ARCO Alaska, Inc. Tarn Drill Site 2N 345 slot #345 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 345 Version Our ref : prop2866 License : Date printed : 4-Jun-98 Date created : 27-Feb-98 Last revi~d : 4-Jun-98 Field is centred on n?0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 12.546,w150 19 5.025 Slot Grid coordinates are N 5911865.808, E 460479.383 Slot local coordinates are 143.18 S 1113.33 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 341 Version #4,,341,Tarn Drill Site 2N 350 Vets. #1,,350,Tarn Drill Site 2N 335 Version #1, 335,Tarn Drill Site 2N 305 Version #2, 303 Version #2, 314 Version #1, 311 Version #1, 315 Version #1, 301 Version #1, 302 Version #1, 304 Version #1, 306 Version #1, 307 Version #1, 308 Version #1, 309 Version #1, 310 Version #1, 320 Version #1, 334 Version #1, 347 Version #1, 327 Version #2, 326 Version #2, 325 Version #3, 319 Version #2, 321 Version #3, 317 Version #1, 305,Tarn Drill Site 2N 303,Tarn Drill Site 2N 314,Tarn Drill Site 2N 311,Tarn Drill Site 2N 315,Tarn Drill Site 2N 301,Tarn Drill Site 2N 302,Tarn Drill Site 2N 304,Tarn Drill Site 2N 306,Tarn Drill Site 2N 307,Tarn Drill Site 2N 308,Tarn Drill Site 2N 309,Tarn Drill Site 2N 310,Tarn Drill Site 2N 320,Tarn Drill Site 2N 334,Tarn Drill Site 2N 347,TarnDrill Site 2N 327,Tarn Drill Site 2N 326,Tarn Drill Site 2N 325,Tarn Drill Site 2N 319,Tarn Drill Site 2N 321,Tarn Drill Site 2N 317,Tarn Drill Site 2N Closest approach with 3-D Last revised Distance 14-May-98 45.5 8-Mar-98 75.2 8-Mar-98 143.7 8-Mar-98 600.0 8-Mar-98 630.0 21-Apr-98 448.7 21-Apr-98 509.8 8-Mar-98 450.0 8-Mar-98 660.0 8-Mar-98 645.0 8-Mar-98 615.0 8-Mar-98 585.0 8-Mar-98 570.0 8-Mar-98 555.0 8-Mar-98 540.0 8-Mar-98 524.6 8-Mar-98 356.7 8-Mar-98 162.4 8-Mar-98 30.5 27-Mar-98 254.9 27-Mar-98 262.5 8-May-98 300.0 8-May-98 380.0 8-May-98 326.1 8-Mar-98 419.9 Minimum Distance method M.D. Diverging from M.D. 625.0 625.0 300.0 / 7020.0 650.0 6957.9 600.0 600.0 400.0 400.0 725.0 725.0 600.0 600.0 600.0 7000.0 300.0 300.0 400.0 400.0 500.0 500.0 600.0 600.0 600.0 600.0 600.0 600.0 300.0 300.0 600.0 600.0 775.0 775.0 625.0 7080.0 300.0 7020.0 850.0 850.0 800.7 800.7 600.0 600.0 675.0 675.0 825.0 825.0 500.0 500.0 337 Version #4,,337,Tarn Dril ..... ,ire 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N 313 Version #4,,313,Tarn Drill Site 2N 330 Version ~3,,330,Tarn Drill Site 2N PMSS <0-9631'>,,343,Tarn Drill Site 2N PMSS <0-8239'>,,339,Tarn Drill Site 2N 331 Version #5,,331,Tarn Drill Site 2N 333 Version #2,,333,Tarn Drill Site 2N PMSS < 0 - 6150'>,,TARN#%,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 13-May-98 103.0 675.0 ..___~. 675.0 28-May-98 285.1 825.0 825.0 28-May-98 211.6 1000.0 1000.0 22-Apr-98 470.0 675.0 675.0 21-May-98 130.3 825.0 823.0 28-Ma¥-98 21.9 600.0 600.0 1-Jun-98 81.0 675.0 675.0 4-Jun-98 95.7 875.0 875.0 4-Jun-98 133.1 800.7 975.0 12-Aug-97 6957.7 625.0 625.0 12-Aug-97 4298.6 650.0 650.0 14-Aug-97 13101.1 600.0 7345.9 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 9~o Telephone 9u7 278 1215 June 5, 1998 AR3B-6003-93 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N 345 Surface Location: 143' FNL 1,113' FEL Sec 3 T9N R7E, UM Target Location: 604' FNL, 283' FWL Sec. 3, T9N, RTE, UM Bottom Hole Location: 604' FNL, 283' FWL Sec. 3, T9N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn' area, KRU 2N 345, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. This well requires a spacing exception. That exception was filed May 5, 1998 and AOGCC issued Conservation Order NO. 428 on May 22, 1998 granting the exception to spacing requirements. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. Alaska Oil & Bas Oons. Ooramission Anchorage 242 2603 David W. Johnston Application for Permit to Drill Page 2 KRU 2N-331 The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Fred Johnson at the number above or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tam Development Group Attachments cc: KRU 2N 345 Well File RECEIVED ,qaska Oil & Gas Cons. commission Anchorage Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission 2N-o41. 7.2N-339and ~ ' ' Re: Tarn accumulation development wells T ~_p~-o.~') .... ,,N-o4>. ARCO Alaska, Inc. by letter dated April 30, 1998 and May 5. 1998. has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of four deviated oil wells to an undefined pool adjacent to the western bounda~ of the Kuparuk River Unit. The first exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-341 oil xvell to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 130' from the north line (FNL), 1,055' from the east line (FEL), Section 3, T9N, RTE. Umiat Meridian (UM) to a target location of 2.506' from the south line (FSL). 624' from the west line (FWL), Section 4. T9N. RTE, UM, and a bottomhole location of 2.161' FSL. 672' FEL, Section 5, T9N, R7E, UM. The second exception would allow ARCO Alaska. Inc. to drill the Tarn 2N-337 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 117' FNL, 997' FEL, Section 3, TgN. R7E, UM to a target location of 1,032' FSL. 2,421' FEL, Section 4, TgN. R7E, UM, and a bottomhole location of 572' FSL. 2,047' FWL, Section 4. TgN, R7E, UM. The third exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-339 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The xvell will be drilled as a directional hole from a surface location 123' FNL. 1,026' FEL, Section 3, T9N, R7E. UM.to a target location of 2,258' FNL, 616' FEL, Section 4, T9N, R7E, UM, and a bottomhole location of 2.462' FNL. 1.144' FEL, Section 4, T9N, RTE, UM. The fourth exception would allow ARCO Alaska. Inc. to drill the Tarn 2N-345 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well ~vill be drilled as a directional hole from a surface location 144' FNL. 1,113' FEL, Section 3. T9N. R7E. UM to a target location of 605' FNL, 118' FWL. Section 3. T9N. R7E. UM. and a bottomhole location of 635' FNL. 289' FEL. Section 4. T9N. RTE, UM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, May 21, 1998, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive. Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter xvill be held at the above address at 1:00 PM on June 4, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office. (907) 279-1433 after May 21, 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If vou are a person ~vith a disability who may need a sp~ion in order to comment or to atten~t the public hearing, 998. David W~Q.ohnston ~ Chairman Published May 6, 1998 ADN AO02814046 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re' THE APPLICATION OF ARCO ) ALASKA, INC.for an order granting ) an exception to spacing requirements of ) 20 AAC 25.055(a)(3) to provide for the ) drilling of the Tarn 2N-341, ~ ..... ,_iN-OD/, ) ',, 2N-339 and 2N-345 oil wells to an undefined pool adjacent to the western ) boundary of the Kuparuk River Unit. ) Conservation Order No. 428 ARCO Alaska, Inc. Tarn '~" ~ ~ ,~t'~-.~41 2N-33'7 ~-,T ..... N-DD'J and 2N-345 May 22. 1998 IT APPEARING THAT: ARCO Alaska. Iilc. in correspondence dated April 30. 1998 and May 5. 1998. requested exception to the well spacing provisions of 20 AAC 25.055(a)(3). The exception would allow drilling the Tarn 2N-341 ,.N-3.~7, 2N-.~_~9 and ,.N-o4> oil wells to a bottomhole location that is closer than 500 feet from a quarter section line. 2. Tile Commission published notice of opportunity for public hearing in the Anchorage Daily News on May 6, 1998 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The Tarn 2N-341 oil well ;viii be drilled as a directional hole from a surface location 130' fi'om the north line (FNL), 1055' from the east line (FEL), Section 3. TgN. RTE. Umiat Meridian (UM) to a target location of 2506' from the south line (FSL), 624' from the ;vest line (FWL). Section 4, TgN, R7E, UM, and a bottomhole location of 2161' FSL. 672' FEL. Section 5. TgN. R7E, UM. "~'1~. T Tile Tarn _t,~-.~o7 oil well will be drilled as a directional hole from a surface location 117' FNL. 997' FEL. Section 3. T9N. R7E. UM to a target location of 1032' FSL. 2421' FEL. Section 4. T9N. R7E, UM, and a bottomhole location of 572' FSL. 2047' F\VL. Section 4. TgN. R7E. UM. The Tarn 2N-339 oil well will be drilled as a directional hole from a surface location 123' FNL. 1026' FEL. Section 3, T9N, R7E, UM to a target location of 2258' FNL. 616' FEL. Section 4, T9N. R7E, UM, and a bottomhole location of 2462' FNL, 1144' FEL. Section 4. T9N. R7E. UM. Tile Tarn 2N-345 oil well will be drilled as a directional hole from a surface location 144' FNL. 1113' FEL. Section 3, T9N, R7E, UM to a target location of 605' FNL. 118' FWL. Section 3, T9N. R7E, UM, and a bottomhole location of 635' FNL, 289' FEL. Section 4. T9N. R7E. UM. Conservation Order No. 4'28 May...'~'~ 1998 Page 2 Offset owners BP Exploration (Alaska) Inc.. Chevron U.S.A. Inc.. Mobil Oil Corporation. UNOCAL Alaska Resources and the State of Alaska have been duly notified. An exception to the well spacing provisions of 20 AAC 25.055 (a)(3) is necessary to all the drilling of these wells. CONCLUSION: Granting a spacing exception to allow drilling of the Tarn 2N-341. oil wells will not result in waste norjeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: .ARCO Alaska's applications for exception to the xvell spacing provisions of 20 AAC 25.055 (a)(3) tbr the purpose of drilling the Tarn 2N-341 _p~-ooT. ~.p~-_~ou and 2N-o43 oil wells are approved. DONE at Anchorage. Alaska and dated Mav 22. 1998. Robert N. Chr~on~ Commissio Alaska Oil and Gas Conser",'ation Commission Camill60echsli, Commissioner Alaska Oil and Gas Conservation Commission .\S 31.05.080 provides that within 20 davs after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application lbr rehearing. A request ~br rehearing must be received by 4:30 PM on the 23~d day following thc date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request lbr rehearing is denied by nonaction of the Commission. the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e.. 10~h dav after the application for rehearine was filed). · WELL PERMIT CHECKLIST COMPANY ~(. Q WELL NAML~/~g ~ N - 3 ~ ,~-- PROGRAM: exp [] dev,~l'redrll [] serv [] wellbore seg EJ ann. disposal para req,~ FIELD & POOL L~ cl ~ ! (,3 ~- INIT CLASS .,~ 0. ~ I - 0 ,' l GEOL AREA_ c~ ~ ~ UNIT# /l,/' //'//]- ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... ~ N ;~ ~L~'~,.1 ~x_~_~.j,)~o~, ~'~L ~,ut.'~.~_. ~e~ 2. Lease number appropriate ................... (~ N 3. Uniquewellnameandnumber .................. ~~yy ~~ 0~ ~-o. ~ c'{~(~. ~>~3 AI~R ,.Z)ATE.~ 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 DATE 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 ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~Oc3~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N d~N GEOLOGY 30. 31. 32. 33. AP. PR DATE 34. Permit can be issued WIG hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ..... Seismic analysis of shallow gas zones ...... ~..._--.~':~. Y N Seabed condition survey (if off-shore)..~~.. ....... Y N Contact name/phone .for weekly..pmgr~~ ....... Y N [exploratory onl With proper cementing records, this plan-- (A) will contain waste in a suitable receiving zone; ....... N (B) will not contaminate freshwater; or cause drilling waste... 'N to surface; (C) will not impair mechanical integrity of the well used for disposal; N (D) will not damage producing formation or impair recovery from a N. pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N GEOI_I({?Y: ENGINEERING: UwlC.~~ RPC ~ BEVV~ ~-/-(~r~ . j D H ......--~ COMMISSION: DWJ RNC co Comments/Instructions: M:chel~list rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklisl 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 Drillinr ",ervices LIS Scan Uti~_.~y Thu Oct 29 10:14:44 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/29 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 ..................... 98/10/29 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, TARN POOL M~4D/~ LOGS WELL NAME: API N-UMBER: OPER3%TOR: 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 MWD RUN 2 AK-MM-80282 PIEPER SPRINGER 1ST STRING 2N-345 501032026400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-0CT-98 3 9N 7E 143 113 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND ~TRING 3RD STRING PRODUCTION STRING REMARKS: 16.000 108.0 9.875 ..~ ... 7.625 2789.0 6.750 7431.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED ON LOG. 3. MWD RUN 2 IS DIRECTIONAL, DUAL GAMMA P~AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR4), COMPENSATED THERMAL NEUTRON PORROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH DOUG HASTINGS OF ARCO ALASKA, INC. ON 08/12/98. MWD IS PDC. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7431'MD, 5632'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). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = COMPENSATED THERMAL NEUTRON SANDSTONE POROSITY. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (BEST BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.50 TO 10.0 PPG FORMATION WATER SALINITY: 19149 PPM CHLORIDES MUD SALINITY: 400-600 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/29 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 GR PEF FET RPD RPM RPS RPX DRHO RHOB FCNT NCNT NPHI ROP $ START 2728 2751 2776 2776 2776 2776 2776 2791 2791 5 2791.5 2791.5 2791.5 2820.0 DEPTH 5 0 0 0 0 0 0 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 7339.5 7326.5 7348.5 7347.5 7347.5 7347.5 7347.5 7326.5 7326.5 7309.5 7309.5 7309.5 7431.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2820.0 7431.0 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 DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 TNPS MWD PU-S 4 1 68 SBD2 MWD G/C3 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 SCO2 MWD G/C3 4 1 68 SNP2 MWD BAi~N 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max .. Mean Nsam DEPT 2728.5 7431 5079.75 9406 GR 38.99 237.49 122.162 9223 R0P 0 1168.03 191.66 9223 TNPS 15.29 52.27 38.877 9037 SBD2 1.885 4.396 2.32259 9071 NCNT 19858.1 41508.8 24502 9010 FCNT 150.73 694.49 224.314 9010 SCO2 -0.073 1.611 0.0926476 9071 SNP2 -0.04 13.31 3.22876 9152 RPX 0.98 2000 4.50685 9144 RPS 0.07 2000 4.39912 9144 RPM 0.25 2000 9.96777 9144 RPD 0.08 2000 5.59961 9144 FET 0.43 78.7 1.86993 9146 First Reading 2728.5 2728.5 2820 2791.5 2791.5 2791.5 2791.5 2791.5 2751 2776 2776 2776 2776 2776 I 't Reae_~g 7431 7339.5 7431 7309.5 7326.5 7309.5 7309.5 7326.5 7326.5 7347.5 7347.5 7347.5 7347.5 7348.5 First Reading For Entire File .......... 2728.5 Last Reading For Entire File ........... 7431 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/29 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 ....... 98/10/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW 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 GR 2728.5 PEF 2751.0 FET 2776.0 RPD 2776.0 RPM 2776.0 RPS 2776.0 RPX 2776.0 DRHO 2791.5 STOP DEPTH 7339.5 7326.5 7348 5 7347 5 7347 5 7347 5 7347 5 7326 5 RHOB' 2791.5 FCNT 2791.5 NCNT 2791.5 NPHI 2791.5 R0P 2820.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 CNP SLD $ 7326.5 7309.5 7309.5 7309.5 7431.0 ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND 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) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 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 15 - JLrL- 98 INSITE 3.2.12.3 SP4 5.04, SLD 10.83, CTN 8.24 MEMORY 7431.0 2820.0 7431.0 .3 59.1 TOOL NUMBER P1035GRM4 P1035GRM4 P1037NL4 P1037NL4 6.750 6.8 LSND 9.90 48.0 9.5 600 4.6 2.700 1.790 3.500 4.000 46.1 .0 Da[a 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 DEPT FT 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHM_M 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 SCO2 MWD 2 G/C3 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 API 4 1 68 TNPS MWD 2 PU-S 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 SBD2 MWD 2 G/C3 4 1 68 SNP2 MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 2728.5 7431 5079.75 9406 RPX 0.98 2000 4.50685 9144 RPS 0.07 2000 4.39912 9144 RPM 0.25 2000 9.96777 9144 RPD 0.08 2000 5.59961 9144 FET 0.43 78.7 1.86993 9146 SCO2 -0.073 1.611 0.0926476 9071 ROP 0 1168.03 191.66 9223 GR 38.99 318.76 122.201 9223 TNPS 15.29 52.27 38.877 9037 FCNT 150.73 694.49 224.314 9010 NCNT 19858.1 41508.8 24502 9010 SBD2 1.885 4.396 2.32259 9071 SNP2 -0.04 13.31 3.22876 9152 First Reading 2728.5 2776 2776 2776 2776 2776 2791.5 2820 2728.5 2791.5 2791.5 2791.5 2791.5 2751 Last Reading 7431 7347.5 7347.5 7347.5 7347.5 7348.5 7326.5 7431 7339.5 7309.5 7309.5 7309.5 7326.5 7326.5 First Reading For Entire File .......... 2728.5 Last Reading For Entire File ........... 7431 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Dat~ ..................... 98/ /29 Origin ................... ST$ ....~ Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Scientific Technical Services Services Physical EOF Physical EOF End Of LIS File LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE '. **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC REEL NAME : 98412 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, KRU 2N-345, TARN POOL, API #50-103-20264-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN . FLIC TAPE NAME : 98412 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, KRU 2N-345, TARN POOL, API #50-103-20264-00 TAPE HEADER TARN POOL OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN 1 98412 H KIRKBY R SPRINGER TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING KRU 2N-345 501032026400 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 12-AUG-98 RUN 2 RUN 3 3 9N 7E 143 1113 149.00 149.00 121.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 2789.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE MODIFIED LDWG FORMATTED DATA ACQUIRED ON ARCO ALASKA'S KRU 2N-345 WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUM~Uh~Y LDWG TOOL CODE DAS FMS $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7434.0 2748.0 7425.0 2793.0 BASELINE DEPTH 88888.0 7274.0 7261.5 7258.5 7256.0 7246.0 7228.5 7226.0 7224.0 7211.5 7194.5 7191.0 7180.0 7175.0 7166.5 7151.0 7147.0 7144.0 .......... EQUIVALENT UNSHIFTED DEPTH DAS FMS .............. 88887.5 88887.5 7273.5 7261.0 7257.5 7254.5 7245.0 7227.0 7224.5 7223.0 7210.5 7193.0 7190.0 7179.0 7179.0 7174.5 7165.5 7150.5 7146.0 7143.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 7143.5 7121.5 7120.0 7092.5 7086.5 7074.5 7072.0 7071.0 7067.5 7047.5 7043.0 7042.5 7008.5 6994.5 6992 5 6982 5 6981 0 6974 0 6973 5 6957 5 6947 0 6932 5 6931.5 6917.0 6916.5 6911.0 6910.5 6905.5 6870.0 6854.5 6846.0 6835.5 6835.0 6825.5 6810.5 6797.0 6794.0 6792.5 6782.5 6765.5 6762.0 6748.0 6742.0 6729.5 6725.5 6704.5 6689.0 6684.5 6683.5 6677.0 6676.0 6629.0 6628.0 6619.0 6618.5 7120.0 7092.0 7071.5 7048.0 7042.5 6995.0 6974.0 6947.5 6932.5 6916.5 6911.0 6855.0 6846.0 6836.0 6826.5 6811.5 6794.5 6783.5 6766.5 6748.5 6731.0 6705.5 6690.5 6684.5 6677.5 663 O. 0 6620.5 7143.0 7119.0 7092.0 7085.5 7074.0 7071.5 7066.0 7042.5 7008.5 6992.5 6984.0 6979.0 6974.0 6957.5 6947.5 6932.5 6916.5 6910.5 6906.0 6870.5 6855.0 6835.5 6797.5 6793.5 6766.5 6762.5 6742.5 6726.0 6687.0 6678.0 663 O. 5 6620.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 6601.0 6590.0 6578.0 6570.0 6557.5 6555.0 6540.0 6539.5 6534.5 6534.0 6528.5 6527.5 6511.5 6503.0 6478.5 64 64.0 6460.0 6450.0 6383.5 6383.0 63 66.0 6365.5 6356.0 6355.5 6346.5 6335.0 6328.5 6325.0 6312.0 6309.5 6298.5 6290.0 6272.0 6240.0 6239.5 6231.5 6226.0 6220.5 6220.0 6196.0 6195.0 6189.5 6177 0 6171 5 6152 5 6141 0 6140 0 6115 0 6109 0 6103 0 6084 0 6074 0 6073 5 6066.5 6043.5 6602.0 6570.5 6558.0 6555.0 6542.0 6536.5 6530.0 6512.0 6480.0 6465.5 6461.5 6385.0 6368.0 6357.5 6348.5 6329.5 6311.0 6292.0 6274.5 6243.0 6235.0 6228.0 6222.5 6198.0 6179.0 6142.5 6117.0 6086.0 6075.5 6068.5 6592.5 6580.5 6542.0 6537.0 6530.5 6505.5 6466.5 6453.0 6385.0 6368.0 6357.5 6335.0 6326.5 6313.5 6301.0 6274.5 6243.0 6222.5 6197.5 6192.0 6172.5 6154.0 6142.5 6110.0 6103.5 6075.5 6046.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 6035 6035 6029 6015 5998 5987 5936 5936 5918 5913 5909 5899 5895 5883 5861 5859 5 5837 0 5822 5 5797 5 5781 5 5779 0 5762 0 5754 5 5749 5 5728 5 5726 0 5692 0 5684 0 5671 5 5669.0 5668 0 5663 5 5640 5 5635 0 5634 0 5597 5 5597 0 5585 0 5581 5 5559 5 5558 0 5538 0 5526.0 5510.0 5509.5 5491.5 5487.5 5478.5 5456.0 5447.5 5446.0 5438.5 5437.0 5410.5 5398.5 · 5 6037.5 0 6037.5 5 6031.5 5 6017.5 0 5999.5 5 5989.0 5989.0 5 5937.5 0 5937.5 5 5919.5 0 5914.5 5 5911.5 5 5901.5 5 5897.0 5 5884.5 5 5863.5 5861.5 5824.0 5797.5 5780.0 5754.5 5749.5 5729.0 5684.5 5670.5 5664.0 5635.0 5598.5 5586.0 5560.5 5538.5 5527.5 5511.0 5489.0 5456.0 5448.0 5439.5 5400.0 5838.5 5781.5 5780.0 5764.0 5729.0 5695.0 5674.0 5670.5 5643.0 5638.0 5598.5 5583.0 5560.5 5511.0 5492.5 5480.5 5448.0 5439.5 5413.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 5397.5 5378.0 5349.5 5322.5 5321.5 5312.5 5305 0 5300 5 5297 5 5273 5 5259 0 5257 0 5240 5 5224.0 5223.0 5210.5 5182.0 5154.5 5152.0 5151.0 5146.5 5135.0 5132.5 5108.0 5098.0 5081.5 5075.5 5075.0 5072 0 5047 0 5039 5 5034 0 5011 5 5003 0 4980.0 4965.0 4963.5 4949.5 4938.5 4938.0 4925.5 4909.0 4895.5 4885.5 4855.0 4851.5 4847.0 4844.5 4840.5 4817.5 4813.5 4796.5 4788.0 4787.5 4767.0 5379.0 5350.5 5323.5 5312.0 5298.0 5259.0 5241.5 5224.5 5182.0 5153.0 5146.5 5134.5 5107.0 5096.0 5082.5 5077.0 5072.0 5048.5 5040.5 5034.0 5012.5 4981.5 4964.5 4951.5 4941.0 4898. 0 4856. 0 4853.5 4848.5 4819.0 4797.5 4788.5 4767.5 5400.0 5323.5 5306.0 5302.5 5276.0 5258.5 5224.5 5212.5 5156.0 5153.0 5134.0 5077.0 5050.5 5006.5 4968.5 4941.0 4927.0 4910.0 4887.0 4846.5 4843.5 4816.0 4789.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 4753.5 4755.0 4752.5 4754.5 4725.5 4729.0 4702.5 4705.5 4698.0 4699.5 4696.5 4700.0 4664.5 4664.0 4655.0 4658.5 4647.5 4648.5 4646.0 4648.5 4640.5 4642.0 4622.0 4623.5 4620.0 4622.5 4601 . 5 4602.5 4592.0 4594.0 4566.0 4568.0 4536.0 4537.0 4504.5 4506.5 4498.0 4500.0 4478.5 4480.0 4466.5 4465.5 4443.5 4446.0 4430.0 4433.0 4422.0 4424.0 4420.0 4419.5 4410.5 4408.5 4390.0 4391.0 4380.0 4382.0 4367.5 4365.5 4360.5 4362.5 4351.0 4349.5 4327.5 4326.0 4311.5 4312.5 4308.0 4308.0 4294.5 4295.5 4283.0 4285.5 4276.0 4277.0 4274.5 4275.5 4247.5 4250.0 4228.0 4230.0 4211.5 4214.5 4207.5 4210.5 4197.5 4199.5 4194.0 4198.0 4165.5 4168.5 4164.0 4168.0 4159.5 4163.5 4151.5 4154.0 4149.5 4154.0 4133.5 4136.0 4122.5 4125.5 4091.5 4096.0 4088.5 4090.5 4085.5 4090.5 4061.0 4063.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 4040.0 4033.5 4023.0 4004.0 3989.5 3987.0 3976.5 3975.0 3950.0 3944.0 3937.0 3922.0 3921.0 3901.0 3890.5 3890.0 3872.5 3871.0 3847.0 3834.0 3826.0 3816.0 3808 5 3803 0 3777 5 3762 5 3756 5 3740 0 3738.5 3734.0 3724.5 3693.0 3692.0 3673.5 3664.0 3657.0 3643.5 3628.0 3613.0 3608.5 3608.0 3601.5 3570.5 3536.0 3531.0 3529.5 3514.0 3512.5 3491.0 3479.0 3471.5 3462.5 3445.0 3443.5 3438.0 4035.5 3991.0 3978.0 3947.0 3924.0 3904.5 3892.5 3873.5 3827.0 3805.0 3779.5 3758.5 3740.0 3736.5 3695.5 3665.0 3610.5 3604.0 3535.0 3517.5 3495.0 3475.5 3447.0 3440.5 4044.0 4026.0 4007.0 3990.5 3978.0 3953.0 3940.0 3924.0 3892.5 3873.5 3848.0 3836. 0 3819.0 3810.0 3766.0 3744.0 3728.0 3695.5 3676.0 3660.5 3647.0 3630.0 3614.5 3611.0 3574.0 3540.5 3534.5 3518.5 3483.5 3467.5 3449.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 3433.0 3415.0 3399.5 3393.5 3393.0 3389.5 3375.5 3374.0 3363 0 3361 0 3352 5 3349 5 3332 5 3332 0 3321 0 3314 5 3310.0 3306.5 3289.0 3285.5 3284.0 3280.0 3264.5 3261.5 3244.0 3232.0 3206.5 3206.0 3188.5 3177.0 3174.5 3160.0 3144.5 3143.0 3130.5 3128.0 3108.0 3099.5 3418.0 3403.0 3397.5 3392.5 3378.0 3365.5 3351.5 3335.0 3321.5 3311.5 3292.0 3283.5 3265.5 3209.0 3192.5 3180.0 3148.0 3133.5 3132.0 3111.0 3102.5 3437.0 3397.5 3378.0 3365.5 3357.0 3335.5 3319.5 3311.5 3290.0 3289.0 3268.0 3246.5 3236.0 3210.5 3179.5 3165.0 3148.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 10 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NOY~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1291929 GR DAS GAPI 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 lvfl~ES DAS 0H~4~1291929 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 GR FMS GAPI 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN 1291929 O0 000 O0 0 1 1 ! 4 68 0000000000 C24 PT4S IN 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 DEV FMS DEG 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 1291929 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7433.500 MRES.DAS 1.327 SCRA.DAS -999.250 RB1.FMS -999.250 DEPT. 2696.500 MRES.DAS -999.250 SCRA.DAS -999.250 RB1.FMS -999.250 GR.DAS -999.250 TENS.DAS 5243.000 TEND.DAS MTEM. DAS 132.898 DT. DAS -999.250 DTSH.DAS GR.FMS -999.250 Cl3.FMS -999.250 C24.FMS AZ.FMS -999.250 DEV. FMS -999.250 GR.MWD GR.DAS -999.250 TENS.DAS -999.250 TEND.DAS MTEM. DAS -999.250 DT.DAS -999.250 DTSH.DAS GR.FMS 82.905 Cl3.FMS -999.250 C24.FMS AZ.FMS -999.250 DEV. FMS -999.250 GR.MWD 910.176 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1998 15:20 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC TAPE NAME : 98412 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, KRU 2N-345, TARN POOL, API #50-103-20264-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/12 ORIGIN : FLIC REEL NAME : 98412 CONTINUATION # PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC, KRU 2N-345, TARN POOL, API #50-103-20264-00
