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191-069
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~/~/¢ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. n Other, No/Type OVERSIZED -[3' Logs-of vadous kinds . n Other COMMENTS: Scanned by: Severly D.i_an~athan TO RE-SCAN Lowell Date:J~ Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ ON OR BEFORE E E W P__~ ._..aL uNDER M ~ C:Lo~LM.DOC PLUGGii~G & LOC_ATION CLE~-~-~CE REPORT ~--e well file, and' c=~m~n: on pluggi=g, well head s=auus, .~d !oca=i~n c!ea~ce;- orov~e loc. c!e~. co~e. Harkar pos= or place: Location Clearanc~: PH' LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-6120 Fax: (907) 265-6224 May 25, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1L-26 and 1L-26A (Permit No. 91/69 & 200-015) Well Completion Reports Dear Mr. Commissioner: Enclosed is the well completion report for the abandonment of 1L-26 and the completion on KRU 1L-26A. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor Phillips Drilling GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL OOMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r'~ Gas [~ Suspended E:] Abandoned [~] Service E] 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 91-69/300-040 ,3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22173-00 4. Location of well at surface ~l,~j~,,~,,~,,~.~ ,~ 9. Unit or Lease Name 566' FNL, 217' FWL, Sec. 32, T11 N, R10E, UM ', ' ' ~"'"""'""" ~~'J'~'! Kuparuk River Unit At Top Producing Interval ..~ 10. Well Number 1626' FNL, 1316' FEL, Sec. 5, T10N, R10E, UM , 1L-26 At Total Depth 11. Field and Pool 1697' FNL, 1258' FEL, Sec. 5, T10N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 129' feetI ADL 25664 / ALK 473 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 31, 1991 June 6, 1991 March 9, 2000 (P&A'd)I N/A feetMSL 1 1~. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9957' MD / 6195' TVD YES D No [~I N/A feetMD 10065' MD / 6252' TVD 22. Type Electric or Other Logs Run CBT/GR/CCL 23. eASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 123' 24" 200 sx AS I 9.625" 36# J-55 Surface 5225' 12-1/4" 850 sx PF Er 580 sx Class G 7" 26# J-55 Surface 10045' 8-1/2" 250 sx Class G set bridge plug @ 8511' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A * Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST ,,, Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned D~.te of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OII'"RATIO I N/A Test Period > Flow Tubing easing Pressure Calculated OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF A'I-I-ACHMENTS Summary of 1 L-26 Plug and Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Chip Alvord Title Drilling Engineerina Supervisor Questions? Call Bill Lloyd 265-6531 INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 05/1!/00 ARCO ALASKA !NC. WELL SUMMARY REPORT Page: WELL:lL-26A STATE:ALASKA COU-NTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/08/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22173-01 03/05/00 (DI) TD/TVD: 0/0 SUPV:G.R. WHITLOCK MW: 10.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ( 0) Prepare rig for skidding. Hold safety meeting. Prep rig for move to 1L-26A. 03/06/00 (D2) TD/TVD: 0/0 SUPV:G.R. WHITLOCK MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) MOVING RIG-RIG 8 IF PAD Move rig from 3H pad to iL pad. APIWL: 0.0 03/07/00 (D3) TD/TVD: 117/117 SUPV:FRED HERBERT MW: 0.0 VISC: 0 PV/YP: 0/ 0 (117) LEVEL PIT COMPLEX. RIG UP M~ve rig to 1L pad. Hold pre-spud meeting. APIWL: 0.0 03/08/00 (D4) TD/TVD: 117/117 SUPV:FRED HERBERT MW: 11.8 VISC: 56 PV/YP: 31/34 0)TIH W/ WHIPSTOCK APIWL: 4.6 Continue to move on pad and rig up, Rig accepted on well ~IL-26A $ 0700 hrs. 3/8/00. Remove tree. N/U BOPE. Test BOPE 250/5000 psi. PJSM. Run 6.125" gauge ring, GR, CCL. 03/09/00 (DS) MW: 11.8 VISC: 53 PV/YP: 27/31 APIWL: 4.0 TD/TVD: 8509/5406 (8392) P/U BHA SUPV:FRED HERBERT RIH. Set CIBP ~ 8511'. POOH. RIH with mill assembly. RIH w/Whipstock. Set Whipstock @ 8486'. Cut window from 8486' to 8509'. Work and ream. Perform FIT to 14.5 EMW. Perform FIT to 14.6 EMW. 03/10/00 (D6) MW: 11.8 VISC: 54 PV/YP: 28/33 APIWL: 5.2 TD/TVD: 8569/5438 ( 60) CIRC & COND FOR TRIP SUPV:FRED HERBERT POOH w/ window assy. PJSM. RIH. Orient tools and run thru window. Drilling from 8509' to 8569' 03/11/00 (D7) MW: il.8 VISC: 55 PV/YP: 27/36 APIWL: 4~0 TD/TVD: 8846/5621 (277) DRILLING $ 8949' SUPV:FRED HERBERT Drilling from 8569' to 8638'. Unable to maintain angle. Circ sweep. Monitor well, POOH to shoe. Reset toolface correction. RIH. Drilling from 8638' to 8846' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS '1~ 'l'yp~ o(:iequest:- Abandon _X Suspend _ Operational shutdown Re-enter suspended well_ " Alter casing _ Repair well _ Plugging / Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 129' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 566' FNL, 217' FWL, Sec. 32, T11N, R10E, UM 1L-26 At top of productive interval 9. Permit number / approval number 1626' FNL, 1316' FEL, Sec. 5, T10N, R10E, UM 91-69 At effective depth 10. APl number 50-029-22173 At total depth 11. Field / Pool 1697' FNL, 1258' FEL, Sec. 5, T10N, R10E, UM Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10065 feet Plugs (measured) true vertical 6252 feet Effective depth: measured 9957 feet Junk (measured) true vertical 6195 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 123' 16" 200 sx AS I 123' 123' Surface 5182' 9.625" 850 sx PF E, 580 sx Class G 5225' 3604' Intermediate 10009' 7" 250 sx Class G 10045' 6242' Production Perforation depth: measured N/A true vertical N/A ORIGIIVAL RECEIVED FEB 10 Tubing (size, grade, and measured depth N/A Packers & SSSV (type & measured depth) N/A ~ 13. Attachments Description summary of proposal __ Detailed operations program __ ' BOP sketch __ " 14. Estimated date for commencing operation 15. Status of well classification as: February 15, 2000 16. If proposal was verbally approved Oil __ Gas __ Suspended __X Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Bill Lloyd 265-6531 Signed ~ 4 ~ Title; Drilling Engineering Supervisor Date 2_//of Zoo0 Chip Alvor, Prepared by Sharon Al/sup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity ~ BOP Test__ Location clearance__ ,~ C~,-)C/~ Mechanical Integrity Test__ Subsequent form required 10- L.~ ~ ~ ORIGINAL SIGNEDBY Approved by order of the,.C, ommission Robert N Christenson Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 1 L-26a Short Well Summary Pre-Riq Work: NOTE: If any problems are observed with the 7" packoff during pre-rig operations, notify the Operations Drilling Engineer, Nabors 16e Company Representative and the wellhead manufacturer. Repairs will be made prior to initiation of rig work. 1. MIRU wireline and tag PBTD. (Work done 1/14/99 - Tagged @ 9916' WLM). 2. Pressure test 10" x 7" casing packoff to 2000 psi (completed 11/17/00). Test 7" casing to 3000 psi for 30 minutes (Completed 1/17/99). 3. Log 7" with USlT bond log (completed 1/18/99). RD wireline. Top of good cement @ 8450' WLM. 4. Make gauge ring/junk basket run to 8550' MD Riq 1. Work If unable to get down with gauge ring/junk basket during pre-rig operations, make a dummy mill run to 8600' MD. Otherwise, PU 7" CIBP on wire line, RIH and set @ 8520'. Use USIT log dated 9/9/85 as tie-in correlation log. Test 7" and bridge plug to 3500 psi. 2. PU Baker Bottom Trip Anchor whipstock and BHA and RIH. Install ditch magnets in troughs. FIIH to -8400' and establish string parameters. Continue in hole to CIBP and orient and set base of whipstock @ 8515'. 3. Displace well to milling/drilling fluid. Shear whipstock bolt and begin milling window in 7". Mill until 29' · of BHA is in .the open hole. Circulate well clean until no metal is seen in returns. Perform LOT· to a .minimum of 12.8 ppg. POOH and LD milling assembly. 4. PU 61/8'' BHA and RIH. Displace wellbore to new 11.8 ppg drilling fluid. Perform PWD baseline tests and drill 61/8'' horizontal wellbore to' MD. Use MWD/GR/Res/Den-Neu in western fault in real time for evaluation. Prior to crossing fault, TOOH for bit and to drop Den/Neu tools. 5. Run 31/2" solid liner to TD and cement. 6. Run 31/2" L-80 standard Kuparuk gas lift completion. Circulate freeze protection to 2200'. Sting SBE into PBR on top of liner top packer. 7. Set and test TWCV to 1000 psi. ND BOPE, NU Tree. Pull TWCV and set/test BPV. RDMO. 1L-26 Proposed Plugback 7", 26#, J-55 casing @ 10,045' MD face 9-5/8" 36# J-55 casing set @ 5,225' MD Packer or Bridge Plug Setting Depth for Whipstock tied in with 7" Casing Tally and CBL 1/18/00 Pressure Test 7" csg to 3000 psi and ran CBL on 1/17-18/00 No Perforations Last Tag at 9,951' MD on 1/14/00 PBTD = 9,957' MD ( Top of Float Collar) TD = 10,065' MD BDN 1/20/00 ARCO Alaska, Inc. Post Office B°.~ ,)0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, / ~s ,~;_W, in;~'~''~''' ?..~"'"Senior Lan d~.~,,~n" JRW:hb Enclosures CC: M. L. Bill L. D. Brown H. R. Engei R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 1 4 1995 Alaska Oil & Gas Cons. Commission ^nchora ,, ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED KUPARUK RIVER UNIT (ARCO Contact: Larry Brown 263-1501) APR 14 1995 Alaska Oil & Gas Cons. Conll~l/ssion Anchora, ARCO hereby requests extensions of "suspended" status for the following wells. Additionally, an exception to the surface plug requirement of AOGCC 20AAC25.110(c) is requested. Ail of these wells, are located in safe and accessible locations on producing drill sites that are monitored daily. The individual status of each well is detailed below. KRU Well 1H-05, APl # 50-029-20727-00, Permit # 82-0038-0 Well 1H-05 was drilled to TD without setting 7" casing despite encountering 10' of net C1 Sand pay. At the time it was drilled, this pay was considered too marginal to justify completion. This area of the drill site, however, may be economically developed using emerging technologies currently being employed on the North Slope (i.e., slimhole completions, coiled tubing drilling/sidetracks/horizontal sections, etc.). For this reason, Well 1H-05's wellbore (especially the surface hole) is a useful asset to ARCO Alaska and should be maintained in the suspended status. Surface casing (10-3/4") was set and cemented at 2425' MD-RKB. Four cement plugs which were witnessed by an AOGCC representative were set @ 9825'-10,300' (225 sacks Class 'G'), 5100'-5700' (290 sacks Class 'G'), 4160'-4590' (260 sacks Class 'G'), & 2230'-2545' MD-RKB (240 sacks Arctic Set I). Additionally, 10.5 ppg brine was left in the wellbore above the top plug. Based on the above, Well 1H-05 is believed to be in a secure condition with no risk of hydrocarbon migration. KRU Well 1L-20, APl # 50-029-22027-00, Permit # 90-0036-0 Well 1L-20 was suspended due to a drill string fish left in the well @ 11,040' MD-RKB. At the time of the initial suspension, a side-track was planned out of the existing surface hole. Problems developed while trying to pull the 7" casing for the side-track; therefore, the decision to drill a completely new well (1L-20X) was made. A time extension is requested for this well in order to complete an evaluation of this well's future use as a coiled tubing or conventional side-track candidate. This well's surface hole might be able to be used to drill a much needed water injection well to the north of 1L-20X's bottomhole location. This is a key location for preventing gas migration from the 1C/1D storage area. if this wellbore's suitability for future use is determined to be uneconomic, then the P&A process will be initiated. Well 1L-20 is in a secure condition with 9-5/8" surface casing set and cemented @ 6000' MD-RKB, a 7" long string set and cemented @ 10,938' MD-RKB, a cement retainer set at 10,878' MD with 100' of cement above, and a permanent bridge plug set @ 6657' MD-RKB capped with 75 sx of Class 'G' cement. KRU Well 1L-26, APl # 50-029-22173-00, Permit # 91-0069-0 Well 1L-26 encountered 4' of net A Sand pay. At the time it was drilled, the economics for completing this well were positive, but were considered marginal as stacked against other projects within the KRU; therefore, the well was not perforated nor was tubing run. RECEIVED Kuparuk River Unit ~ Page 2 APR 1 4 1995 A. bska 0il & Gas Cons. Commlssi0n This well does have future potential as either a producer or water it~tr~'r". Again, emerging completion technologies may provide stronger economic justification for completion in the future. Additionally, Well 1L-26 is strategically located regarding future development of the southern KRU area. Well 1L-26 is in a secure condition with 7" casing to TD which is cemented to above the top of the Kuparuk. The 7" X 9-5/8" annulus is cemented with 200 sacks of Permafrost 'C' cement with a 70 bbl Arctic Pack cap. The 7" casing is filled with kill weight brine and, as mentioned above, is not perforated. KRU Well 2E-05., APl # 50-029-22423-00, Permit # 93-0179-0 While open hole LWD logs for Well 2E-05 indicate that there is 9' of net pay in the C Sand and 6' in the A Sand, there is concern about the quality of fluid contained within that pay. Cores taken from the C Sand in Well 2E-17, 0.9 mile to the west, and from the C Sand in Well 2E-08, 1.2 miles to the northwest, contained a highly asphaltenic, non- flowable hydrocarbon. There is a large degree of uncertainty as to the flowability of hydrocarbons contained in either the A or C Sand in 2E-05. If only the A Sand contains flowable hydrocarbons, the reserves associated with that pay is limited. At this time, development of the A and C Sand reserves in Well 2E-05 have poor economics due to the fluid quality uncertainty and oil price. Nevertheless, the well does have future potential as either a producer or water injector. Completion and production of nearby wells may increase confidence as to the flowability of hydrocarbons in Well 2E-05. Geochemical studies of the fluid from the 2E-17 and 2E-08 cores may increase understanding of why and where non-flowable hydrocarbons occur within the southern Kuparuk River Unit. Advances in coiled tubing completion technology and a more favorable oil price may enable economic development of limited reserves. Well 2E-05 is in a secure condition with the 7" casing run to TD and cemented to above the top of the Kuparuk. The 7" x 9-5/8" annulus is cemented with 650 sx of ASI with a 59 bbl Arctic Pack fluid cap. The 7" casing is filled with kill weight brine and has not been perforated. KRU Well 2E-06 While open hole LWD logs for Well 2E-06 indicate that there is 19' of net pay in the C Sand and 6' in the A Sand, there is concern about the quality of fluid contained within that pay. Cores taken from the C Sand in Well 2E-17, 0.6 mile to the northeast, and from the C Sand in Well 2E-08, 1.4 miles to the north, contained a highly asphaltenic, non-flowable hydrocarbon. There is a large degree of uncertainty as to the flowability of hydrocarbons contained in either the A or C Sand in 2E-06. If only the A Sand contains flowable hydrocarbons, the reserves associated with that pay is limited. At this time, development of the A and C Sand reserves in Well 2E-06 have poor economics due to the fluid quality uncedainty and oil price. Nevedheless, the well does have future potential as either a producer or water injector. Completion and production of nearby wells may increase confidence as to the flowability of hydrocarbons in Well 2E-06. Geochemical studies of the fluid from the 2E-17 and 2E-08 cores may increase ALASKA OIL AND GAS · CONSERVATION COMMISSION August 19, 1994 David Sutter, Land Manager ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 · WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. · Chairman encls c: Blair Wondzell bew/llarsusp INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 91-069 CDN 91-069 CDR 91-069 407 91-069 DAILY WELL OP 91-069 SURVEY 91-069 Are well tests required? Was well cored? Yes /N~. 4930 Yes 5225-10065 5225-10065 COMP DATE:06/09/91 05/31/91-06/08/91 ANADRILL 5225-10065 If yes, was the core analysis & description received? Yes ~ Are dry ditch samples required? Yes~ WELL IS ON COMPLIANCE. ~ 09/10/1993 PAGE: 1 COMMENTS: STATE OF ALASKA ALASr~A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS [] SUSPENDED [~ ABANDONED ~--~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91~69(Permit No.) & 93-220(SA Apr No.) 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 O~/G/IV/~L , 50-029-22173 4 Location of well at surface ~..~:: , , ...... 9 Unit or Lease Name 566' FNL, 217' FWL, Sec. 32, T11 N, R10E, UM ~-OC^]'tO~N5 ~ KUPARUK RIVER AtTop Producing Interval VF.~IFtED~,~;j,7..~_ I lO Well Number 1626' FNL, 1316" FEL, Sec. 5, T10N, R10E, UM . 2~'~r~~i 1L-26 At Total Depth 11 Field and Pool 1697' FNL, 1258' FEL, Sec. 5, T1ON, R10E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 129' RKB-MSL, PAD 86' GLI ADL: 25664 ALK: 473 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 05/31/91. 06/06/91. 6/09/91 .(SUSP)I NA feet MSLI NA , 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 10065' MD, 6252' TVD 9957' MD; 6195'TVD YES X~_JMWD NO UI NA feet MDI 1600' APPROX 22 Type Electric or Other Logs Run CDR, CDN 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 123' 123' 200 SX AS I 9 5/8" 36# J-55 SURF 5225' 12-1/4" 850 SX PF E, 580 SX CLASS G 7" 26# J-55 SURF 10045' 8-1/2" 250 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NA NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECE V . $ P - 9 199;5 Alaska Oit & Gas Co;-!s. Anchorage 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 recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA NA 31. LIST OF ATFACHMENTS SUMMARY OF OPERATIONS, 2 COPIES OF MWD SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 .ARGO ALASKA INC. WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1L-26 NORTH SLOPE KUPARUK RIVER UNIT ADL 25664 ALK 473 50-029-22173 91-69 AK6098 55.252072 DAILY OPERATIONS PAGE: 1 ACCEPT: 05/30/91 18:00 SPUD: 05/31/91 03:00 RELEASE: 06/09/91 05:30 OPERATION: DRILLING RIG: POOL 7 05/31/91 ( 1) TD: 500' ( 500) SUPV:KKL 06/01/91 ( 2) TD: 4151' (3651) SUPV:KKL 06/02/91 ( 3) TD: 5240' (1089) SUPV:KKL 06/03/91 ( 4) TD: 5240'( SUPV:KKL o) DRLG 8 500' MW: 8.6 VIS: 83 MOVE F/1L-25 TO 1L-26. ACCEPT RIG 1800 5/31/91. NU SURF STACK & DIVERTER & TST PU BHA 1. CHANGE OUT 3- 12 1/4" STAB SLEEVES. ORIENT DD & MWD. RIH & BREAK CIRC. CHK PMPS & STD PIPE. POH. LOST CENTER JET ON BIT. BREAK OUT BIT & MAKE UP NEW BIT. (1ST BIT DID NOT DRILL ANY HOLE SO DID NOT INCLUDE IN BIT RECORD) DRLD 123'-500'. ADT=2 HRS. TAGGED JUNK 8 107' (BTM OF CONDUCTOR). WORKED ON JUNK FOR 4'OR 5'. DID NOT SEE JUNK AGAIN AFTER THAT. DAILY:S69,988 CUM:$69,988 ETD:S69,988 EFC:$1,690,000 DRLG 8 4151' MW:10.1 VIS: 47 DRLD 500' TO 1939'. ADT 5.75 HRS. CIRC & COND MUD. DROP SINGLE SHOT. POH. RETRIEVE SURVEY. MU BIT #2 & RIH. BREAK CIR. DRLD & SURVEYED F/1939' TO 4151'. ADT 9.75 HRS. MADE DIRECTIONAL CORRECTIONS AS REQD. DAILY:S83,123 CUM:$153,111 ETD:S153,111 EFC:$1,690,000 POH F/ CASING MW:10.5 VIS: 48 DRLD 4151' TO 5240'. ADT 10.75 HRS. MADE DIR CORR AS REQD. CIRC & COND HOLE.. POH F/ SHORT TRIP. NO PROB W/ 1ST 30 STD OFF BTM, BUT HOLE VERY TIGHT 8 3691', 3323,3231, 2772' WORK THROUGH & CONT POH. HOLE TIGHT AGAIN AT 2586 & 2217'. ~ORK THROUGH. HOLE BEGAN SWABBING- KELLY UP & PUMP & REAM THROUGH TIGHT SPOTS. SAW SOME COAL COME OVER SHAKERS. CONT PUMPING OUT F/ 2217 TO 1429'. PULLED CLEAN F/ 1479 TO 1018' HOLE TOOK RIGHT AMT OF FLUID. RIH. CIRC & COND HOLE & MUD FOR 9 5/8 CSG. POH FOR CASING. DAILY:S50,065 CUM:$203,176 ETD:S203,176 EFC:$1,690,000 TSTG BOP 9-5/8"8 5225' MW:10.6 VIS: 42 FINISH POH. LD BHA. CUT 80'DRLG LINE. RU WEATHERFORD & FLOOR TO RUN CSG. RAN 125 JTS OF 9 5/8" 36# J55 BTC CSG W/ SHOE 8 5225', .FC 8 5137'. CIRC & COND MUD HAD TO CONT CIRC WHILE INJECTING MUD OUT OF PITS. HAD ASSUMED THAT LOST CIRC WOULD BE A PROBLEM SO PIT VOLUME HAD NOT BEEN REDUCED SIGNIFICANTLY. RU HOWCO. PUMP WATER & FILL LINES, TEST TO 4000PSI. DROP 1ST PLUG, PUMPED 40 BBL FRESH WATER, DROP 2ND PLUG, MIX & PUMP 850 SX PF E W/ 1/4 PPS FLOCELE 8 12.3 PPG, MIX & PMP 580 SX CLASS G W/ 2% NACL & 1/4 PPS FLOCELE @ 15.8 PPG. DROP TOP PLUG. DISPL W/ RIG PUMPS, BUMPED PLUG W/ 2000 PSI. HA/) FULL RETURNS & GOOD MUD /CEMENT BREAKOVER INTERFACE. HAD 10-13 BBL CMT TO SURF FLOATS HELD. DRAIN DIVERTER & WASH CMT OUT. LD LANDING JT. ND DIVERTER & LINES. LD CSG ELEVATORS & BIG BAILS, PUT ON SMALL BAILS. CLEAN OUT FLOWLINE. INSTALL 11 3/4" BTC X 11" 3M BRADENHEAD. MU TO 13000FT-LB. NU BOP. FUNCTION TST BOP. MU TST PLUG & TSTG BOP. DAILY:S199,331 CUM:$402,507 ETD:S402,507 EFC:$1,690,000 RECEIVE Alaska Oil & Gas (.;{~is. bo .... Anchorag~ WELL: 1L-26 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 06/04/91 (5) TD: 6321' (1081) SUPV:KKL 9-5/8"@ 5225' MW: 9.1 VIS: 37 FINISH TSTING BOP. SET WEAR RING. PU 8.5" BHA #2. CHANGE OUT BEARING SECTION ON TURBINE. PROGRM LWD TOOLS. LOAD SOURCE. RIH TO 5115'. KELLY UP. TAG UP ON PLUG ABOVE FC(@ 5136'). BREAK CIRC. TEST 9-5/8" CSG TO 2000 PSI. DRILL FC,FS & 10' OF NEW HOLE TO 5250'. PERFORM LEAK OFF TEST W/ 9.2 MUD TO 12.5 PPG EMW. DRILLED 5250-5644'. ADT 1.75 HR. MWD TOOL PROB. TRIED TO RESOLVE & LOCATE PROB WHILE STILL IN HOLE W/O SUCCESS. CBU. PUMP DRY JOB. POH. UNLOAD CDN SOURC LD MWD. DOWNLOAD CDR & REPROGRAM. PU NEW MWD TOOL & ORIENT. DOWNLOAD CDN & REPROGRAM. LOAD SOURCE IN CDN. RIH. TAGGED FILL @ 5610 (34'). BREAK CIRC. CLEAN OUT FILL TO 5644'. SURVEY. DRLD 5644'-6321'. ADT 4.5 HR. DAILY:S51,326 CUM:$453,833 ETD:S453,833 EFC:$1,690,000 06/05/91 ( 6) TD: 8468' (2147) SUPV:KKL DRLG @ 8468' 9-5/8"@ 5225' MW: 9.2 VIS: 33 DRLD 6321-7855'. ADT 10.5 HR. SURV & MADE CORR AS REQD. TRIP TO SHOE(29 STD). REPLACE HOSE IN MUD LINE BETWEEN SUB BASE & RIG FLOOR. (HOSE BEGAN LEAKING). RIH. DRLD 7855-8468'. ADT 4 HR. DAILY:S48,926 CUM:$502,759 ETD:S502,759 EFC:$1,690,000 06/06/91 ( 7) TD:10026' (1558) SUPV:JRR DRLG 8-1/2" HOLE DRLD 8468-10026'. DAILY:S61,869 9-5/8"@ 5225' MW:10.5 VIS: 44 CUM:$564,628 ETD:S564,628 EFC:$1,690,000 06/07/91 ( 8) TD:10065' ( 39) SUPV:JRR CIRC W/ BATCH MIX CMT 9-5/8"@ 5225' MW:10.5 VIS: 47 DRLD 10026-10065. CIRC BU. 25 STD SHORT TRIP. CIRC & COND MUD. TOH. UNLOAD LOGS & SOURCE FROM LWD. LD BHA. PULLED WEAR RING. RU WEATHERFORD TO RUN CSG. RAN 117 JTS 7" 26# J55 BTC & 118 JTS 7" 26# J55 BTC-MOD CSG PLUS MARKER JT. FS @ 10045' FC @ 9957'. CIRC AT 9-5/8" SHOE(OK). FINISH RIH W/ PARTIAL RETURNS WHILE BATCH MIXING CMT AND RECIPROCATE. DAILY:S148,447 CUM:$713,075 ETD:S713,075 EFC:$1,690,000 06/08/91 ( 9) TD: 9957'( SUPV:JRR o) RIG RELEASED 9-5/8"@ 5225' MW:10.6 VIS: 0 TEST CMT LINES TO 4000 PSI; PMP 10 BBL ARCO PREFLUSH, DROP PLUG #1; PMP 35 BBL ARCO SPACER, DROP PLUG #2; PMP 250 SX (54 BBL) BATCH MIXED CLASS G CMT + 3% CFR-3 + 0.235 HR-5 + 0.5% BENTONITE + 3.0% CAL SEAL + 0.6% LAP-1 + 0.02 GPS 434B @ 15.5 PPG (1.23 CUFT/SX); DROP TOP PLUG, DISPLACED W/380 BBL 10.6 PPG NACL/NABR; BUMPED PLUG TO 3500 PSI FOR CSG TEST RECIPROCATED PIPE BUT NO RETURNS WHILE CEMENTING. P/U BOP STACK AND SET SLIPS; CUT OFF 7" LANDING JT AND SET PACKOFF; BLEW DOWN BRINE TO 80'; N/U BOP STACK. LDDP. N/D BOP STACK N/U FMC 11" 3000 X 7-1/16" 5000 TBG SPOOL; TEST PACKOFF TO 3000 PSI (OK); INSTALL 7-1/16" 5000 X 3" 5000 ADAPTOR FLANGE AND 3" 5000 VALVE. INJECT 125 BBL DIESEL FOR FREEZE PROTECTION. **RELEASED RIG @ 0530 09-JUN-91** TEAR DOWN RIG FOR MOVE TO 1R-19. DAILY:S238,247 CUM:$951,322 ETD:S951,322 EFC:$1,690,000 SIGNATURE: DRI LLI N~~PERINTEN~NT RECEiV,;.-., Alaska Oil & das ~uns ..... ,~,,,~s,s,, Anchora,q. a PAGE C{3MPA~: ARCO ALAS~ IHC, WELL W-d'iE 1L-26 IJ3CATI~ 1 KUPARtH< RI~,~FJ~ UNIT LOCATION 2 hN3R'lT{ SLOF'£ ALASI<A P~eg'NKFI C DECLINATION DATE: 06-JIM,i-91 ~LL ~t~ER 26 WELL HF~D LOCATION: L~T(N/-S) 0,00 AzI~rrH ~ql"l RtlTA~Y TABLE. TO TARUET IS TIE IN POIHT(TIP> : MEASURED DEPTH 0.0~ TRUE VERT DEPTH 0.00 INCLIH~TIEM 0.00. ~TI'I'LH)E (H/-S) 0,~ DEF'AR'rURE (U-W) 0,00 DEF'(E/-W) 0,00 150,30 RECE)V D S ~': P --- 9 1993 Alaska Oil & Gas Cons. Gomrniss~o'" Anchorage PAGE HO, MEASURED INTERVAL VERTICAL OS'TH I)~H ft fT f~ 0,00 0,¢ O.OD 204,97 205,0 204,97 396,00 191.0 395,76 567,98 172,0 565,65 747,66 179.7 739.74 1114.43 12'76.84 1480,81 1~.'7 1944,57 2138,62 2323.7i 2503.~ 2688.46 3232.52 3602.23 3785.94 4061,03 4430.27 4&~4.~D 4990.I6 5149.5~ 5542.00 ~57.19 6230,24 68.89.35 7077,70 7449,42 7824,42 8202,96 8860.46 ?230.9 9600,95 9963,62 10065.00 17%4 ~D'?,I2 187,4 1079,36 1~2.4 1236,01 184,0 13U,23 187,1 1~4,82 276,6 1679,41 194,1 185.1 1917.39 179,8 20~.97 I85,0 21~,01 270,2 ~.18 273,9 2445.69 359.7 2655,49 183.7 2.7~.42 2~,1 ~4,~ ~69.2 3139,89 374,1 ~9.~ 185.8 34~.54 159.4 3~.1.77 E72.4 3752.5B ~73,1 41~.D 65%1 45~'.41 135,4 ~43,35 371,7 46~5,42 375,¢ 5045,63 378,.5 5246.18 657.5 5601,39 36%9 5804.06 370.6 6004.2~ 362,7 6198,~ 101,4 6252.59 SURUEY CALCLLA~.]ONS mw, RAI)IUS OF CUg~Al't~ iEtHO~~ TAt;,'G£T STATION AZIMLrI'H lATITUDE S~TiON INC~. N/-S ft deo ~e~ ft 0,00 0,00 336.1: 0,00 -0.~ 0,19 336,14 0,30 -0,~ 4,91 1~.52 -1,87 24,71 12,~ 1~,]4 -26,13 67,82 16,10 165.1-' -68,~ 1L-26 D~'ARTL~:E DIE;F'IACI~"ENT at £/-W ft ft 0,00 0,00 -0,13 0,33 -5,09 %43 4,06 26,45 16,~ 70.60 AZI~bTH DLS deq/ deg lO0ft C,DO 0,00 336,14 0,09 24~,04 2,67 171,17 4,41 1~.45 2.07 1~,08 ~,~ 162,68 -1~,25 ~.87 1~,49 1E5,29 3,47 202,~ 27,02 1~.~6 -197,'~ 61,13 207,22: 16E.~4 3,07 2~,08 34,46 1~,11 -282,78 9%80 299,87 160,56 4,10 412.~ 45.05 154.~9 -389.74 148.43 417.05 15~.15 5.76 548.71 ~,97 152,13 -512,27 20%36 553,40 157,77 2.37 763,06 52,74 152.53 -702.23 300,96 767,20 914,66 50,16 153.30 -8,37,35 378,05 918,74 1057,82 51,37 153.50 -965,55 ~2,24 I~2,01 1200.68 54,:32 155,72 -I~74,98 503,67 1205,26 1~1,~ ~,96 153.79 -1~1,41 567.~ 1356.~ 1572,08 54,~ 1~.~ -1426,71 1796.13 ~,86 151.19 -1622,15 2100,43 55.99 147,45 -I0&3.90 2248,~ 52,04 148.~6 -2009,81 2471,62 ~,22 147,75 -2198.~ 2771,~ 52.42 149.12 -2454.43 3073,90 55,~ 151,74 -2717,59 3224.45 52.81 152.C5 -2850.44 ~53.72 55,61 l~d~ -2963,90 3678.12 ~,91 150.41 -~46.29 ~,52 C~,2~ 147.56 -3~7.82 4243.~ 56,36 150.12 -3731,42 47~,45 56,53 1~,58 -4205,89 4949,52 56,50 151.C6 -4341,67 5261,45 57,64 l~,2D -4610,81 5b'78.3~ 57,83 148.83 -4881,22 58!~',17 58,19 147,24 -5153,58 6450.[~ 56.41 143.~5 -5609,17 6757.43 57,14 142,87 -5857.12 70&6,41 57,46 142.12 -6104.52 1~,25 1.37 155.70 1,36 1~:,3i' 0,66 155,30 1,91 155.24 0,9'2 671,70 1~6,~ 154.79 1,07 781,~ 1800.46 1~,28 0,28 ~,54 2103,85 153,57 0,89 1015.50 2251.80 152.19 2.I9 1133,42 2473,85 152.73 1.53 1290.~ 2772.97 152.27 1.07 1439.70 3075.39 152.09 1.01 1510.64 3226.00 '152.38 1,48 1572.65 3355,29 152,05 1.90 I7~.30 3679,58. 151,?1 0.~' 1665,46 3937,73 151,72 0.90 2022,~ 42~,~ 151.54 0.93 2299,03 4793,23 15],34 0,30 2378,00 4950,~ 151,29 1.10 2535.74 5262,09 151,19 0,71 2701,34 5578,85 151.~4 0.15 2871,29 5899,47 150.~ 0,37 3185,04 64~,37 15(:,41 0.53 3370.11 6757,48 150.08 0,27 3560°00 70~5,74 14~.,-"5 0.19 7369,02 57.76 140.80 -6344.06 7453.65 57.80 140.~0 -6410.54 3750,80 7~9.91 149,41 0,32 380%08 7454.77 14'~,31 0.04 REC£1VEp. ARCO Alaska, Inc. { 'i Pos! Office B~,~ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 16, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1L-26 Suspend N/A If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments ARCO Ataska, Inc. is a Subsidiary of AtlanticRichfieldCompany A~ ' OIL AND GAS CONSERVATION COMMk ~N 1 Abandon _ Suspend X Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well__ Plugging _ Time extension _ Stimulate _ ' . Change approved program Pull tubing Variance Perforate 5. Type of Well: F or KB) / .///'..,,J Development X Exploratory _ d 86' GL feet '~] Stratigraphic _ '1 Service __ 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 566' FNL, 217' FWL, Sec. 32, T11N, R10E, UM At top of productive interval At effective depth 1626' FNL, 1316' FEL, Sec. 4, T10N, R10E, UM (approx) At total depth 1697' FNL, 1259' FEL, Sec. 4, T10N, 12. RIOE, UM (approx) Present well condition summary Total Depth: measured 10,065 feet (approx) true vertical 6,253 feet Effective depth: measured 9,957 feet (approx) true vertical 6,1 95 feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 5,1 8 2 9 - 5 / 8" Intermediate Production 1 0,009' 7" Liner Perforation depth: measured None Plugs (measured) Junk (measured) true vertical Cemented 200 Sx AS I 850 Sx Class E 580 Sx Class G 250 Sx Class G Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 6. Datum elevation (DF or KB) 129' RKB-MSL Pad 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-26 9. Permit number 91 -69 10. APl number 50-029-22173 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 123' 123' 5,225' 3,396' (approx) 10,045' 6,241' (approx) RECEIVED 13. Attachments Alaska Oii & Gas Cons. Description summary of proposal X Detailed operation program ._' ........ -E~OP sketch _ 14. Estimated date for commencing operation 16. If proposal was verbally approVed Name of a. pprover Date approved 15. Status of well classification as: Oil m Gas __ Suspended X Service 17. I herebv/c~brtify .thaC~the foren~,ing is true and correct to the best of my knowledge. S i~]ned ~/-~/~'~- ~ Title ~/~/~- ~'~,~/~ ~ FOR COMMISSION USE ~NLY Conditions of approval: Notify Commission so representative may witness IApproval N~, Plug integrity __ BOP Test _ Location clearance__ ~,pproveql Cop}, / Returned Mechanical Integrity Test_ Subsequent form require 10"~¢0-7--- ~//y/t;,~;~ Original Signed By " Approved the order of the Commission r3;'~Vi~ W. johnston Commissioner Date by Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 Request for Suspension KRU Well 1L-26 ARCO Alaska Inc. requests approval to place KRU Well 1 L-26 on suspended status pursuant to AOGCC 25.105 (e). Additionally, a waiver to AOGCC 25.110 (c) is requested for the surface plug requirement. Open hole LWD logs for Well 1L-26 indicate that the A Sand has 4' of net pay. Though development of these reserves has poor economics at this time, the well does have future potential as either a producer or water injector. Advances in coiled tubing completion technology may provide economical alternatives. Upcoming drilling at Drillsite 2E should improve the understanding of regional trends. Based on the results of further peripheral drilling, Well 1 L-26 is strategically located regarding future development of the southern KRU area. Well 1 L-26 is in a secure condition with 7" casing to TD which is cemented to above the top of the Kuparuk. The 7" x 9-5/8" annulus is cemented with 200 sx of Permafrost C cement with a 70 bbl Arctic Pack fluid cap. The 7" casing is filled with kill weight brine and has not been perforated. 1 L-26 is in a safe and accessible location on a producing drillsite that is monitored daily. ALASKA OIL AND GAS CONSERVATION COMMISSION August 2, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Arco Alaska, Inc. ~. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 1L-26 -- Noncompliance Operation Shut Down Dear Mr. McBride: A review of our well records and correspondence shows a shutdown of well operations on Kuparuk River Unit 1L-26 expired on September 12, 1992. At that time operations were to be resumed or the well was to be plugged and abandoned according to 20 AAC 25.072. By correspondence dated March 23, 1993, (see attached letter) you were notified of the noncompliance condition of the well. Alternative to plug and abandonment, you may apply for suspension under 20 AAC 25.110. To date, no application for suspension has been received. The condition of well 1L-26 is out of compliance with 20 AAC 25.072, and you must show cause why the well should not be immediately abandoned as required by .the referenced regulation. The Commission requests your response to this notice within 15 working days from the receipt of this letter. If no response is forthcoming, the Commission has no choice but to order plugging and abandonment of the well under 20 AAC 25. 072. Sincerely, Chairman Enclosure ~¢~ l)rin~ed on ~ecycle(J pal)er b y C.,. ~'1. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 MARCH 23, 1993 WAYNE MCBRIDE ARCO ALASKA INC. ATO 1448 P O BOX 100360 ANCHORAGE, ALASKA 99510 RE: 91-0069 KUPARUK RIVER UNIT 91-0093 KUPARUK RIVER UNIT DEAR MR. MCBRIDE, 1L-26 1R-24 OUR FILES INDICATE THAT ARCO ALASKA INC. AS THE OPERATOR OF THE SUBJECT WELLS, HAS NOT FULLY COMPLIED WITH ALL THE REQUIREMENTS ASSOCIATED WITH THE OPERATIONAL SHUTDOWN OF THE · "IF ABOVE REFERENCED WELLS. ACCORDING TO 20 AAC 25.072(d), WELL OPERATIONS ARE NOT RESUMED WITHIN 12 MONTHS, THE OPERATOR SHALL IMMEDIATELY PROCEED TO ABANDON THE WELL." ITS THE OPERATORS RESPONSIBILITY TO MONITOR THE STATUS OF YOUR WELLS FOR COMPLIANCE WITH THE COMMISSIONS REGULATIONS. WILL YOU PLEASE ADDRESS THE MATTER OF YOUR FUTURE PLANS CONCERNING THESE WELLS. PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THIS CORRESPONDENCE AS REQUESTED IN A TIMELY MANNER. SINCERELY, STEVE MC MAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-03 LIS Tape and Listing 1 -27-92 92095 3 R- 12 D LIS Tape and Listing 2 - 4 - 9 2 92115 THE' FOLLOWING LIS TAPES ARE STAMPED WITH A 'CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK YOU. I R-17 LIS Tape and Listing 9-1 9-91 92026 I R - 2 0 LIS Tape and Listing 9 - 9 - 9 1 9 20 26 1 R-21 LIS Tape and Listing 1 0 - 6 - 9 1 92026 1 R-22 LIS Tape and Listing 9- 24- 9 1 92026 I R-23 LIS Tape and Listing I 0-22-91 92026 I R - 2 4 LIS Tape and Listing 7 - 3 0 - 9 1 9 2 0 26 1 R - 2 6 LIS Tape and Listing 7 - 1 8 - 9 1 9 2 0 26 I R - 2 7 LIS Tape and Listing 8 - 3 1 - 91 9 2 026 1 R - 2 9 · LIS Tape and Listing 8 - 1 4 - 91 9 20 26 1 R - 1 9 LIS Tape and Listing 6 - 1 9 - 91 9 2 0 26 2 M - 21 LIS Tape and Usting 1 1 - 1 1 - 91 92026 2 M - 1 9 LIS Tape and Listing I 1 - 1 7 - 91 92026 I L-23 LIS Tape and Listing 5-9-91 92026 I L - 24 LIS Tape and Listing 5 - 1 9 - 91 92026 I L - 2 5 LIS Tape and Listing 5 - 2 6 - 91 92026 I L-26 LIS Tape and Listing 6 -3 - 91 92026 Receipt Acknowledged: -- Date' REC--EWED DISTRIBUTION: Lynn Goettinger FEB 2 8 1992. Alaska 0il & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date' February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return o. ne signed copy of this transmittal. ~ ~,. ~' 1~,~I2M-10 Lithe-Density & Casing Neutron 11-29-91 700~)~7756,~~ -" Porosity Data & 12-29-91 700 7.669 2M-1 0 Lithe-Density & Casing Neutron I I-29-91 7000-7756 Raw Data & 12-29-91 7 0 00 - 7 6 6 9 ., ~J~?'~ (3Q-04 CDR ,., 1-12-16-92 4517.7-7720 ,~3Q-03 CCN ~ 1-24-27-92 5090-9640 1~13,,~'~3Q-03 .CDR ~ 1-24-27-92 5090-9640 ,~THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUESTED THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG. ..~ · _THANK YOU. .. ~1.--~,'3'~ ~ ~ 5.9."i3:91 :, 5237:10476 /~? 1L-26~;~q-~p~ 6-3-6-91 52'25-10065 ?-I ~ 2M-19~ ~ 11-17-'91 3835-9250 q'-' ..~ 1R-17;~ ~ 9-15'-19-91 5698-10345 ~ ,~-,~/ ~ 6-1 9-23-91 - 5390-9841 ~( ~ 1R-20J ~ 9-9-91 5568-10080 ~t~ ~ 1R-21~ ~ 10-6-11-91 5070-10180 qJ,~,':~ 1R-22~ ~ 9--24-29-91 6001-10813 ~ol I R-23 ~/ ~. ~ 10-22-91 6330-12188 3' ~z 1R-24~ / ~ 7-30/8-5-91 6753-12972 ~.~1R-26 ./ ~ 7-18-21-91 5591-10218 ~,'~;~1 R-27/ ~/ 8-31 -91 6547-9250 ~l.~ 1R-29 ~ ~// 8-14-91 6042-11368 ~ 1L-24 ~' ~ d 5-19-22-91 5081-9241 ~i _~ 1L-25 ~ ~ / 5-26-29-91 4978-9352 / REC[IVED FEB 1 1992. Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Qperation Shutdown X Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 566' FNL, 217' FWL, Sec. 32, T11N, R10E, UM At top of productive interval At effective depth 1626' FNL, 1316' FEL, Sec.4, T10N, R10E, UM (approx) At total depth 1697' FNL, 1259' FEL, Sec. 4, T10N, R10E, UM (approx) 12. Present well condition summary Total Depth: measured (approx.) true vertical 1 0,065' feet 6,253' feet Plugs (measured) 6. Datum elevation (DF or KB) 129' RKB-MSL. PAD 86' GL feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-26 9. Permit number/approval number 91-69 10. APl number 50-029-22173 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured (approx.) true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9,957' feet 6,1 95' feet Length Size 80' 1 6" 5,182' 9 5/8" 1 0,009' 7" measured None Junk (measured) Cemented Measured depth 215 Sx AS I 123' md 850 Sx CLass E & 5,225' 580 Sx Class G 250 Sx Class G 1 0,0 4 5' True vertical depth 123' tvd 3,396' (approx) 6,241' (approx) true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED .Oil & Gas Cons. Commission Anchorage 14. Representative Dally Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil Gas Suspended X Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev Title Area Drilling Engineer Date ~/~/~,/~"~/ SUB~T I1~ DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1L-26 NORTH SLOPE KUPARUK RIVER UNIT ADL 25664 ALK 473 50-029-22173 91-69 AK6098 55.252072 ACCEPT: 05/30/91 18:00 SPUD: 05/31/91 03:00 RELEASE: 06/09/91 05:30 OPERATION: DRILLING RIG: POOL 7 05/31/91 ( 1) TD: 500' ( 500) SUPV:KKL 06/01/91 ( 2) TD: 4151' (3651) SUPV:KKL 06/02/91 ( 3) TD: 5240' (1089) SUPV:KKL 06/03/91 ( 4) TD: 5240'( SUPV:KKL o) DRLG @ 500' MW: 8.6 VIS: 83 MOVE F/1L-25 TO 1L-26. ACCEPT RIG 1800 5/31/91. NU SURF STACK & DIVERTER & TST PU BHA 1. CHANGE OUT 3- 12 1/4" STAB SLEEVES. ORIENT DD & MWD. RIH & BREAK CIRC. CHK PMPS & STD PIPE. POH. LOST CENTER JET ON BIT. BREAK OUT BIT & MAKE UP NEW BIT. (lST BIT DID NOT DRILL ANY HOLE SO DID NOT INCLUDE IN BIT RECORD) DRLD 123'-500'. ADT=2 HRS. TAGGED JUNK @ 107' (BTM OF CONDUCTOR). WORKED ON JUNK FOR 4'OR 5'. DID NOT SEE JUNK AGAIN AFTER THAT. DAILY:S69,988 CUM:$69,988 ETD:S69,988 EFC:$1,690,000 DRLG @ 4151' MW:10.1 VIS: 47 DRLD 500' TO 1939'. ADT 5.75 HRS. CIRC & COND MUD. DROP SINGLE SHOT. POH. RETRIEVE SURVEY. MU BIT #2 & RIH. BREAK CIR. DRLD & SURVEYED F/1939' TO 4151'. ADT 9.75 HRS. MADE DIRECTIONAL CORRECTIONS AS REQD. DAILY:S83,123 CUM:$153,111 ETD:S153,111 EFC:$1,690,000 POH F/ CASING MW:10.5 VIS: 48 DRLD 4151' TO 5240'. ADT 10.75 HRS. MADE DIR CORR AS REQD. CIRC & COND HOLE.. POH F/ SHORT TRIP. NO PROB W/ lST 30 STD OFF BTM, BUT HOLE VERY TIGHT @ 3691', 3323,3231, 2772'. WORK THROUGH & CONT POH. HOLE TIGHT AGAIN AT 2586 & 2217' WORK THROUGH. HOLE BEGAN SWABBING- KELLY UP & PUMP & REAM THROUGH TIGHT SPOTS. SAW SOME COAL COME OVER SHAKERS. CONT PUMPING OUT F/ 2217 TO 1429' PULLED CLEAN F/ 1479 TO 1018' HOLE TOOK RIGHT AMT OF FLUID. RIH. CIRC & COND HOLE & MUD FOR 9 5/8 CSG. POH FOR CASING. DAILY:S50,065 CUM:$203,176 ETD:S203,176 EFC:$1,690,000 TSTG BOP 9-5/8"@ 5225' MW:10.6 VIS: 42 FINISH POH. LD BHA. CUT 80'DRLG LINE. RU WEATHERFORD & FLOOR TO RUN CSG. RAN 125 JTS OF 9 5/8" 36# J55 BTC CSG W/ SHOE @ 5225', FC @ 5137'. CIRC & COND MUD HAD TO CONT CIRC WHILE INJECTING MUD OUT OF PITS. HAD ASSUMED THAT LOST CIRC WOULD BE A PROBLEM SO PIT VOLUME HAD NOT BEEN REDUCED SIGNIFICANTLY. RU HOWCO. PUMP WATER & FILL LINES, TEST TO 4000PSI. DROP lST PLUG, PUMPED 40 BBL FRESH WATER, DROP 2ND PLUG, MIX & PUMP 850 SX PF E W/ 1/4 PPS FLOCELE @ 12.3 PPG, MIX & PMP 580 SX CLASS G W/ 2% NACL & 1/4 PPS FLOCELE @ 15.8 PPG. DROP TOP PLUG. DISPL W/ RIG PUMPS, BUMPED PLUG W/ 2000 PSI. HAD FULL RETURNS & GOOD MUD /CEMENT BREAKOVER INTERFACE. HAD 10-13 BBL CMT TO SURF FLOATS HELD. DRAIN DIVERTER & WASH CMT OUT. LD LANDING JT. ND DIVERTER & LINES. LD CSG ELEVATORS & BIG BAILS, PUT ON SMALL BAILS. CLEAN OUT FLOWLINE. INSTALL 11 3/4" BTC X 11" 3M BRADENHEAD. MU TO 13000FT-LB. NU BOP. FUNCTION TST BOP. MU TST PLUG & TSTG BOP. DAILY:S199,331 CUM:$402,507 ETD:S402,507 EFC:$1,690,000 RECEIVED Alaska OiJ & Gas C;ons, iJommis$io~'~, Anchorage WELL: 1L-26 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 06/04/91 ( 5) TD: 6321' (1081) SUPV:KKL 06/05/91 ( 6) TD: 8468' (2147) SUPV:KKL 9-5/8"@ 5225' MW: 9.1 VIS: 37 FINISH TSTING BOP. SET WEAR RING. PU 8.5" BHA #2. CHANGE OUT BEARING SECTION ON TURBINE. PROGRM LWD TOOLS. LOAD SOURCE. RIH TO 5115'. KELLY UP. TAG UP ON PLUG ABOVE FC(@ 5136'). BREAK CIRC. TEST 9-5/8" CSG TO 2000 PSI. DRILL FC,FS & 10' OF NEW HOLE TO 5250'. PERFORM LEAK OFF TEST W/ 9.2 MUD TO 12.5 PPG EMW. DRILLED 5250-5644'. ADT 1.75 HR. MWD TOOL PROB. TRIED TO RESOLVE & LOCATE PROB WHILE STILL IN HOLE W/O SUCCESS. CBU. PUMP DRY JOB. POH. UNLOAD CDN SOURC LD MWD. DOWNLOAD CDR & REPROGRAM. PU NEW MWD TOOL & ORIENT. DOWNLOAD CDN & REPROGRAM. LOAD SOURCE IN CDN. RIH. TAGGED FILL @ 5610 (34'). BREAK CIRC. CLEAN OUT FILL TO 5644'. SURVEY. DRLD 5644'-6321'. ADT 4.5 HR. DAILY:S51,326 CUM:$453,833 ETD:S453,833 EFC:$1,690,000 DRLG @ 8468' 9-5/8"@ 5225' MW: 9.2 VIS: 33 DRLD 6321-7855'. ADT 10.5 HR. SURV & MADE CORR AS REQD. TRIP TO SHOE(29 STD). REPLACE HOSE IN MUD LINE BETWEEN SUB BASE & RIG FLOOR. (HOSE BEGAN LEAKING). RIH. DRLD 7855-8468'. ADT 4 HR. DAILY:S48,926 CUM:$502,759 ETD:S502,759 EFC:$1,690,000 06/06/91 ( 7) TD:10026' (1558) SUPV:JRR 06/07/91 ( 8) TD:10065' ( 39) SUPV:JRR 06/08/91 ( 9) TD: 9957'( SUPV:JRR o) DRLG 8-1/2" HOLE DRLD 8468-10026' 9-5/8"@ 5225' MW:10.5 VIS: 44 DAILY:S61,869 CUM:$564,628 ETD:S564,628 EFC:$1,690,000 CIRC W/ BATCH MIX CMT 9-5/8"@ 5225' MW:10.5 VIS: 47 DRLD 10026-10065. CIRC BU. 25 STD SHORT TRIP. CIRC & COND MUD. TOH. UNLOAD LOGS & SOURCE FROM LWD. LD BHA. PULLED WEAR RING. RU WEATHERFORD TO RUN CSG. RAN 117 JTS 7" 26# J55 BTC & 118 JTS 7" 26# J55 BTC-MOD CSG PLUS MARKER JT. FS @ 10045' FC @ 9957'. CIRC AT 9-5/8" SHOE(OK). FINISH RIH W/ PARTIAL RETURNS WHILE BATCH MIXING CMT AND RECIPROCATE. DAILY:S148,447 CUM:$713,075 ETD:S713,075 EFC:$1,690,000 RIG RELEASED 9-5/8"@ 5225' MW:10.6 VIS: 0 TEST CMT LINES TO 4000 PSI; PMP 10 BBL ARCO PREFLUSH, DROP PLUG #1; PMP 35 BBL ARCO SPACER, DROP PLUG #2; PMP 250 SX (54 BBL) BATCH MIXED CLASS G CMT + 3% CFR-3 + 0.235 HR-5 + 0.5% BENTONITE + 3.0% CAL SEAL + 0.6% LAP-1 + 0.02 GPS 434B @ 15.5 PPG (1.23 CUFT/SX); DROP TOP PLUG, DISPLACED W/380 BBL 10.6 PPG NACL/NABR; BUMPED PLUG TO 3500 PSI FOR CSG TEST RECIPROCATED PIPE BUT NO RETURNS WHILE CEMENTING. P/U BOP STACK AND SET SLIPS; CUT OFF 7" LANDING JT AND SET PACKOFF; BLEW DOWN BRINE TO 80'; N/U BOP STACK. LDDP. N/D BOP STACK N/U FMC 11" 3000 X 7-1/16" 5000 TBG SPOOL; TEST PACKOFF TO 3000 PSI (OK); INSTALL 7-1/16" 5000 X 3" 5000 ADAPTOR FLANGE AND 3" 5000 VALVE. INJECT 125 BBL DIESEL FOR FREEZE PROTECTION. **RELEASED RIG @ 0530 09-JUN-91** TEAR DOWN RIG FOR MOVE TO 1R-19. DAILY:S238,247 CUM:$951,322 ETD:S951,322 EFC:$1,690,000 RECEIVED SIGNATURE: DRI LLIN~PERINTEN~NT ARCO Alaska, Inc. Date' July 5, 1991 Transmittal #: 8161 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Confidential items. receipt and return one signed copy of this transmittal. Please acknowledge 1L-26 CDN 6/3-6/9 1 5225-1 0065 1L-26 CDR 6/3-6/9 1 5225-1 0065 1L - 26 LIS Tape and Listing 6 - 3 - 91 74615 Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: State of Alaska RECEIVED JUL 8 7991 Alaska 011 & Ga~ Cons. ALASKA OIL AND GAS CONSERVATION COMMISSION May 20, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510'0360 Re: Well No. Kuparuk River Unit 1L-26 ARCO Alaska, Inc. Permit No. 91-69 Sur. Loc. 566'FNL, 217'FWL, Sec. 32, TllN, R10E, UM Btmhole Loc. 1779'FNL, 1441'FEL, Sec. 5, T10N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. David W.~_~°hn~ton, Chairman Alaska O~ Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill I~ Redrill r'-']l lb. Type of Well Exploratory ['-I Stratigraphic Test I-1 Development Oil Re-Entry r'l Deepen [-II Service r'l Development Gas r'l Single Zone [] Multiple Zone 2_. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 129'~ Pad 86' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25664, ALK 473 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 566' FNL, 217' FWL, Sec. 32, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1350' FNL, ;~)0' FEL, Sec. 5, T10N, R10E, UM 1L-26 #UG30610 At total depth 9. Approximate spud date Amount 1779' FNL, 1441' FEL, Sec. 5, T10N, R10E, UM 5/29/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 L-19 10,123' MD ..!..~441' @ TD feet 60' ~ surface feet 2501 6,337' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 56° Maximum sudace 2149 psig At total depth (TVD) 3060 psig 18. Casing program Settinc} Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Couplin~l Len~lth IVD TVD lYE) TVD Iinclude sta~le data1 24" 16" 62.5# H-40 Weld 80' 43' 43' 209' 209' +200 CF 12125" 9.625" 36.0# J-55 BTC 5244' 43' 43' 5,287' 3,630' 800 Sx AS III & HF-ERW 580 Sx Class G 8.5" 7" 26.0#i J-55 BTC 10080 43' 43' 101123' 6~337' 210SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth RECEIVED Conductor Surface Intermediate ProductionMAY 16 Liner AJaska 0ii & Gas Cons. Commission Perforation depth: measured .... true vertical ~lJlchorage 20. Attachments Filing fee [~ Property plat r'] SOP Sketch [] Diverter Sketch F~ Drilling program [~] Drilling fluid program [] Time vs depth plot E] Refraction analysis I--I Seabed report r-I 20 AAC 25.050 requirements [] ~'1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~'~/~ ~~ Title Area Drilling Engineer Date ,,~~/¢/ Commission Use Only i permit Number I API number I Approval0~a~ Ieee cover letter for ?//'" ~"~ 50-4~7.2.~'~ -' 2_ 2- // 7~.~ 20 / 9]- other recluirements Conditions of approval Samples required r"~ Yes J~ No Mud Icg required D Yes .[~ No Hydrogen sulfide measures D Yes [~ No Directional survey required /,~ Yes E] No Required working pressure for DOPE r"l 2M ~] 3M E] 5M E] 10M r-] 15M Other: '~ ~ ..... by order of / Appr _ _:__ .... Commissioner the commission Date DRILLING FLUID PROGRAM (1L-26) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drillino Fluid System' T~.ndem B~andt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2149 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 L-26 is 1 L-19. As designed, the minimum distance between the two wells would be 60' @ surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVED ~AY 1 (; t991 Alaska 0il & Gas Cons. Commission Anchorage o o · '400 _ -6 800 - - 1200- _ (--" 16oo- CL - (l,) 2000- 2400- 0 ~ 2800- - (D 3200- _ 3000~ 4000- _ 4400 - - V 4800- _ 5200- 6400 - ARCO ALASKA Structure · Pad 1L Well' 26 Field · Kuporuk River Unit Location · North Slope, Alaska Created by : jones For: E FITZPATRICK Date plotted : 13-May-91 IPIot Reference is 26 Version #2, ICoordinotes are in feet reference slot /~26, [True Vertical Depths are reference wellhead· / [-}}}J~ E A S T M A N / IZ;J/IIICH RISTE NS E N I A Baker Hu~heJ company Scale, '200.00 East --> 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 I I I I I I I I I I I I I I I I I I I I I SURFACE LOCATION: J 566' FNL, 217' FWL SEC. $2, TllN, RIOE S 29 DEG 9 MINE 6944' (TO TARGET) RECEIVE RKB ELEVATION: 130' KOP TVD:300 TMD:300 DEP:O 3.00 g.o0 15.00 BUILD 3DEG/IO0' 21.00 27.00 33.00 B/ PERMAFROSTTVD=1480 TMD=1572 DEP=408 39.00 45.0O 51·00 EOC WD=1883 TMD=2165 OEP=841 Nastm.oij & Gas Cons, Commission ',t4nchorage TARGET LOCATION: 1350' FNL, 1680' FEL SEC. 5, TION, RIOE TARGET TVD-6005 TMD=9550 DEP-6944 SOUTH 6064 EAST 3383 T/ UONU SNDS 7VD:2375 TMD=3045 DEP=1570 T/ W SAK SNDS'R/D=2950 TMD:4072 DEP:2421 B/ W SAK SNDS TVD=3430 TMD:¢930 DEP=3132 9 5/8"CSG PT TVD=3630 TMD=5287 DEP=3428 K-lO TVD=3835 TMD=5653 DEP=3731 AVERAGE ANGLE 55 DEG 58 MIN K-5 TVD:5170 TMD=8038 DEP=5708 TD LOCATION: ] 1779' FNL, 1¢41' FEL SEC. 5, TION, RIOE TAROET -- T/ZONE C TVD:6005 TMD=g550 DEP=6944 T/ ZONE A TVD=6135 TMD=9762 DEP=7136 'x~ B/ KUP SNDS 1VD:6225 TMD:9923 DEP:7270 TD / LOGGING PT 3VD=6357 TMD:10123 DEP=7435 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Scale 1 : 200,00 Vertical Section on 150,84 azimuth with reference 0,00 N, 0.00 E from slot #26 400 .. · 12oo _ -16oo _ -2000 _ -2400 - 0 -2800 - ---!-- -3200 - -3600 - V -4400 _ -4800 _ -5200 _ -5600 _ - 6000 _ -6400 6800 100 I 150 I 200 I 250 3O0 350 4O0 ,,I i i I 350 400 450 500 550 SO0 $50 700 FSO ii , m i 500 { - i k,soo ~ I _ ,:oo ,,, ~ 900 x 1 O0 150 \ %1100 \ \ ! ! I 250 I 200 , I 300 35O 400 350 400 450 500 550 6O0 650 70O 750 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 L-26 I . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" sudace casing point (5,287') according to directional plan. Run and cement 9-5/8" casing. Install and test DOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to logging point (10,123') according to directional plan. Run open hole evaluation logs. Run and cement 7" casing. Pressure test to 3,500 psi. ND DOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test DOPE. Perforate and run completion assembly, set and test packer. ND DOPE and install production tree. Shut in and secure well. Clean location and release rig. 7 , 6 5 I3 4 13 5/8" 5000 I-,.,I BOP STACK AC(~UMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W! CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR Gas 'Cons. Commission Anchorage ,'(UPARUK RIVER UN~£ 20" DIVERTER SCHEMATIC I 5 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACH IEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) REEEiVED ~a~:,Oil.& Gas Cons. ~r~iss~o~ gnchorage 1. 16" ~NDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH ~O 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SP~L WITH ~O 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNU~R PREVEN~R. VALVES CAN BE REMOTELY CONTROLLED TO ACH IEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNU~R PREVENTER SRE 2/6/ *~ CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE [2 ~hru 8] '[9 thru 13] [10 & 13] · [14 thru 22] (5) BOPE ~.~ G'o ~ ?-~/ [23 thru 28] (6) Other [29 thru 31] (6) Addl Company //-,,..~ Lease $ Well 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool ................. , ............. 3. Is well located proper distance from Property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ YES NO 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Does operator have a bond Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ............................ ... Is in force ................................... ~ conductor string provided ......................................... 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. Is Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. enough cement used to c i rculate on conductor & surface ............ ,¢¢g' Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to .~Od~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented.... 32. Additional requirements ............................................. REMARKS O -4 -r'z ,--,-~ O geology' eng i neer i ng~ DW~I~ MTM,~-~¢' LCS ',/'~Y' RP~ BEW ¢ RAD, '~, dH/ -" rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' 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. * ALASKA COMPUTING CENTER , , , * ....... SCHLUMBERGE~ .... ---* ****************************** CORRECTED COPY CO~P.A, NY NA~E : ARChi ALASKA, W . .. L,_.t L -_.2.6--.------ ',ELL ~,~' ~ ~ E ~'IELD BOROUGH : NO,TM SbOPE STATE : API ~L;~!~ER : 50-O29-~2173 PEFE~ENCK NO : 92026 I NC, UNIT RECEIVED FEB :! 5 1992 Alaska 011 & (las Cons. Commi~slon Ar~ora~ ID 90~[00 : DIri~ : I ~d~£ S[]OiA~d ~t9~L : 3w~a ad~ **** a3ov3a 3d~i **** :3D~d bis var, e verification bisttna 5chl,J~,~erqer Alaska Como~tlnc CeDter 120 GL: R6 ~T? LOGGED: 03-JUN-91 10065 CASI'!C : 9 5/8" 36 I~B ~a DRILLER PFPTH OF 52~.5 DENSITY: 10.4 RESISTIVITY: RESISTIVITY: 3.35 ~ 72 4.51 a 72 ~XI~!J~ TEMP RECORDED: 149 bOGGING DISTRICT: LnGGING PR!,!DNOE BAY PERRY RGS02~ NBS014 F!ELD REMARKS: BIT RU~,f ONE-' DRILLED INTERVAL 524(~' Tgi 5644'. GAMNA RAY READING 77FT BEHIND BIT RESISTIVITY ,i~EADING 66FT ~EHIND BIT. DENSITY READING I?gFT B~HIND BIT. NEU..RON READING 13~FT BEHIND BIT. BIT RUN TWO: ,tD~ILLED. INTERVAL 5644' Tf) 10065 . GAMMA RAY READING 77FT BEHIND BI .... . RESISTIVI~'Y READING 67FT BEHIND BIT. DENSITY REAPING 179~.,. ggHIiD BIT. NEUTRON READI?;G 1]6ET BEHIND BIT. RESISTIVITY/GR RECORDED SAMPLING RATE: 20 SEC.. pt.l}.tP HOURS= 45.5 REAL TIME RESIST~VITY/GR TRANS~*!IssIo~N RATE= 1,5 BPS. ~ DENSITY ~ATRIXm 2.65 G/CC. FLUID DE~SITY= 1.0 G/CC. CDM S~ABILI~ER OD- 8.4375". STEERABLE BHA USED TO DRISL 8 1/2" HOLE. BII TYPE = PDC. BARI'rE USED AS A ~UD ADDITIVE. CDh SA~PLING RATE-- 30 SEC. DATE JOB STARTED: IO-JUN-ql J~B REFERENCE NO: 74615 LDP/ANA: KOHRING PAGE: FILE - ED!T.oO1 ARCO ALASKA~ K, tlPA RI[IK 50-0~9-~2.17~ DRILLING PASS -. DIT R[IN1 MERGED TD BIT RI.J~!2 AlasKa C_omPutln~ Center ~ 1-,IAN-?.q. 97 ',.35:54 O~TA SA?,~["I,ED EVi'~F¥ -.bs)O0 FEET TYPE !!S ~lO !',i AME CDR ,LWD G~ .LWD C~ .5WD COi~!PENSATEh OItAL RESISTI~!ITY RaY CO~-" DE~SATEO NEUTRON 5525' TO 9998' 5525' TO 9988' 5525' TO 9935' PAGE{ CC~MPLITING CEHTER Rf:MARKS (20-JAN-92): ~IS [,IB~ARY T~PE HAS B~EN REVISED TO INCLUDE REC~LIBRATED CDN DENSITY DATA. DATA PRESE~,~TED IS FRON 'RHOB TYPE TUNI V;[,U DEFI TYPE FT FT FT FT CP ARCO AbASKA INC. KUPARUK RIVER UNIT 1b-26 50'029'22t73 566' FNL & 217' FWb I!N NORTH SLOPE ALASKA USA 129. 129, 1~9. ~6, 10065, 10065. 5225. 3.35 Company Name Field Name Well Name API Serial Number Field Locatio~ Section Townsbip Range County State or Province Nation Witness' Name Service Order Number Permanent datum Elevation of Perm, Da bo~ Measured From ABOVE PER~ANENT DATUM Elevation of Kelly gu Elevation o~ Derrick Elevation of Ground b Total Depth - Driller Total Depth - LoDger ZONE Bottom Lo~ Interval Top bo~ Interval Drilling Fluid Type ZONE Dr]llin~ Fluid Densit Drillln~ Fluid Ph ZONE Drilling Fluid ¥iscos ZONE Drillin~ Fluid boss ZON~ Reslstf~ity of ~ud Sa, bis ~*ane verff~.cati, en [.tstino $cblt.l~,er¢'ter Alaska ComI3utina Ceoter 95:54 PAGE: 4 72. ~ud Sample TemDeratur 4.51 Resist]v~t¥ of mud fi 72. ~ud Filtrate Sample T Resistivity of Mud Ca ZONE ~ud Cake Sample Tempe ZONE 1.49. 5otto~n Hole Temoeratu TYPE : CURV DEP~ DePth Chan~el Name p~r Photoelectric Factor D~o Delta ROS2 SS2 RHO [~ensitv - L.)~ ~Ug Bulk Density DCA[, Differential Caliper DP~{I Density Porosity PO~ Oenstt¥ ~orosity output from an Appllcatlo~ Pro~ram ~CI:~[, Far CN Detector Counts ~C~L Near C~L Detector Counts T~Pg Thermal ~eutrom Porosity ~T~ PGS BHC ATTENUATION RESISTIVITY pSR ~GS gMC PHASE SHIFT RESISTIVITY DF~ DIEbECTRIC RESISTIVITY FRO~ RGS ~OP~ RATE OF [)RIbbING GR Gamma Ray bis 'fane verffi, cat.ion [,i.$t~n~ 3ch]t~mberoer ~.laska Comp~lti~q center 21-JA~'~-I 992 05:54 PAGE: 66 0 3 73 64 4 66 5 66 6 73 7 66 8 68 0.5 !~ 66 16 !3 66 0 14 65 ~T i5 65 66 16 6~ 0 66 0 ** SET TYPE - CHAN '~'''~'''V ~T~'~~E ......... ApI ;~ ...... API ;~'~T~ ..... ~; NUMB' .... $'~''''''''ZE REPR ...... pROCEsS'''''' ' ..... . ........................... ...... ........ ......... .... DEPT FT 00 0 00 0 1 1 l 8 000 000000 PFF l..,¢P 00 000 00 0 I 1 1 4 6R 0000000000 DRH9 I.,~D G/C3 00 000 ()O 0 I I I 4 68 0000000000 ~OS~ !,WD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 ~('~B I~9 G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 ~C~[, L~D IN 00 000 00 0 1 ~ 1 4 68 0000000000 DPHI !,w'~ PU O0 000 O0 0 1 ! I 4 68 0000000000 ~PO~ L~D PU 00 000 00 O 1 1 I 4 68 0000000000 FOcaL Lw~ CPS O0 000 O0 0 ! 1 1 4 68 0000000000 NC~I,, t,~D CPS Oo 0o0 O0 0 1 ! I 4 68 0000000000 TNPg LND PU O0 O00 O0 0 i I 1 4 6~ 0000000000 ATR [,wD O~a~ 00 000 00 0 1 ~. 1 4 68 0000000000 PSR L~D O~M~ O0 000 O0 0 1 I ~ 4 68 0000000000 [)F~ [,~> (39~ O0 000 O0 0 1 ! 1 4. 68 0000000000 ROPt~ [..,~9 F/HR 09 000 90 0 1 ! 1 4 68 0000000000 (;~ [.,~D (JAPJ O0 000 O0 0 1 I l 4 6~ 0000000000 .~99 250 ROS2oI.,WD -.~99;250 DPoR.LWD -999.250 10.555 GR.bWD -999, 0 -999.250 -999.250 bl..q 'va~e verificatlon Ltstinq pMpT. 9700. OOO PEK. ~'Cf'.~L. {,t< D 22.162 r:'CNL. I, WD PSR. t.,t,: O 2. 920 O~R. DEFT. 96on,. 00o PE~. 5wD R:~O~. I,:~D 2,452 DC~b. bt,;D ~S~. T., t~ D 4. 589 DER. 2.499 2i.263. 2. ~47 DER. L~D q3Oq. 000 PFF. LWD 2,409 DCAb. LWO 19.793 3,358 DER PS~, L?,~D 3. 207 DFR. bUD 21-da~"-! 992 o5:54 -99 -99 2O 22 21 22 9.25o 9.250 9,250 9.250 3.8~7 0.605 7.835 2.4~4 3,184 0.491 6.263 4.616 4.093 0,591 2.137 2,885 3,024 0.522 0 7~6 4~6 2 3.177 0,728 215.0!3 2.777 3.324 0.451 207,334 2,!73 3.304 0,302 200.692 3.181 4,038 0.43l 214.216 3.094 5,564 0.23l 219,363 3.562 3,764 0,399 200,114 3.5~0 ,D-, P~ ! F~ 0 H l. T:JP~, RnPE. ~aPE,L~D D~HO, r:, p N I DR~O. b~,J9 ROPE.L:~D ORHO r)PMI DR~O. OPMI,LW9 ROPE DPMI T~]PH ROPE [)RNO DPNI,LWD TNPH POPE, L~D DRHO DPHI.bwD ?t'iPH DPHI q'L~P t{ POPE -999.25o -999.250 -999.250 -0.003 8.5O0 46.105 19.559 0 010 To:soo 33.762 7go120 -0.008 6.600 4O 65O 793997 0 031 i iooo 6 335 84.107 -0.052 6 500 54.201 -0 032 9~200 41.703 206,264 -0.017 14.600 46.142 86.750 -0.027 9.200 38.857 89.554 -O.OOl 2.700 41.1.63 67,419 -0.01.3 12.400 46.090 175.304 ROS2.L~D DPOR.LWD hTR.LwD GR.LWD ROS2.L~D DPOR.LWD hTR.LwD GR.LwD ROS2.LWD DPOR LWD ~TR:LWD GR.LWD ROS2 LWD DPOR[LWD ATR.LWD GR.LWD R052 LwD ATR LWD R082 L~D ~TR,L~D GR.LwD ROS2,L~D DPOR.I.,~D ATR.LWD GR.LwD RO$2.LWD DPOB.L~D ATR.LWD GB.LWD ROS2,LWD DPOR.I. WD ATR,LWD GR.LWD ROS2.LWD DPOR.LWD ATR.LWD GR.LWD ROS2.L~D DPOR.LWD CR.LwD PAGE: '999,250 -999,250 -999.250 -999,250 2,509 8,500 2.237 83,195 2 477 !0i500 4 ~52 71,05~ 2 542 6~600 2.827 85,906 ,i::i 2.499 9'200 195 2.409 ~4,600 2,932 ~06.949 2.498 9.200 2,822 147.476 2..605 2.700 3,186 242.982 2 445 12,400 3,~23 161,734 bis Ta~e verification [.istinq Schlu~.~erqer AlasKa Co~Dutlnq Cer'~ter 89oo. 000 PFTF. I;wD ~. t 48 I".Ek'. DFPT. 87~0,000 PEF.LWD ~O~,[¢D 2,334 OC~b,bWD FCNL.LWD ~0,148 ~CNL.I, wL) DSR,LWD 7.058 [)FiR.!,WD 8600 000 20,778 NCNb. LWD 5,324 DFR, LWD gEPT, 8500,000 RNOB,[..~9 2.513 DCAL,L~D F'CNL.Lwo 22.065 NCNL.UWb PSR.L~D 3,477 DFP'.r. 8400,000 PEF,LWD PWOB,LWD 9,443 DCAL't. WO ~CNb,LWD ~7,438 NCNh. LWD PS~.LWi) 5,572 DE~.LW9 D~PT. 8300,000 PEF.LWI) ~ ~ 0 B l,,, ,~ t) 2,633 D C l L. L w D FCNL,LWD 19,174 NCNL.L~D ~,~ L Q 4,363 DER LWD D~PT. 8200.000 PEF,LND ~OB.LWU 2.367 DCAL,LHD FCNL,L~D 2~,429 NC~L,LWD PS~,Lw~ 5.190 DER,LWD D~PT. 8100. 000 PEr. ~ aO~,~,. LwD 2,365 FCNI,.LW~ . 20,992 NCNL,L~D PS~ I.,'~;D 3,349 :,ER LwD DFPT. 7900,000 PEF.LWD P~;OR.LwQ 2.434 DCAb,LWD FC~!L.L~D 21.59i ~CNL,i, WD PS~.LWD ?.2~3 DFR.LwD 21-JAH-1992 3.966 0.307 ~10.216 TF:PM.BwU 4.837 RC!PE,Lw9 3.708 Di~HO.BW¢ 0,113 DPNI,LWD 21!,865 TF?}i. LWD 6,469 RC)PE,LwD 3.927 DPHU.LWO 0.264 DPMI.LWD 204.432 TNPH,L~O 5.020 ROPE,LWD 2.989 DPHO.LND 0.512 DPH!.LWD . 2 'P bWO 204 6 4 T~.:H. 3,479 ROP~.LWD 3.210 D~HO,LWD O.300 DPMI.LW9 222,004 Tr~PH.LWD 5.436 ROPE.LWD 4,214 0,762 DPHI,LWO 196,014 TNPH.bWD 4,163 RDPE.LWO 2,832 DFHO,LW9 0,391 DFHI,LwD 208,809 T~:PH.LWD 4,747 RpPE,LWD 3,0~3 0.3 6 DP~',I, u 208 4.21 TN~H, LWD ~2: 875 ~ 0 P C, L W D -0.016 13.300 45.999 54.a91 -0 010 q:800 41.434 40.654 -0.015 19.100 47,569 154.203 -0.030 1.3 ~00 42!9.35 1.97 813 -0.014 8.300 ~0.263 149.201 -0,022 ~.5oo 29.1,32 91,950 0.038 1.000 45.074 ~47.545 -0 041 39,084 96,657 0,005 17 200 43ii35 130 434 -0,021 16 400 35i924 158 497 -0.002 13.I00 41,891 236,439 ROS2.LWD DPOR,LWO ATR,LWD ~R.LWD RO$2.L~D DPOR.LWD ATR.LWD GR,LWD RO$2.bWD DPOR.bWD ATR,LWD GR,LWD ROS2,bWD DPOR,LWD ATR,LWD GR,LWD ROS2,LWD DPOR,LWD ATR,LWD GR,LWD RO$2 LWD DPOR:bWD ATR,LWD GR,LWD ROS2.LWD DPOR,LWD AT~,LWD GR,LWD ROS2.LWD DPDR,LWD ATR,LWD GR.LWD R052 LWD DPOR' ATR .LwD ,LWD GR.L~D R052 LWD DPOR,LWD ATR,LWD , W GR L D RO$2.LWD DPOR,LWD ATR.LWD GR,LWD PAGE: 2.430 13.300 3.210 101.422 2.488 9.80O 4,398 99.332 2,334 19 100 4~494 90,211 2 423 4,560 131,645 2.513 8,300 3,483 107,119 500 5,.178 75,390 2,633 ,000 .847 12:563 2,]67 17, O0 2,912 138,459 2,365 17,200 2,430 121.844 2.380 I~,400 ,878 96.553 2 434 13:i00 2,302 88,686 bis ~ra~e Verification Listinc; 5chit}robert;er Alaska Comptltln~ Center 77 O 0.000 2,403 23.232 3,~42 7600,000 2,373 2.83 1 7500,000 24.716 ?. O 16 740u, 000 2.416 23,468 2. 670 7300.000 23,564 7200,000 2.603 7100,000 2,402 23.403 2. 673 7000, g 00 22,861 2,705 ~900,000 2,343 23, 2. 777 .68 ~'' 21.356 05:54 21 2.9~8 o.401 2,635 2.754 FEF.!,~D 2.713 !~C~!,.L~O 0.262 ~CNI~.LWD 214.314 !)EP,LWD 3,047 ~.LWD 2,707 OC~L.LWD 0,284 NCNb. LND D~R.LWQ 2,883 PEF.LWD 2.848 DCAL.LwD 0.362 !)~R,LWD 3.150 PEF.LWD 2,731, DCAb,LWD 0.314 ~CNL,LWD D~R.L~D 2.753 P~F.I.WD 2,597 DCAL.L~D 0.273 NCNL.LWD 212,753 DM~,LWD PEF.LWD 2,535 DCAb. LWD 0,425 ~'}CNb,LWD 2~)5"694 DER.LWD 2.570 PRF,LWO 2,902' DCAL.L~D 0.214 ~C~h.bWO 211,312 /'>~R.L!~D 2.964 PEF.L~D 2,743 DCAL,L~{D 0,3~9 5~CN[.,,LWD 210,15] DE~.I.,WD 2,817 P~F.L~D 2.706 DCAL,L~O 0.288 t>~R. LWt) 2. 769 PEF,L~D 2. 709 DCAL.b~O O. 594 [>ER.L~,:O 2.738 DRHO.L~O OPHI.L~D ROPE.5~D DPHI. [,Wi) DRHO,LWD Or'~I,bWD D~HO.bWD OP~I. LwD ~OP~.Lw9 ~MO.bWO DPHI,LWD TI~PH,bWD ROPE,LWD Di?HO,LWD DPM!,bwD TNPH.LWD ROPE,LWD DRMO,LWD DPHI.L~D TNPH.bWQ ROPE,LwD r>RMO,LWO DPHI,LWD '?~PH.bWO DRHO,LWD TNPH.LWD DRHO.LW© OPHI,LWD TgPg,LWD ROPE.L~D DPHI'L~D TUPH,LMO ROP6,LWD 0.011 11.600 37.089 108.813 -0.021 15.000 37.9~8 146.996 -0.014 16 800 I82.572 0.002 15.100 35 856 268~585 0.001 14 200 35!370 263 192 i0 019 8~000 38,445 244.$98 -0.004 15 500 40i534 272 795 0.014 15.000 37,114 205,070 -0.018 ~6,400 39.019 234.537 0.001 18 600 130.410 0.008 15.100 40.457 207.371 ROS2.LWD DPOR.L~D aTR.LWD GR.L~D ROS2.LwD DPOR LWD 'R A~.~LWD GR.LWD ROS2.bWD DPOR.LWD ATR.LWD GR.LWD ROS2 LWD DPOR~LWD ATR,LWD GR.LWD ROS2 LWD DPOR:LWD ATR,LWD GR,LWD ROS2 LWD DPORiLWD ATR LWD RO$2.bWD DPOR,LWD AT~,LWD GR.LWD ROS2,LWD DPOR,LWD ATR,LWD GR.LWD R052 LWD DPORiLWD ATR LWD GR,LWD ROS2.LWD DPOR.LWD ATR.LWD GR,LWD ROS2 LWD ATR.LwD 6R,LWD PAGE: 2.458 ½:,oo 787 79,353 2 403 15i000 3058 80 663 2,373 16,800 2,986 79,922 2,40~ 15,10 3,486 63,349 556 21.352 18,000 3.333 76,434 2,394 15,500 2,5!7 69,897 i!°°° 9t9 7 829 I 400 6O0 12,755 73,027 2,784 85,961 Schlu,berner A].aS~S ..COmmUti~(~ Center PS~. L..,~D 2. 872 D~R. L~'D DFPT. 6500. 000 PKF. PHO~. b t,~ I) 2.331 r)c Ab. b~D FCK~T,. L~,,D 21 .946 DEPT. 6400. 000 PEP. b~'D RHg~. [~ 2,362 FC~;T,. L~O 2i .360 t,~CNL, b~/D PSn. L~D 2. 747 DER. DFPT. 6300. 000 PEF. Psn. [,~n 2.911 D~DT. 6200,000 PFD, ~HOB.L~4D 2,240 DCAL.bWD PS~. [..~ ~3 2,364 DER, t)FPT 61 C~ 0, O00 PEF. bw P $ ~. L ~,~'D 2.3 ! 6 D E R. L w D DKPT, 6000,000 P. EF. PHO~,. L~,~D 2.317 OCAL, l.~J PSP. t3 ~ O 3.510 DER. t.,~; D DFPT. 5900 ~ 000 PEF. ~"Og. [.,~'~ ~ 2,403 DCAL.Lt<D DS~. t., ~,~ D 3, ~42 DER. byrd [?KpT. 5aGo. 900 ~Er. L RHOH.L~D 2,250 DCAL. hW[> PS~. [,~P 7, t 2O DER. [) ~ [., Y. 57 (" 0. C) 00 P g F. k: H['~R. t,, ~ D_ ? .262 DCA L,. ~,~,qD .... P S P, L ~ r) 5,079 ~:) F] R. L ~49 21-JA?,;-lq':)2 a5:54 2.889 DRHO.L:VD 0.n46 npHl.bWD 213,046 TNPH,b~D 2.695 0.164 9PHI,L~D 212.469 3.0b0 RUPg. L~D 2,745 0 325 OP~I.LWD 2()6~059 T[,~PH.GW9 2,872 ROPE,L~O 2.797 D~HO,LWD 0.247 DPMI.L~D 206.820 2.990 2.728 DRHO.L~D 0.410 DPHI.L!~D 205,248 TNPH 2,977 RO 0,055 DPHI,LWD ~03,g42 2.615 ROPE:,LWD 2,665 DR:40,LWO 0,206 DPHI.LWD 195,078 2,~47 2.947 tJRHO,L~D 0,000 DPHI,bWD 207,020 TNPH,b~D ..3'545 RO~E.L!~D 3.046 DRHO,LwD 0.878 DPgI,LWO 188,628 TNPH,LWD 3,939 ~,519 1.273 DPUI,LWD !84,034 T~PH,~WP 7,441 2,421 DRHO,LWD 0.653 P~II, 207.110 T~!P~,LWD 5,31! -0.027 19.900 40.077 133.598 -0.022 20.600 38.882 168.213 -0.011 19.300 40.726 156.583 -0 020 17i400 3q 963 123 625 -0.035 20 600 40:116 150,650 ~0 026 4~900 40 818 204~230 -0.032 2~.700 41.908 123.552 -0.018 2O 2OO 112,739 0.023 15,000 46,931 !26.588 0 007 24i200 4.6 685 231,681 -0.024 23,500 34 724 s 232o RO$2.LWD DPDR.LWD ATR.LWD GR.L~D ROS2.bWD DPOR.LWD ATR LwD GR:LWD ROS2.LWD DPOR LWD ATR:LWD Gr'l, wD ROS2.LWD DPOR LWD ATRiLWD GR L~D ROS2,LWD DPOR,LWD ATR.LWD GR.LWD ROS2.L~D DPOR LWD A~R:~wD GR.LWD ROS2,LWD DPOR,LWD ATR.LWD GR.LWD ROS2 LWD DPOR:LWD ATR,LWD GR,LWD ROS2.LWD DPOR,SWD ATR,LWD GR,LWD ROS2 I, WD DPORi~WD ATR,LWD GR,I, WD R~$2,LWD DPOR.LWD ATR,LWD GR.LWD 2,321 1~,900 76'233 . 2,331 19,300 8 967 2.362 t7.400 3,931 73,146 2,310 20,600 3,115 88.242 2.2.40 24,900 3.809 83,973 2.293 21,700 ~,952 7 ,299 2! '317 .200 .618 86,877 ~40~ 1~ 000 0 727 5~.271 2.262 23,500 6,035 64,879 bis ~ane verification I, istinq Sc~lu~,~,er.qer AlasKa Computin~ Ceater 2!-JAN-19q2 05:54 PAGE: lO 2.638 OkHO.b¢!) 0 018 1.132 ~P~I.5~D 17~500 t84.751 Ti,;P~.L~O 48.340 3.599 RoPE.b~D -999.250 DFPT. 550~.500 P~.[.WD -99q.250 D~gO,bV~D -999.250 Rt~O~.L~n -999.25~ [.)C~L.L~D -999.25{) OPRI.L~D -999.250 ~NI..L~D 16.529 ~C~]U.LMD 179.554 T~PH.Lw9 50.070 PSg.b~U -999.259 DER.b~O -999.250 ROPE.b~D -99g.250 ** END OF nATA ** ROS2.LWD DPOR,bWD ATR,LWD GR.LWD ROS2.[,WD DPOR.LWD ATR.LWD GR.LWD 2.361 17,500 3,771 99,339 -999,250 -999,250 -999,250 -999,250 **** FILE TRAILER **** FILM NA~E :'EDIT .001 SERVICE : FL!C VERSIO~ ~ 00~AO6 !)aTF : ~2/01/21 ~X REC SIZE t !024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SMR~!CE NAaE : EDIT D~TE : 92/01/2i 'r~P~ NA~E ~ 74615 COb~TI ~UATIOM ~ DPEVlO[!$ TAPE CO~!~E~T **** REEL TRAILER **** SM~V!C~ NA~qE ~ EDIT [!~IGIN : Fl, lC pFEL ~A~E : 74615 CONTINUATION # : PP~VIOOS REEL CO~E~T : ARCO ALASKA, INC.,KUPARUK RIVER UNIT,1L-26,50-029-22173 INC.,KUPARUK RIVER UNIT,Ib-26,50-029-22173
