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Home My WebLink About200-100Ima~roject Well History File CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (~O~- 1 ~- 0 Well History File Identifier RES(~AN DIGITAL DAT,R OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation x o= ! BY: BEVERLY ROBIN VINCENT SHERYL~VINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES BEVER~ VINCENT SHERYL MARIA WINDY BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO FOUND: '~ YES IF NO IN STAGE 1, PAGE(S) DISCREP~E NO III IIIIIIIIIII II II RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: I$1 General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, May 22, 2009 9:08 AM To: 'Peirce, John W Subject: 2N-318 (200-100) John, I am reviewing the 407 submitted for the plugging of this well in preparation for re-drill. It does not appear that the summary for 3/25/09 is complete. The summary ends white continuing to test BOP and the ' 3/26/09 summary begins with "continuing to POOH with tubing". Would you please send the revised summary? Thanks in advance. Tom Maunder, PE AOGCC a~ t,~ Maunder, Thomas E (DOA) From: Allsup-Drake, Sharon K (Sharon.K.Allsup-Drake@conocophillips.com] Sent: Friday, May 22, 2009 11:08 AM To: Maunder, Thomas E (DOA) Cc: Peirce, John W Subject: FW: revised summary for 2N-318 Attachments: 20090522150303 001.PDF 20090522150303_0 01.PDF (280 KB... Tom - Attached is a revised summary of the PS~A operations for 2N-318 that you requested. Thank you, Sharon 263-4612 -----Original Message----- From: Allsup-Drake, Sharon K Sent: Friday, May 22, 2009 11:06 AM To: Allsup-Drake, Sharon K Subject:. GlobalScan document sent from sallsup. 5/22/2009 STATE OF ALASKA • 'S ALASKA OIL AND GAS.CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged / Abandoned / Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March , 2009 12. Permit to Drill Number: 200-100 / 309-047_ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 7, 2000 13. API Number: 50-103-20343-00 4a. Location of Well (Governmental Section): Surface: 51' FNL, 719' FEL, Sec. 3, T9N, R7E, UM 7. Date TD Reached: August 25, 2000 14. Well Name and Number: 2N-318 - Top of Productive Horizon: 273' FSL, 2015' FEL, Sec. 28, T10N, R7E, UM 8. KB (ft above MSL): 35' RKB - Ground (ft MSL): 153' AMSL 1b. Field/Pool(s): Kuparuk River Field Total Depth: 709' FSL, 2374' FEL, Sec. 28, T10N, R7E, UM 9. Plug Back Depth (MD + TVD): 2810' MD / 2449' TVD Tarn Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460874 y- 5911957 Zone- 4 10. Total Depth (MD + TVD): 11456' MD / 5243' TVD - 16. Property Designation: ALK 380054, 375074 TPI: x- 454317 y- 5917597 Zone- 4 Total Depth: x- 453960 - 5918036 Zone- 4 11. SSSV Depth (MD + TVD): ~ sanding nipple @ 518' MD / 518' TVD 17. Land Use Permit: 4602 18. Directional Survey: Yes ^ No0 (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): approx. 1225' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 40' 114' 40' 114' 24" 9 cu yds High Early 7.625" 29.7# L-80 40' 2603' 40' 2311' 9.875" 515 sx AS III Lite, 240 sx Class G " 5.5" 15.5# L-80 40' 10590' 40' 4982' 7.5" 280 sx Class G & 34o sx Class G 3.5" 9.3# L-80 10590' 11447' 4982' 5241' 7.5" included above '5.5 casing cut @ 2810' 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET entire liner is slotted except for the following blank intervals: none 10580' perforations squeezed off 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 10630' 38 bbls cement cement plug 2410'-3204' 202 sx Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / Sidewall Cores Acquired? Yes No ^/ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~ ter- ~~~:" NONE aA ~' ~~_ ~ ~I~~~~ ~fl ~ has Cony, ~r~mmi ' ssiQl-~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE T,~~S~~~ttrErtlA /p ~ ~ ~ '~, ~;pY ~ ~ 2009 ~~~~ ~ ~5~1'1 28. GEOLOGIC MARKERS (List all formations and mar encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1249 1225' needed, and submit detailed test information per 20 AAC 25.071. T-3.1 10650' 4999' T-2 11075' 5127 N/A .Formation at total depth: not applicable 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: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Enoineer "~ ,~! ~ , ~ ~ "~ ®~ ~ Signature ~ ~ ~~'~/ w~ ~` ~ Phone Date / / 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 welt 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 " KUP • 2N-318 ant, i CC3I~~drt 11~1I~$ 1~ e ttn ut _ es - ~ ax ° ngle & MD TD . ~.. r`; ~.:.I !1Ir_. ' w weu sta ~~ ) tus Prod/ln T lnd 1 YPa ( I MD(ttKBI 1', Act Bim (RKBI ' , - -- S0 032034 00 . PROD TARN PARTICIPATING AREA 76.78 6,396 ' 11,456 Comment IH2S (ppm) Date ~ Annotation End DaM KB-Grd (tt) Rig Release Date ° --- - SSSV~ NIPPLE 20 7/1/2008 I Last WO: ~ 40.19 I 9/V2000 ~ I ____wenc n -zN~3+e zz5rz6u<:a ~; - ~.~ _ snema A,uvi ', Annotation '1 Depth (ftK6) End Date (Annotation '.End Date 1 fi .VIP~LE. 516 ~ I, Top Incl f ' Top (itK6) ftKB ( ) (°) Description Comment __ - 518 517.5 6.14 _ NIPPLE Camco'DS'Nipple GAS LIFT'___-- 2,360 - 2,364 2,139.8 42.17 GAS LIFT CAMCO/KBG 2-9/1/DMY/DCK/1/Comment STA1 - 5,656 3,466.1 ~, 69.27 1 GAS LIFT CAMCO/KBG 2-9/1/DMYIDCK///Comment STA 2 8.504 _ 4,348.8' 70.28 GAS LIFT ~CAMCO/KBG 2-9/1/DMY/BTM///Comment: STA3 10,512 4,959.7 ~I 73.60 SLEEVE-C BakerCMU Sliding Sleeve, w/2.813" Camco profile: SURFACE. _ CLOSED 4/27/2006 2.603 _ _ 10,553 4971.2 73.39 GAS LIFT CAMCO/KBG 2-9/1/DMYlDCK//l Comment STA4 10,580 4,979.0 73.25 CSR Baker CSR Assy, Size 80-00, 5.5" x 4" 10,595 4,983.3 73.18 NIPPLE Camco'D' Nipple, wlNo-Go prof le Gns uFr. ~ ~~ 10,604 985.9 73.13 4 SEAL Baker 80-00 Casing Seal Assembly 4" od x 2.985" id 5,656 . , , , 10,630 4,9935 ~, 73.00 CMT Retainer 3.5" EZSV HALLIBURTON CEMENT RETAINER (OP 7 '', 1 ',32.96") PRE-SIDETRACK EUE GAS LIFT. es6a ...r t......t 10.952 ....,r~ ..-.-_, ....._r .-..~~e ..o.e .. ~~r~ 10 96711 5,087 7 5,092.6 9/62000 4.O~IPERF .....~~~..e.. 25" HSD, 180 deg ph ~` Stimula tions & Treatments B n Min Top o nm Max Bim ITOp Depth Dapih Depth Depth (TVD) (Tl/DI (RKBI (RKB( (RKB( (RKBI T ypa Date 1 Comment SLEEVE-c. __ 10,952 _ _ _ 10.957 5 087] 5,089.3~FRAC 9/10/2000 ~~Placed 234 Mlbs of proppant in formation 10.512 N -____-...__ - . l 8 S f _ , otes: Genera a ety End Date Annotation - 7/252005 ', NOTE' LAST SBHP SURVEY TAKEN @ 8807 RKB 5/1/2006 I NOTE: FOUND IA z FORMATION LEAK @ 5180' ELMD - 5700' ELMD - GAS LIFT,. 10,553 PRODUCTKN, i 10,580 CSR, 10,580 NIPPLE, 10,595- 1 SEAL, 10.606- I CMT Ratainer. 10.630 FRAC, 10,952 ~~ ' IPERF, _ _ 10552-'0567 PRODUCTION, 1164] TD, 11.456 s ~r 2N-318A Sidetracl~As Built) ~~~~ 1 » Topset 5-/z Casing 3'/2' Camco 'DS' nipple w/ 2.875" No-Go profile at 505' MD 3'/2' 9.3# L-80 IBT Mod Tubing w/3.865" OD Special Clearance Couplings 7-5/8" 29.7# L80 BTCM casing @ 2603' MD / 2310' TVD Sidetrack KOP @ +/- 2800' MD 5-'/2' 15.5# Casing Cut @+/-2800' MD Baker "K-1" CIBP @ +/- 3200' MD Tubing chemical cut @ 10500' MD GLM# Tvpe Setting Depth (TVD-RKB) Valve Type 1 KBG2-9 2,400' SOV 2 KBG2-9 3,500' Dummy 3 KBG2-9 4,258' Dummy 4 KBG2-9 1 Jt above Sliding Sleeve Dummy 3'/2' CMU Sliding Sleeve w/ 2.813" DS profile (closed position), one joint above 2.75" D nipple 10,369' MD 3'/z' Camco 'D' nipple w/ 2.75" No-Go profile, one joint above seal assembly 10,419' MD Liner Top Packer 10,494' MD Cement Retainer set @ +/- 10630' MD Topset Point: 5-1/2" 15.5# L-80 Hydril 563 @ 10,704' MDl4,922' TVD 3-%z' @ 11,447 MD~ TD: 3-1l2" Hydril 511 9.3# liner @ 11435' MD / 5,175' ND • 2N-318 Pre Rig Summary (~2~ ~~~' DATE SUMMARY 2121/09 PULLED CA-2 PLUG BODY @ 10595' RKB. DRIFTED TBG AND SAT DOWN AT 10,650' SLM WORK THRU TO 10,688' SLM. UNABLE TO GET ANY DEEPER (APPEARS TO BE PUSHING SOMETHING DOWNHOLE -POSS. SAND) WILL RETURN AT A LATER DATE TO TROUBLESHOOT. 2!22109 SET CAT STANDING VALVE AT 10,595' RKB, PT TUBING TO 2504 PSI HELD SOLID FOR 30 MINUTES, TAG AND OBTAINED SAMPLE OF FILL FROM TUBING AT 10,714' SLM. IN PROGRESS 2!24/09 RAN A STATIC PRESS. TEMP SURVEY. 10710': 3115.5 PSI, 131.3 DEGF, 10410': 3085 PSI, 130.1 DEGF. SETA 3.5" CEMENT RETAINER MID ELEMENT 10630'. PT RETAINER TO 2500 PSI, PT FAILED, LOST 700 PSI IN 9 MIN. 2/27/09 TAGGED @ 10574' SLM WITH 2.73" LIB; INCONCLUSIVE. IN PROGRESS. 3/2!09 RAN 2.62" LIB TO CEMENT RETAINER @ 10633' SLM. REC. PICTURE OF RING ON LIB. READY FOR CTU. 3/6/09 PERFORMED CEMENT P&A THROUGH EZSV RETAINER @ 10633 CTMD. PUMPED 2.3 BBLS BELOW RETAINER & 34 BBLS SQUEEZED IN PERFS. PUMPED 2 BBLS ABOVE RETAINER, REVERSED OUT WITH BIOZAN PILL TO 10550 CTMD. SWAPPED WELL TO DIESEL, LEFT 500 PSI ON TUBING, READY FOR S/L. 3/8/09 GAUGED TBG WITH 2.70" GIR ON 2-1/8" x 15' STEM TO TAG @ 10528' WLM. MIT TBG 1500 PSI, 30 MtN, GOOD TEST. READY FOR E/L. 3/8/09 POWER JET CUT 3.5" TUBING AT 10368.3'. UNABLE TO REACH CMU WITH JET CUTTER. TAGGED AT 10502'. CONSULT WITH DRILLING ENGINEER AND DECIDE TO CUT AT 10368'. VAVLE CREW TO SET 8PV AND VR PLUG WHEN WEATHER BREAKS. 3/20109 Move rig from 2N-305A to 2N-318A 3/21/09 Completre rig move (Moved 196' From 2n-305A to 2N-318A} Rig accepted @ 09:00 hrs. Lubricate BPV out, (460 psi on tubing 250 psi on annulus)Displace well to seawater. 3122/09 Complete displacement to seawater. Shut in and monitor pressures. rig up and circulate thru choke to poorboy degasser. Shut in monitor pressures. Pick up and rack back 4" drillpipe while waiting on mud. Service rig. displace from seawater to 9.3 ppg mud. Shut in monitor pressures. Weight up to 9.6 ppg. 3!23109 Shut in well, Record pressures. Circulate 9.8 ppg mud around. bleed back and shut in well. Repeat shut in and bleed back steps. Circulate @ 9.9 ppg. Perform Exhale test. Set BPV, N/D tree, Nipple up BOP's, Change top rams to 3-1/2" X 6" Variables. 3124/09 Continue to nipple up BOP stack, PJSM- rig up to test, pickup 3-/2" test joint and FMC test plug, fil! stack, body test to 250 psi and 3500 psi-OK. Witness of test waived by AOGCC inspector John Crisp. Test BOP stack: Test to 250 psi low and 3500 psi high with a 3-1/2" test joint. Test annular- good. No test on upper and lower pipe rams (Both are 3-112" x 6" variables rams}. Test to 250 psi low and 3500 psi high with 3-1/2" test joint and annular the valves #1,4,5,6,7,9,10,11,12,13,14,15,16,17 and 18 in the choke manifold, 4" Demco on the kill line, XT39 dart valve and floor safety valve, 3-1/2" dart and floor safety valve, top drive upper and lower !BOP, choke HCR, manual kill and kill HCR valve. Test to 250 psi low and 3500 psi high with 4" test joint: upper and lower pipe rams, annular, choke manifold valves #2,3,8. Test to 250 psi low and 3500 psi high with 5-1/2" test joint: Annular-good test, no test on upper and lower pipe rams (3-1/2" x 6" variables), test blind rams- good test. With the 3-1/2" test joint test the lower pipe rams- again no test. Lay sown the test joint blow down kill and choke lines, suck out the water in the stack. Open both upper and lower rams- change packers and top seals on the rams (3-1/2" x 6" variables). Rig up to test, fill stack, attempt to test upper rams with a 3-1/2" test joint- no test. 2N-318 Pre Rig Summary ~~~~ la a 3/25/09 Fill stack. Attempt to test upper rams (3-1/2" x 6" variables) with a 3-1l2" #est joint. Tes#ing against manual choke and kill line valves. No test. Test lower rams w/ 3-1/2" test joint-Good test. Inspect upper ram cavity, wear plate and ram seals- looks good. Test upper pipe rams with a 3-1/2" test joint against manual choke and kill line valves- no test. Test upper rams to choke manifold valves 2,3,5,8,9 and manual kill line valve- good test. Perform Koomey test. Change out the test joint to 4". Test upper rams against valves 2,3,5 and 8 of the choke manifold and manual kill line valve -good test. Tested lower pipe rams with 4" test joint- good test. Test upper pipe rams with a 5-1/2" test joint against HCR valve on the choke line side and manual kill line valve- good test. Tested lower pipe rams w/ 5-1/2" test joint- good test. Attempt again to test and verify manual kill valve leaking with 5-1/2" test joint- no test- valve leaking. Replace gate and upstream seat on manual choke valve. Inspect valve cavity- OK. Fill stack with water, install 5-1/2" test joint, test annular against manual chake valve and manual kill valve- good test. Tested gas alarms 3/24/2009. Remove test joint, remove blanking plug and running tool. Pull the 3-1/2" back pressure valve. RU up to pull 3-1/2" 9.3 ppf EUE-mod L-80 tubing. PJSM for pulling tubing. Screw into FMC tubing hanger, back out lockdown screws. Work string free. Working string from planned PU wt of 149k. Work up to 180k, then started moving with 192k on weight indicator (Pulling seals free), with seals out: PU weight indicator of 162k, blocks 72k. Pull hanger to the rig floor, remove hanger w/ pup jt. Monitor well on trip tank-OK. Circulate 185 bbls @ initial 82 gpm w/ 960 psi, final 88 gpm w/ 920 psi, lost 40.5 bbls. Max gas observed by EPOCH was 162 units. Monitor well- breathing slightly, POOH standing back 36 stands of tubing, SLM, lay down completion tubing to depth of 6077' @ midnight. {193 jts in the hole) 3!26/09 Continue to POOH laying down 3-1/2" 9.3 ppf L-80 EUE-mod tubing, SLM from 6077' (193 jts in the hole} to 1833', monitor well, circulate to even out mud wt, continue to lay down 3-1 /2" completion, clear floor, make up 5-1/2" scraper, RIH to 3396', monitor well, POOH, UD scraper, MU Baker "K 1 Mechanical cement retainer, trip in to set @ 3204', set retainer, pickup 2', attmept to test- aired up mud, circulate 140 degree water to warm up 7-5/" x 5-1/2" annulus, test retainer with water- lost 40 psi in 5 min, blow down lines, pull out of the hole with Baker running tool, lay down running tool, clear floor, bring fishing tools to the floor, rig up to pull FMC 5-112" packoff, pressure to 500 psi on top of packoff, back out lockdown screws. Note: Packoff came up 21"when lockdown screws were backed out. Note: Cut 5-1/2" casing @ 2810' MD (Doyon 15 RKB). 3/27/09 Continue to back out lockdown screws (Set down 20k of top drive weight & 500 psi w/ annular shut}, pull FMC packoff to the floor, lay down tools, RU Schlumberger WL, RIH w/jet cutter toolstring to 2940', tie in to collars, jet cut the 5-1/2" 15.5 ppf L-80 LTC-mod casing @ 2810' RKB Doyon 15 (8' below box of jt # 66 in the hole- original jt #209 in the hole), POOH w/wireline, rig down wireline equipment, MU Baker spear assembly, change grapple f/ 4.961" to 4.805", remove damaged packoff, engage fish (5-112" casing), work pipe to maximum 270k on weght indicator, work hanger to floor, release Baker spear, lay down spear to pipe shed, RU casing handling tools (350 ton), continue to work casing up hole to 2753', rig up single joint elevators under the 350 ton elevators, PJSM, continue to work out to 2175' trying to circulate every 5 jts pulled, rig down 350 ton tools, RU 75 ton YT elevators, RU and finally circulated @ 2175', circulated 270 bbls, monitor well on trip tank, monitor visually, rig down circulating equipment, continue to POOH w/ 5-1/2" 15.5 ppf L-80 LTC casing to 855' at midnight. Note: Packoff came up 21"when lockdown screws were backed out. Note: Cut 5-1/2" casing @ 2810' MD (Doyon 15 RKB). 3!28/09 Continue to POOH w/ 5-1/2" 15.5 ppf L-80 LTC casing f/ 855' to surface, lay down 8" cut off joint, R/D casing equip, install FMC wear bushing, L/D spear, clear ftoor, pickup tools f/ cleanout run, move 36 stands of 3-1/2" tubing to driller's side of derrick, PU/MU cleanout BHA, single in hole w/ 4" drill pipe to 2353', trip in f/ derrick to 2603', circulate, continue in to 2751' (bridge and light packing off), displace to 9.0 ppg mud, wash in to 2810', circulate, pump a 20 bbls high vis sweep (9.0 ppg/600+ vis), monitor well-s tatic, backream out to 2613`, pull to 2600'. Pump a 20 bbls high vis sweep (9.1 ppg/294 vis), wiper trip to 2810' and back to 2259', pump a 20 bbl dry job (10 ppg), blow down lines, POOH to 560', service rig, continue POOH to 466', monitor well, L/D BHA, rig up to PU/MU 2-7/8" stinger for cement plug/Kick off plug. PJSM on same, continue to rig up. Pickup/Make up 30 joints of 2-7/8" 6.4 ppf L-80 hydril 511 tubing, crossover to 3-1/2" 9.3 ppf L80 EUE-mod then a 10' pup joint. change equipment to handle 3-1/2", run stands out of derrick, tag retainer inside of the 2N-318 Pre Rig Summary ~Z S~v ~~ 7 5-1/2" @ 3204', lay down a single, rig up circulating equipment, Establish circulation. Pumping 53 spm (4.5 bpm) w/ 440 psi-42°lo flow out. Then line up to circulate thru choke manifold to hold resistance against pump operation and be able to keep fluids togetherwhen shutting down. Close annular, open to choke manifold and poor boy degasser. Stage rate from 3 bpm (36 spm) w/ 320 psi to 4.5 bpm (53 spm) and 430 psi. Held PJSM on cement job while circulating. Pumped a total of 186 bbls. Dowell pump 3.1 bbls mud push (13 ppg) @ 1.3 bpm w/ 270 psi, shut down, test lines to 4000 psi, continue to pump 13 ppg mud push @ 3 bpm w/ 230 psi for a total of 27.2 bbls, shut down/ shut choke wj 180 psi on choke, mix cement @ 17 ppg, open choke and start pumping cement at midnight. 3/29109 Dowell pumped 35.9 bbls of 17 ppg cement (yield 1 cuft/sx-Mix water 3.92 gallsx) at 3 bpm w/ 315 to 338 psi, shut down/ shut choke w/ 450 psi on choke, mix and pump 7 bbls mud push (13 ppg) @ 2.3 bpm w/ 223 psi, shut down/ shut choke w/ 280 psi on choke, open choke and displace with rig 9 bbls of 9 ppg mud, shut down- open choke. Open Annular. Rig down cement hose. CIP @ 0030 hrs 3/2912009. POOH, UD 2 jts, pull 8 stands, PU single- make up circ hose- run in hole to 2410'. Circ at 4 bpm w/ 440 psi-39% flow out. Observed mud push at shakers at calculated strokes of 603 (51 bbls) and started dumping mud to rockwasher, continued to pump! dump mud push to rockwasher. Maximum weight observed at the shakers was 11.5 ppg. Quit dumping mud after 1850 strokes (156.5 bbls). Continue to circulate at 8 bpm (94 spm) w/ 570 psi-47% flow out. Monitor well. Pump 20 bbl dry job (11 ppg). Blow down cementing line. Rig down circ equipment. Rig up GBR tongs to pull and lay down tubing. Pull out of the hole, laying down the 3-112" 9.3 ppf L-80 EUE 8rd-mod tubing from 2410' to 900'. Trip in with 15 stands tubing from the derrick to 2297'. POOH L/D 5 stands of tubing. RIH with 4 stands of tubing to 2204'. POOH UD 14 stands of tubing. Lay down 10' pup jt and crossover to 2-7/8" Hydril 511. Change handling tools to 2-7/8". POOH UD 10 stands of 2-7/8" 6.4 ppf L-80 Hyd 511 tubing and mule shoe. R/D GBR tubing handling equipment. Rig up to PU/MU BHA # 6 (Verify top of cement). PJSM for MU BHA. MU BHA #6 {Verify top of cement). RIH w/ BHA #6 on 4" dp. Make a connection, fill pipe, wash down f/ 2348', pumping 11 spm (39 gpm} w/ 120 psi-12% flow out. Set down 10k, TOC @ 2434'. PU and circ, pumping 3 bpm w/ 210 psi-34% flow out. Pumped a total of 4532 strokes (383 bbls). Stand back a stand. Blow down. RU then test 7-518" 29.7 ppf L-80 BTC-m casing to 1800 psi f! 30 minutes (TOC 2434'), chart test. RD tes#ing equipment. Slip and cut 119' drill line, service rig, POOH to 2155'. 3!30/09 POOH f/ 2155' ,lay dawn BHA, clear floor, PU 6-3/4" Sperry Sun GeoPilot BHA w/ 7=1/2" Smith Rhino Reamer, shallow pulse test @ 653', trip in hole to 2348', obtain SPR's and parameters, drill cement f/ 2434' to KOP @ 2692' (2372' TVD) (shoe of 7-5/8" @ 2610' MD (2317.8' TVD)}, continue to drill to 2727' (2395' TVD), circulate, perform LOT to 14.8 ppg with 9.0 ppg mud, pertorm PWD baseline, drop 1-1/8" ball to activate Smith Rhino Reamer, drill 6-3/4" hole w/geopilot (7-1/2" Rhino Reamer back 99' from bit) from 2727' to 2861', problems with azimuth/MWD (possible interterence with old wellbore)- Sperry talk with town Continue #o drill 6-3/4" hole w/geopilot (7-112" Rhino Reamer back 99' #rom bit) from 2861' to 3010', blow down top drive, monitor well on the trip tank- static, trouble shoot pit gain/PVT system. Note" Determined that water was getting into pits from rig water pump. 3/31/09 Monitor well- static. Trouble shoot pit gain/PVT system, determined that water was getting into pits from rig water pump, continue to directional drill 6-3/4" hole {Sperry Sun Geopilot-opening up hole to 7-1/2" with Smith Rhino Reamer 99' behind bit) from 3010' to 3346' (2786' TVD), Circulate 15 bbl nut plug sweep, monitor well- static, pump a dry job, POOH f/ 3346' due to unable to achieve build rates with GeoPilot assembly, download MWD, replace Sperry DM tool, L/D Smith Rhino Reamer, upload MWD, shallow test MWD, service rig, PU1MU BHA #7 (6-3/4" bit, Rhino Reamer & Motor), trip in to 3180' make a connection, ream out the 6-3/4" hole (3247' to 3346'), Start reaming @ 3200' to 3346'- enlarging hole to 7-1/2", directional drill w/ 1.5 deg bend motor from 3346' to 3500'. a ~=~~~~ ~i-~aa 2N-318 Pre Rig Summary DATE SUMMARY 2/21/09 ULLED CA-2 PLUG BODY @ 595' RKB. DRIFTED TBG AND SAT DO~AT 10,650' S WORK THRU TO 10,688' SLM. UNABLE TO GET ANY DEEPER (APPEARS TO BE PU ING SOMETHING DOWNHOLE -POSS. SAND) WILL RETURN AT A LATER DATE 2/22/09 OUBLESHOOT. C T STANDING VALVE AT 10 595' RKB PT TUBING TO 2500 PSI HELD SOLID FOf N ES, TAG AND OBTAINED SAMPLE OF FILL FROM TUBING AT 10,714' SLM. IN 2/24/09 RAN A STA IC PRESS. TEMP SURVEY. 10710': 3115.5 PSI, 131.3 DEGF, 10410': 3085 PSI, 130.1 D F. SETA 3.5" CEMENT RETAINER MID ELEMENT 10630'. PT RETAINER TO 2500 PSI, FAILED, LOST 700 PSI IN 9 MIN. 2/27/09 TAGGED @ 105 'SLM WITH 2.73" LIB; INCONCLUSIVE. IN PROGRESS. 3/2/09 RAN 2.62" LIB TO EMENT RETAINER @ 10633' SLM. REC. PICTURE OF RING ON LIB. READY FOR CTU. 3/6/09 PERFORMED CEME P&A THROUGH EZSV RETAINER @ 10633 CTMD. PUMPED 2.3 2 BB RETAINER, REVERSED UT WITH BIOZAN PILL TO 10550 CTMD. SWAPPED WELL TO DIESEL, LEFT 500 PSI O UBING, READY FOR S/L. 3/8/09 GAUGED TBG WITH 2.70" G/ ON 2-1/8" x 15' STEM TO TAG @ 10528' WLM. MIT TBG 1500 PSI, 30 MIN, GOOD TEST. READY FOR E/L. 3/8/09 POWER JET CUT 3.5" TUBING A 10368.3'. UNABLE TO REACH CMU WITH JET TO SET 30 MI CUTTER. TAGGED AT 10502'. C CUT AT 10368'. VAVLE CREW TO SULT WITH DRILLING ENGINEER AND DECIDE TO ~T BPV AND VR PLUG WHEN WEATHER BREAKS. 3/20/09 Move rig from 2N-305A to 2N-318A 3/21/09 Completre rig move (Moved 196' From 2n- 05A to 2N-318A~Rig accepted @ 09:00 hrs. Lubricate BPV out, (460 psi on tubin 250 ~ on annulus Displace well to seawater. 3/22/09 Complete displacement to seawater. Shut in a d monitor pressures. rig up and circulate thru choke to poorboy degasser. Shut in monitor pre ures. Pick up and rack back 4" drillpipe while waiting on mud. Service rig. displace from s awater to 9.3 ppg mud. Shut in monitor pressures. Weight up to 9.6 ppg. 3/23/09 Shut in well, Record pressures. Circulate 9.8 ppg mu around. bleed back and shut in well. Repeat shut in and bleed back steps. Circulate @ 9.9 g. Perform Exhale test. Set BPV, N/D tree Ni le u BOP's Chan a to rams to 3-1/2" X "Variables. 3/24/09 Continue to nipple up BOP stack, PJSM- rig up to test, pic up 3-/2" test joint and FMC test plug, fill stack, body test to 250 psi and 3500 psi-OK. Witne of test waived by AOGCC inspector John Crisp. Test BOP stack: Test to 250 psi low an 3500 psi high with a 3-1/2" test joint. Test annular- good. No test on upper and lower pipe rams Both are 3-1/2" x 6" variables rams). Test to 250 psi low and 3500 psi high with 3-1/2 test joint and annular the valves #1,4,5,6,7,9,10,11,12,13,14,15,16,17 and 18 in the choke nifold, 4" Demco on the kill line, XT39 dart valve and floor safety valve, 3-1/2" dart and floor fety valve, top drive upper and lower IBOP, choke HCR, manual kill and kill HCR valve. Te t to 250 psi low and 3500 psi high with 4" test joint: upper and lower pipe rams, annular, cho a manifold valves #2,3,8. Test to 250 psi low and 3500 psi high with 5-1/2" test joint: Annula good test, no test on upper and lower pipe rams (3-1/2" x 6" variables), test blind rams- good st. With the 3- 1/2" test joint test the lower pipe rams- again no test. Lay down the test joint low down kill 3/25/09 Fill stack. Attempt to test upper rams (3-1/2" x 6" variables) with a 3-1/2" testj ~ t. Testing against manual choke and kill line valves. No test. Test lower rams w/ 3-1/2" tes ~oint-Good test. Inspect upper ram cavity, wear plate and ram seals- looks good. Test upper ~ e rams with a 3-1/2" test joint against manual choke and kill line valves- no test. Test upper ams to choke manifold valves 2,3,5,8,9 and manual kill line valve- good test. Perform Koome test. Change. out the test joint to 4". Test upper rams against valves 2,3,5 and 8 of the choke manifold and manual kill line valve -good test. Tested lower pipe rams with 4" test joint- od test. Test upper pipe rams with a 5-1/2" test joint against HCR valve on the choke line side and manual kill line valve- good test. Tested lower pipe rams w/ 5-1/2" test joint- good test. Attempt again to test and verify manual kill valve leaking with 5-1/2" test joint- no test-valve leaking. Replace gate and upstream seat on manual choke valve. Inspect valve cavity- OK. Fill stack with water, install 5-1/2" test joint, test annular against manual choke valve and mangy l i #3.f rr ~~} 2N-318 Pre Rig Summary 3/26/09 ontinue to POOH laying dow /2" 9.3 ppf L-80 EUE-mod tubing, SLM fr~6077' (193 jts in a hole) to 1833', monitor we ,circulate to even out mud wt, continue to down 3-1/2" com tetion, clear floor, make up 5-1/2" scraper, RIH to 3396', monitor well, POOH, UD scrap , MU Baker "K 1 Mechanical cement retainer, trip in to set @ 3204', set retainer, pickup attmept to test- aired up mud, circulate 140 degree water to warm up 7-5/" x 5-1/2" annulus, st retainer with water- lost 40 psi in 5 min, blow down lines, pull out of the hole with Baker runni tool, lay down running tool, clear floor, bring fishing tools to the floor, rig up to pull FMC 5-1 "packoff, pressure to 500 psi on top of packoff, back out lockdown screws. Note: Packo ame up 21"when lockdown screws were backed out. Note: Cut 5-1/2" 2810' N1wD (Dovon 15 RKB). 3/27/09 Continue to back out`4pckdown screws (Set down 20k of top drive weight & 500 psi w/ annular shut), pull FMC Packo o the floor, lay down tools, RU Schlumberger WL, RIH w/ jet cutter toolstring to 2940', tie in collars,1et cut the 5-1/2" 15.5 ppf L-80 LTC-mod casing @ 2810' RKB Do on 15 8' below b of ~t # 66 in the hole- on final 't #209 in the hole), POOH w/ wireline, rig down wireline a ipment, MU Baker spear assembly, change grapple f/ 4.961" to 4.805", remove damaged pac ff, engage fish (5-1/2" casing), work pipe to maximum 270k on weght indicator, work han er floor, release Baker spear, lay down spear to pipe shed, RU casing handling tools (350 ton continue to work casing up hole to 2753', rig up single joint elevators under the 350 ton ele tors, PJSM, continue to work out to 2175' trying to circulate every 5 Its pulled, rig down 3 ton tools, RU 75 ton YT elevators, RU and f finally - circulated C~ 2175', circulated 270 bbls, onitor well on trip tank, monitor visually, rig down circulating equipment, continue to POOH / 5-1/2" 15.5 ppf L-80 LTC casing to 855' at " ' 3/27/09 JET CUT 5.5 CASING AT 2810 IN PREPA ATION FOR SIDETRACK. 3/28/09 Continue to POOH w/ 5-1/2" 15.5 ppf L-80 L casing f/ 855' to surface, lay down 8" cut off joint, R/D casing equip, install FMC wear bushi , UD spear, clear floor, pickup tools f/ cleanout run, move 36 stands of 3-1/2" tubing to filler's side of derrick, PU/MU cleanout BHA, single in hole w/ 4"drill pipe to 2353', trip in f/ errick to 2603', circulate, continue in to ~ 2751' (bridge and light packing off), displace to 9.0 p mud, wash in to 2810', circulate, ~~"` pump a 20 bbls high vis sweep (9.0 ppg/600+ vis), mo ~ or well-s tatic, backream out to ' ' ' ~ \ 2613 , pull to 2600 . Pump a 20 bbls high vis sweep (9.1 g/294 vis), wiper trip to 2810 and r ' back to 2259', pump a 20 bbl dry job (10 ppg), blow down I es, POOH to 560', service rig; continue POOH to 466', monitor well, L/D BHA, rig up to PU U 2-7/8" stinger for cement plug/Kick off plug. PJSM on same, continue to rig up. Pickup/ ke up 30 ~oints of 2-7/8" 6.4 ppf L-80 hydril 511 tubing, crossover to 3-1/2" 9.3 ppf L80 EUE- od then a 10' pup joint. change ewuipment to handle 3-1/2", run stands out of derrick, tag tainer inside of the 5-1/2" 3/29/09 Dowell um ed 35.9 bbls of 17 p g cement (yield 1 cuft/sx- Mix wat 3.92 gal/sx) at 3 bpm w/ 315 to 338 psi, shut down/ shut choke w/ 450 psi on choke, mix an ump 7 bbls mu push (13 ppg) @ 2.3 bpm w/ 223 psi, shut down/ shut choke w/ 280 psi n choke, open choke and displace with rig 9 bbls of 9 ppg mud, shut down- open choke. pen Annular. Rig down cement hose. CIP @ 0030 hrs 3/29/2009. POOH, L/D 2 jts, pull 8 sta s, PU single- make up circ hose- run in hole to 2410'. Circ at 4 bpm w/ 440 psi-39% flow o .Observed mud push at shakers at calculated strokes of 603 (51 bbls) and started dumpin mud to rockwasher, continued to pump/ dump mud push to rockwasher. Maximum weigh observed at the shakers was 11.5 ppg. Quit dumping mud after 1850 strokes (156.5 bbls). C tinue to circulate at 8 bpm (94 spm) w/ 570 psi-47% flow out. Monitor well. Pump 20 bbl dry jo (11 ppg). Blow down cementing line. Rig down circ equipment. Rig up GBR tongs to pull an lay ~ down tubing. Pull out of the hole, laying down the 3-/12" 9.3 ppf L-80 EUE 8rd-mod tubin from 2410' to 900'. Tri in with 15 stands tubin from the derrick to 2297'. POOH UD 5 st d 3/30/09 POOH f/ 2155' ,lay down BHA, clear floor, PU 6-3/4" Sperry Sun GeoPilot BHA w/ 7-1/2" Smith Rhino Reamer, shallow pulse test @ 653', trip in hole to 2348', obtain SPR's and parameters, drill cement f/ 2434' to KOP @ 2692' (2372' TVD) (shoe of 7-5/8" @ 2610' MD_ (2317.8' TVD)), continue to drill to 2727' (2395' TVD), circulate, perform LOT to 14.8 ppg with, 9.0 ppg mud, perform PWD baseline, drop 1-1/8" ball to activate Smith Rhino Reamer, drill 6- 3/4" hole w/ geopilot (7-1/2" Rhino Reamer back 99' from bit) from 2727' to 2861', problems with azimuth/MWD (possible interference with old wellbore)- Sperry talk with town. Continue to drill 6-3/4" hole w/ geopilot (7-1/2" Rhino Reamer back 99' from bit) from 2861' to 3010', ~ ~l \~ blow down top drive, monitor well on the trip tank- static, trouble shoot pit gain/PVT system. . _ Note" Determined that water was getting into pits from rig water pump. a ~ as 2N-318 Pre Rig Summary 3/31/09 nitor well- static. Trouble shl~it gain/PVT system, determined that wat~as getting int its from rig water pump, co mue to directional drill 6-3/4" hole (Sperry Geopilot- open g up hole to 7-1/2" with Smith Rhino Reamer 99' behind bit) from 3010' to 3346' (2786' TVD), ~rculate 15 bbl nut plug sweep, monitor well- static, pump a dry job, POOH f/ 3346' due to un ble to achieve build rates with GeoPilot assembly, download MWD, replace Sperry DM tool, L/ Smith Rhino Reamer, upload MWD, shallow test MWD, service rig, PU/MU BHA #7 (6-3/4" bit, hino Reamer & Motor), trip in to 3180' make a connection, ream out the 6- 3/4" hole (3247 0 3346'), Start reaming @ 3200' to 3346'- enlarging hole to 7-1/2", directional drill w/ .5 deg bend motor from 3346' to 3500'. '.i.! ~~°~ '^~ ~. NO. 5125 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 :~ ~~ ~/j,L~~ '~, "'` ~~~, Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ..~~ 1. Well Job # Log Description Date BL Color CD 03/03/09 3H-33 604C-00006 USIT _ - 02/09/09 1 1 1 D-130 ANHY-00049 INJECTION PROFILE ~) : ct'~ - 02/12/09 1 1 2A-26 ANHY-00053 PERF/SBHP SURVEY ~ _ C t~ ~ 02/16/09 1 1 3H-33 AYS4-00039 SFRT 02/23/09 1 1 3C-06 B14B-00005 GLS ~! ~ 02/23/09 1 1 2N-318 B14B-00006 SBHP SURVEY _ / 02/24/09 1 1 3H-33 B04C-00006 SONIC SCANNER - ~' 02/09/09 1 1 3J-06 6148-00008 PRODUCTION PROFILE 02/27/09 1 1 1 D-119 AYS4-00044 INJECTION PROFILE ~ ' ~'} - _ ~ ~ 02/28/09 1 1 3G-03 AYS4-00043 PRODUCTION PROFILE - ~' - - 02/27/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317: Thank you. J • ALASSA OIL A1~TD GA,S COI~TSERQATIOI~T CO1~II-IISSIOI~T SARAN PALIN, GOVERNOR 333 W. 7th AVENUE, StJlTE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 `~``"~~~ ~F(3 ~ ~~ ~~~ ~~~_ ((~ Re: Kuparuk River Field, Tarn Oil Pool, 2N-318 Sundry Number: 309-047 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ /~~ Cathy . Foerster Commissioner 1`L`- DATED this ~3 day of February, 2009 Encl. ~ 0~ ~~\~ N • STATE OF ALASKA ~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION FED U ~ ~~~g APPLICATION FOR SUNDRY APpRR--nn~v ~l~ 3 Rfd~(Uil~~a~ ~,osl~, ~ol'nmission 20 AAC 25.280 1. Type of Request: Abandon Q Suspend ^ Operational Shutdown ^ Perforate ^ fiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 200-100 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20343-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 2N-318 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380054, 375074 RKB 35' Kuparuk River Field / Tarn Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11456' 5243' 11351' 5211' 10595' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16" 114' 114' SURFACE 2568' 7-5/8" 2603' 2311' PRODUCTION 10555' 5-1/2" 10590' 4882' PRODUCTION 857' 3-1/2" 11447' 5241' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10952'-10967' 5087'-5093' 3-1 /2" L-80 10605' Packers and SSSV Type: Packers and SSSV MD (ft) Baker CSR assy @ 10580' Camco 'DS' nipple @ 518' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Plugged and Abandoned Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat February 20, 2009 Oil ^ Gas ^ Plugged ^~ Abandoned ^~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer Signature ~ ~ ~-- Phone 265-6471 Date 2. "' ,5'^'Q Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -~» Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ `~'~.jYJ~~,~ ~/~ v a"t C~ ~~ @ "~ ~S ~~ Other: 3 v" 'im " ~~~ ` ~ v sW ixs ~ r.., Subsequent Form Required: "td~ f~ APPROVED BY ~ ~/z ~~ Approved by: COMMISSIONER THE COMMISSION Date: J I~ Form 10-403 Rev' ed 06/2006 f' ' ` I ' ' F Submit in Du licate 2/~,?lam' ConocoPhillips ! ~~ ~ :,,•~, I~,;. ... _ etLCo fis 2N-316, a <<- _ ___- Sdxxna:ic A v ~: KUP ~ 2N-318 Well Attributes WellboreAPVUWI Fieltl Name -- Well Status Prod/Inj Well Type Intl (°) MD(kK8) 'TD (max)(H 501032034300 (TARN PARTICIPATING AREA .PROD I I 76.78 6,39564 11456.0 Comment H2S (ppm) Date Annotation End Data KB-Grd (H) Rig Release Date SSSV. NIPPLE _ 30 i I 7/1/2008 Last WO: 40.19 9!12000 Annotation 'iDepth (HKB) End Date Annotation Entl Date Last Tag' ~ 10,6460 10/7/2006 Rev Reason RESET CA-2 PLUG _ 1 1 /8120 08 Casin Strin s String OD ' String ID Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top (kK81 (ftKB) (HKB) (Ibs/H) Gratla_ String TOp Thrt CONDUCTOR 16! 15.062 0.0 1180 118.0 62.50 H-40 WELDED URFA E 6,750 I 0 0 2 603.0 2,311.3 29.70 L~0 BTCM - PRODUCTION 512! 4.950 00 10,580.0 4,979.0 15.50 L-80 LTC-MOO PRODUCTION 31/2 2.992 __ _ 10,580.0 114470 5,240.6 9.30 L-80 {iBRD EUE I _. Tubing_Strings String OD String ID __ Set Depth Set Depth (ND) ii String Wt __ String Tubing Description (In) (In) Top (HKB) (ftKB) (HKB) ~~, (Ibslft) Grade Siring Top Thrt ~ TUBING 31/2 2992 0.0 10,605.0 'BRD EUE 4986.2''. 9.30 i, L-80 i_ Other In Hole All Jewel : Tubin Run 8 Retrievable Fish etc. Top Depth ~ ', (TVD) Top ~ Top (ftKB) (ftKB) Intl (°) Description Comment _ Run Oate ID (i~ 518.0 517.5 6.14 NIPPLE Camco DS' Nipple 9/1/2000 2 8; 2,364.0 2,139 8 42.17 GAS LIFT CAMCO/KBG 2-9/1/DMY/DCKI/! Comment STA 1 9/1/2000 2.9( 5,656.0 3,466.1 69.27 GAS LIFT CAMCO/KBG 2-9/1/DMY/DCK/// Comment: STA 2 9/1/2000 2.9( 8,504.0 4,348 8 70.28 GAS LIFT CAMCO/KBG 2-9/1/DMY/BTM/// Comment: STA 3 1027/2001 2.9( 10,512.0 4,959 7 73.60 SLEEVE-C Baker CMU Sliding Sleeve, w/2.813" Camco profle; CLOSED 9!1/2000 2.81 4/27/2006 10,553.0 4,971.2 73.39 GAS LIFT CAMCO/KBG 2-9l1/DMY/DCK/// Comment: STA4 9/1/2000 2.9( 10,580.0 4 979 0 7325 CSR Baker CSR Assy, Size 80-00, 5.5" x 4" 9/1/2000 4.0( 10,595.0 4,983.31 73.18 NIPPLE ~ iCamco'D' Nipple, w/No-Go profle 9/1/2000 2JE 10,595.0 4,983.3; 73.18 PLUG 12.75" CA-2 PLUG 7/10/2008 0.0( 10.604.0 4.985.9 73.13 SEAL Baker 80-00 Ga51n0 Seal Assembly. 4" od z 2.985" id ~9l1/2000 2.9F 'op (HKB) Bim (ftKB)', (HKB) (ftKB) Z e Date Is"-~ Type 10,952.0 iQ,967.0 '~ 5,087J _ 5,092.6 9/6/2000 4.0 IPERF 2.E stimulations Sr Treatme nts Bomm~ ..._ i _ Min Top Max Btrn TOp Depth Depth Depth Depth (ND) (TVD) '~ (HKB) (kKB) (RKB) 1HK61 Tvoe I Date 5!1/2006 FOUND IA-FORMATION CB nowr ELMD- Comment ph 2N-318P&A Sundry Request 2-6-09 PTD# 200-100 The purpose of the 2N-318 sidetrack is to move the bottom hole location towards a thicker reservoir section with the intent of achieving higher oil rates and recovering additional resources from potentially un-swept regions of the reservoir. 2N-318 has also been shut-in since March 2006 with a 5.5" casing x formation leak at 5183' RKB. The 2N-318A sidetrack is planned as an MWAG supported fracture stimulated producer. This sidetrack will be drilled approximately 600 feet south of the original 2N-318 bottom hole location. ,~ CUB Cvr w~'r~ ~~AjO~ fOt^ Procedure Outline G bQ~o%~r-f % y~ ~ r<<Sr. ~ eve(/ ~o~e. ~ /~ ~l~/09 1. Pre-cement squeeze prep work: 1. Mobilize DHD crew to test tubing and casing packoffs /cycle LDS's. 2. PT tubing to 2500 psi (last MIT-T was 10-24-06). Bleed IA to zero. 3. Pull the 2.75" CA-2 blanking plug set at 10595' RKB. 4. Use pump truck and establish injection (with diesel) into the open perfs at 1-2 bpm. Record pressures vs. rate. The CMU is closed. Well has 5.5"Csg leak at 5183' RKB (reported to AOGCC 5-2-06). 2. EZSV Setting procedure using E-line (or by using CT due to high hole angle) 1. Run Halliburton EZSV 3.5" cement retainer. Set depth for EZSV will be +/- 10700' RKB. Set the EZSV in a mid joint (per CCL). 3. Cement Squeeze Procedure: 1. RU CTU. Notify AOGCC Inspector of date and time of operation. (659-2714 or pager 659-3607). 2. Run hardline from tubing connection to an open-top with an inline choke skid. 3. Rig up CTU and cement unit: Pressure test coil, BOP's and hardline to 3500 psi. 4. RIH with CTU with EZSV retainer stinger assembly (use two `star centralizers' to ensure coil has straight shot at the ID of the retainer) , stab into EZSV at +/- 10700' RKB; shift sliding valve open by moving valve downward. Pump slick seawater at approx. 1-2 bpm to establish injection rate and pressure. 5. Pump cement into formation until target squeeze pressure of 1000 psi is reached. Tota13.5" production liner volume below the retainer is approximately 6.5 bbls. Attempt to squeeze away at least 7.5 bbls of cement into the formation, if possible. 6. Pull out of retainer, open CT x tubing annulus and lay in cement to +/- 10650' RKB taking 1-1 returns. Swap to biozan and jet out cement while POOH. Freeze protect the last 2500' with diesel. 7. Wait 24 hrs for cement to set. Rig up SL to drift for jet cutter. Drift tubing to PBTD (TOC) with 2.73" gauge. Pressure test cement plug to 1500 psi on the tubing; hold for 30 min. Record results. (Notify AOGCC of the timing of the post cement plug tag and PT). s. Perform Drawdown test by bleeding any tubing, IA and OA pressure to open-top tank. Tubing and IA should bleed to 0 psi. RIH and pull DV from GLM at 8504'RKB. 9. Rig up E-line and jet cut 3.5" tubing at +/- 10500' RKB at the nearest mid joint. POOH with E-line, verify the cutter operated properly and rig down E-line unit. (Chemical cutter not needed for this operation) 10. Set BPV and VR plug. Pull well house and prep site for rig. Notify Wells group of well status. 4. Drilling Rig P & A Component 11. MIRU Doyon 15. Pull BPV and VR plug. Circulate brine around tubing and IA through tree. Ensure well is dead. 12. Set Blanking plug and BPV, ND tree, NU BOP's and test. Pull BPV blanking plug and pull tubing hanger to floor. Pull remaining tubing out of well and lay down same. 13. RU E-line. RIH with 5.5" CIBP and set at approx. 3200' RKB. 14. RIH with 5.5" Jet Cutter and cut the casing at approx. 2800' RKB. RD E-line. 15. Pu115.5" casing and lay down same. 16. PU openhole whipstock with sidetrack mill and RIH to land out on casing stub. Orient and set whipstock. Shear out and commence sidetrack of well. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, AI~4SKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ °~ %~a ~~~ NOl~ ~ ~ 200 Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ~. w~~ on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9!16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n!a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" nla 5" n/a 9.5 9/27!2007 • • ConocoPhi~lips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 ~ NG`1 ~ ~ 2007 Anchorage, AK 99501 ~~.~~~~~ Dear Mr. Maunder: RF~~ oeT ~VF4 A/e~k~ DiJ~ ~a ~ 2 ?Opp s gn~ha a~'e C~issi on ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KR~. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ;~ ~~ ~- M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • ConocoPhiilips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Weil Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-103 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2t_-309 205-210 13' 3" 2 18" 9!9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16!2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n!a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" nia 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 208-179 12" n/a 12" n/a 10 9/27/2007 2N-313 19&091 5" n/a 5" n/a 2 9/27!2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n!a 6" n/a 3 9/27/2007 2N-317 19&143 5" n/a 5" n!a 1 9!27!2007 2N-318 200-100 10" n/a 10" n/a 1 9!27/2007 2N-319 198-197 5" n!a 5" n/a 9.5 9/27/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 5GANNEDJAN 1 9 2007 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTr) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 1 BL / EDE Disk 2N - 318 Leak Detect - WLD 07-Nov-G6 2) 3) 4) 5) aCD -L 00 6) {i;~ 7) (J.lt 1L{:i7-{ Signed: Date: l/iff/Dr- !!krì.s.fhu:) !hf),¡Ú a.- j¿ L)4/1 I r Print Name: . PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 D:\OO _ PDSANC·2006\Z.W ordlDisfribubon\ Transmittal_ Sheets\Transmit _ Original.doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and jar Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Roaq~.~~ ~ !Ñ\íM~::~) Suite C ,.}",~'t~" ',I .'- . Anchorage, AK 99518 Fax: (907) 245-8952 p (j' 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) 2N-318 Leak Detect - WLD 07 -Nov-06 Print Name: (j,dt- r:hd<;H lAp ¡}¡40 IAK¡?M Signed: Date : 860-l00 ii. 1¿,/~'7- (6el./~-+ 1oct.e.l C::D o\v<2..tb Lûrov~ WQL( :t\=: Ol/l L-Ä-S") (; ~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E...MAIL: PO:3;'\i\::CH();:t.'\~2{ÔW!EMO\::"'>fL:;G.:::;C;'J¡ WEBSITE : 1It¡'V\fl~i.}âE;\¡i()R.\{LOG,GCìM 0\00 _ PDSANC-2006\Z _ W ord\Distribution\Transrcittal_ Sheets\ Transrcit_ Ongjnaldoc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowfedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C . Anchorage. AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 2N - 318 Caliper Report 19 - Oct - 06 1) 2) 3) 4) 5) 6) 7) c - ¿!J:J~j Print Name: 0Jb ----- " ß~ r\,") }', VI. ~ Gn ö.1A1A kf VI ;)oÜ-IOO :t ¡L[8od Signed: Date : PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAil: ;o;:>';X"¡~:-:>"A3::::t;',;E'\:':¡;r,·',.d.¿:;:i\; WEBSITE : ·'I'PH',1UV'''':iL:;",'l',''..(}'3.::'¡X;] D::OO _ PDSANC-2006\Z _ WordIDistributionlTransrnittal. SbeetslTransrnit_ Onginal.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 19, 2006 8064 1 3.5" 9.3 lb. L-BO EUE 8rd Tubing Well: 2N-318 Field: Kuparuk state: Alaska API No.: 50-103-20343-00 Top Log IntvI1.: Surface Bot. Log Intvl1.: 10,453 Ft. (MD) Inspection Type: COffosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the GLM 3 @ 8,504' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing interval logged appears to be in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 56% in joint 330 (10,357'). Wall penetrations ranging 20% to 56% are recorded in 67 of the 341 joints logged. The deeper penetrations are recorded in the interval between -9,000' and 10,453', as illustrated in the Body Region Analysis Page of this report. The damage appears in the forms of isolated pitting, general corrosion, and lines of corrosion. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded in the 3.5" tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion ( 56%) Jt. 330 @ 10,357 Ft. (MD) Line Corrosion ( 54%) Jt. 321 @ 10,080 Ft. (MD) Corrosion ( 52%) Jt. 294 @ 9,239 Ft. (MD) Line Corrosion ( 52%) Jt. 303 @ 9,544 Ft. (MO) Corrosion ( 51%) Jt. 318 @ 10,015 Ft. (MO) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. Field Engineer: R. Richey Analyst: M. Tahtouh GOD -106 1t 1L.IQ6~ 13G9, Staff~;~~.:fùn,e~~;\:f~OCß E. -659-2314 . NO\J 0 'ð 'LOGD commìSSlon 0\\ &. GaS cons. ~ þ'~e I I I Well: Field: Company: Country: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Grade & Thread L-BO WE 8rd Weight 9.3 f I I Penetration and Metal Loss (% wall) penetration body metal loss body I 400 300 200 100 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10% I o o I pene. loss I Damage Configuration ( body ) 150 I 100 I 50 o I isolated general line ring hole / pass pitting corrosion corrosion corrosion ¡ble hole I o I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Norn.ID 2.992 ins October 19, 2006 MFC24UWNo.211387 1.69 24 M. T ahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) penetration body o o GLM2 GLM3 GLM 1 metal loss body 50 100 Bottom of Survey = 333 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 3.5 in (30.5' - 10449.3') GlM 1 150 '- ill GlM2 E :;¡ z 200 E 0 GlM 3 I Bottom of Survey = 333 I I Well: Field: Company: Country: Survey Date: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Approx. Tool Deviation Approx. Borehole Profile 250 50 100 300 333 o 50 Damage Profile (% wall) I Tool Deviation (degrees) 33 1575 3153 4712 0 ~ .,..; LL c 6291 ..c õ.. (j) 0 7850 9419 10449 100 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Joint Jt. Depth Pel Pen. ,Vle!ill Min. Damage Profile No. (Ft.) Body /.D. Comments (%wall) ì (Ins.) (Ins.) 0 50 100 .1 30 0 0.03 J 2 2.92 PUP ShalloW¡:¡ittiOg. I 1 33 0 0.03 J j 2.93 1.1 66 J) 0.03 1 i) 2.91 PUP 2 76 0.03 ~ ~'2 2.93 Shallow..pj tti OK 3 108 ( 0.03 12 5 2.93 4 139 ) 0.03 12 3 2.95 Shallow corrosion. 5 170 0.03 13 (: 2.93 Shallow pitting. 6 202 0.04 I ß 2.94 Shallow corrosion. 7 233 0 0.04 \ L (: 2.93 Shallow pitting. I 8 264 0 0.03 ¡ 4 2.93 Shallow corrosion. 9 295 0.03 I 2.94 Shallow corrosion. 10 326 0.03 13 2.93 Shallow corrosion. m 11 356 ( 0.03 \ .3 .' 2.89 Shallow corrosion. 12 388 ) 0.04 I 2.94 Shallow corrosion. 13 419 0 0.03 I t 2.95 Shallow corrosion. 14 450 0 0.04 1 L ¿ 2.93 Shallow corrosion. 15 482 0 0.03 J 3 2.94 Shallow pitting. 15.1 511 J! 0 0 0 2.88 DS NIPPLE 16 514 Jl 0.03 13 4 2.93 Shallow corrosion. 17 545 0 0.03 \3 2 2.93 Shallow corrosion. 18 575 0 0.04 16 3 2.93 Shallow corrosion. 19 606 0 0.03 1 1 2.96 20 638 C 0.04 1 '. 2.94 Shallow corrosion. / 21 669 0 0.04 I (, 2.93 Shallow pitting. 22 701 0 0.04 j( 2 2.95 Shallow pitting. 23 732 0 0.04 1) I" 2.93 Shallow corrosion. 24 764 J) 0.03 1 2.94 Shallow..Qittil]g. 25 795 0 0.04 14 2.94 Shallow corrosion. 26 827 0 0.04 h 2.94 Shallow corrosion. 27 857 0 0.04 1 2.93 Shallow pitting. 28 887 0 0.04 1 2.93 Shallow corrosion. 29 918 0 0.04 1 L 2 2.96 Shallow corrosion. 30 950 jJ 0.04 I __4 2.93 Shallow corrosion. 31 981 (1 0.03 J I" 2.94 Shallow pitting. 32 1013 U 0.03 13 2.94 Corrosion. ~ 33 1044 0 0.04 10 I 2.95 Shallow corrosion. 34 1075 0 0.03 12 2.94 Shallow pitting. 35 1107 0 0.03 11 2.93 36 1138 0 0.03 \3 2.93 Shallow corrosion. 37 1170 0 0.03 \3 3 2.93 Shallow corrosion. 38 1200 j 0.03 \3 2.93 Shallow corrosion. 39 1231 0.04 14 2.96 Shallowpi tti ng. 40 1263 i 0.03 I 2.94 Shallow pittim1:. 41 1294 ( 0.03 1 2.94 Shallow corrosion. 42 1326 I 0.03 I 2.93 43 1356 0 0.04 1 2.93 Shallow corrosion. 44 1387 0 0.03 J ] 2.94 Shallow pitting. 45 1418 (1 0.03 _I _.1 2.93 Shallow corrosion. 46 1450 J) 0.03 I ') 2.92 Shallow oittinQ. 47 1481 0 0.03 12 ß 2.93 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf 1.-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Joint Jt. Depth Pen. Pen. Pen. ,.1, ,¡ Min. Damage Profile No. (Ft.) (;:::(;1 Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 48 1513 0.02 9 4 2.93 49 1544 0 0.03 13 2.93 Shallow pitting. It. Dé!Posits. 50 1575 0 0.D3 J 6 2.93 51 1606 0.03 I Z 2.94 ShallowJ)ittirg. 52 1638 { 0.D3 12 : 2.93 Shallow pitting. 53 1667 0.03 3 / 2.94 Shallow Ditting. 54 1698 ( 0.04 1 4 2.93 Shallow corrosion. 55 1729 0 0.03 1 6 2.94 Shallow corrosion. 56 1761 I 0.03 I ..6 2.94 57 1792 0 0.03 ¡ () 2.93 Shallow pitting. 58 1824 I) 0.03 J( ,6 2.93 59 1855 0.03 1 2.94 Shallow_nittiOg. 60 1886 I 0.03 12 / 2.93 Shallow Ditting. 61 1915 { 0.04 17 2.93 Shallow corrosion. III 62 1946 I 0.04 5 I 2.94 Shallow corrosion. 63 1978 0 0.04 4 2.93 Shallow corrosion. 64 2009 0.02 ...6 2.93 65 2041 0 0.03 I 4 2.92 66 2072 LL 0.03 ~1 -'} 2.93 67 2103 Jl 0.03 3 2.93 Shallowpittin~. 68 2135 0 0.04 14 2.95 Shallow corrosion. 69 2166 0 0.03 1 2.94 Shallow oittim<. 70 2197 0 0.D3 I 2.95 Shallow corrosion. 71 2228 0 0.03 I 2.94 72 2260 0 0.04 1, 2.94 Shallow corrosion. 73 2291 0 0.03 n ß 2.93 Shallow corrosion. 74 2323 0 0.02 _9 J¡ 2.94 74.1 2354 J) 0.03 I 2.89 PUP U. D~posits. 74.2 2361 U 0 0 I N/A GlM 1 (latch @ 8:00) 74.3 2367 0 0.02 9 ) 2.90 PUP It. Deposits. 75 2372 0 0.04 16 I 2.93 Shallow corrosion. 76 2404 I 0.04 14 5 2.93 Shallow corrosion. 77 2435 .1 0.04 .15 _~1 2.93 Shallow_pittir¡g. 78 2466 J) 0.04 J5 J¡ 2.94 Shallow corrosion. 79 2497 0 0.03 12 / 2.95 80 2529 { 0.03 12 I 2.96 81 2560 0 0.03 11 / 2.93 82 2591 0 0.03 12 2.94 Shallow pitting. 83 2623 0 0.D3 12 I 2.94 84 2654 0 0.02 ( 5 2.93 85 2684 J) 0.02 f 5 2.93 86 2715 J1 0.03 I) 6 2.94 Shallow pitting. It. Dej)osits. 87 2746 JL 0.03 12 6 2.94 Shallow corrosion. 88 2778 .1) 0.04 14 " 2.93 Shallow corrosion. 89 2809 0 0.03 1 7 2.94 90 2841 0 0.03 II I 2.95 91 2873 I 0.03 I 2 2.95 92 2904 J) 0.02 q ...4 2.93 93 2933 Jt 0.02 q " 2.93 94 2964 0 0.03 13 6 2.92 Shallow corrosion. ~ Body Metal loss Body Page 2 I I I I I I I I I I I I I I I I I I I REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in We!!: Field: Company: Country: Survey Date: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Joint Jt. Depth Pen Pen. Pen \/Ieldl Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) ¡Ins) (Ins.) (Ins.) 0 50 100 95 2996 () 0.D3 1 2 2.96 96 3028 0 0.03 I 2 2.93 Shallow pitting. 97 3059 () 0.03 I I 2.94 98 3090 0 0.03 I ! 2.94 99 3122 0 0.03 I 5 2.93 Shallow oittim!. 100 3153 JJ 0.03 1 2.93 ShalloWDi tti!}g. 101 3183 () 0.03 10 2.94 102 3215 0 0.03 10 2.92 103 3246 () 0.02 9 2.96 104 3278 () 0.03 11 2.95 105 3309 0.03 ..11 5 2.93 Shallow corrosion. 106 3338 () 0.03 _11 _l> 2.92 107 3370 J) 0.03 10 2 2.95 Lt. Deoosits. 108 3401 Jl 0.03 12 4 2.94 Shallow corrosion. 109 3430 0 0.03 12 2.92 110 3460 0 0.03 1 2.95 111 3491 0 0.03 1 2.94 112 3523 0 0.03 1 2.93 Shallow corrosion. I 113 3554 0 0.D3 I ( 2.95 Shallow corrosion. 114 3586 0 0.03 I 6 2.94 115 3617 0 0.03 1 -"I 2.92 Shallow corrosion. 116 3648 J 0.04 LiL ...11 2.93 Shallow corrosion. 117 3680 0.D3 1 4 2.92 Shallow oittimt 118 3710 I 0.04 1 4 2.92 Shallow corrosion. 119 3741 ( 0.04 1 6 2.95 Shallow corrosion. 120 3773 0 0.03 p 2 2.96 121 3805 0 0.03 J J. 2.94 Shallow corrosion. 122 3836 J) 0.04 14 2.93 Shallow corrosion. 123 3866 0 0.03 13 2.91 Shallow corrosion. 124 3896 0 0.03 12 2.95 125 3928 0 0.02 2.91 126 3959 0 0.03 2.94 Shallow pitting. 127 3991 0 0.03 I 2.95 128 4D23 0 0.03 (; 2.94 Shallow corrosion. 129 4054 0 0.03 J¡ 2.94 130 4D85 0 0.02 9 (, 2.95 131 4117 Q 0.03 10 ( 2.93 132 4149 _0 0.03 II 2.95 133 4181 ! 0.03 11 2.95 134 4212 () 0.D3 10 2.93 135 4243 0 0.03 11 " 2.92 Lt. Deposits. 136 4275 0 0.03 11 () 2.94 137 4306 JI 0.03 H IJ 2.92 ! 138 4338 0 0.04 14 1 2.94 Shallow corrosion. 139 4369 0 0.04 14 J 2.95 Shallow_pittiag. Ii 14D 4400 j) 0.04 J1L 2.94 Shallow j¿i ttif}g. 141 4431 ! 0.03 1 2.93 Shallow pitting. 142 4463 0 0.04 I) I 2.93 Shallow corrosion. 143 4494 0 0.04 1 2.92 Shallow pitting. 144 4524 0 0.04 1 ! 2.95 Shallow corrosion. Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf 1.-80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 1 9, 2006 Joint Jt. Depth Pen. Pen. I'en. :"1c'lal Min. Damage Profile No. (Ft.) -I Body 1 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 145 4555 () 0.03 ,) 2.95 146 4586 () 0.04 1 2.94 Shallow nittim!. 147 4618 I 0.03 4 2.93 148 4650 I 0.03 2 2.94 Shallow Dittim!. 149 4681 0.04 14 2 2.94 Shallow Dittim:!:. 150 4712 1 0.03 12 2.93 Shallow corrosion. 151 4744 I 0.ü3 12 2.94 Shallow pitting. 152 4776 0 0.03 1 2.93 Shallow corrosion. 153 4808 1 0.03 I. 2.94 154 4838 0 0.04 1 ¿ 2.93 Shallow corrosion. 155 4869 0 0.04 1 2.92 Shallow corrosion. 156 4900 0 0.04 1 Ii 2.97 Shallow Dittin\!. 157 4929 () 0.02 I) 6 2.94 158 4961 () 0.03 1 2.93 159 4992 0 0.03 12 ! 2.94 160 5024 0 0.04 17 2.93 Shallow corrosion. 161 5055 0 0.03 1 2.93 162 5086 0 0.03 I 7 2.92 Shallow pittimI. 163 5119 0 0.03 I S 2.95 Shallow nittin\!. 164 5150 0 0.03 I 2 2.95 Shallow corrosion. 165 5182 0 0.04 1 4 2.94 Shallow Dittim!. 166 5212 0 0.04 15 ( 2.95 Shallow pitting. I 167 5244 0 0.04 14 2.94 Shallow pitting. 168 5275 ei 0.03 1 1 2.91 Shallow pitting. III 169 5307 0 0.04 I 2.94 Shallow pitting. 170 5338 0 0.04 11 2.93 Shallow corrosion. ~ 171 5370 0 0.04 I 2.95 Shallow Dittin\!. 172 5400 0 0.04 1 1 2.93 Shallow Ditting. 173 5431 0 0.03 12 2.93 --InJ 174 5462 0 0.03 II ) 2.93 175 5493 0 0.04 16 2.92 Shallow corrosion. 176 5524 (i 0.04 16 2.96 Shallow pitting. 177 5555 0 0.03 11 . 2.93 178 5587 0 0.04 17 2.93 Shallow pittin\!. 179 5618 0 0.04 17 I. 2.93 Shallow corrosion. 179.1 5649 I.) 0.02 (J 2 2.91 PUP 179.2 5654 0 0 0 0 N/A GLM 2 (Latch @ 9:00\ 1 79.3 5663 I. 0.03 10 2 2.90 PUP 180 5667 Ii 0.cJ4 15 2.93 Shallow corrosion. 181 5699 0 0.04 I· 2.93 Shallow corrosion. 182 5730 Ii 0.03 1 2.92 Shallow pittiml. 183 5761 Ii 0.05 21 2.92 Corrosion. 184 5793 0 0.04 1 4 2.94 Shallow Dittin\!. 185 5824 I. 0.05 2e1 2.93 Isolated pitting. 186 5856 I 0.05 I ) 2.93 Shallow corrosion. 187 5887 ( 0.05 I 2.93 Shallow pitting. 188 5917 1 0.04 1 I. 2.94 Shallow corrosion. 189 5949 ei 0.04 1 2 2.93 Shallow Dittim.?:. 190 5979 0 0.04 I 2 2.95 Shallow Ditting. 191 6009 0 0.05 11] 6 2.92 Shallow pittìm!.. Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf l-BO EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Date: 2 N-318 Kuparuk ConocoPhillips Alaska, Ine. USA October 19, 2006 Joint Jt. Depth Pen. Pen. Pen. (vlelal Min. Damage Profile No. (Ft.) Body I 1.0. Comments (%wall) 115) (Ins.) (Ins.) 0 50 100 192 6041 I) 0.03 IJ 2.94 Shallow oittim;¡. 193 6073 j) 0.04 17 2.94 Shallow corrosion. 194 6104 0 0.04 .) 2.93 Shallow oittim2. 195 6136 0 0.04 .) 2.94 Shallow corrosion. 196 6167 0 0.04 .5 2.95 Shallow oittim2. 197 6197 0 0.04 4 2.92 Shallow corrosion. It Deposits. 198 6229 0 0.05 ') 2.93 Shallow corrosion. 199 6260 0 0.04 '} 2.95 Shallow oittim;¡. 200 6291 0 0.04 14 2.94 Shallow pitting. 201 6322 0 0.06 23 2.94 Isolated pitting. Lt. Deposits. 202 6353 0 0.04 1] i 2.93 Shallow corrosion. 203 6385 ..0 0.04 I I) 2.93 Shallow oittim;¡. 204 6416 0 0.04 .5 2.93 Shallow oittimL 205 6447 0 0.06 \ 2.94 Isolated oittimL 206 6478 I) 0.04 .5 2.96 Shallow pitting. Deposits. 207 6509 0 0.04 2.94 Shallow pitting. 20B 6540 0 0.05 11 2.93 Shallow corrosion. 209 6571 0 0.06 22 2.94 Isolated nittim:!. 210 6601 0 0.04 1.5 2.95 Shallow oittimz. 211 6634 0 0.05 .5 2.92 Isolated oittimz. 212 6665 0 0.06 7 2.93 Isolated Dittim:L 213 6697 0 0.05 4 2.95 Shallow oitting. 214 6726 0 0.06 6 2.92 Isolated pitting. U. Deposits. 215 6758 0 0.06 )4 .5 2.94 Isolated pitting. 216 6789 0 0.05 19 2 2.95 Shallow pitting. 217 6821 0 0.07 .2B 2 2.96 Isolated pitting. 218 6852 j) 0.05 .2 6 2.93 Corrosion. 219 6883 D 0.05 21 (, 2.94 Isolated oitting. 220 6913 0 0.04 11 4 2.93 Shallow corrosion. 221 6943 I) 0.04 I 3 2.93 Shallow pitting. 222 6975 I) 0.05 l' 2.95 Shallow corrosion. 223 7007 t 0.06 22 2.92 Isolated pitting. It. Deposits. 224 7039 I) 0.04 15 i 2.94 Shallow pitting. 225 7070 I) 0.04 17 2.93 Shallow pitting. 226 7102 11 0.04 2.94 Shallow oittin\:!. 227 7132 0.05 2.95 Shallow oittim;¡:. 228 7164 1 0.06 2.95 line corrosion. 229 7195 0.05 6 2.94 Shallow Ditting. 230 7228 I) 0.06 2.93 Isolated Ditting. 231 7256 U 0.04 H 2.93 Shallow pitting. Lt. Deposits. 232 7288 I) 0.06 L 2.96 line corrosion. 233 7319 0.06 23 2.95 Corrosion. 234 7350 0.05 2.95 Shallow Dittin\:!. 235 7381 1 0.07 ) 2.94 Corrosion. 236 7413 0.05 2.96 Corrosion. 237 7445 ( 0.05 2.93 Shallow pitting, 238 7476 U 0.05 ;2 2.95 Isolated_pitting. 239 7507 0 0.05 I 2.93 Shallow oittin\:!. 240 7539 0 0.05 ) 2.93 Shallow Dittimz. 241 7569 [) 0.04 1 2 2.95 Shallow pitting. Penetration Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Joint Jt. Depth Pel· Pen. Pen. Metal Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 242 7601 0 0.04 5 2.93 Shallow pitting. i 243 7633 0 0.07 2; 2 2.93 Isolated pitting. 244 7664 0 0.05 2.95 Shallow pitting. 245 7696 0 0.05 2f 2.94 Corrosion. 246 7727 0 0.03 IJ 2.96 Shallow oittiml. 247 7755 0 0.03 I 2.93 Shallow oitti0\2. 248 7787 0.04 ¡ 2.93 Shallow oittiml. 249 7819 0 0.04 1 2.95 Shallow oittim;¡. 250 7850 0 0.04 I, ') 2.94 Shallow corrosion. 251 7882 0 0.04 '¡ 2.93 Shallow pitting. 252 7911 0 0.04 2.93 Shallow corrosion. 253 7942 0 0.05 1( 2.96 Shallow corrosion. 254 7975 0 0.04 14 2.94 Shallow oittiml. 255 8007 I 0.04 I 2.95 Shallow oittiO\:!. 256 8037 0.04 I 2.95 Shallow pitting. 257 8068 0.04 I 2.94 Shallow oittiml:. 258 8101 0.05 l' 6 2.94 Shallow corrosion. 259 8132 ( 0.05 I' 2.95 Shallow pitting. 260 8163 0 0.04 J4 2.94 Shallow corrosion. 261 8195 0 0.03 11 / 2.93 262 8223 LL 0.02 B 2.94 263 8253 C 0.04 I (, 2.93 Shallow pittilll!. Lt. Deoosits. 264 8284 C 0.04 I' 7 2.94 Shallow corrosion. 265 8315 0 0.04 I 5 2.94 Shallow corrosion. 266 8345 0 0.04 1 b 2.92 Shallow pitting. 267 8377 0 0.07 29 2.92 Corrosion. U. Deposits. 268 8407 0 0.04 17 2.93 Shallow corrosion. 269 8438 0 0.04 16 ( 2.95 Shallow pitting. Lt. Deposits. 270 8468 0 0.04 ~4 2.94 Shallow oitting. 270.1 8498 0.03 t2 2.86 PUP Shallow oittil]g. Lt. Deposits. 270.2 8505 0 0 I N/A GLM 3 (Latch @ 9:0Ql 270.3 8512 0.03 2 2.85 PUP Lt. Deoosits. 271 8519 ( 0.04 I' 4 2.93 Shallow pitting. 272 8548 0 0.03 1 (: 2.95 273 8580 0 0.03 H 2 2.95 274 8610 0.03 U 7 2.93 Shallow_pitting. 275 8642 0.04 6 2.94 Shallow pitting. 276 8673 0.04 4 2.94 Shallow corrosion. 277 8704 J 0.04 I 7 2.94 Shallow corrosion. 278 8736 ) 0.03 2 2.94 279 8767 () 0.07 21 2.94 Line corrosion. 280 8797 0 0.06 24 2.93 Isolated pitting. 281 8829 0.06 0.07 )( 2.95 IsolatedJ.Jitting. 282 8859 0.09 ) 2.92 Corrosion. 283 8890 0.08 2.94 Isolated pittiml:. 284 8922 0.09 4 2.94 Line corrosion. 285 8952 0.10 ß 2.94 Line corrosion. 286 8984 0 0.08 71 6 2.92 Corrosion. Lt. Deposits. 287 9017 0.07 0.12 49 ..6 2.93 Corrosion. 288 9047 0 0.08 33 q 2.94 Corrosion. Body Metal Loss Body Page 6 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaltD.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA October 19, 2006 Joint Jt. Depth Pel Pen. Pen. Ilclc'lal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (II) (Ins.) (Ins.) 0 50 100 289 9078 0 0.10 39 5 2.95 Isolated pitting. 290 9109 0 0.11 43 (; 2.93 Line corrosion. Lt. Deposits. 291 9140 010 0.10 40 5 2.93 Isolated pitting. 292 9171 1 0.09 14 , 2.90 Corrosion. Lt. Deposits. 293 9202 0 0.09 6 2.94 Corrosion. 294 9234 O.W 0.13 ,2 2.93 Corrosion. 295 9264 U 0.10 2.92 Line corrosion. I t. Deposits. 296 9296 0 0.12 _L 2.92 Line corrosion. Lt. Deposits. 297 9325 0 0.13 2.93 Corrosion. Lt. Deposi ts. 298 9356 0 0.09 2.93 Corrosion. 299 9390 o OS 0.08 35 3 2.91 Isolated pitting. 300 9419 0 0.12 4 6 2.92 Isolated pitting. 301 9452 0.07 0.07 ¿ 2 2.93 Isolated pitting. 302 9484 0 0.03 J I 2.94 Shallow pitting. 303 9515 0 0.13 5. a 2.93 Line corrosion. Lt. DepOsits. 304 9547 0.111 0.13 51 5 2.93 Corrosion. 305 9576 I 0.05 It; 4 2.91 Shallow corrosion. 306 9609 010 0.12 46 2.93 Corrosion. 307 9641 0.09 0.09 34 2.93 Line corrosion. Lt. Deposits. 308 9671 0 0.10 2.93 Corrosion. 309 9702 JUS7 0.10 2.93 Corrosion. 310 9735 0 0.09 2.92 Line corrosion. 311 9764 0 0.10 2.92 Line corrosion. 312 9797 0.09 0.09 3 I 2.93 Line corrosion. 313 9829 006 0.10 3< 2.91 Line corrosion. 314 9860 0 0.04 7 2.93 Shallow pitting. 315 9891 0 0.04 b 2.94 Shallow pi tti ng. 316 9921 00(1 0.09 ) 2.91 Corrosion. It. Deposits. 317 9953 U 0.11 2.94 Line corrosion. 318 9984 0 0.13 2.92 Corrosion. 319 1001 6 0.05 0.05 2.92 Corrosion. U. Deposits. 320 10049 0 0.12 ¿ J 6 2.92 Line corrosion. Lt. Deposits. 321 10079 0 0.14 , 'i 2.91 Line corrosion. Lt. DePosits. 322 10111 0 0.12 5 2.93 Corrosion. It. Deposits. 323 10139 0 0.09 4 2.92 Line corrosion. Lt. Deposits. 324 10172 ( 0.10 '') 2.94 Line corrosion. 325 10202 OJ 16 0.08 ¡ 5 2.94 Line corrosion. Lt. Deposits. 326 10233 I 0.09 3' 6 2.95 Corrosion. 327 10265 I 0.11 4. 2.92 Line corrosion. 328 10296 0 0.11 43 2.93 Line corrosion. Lt. Deposits. 329 10326 011 0.13 ')1 2.92 Line corrosion. Lt. Deposits. 330 10357 011 0.14 56 2.91 Line corrosion. Lt. Deposits. 331 10387 0.06 0.11 44 ( 2.92 Line corrosion. It. Deposits. 332 10419 lur 0.10 I 'r 2.92 Corrosion. U. Deposi ts. 333 10449 006 0.08 10 2.93 Corrosion. Lt. Deposits. Body Metal loss Body Page 7 .. - -.. -- ------- -...... - - PDS Report Cross Sections Well: Field: Company: Country: Tubin : 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 EUE 8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: October 19, 2006 MFC 24 UW No. 211387 1.69 24 M. Tahtouh Cross Section for Joint 330 at depth 10357.2 ft Tool speed = 43 NominallD 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 86 0 Finger 20 Penetration = 0.142 ins Line Corrosion 0.142 ins = 56% Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. 2N-318 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 EUE 8rd .. .. .. .. .. .. .. .. PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: October 19, 2006 MFC 24 UW No. 211387 1.69 L4 M. Tahtouh Cross Section for Joint 321 at depth 10079.85 ft Tool speed = 43 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 92 0 Finger 18 Penetration = 0.138 ins Line Corrosion 0.14 ins = 54% Penetration HIGH SIDE UP Cross Sections page 2 .. -- .. .. ------ Well: Field: Company: Country: Tubin : ------- - - -- - - - 2N-318 Kuparuk ConocoPhiIlips Alaska, Ine. USA 3.5 ins 9.3 f L-80 EUE 8rd Cross Section for Joint 294 at depth 9238.65 ft Tool speed'" 43 Nominal 10 '" 2.992 Nominal OD '" 3.500 Remaining wall area'" 97 % Tool deviation'" 99 ù . PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st October 19, 2006 MFC 24 UW No. 211387 1.69 24 M. Tahtouh Finger 18 Penetration'" 0.133 ins Corrosion 0.13 ins'" 52% Penetration HIGH SIDE = UP Cross Sections page 3 I KRU 2N-318 I 12N..31B\ API: 501032034300 Well Type: PROD Angle @ TS: deg@ SSSV Type: NIPPLE Orig 9/1/2000 Angle @ TO: 72 deg @ 11456 Completion: NIP (518-519, Annular Fluid: LastW/O: Rev Reason: PULL ISO SLEEVE 00:3500) Reference Loa: RefLoa Date: Last Update: 5/17/2006 TUBING Last Tao: 10947 TD: 11456 ftKS (0-10605, 00:3500. ~I\[[ Max Hole Anale: 77 deQ @ 6396 ID:2.992) DescriDtion Size Too Bottom TVO Wt Grade Thread CONDUCTOR 16.000 0 118 118 62.50 H-40 WELDED SURFACE 7,625 0 2603 2310 29.70 L-80 STCM Gas Lift PRODUCTION 5.500 0 10580 4979 15.50 L-BO LTC-MOD I ndl'êllDummy Valve 1 PRODUCTION 3.500 10580 11447 5241 9.30 L-80 8RD EUE (2364-2365, IUMINl.. OD:4.725) Size I Top 1 Bottom I TVD I Wt I Grade 1 _Ihread 3.500 0 I 10605 I 4986 I 9.30 I L-80 I 8RD EUE !Iii I lone 1 Status 1 ft ISPfl Date ¡ TlIl1e 1 Comment Gas Lift 1 I 1 I 15 1 4 I 9/6/2000 IIPERF 12.5" HSD. 180 deo ph I ndrellDummy Valve 2 ¡FRAC TVl"le I Comment (5656.5657. ¡ Placed 234 Mlbs of proppant in 00:4.725) IGal St MD TVD Man Man Type VMfr V Type VOD Lateh Port TAO Date VllI Mfr Run Cmnt 1 2364 2140 Cameo KBG 2-9 Cameo DMY 1.0 DCK 0.000 0 9/1/2000 Gas Lift 2 5656 3466 Cameo KBG 2-9 Cameo DMY 1.0 DCK 0.000 0 9/112000 I ndrellDummy 3 8504 4349 cameo. Cameo DMY 1.0 BTM 0.000 0 0127/2001 Valve 3 (8504-8505, 4 10553 4971 Cameo 2-9 Cameo DMY 1.0 DCK 0.000 0 9/ 1/2UOO 00:4.725) Muin, .eteJ.. Depth TVD Type Description 10 518 517 NIP Cameo 'OS' Nipple 2.875 10512 4959 SLEEVE Baker CMU SlidinQ Sleeve w/2.813" Cameo profile; CLOSED 4/27/2006 2,813 10512 4959 PUMP CS 2.813" LOCK WJTRICO JET PUMP SET 10/28/01 0.000 PUMP 10580 4979 CSR BakerCSR Assv, Size 80-40, 5.5" x4" 4.000 10612,10613, 00:2.813) 10595 4983 NIP Cameo 'D' Nipple, wINo-Go profile 2.750 SLEEVE 10604 4986 SEAL Baker 80-40 Casin¡¡ Seal 4" od x 2.985" id 2.985 10612,10613, 00:3.500) Date Note 7/25/2005 LAST SBHP SURVEY TAKEN @ 8807' RKB 51112006 FOUND IA - FORMATION LEAK @ 5180' ELMD - 5700' ELMD Gas lift I ndrellDummy Valve 4 10663-10664, 00:4.725) , ROOUCTlON (0-10580. OD:5500. Wt:15.50) CSR 1Q500.10581, 00:5.500) NIP 10695-10696, 00:3.500) , RODUCTlON 1Q500.11447, 00:3.500, SEAL 10004-10605, 00:4.000) FRAC ,-" I~ 10952-10957) i:= Perf 10952-10967) "( ~- 7'- (-- ~-, I I I I I I I I I I I I I I I I I 05/09/06 Schlumbel'gel' NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~{' i\N\\!F L' .....~t,.g ....Miiioi ~L li Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ' ...l 00 Field: Kuparuk 'a., Ö 0 ""2.. t ø J-N;~ Well Job # Log Description Date BL Color CD 1Y-29 11213739 PRODUCTION PROFILE W/DEFT t "írlr' - r.. C\ I 04/28/06 1 3M-25A N/A SHUT IN 6HP I ct '-I - aG<O 04/23/06 1 2N-303 N/A LDL ,:;:) c(: - Il~c., 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT l~I-t\3 04/25/06 1 3F"07 N/A INJECTION PROFILE / '1(";- - f 4¿,,- 04/23/06 1 16-16 11235353 PRODUCTION PROFILE W/DEFT IC 1../- ("''""} 04/04/06 1 36-15 11213741 INJECTION PROFILE 4<.<" -, ;: 1':"- 04/30/06 1 1G-07 N/A PRODUCTION LOG W/DEFT I ~::+ - rl0 \ 04/19/06 1 1 A-20 11235356 PRODUCTION LOG W/DEFT l'îO-Ii~~ 04/26/06 1 1H-18 N/A INJECTION PROFILE Ie¡ '?,- I':lb 04/24/06 1 1 R-12 11213738 PRODUCTION LOG W/DEFT I ~S- ~Oc,~ 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE ~~ - C' \ç' 04/29/06 1 2N-318 11213742 LDL dOC -lOb 05/01/06 1 1 Q-OBA 11213743 INJECTION PROFILE I '1'1 - ',e, ':2, 05/02106 1 1 G-01 11213744 INJECTION PROFILE ,,,\,~ - t;\D 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT ¡c, {,- - I Llr 05/04/06 1 1 R-26 11258705 INJECTION PROFILE '¡ C., I - (iC, '~ 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ <,rL./ _ (~",-~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I ".. rl - ;:\,:).h 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE ,-:r2,- ,'"'It., 05/07/06 1 1G-14 11249904 INJECTION PROFILE 1-4<3'-/';'/1 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e about blank e e -------- Original Message -------- Subject:RE: 2N-318 (PTD 200-100) report of failed MITlA Date:Wed, 03 May 2006 13:07:47 -0800 From:NSK Problem Well Supv <n1617@conocophillips.com> To:Thomas Maunder <tom _ maunder@admin.state.ak.us> CC:James Regg <jimJegg@admin.state.ak.us> Tom, A problem was first observed on 2/6/06 when a spike in power fluid injection water was observed. Prior to the increase, the lift rate was 1475 BWPD at 2170 psi. The lift rate jumped to 2675 psi (bpd??- TEM) until the power fluid was choked back to recommended rate on 2/7/06. The lift rate was 1175 BWPD at 600 psi. On March 7th, a welltest showed 200 bbls of water metered when the lift volume metered during the test period was 428 bbls. On 3/23/06, the well was 51 as it was not producing. Attached is a schematic and TIO plot w/injection rate and pressure for your reference. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, May 03,20067:23 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 2N-318 (PTD 200-100) report of failed MmA Marie, Prior to being SI in late March, when were any performance anomalies first noticed? It would help if you would provide a summary of how the performance changed. Thanks in advance. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/2/20068:21 PM: Tom & Jim, An MITIA failed on surface powered jet pump producer 2N-318 (PTD 200-100) during diagnostic wellwork to troubleshoot poor pump performance. On Monday May 1,2006, ConocoPhillips Alaska, Inc., (CPA!) determined the production casing had failed on producing well 2N-318 based on the results of a diagnostic leak detection log. During routine servicing of the surface powered jet pump a production casing MIT was attempted. Due to an inability to pass the MIT a leak detection log (LDL) was run. A leak in the production casing has been identified at 5180' MD, which is above the packer and jet pump location in the tubing string. Well 2N-318 was reported in 2002 to the AOGCC to be one of several surface powered jet pump 10f2 5/9/2006 12:38 PM about:blank e e producers in the Kuparuk area. The power fluid used for this well is produced water. The weB has been shut-in since March 23, 2006 for jet pump troubleshooting. The CMU has been closed and the leak detect log verified tbg integrity, the well is secured. Plan forward is to review the leak detect log results and then develop repair or workover options. The well will remain shut-in and secured until appropriate plans are developed. Please let us know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 20f2 5/9/2006 12:38 PM NIP TUBING~-- (0-10605, OD:3.500, ID:2992) Gas Lift landrel/Dummy Valve 1 (2364-2365, OD4725) Gas Lift landrel/Dummy Valve 2 (5656-5657, 00:4.725) Gas Lift landrel/Dummy Valve 3 (8504-8505, 004725) PUMP (10512-10513, 00:4.000) SLEEVE (10512-10513, 00:3.500) Gas Lift ¡andrei/Dummy Valve 4 (10553-<10554, 004725) PRODUCTION (().10680, OD-5.500, Wt:15.50) CSR (10580-10581, 00:5.500) NIP (10595-10596, OD:3.500) SEAL ----~ (10604-10605, OD:4.000) FRAC (10952-10957) Perf (10952-10967) no ! -2-06 to F: \LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Re: Je[ Pumped Wells Subject: Re: Jet Pumped Wells From: "NSK Problen1 \Nell Supv" <n 161 ì@conocophillips.eom> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tom l\1aunder <tom_n1aunder@]admin.state.ak.us> cc: "n 1617" <n 1617@eonoeophil1ips.eom> Tom: 1 requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently 51 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-30S (PTD 2001350) ","~'~2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tc,m mallnder(~'ddmin.state.Cik.u3> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet ~umped Wells Pete and or Jerry, I have some emails f h'l b rom aWl e ack regarding the wells out there on jet pumps. Would you please provide an updated listing of the ~\'ells presently on jet pumps in greater KRU?? Thanks in advance. To Permitto Drill 2001000 MD 11456 - TVD DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. KUPARUK RIV U TARN 2N-318 Operator PHILLIPS ALASKA INC. 5243 -~ Completion Dat 9/6/2000 . Completion Statu 1-OIL APl No. 50-103-20343-00-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_go Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ._~ Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments SRVY RPT FINAL SRVY RPT FINAL TVD GP,/NEU/DEN 5 FINAL _MD GR/NEU/DEN 5 FINAL MD GR/ROP/RES 5 FINAL TVD GR/RES 5 FINAL 10128 FINAL LIS Verification FINAL 2566 0 0 2566 2566 2566 2285 2566 11401 11456 11456 5243 11456 11456 5243 11401 Open 5/1/2001 10128 ~66-11401 OH 9/19/2000 SPERRY 0-11456 OH 9/19/2000 SPERRY 0-11456 MWD OH 5/1/2001 2566-5243 BL, Sepia OH 5/1/2001 2566-11456 BL, Sepia OH 5/1/2001 2566-11456 BL, Sepia OH 5/1/2001 2285-5243 BL, Sepia CH 5/1/2001 10128 ~'~566-11401 Digital Data CH 5/1/20~1-----~kl.)~ LIS Verification Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R ~.r.~.iv~.d ? Daily History Received? ~ N Formation Tops ~/N Comments: Permitto Drill 2001000 MD 11456 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. KUPARUK RIV U TARN 2N-318 Operator PHILLIPS ALASKA INC. 5243 Completion Dat 9/6/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. $0-103-20343-00-00 UIC N Compliance Reviewed By: Date: Annular Dis ~osal durin the second quarter of 2001: h(1) h(2) ' h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 ]¢-133, 1c-121, lC-123, lC-127 > 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N,314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 Ma), 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 .100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total VolUmes into Annuli for which Disposal Authorization Expired during the secOnd quarter 2001' ............................... j ............. ~ ........................ · %, ,~ Total'Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume .Status of Annulus ' 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 · 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- / 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 ,qnnutar vtsposat aurtng me tntra truarter oj zoo~: h(1) ! h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 luly 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Dis ~osal Authorization Expired during the third quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 ~-~ 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, ' ' 1D-36 1D-30 31622 100 0 31722 OPen, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze ProteCted Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 .. · 2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attaChed the revised report with the volumes disposed into surface casing by production casing annuli dUring the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, ~ Paul Mazzolini Drilling Team Leader PM/skad CC.' Malty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Annular Disposal durin ~,he second uarter ~ 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 IC-133, lC-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 . Dec 00 Jun 01 2N-302, 2N-31..4, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli ~or which Dis ~osal Authorization Expired during the second quarter 2001: Total Volume Start ! End Source Wells Total h(1) Total h(2) T°tal h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 ID-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CDi-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 ,, CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only ,. CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD 1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1 '-' 33, CD1-NQ1 0 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad RECEIVED JUL i 9 2001 CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel ! Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska Oil & Gas Cons. Commission Anchorage Annular Dis ~osal durin the second uarter ~2001: h(1) h(2) h(~) Total for Previous New start End SourCe Wells Well Name Volume VolUme Volume Q,~rter Total To(~! Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133,'1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 '"100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 '"May 01 ,' Jun 01 CD2-24 1C-27 3533 100 0 3633 0 ' 3633. Jun01 'Jun01 1C-127 Total Volumes into Annuli Cur which Dis ~osal Authorization E~ ~ired during the second quarter 2001: ~~ ...................... ~ ............. r ........................ Total Volumer ........... o .... · Start End Source Weils Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, FreeZe Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only ~' CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 200'1 CDI-10, CD1-28, CD1- 33, CD 1-NQ 1 Nabors 16E Diesel/Mud Rettm~ Subject: Nabors 16E Diesel/Mud Return Date: Thu, 5 Jul 2001 15:44:36-0800 From: "NSK Env Coord" <n1438~ppco.com> To: wendy_mahan~admin.state.ak, us CC: 'qXlabors 16E Toolpusher" <n1458~ppco.com> Wendy, On July 1, 2001 well 2N-318 became plugged. 2N-318 is being used by Nabors 16E for annular injection. In an effort to clear the well, it was pressured up to 2000 psi. After pressuring up, the well was bled down. During the bleed down process, diesel in the rig's above ground injection lines was mixed with returned drilling mud. Per the rig's estimate, 10 to 20 bbls of diesel was mixed with approximately 96 to 106 bbls of drilling mud. PAI believes that the diesel/drilling mud mix is intrinsically associated with drilling and therefore suitable for annular injection. However, PAI would like to obtain AOGCC's viewpoint on this matter prior to injection. II'you have questions, please contact me at 659-7212. Jason Charton Kupamk Environmental 1 of I 7/5/01 4:04 PM WELL LOG TRANSMITTAL To: State of Alaska April 26, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-318, AK-MM-00130 c O -/oo The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~N-318: "2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20343-00 t .f~,, x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20343-00 L/2" x 5" MD Neutron & Density Logs: 50-103-20343-00 t-/2" x 5" TVD Neutron & Density Logs: 50-103-20343-00 --/'i Blueline '/1 Rolled Sepia Blueline Rolled Sepia ~1' Blueline ~'~1 Rolled Sepia f'l~ Blueline ~(Rolled Sepia RECEIVED 0 1 2001 Alaska Oil & Gas Cons, ~;omnassio~ Anchorage WELL LOG TRANSMITTAL To: State of Alaska April 12, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-318, 1 LDWG formatted Disc with verification listing. API#: 50-103-20343-00 RECEIVED ~AY 0 1 2~1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR ~ 5 ?,00! Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel ! Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Disposal durin ; the first quarter of 2001: · h(1) h~(2) h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 cm.33, Cm-NQ~, cra40, ¢m.28 2N-318 12276' 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37~ 1D-39 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli for which Diz ~osal Authorization Expired during the first quarter 2001: Total Vo ume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name ~ Volume Volume Volume Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 .32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD1-09, CD1-06 CD1-38 20220 100 '0 20320 Open, Freeze 'Protected March 2000 May 2000 CD1-44, CD1-41, CDI- 19A CD1-05 286' 100 0 ' 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1- 30 I PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23,2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not cOUnted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during, th, :fourth quarter of 2000: h(1)' h(2)' hi3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42. 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30' 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 I ~%/Ol 179-//7 ~ao-/3a Annutar otsposat aurtng me tntra q,uarter oj zoo~ : h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 30443 100 0 30543 375 30918 June 2001 Sept 2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ~ 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli ~or which Dis ~osal Authorization Ex ~ired during the third quarter 2001: Total Volume Start End Source Wells TOtal h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-14Y 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 · 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332' was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by productiOn casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposat-during..thefourth quarter of 2000: h(1)T h(2)~ h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 .26390 CD1-45 26735 100 0 26835 5501 32336 CD1'42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640' 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320' 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 '0 380 0 380~ 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100. 0 12681 0 ' 12681 7.00- 055' ga:>-Io~c Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD 1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel ! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files Re: 2N-318 Annular Disposal Subject: Re: 2N-318 Annular Disposal Date: Thu, 28 Dec 2000 07:37:20 -0900 From: Julie Heusser <julie heusser@admin.state.ak, us> To: James A Trantham ~JTRANTH@ppco.com> James, That approach works for me. A date would also be useful - it will help us keep track of these annular disposal "snapshots in time". Cheers Julie James A Trantham wrote: Julie, in answer to your question on annotating the traveling cylinder, we were thinking of hand writing in the volume pumped to date on the plot (dating the page at the bottom) and probably annotating NA on wells that are not permitted. Hope this helps. Sincerely, James Trantham GKA Drilling Engineering Supervisor Phillips Alaska, Inc. 700 G Street, Anchorage, AK 99501 (w) 907.265.6434 (c) 907.244.5680 I of 1 12/28/00 10:02 AM Re: 2N-318 Annular Disposal Subject: Re: 2N-318 Annular Disposal Date: Wed, 27 Dec 2000 17:22:03 -0900 From: Julie Heusser <iulie heusser@admin.state.ak, us> To: James A Trantham ~JTRANTH@ppco.com> Hi James, Just a quick question - how much effort would it be to add annotations regarding the annular disposal volumes on the traveling cylinder presentation? This would be in addition to the tabulation. Can the label of the traveling cylinder presentation be modified to reflect the the time frame? For example: "Annular Disposal Volumes as of December 31, 2000" or "Annular Disposal Volumes as of a particular date." The company will always have more current annular disposal information than is currently submitted to us on quarterly basis. Cheers Julie James A Trantham wrote: Julie, thanks for the follow up email from this mornings conversation. We are looking into various formats for providing you with the plan view of where wells are located with respect to "a well" being permitted for annulus pumping. Here is an example of a plan view (in this example well, we have presented a snapshot traveling cylinder at the TVD of the surface casing setting depth). In addition, we would attach a table with the more detailed information you have requested (eg., is the offset well permitted for annulus pumping; if so, what time period was it injected into; what volume has been pumped into the well to date; etc.). Let us know your thoughts or suggestions on this. Thanks for your attention and consideration. James Trantham Phillips Alaska, Inc. (w) 907.265.6434 GKA Drilling Engineering Supervisor 700 G Street, Anchorage, AK 99501 (c) 907.244.5680 (See attached file: 2n318 Horizontal trav cyl at 2300' TVD .doc) Name: 2n318 Horizontal trav cyl at 2300' TVD .doc 2n318 Horizontal trav cyl at 2300' TVD .doc Type: Microsoft Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 1 of 1 12/28/00 10:02 AM 2N-318 Annular Disposal Subject: 2N-318 Annular Disposal Date: Wed, 27 Dec 2000 14:15:29-0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: "Noel, Brian" <bnoel@ppco.com>, "Trantham, James" <jtranth@ppco.com> James and Brian, Here is a copy of the email I sent to Tom Maunder summarizing our conversation this morning. There is an item at the bottom that we did not discuss - i.e. providing an explanation for those wells with "unusual" LOT information. I'd be happy to discuss this with you. Please give a call at your convenience. Regards Julie Morning Tom, I just had a phone conversation with James Trantham and Brian Noel re 2N-318 annular disposal operations. At the end of the discussion, I gave them the go ahead to proceed with annular disposal on the understanding that by mid next week they would provide the information listed below. In addition, I've requested the annuli of 2N-319 (the well with the unusual surface casing LOT information) be monitored during any disposal operation on 2N-318. I did not specify the details of the pressure monitoring - I left that up to them for the time being. 1. A list of all wells within 1/4 mile of the surface casing shoe. 2. Annular disposal volumes for these wells including the begin and end date. 3. The excel spread sheets for LOT's and surface casing pressure tests for these same wells. 4. Spider map of the 1/4 mile with the disposal volumes identified at the surface casing shoe. 5. Any additional annular disposal information on any of the wells. In retrospect, I would have asked for' one more piece of information from Phillips. This would apply to any well that had "unusual" LOT information. It would be useful for the company to provide a paragraph detailing their interpretation of this data. If there were any wells that had "unusual" LOT information, these are wells that should be monitored during actual annular disposal operations. Cheers Julie I of I 12/28/00 10:02 AM Re: 2N annular injeclJon well Subject: Re: 2N annular injection well Date: Fri, 22 Dec 2000 17:10:12 -1000 From: "Brian D Noel" <BNOEL@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak. us> Could possibly spud late Tues, but given the way things have been going, Wed is more believable. Tom Maunder <tom_maunder@admin.state.ak. us> on 12/22/2000 04:04:21 PM To: Brian D Noel/PPCO@Phillips cc: Julie Heusser <julie_heusser@admin.state.ak. us>, Wendy Mahan <wendy_mahan@admin.state.ak. us> Subject: Re: 2N annular injection well Brian, Thanks for the notification. I will need to look at what has been submitted for 2N-318. We will get back to you the afternoon of the 12/26. Is your planned spud date Tues 12/26 or Wed 12/2777 Tom Brian D Noel wrote: Nabors 19E will complete well 2L-317A this weekend and move back to 2N pad. After the ~torkover on 2N-303 (pull~rerun tubing), the rig uill spud 2N-314 (estimate starting Wed- 12/26). We plan to rig up for annular injection on well 2N-318. As we did for Blair, by this email we are notifying AOGCC of the intent to begin injection into the recently permitted 2N-318 annulus. Our records indicate the followfng information for 2N-318: Annular injection approval by AOGCC permit #300-239 9/27/00 Well permit no. 200-1 O0 APl # 50-103-20343 Cumulative volume injected to date is 320 bbls (LOT~freeze protect Sept. 2000) Thanks - Brian (See attached file: tom_maunder, vd) Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 2 12/26/00 12:52 PM Re.'*2N annular injection well Subject: Re: 2N annular injection well Date: Fri, 22 Dec 2000 17:04:21 -0900 From: Tom Maunder <tom_maunder~admin. state.ak.us> To: Brian D Noel <BNOEL~ppco.com> CC: Julie Heusser <julie_heusser~admin. state.ak.us>, Wendy Mahan <wendy_rnahan~admin. state.ak.us> Brian, Thanks for the notification. I will need to look at what has been submitted for 2N-318. We will get back to you the afternoon of the 12/26. Is your planned spud date Tues 12/26 or Wed 12/2777 Tom Brian D Noel wrote: 2> > 2> .-> 2> > ,> Nabors 19E will complete well 2£~317,,I this weekend and move back to 2N'pad. After the workover on 2N-303 (Pull/reru. n t'ubing), the rig will spud 2N-314 (estimate starting ~I~d - 12/26). bI/'e plan to rig up for annular injection on well Z_~_Nz3.18.. As we did for Blair, by this email we are noti./),ing A OGCC of the intent to begin injection into the recently permitted 2N-318 annulus. Our recorc~ indicate the following information jbr 2N- 318: Annular injection approval by A OGCCpermit #300-239 .9,/27/00 Well permit no. 200-100 APl # 50-103-20343 Cumulative volume injected to da. re is 320 bbls (1077freeze protect Sept. 2000) Thanks - Brian Tom Maunder <tom maunder~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 12/26/00 10:13 AM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantharn Phone (907) 265-6434 Fax: (907) 265-6224 October 25, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 2N-318 (200-100) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 2N-318. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. Sincerely, James Trantham Drilling Engineering Supervisor PAI Drilling JT/skad OCT 2.6 -000' Alaska Oil &Gas Cons. STATE OF ALASKA AL ' OIL AND GAS CONSERVATION COM :,,oSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classilication of Service Well O,, E! ~ D Suspended D Abandoned D Service O 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. _ _ 200-100 / P. O. Box 100360, Anchorage, AK 99510-0360 ¥1~ 50-103-20343-00 51' FNL, 719' FEL, Sec. 3, T9N, R7E, UM (ASP: 460874, 5911957) Kuparuk River Unit At Too Producing Interval i 10. Well Number 273' FSL, 2015' FEL, Sec. 28, T10N, R7E, UM (ASP: 454317, 5917597) '!:.i 2N-318 At Total Depth i ..... Ej~ ........ i 11. Field and Pool 709' FSL, 2374' FEL, Sec. 28, T10N, R7E, UM (ASP: 453960, 5918036) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Pool RKB 35 feetI ADL 380054 / 375074, ALK 4602 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Su§p..Or,~band. 115. Water Depth, if otlshore 16. No. of Completions August 7, 2000 August 25, 2000 September.~, 2000~"' "~' il N/A feet USE 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness o! Permafrost 11456' MD / 5243' TVD 11351'MD/5211'TVD YES El No [~I N/A feetMD 1225' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CBL, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE V~I'. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 24" 9 cu yds High Early 7.625" 29.7# L-80 Surface 2603' 9.875" 515 sx AS III Lite, 240 sx Class G 5.5" x 15.5# L-80 Surface 10590' 7.5" 280 sx Class G & 340 sx Class G 3.5" 9.3# L-80 10590' 11447' 7.5" (included above) 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10605' 11590' (CSR) 10952'-10967' MD 5087'-5093' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10952'-10967' Pump 234305#? lr~./2~,.p~p ~3r~d 10852#'S in pipe 27. PRODUCTION TEST '" "' Date First Production Method of Operation (Flowing, gas lift, etc.) September 25, 2000 Flowing ~laska U~, Date of Test !Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I ~[-"0'I[.-P~TIO 9/25/2000 8.0 Test Period > 641 361 12 100Ii 927 Flow Tubing iCasing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL :OIL GRAVITY - APl (con') press 417 psi 829 24-Hour Rate > 2103 1192 39 not available 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. 30. GEOLOGIC MARKER FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3.1 10650' 4999' T-2 11075' 5127' Annulus left open - freeze protected with diesel. OCT 26 2000 Alaska Oil & Cas Cons Commission 31. LIST OF ATTACHMENTS ~1~101 r~.~i, Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 ~, ·I, ~ ~rl~~L~_ _ ~ Title D ri II i n.q En .q in esr n.q Sups wi so r Date-~ ~;~ ~'~) ~.,.'"r -~::1~ James Trantham INSTRUCTIONS Prepared by Sharon Al~sup-Drake 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 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: 09/26/00 ARCO ALASKA INC. WELL S%7MMARY REPORT Page: 1 WELL:2N-318 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:08/07/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20343-00 08/07/00 (D1) TD/TVD: 300/300 SUPV:R.W. SPRINGER MW: 9.3 VISC: 100 PV/YP: 1/ 0 (300) DRLG CMT IN SURFACE APIWL: 0.0 Accept¥ig @ 0100 hrs. 8/7/00. Function test diverter system. PJSM. Drilled from 114'-164' Shakers screens blinding off change shaker screens. Drill from 164-300' Gravel, sand & clay. Circulate. Gyro survey @ 280'. Run 10 its 2-7/8" tubing for cementing. PJSM. Pump cement. TOH w/tubing. 08/08/00 (D2) TD/TVD: 300/300 SUPV:R.W. SPRINGER MW: 9.2 VISC: 38 PV/YP: 10/ 4 0) MAKE UP DIRECTIONAL BHA & RIH APIWL: 0.0 RIH, tag cement @ 116', cement soft. Waiting on cement. Drilled cement plug from 116' to 241'. RUn 2-7/8" tubing to 241'. PJSM. Pump cement. POH w/tubing to 86' Circ H20 flushing out cement. RIH, tag cement @ 90'. Waiting on cement, tag @ 90'. Drill 10', wait on cement. Drill cement from 100'-244' 08/09/00 (D3) TD/TVD: 777/773 SUPV:R.W. SPRINGER MW: 9.9 VISC: 120 PV/YP: 23/26 (477) DRILLING @ 1050' APIWL: 8.0 Drilled from 244'-300'. Circ & condition hole, displace with mud. Run gyro. POH. RIH to 285' and run gyro. Drilled from 300'-385'. Circulate and condition mud. Drilled from 385'-777'. Large pieces cement sheath falling off wellbore and unloading from well. 08/10/00 (D4) MW: 10.2 VISC: 58 PV/YP: 23/26 APIWL: 7.6 TD/TVD: 1952/1834 (1175) DRILLING @ 2260' SUPV:R.W. SPRINGER Drilled from 777'-1746'. Circulate hole clean. Short trip from 1746'-1000', no tight spots. RIH. Drilled from 1746'-1952'. Electrical transformer problems. Able to circ on bottom. 08/11/00 (D5) MW: 58.0 VISC: 19 PV/YP: 19/20 APIWL: 6.0 TD/TVD: 2610/2315 ( 658) CIRCULATING PRIOR TO CEMENTING SURFACE CASING SUPV:R.W. SPRINGER Finish repairing electrical transformer. Drilled from 1952'-2610'. Pump low vis sweep. Short trip from 2610'-1736'. RIH. Pump lo & high vis sweep & circ hole clean. POH. PJSM. Date: 09/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/12/00 (D6) MW: 10.0 VISC: 40 PV/YP: 16/ 5 APIWL: 0.0 TD/TVD: 2610/2315 ( 0) RIH TO DRILL OUT CASING SUPV:R.W. SPRINGER PSJM. Run 7-5/8" casing. Circulate bottoms up thick mud out of hole. Run remainder of casing. PJSM. Circ and condition mud for cementing. Pump cement. Bump plug, floats held. PJSM. ND diverter. NU BOPs and test. 08/13/00 (D7) MW: 9.5 VISC: 48 PV/YP: 12/10 TD/TVD: 2891/2500 (281) DRILLING @ 3090' SUPV:R.W. SPRINGER APIWL: 6.0 Test BOPE. RIH. Circulate bottoms up. Clean out contaminated mud and drill cement from 2440'-2610'. Drill 20' new formation to 2630'. Change out drilling mud. Perform leak off test to 15.9 ppg EMW. POH. RIH. Drill from 2630'-2891' 08/14/00 (D8) MW: 9.6 VISC: 46 PV/YP: 14/10 TD/TVD: 3314/2500 (423) DRILLING @ 3770' SUPV:R.W. SPRINGER APIWL: 5.0 Drilled from 2880'-3228'. Sperry tools quit working, circulate for trip, pump pill. POH. D.P. screen washed out, not the cause for failure. Load MWD tool & function test. RIH, Unable to find screen remnants. Drilled from 3228'-3314'. 08/15/00 (D9) MW: 0.0 VISC: 46 PV/YP: 0/ 0 TD/TVD: 4618/2500 (1304) CIRCULATE BOTTOMS UP. SUPV:R.L. MORRISON JR. Directional drill from 3314' to 4618' APIWL: 0.0 08/16/00 (D10) MW: 9.6 VISC: 47 PV/YP: 16/13 APIWL: 4.4 TD/TVD: 5355/3368 (737) DRILLING AT 5590' SUPV:R.L. MORRISON JR. Directional drill from 4618' to 4945'. Pump hi-vis sweep. Monitor well. Pump slug. Pull to shoe at 2603'. Hole free. RIH to bottom. Hole free no fill. Circulate bottoms up. Directional drill from 4945' to 5355' 08/17/00 (Dll) MW: 9.6 VISC: 47 PV/YP: 16/15 APIWL: 4.4 TD/TVD: 5891/3547 (536) POOH - LAY DOWN ABI MOTOR - TEST BOPE - PICK UP MACH1X SUPV:R.L. MORRISON JR. Directional drill from 5355' to 5845'. Circulate and monitor well. Wiper trip from 5845' to 4900'. Hole free, no fill. Directional drill from 5845' to 5923' Date: 09/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/18/00 (D12) MW: 9.6 VISC: 57 PV/YP: 21/24 APIWL: 5.0 TD/TVD: 5983/3569 ( 92) DRILLING SUPV:R.L. MORRISON JR. Directional drill from 5891' to 5962'. Pump sweep, circulate clean, pump slug. POOH, hole free. Test all rams, lines and valves to 350/3500 psi. RIH. Circulate bottoms up. Directional drill from 5962' to 5983' 08/19/00 (D13) MW: 9.6 VISC: 48 PV/YP: 16/16 APIWL: 3.8 TD/TVD: 6931/3839 ( 948) DRILLING @ 7100' SUPV:R.L. MORRISON JR. Directional drill from 5983' to 6615' Circulate to clean hole and reduce ECD. Directional drill from 6615' to 6741' Circulate to clean hole. Directional drill from 6741' to 6931' 08/20/00 (D14) MW: 9.6 VISC: 48 PV/YP: 16/15 APIWL: 3.9 TD/TVD: 7783/4126 ( 852) DRILLING AT 8110' SUPV:R.L. MORRISON JR. Directional drill from 6931' to 7499'. Circulate bottoms up. Wipe hole from 7499' to 6038'. Hole free, no fill. Clean drill pipe screen. Directional drill from 7499' to 7783' 08/21/00 (D15) MW: 9.6 VISC: 47 PV/YP: 14/16 TD/TVD: 8960/4492 (1177) DRILLING AT 9270' SUPV:R.L. MORRISON JR. Directional drill from 7783' to 8960' APIWL: 3.5 08/22/00 (D16) MW: 9.6 VISC: 47 PV/YP: 14/16 APIWL: 3.~ TD/TVD: 9742/4736 ( 782) TOH -( RIG OFF HI LINE @ 16:30HRS - CPF SAID SHOULD BE SUPV:DEARL W. GLADDEN Dir drilling 8960' to 9300'. CBU, circ hole clean. Monitor well (static), pump dry job. Wiper trip to 5500', no tight hole. Dir drilling 9300' to 9742' 08/23/00 (D17) MW: 9.6 VISC: 51 PV/YP: 14/16 APIWL: 3.2 TD/TVD: 9742/4736 ( 0) DIR DRLG 6 3/4" HOLE @ 9927' ( RIG ON RIG GENERATORS SUPV:DEARL W. GLADDEN Problems drilling, attempt to slide, assy will not drilling, pump nut plug sweeps, suspected balled bit, no results. TOH. PJSM. Test BOPs to 300/3500 psi. PJSM. TIH. 08/24/00 (D18) MW: 9.6 VISC: 49 PV/YP: 17/21 APIWL: 3.1 TD/TVD:10652/5004 (910) DIR DRLG @ 10,880' ( RIG BACK ON HI LINE POWER @ 8:00 SUPV:DEARL W. GLADDEN Wash & ream 9706 to 9742'. Dir. drilling from 9742' to 10621'. Finish circ sweep to surface. Dir drilling 10621' to 10652' Date: 09/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/25/00 (D19) MW: 9.6 VISC: 49 PV/YP: 18/19 APIWL: 3.4 TD/TVD:l1456/5243 ( 804) TOH TO RUN CSG ( RIG ON HI LINE POWER LAST 24 HRS) SUPV:DEARL W. GLADDEN Dir Drilling 10652' to 11456'. Rotate and recip pipe, pump hi vis weighted pill, circ well clean. 08/26/00 (D20) MW: 9.6 VISC: 45 PV/YP: 18/19 APIWL: 3.4 TD/TVD:l1456/5243 ( 0) RUNNING MONO BORE CSG (RIG ON HI LINE POWER LAST 24 HR SUPV:DEARL W. GLADDEN Wiper trip to 9539', no swab, no excess drag. Circ sweep around. Spot lube pill on bottom. TOH. PJSM. St test plug. PJSM. Run monobore casing. 08/27/00 (D21) MW: 9.6 VISC: 44 PV/YP: 18/14 APIWL: 6.0 TD/TVD:l1456/5243 ( 0) TOH L/D CSG ( RIG ON HI LINE POWER LAST 24 HRS) SUPV:DEARL W. GLADDEN Run 5.5" casing to shoe. CBU from shoe. Run 5.5" casing to 6151'. Break circ, partial returns, loss 85 bbl. Run 5.5" casing. No returns. Run casing. Attempt to work pipe and regain return. No returns. Still losing mud if pumping. Pull 5 its and each time attempt to circ. L/D casing back to 100 its. Will not circ. 08/28/00 (D22) MW: 9.6 VISC: 44 PV/YP: 13/10 APIWL: 6.0 TD/TVD:l1456/5243 ( 0) TIH W/ 6 3/4" H.O.ASSY @ 5499' - CIRC & CONDITION MUD SUPV:DEARL W. GLADDEN TOH L/D 5.5" casing, pipe lightly swabbing. Regained circ. Continue TOH. TIH to 1764' Stage in hole 500' at a time. 08/29/00 (D23) MW: 9.6 VISC: 42 PV/YP: 15/ 9 APIWL: 5.0 TD/TVD:l1456/5243 ( 0) CHANGING PIPE RAMS, PREPARING TO RUN CASING (RIG ON HI SUPV:R.W. SPRINGER Stage into hole, circ bttms up. Trip in, tag up @ 10010' RIH to 10861' Circulate bottoms up. Spot lube pill, monitor well. POH. 08/30/00 (D24) TD/TVD:l1456/5243 ( SUPV:R.W. SPRINGER MW: 9.7 VISC: 41 PV/YP: 15/ 9 APIWL: 5.0 0) RUNNING PRODUCTION CASING (24 HR HI-LINE POWER) POH, tight spot @ 7227', work pipe. Set test plug. Rig up to run 3.5" casing, PJSM. Run 3.5" casing. Rig up to run 5.5" casing. Circulate bottoms up @ casing shoe @ 2600'. Continue running 5.5" casing. Circ bttms up. Run casing to 8821' Circ bttms up. 08/31/00 (D25) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1456/5243 ( 0) RUNNING COMPLETION (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Circ @ 8821', 5 bbl loss. Continue RIH w/5.5" casing. Circ bttms up @ 10523', 7 bbl loss. RIH w/5.5" casing to TD. Pump cement. Bumped plugs, floats held. Install packoff and test. PJSM. Run 3.5" completion. Date: 09/26/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 09/01/00 (D26) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1456/5243 ( 0) N/U TREE, PREPARING TO MOVE. (16 HR HI-LINE POWER- PRE SUPV:R.W. SPRINGER Run 3.5" tubing completion. Test casing to 3500 psi, test tubing to 3500 psi. Pump diesel to freeze protect. PJSM. 09/02/00 (D27) TD/TVD:l1456/5243 ( SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIG RELEASED & MOVED TO 2N-349 (RIG OFF HI-LINE F/ MOV PJSM. ND BOPE, NU tree and test to 5000 psi. Release rig @ 1000 hrs. Move rig to 2N-349. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-318(W4-6)) WELL 2N-318 DATE O9/O6/OO JOB SCOPE PERFORATIONS-E-LINE(260) DAILY WORK CEMENT BOND LOG, PERFORATING, SBHP DAY OPERATION COMPLETE I SUCCESSFUL I YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 300 PSI 0 PSI 500 PSI DAILY SUMMARY KEY PERSON SWS-STEPHENSON Final Inner Ann 500 PSI JOB NUMBER 0904001703.14 UNIT NUMBER SWS - 2145 SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 300 PSII 300 PSI MAX DEPTH REACHED 11262' (STOPPED DUE TO DEVIATION), CEMENT BOND LOG SHOWED GOOD ISOLATION, PERFORATED FROM 10952' - 10967' WITH 2.5" HSD USING BH CHARGES 4 SPF & 180 DEGREE PHASING, MADE TWO ATTEMPTS TO LOG SBHP WITHOUT SUCCESS - COULD NOT GET PAST 4075' DUE TO DEVIATION, WHTP, & POSSIBLE PERF DEBRIS. TIME LOG ENTRY 07:00 DEPART FROM KCC TO 2N-318 08:00 ARRIVE ON LOCATION - HOLD SAFETY MEETING 08:15 SPOT VEHICLES 08:45 START RIG UP 09:30 PT TO 300# 09:35 PT TO 3500# 09:45 10:28 RIH WITH WGT BAR - CCL - GR - TEMP - PRES - SCMT (LENGTH = 39', MAX OD = 1.6875") TOOLS STOPPED @ 6390' 10:30 TOOLS SAT DOWN AGAIN- POOH 200' & RETRY 10:33 SAW COUPLE OF BUMPS BUT GET THROUGH 10:55 TOOLS STOPPED @ 10035'- POOH 200' & RETRY 10:58 TOOLS STOPPED FOR A SECOND & CONT TO RIH 11:05 STOPPED @ 10910' - POOH 200' & RETRY 11:07 GET THROUGH BUT SLOW GOING 11:12 STOPPED @ 11074', LOG 200' REPEAT PASS 11:25 RIH 11:30 STOP @ 11106' - PICK UP 200'& RETRY 11:35 STOP @ 11170' - PICK UP & RETRY 11:40 STOP @ 11250'- PICK UP & RETRY 11:45 STOP @ 11262', PUTTING EXCESS SLACK IN CABLE, LOG MAIN PASS TO 10000' 13:30 RIG DOWN SCMT 13:55 HOT CHECK GUN SYSTEM 14:10 STAB ONTO WELL 14:20 PT TO 4000# 14:30 15:35 RIH WITH WGT BAR - 2" ROLLERS- OFFSET HEAD- CCL- SAFE - 15' 2.5" HSD @ 4 SPF WITH BH CHARGES- 2.625" ROLLERS (TOTAL LENGTH = 42') LOG TIE IN PASS TIME 15:55 16:20 16:25 16:55 17:15 17:30 17:40 17:55 17:58 18:00 18:25 18:45 19:05 LOG ENTRY PRESSURE UP TUBING TO 4000# LOG INTO SHOOTING POSITION & PERFORATE FROM 10952' - 10967' WITH 4000 PSI WHP, WHP DROPPED TO 1000 PSI AFTER PERFORATING POOH WHP @ 0 PSI RIG DOWN GUN RIG UP PSP RIH WITH WGT BAR - 2" ROLLERS - WGT BAR - CCL - GR - PRES - TEMP (& PFCS FOR ROLLERS) (LENGTH = 31') STOPPED @ 4070' STOPPED @ 4050' STOPPED @ 4040', POOH FOR DIFFERENT CONFIGURATION RIG DOWN PSP CONFIG 1, NOTE CCL AFTER PERF AND THIS ATTEMPT HAS LOTS OF METAL FILLINGS STUCK TO IT RIH WITH WGT BAR - CENT/ROLLER - WGT BAR - CENT/ROLLER - PSP - CENT/ROLLER (LENGTH = 35') STOP @ 4075' - PICK UP 200' & RETRY 19:08 STOP @ 4065' - PICK UP 50' & RETRY 19:10 STOP @ 4070'- POOH 19:30 START RIG DOWN 19:45 CCL WAS COVERED IN METAL FILINGS AGAIN 20:30 COMPLETE RIG DOWN - LEAVE LOCATION 21:30 RETURN TO KCC PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-31S0N4-6)) WELL 2N-318 JOB SCOPE DRILLING SUPPORT-CAPITAL JOB NUMBER 0908001452.4 DATE DAILY WORK UNIT NUMBER 09/10/00 FRAC TREATMENT KEY PERSON SUPERVISOR DS-GALLEGOS FERG USON Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSII 0 PSII 0 PSI DAY OPERATION COMPLETE SUCCESSFUL 1 YES YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 200 PSI DAILY SUMMARY RU DOWELL FRAC EQUIP AND PUMP BREAKDOWN, SCOUR AND DATAFRAC STAGES. PUMP JOB WITH MAX PAD TO OPTIMIZE HALF LENGTH. SCREENOUT AFTER PLACING 234,305#'S BEHIND PIPE WITH MAX CONC OF 7 PPA (86% OF DESIGN). LEFT 10852#'S PROP IN PIPE.[Frac-Refrac] TIME LOG ENTRY 09:00 ARRIVE LOCATION. DOWELL RIGGING UP PUMP EQUIPMENT 09:50 SAFETY MEETING. 10:30 PT LINES TO 10800 PSI 10:35 START 1ST BREAKDOWN STAGE OF J313 10:45 PERFORM SDT AND ISIP, ISIP=590 PSI, FG=0.57, XS FRICTION AT 27 BPM=1810 PSI 11:05 PERFORM SCOUR STAGES AND SDT WITH PULSES. ISIP= 599 PSI, FG=0.57, XS FRICTION IS 414 PSI AT 25 BPM 12.~10 START DATAFRAC WITH 300 BBLS OF 40# X/L AT 25 BPM 13:20 SD FOR DATAFRAC ANALYSIS. TC=6.2 MIN, PC=794 PSI, EFF=29%,. NO CHANGES MADE TO PAD 13:30 START FRAC WITH DESIGN PAD AND RAMP. 35 BPM AND 7000 PSI 13:50 SD FOR 600 BBL ISIP IN 1000 BBL SLICKWATER STAGE OF PAD 14:20 SD FOR 600 BBL ISIP INTO 1000 BBL X/L PAD 14:33 REDUCE RATE TO 25 BPM AND START 1 PPA STAGE 14:50 SWAP TO 40# GEL AT BEGINNING OF 4 PPA FLAT STAGE 15:45 SCREENOUT 48 BLS INTO THE 93 BBL FLUSH 15:50 PLACE 234305#'S PROPPANT BEHIND PIPE AT MAX CONC OF 7 PPA. LEFT 10852#'S IN PIPE. 17:30 JOB COMPLETE RDMO PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into suaace casing oy p~ucuon cas~ng annuli during the third queer of 2000, as well as tot~ volumes injected into ~nuli for which injection authorization expired during the third queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990. 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907. 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: ~otal ~ Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel ! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Offioe Box 100~60 Anchorage, Alaska 9951~60 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas ConserVation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 La CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 cvc,-~ CD1-25 24860 100 0 24960 8627 . '33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347. 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 13-Sep-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 MWD+IIFR tool type (Definitive) Re: Distribution of Survey Data for Well 2N-318 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 11,456.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) 19 000 0il..& Gas Cons. Commission Anchorage 13-Sep-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 MWD tool type (Not Definitive) Re: Distribution of Survey Data for Well 2N-318 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 11,456.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) SE? 19 _000 Alask~ 0il & Gas Cons. C0mmissiQ~ Anch0rar~e North Slope Alaska Alaska State Plane 4 Kuparuk 2N 2N-318 MWD Job No. AKMMO0130, SURVEY REPORT 13 September, 2000 Your Ref: API-501032034300 Surface Coordinates: 5911956.79 N, 460873.98 E (70° 10' 13.4611" N, Kelly Bushing: 153. lOft above Mean Sea Level 209° 41' 06.3938" E) gl~'l I-.I- IN O SeFtVlCe~ A Halliburton Company RECEIVED SEP 19.2000 Oil& Gm Cons. Commi~sTo~ Anchorage Survey Reh svy9289 Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: AP1-501032034300 Job No. AKMMO0130, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -153.10 114.00 0.000 0.000 -39.10 202.00 0.500 94.000 48.90 275.00 0.800 258.500 121.90 308.97 2.040 266.740 155.86 336.93 2.670 271.890 365.53 3.070 290.680 396.18 3.200 298.800 426.55 3.730 304.870 456.17 4.380 308.500 486.51 5.270 307.260 516.45 6.090 298.560 545.69 7.100 303.250 576.31 7.670 301.940 605.80 7.720 302.070 636.08 8.640 306,240 666.69 9.350 310.180 697.11 9.680 309.780 727.14 10.840 310.420 759.17 11.820 309.000 788.64 12.680 310.150 850,32 12.250 310.900 911.92 14.480 310.820 997.15 17.110 309.510 1093.60 18.330 309.320 183.79 212.36 242.96 273.28 302.82 333.05 362.85 391.89 422.26 451.48 481.46 511.69 541.69 571.24 602.65 631.44 691.67 751.60 833.60 925.48 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 0.00 114.00 202.00 275.00 308.96 336.89 365.46 396.06 426.38 455.92 486.15 515.95 544.99 575.36 604.58 634.56 664.79 694.79 724.34 755.75 784.54 844.77 904.70 986.7O 1078.58 0.00 N 0.00 E 0.00 N 0.00 E 0.03 S 0.38 E 0.15 S 0.20 E 0.23 S 0.63 W 0.24 S 1.78 W 0.05 N 3.16 W 0.76 N 4.68 W 1.73 N 6.24 W 2.98 N 7.91 W 4.55 N 9.93 W 6.14 N 12.42 W 7.87 N 15.29 W 9.99 N 18.61 W 12.08 N 21.95 W 5911956.79 N 460873.98 5911956.79 N 460873.98 5911956.76 N 460874.36 5911956.64N 460874.18 5911956.56 N 460873.34 5911956.56 N 460872.20 5911956.86 N 460870.82 5911957.57N 460869.30 5911958.55 N 460867.75 5911959.81N 460866.08 5911961.39 N 460864.08 5911962.99 N 460861.60 5911964.74 N 460858.73 5911966.88 N 460855.43 5911968.99 N 460852.09 Dogleg Rate (°/100fi) 14.51 N 25.51W 5911971.43 N 460848.54 17.47N 29.27W 5911974.41N 460844.80 20.70N 33.12W 5911977.66N 460840.97 24.15 N 37.21W 5911981.13 N 460836.89 28.17 N 42.05W 5911985.17 N 460832.07 Alaska State Plane 4 Kuparuk 2N 32.15 N 46.87W 5911989.18 N 460827.28 40.80 N 56.99W 5911997.88 N 460817.20 50,12 N 67.76W 5912007.25 N 460806.48 65.06 N 85.50W 5912022.29 N 460788.82 83.70N 108.18W 5912041.05 N 460766.23 Vertical Section Comment E 0.00 E 0.00 0.00 E 0.57 -0.31 E 1.77 -0.25 E 3.69 0.33 E 2.37 1.20 E 3.55 2.44 E 1.51 4.06 E 2.12 5.87 E 2.36 7.96 E 2.95 10.51 E 3.96 13.43 E 3.91 16.75 E 1.94 20.64 E 0.18 24.55 E 3.61 28.83 E 3.07 33.61 E 1.11 38.64 E 3.88 43.99 E 3.18 50.28 E 3.03 56.53 E 0.74 69.85 E 3.62 84.08 E 3.11 107.28 E 1.27 136.63 RECEIVED 19'2000 MWD Magnetic Continued... 13 September, 2000- 3:23 -2- AJ;~ska OJJ & G~ Cons. C0mmissien Anchorage DrillQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 2N.318 MWD Your Ref: API-501032034300 Job No. AKMMO0130, North Slope Alaska Measured Depth (~t) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (~t) (ft) (~t) (~t) 1188.56 19,940 307,730 1015,19 1168,29 1283.45 22.340 306,970 1103,68 1256,78 1378,23 23,630 305,110 1190,94 1344,04 1470,74 26.770 301,260 1274,64 1427,74 1567,13 28,350 300,600 1360,09 1513,19 1662.72 30,260 302,610 1443,44 1596,54 1757.29 33.550 308,090 1523,73 1676,83 1852.04 35.120 306,940 1601,97 1755,07. 1946,43 39,190 305,010 1677,19 1830,29 2041,36 42,640 302.980 1748,92 1902,02 2104,35 43,030 303.620 1795,11 1948,21 2167,70 42,590 302,590 1841,58 1994,68 2231.01 42.370 303.100 1888.28 2041.38 2294.02 42.210 303.940 1934.89 2087.99 2363.86 42.170 305.010 1986.63 2139.73 2420,70 42,230 305,540 2028,74 2181,84 2484.14 44.110 303.290 2075,01 2228,11 2534,44 45,630 300,320 2110,66 2263,76 2637.24 48,360 304,220 2180,79 2333,89 2700,73 47,420 304,710 2223,36 2376,46 2794,82 49.280 305,790 2285,89 2438,99 2889,68 51,980 309,600 2346,07 2499,17 2984,56 54,760 311,270 2402,67 2555,77 3079.27 60.530 313.440 2453.34 2606.44 3175.02 61.590 312.720 2499.67 2652.77 103.07 N 132.54W 5912060.54 N 460741.97 123.82 N 159,75W 5912081.43 N 460714.87 145.58 N 189.68W 5912103.35 N 460685.05 167.06 N 222.67W 5912125.00N 460652.18 189.98 N 260.93W 5912148.11 N 460614.04 214.51N 300.75W 5912172.85 N 460574.34 243.49 N 341.41W 5912202.04N 460533.83 276.02 N 383.81W 5912234.79 N 460491.61 309.46 N 429.95W 5912268.47 N 460445.63 344.19 N 481.51W 5912303.46 N 460394.26 367.70 N 517.30W 5912327.16 N 460358.58 391.21 N 553.36W 5912350.86 N 460322.65 414.40 N 589,28W 5912374.23 N 460286.85 437.81N 624.63W 5912397.83 N 460251.62 464.36 N 663.30W 5912424.58 N 460213.09 486,41N 694,47W 5912446,79 N 460182,04 510,93 N 730,27W 5912471,48 N 460146.36 529,61N 760,43W 5912490,33N 460116,30 569,78 N 823,94W 5912530,82 N 460053.00 596,43 N 862,77W 5912557,68 N 460014.31 637,01N 920,17W 5912598.55 N 459957.11 681,87 N 978,15W 5912643,71N 459899,37 731,26 N 1038,08W 5912693,40 N 459841,69 785,17 N 1095,14W 5912747,62N 459782,91 842,40 N 1156,34W 5912805,16 N 459722,01 Alaska State Plane 4 Kuparuk 2N Dogleg Rate (°/lOOff) 1,78 2.55 1.56 3.83 1.67 2.25 4.63 1.79 4.48 3.89 0.93 1,31 0,65 0,93 1,03 0,64 3.83 5.15 3,84 1.59 E 2,15 E 4,21 E 3,25 E 6,39 E 1,29 Vertical Section Comment 167,74 201,91 238.80 277,85 321.83 368,O7 417.81 471,18 528,00 589,76 632.26 674.96 717,34 759.44 806.09 844,12 887,27 922.35 996,75 1043,59 1113.61 1186.83 1262,96 1342.88 1426.58 RECEIVED SEP 19 2000 Continued... 13 September, 2000 - 3:23 -3- Alaska Oil & Gas Cons. Commission Anchorage DrillQuest 2,00,02 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: API.501032034300 Job No. AKMMO0130, Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (~t) (ft) (ft) (ft) 3269.74 64.010 310.720 2542.97 2696.07 3364.16 69.110 308.500 2580.52 2733.62 3458.69 70.890 304,910 2612,86 2765.96 3554.84 70.460 303,090 2644.68 2797.78 3648.10 68.300 303.020 2677.52 2830.62 3742.80 66.650 302.140 2713.80 2866.90 3838.08 66.520 302.060 2751.66 2904.76 3933.07 66,860 301.780 2789,25 2942,35 4028.26 72.760 302.970 2822.09 2975.19 4123,10 75.630 304.630 2847.92 3001.02 4215.89 75.900 304.490 2870.74 3023,84 4312.06 73.130 305.180 2896.41 3049.51 4407.94 73.840 304.920 2923,67 3076.77 4503.01 71.970 305.600 2951.61 3104.71 4597.18 71.970 305.540 2980.76 3133.86 4691,92 71.660 306.180 3010.33 3163.43 4786.47 71.200 305.300 3040.44 3193.54 4881.87 70.870 305.050 3071.44 3224.54 4976.39 71.400 305.680 3102.01 3255.11 5070.79 73.920 306.340 3130.14 3283.24 5164.88 73.280 306.140 3156.70 3309.80 5260,72 71.200 305.890 3185.94 3339.04 5354.34 71.670 305.420 3215.74 3368,84 5456.05 72,550 305.950 3246,99 3400.09 5543.79 70.870 305.170 3274,52 3427,62 898.45 N 1219,23W 5912861.53 N 459659.41 953.63 N 1285.96W 5912917,06 N 459592.97 1006.70 N 1357.17W 5912970,49 N 459522.04 1057,43N 1432.38W 5913021,62 N 459447.08 1105,04 N 1505,54W 5913069.60 N 459374.18 1152.15 N 1579.24W 5913117.08N 459300.72 1198.61N 1653.31W 5913163.93 N 459226.89 1244.73 N 1727.35W 5913210.44 N 459153.09 1292.56 N 1802.76W 5913258.66 N 459077.92 1343.33N 1878.58W 5913309.81 N 459002.37 1394.35 N 1952.65W 5913361.22 N 458928.57 1447.28 N 2028.71W 5913414.54N 458852.78 1500.07 N 2103.97W 5913467.72N 458777.80 1552.52 N 2178.16W 5913520.55 N 458703.87 1604.61N 2251.00W 5913573.02N 458631.31 1657.34N 2323.95W 5913626.12 N 458558.63 1709.69 N 2396.69W 5913678.85 N 458486.16 1761.67N 2470.44W 5913731.20 N 458412.68 1813.43N 2543.38W 5913783.35 N 458340.01 1866.41N 2616.26W 5913836.70N 458267.40 1919.77N 2689.06W 5913890.44N 458194.88 1973.44N 2762.88W 5913944.48 N 458121.34 2025.17 N 2834.99W 5913996.59 N 458049.49 2081.63N 2913.61W 5914053.45 N 457971.17 2130.08N 2981.38W 5914102.25 N 457903.66 Alaska State Plane 4 Kuparuk 2N Dogleg Rate (°/100fi) 3.17 5.82 4.03 1.84 2.32 Vertical Section Comment 151o.79 1597.37 1686.0o 1776.16 1862.72 1.94 0.16 0.45 6.31 3.46 1949.38 2035.90 2122.18 2210,61 23Ol.25 0.33 2.96 0.78 2.08 0.06 239o.72 2482.95 2574.48 2664.98 2754.20 0.72 1 .Ol 0.43 0.84 2.75 2843.93 2933.26 3o23.10 3112.20 3202.04 E 0.71 E 2.18 E 0.69 E 1.00 E 2.09 3292.06 3383.06 3471.51 3567.97 3650.98 RECEIVED SEP 19 2000 Continued... 13 September, 2000 - 3:23 -4- Alaska Oil & Gas Cons. commissiea Anchorage DrillQuest ZOO.02 Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: API-501032034300 Job No. AKMMO0130, North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5638.15 69.220 304.740 3306.72 3459.82 5732.94 69.500 305.590 3340.14 3493.24 5827.81 71.590 308.100 3371.74 3524.84 5922.67 71.650 309.370 3401.65 3554.75 6016.93 72.480 306.760 3430.68 3583.78 6111.06 73.070 303.360 3458.56 3611.66 6205.97 71.590 301.820 3487.37 3640.47 6300.91 73.590 302.820 3515.78 3668.88 6395.65 76.780 304.460 3540.00 3693.10 6490.84 74.550 303.890 3563.57 3716.67 6585.84 74.480 303.040 3588.93 3742.03 6680.58 73.910 301.220 3614.74 3767.84 6775.63 74.210 300.790 3640.84 3793.94 6869.90 72.570 300.550 3667.79 3820.89 6964.66 71.070 299.000 3697.36 3850.46 7059.48 72.370 299.120 3727.10 3880.20 7154.23 71.310 301.660 3756.63 3909.73 7248.96 68.720 305.440 3789.01 3942.11 7343.56 68.850 306.980 3823.25 3976.35 7438.62 70.410 310.050 3856.34 4009.44 7532.49 70.990 312.280 3887.37 4040.47 7627.24 70.420 313.290 3918.68 4071.78 7721.76 70.600 313.480 3950.22 4103.32 7816.61 70.410 314.800 3981.87 4134.97 7911.69 70.100 314.420 4013.99 4167.09 2180.89 N 3054.07W 2231.98 N 3126.58W 2285.62N 3198.15W 2341.95 N 3268.37W 2397.23 N 3338.97W 2448.87N 3412.55W 2497.58 N 3488.74W 2546.01N 3565.29W 2596.75 N 3641.52W 2648.55 N 3717.82W 2699.04N 3794.19W 2747.52 N 3871.38W 2794.59 N 3949.72W 2840.67N 4027.42W 2885.38 N 4105.55W 2929.12 N 4184.25 W 2974.65 N 4261.91 W 3023.82 N 4336.09 W 3075.91 N 4407.24 W 3131.41 N 4476.95 W 3189.72 N 4543.64W 3250.46N 4609.27W 3311.67 N 4674.03W 3373.93 N 4738.19W 3436.78 N 4801.90W -5- Alaska State Plane 4 Kuparuk 2N 5914153.44N 457831.23 5914204.90 N 457758.98 5914258.92N 457687.69 5914315.61N 457617.76 5914371.25 N 457547.45 Dogleg Rate (°/lOOft) Vertical Section Comment E 1.80 3739.27 E 0.89 3827.60 E 3.33 3916.87 E 1.27 4006.85 E 2.78 4096.45 5914423.27 N 457474.13 5914472.37 N 457398.20 5914521.20 N 457321.90 5914572.33N 457245.93 5914624.53 N 457169.91 E 3.51 4185.95 E 2.20 4275.54 E 2.33 4365.22 E 3.76 4456.16 E 2.41 4547.84 5914675.41 N 457093.79 5914724.28 N 457016.85 5914771.77N 456938.76 5914818.25 N 456861.30 5914863.36 N 456783.40 E 0.87 4638.72 E 1.94 4728.93 E 0.54 4819.09 E 1.76 4908.13 E 2.22 4996.61 5914907.50 N 456704.93 5914953.43N 456627.51 5915002.98 N 456553.58 5915055.45 N 456482.70 5915111.30 N 456413.28 E 1.38 5084,88 E 2.78 5173.53 E 4.64 5261.89 E 1.52 5349.84 E 3.44 5438.90 5915169.96 N 456346.89 5915231.04N 456281.58 5915292.58 N 456217.14 5915355.17 N 456153.30 5915418.35 N 456089.91 E 2.33 5527.47 E 1.17 5616.82 E 0.27 5705.81 E 1.33 5795.03 E 0.50 5884.27 RECEIVED SEF' 19 2000 Alaska 0il & G~ Cons. Commission Continued... Dr#/Quest ZOO.02 13 September, 2000 - 3:23 Anchorage Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: API-501032034300 Job No. AKMMO0130, North Slope Alaska Alaska State Plane 4 Kuparuk 2N Measured Depth (ft) Incl. Azlm. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 8006.68 73.070 316.810 4044.00 4197,10 8101.20 72.880 316,420 4071.68 4224.78 8196,25 75.440 316.070 4097.62 4250.72 8290,73 72.960 320.110 4123,35 4276,45 8385.78 68,650 320,410 4154,59 4307.69 8481.05 70.340 321.700 4187.97 4341.07 8575.87 70.080 320.930 4220.07 4373.17 8670.79 71.200 321.040 4251.54 4404.64 8765.55 72.040 320.100 4281.42 4434.52 8861.12 72.880 320.030 4310.22 4463.32 8955.19 72.750 319.280 4338,01 4491.11 9049.75 72.180 318.400 4366.50 4519.60 9144,64 73.060 319.610 4394,85 4547.95 9239.38 71.660 321,350 4423.56 4576.66 9334.34 71.590 320,400 4453.49 4606,59 9428.14 72.380 320.340 4482.50 4635.60 9523.75 72.030 318.710 4511.72 4664.82 9618.31 71.130 322.270 4541.61 4694.71 9712.93 70.540 321.970 4572.67 4725.77 9807.53 73.070 321.240 4602.21 4755.31 9902.05 74.170 321.220 4628.87 4781.97 9996.86 74.550 322.400 4654.43 4807.53 10091.88 72.500 322.910 4681.37 4834.47 10186.26 73.470 323.070 4708.99 4862.09 10280.88 73.080 323.170 4736.22 4889.32 3501.19 N 4864.92W 3566.87 N 4927.00W 3632.91N 4990.23W 3700.53 N 5050.95W 3769.54 N 5108.33W 3838.94 N 5164.41W 3908.58 N 5220.17W 3978.16 N 5276.55W 4047.62 N 5333.66W 4117.49 N 5392.16W 4185.99 N 5450.34W 4253.87 N 5509.68W 4322.22 N 5569.08W 4391.86 N 5626.54W 4461.77N 5683.40W 4530.47N 5740.30W 4599.71N 5799.38W 4668.91N 5856.46W 4739.46 N 5911.33W 4809.88 N 5967.15W 4880.58 N 6023.93W 4952.34N 6080.38W 5024.78 N 6135.65W 5096.84 N 618g.98W 5169.33 N 6244.36W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5915483.08 N 456027.23 E 5915549.08 N 455965.49 E 5915615.45 N 455902.60 E 5915683.38 N 455842.23 E 5915752.69 N 455785.21 E 5915822.38 N 455729.49 E 5915892.31N 455674.08 E 5915962.18 N 455618.07E 5916031.93 N 455561.31E 5916102.10 N 455503.18 E 5916170.90 N 455445.36 E 5916239.09 N 455386.36 E 5916307.74 N 455327.32 E 5916377.68 N 455270.23 E 5916447.88 N 455213.72 E 5916516.87 N 455157.18 E 5916586.43 N 455098.45 E 5916655.92 N 455041.74 E 5916726.74 N 454987.23 E 5916797.46 N 454931.78 E 5916868.45 N 454875.36 E 5916940.50 N 454819.29 E 5917013.22 N 454764.39 E 5917085.57 N 454710.44 E 5917158.33N 454656.43 E 3.93 0.44 2.72 4.88 4.54 2.18 0.81 1.18 1.29 0.88 0.77 1.07 1.53 2.29 0.95 0.84 1.66 3.70 0.69 2.77 1.16 1.26 2.22 1.04 0.42 Vertical Section Comment 5974.01 6063.85 6154.81 6244,88 6333.30 6420.99 6508.59 6596.62 6685,13 6774.96 6863.66 6952.85 7042.39 7131.27 7219.89 7307.74 7397.62 7485.93 7573.44 7661.59 775O.66 7840.15 7929.19 8017.27 8105.66 RECEIVED SEP 19 ,?.000 Gas Cons. Anchorage Continued... DrillQuest 2.00.02 13 September, 2000 - 3:23 - 6 - Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: API-501032034300 Job No. AKMMO0130, North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 10375.76 71.850 322.490 4764.81 4917.91 5241.42 N 6299.02 W 10470.05 72.490 322.820 4793.68 4946.78 5312.78 N 6353.47 W 10565.12 73.330 322.600 4821.61 4974.71 5385.07 N 6408.52 W 10666.58 72.810 322.590 4851.16 5004.26 5462.17 N 6467.48 W 10754.59 73.6.50 322.590 4876.55 5029.65 5529.11 N 6518.68 W 10855.84 73.340 320.920 4905.32 5058.42 5605.35 N 6578.77W 10951.00 71.130 319.870 4934.35 5087.45 5675.17 N 6636.53W 11039.22 71.320 319.720 4962.75 5115.85 5738.96 N 6690.45W 11134.78 71.910 320.310 4992.89 5145.99 5808.44N 6748.72W 11229.12 72.560 319.710 5021.67 5174.77 5877.27 N 6806.45W 11324.43 73.080 319.990 5049.82 5202.92 5946.87 N 6865.17W 11370.79 71.860 320.770 5063.79 5216.89 5980.92 N 6893.36W 11456.00 71.860 320.770 5090.32 5243.42 6043.65 N 6944.57W Global Coordinates Northings Eastings (~t) (~t) 5917230.70 N 454602.14 E 5917302.34N 454548.06 E 5917374.92 N 454493.38 E 5917452.33 N 454434.82 E 5917519.53 N 454383.98 E 5917596.07N 454324.28 E 5917666.19 N 454266.88 E 5917730.26 N 454213.29 E 5917800.04N 454155.38 E 5917869.17 N 454098.00 E 5917939.07 N 454039.65 E 5917973.27 N 454011.64 E 5918036.26 N 453960.75 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 310.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11456.00ft., The Bottom Hole Displacement is 9206.12ft., in the Direction of 311.032° (True). Dogleg Rate (°ll00ff) Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 1.47 8194.Ol 0.76 8281.72 0.91 8370.51 0.51 8465.38 0.95 8547.75 1.61 8642.92 2.55 8732.16 o.27 8814.56 0.85 8903.97 0.92 8992.55 0.61 9082.37 3.08 9125.91 0.00 9205.56 Projected Survey RECEIVED Continued... 13 September, 2000 - 3:23 -7- Cons. Anchor~e DrillQuest ZOO.02 Sperry-Sun Drilling Services Survey Report for 2N-318 MWD Your Ref: AP1-501032034300 Job No. AKMMO0130, North Slope Alaska Alaska State Plane 4 Kuparuk 2N Comments Measured Depth (ft) 11456.00 Station Coordinates TVD Northings Eastings (~t) (~t) (~t) 5243.42 6043.65 N 6944.57 W Comment Projected Survey Survey tool program, From To Measured Vertical Measured Depth Depth Depth (~t) (~t) (~t) Vertical Depth (fi) 0.00 0.00 308.97 308.96 308.97 308.96 11456.00 5243.42 Survey Tool Description AK-2 BP_CG MWD Magnetic- RECEIVED SEP 19 2000 13 September, 2000.3:23 .8 - STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ '13me extension _ Stimulate _ Other_X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 35 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Ser~ce_ Kuparuk River Unit 4. Location of well at surface 8. Well number 51' FNL, 719' FEL, Sec. 3, T9N, R7E, UM (ASP: 460874, 5911957) 2N-318 At top of productive interval 9. Permit number / approval number 90' FSL, 2229' FEL, Sec. 28, T10N, R7E, UM (per APD) 200-100 At effective depth 10. APl number 50-103-20343-00 At total depth 11. Field / Pool 709' FSL, 2374' FEL, Sec. 28, T10N, R7E, UM (ASP: 453960, 5918036) Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11456 feet Plugs (measured) true vertical 5243 feet Effective depth: measured 11351 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 16" 9 cu. Yds High Early 114' 114' Surface 2568' 7.625" 515 sx AS III Lite, 240 sx Class G 2603' Intermediate 10555' 5.5" x 280 sx Class G & 340 sx Class G 10590' Production 857' 3.5" (included above) 11447' Perforation depth: measured no perforations RECEIVED true verticalN/ASEP 1 4 Z000 i Tubing (size, grade, and measured depth 3.5", 9.3#, L-SO @ 10605',~u~aska Gl & Gas Cons. Commission Packers & SSSV (type & measured depth) No SSSV, Baker Seal Receptacle @ 10590" 13. Attachments Description summary of proposal m Detailed operations program LOT test, surface cement details and casing detail sheets __X 14. Estimated date for commencing operation 15. Status of well classification as: September 15, 2000 16. If proposal was verbally approved Oil mX Gas Name o~ approver Date approved Service _ r" 17. i hereby ;ertify that the foregoing is true and correct to the best of my knowledge. Questions? Call Torn Brassfield265-6377 Signed ~ ~,~t.,~,,,~ Title: Drilling Engineering Supervisor Date ,, James Trantham Prepared b~/ Sharon AIIsu~-Drake FOR COMMISSION USE ONLY Conditionsofapproval: NotifyCommissionsorepresentativemaywitness I Appr°valn°'~00 Plug integrity_ BOP Test__ Location clearance _ , Mechanical Integrity Test _ Subsequent form required 10- ~' ORIGINAL SIGNED BY A pprovedbyorderoftheCommission D Taylor Seamount Commissioner Date y/~"~~' Form 10-403 Rev 06/15/88 · ! SUBMIT IN TRIPLI CATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-318 Date: 8/13/00 Supervisor: R.W. SPRINGER Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8",29.7#, L-80 BTC-MOD Casing Setting Depth: Mud Weight: 2,603' TMD 2,310' TVD 9.3 ppg Hole Depth: Length of Open Hole Section: 2,630' TMD 2,328' TVD 27' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 800 psi 0.052 x 2,328' EMW for open hole section = 15.9 ppg Pump output = 0.1000 bps Fluid Pumped = 3.6 bbl +~PI~ 2,200 psi 2,100 psi 2,000 psi -- 1,900 psi 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 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi D~j~ --~" LEAK-OFF TEST --CASING TEST ..... ~---LOT SHUT IN TIME TIME LINE , , STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE i ..................... _2..s__t.k__s. ....... _2. .0_ _0_. _p_s_ ! .... ; 4 stks 600 psi ': 5 stks 800 psi ! ..................... ~-'~i'~ ....... '~6~-~-~i .... , .................................................... i ..................... _~__s__t~.s. ....... .s._s__o___p_s_! .... "'~1i 10 stks . 550 psi ~,~: 12 stks : 550 I1 ................................................... -~.,,~, 14 stks 550 psi , , 16stks ~r 550 ps' 4 i i i · i , ' j 18 stks ~ 550 psi i i ~ : 20stks : 550 , , · j 22 stks ! .5--2--5---P-S--L--J ll~ , , -,, ............... ~,____2__4._s__Lk..s...,....s..o..o.£..s.!...: ~, ; 26 stks 500 psi ................ , ................................. .................... _2__~__s_.Lk..s. ...... _s__o__o.__p_s_L.: 30 stks 500 psi .................... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... .3.._s!..k?..._j_._..3~.O.._R_s.i...J i 4stks i 750 psi i ................. ~ ............... t ................. '1 i i ' , , , 6stks , 1,000ps, , ' '8stks'''"'"---- -' ' ................. i , , . . , , , i , i , , 34stks . 500 psi : 36 stks 500 psi i : ' .................................. t ................. ~ I , , , SHUT IN TIME ~ SHUT IN PRESSURE ........................................................ '61i~'~i-ri'": ................... J I .....L'-' .......... ~ ........................... .~ .... ................................. ',' ................. : 1.0 min : 2,000 psi ................................................................. ; .................................................... ; .... ~'.i~'~i'ri'--r .................. ' I ................. ~. .............................. SHUT IN TIME SHUT IN PRESSURE .....3...O...m.j~_.., ................... .2.,.0..0.0_.R~... .... _o_:_o...m. Ln' ....................... ..s.o..o_._p.s.L_.i __..4:.o...m.j.n.___L ............... j..~,.o..o.o__p..s. Lj 1.0 min 400 psi J ._._a_:_o___m_!D.__ ................ i.__?__o_.o._.p_s.L.i ..__3_:9___m_Ln_ ....................... .4_o_.o__p.s_L.i ._._4_:9_m_Ln_ ...................... ?..o.9__p.s_L_j .___s_:_o___,Z,_Ln_ ....................... ~P..~_L..j 5.0 mini J 2,000 psi ""aT TrF't ................ ..... -'.' .......... I. ............... 4 ........... z ...... 7,0 min I 1,980 p_si _.._9:.o...m.j.n_.L .................. _I.,.~..6_o._R_s_L. .... _6_:9___m_Ln- ....................... .3_.9_.o...p.s.j__.j ~__].o_....o...m.j.n_._ L .................. .1..,.9._s_o._ R.s.i _, 7.0 min 390 psi ! 15.0 minj j 1,950 psi ' ................ ~, ................. ~ ................. 80min j ] 390 psi ..... ' ........................................... 4 ......-' .......................... 4 ........... ~ ...... 9.0 min .., , 390 psi 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-318 Date: 9/1/00 Reason(s) for test: Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE Casing Setting Depth: 2603' TMD Hole Depth: 8,004' TMD ! 10 stks 220 psi ] 4 stks 750 psi I ................ ' ................ ~ ................. t ............................................. ~' ...... 6 stks 1,000 Psi , 2310' TVD 4,197' TVD ! 15 stks 240 psi ~ - .~ : ................ I ................ ; ............. :---, 1,600p. si~ ~-'~ .tL,'~--~_. ,~' $'{/O/ .1~i ................ J----2--0--s--t-k--s---,"----2--5--0---P-S-~---i ................. 8,tk$ Mud Weight: 9.6 ppg Length of Open Hole Section: #VALUE! -~il 25 stks i 260 ps, ] '--'l'~'~'t'l~-" Leak-off Press. + Mud Weight EMW = 0.052 x TVD = 275 psi + 9.6 ppg .................... _3..5_.s__t.k_.s. ...... .2..7_.O.._p.s..i...j ................................................ 40 stks 270 psi 0.052 x 4,197' EMW for Open hole section = 10.9 ppg Pump output = 0.0580 bps Fluid Pumped = 5.8 bbl 2,200 psi 2,100 psi 2,000 psi -- 1,900 psi 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 800 psi 700 psi --.e=.. LEAK-OFF TEST "-a--CASING TEST ....... ~...~. LOT SHUT IN TIME -~,~ CASING TEST SHUT IN TIMF 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi! 0 psi i STROKES 45stks , 270 psi ! ................ -I ................................. 1 i i · i : 50stks : 275 ps, .................... _q_~_.s_!k..s. ...... .2_Z.S...Rs.,_._i .................... _6..o_ ?._t.k_s_ ...... .2_Z.S..Rsj___j ..................... _6..~_?_!~ ...... ~Z~_._Rs_L.j ................ ]_.__7..o.~_tk_~..L..2_z.~_._p?_L..i 75 stks 275 psi i : .................... ii6-~ii~; ...... ~k--b'~i'"; ::::::::::::::::::::::::::::::::::: ................. I ................ ................. - ................ 95 stks 275 ps~ I i ................ ,J- ............... .~ ................. .~ I I 100 stks i 275 psi i SHUTIN TIME SHUTIN PRESSURE i .................................................. , ................. ................................. i ................. iI-----°-'-°---m--i-n----~ .................. ~:-°--°--°--P--S-Li J j1.0 min 2,000 psi j : ; ,__..2:.o.._m_j.n_ .................... ............. _ _s_..u_ _T_,_,_ _T_,~ _E ] ............... _S. _._U.T_.,.,..P..,~ _S.S.U_ _,.~ .3..9___m_j.n' ..................... .2.,9_.o9_R~:_~ 0.0 minj 275 psi 4.0 min 2,000 psi ................ ~ ................ ~. ................. .~ ................. 1.0 min : ____3_:_o___m_].n. ........................ .2_.2_.o_._p_s.] .... _.4_._o___m_Ln- ........................ ~.o...p?] .... ...~:.o___m_Ln- ........................ .2..2..o...p. sj .... .... .6= 9. _ .m_ ! p_ ....................... .2.?..o...pR] .... ___Z:p__.m_jp_ ....................... .2__2__o_..p.s] .... ....8_:9.__m_!p_ ....................... .2_.2_9...P~] .... ____9_:p...m.!.n_ ....................... ?_?__o_p~j .... 5.0 min 2,000 psi 60min , 2,000Dsi , .... :.'.' .......... L ........................... · ..... __.?_._o___m__i.n. ..................... !:.~..8_o__R.s. Lj ..9_..o_._m_j.n. ..................... _!,?Z..O.p..s_L] ...9:.o.._m_].n_ .................. j._!.,_~9..°.P_S_[_] ....l_O...o._Dj.n. .................. L ..1.., .9..s..°. P..S.L j 15.0 min j 1,950 psi i ................................. 1 ................. __.ag..9_m_j.n___~ ............... .___2_5:.o_m. j.n_ .................. i..j.,~.5.9_p..s.!.j ,__2_o_.9_.m_Ln. ...................... _2__2__O___p_s_i ....... _39:_o_._mj.n' .................. L_!,~.9.o._p_~L] NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-318 Report Date: 08/11/2000 Report Number. 5 R~ Name: Nabors 1gE AFC No.: AK 0058 F~eld: Tarn Centrallzem State type used, intervals covered and spacing Comments: 29 bow spring, its 1-12,15,18~1~4,27,30,33,36,39,42,45,48,51 ,b'7,60 Mud Weight: PV(prior cond): PV(after cone0: I YP(prior cond): YP(atter cond): Comments: 10.2 23 19I 26 19 Spud Gels before: Gels after: Total Volume Circulated: ' 12/20 17/75 1-1/2 hole volumes WaSh 0 Type: Volume: Weight: CommentS: ARCO B47 20 bbl 10.2 · , Spacer · 0 Type: Volume: Weight: Comments: ' ARCO B45 40 bbl 10.2 : . I~eadCement :0 ''Type: I Mixwtrtemp: No. of Sacks:I Weight: Yield: 'Comments: AS III Ute , 75 515 10.7 4.43 Additives: . .' i:. · · .,' · " " Additives: · : ~ ~ "' G W/1%S1 +.3% D65 +.2% D46 .' . . '.:..: . DisPlacement..'0 .... Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: · , , 6BPM 6 BPM : · Reciprocation length: Reciprocation speed: Str. Wt. Down: · ' . : . 10'. ~ 1 SPM . · . ' . ', · . Theoretical Displacement: Actual Displacement: Str. Wt. in mud: . . . 115.5 BBL 115.5 BBL Calculated top of cement: CP: Bumped plug: Floats held: CMT TO SURFACE Date:8/12/00 YES YES Time:1030. Remarks:GOOD· CMT TO SURFACE @ 395 BBL INTO MIXING AND DISPLACEMENT. CEMENTED USING TWO VACUMN TRUCKS TIED INTO CONDUCTOR TAKING MUD RETURNS AND EXCESS CMT TO VACUMN TRUCKS. FULL RETURNS THROUGHOUT. , Cement Company: Rig Contractor: IApproved By: Dowell NABORS I R.W. SPRINGER RECEIVED SEP 14 000 Aiaska 0i'; & Gas Cons. C0mmi~0n PHILLIPS Alaska, Inc. Casing Detail 7-5/8" surface casing WELL: 2N-318 DATE: 8/11/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.50' TOPS Above RKB 4.54 7 5/8" Landing Joint (38.97 total) 34.50 4.54 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.43 39.04 jts.38-61 7 5/8", 29.7#, L-80 BTC-MOD 1003.16 41.47 Tam Port Collar 2.43 1044.63 jts 3-37 7 5/8", 29.7#, L-80 BTC-MOD 1469.94 1047.06 Gemeco Float Collar 1.33 2517.00 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD - 83.26 2518.33 GemeCo Float Shoe 1.50 . 2601.59 BTM OF SHOE @ ..... >>>>> 2603.09 TD of 9 7/8" hole = 2610'MD 29 TOTAL', Gemeco Bow Spring Centralizers 3, Centralizers in center of its; 2, 37 and 38 over stop collars 26 ,Centralizers over collars of its. 1 ,. 3-12, 15, 18, 21, 24, 27, 30, 33 36, 39, 42, 45, 48, 51,57, 60 · . · . mc:r, ¢::n,,l:::D ~O[,,.r i~i. LVVV Aiaska.Oi'~ & Gas Cor~s. ~,~missio, ^nchom.~e , Remarks: String Weights with Blocks; 79 k Up, ??k Dn, 15k Blocks. Ran 61 joints of casing. Drifted casing with 6. 750" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Four joints surplus. PHILLIPS ALASKA INC CASING TALLY PAGE: 1 of 2 WELL: 2N-318 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 8/11/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 41.46 26 42.34 51 43.73 76 101 126 151 176 2 41.80 27 40.31 52 43.17 77 102 127 152 177 3 41.82 28 41.52 53 43.28 78 103 128 153 178 4 42.52 29 42.42 54 43.30 79 104 129 154 179 5 42.82 30 42.65 55 33.88 80 105 130 155 180 6 40.49 31 42.92 56 43.24 81 106 131 156 181 7 43.67 32 43.17 57 43.05 82 107 132 157 182 8 40.82 33 42.65 58 43.25 83 108; 133 158 183 9 43.73 34 42.59 59 39.95 84 109 134 159 184 10 42.37 35 41.41 60 42.23 85 110 135 160 185 11 42.83 36 42.62 61 36.49 86 111 136 161 186 12 43.77 37 39.00 62717~?ii~ii~?ii!ii~', 87 112 137 162 187 13 41.67 38 42.40 63 i?~iii~i~iii?~i 88 ,113 138 163 188 14 42.88 39 40.65 64i!ii!ii!i!!i~iiiiii?!i 89 114 139 164 189 15 42.47 40 43.15 65 ?~iii?~i??~i 90 115 140 165 190 i'1'1'1'1'1'1~1'1'1'1'1'1'1'1'1'1'1'1'1· 16 42.22 41 43,80 66 91 116 141 166 191 17 42,60 42 42,46 67 92 117 142 167 192 18 42.69 43 41.18 68 93 118 143 168 193 19 41.64 44 41.98 69 94 119 144 169 194 20 39,84 45 42.61 70 95 120 145 170 195 21 41,34 46 36,46 71 96 121 146 171 196 22 39,32 47 42,37 72 97 122 147 172 197 23 42,62 48 43,18 73 98 123 148 173 198 24 39,63 49 43,17 74 99 124 149 174 199 25 42.58 50 44.18 75 100 125 150 175 200 Tot 1049.60 Tot 1051.19 Tot 626.48 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2727.27 TOTAL JOINTS THIS PAGE = 65 DIRECTIONS: Float Shoe = 1.50 Float Collar = 1.33 Stage Collar = 2.43 Fluted Hanger = 2.43 PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 2 WELL NUMBER: Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 8/11/00 Column9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254! 279 30~ 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 33Z 359 ~384 210 235 260 2851 310 335 360 385 211 236 ~261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313! 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340! 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 ~295 320 345 370 395 221 246 271 i296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 2727.27 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 65 Average Jt = 41.96 DIRECTIONS: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, '~,:,~,, DATE: Chairman ,~'./ ~ THRU: Blair Wondzell, ~ ~-~o~ P. I. Supervisor FROM: Jeff Jone~f~F~-- SUBJECT: Petroleum~ln§~tor August 7, 2000 Diverter Function Test Nabors 19E Phillips 2N-318 'Tarn Field/KRU Non-Confidential Monday, Au_qust 7, 2000; I traVeled to Phillips Alaska Inc.'s Tarn Field to witness the Diverter Function Test on~el[~#:~2N:'3'iS~ where Nabors Rig 19E was rigging up to spud. The rig was fairly close to being Completely rigged up. The layout of the 16" vent line was such that it provided for down wind venting of the gas and allowed for escape from the pad if necessary. The gas detectors were tested during the function test and operated properly. The Nabors crew performed the Diverter Function Test in a safe and proficient manner. The vent line was not tied down when I arrived, but this was accomplished while I was on location. I found the rig and the surrounding area in satisfactory cOndition. SUMMARY: I witnessed a successful Diverter Function Test on NaborS Rig 19E drilling development well # 2N-318 in the Tarn Field, Kuparuk River Unit. No failures witnessed, test time: 2hrs. Attachments: DVTRINSP Nabors19E 8-7-00 JJ cc:. Morrisson; Overstreet (KRU Drilling Supervisors) NON-CONFIDENTIAL Dvtrinsp Nabors19E 8-7-00 JJ.doc STATE OF ALASKA( ~ ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Drlg Contractor: Nabors Alaska Rig No. Operator: Phillips Alaska Inc. Oper. Rep.: Well Name: 2N-318 Rig Rep.: Location: Sec. 3 T. 9N R. 7E Date: 8/7/00 X Exploratory: O0 1000 Rig Ph. # 263-3140 Ray Springer 19E PTD # Jerry Otto Merdian UM. MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: P Well Sign: P Systems Pressure: 3250 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1600 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: 0 min. 25 sec. Systems Pressure Attained: 3 min. 40 sec. Nitrogen Bottles: 4 @ 2050 psi avg. DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: P Vent Line(s) Size: 16 Vent Line(s) Length: 85 Line(s) Bifurcated: N/A Line(s) Down Wind: P Line(s) Anchored: P Turns Targeted / Long Radius: N/A in. psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: P P ft. Mud Pits: P P Flow Monitor: P P GAS DETECTORS: Light Alarm Methane P P Hydrogen Sulfide: P P CAMP North/~ RIG wind direction 85' Diverter line South Non Compliance Items 0 Repair Items Within N/A Remarks: 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.: OPERATOR REP.: VOoa84is. xls Jeff Jones DVTRINSP.XLT (REV. 1/94) IPHILLIPS Alaska, Inc. StruchJre: Torn Drill Site 2N Well: 318 Field: Tarn Development Field LoQ~lon: North Slope, Alaska RECEIVED JUL 0 7 2000 Alaska 0;'; A Gas Cons, Commission Anchorage 1400 0 11oo z <- West (feet) 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 go0 800 700 600 500 400 ~)0 ' 1900 1900 (~""-..~.~o ~ . ,. ~( \ \~,oo ,,- ',,.,~oo -.,~,oo .,,~,oo \~,oo7~o.\ 4800 17OO -.... .. ',, \ 1700 4700 O0' ' ', 2200 . ,,oo -... -,,,, '.. · ,,, .\ ~ ,,jooo "00' 4~oo '-.~oo "x3,oo '-, · ,,.~30o \2ooo\ \ .oo -..... ~ ~oo '... \ \~,oo ,,- o -...., ",..5\ \ 2300 .~0 ., ~ 5000 ,, ~ ~ ' ~.~o -.... X....~.,oo .,, \ ,,o; ~° =o -.~. ~o~ -..... ... \ \ ,ooo -...,,oo-,,,..... ,,oo,, \ \ '-. o'",~,. .... '. \ \ ~soo ~ ''''.. 220 6~ .,z'~uu ', \ \ -,,,, -~. ~.--- ~-,. '.,\ \ .ooo ~oo~ --,.,~',, ..\,,=\ 2200 "~900 ',. ,, ~, _ ., .__%._ ,. ,, \~7oo \ 3400 ',. ~ '.. .,5oo',,,.',,,,,,,.",k \ ,00 3400 2,oo 33oo ~ ",.2,oo'; 2ooo' 3300 ~ -~- 2 ) .... 3200 ~ I soo soo 2600 3200 2000 " '~k 1900 3100 2500 O0 ,, ~ 1600 700 70o .. 2400 1900 3000 ' - ~,' ' ' ' -.2400 5000 ~300 1800 2900 600 600 - ~ 2500 2400 2300 2200 2100 2000 1 g00 1800 1700 16oo ! 500 f 400 1300 1200 1100 1000 go0 800 700 600 500 400 <- West (:feet) 1500 1400 A I 13oo Z 0 lOOO 320 300 280 260 240 220- {~ 200 . 180 - . 160 - 140 2100 1500 2000 120 ' 100 - 80 0 60 Z 4O 2O 2O -L1200 100 800 1400 '---.o 1100 800 700 7OO 600 6O ~320 300 280 260 240 PHILLIPS Alaska, Inc. Structure: Torn Drill Site 2N Well: 3t8 Field : Torn Development field Loooflon: North Slope, Mask( RECEIVED JUL 0 7 2000 Alaska 0{-; & (~as Cons. Commission Anchorage <- West' (feet) 220 200 180 160 140 120 100 80 80 40 20 0 20 40 60 80 --.... , '-... 1ooo ' ~ ~oo '-J-~ .._~ ~, '~ 1 t00 ,~ 1900 ' ~ ~ ' ' -~ ' ~ , 1000 ~~ ~oo '~ ~ ~~ ~.oo ooo,-... ' ~ ~ ~ N. oo -,, ', X~.oo-',, ___ V°° ~.oo ~ q~ · '-, .oo ',,~o -,, ~ ~~.oo --,,.'~ ,o~,,oo X, oo .~ ~oo .~ ~oo -,,~oo ~. ~ 300 ~%~ '. X ~.~' ~ 6oo ~ soo --. ,ooo ~ ~ ~oo ?oo~~o,, -..roe ~o, -:- _:~ ~oN~oo ---_.._~ ,~oo ,,. ~~,.__ -'..,oo ~oo 400~ 700 300 600 600 300 ~oo 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 <- West (feet) I0O 1oo -220 20O 180 160 140 120 I loo Z 0 80 so 4O 20 20 4O 60 120 a~ For: Dole Moiled ~ "~:~ 960 920 880 840' 800 720 680 640 2900 600 ,560 2800 520 I 480 '.4,-- ~.. 440 '1~ 400 0 560 1600 ~20 280 240 - . 200 - 160 96{3 1800 760 720 680 2000 2200 1700 - - - _. 1900 920 880 840 800 7SO 2700 720 PHILLIPS Alaska, Inc. StnJcJure .' Torn .D~III SHe 2N Well t 318 Field: Tam Development field Lo(~otlon: Nor'ih Slope, Alaska <- West (feet) 640 600 560 520 480 440 1500 1900 RECEIVED 2100 JUL 0 7 ?_000 Alast~a G~ a ~as [;ons. ,;ommission Anchorage 400 360 320 280 240 200 160 120 80 ~o 68O 640 · 2200 x,~ 1800 ",, ~ 600 1600 18~' x ~ ~ 560 '- ', h '. 1700~ -520 - ', X ,, k,,°° . ,.;y. ,.oo-., ', , qy~ x k o 360 1 1400 1 520 18~ 25~ ~ 280 1400 1500 1700 1400 ' ~ 1600 240 1900 1600 2100 '%,1300 2O0 '000 680 640 600 560 520 480 <- Wesf (feet) 440 400 360 320 280 240 200 180 120 gu 160 3600 RECE!VED PHILLIPS Alaska, Inc. lC,earedW tbeb For: T Brassfleld I ~ 0Jotted .* ~9.~m-~o I Sh'uch]ro: Torn DJ'HI Silo 2N Well: 318 pbt tu~,,m,,ce b 318 vt,.bfl IS. I gJeld: Torn DoveJopmo,'~ gfeld Lo~2flon: NorJh Slopo. Alaska Coo.fbM~eo ~e v. feet ~ dot f3ts. I ,u Wt~o, ~DI,= ml~, mCB(14abo,s t001 I ~ I JUL 07 2000 Alaska 0~i & Gas Cons. Commission Anchorage <- ~esf (feel) 460O 3200 · 5000 ~ ~ 30 · 4800 · ' 3000 '\ ~3400 4600 . \ · . ~3000 2800 % % \ ~ 2800 . 5200 ~ · . ~ 2800 · 4000 . 380O 3600 32OO 3600 3OO0 3800 56OO 28OO 2BO0 320O 26oo 2400 - ~000 3000 2600 ~400 3000 1800 3200 4400 2600 4000 3800 3OOO A 26oo I 22OO 2OOO 1800 1600 1400 ' ,= 3000 1400 4600 ". 3400 4200 3200 -~, 3800 lO00 4800 4600 4400 4200 4000 3800 ~500 3400 3200 3000 2800 2600 2400 . 2200 <- rest (feel) 1600 1400 1200 1000 ~30 400 56OO 52O0 ^ I 4soo 4000 - 38OO 36OO 32OO PHILLIPS Alaska, Inc. Sfructure: Torn DHII Site 2N Well: 318 Field: Tarn Developmefl! lrleld l. ooaflon: HarSh Slope, Alaska RECEIVED JUL 0 T ; 000 A~aska 0[-~ & Gas Cons. Commission Anchorage <- West (feeO 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 6800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 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 - ,. 5..200 ' ' - - .,.5ooo 4800 ', · 4400 ., ~ 4000 00 ' ~ ,. ,, '., 4000 ' -...4800 , , ' ' "" -. ~ 5200 ' ' ,, 3800 ' ' ",,, 4600 -, · ,~ 4400 · · 4800 4200 4OOO 4600 ,. · , '~3600 ~',.%4200 4600 % % · 4400 · 4000'~ · % 4200 · · % · · ~ 3800 · % % · 38OO 3400 · ~00 5200 · % % % · 7800 7600 7400 72130 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 .3600 <- West (feet) 56O0 52OO 5O00 46oo Z 0 46oo 23. 4400 ~ ,-I- 42OO 4OOO 3BO0 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-318 Reason(s) for test: Date: 8/13/00 Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Dee'p. Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8",29.7#, L-80 BTC-MOD Casing Setting Depth: 2,603' TMD Hole Depth: 2,310' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 2,63O' TMD 2,328' TVD 27' EMW = Leak-off Press. + Mud Weight -- 800 psi 0.052 x TVD 0.052 x 2,328' EMW for open hole section = 15.9 ppg + 9.3 ppg Pump output = 0.1000 bps Fluid Pumped = 3.6 bbl I,M 2,200 psi 2,100 psi 2,000 psi -- 1.900 psi 1,8(]0 psi 1.700 pst 1,600 psi -- 1,500 psi 1.400 psi 1,300 psi 1,200 psi 1.100 psi L000 psi 9ao psi 700 psi 500 psi 400 pst 300 psi 200 psi 100 psi __ '"e--LEAK-OFF TEST ::; I --,,-CASING TEST I I I I I I I ~ ~ ~- LOT SHUT IN TIME j:~!.!'~i!~:~i~!.:,!:?i~.. ~-' CASING TEST SHUT IN TIME I TIME LINE · IIII IIII I~l IIT~ ....... 1111 . rll , , 0pd STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................ L....o_sj.k.?. ........ .o..p.?j. .... j 2 stks 200 psi ! 4 stks 600 Esi ................ ~__...s..s.!.k..s. ...... .s..o.g...p?.L.' ................ ,~....S..s..t.k..s....,....S..0..0...p.s.!...~ ! 8stks 550 psi , ................ i _ _~.9..sjks. ..... ................ i...t2_.s.!ks. ...... J 14stks ....5..5..0. ~.s..i.. ~. ~ 16stks 550~si ' ................ :'"i'[~'~ii~ ..... g§if p'~i .... :::::::::::::::::::::::::::::::::::::::::::: j 22 stks 525psi ................ · 4- ............... ~ ................. j 24 stks 500 psi j 26stks 500 psi ! .., ............. ~...~.S.~!.k..s. ...... .s..o..o...p.?Ei ................ i..?..O_~!.k.?. ..... ~9..e~!...i ................ i..?..2..s.!~ ...... .s..o..o_Rsj... ........... : .... i..?..4.~!.k.~ ...... ~9.e~!...) ! 36 stks 500 psi , , , , , , i , , ! , 4 I I ! 1 SHUT IN TIME j SHUT IN PRESSURE 10min i ! 400Bsi~J .... .' .......... .{. ............... f ................ · , , ' 2.0mm , , 400~s~ · ...... , ........ + ............... t ......... ~' ...... 3.0min i I 400psi ! ................ ~- ............... -~ ......... -'- ...... _?.:.°...m. Ln...i ............... L--4--°-RP--~!---I 5.0min i. . i 390 psi l ................ · 4- ............... '~ .......... %' ...... 4 ! 6.0min ! I 390 psi i i ................ -L ........... ....~ .......... '........a l' 70min i i 390osi ! I ..... : .......... + ............... f .......... ~' ...... ~ 80min ~ ;. 3900sJ I l ..... : .......... 4- ............... ~ ......... -~ ...... I * I I , g. O m~n ,, , 3gOB. t I ................ ~- ............... ~ ......... ~:' ..... 4 i_.Lo.-..o...m. Ln_i ............... i_...3.~gP_S.i...l CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... iF~;'[,'~'"! ..... 6'i~;f ..... ..................... ~..s!_k.s....j.._.3~.O..R.sJ.._, 4stks ~ 750~si ............. '": .... iF~i-[,'~"".,'"g~6'~ ~i" ..................... , ' , .... .......... .-.,, ................................ 4 I SHUT IN TIME SHUT IN PRESSURE · , , * OOmm , , 2.000om , ...... '- .......... ~- ............... 4 .... : ...... .r. .... 4 1.0 min .! 2,000 osi j ..._2:.o...m..i.,. ................... l...2.:.o..o.o..! .._~.:.o..m'.,.n.... i 2,ooo ~ .....~...o..~.i?. .... :::::::::::::::::::::::::::::: 5 0 min | 2,000 p. si l 6 0 min / !2,000 osi I ..... :-'~ .......... ~. ............... 4 ........... r. .... _ . . ?:.o. . .mj.n. ................... l...',.:?_,.o..p.~L! 8,..0 minj ! 1,970 psi j 9.0min [ ] 1,960 psi j ,'-'i'aEi:i'fifiii~"[ ............... i"~'7~'~'~';;['i ,... ......... ....&. ............... d ........... · ..... 15.0 min j 1,950 psi j ............ '~----r ............... 1 ............... ;-3 200m~n I ; 1,9500s~ ~ ......25.0-' .......... min ! ............... ;~' ........... 1,950psl ~' .... ' ~' "'~'6:~'~;~"[ ............... 1'"~:b%'6'."[i'1 ................. . ............... ., ........... ~ ..... 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-318 Date: 911100 Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test Reason(s) for test: [] Formation'Adequacy for Annular Injection ;~: [] Deep Test: Open Hole Adequacy for Higher Mud Weight ~~. Cc~ing S~and Description: 7-518",29.7#,L-80 BTC-MOD ~=~ ~._.,'13 COg Setting Depth: 2603' TMD · ~o ,~ Mud Weight: 9.6 PP9 rn EMW ~:~_eak-off Press. + Mud Weight --0.052 x TVD LEAK-OFF DATA MINUTES FOR LOT CASING TEST DATA STROKES PRESSURE j ................ T'"~/'~ii~['"i""i~i~i}]~.F! Hole Depth: 8,004' TMD ! 10 stks 220 psi i ~,~"~-5' j ............. 'T"i'~'~ii~~ ...... ~i~,-'/,'~i'"~, / , ................ -I- .................................. i J 20. stks 250 psi Length of Open Hole Section: #VALUE! -JJ~? j 25 stks 260 psi j = 275 psi + 9.6 ppg 35 stks 270 psi 0.052 x 4,197' EMW for open hole section -- 10.9 ppg Pump output = 0.0580 bps Fluid Pumped = 5.8 bbl 2,200 psi · 2,100 psi 2,000 psi -- 1,900 psi -.e-- LEAK-OFF TEST --e--CASING TEST ~_~._ LOT SHUT IN TIME ~ CASING TEST SHUT IN TIMF , 1,800 psi .4..O..s..t.k..s... 270 psi .................... .................... .5..o.?..t~.s. ...... ~Z.5.£~L..i 55 stks 275 ~si j .................... _6..5. ?..t.k_s. ...... .2..7..5. 70 stks 275 psi ................... ....... ::::::::::::::::::::::::::::::: .................... .~..5.?.!~?. ....... ~Z.5..p..sJ...j ': ................... .~..0..s..t.k_.s. ....... .2.Z.5...p?.L.j 95 stks 275 psi j ................... i'ii6-]ii~'~- ...... '~"~'~i'"i , I SHUT IN TIME SHUT IN PRESSURE 0.0 min '275 psi | ._.l.:.O...m.j.n. .................... 240.1E. si' ] ..~:.o...m. Ln. ................... .................... ....s.:.o_.mj... ........................ ~.o.~!._.] 6.0 min 220psi j 70rain i i 220psi ..... : .......... 'l- ......... ~ ..... ~ ......... -'- ...... 8.0mln' ', ', 220os1' I ................ '1- ............... ~ .......... "' ...... · I I i I 9.0m~n ~ ~ 220psi ; .., ........... ..~- ............... ? .... . ........ ~--- 1,700 psi 1,600 psi STROKES 1,500 psi 1.400 psi 1,300 psi 1.2a0 psi 1,100 psi 1,000 pSI ~ psi 800 pd 700 psi 6EX] psi 500 pd 400 psi 300 psi 2~0 pa 100 psi Opsl, MINUTES FOR CSG TEST STROKES PRESSURE .......... , ......... ..... ..... ::::::::::::::::: :::::::::::::::::::::::::::::: 4stks ! 750p. si | ................ ,' ............... ['-'~'~'t'f,'~"'j"i .......... , ...... ~ ............... , ............. ................. t ............... ~ .............. J r ............................... ~ r ................ r ............... ! .................. SHUT IN ~ME ! SH~ IN PRESSURE ?-. ........ = .... t ............... ~ .............. =-3 0.0mm ~ ~ 2,000pm ~ ~ .............................................. ~'1 10min [ ~ 2,000Es~ ~ ....:: .......... ~ ............... ~ ................ 2.0rain I ~ 2,000~ ::::::::::::::::::::::::::::::::: ,...~:~.~ ................... L&~.~. 5.0 rain i 2,000 Esi ................... 8.0 min ! 1,g7Opsi ...~Z~ .................... ..~.,~.~.~[..= · = 10.0 min 1,950 Ds~ , 15 0 mini 1,950 ~si i ...... : ......................... ~ ........... ' ..... I 20.0 min[ 4 1,g50Esi4 :::::::::::::::::::::::::::::::::::::::::::::: NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 2 WELL NUMBER: Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 8/11100 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet' 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 , 253 278 303 328' 353 378 · 204 229 254 279 30z 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 3061 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 2591 284 309 334 359 384 210 235 260 28~ 310 335 360 385 211 236 2611 286 311 1336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 '338 363 388'. 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365' 390 216 241 266 291 316 '341 366 391 217 242 267 292 317 342 367 392 2181 243 268 293 318 343 368 393 219' 244 269 294 319 344 369 394 ... , , 220 245 270 295! 320 345 370 395 221 246 271 2961 321 ·346 371 396. 222 247 272 297 322 347 372 397 223 248 273 298 323. 3481 373 398- 224 249 274 299i 324 3491 374 399 225 250 275 300 325 3501 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 2727.27 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 65 Average Jt = 41.96 DIRECTIONS: ALASILA OIL AND GAS CONSERVATION COPlPIISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 27%1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips. Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2N-318 Phillips Alaska, Inc. Permit No: 200-100 Sur Loc: 5 I'FNL, 719'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 212'FSL, 2597'FWL, Sec. 28, T10N, R7E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional 'permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this j ~ ~ day of July, 2000 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 [~] Redrill D I lb. Type of well. Exploratory D Stratigraphic Test D Development Oil [~] Re-entry D Deepen DI Service D Development Gas D Single Zone [] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation ,,;~7~'~7~-,-~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 380054 ALK 4602 ,,~ Tarn Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 51' FNL, 719' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 90' FSL, 2229' FEL, Sec. 28, T10N, R7E, UM 2N 318 #U-630610 At total depth 9. Approximate spud date Amount 212' FSL, 2597' FWL, Sec. 28, T10N, R7E, UM July 20, 2000 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD a~nd TVD) S?5-/O~'~b 2597 @ TD feet 2N-317 14.8' @ 300' feet 2560 11306' MD/5425 ' TVD 16. To b~ completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 70.13 Maximum surface 1890 psig At total depth (TVD) 2400 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTCM 3202' 35' 35' 3237' 2300' 330 sx AS III L & 240 sx Class G 6.75" 5.5" x 15.5# L-80 LTC Mod 10370' 35' 35' 10405' 4908' 630 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 901' 10405' 4908' 11306' 5425' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate REOE!VED Production dUk 0 ? I 000 Pertorationdepth: measured~-~la$~l ~ & C~aa ¢on~. ¢ommi~ion true vertical 20. Attachments Filing Iee[] Property Plat [-1 BOP Sketch I'~ Diverter Sketch [~ Ddlling program Ddlling fluid program ~ lime vs depth plot [-]Refraction analysis ~ Seabed report I'~ 20 AAC 25.050 requirements 21. I hereby ce~ ht that the foregoin§ is true and correct to the best o~ my knowledge Ouest~ot~$? Call Tom Brassfielcl2$~-~$7'. James rrantharn Preoarecrbv Tom Rrassfielc Commission Use Onl} Permit Number~ /~)~) I APl number I I Soo c°ver letter '-- 50- /~)..~ -' ~-~'V~=~- ~ Approval da.~,~,, / ~ ~,4~/,~ Ifor other requirements Conditions of approval Samples required D Yes J~ No Mud log required D Yes C~ No Hydrogen sulfidemeasures D Yes ~_ No Directional surveyrequired ~' Yes D No I-I M; EI( I-1 I--I lou;l--I Required working pressure for BOPE E] Other: ORIGINAL SIGNED BY Approved by D Taylor Seamount by order of Commissioner the commission Date "q "" / '~'~---"~ .... Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc. Well Proximity Risks: RECEIVED The nearest well to 2N-318 is 2N-317, The welts are 14.8' from each other at a depth of 300' MD. This welt does meet with the Phillips ellipse separation criteria, The well which does not meet this criteria is 2N 316. The ellipse separation at 1180; MD is 19.3'. To mitigate this risk, 2N 316 will not be perforated when drilling 2N 318, JUL 0 7 2000 Alaska G'~ & Gas Cons. Commission ~horage Drillinq Area Risks: One identified risk in the Tarn 2N-318 drilling area is the shallow gas hydrates below the permafrost. To date the hydrates encountered while drilling the Tarn Phase 3 wells 2N 347 & 2N 332 have been minimal. Standard SOP's have been developed to minimize the hydrate impacts i.e. maintaining Iow mud viscosities, pre-treating with Driltreat (Lecithin) and DriI-N- Slide, using cold make-up water for the mud, control drilling, and optimized flow rates. The surface hole will be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. 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. Recent information has indicated the possibility of gas migration from the reservoir to a shallower sand interval. However, NO overpressured zones were encountered while drilling 2N-347 or 2N-332 wellbores. Log, tracer, pump-in test, and offest BHPBU evaluations indicate any migration has occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4428' TVD, the highest required MW would be 10.4 ppg. Annular Pumpin_~ Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected 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-318 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. Following drilling operations, Phillips Alaska, Inc. will submit application for approval of 2N-3t8 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 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 Phillips Alaska, Inc. ('''~ 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 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 i5,483 psi 5W' 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 15,950 psi 3Y=" 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). RECEIVED JUL 0 7 2000 A~aska O~ & Gas Cons. Commission An~omge {':~:~ Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N-318 1. Move in and rig up Nabors 19e. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top Job will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill ~"xT--tJ2" hole to TD according to directional plan. Run LVVD logging equipment with density and porosity tools. , 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)(0). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" 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. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TWC, ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Handover well to Operations Personnel. RECEIVED JUL 0 7 2000 Alaska 0~, & Gas Cons. Commission Anchorage . LEAK OFF TEST PROCEDURE Tarn After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the PAl LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 5/19/00 RECEIVED JUL 0 7,0000 Alaska 0~{ & Gas Cons. Commission Anchorage ( Phillips Alaska, Inc. ( DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-318 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~l point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 _+10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% RECE!VED JUL 0 7 2.000 Alaska 0ii & ~as Uo~]s, Commissi~ A~chorage Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *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 reservoir pressure of 2400 psi at a target mid-point of 5096' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MAS P=((2400/5096)-0.1 )*5096 MASP=1890 psi Therefore PAl will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be ~2,400 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.62 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5096'. Target (Midpoint T2 T3) (2400+150)/(0.052'5096)=9.62. 400 4O0 1200 1600 2OOO 24OO 28OO 32OO 36OO 480O 56OO IPHILLIPS Alaska, Inc. Siruofurs: Torn Drill Silo 2N Well: 318 Field: Torn Development Fleld Lo<~llon: North Slope, Alosko RKB ELEVATION: 15,5' .5 O0 KOP ~,:oo 9.00 DIS: 3.00 (:leg per 100 fL 12.00 . Begin Build/Turn 18.00 21.00 Port Collar .- . 24.00 DLS: ~.O0 deg per ]~,; ~t 2~gBOSe Permafrost 308.6 AZIMUTH :~2'~"T°pWS°k 8697' (TO TARGET) 44.99 50.9o ***Plone of Proposol*** ~ 56'9692.99 Bose W S0k "'"' RECEIVED C80 MAXIMUM ANGLE ----..~- c~p ss 70.13 DEG ~~ J, UL 0,7 2000 ~ Alaska Of; & Gas Cons. ~Jomrnission Anchorage C40 ~ c37 ~ - . . ~ DLS: 2.00 deg per 100 ft Begin Drop/Turn ~ 69,32 Iceberg ~ 65.%.32 T7 61,07 58.94 56,92 55.05 TARGET ANGLE 55 DEG m - cos~.g Pt ~ 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 Verficol Section (feet) -> Azimuth 508.60 wifh reference 0.00 Iq, 0.00 £ from 8! 6000 55OO 5OOO 45OO 4OOO A 35o0 ~ 3ooo (D 25OO '~' 2Ooo - 15oo lOOO 5OO 500 [PHI___ LLIt>S __Ala_sk___a, I__nc. Struature ; Tarn Drill Sit~ 2N Well : 318 Field: Torn Development Field Loccgion : North Slope, Alaska <- Wesf (feel) X) 8000 7500 7000 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 1500 1000 500 0 500 10 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 '~ / ~'- 8697' (TO TARGET) ~o'~' ~ ***Plane of Proposal*** RECE.VED SEC. 28, TI ON, RTE I ~ TARGET LO~TION: ., ~ ~ . , [o . ~SL, z~,.'°~k I ~ ~ka ~i a Gas Cons. commiss,on SEC. 28, TI ON, RTE I ~ ~cho~ge '~ I SURF~E LO~TION: I I 51' FNL, 719' FEE I I SEC.~.~gu.~z~ ! .~' ~0 7500 7~0 6500 6000 5500 5000 4500 4000 ~5~ ~0 2500 2000 ~ 500 1000 <-- West (feet) 6000 5500 5000 4500 4000 3500 . -3000 . -2500 -2000 1500 1000 500 500 RECEIVED JUL 0 ? 2000 Alaska 0~-; & 6as Cons. Commission Anchorage I I ~ ~: ~-~ PHILLIPS Alaska, Inc.] Stru~qure: Tom Drill SHe 2N Well: 318 Field: Tam Developm®~f Field Locoflon :.-No~th Slope, Ak~kaI PROFILE COMMENT DATA Point KOP Begin Build/Turn Port Collar Base Permafrost Top W Sak Bose W Sok EOC 7 5/8 Casing C80 Comp SS C50 C40 C57 Begin Drop/Turn Iceberg T7 EOC T3.1 T5 Target Mid Bermuda T2 C55 TD - Cosinq Pt MD 500.00 800.00 1016.70 1240.55 1500.48 2297.79 2658.19 3237.02 3804.99 3952.13 73,36.41 7939.70 8425.27 9054.50 9448.86 9791.51 10405.32 10570.45 10605.52 10752.59 10858.12 11006.51 11506.51 Inc Dir TVD North East V. Sect 0.00 515.00 500.00 0.00 0.00 0.00 15.00 313.00 794.31 44.38 -47.59 64.89 21.50 312.27 1000.00 90.27 -97.54 132.54 28.21 311.86 1203.00 153.23 -167.57 226.40 56.01 311.56 1423.00 245.06 -270.46 ,.564.25 59.92 311.08 1955.00 652.85 -712.51 951.51 70.13 510.94 2096.52 855.06 -944.88 1259.42 70.15 310.94 2500.00 1204.12 -1570.50 1822.15 70.13 310.94 2493.00 1554.16 - 1773.80 2355.86 70.15 310.94 2545.00 1644.84 -1878.55 2494.15 70.13 310.94 ,.5693.00 3730.58 -4282.61 5674.36 70.13 ,..310.94 5898.00 4102.39 -4711.20 6241.28 70.15 510.94 4065.00 4401.65 -5056.16 6697.57 70.15 510.94 4270.02 4777.12 -5488.98 7270.07 65.08 505.84 4428.00 5009.85 -5792.76 7652.67 61.17 297.53 4585.00 5165.90 -6055.22 7955.15 55.00 285.00 4908.28 5555.94 -6538.32 8451.29 55.00 285.00 5003.00 5390.95 -6668.98 8575.25 55.00 285.00 5025.00 5598.54 -6696.57 8601.42 55.00 285.00 5096.00 5425.55 -6797.27 8696.96 55.00 285.00 51 68.00 5451.94 -6896.60 8791.19 55.00 285.00 5255.00 5485.,36 -7015.85 8902.4,3 55.00 285.00 5425.07 5546.96 -7251.23 9127.63 Deg/lO0 0.00 5.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 320 23OO IPHILLIPS Alaska, Inc. Field: Torn Development ~eld Location: North Slope, Alaska 330 340 TRUE NORTH 1900 r---1 4100 35 0 1 ~?00 20 1500 ~!2700 / ! ~0 4/2500 ! ,' 40 ! ' 2300 5O 300 60¸ 290 280 70 270 9O 260 25O 100 10 240 ! 230 ' ! ! ~1700 , 220 ! / 2300 / 200 Normol Plone Trovelling Cylinder - Feet 120 150 1300 130 1500 180 All depths shown ore Meosured depths on Reference Well RECEIVED JUL 0 7 2000 Alaska Oil & Gas Cons. Commission Anchorage 220 200 180 160 140 - 120 - ' 100 - 80 4O 20 2O 4O 520 500 280 260 240 IPHILLIPS Alaska, Inc. Structure: Tarn DHII Site 2N Well: 518 Field: Tarn Development Field Looation: North Slope, Alaska RECE v JUL 0 7 2000 Alaska O~ & Gas Cons, Commissio~ Anchorage <- West (feet) 220 200 180 160 140 120 1 O0 BO 80 40 20 0 20 40 60 80 2100 '... , ~ . ~' ,.12oo ~--.. ,,~ ~',. ~. 2000 ~ ~ ~ ~ ~-- ~ '. ~ ~ ',1100 ~1000 , oo ,oo .? , ,o ,,,, '-~ '~ ~ '-. ".X k,~&~?°0° - ~1100 ~ ~ ~ ~ooo~ ~ ~ ~oo N '. '. ~X -, .... ~aoo ~-5~ k. 'k ~oo Npoo X~oo '-----.. ~ ~oo ~~oo "-,~oo ,o;N: '-- '--. 1~oo % 13oo .... ~X~ ', ~, ', "-- -~ -- ,~oo .... ~ ~ ~oo ,,~u X~oo ' ' ' ' I ~- ~ ~ 700 ~v1500 x. 700 90C ' ' 500 500 ----~ ~ --,,oo ~~ '-.:~o,o~ ' ' -. 1200 ~ O0 x 500 ooo ~ , "---.~Z~oo .oo , ~~o~ ~ 700 800 7O0 800 600 600 300 700 500 300 600 lOO 120 220 200 180 160 140 120 ' - lOO Z 0 BO ~" ~o 4O 20 20 4O 60 $20 500 280 260 240 220 200 t 80 160 140 120 1 O0 80 $0 40 20 0 20 40 60 80 <- West (feet) lOO 60 120 For: T Brassfield Reference is 318 ~ ~6. I ~fl~ arb ~ fad ref~ IPHILLIPS Alaska, Inc. Structure: Tarn Drill SHe 2N Well; 318 field: Tarn Development Field Location : North Slope, Alaskai RECEIVED JUL 0 7 2000 Alaska Oii & Gas Cons. Commission Anchorage <- West (feet) 960 920 880 840 800 760 720 680 640 600 560 ,520 480 440 400 .360 .320 280 240 200 160 120 80 oao'2°t~ ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' i ' ' ' ' ' ' ' '~' ' ' ' ' ' ' ' ' '2°°° 19oo 'I;~' ~ ,2O~o ~,o ~,oo .. ?o ,,,.~ ,.., , O0 1500 600 "', ,.~... ",,· 600 2,°0 ,9oo'--. 16oo 18oo'..,, 560 ,,. · ,,, · ~ ~,· ~ 560 . -, ',~2~oo \ ,, ... ~., ,,. ,, ~. ~N,~ '~" "'~~.k ~ '~"· 520 ~· 1400 ,oo~-.. X ,~oo...-~ \ ... \ 2600 '-, 'x '-, '4°~ ,, k ,~oo ... X,~oo ,,. xx...,x... ....~ .~, .:::::,oo . , , \ ~oo ,~o;'..X ,~oo'.. ~.,o,O~o;.,. \ ,oo '-."". kX ',,\ ~,oo '-'- "'-S,' ,,::o 350 1900 1500 380 2300 ~o ,.oo ,~o;.,~ ~o~... \ ~o ~oo ~oo ~,oo ,,yoo 520 I 48o ,.!-- 440 L. 400 0 280 1400 1 ~· 280 · 2100 2200 1300 ~1600 240 240 . . . . 1700 1400 ' ' ' '- -~,. 1800 2000 1500 2100 "" 200 ' ' '-. 1600 1700 ' -.. 1900 160 ' ,.. 15oo 200 160 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 360 `320 280 240 200 160 120 80 <- Wesf (feel) A I Z IPHILLIPS Alaska, Inc. StrucJuro = Tarn Drill SJJo 2N W®ll: .318 held: Tarn Dovolopmeflt field I.o~TJJon: No~lh SJopo, Maska RECE ',,/ED JUL 0 7 2000 /~aska O~i & Gas Cons. c.,omm~ion Anchorage <- Wesf (feel) 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 .:300 1900 J 170O 4700 46OO 1600 1500 1400 0 11oo Z 230O 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 190~ x~ ~ - ~ %2400 % X2~O X 1~ x ~ 3~00 ~ 2400 ~ N X '~2~0 ~ % ~ 2100 ~ ~ '. ~ ', , k ~ X~ "-, ~oo',, ", k ~ ~ "~ '- ~ ', ', k ~22~ k '-. ~ ', ,, ~ ~ X~ooo ? '-~oo~,oo '.. ',~oo ~ k X '~ ~ .oo '-. ~ '. ~oo '. ~ .... k k N -. ~ .. ', ~ h a~oo k2s°° ,~ ..., ,,,, ~ 2400 x x x x ~oo~ ~~~ ~.~ ... '..~oo k,.o X~ooo X ~. ' ',,, X X X 0 ~ 270(~ ~ 3900 .. ~ , , ~ ~ ~ ~ 0 ~,oo ~- --~ ~o~.. '~ ~ ~,,o0 ~ = ~ ~o "'. ~ ", ", k,.~ ~--- ~ '= ~o ~ ~ "-. ~=oo~ ~'0o ",, k h,~o ~ ~oo~ ~ ... '~~ooo _~k,,o° 3100 1600 ~ IOO0 goo 800 700 600 25OO 3300 2~00 2500 3100 240O 2400 ,:3000 2300 1900 1 3000 1800 2900 7O0 600 2500 2400 2,300 2200 2100 2000 1900 1800 1700 1600 1500 t 400 1300 1200 11 O0 1000 gO0 800 700 600 500 400 300 <- Wes} (fee{) ^ I 2~oo IPHILLIPS Alaska, Inc. Structure: Tar~ Drill SHe 2N Well: .518 Field: Torn D~,$1opment Field Loooflon: Hoeth Slope, Alosko <- West (feet) RECEIVED JUL 0 7 1~000 Alaska Oii& Gas Cons. C~mmission Anchor~e 28OO 4800 4600 4400 4200 4000 ~800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 3800 '-. ' "~§000 ',~ "~ 3000 X \ '', ~ '', ', k 4600 3200 ., ,ooo ,,, \ \ 320o \ '.,~ ,, ,,,acco 2, ~,~ \ \ ". 'x '- ', '\k \ =o ~ ~?oo ... .,,:.w x. .. \ \,2oo 3ooo ~ x~ %. 3200 ~ ', ', k 2.oo ~ ~ '-. ",..2oo '. 2,00 '. \3o, % k,ooo 32~'"'...'~2°° -'-.. ~. ".. '..~= '\\ ~ '-. -~ . .. \ \ \ ~ '- .... ~ooo ',, ,, ~ \ \ s~oo ~ .... ' ~, 3000 ~ ~ ,, \ 21t00N. \ 22oo -I ', ' k 2 600'~,, kO0 22oo J 600', ', \ \ \ ] -, ,, \ \ \ ~4oo 2oooq ', ', \ \ 2~o,~ 2000 Ob,.x ,.~ 2200'~ t , , \ \ , ',, \ 1§00 . ~x ~ ~ 20¢D 1000 ,o ', xx x~. ~ 1400 1400 x ,~ 220~ I ., 2200 12oo 12oo % \ .% % o,, 1000 1000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 <- West (feet) Z o 5800 56O0 5OOO ^ I 4~00 4600 ICreoted by ~J,,c~, For: T Brassfleld Date t~btl~l: ~-J~-~ P~ ~e~e h 318 ~ ~ I IPHILLIPS Alaska, Inc. Structure: Torn Drill SHe 2H Well: 318 Field: Tarn Development Fleld Loeation: North Slope, Alaska RECEIVED JUL 07 2000 Alaska O{.i & Gas Cons. ~,mmission Anchorage <- West (feet) 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 .5400 5200 5000 4800 4600 4400 4200 4000 3800 5600 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I~[~oo - - ,. 5_200 ' - ...5000 4600 44O0 '" -,,. 4800 '" .. 4600 4200 48O0 ,% 4000 4200 '" ~ 3800 3800 4000 ,, ' " 5200 3600 " " .~ - ",~ O0 3BOO · % - 32OO ~ 4000 % · %\ · ~00 ~x~ 4000 ~ 52~ ' ~3800 50~ ~ ~ 4400 ~4200 ,4600 40~ ' x '~ ~00 ~00 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 ,:3600 <- West (fee{) 58OO 56OO 54OO 5OOO A 4400 -'~ 4200 4O0O 58OO $6OO 5200 PHILLIPS Alaska, Inc. Tarn Drill Site 2N 318 slot #318 Tarn Development Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 318 Version #6 Our ref : prop3883 License : Date printed : 29-Jun-2000 Date created : 23-Feb-2000 Last revised : 29-Jun-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.461,w150 18 53.606 Slot Grid coordinates are N 5911956.785, E 460873.988 Slot local coordinates are 50.19 S 719.15 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North PHILLIPS Alaska, Inc. Tarn Drill Site 2N,318 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 318 Version #6 Last revised : 29-Jun-2000 Dogleg Vert Deg/100ft Sect 0.00 0.00 313.00 0.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 313.00 300.00 0.00 N 0.00 W 0.00 0.00 KOP 400.00 3.00 313.00 399.95 1.79 N 1.91 W 3.00 2.61 500.00 6.00 313.00 499.63 7.14 N 7.65 W 3.00 10.43 600.00 9.00 313.00 598.77 16.04 N 17.20 W 3.00 23.44 700.00 12.00 313.00 697.08 28.46 N 30.52 W 3.00 41.61 800.00 15.00 313.00 794.31 44.38 N 47.59 W 3.00 64.89 Begin Build/Turn 900.00 18.00 312.60 890.18 63.67 N 68.44 W 3.00 93.21 1000.00 21.00 312.31 984.43 86.19 N 93.06 W 3.00 126.50 1016.70 21.50 312.27 1000.00 90.27 N 97.54 W 3.00 132.54 Port Collar 1100.00 24.00 312.09 1076.81 111.89 N 121.40 W 3.00 164.68 1200.00 26.99 311.92 1167.07 140.69 N 153.39 W 3.00 207.65 1240.55 28.21 311.86 1203.00 153.23 N 167.37 W 3.00 226.40 Base Permafrost 1300.00 29.99 311.78 1254.94 172.51 N 188.92 W 3.00 255.27 1400.00 32.99 311.66 1340.20 207.27 N 227.91 W 3.00 307.43 1500.00 35.99 311.56 1422.61 244.87 N 270.25 W 3.00 363.97 1500.48 36.01 311.56 1423.00 245.06 N 270.46 W 3.00 364.25 Top W Sak 1600.00 38.99 311.48 1501.95 285.21 N 315.82 W 3.00 424.75 1700.00 41.99 311.40 1577.99 328.18 N 364.49 W 3.00 489.60 1800.00 44.99 311.33 1650.53 373.66 N 416.14 W 3.00 558.33 1900.00 47.99 311.27 1719.37 421.52 N 470.62 W 3.00 630.77 2000.00 50.99 311.22 1784.32 471.64 N 527.78 W 3.00 706.71 2100.00 53.99 311.17 1845.20 523.87 N 587.47 W 3.00 785.95 2200.00 56.99 311.12 1901.85 578.08 N 649.52 W 3.00 868.26 2297.79 59.92 311.08 1953.00 632.85 N 712.31 W 3.00 951.51 Base W Sak 2300.00 59.99 311.07 1954.11 634.11 N 713.76 W 3.00 953.42 2400.00 62.99 311.03 2001.83 691.82 N 780.02 W 3.00 1041.21 2500.00 65.99 310.99 2044.90 751.04 N 848.11 W 3.00 1131.37 2600.00 68.99 310.96 2083.18 811.60 N 917.85 W 3.00 1223.66 2638.19 70.13 310.94 2096.52 835.06 N 944.88 W 3.00 1259.42 EOC 3000.00 70.13 310.94 2219.46 1058.04 N 1201.92 W 0.00 1599.41 3237.02 70.13 310.94 2300.00 1204.12 N 1370.30 W 0.00 1822.13 7 5/8" Casing 3500.00 70.13 310.94 2389.36 1366.19 N 1557.13 W 0.00 2069.26 3804.99 70.13 310.94 2493.00 1554.16 N 1773.80 W 0.00 2355.86 C80 3952.13 70.13 310.94 2543.00 1644.84 N 1878.33 W 0.00 2494.13 Camp SS 4000.00 70.13 310.94 2559.27 1674.34 N 1912.34 W 0.00 2539.11 4500.00 70.13 310.94 2729.17 1982.50 N 2267.55 W 0.00 3008.97 5000.00 70.13 310.94 2899.07 2290.65 N 2622.76 W 0.00 3478.82 5500.00 70.13 310.94 3068.98 2598.80 N 2977.98 W 0.00 3948.67 6000.00 70.13 310.94 3238.88 2906.95 N 3333.19 W 0.00 4418.53 6500.00 70.13 310.94 3408.78 3215.10 N 3688.40 W 0.00 4888.38 7000.00 70.13 310.94 3578.68 3523.25 N 4043.61 W 0.00 5358.23 7336.41 70.13 310.94 3693.00 3730.58 N 4282.61 W 0.00 5674.36 C50 7500.00 70.13 310.94 3748.59 3831.40 N 4398.83 W 0.00 5828.09 7939.70 70.13 310.94 3898.00 4102.39 N 4711.20 W 0.00 6241.28 C40 8000.00 70.13 310.94 3918.49 4139.55 N 4754.04 W 0.00 6297.94 8425.27 70.13 310.94 4063.00 4401.65 N 5056.16 W 0.00 6697.57 C37 8500.00 70.13 310.94 4088.39 4447.71 N 5109.25 W 0.00 6767.79 9000.00 70.13 310.94 4258.30 4755.86 N 5464.46 W 0.00 7237.65 9034.50 70.13 310.94 4270.02 4777.12 N 5488.98 W 0.00 7270.07 Begin Drop/Turn level). RECEIVED Ail data is in feet unless otherwise stated. Coordinates from slot #318 and TVD from RKB(Nabors 19E) (153.00 Ft above mean sea Bottom hole distance is 9129.57 on azimuth 307.41 degrees from wellhead. Total Dogleg for wellpath is 97.56 degrees. Vertical section is from wellhead on azimuth 308.60 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ JUL 0 7 2000 Alaska O;i & (~s Cons. ,,ommission Anchorage PHILLIPS Alaska, Inc. Tarn Drill Site 2N,318 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 318 Version #6 Last revised : 29-Jun-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 9100.00 69.32 309.85 4292.72 4816.94 N 5535.76 W 2.00 7331.48 9200.00 68.08 308.17 4329.05 4875.58 N 5608.15 W 2.00 7424.64 9300.00 66.86 306.45 4367.37 4931.57 N 5681.61 W 2.00 7516.97 9400.00 65.66 304.70 4407.63 4984.82 N 5756.05 W 2.00 7608.38 9448.86 65.08 303.84 4428.00 5009.83 N 5792.76 W 2.00 7652.67 Iceberg 9500.00 64.48 302.92 4449.79 5035.29 N 5831.38 W 2.00 7698.74 9600.00 63.32 301.11 4493.79 5082.90 N 5907.52 W 2.00 7787.94 9700.00 62.18 299.25 4539.58 5127.59 N 5984.36 W 2.00 7875.88 9791.51 61.17 297.53 4583.00 5165.90 N 6055.22 W 2.00 7955.15 T7 9800.00 61.07 297.36 4587.10 5169.32 N 6061.82 W 2.00 7962.45 9900.00 59.99 295.43 4636.30 5208.03 N 6139.79 W 2.00 8047.54 10000.00 58.94 293.46 4687.11 5243.68 N 6218.19 W 2.00 8131.05 10100.00 57.91 291.44 4739.47 5276.22 N 6296.92 W 2.00 8212.88 10200.00 56.92 289.38 4793.33 5305.61 N 6375.88 W 2.00 8292.93 10300.00 55.97 287.27 4848.60 5331.82 N 6454.98 W 2.00 8371.10 10400.00 55.05 285.12 4905.24 5354.81 N 6534.12 W 2.00 8447.29 10405.32 55.00 285.00 4908.28 5355.94 N 6538.32 W 2.00 8451.29 EOC 10500.00 55.00 285.00 4962.59 5376.01 N 6613.24 W 0.00 8522.36 10570.45 55.00 285.00 5003.00 5390.95 N 6668.98 W 0.00 8575.25 T3.1 10605.32 55.00 285.00 5023.00 5398.34 N 6696.57 W 0.00 8601.42 T3 10732.59 55.00 285.00 5096.00 5425.33 N 6797.27 W 0.00 8696.96 2N-318 Rvsd 29-Jun-00 10858.12 55.00 285.00 5168.00 5451.94 N 6896.60 W 0.00 8791.19 T2 11000.00 55.00 285.00 5249.38 5482.02 N 7008.86 W 0.00 8897.70 11006.31 55.00 285.00 5253.00 5483.36 N 7013.85 W 0.00 8902.43 C35 11306.31 55.00 285.00 5425.07 5546.96 N 7251.23 W 0.00 9127.63 TD - Casing Pt level). RECEIVED JUL 0 7 2000 Alaska O~i & Gas Cons° Commission Anchorage All data is in feet unless otherwise stated. Coordinates from slot #318 and TVD from RKB(Nabors 19E) (153.00 Ft above mean sea Bottom hole distance is 9129.57 on azimuth 307.41 degrees from wellhead. Total Dogleg for wellpath is 97.56 degrees. Vertical section is from wellhead on azimuth 308.60 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Tarn Drill Site 2N,318 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 318 Version #6 Last revised : 29-Jun-2000 Comments in wellpath MD ~ Rectangular Coords. Comment ................................................................................................ 300.00 800.00 1016.70 1240.55 1500.48 2297.79 2638.19 3237.02 3804.99 3952.13 7336.41 7939.70 8425.27 9034.50 9448.86 9791.51 10405 32 10570 45 10605 32 10732 59 10858 12 11006 31 11306 31 300.00 794.31 1000.00 1203.00 1423.00 1953.00 2096. 2300. 2493. 2543. 3693. 3898 4063 4270 4428 4583 4908 5003 5023 5096 5168 5253 5425 0.O0 N 0. 44.38 N 47. 90.27 N 97. 153.23 N 167. 245.06 N 270. 632.85 N 712. 52 835.06 N 944 00 1204.12 N 1370 00 1554.16 N 1773 00 1644.84 N 1878 00 3730.58 N 4282 00 4102.39 N 4711 00 4401.65 N 5056 02 4777.12 N 5488 00 5009.83 N 5792 00 5165.90 N 6055 28 5355.94 N 6538 00 5390.95 N 6668 00 5398.34 N 6696 00 5425.33 N 6797 00 5451.94 N 6896 00 5483.36 N 7013 07 5546.96 N 7251 00 W KOP 59 W Begin Build/Turn 54 W Port Collar 37 W Base Permafrost 46 W Top W Sak 31 W Base W Sak 88 W EOC 30 W 7 5/8" Casing 80 W C80 33 W Camp SS 61 W C50 20 W C40 16 W C37 98 W Begin Drop/Turn 76 W Iceberg 22 W T7 32 W E0C 98 W T3.1 57 W T3 27 W 2N-318 Rvsd 29-Jun-00 60 W T2 85 W C35 23 W TD - Casing Pt Casing Dositions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3237.02 2300.00 1204.12N 1370.30W 7 5/8 Casing 0.00 0.00 0.00N 0.00E 11306.30 5425.07 5546.96N 7251.22W 5 1/2 Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ................................................................................................ ........... 2N-3t8 Rvsd 29-Jun-0 454105.000,5917416.000,0.0000 5096.00 5425.33N 6797.27W 23-Feb- 2000 RECEIVED JUL 0 7 2000 Alaska 0~; & Gas Co~s~ Cor~mission AnChorage PHILLIPS Alaska, Inc. Tarn Drill Site 2N 318 slot #318 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 318 Version #6 Our ref : prop3883 License : Date printed : 29-Jun-2000 Date created : 23-Feb-2000 Last revised : 29-Jun-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.461,w150 18 53.606 Slot Grid coordinates are N 5911956.785, E 460873.988 Slot local coordinates are 50.19 S 719.15 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object weltpath PMSS <10920 - l1225'>,,331,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <O-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-!2339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209-???'>,,332,Tarn Drill Site 2N PMSS <5303 - l1526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 10-May-2000 195 14-Aug-1998 14 9-Oct-1998 309 24-Feb-1999 150 8-Mar-1999 163 30-Mar-1999 134 9-0ct-1998 14 16-May-2000 39 27-Oct-1998 216 30-Sep-1998 345 28-Feb-2000 374 21-Ju1-1998 394 4-Aug-1998 73 21-Dec-1998 91 9-Feb-1999 22 10-May-2000 153 20-May-2000 75 7-Jun-2000 434 27-Jun-2000 284 27-Jun-2000 284 26-Jun-2000 210 29-Jun-2000 210 29-Feb-2000 45 21-Dec-1998 45 .0 20.0 · 8 300 0 .5 522 2 · 0 00 .8 322 2 .0 300 0 .9 455 6 · 4 655 6 · 5 988 9 · 5 100 0 .3 422 2 .8 688 9 .0 444.4 .7 811 1 .3 533 3 .6 700 0 .2 20 0 · 9 200 0 · 1 444 4 . t 444 4 .1 100.0 .1 100.0 .4 20.0 .4 20.0 20.0 300.0 522.2 0.0 322.2 300.0 455.6 655.6 988.9 455.6 422.2 688.9 444.4 811.1 10780.0 700.0 10312.5 200.0 444.4 444.4 100.0 100.0 11306.3 7760.0 RECEIVED JUL 0 7 2000 Alaska O;~ & Gas Co~s, Commission AnChorage PHILLIPS Alaska, Inc. Tarn Drill Site 2N 318 slot #318 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hu§hes INTEQ Your ref : 318 Version #6 Our ref : prop3883 License : Date printed : 6-Jul-2000 Date created : 23-Feb-2000 Last revised : 29-Jun-2000 RECE%VED JUL 0 7 2000 Alaska G-; & G~ Cong, Commission Anchorage Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.461,w150 18 53.606 'Slot Grid coordinates are N 5911956.785, E 460873.988 Slot local coordinates are 50.19 S 719.15 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PMSS <10920 - l1225'>,,331,Tarn Drill Site 2N 10-May-2000 349(to312'sTgt)Ver#2,,349,Tarn Drill Site 2N 23-Mar-2000 305 Version #l,,305,Tarn Drill Site 2N 25-Feb-2000 PMSS <0-8500'>,,317,Tarn Drill Site 2N 14-Aug-1998 339 (Sidetrack) Vers.#2,,339St,Tarn Drill Site t0-May-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 9-0ct-1998 25-Sep-1998 16-May-2000 27-0ct-1998 30-Sep-1998 28-Feb-2000 21-Ju1-1998 4-Aug-1998 25-Sep-1998 21-Dec-1998 9-Feb-1999 10-May-2000 PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <O-10520'>,,308,Tarn Drill Site 2N PMSS <O-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N 315A Version #l,,315A,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <O-9134'>,,313,Tarn Drill Site 2N 325 Version #5,,325,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <O-9690'>,,329,Tarn Drill Site 2N )194 1 )4OO 9 )193 3 )13 2 )313 3 )305 6 )149 4 )162 1 )132 1 )12 5 )1064 1 )31 5 207 6 343.3 371.2 390.5 )70.3 671.0 )84.2 )18.7 149.1 220 0 1444 4 311 1 311 1 411 1 566 7 200 0 333 3 322 2 466 7 6800 0 888 9 1016 7 477 8 466 7 722 2 544 4 3200.0 844.4 555.6 722.2 9262 5 1444 4 311 1 311 1 411 1 9795 8 10680 0 9512 5 322 2 466 7 7336 4 10732 6 11060 0 11260 0 9212 5 6020 0 544 4 3200.0 8340.0 11306.3 10880.0 PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <O-12735'>,,347,Tarn Drill Site 2N 322 Version #31,,322,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N 314 Version #4,,314,Tarn Drill Site 2N PMSS <5303 - l1526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N 316A Version #2,,316A,Tarn Drill Site 2N 316 Version #12,,316,Tarn Drill Site 2N 332A Version #l,,332A,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N 318A Version #1,,318A,Tarn Drill Site 2N 20-May-2000 7-Jun-2000 23-Jun-2000 27-Jun-2000 27-Jun-2000 29-Jun-2000 29-Feb-2000 21-Dec-1998 29-Jun-2000 5-Jul-2000 21-Jun-2000 6-Jul-2000 6-Jul-2000 22-Jun-2000 )74 )433 )58 )281 )281 )48 )45 )45 )19 )19 )2293 )209 )209 )0 180 400 260 488 488 966 100 100 1177 1177 6880 120 .0 10137.5 0 10920.0 0 11306.3 9 10150.0 9 10150.0 7 10820.0 0 10640.0 0 7400.0 .8 9047.6 .8 2638.2 .0 11306.3 .0 9412.2 120.0 11306.3 3960.0 10900.0 RECEIVED JUL 0 7 2000 AJaska Oi~ & Gas Cons. ~mmlss~orl An~omge Phillips Alaska, Inc. Diverter Schematic Nabors 19e Flowline 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16-3/4" 2M SOW Starting Head 16-3/4" x 21-1/4"x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECEIVED JUL 0 7 2000 Alaska Oi{ & Gas COns. Co~rnission Anchorage Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT ¼ P L I 1 F I I L 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE MANUAL GATE V KILL LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP r_j ~raulic actuator ~,.~L~ ~00 psi t~oOcKf LINE 11" 5,000 psi WP DRILLING SPOOL L1 w/two 3" 5M psi WP outlets I J SINGLE 11" 5,000 psi WP, - HYDRIL MPL BOP w/pipe rams I RECEIVED JUL 0 7 2000 Naska Oi~ & Gas COns. Co~lrnission Anchorage Phillips Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 July 6, 2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-318 Surface Location: 51' FNL 719' FEL Sec 3 TgN R7E, UM or ASP4, NAD 27 coordinates of X=460,874 & Y=5,911,957 Target Location: 90' FSL, 2229' FEL Sec. 28, T10N, R7E, UM Bottom Hole Location: 212' FSL, 2597' FWL Sec. 28, T10N, R7E, UM Dear Commissioner Christenson, Phillips Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-318, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Nabors Rig 19e will drill the well. If commercial, the well will also completed with Nabors 19e. 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 preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or 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, Phillips 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. The following are Phillips' designated contacts for rePorting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist 265-6967 (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 265-6434 in our Anchorage office. Si[~cerely,_ j !m eO's~r a ~t h ~m v"~"~~ ~ Drilling Engineering Supervisor Attachments cc: KRU 2N-318 Well File Phillips Alaska, Inc. is a Subsidiary of Phillips 66 RECEIVED JUL 0 7 2000 Alaska Oi-; & Gas ¢o~$. Co~qrnission Anchorage I~'O000],OOClSCt,, ~:O.O.~.c~OL, 8~.8~: OC~ cto000,' , ~ .~.; t/, W~ PERMITcHECKLIST COMPANY '/~'/'//~, WELL NAME ~./V¢~/~ PROGRAM: exp FIEm&PooL ~?O/~ INIT C~Ss r~~ ~0/~ GEOLAR~ ADIIENISTRATION APPR DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... EN~NEERING 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 '~~ 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 ................. dev v/ redrll __ serv __ wellbore seg ann. disposal para req __ N U. T# , ON/OFF SHORE (~N N N N N N GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... (~ N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............ 33. Seabed condition survey (if off-shore) .......... 34. Contact name/phone for weekly progress reports [expl~ato~ only] Y N ~.~ .~ ~/~/ . /_~ ~ · ANNULAR DISp. OSAL35. DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. . .. Y. N GEOLOGY': ENGINEER, lNG: UIC/Annular COMMISSION: '~M~.w'3-,~"/o-~ , , , ..... - Comments/Instructions: ]§ i_,I z --I -!- c:Vl~office\wordian\diana\checklist (rev. 02117/00) Well Histo.ry 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 APPEN. DIX, No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Mar 19 17:10:40 2001 Reel Header Service name ............. LISTPE Date ..................... 01/03/19 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 ..................... 01/03/19 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) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-00130 B. HENNINGSE R. SPRINGER 2N-318 501032034300 PHILLIPS Alaska Inc. Sperry Sun 19-MAR-01 MWD RUN 3 AK-MM-00130 B. HENNINGSE R. SPRINGER MWD RUN 4 AK-MM-00130 B. HENNINGSE B. MORRISON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 5 AK-MM-00130 J. MARTIN D. GLADDEN 3 9 N 7 E 51 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 719 153.10 151.77 119.30 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 114.0 9.875 7.625 2602.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED 3. MWD RUNS 2 - 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN AND STABILIZED LITH-DENSITY (SLD). 4. GAMMA RAY LOGGED BEHIND CASING TO 2602' MD, 2310' TVD. 5. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 9/28/00. MWD DATA CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 2N-318 WITH API % 50-103-20343-00. THIS WELL REACHED A TOTAL DEPTH OF 11456' MD, 5243' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARA/METERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 7.5" & 6.75" MUD WEIGHT: 9.30 - 9.60 PPG MUD FILTRATE SALINITY: 400 - 600 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.00 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 ....... 01/03/19 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DRHO RPX RPS RPM RPD NPHI FCNT RHOB PEF NCNT FET ROP $ START DEPTH 2566 0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 2610.5 2612.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ STOP DEPTH 11401.5 11357 5 11408 5 11408 5 11408 5 11408 5 11342 0 11342 0 11357 5 11357 5 11342 0 11408 5 11456 0 EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 2566.0 3225.5 3 3226.0 5962.0 4 5962.5 9742.0 5 9742.5 11456.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 t 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Last Name Service Unit Reading DEPT FT 11456 ROP MWD FT/H 11456 GR MWD API 11401.5 RPX MWD OHMM 11408.5 RPS MWD OHMM 11408.5 RPM MWD OHMM 11408.5 RPD MWD OHMM 11408.'5 FET MWD HR Min 2566 4.74 46 29 1 13 1 34 1 22 1 53 0 36 Max Mean Nsam 11456 7011 17781 4500 101.64 17689 236.38 124.349 17672 1854.34 4.87335 17634 2000 5.17223 17634 2000 6.41371 17634 2000 6.41787 17634 28.51 1.73979 17597 First Reading 2566 2612 2566 2592 2592 2592 2592 2610.5 11408.5 NPHI MWD PU-S 11.21 53.29 11342 FCNT MWD CP30 103.12 1004.81 11342 NCNT MWD CP30 12100.9 32262.1 11342 RHOB MWD G/CM 1.48 3.24 11357.5 DRHO MWD G/CM -0.89 0.91 11357.5 PEF MWD B/E 1.32 14.35 11357.5 33.946 17501 248.572 17501 19042.1 17501 2.32283 17532 0.0691085 17532 2.87258 17532 2592 2592 2592 2592 2592 2592 First Reading For Entire File .......... 2566 Last Reading For Entire File ........... 11456 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 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 ....... 01/03/19 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 RPM RPS RPD FCNT NCNT RHOB DRHO PEF NPHI 2566.0 2592.0 2592.0 2592.0 2592 0 2592 0 2592 0 2592 0 2592 0 2592 0 STOP DEPTH 3163.5 3170 5 3170 5 3170 5 3104 5 3104 5 3119 5 3119 5 3119 5 3104 5 RPX 2592.0 FET 2610.5 ROP 2612.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3170.5 3170.5 3225.5 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 Data Reference Point .............. Undefined 14-AUG-00 Insite 4.05.02 65.44 Memory 3225.0 47.4 60.5 TOOL NUMBER PB0t588HAGR4 PB01588HAGR4 PB01428NL4 PB01428NL4 7.500 LSND 9.50 48.0 10.5 55O 6.0 2.600 2.086 2.800 2.800 72.0 91.4 72.0 72.0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HR 4 1 68 MWD020 PU-S 4 1 68 MWD020 CP30 4 1 68 MWD020 CP30 4 1 68 MWD020 G/CM 4 1 68 MWD020 G/CM 4 1 68 MWD020 B/E 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 DEPT 3225 ROP 3225 GR 3163 RPX 3170 RPS 3170 RPM 3170 RPD 3170 FET 3170 NPHI 3104 FCNT 3104 NCNT 3104 RHOB 3119 DRHO 3119 PEF 3119 Last Name Service Unit Min Max Reading FT 2566 3225.5 .5 MWD020 FT/H 6.17 4500 .5 MWD020 API 47.32 153.71 .5 MWD020 OHMM 1.5 1854.34 .5 MWD020 OHMM 1.53 2000 .5 MWD020 OHMM 1.22 2000 5 MWD020 OHMM 1.53 2000 5 MWD020 HR 0.4 .2.33 5 MWD020 PU-S 20.63 53.29 5 MWD020 CP30 103.12 500.24 5 MWD020 CP30 12100.9 28672.5 5 MWD020 G/CM 1.48 2.93 5 MWD020 G/CM -0.89 0.4 .5 MWD020 B/E 2.36 14.35 .5 Mean 2895.75 182.223 105.841 7.74635 9.61307 25.2548 24.055 1.24134 40.2491 173.771 16497.9 2.18176 0.0389962 3.66331 Nsam 1320 1228 1196 1158 1158 1158 1158 1121 1026 1026 1026 1056 1056 1056 First Reading 2566 2612 2566 2592 2592 2592 2592 2610.5 2592 2592 2592 2592 2592 2592 First Reading For Entire File .......... 2566 Last Reading For Entire File ............ 3225.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 3105.0 FCNT 3105.0 NPHI 3105.0 PEF 3120.0 DRHO 3120.0 RHOB 3120.0 GR 3164.0 FET 3171.0 RPD 3171.0 RPM 3171.0 RPS 3171.0 RPX 3171.0 ROP 3226.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5841 0 5841 0 5841 0 5856 5 5856 5 5856 5 5900 0 5907 0 5907 0 5907 0 5907 0 5907 0 5962 0 18-AUG-00 Insite 4.05.02 65.44 Memory 5962.0 61.6 75.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN TOOL NUMBER PB01588HAGR4 PB01588HAGR4 PB01428NL4 PB01428NL4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.500 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): LSND 9.60 47.0 9.1 450 4.4 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 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.000 1.754 2.000 1.960 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CP30 4 1 68 36 10 NCNT MWD030 CP30 4 1 68 40 11 58.0 104.0 56.0 58.0 RHOB MWD030 DRHO MWD030 PEF MWD030 G/CM G/CM B/E 1 68 1 68 1 68 44 12 48 13 52 14 Last Name Service Unit Reading DEPT FT 5962 ROP MWD030 FT/H 5962 GR MWD030 API 5900 RPX MWD030 OHMM 5907 RPS MWD030 OHMM 5907 RPM MWD030 OHMM 5907 RPD MWD030 OHMM 5907 FET MWD030 HR 5907 NPHI MWD030 PU-S 5841 FCNT MWD030 CP30 5841 NCNT MWD030 CP30 5841 RHOB MWD030 G/CM 5856.5 DRHO MWD030 G/CM 5856.5 PEF MWD030 B/E 5856.5 Min 3105 5.35 46 29 2 21 2 41 2 52 2 71 0 36 18 13 130 85 14287.5 1.89 -0.1 1.57 Max 5962 472 77 147 58 13 28 12 06 11 09 9 25 14 22 47 72 646 28 29627.7 2.87 Mean Nsam 4533.5 5715 86.7559 5473 109.479 5473 4.29702 5473 4.46642 5473 4.58262 5473 4.67432 5473 1.82865 5473 35.202 5473 222.266 5473 18324.7 5473 2.24333 5474 0.67 0.0530745 5474 7,67 2.92284 5474 First Reading 3105 3226 3164 3171 3171 3171 3171 3171 3105 3105 3105 3120 3120 3120 First Reading For Entire File .......... 3105 Last Reading For Entire File ........... 5962 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... t.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI NCNT FCNT RHOB DRHO PEF GR RPD RPX RPS RPM FET ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 5841.5 5841.5 5841.5 5857.0 5857 0 5857 0 5900 5 5907 5 5907 5 5907 5 5907 5 5907 5 5962 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD 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: STOP DEPTH 9623.5 9623.5 9623.5 9638 5 9638 5 9638 5 9682 0 9689 0 9689 0 9689 0 9689 0 9689 0 9742 0 22-AUG-00 Insite 4.05.02 65.44 Memory 9742.0 67.1 76.8 TOOL NUMBER PB01588HAGR4 PB01588HAGR4 PB01428NL4 PB01428NL4 7.500 LSND 9.60 47.0 9.1 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 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 400 3.4 1. 900 1.104 1. 950 1.860 64.0 115.0 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 5841.5 9742 7791.75 7802 9742 ROP MWD040 FT/H 4.74 209.1 102.481 7560 9742 GR MWD040 API 57.6 236.38 132.966 7564 9682 RPX MWD040 OHMM 1.13 24.03 4.6054 7564 9689 First Reading 5841.5 5962.5 5900.5 5907.5 RPS MWD040 OHMM 1.34 22.69 9689 RPM MWD040 OHMM 1.7 18.86 9689 RPD MWD040 OHMM 1.91 14.33 9689 FET MWD040 HR 0.51 23.12 9689 NPHI MWD040 PU-S 11.47 48.32 9623.5 FCNT MWD040 CP30 141.8 1004.81 9623.5 NCNT MWD040 CP30 15347.6 31822.2 9623.5 RHOB MWD040 G/CM 1.58 3.24 9638.5 DRHO MWD040 G/CM -0.18 0.91 9638.5 PEF MWD040 B/E 1.32 5.36 9638.5 4.81905 7564 5. 13456 7564 5.21348 7564 1. 62668 7564 33.7497 7565 243.095 7565 18896 7565 2.35798 7564 0.0864186 7564 2.80485 7564 5907 5 5907 5 5907 5 5907 5 5841 5 5841 5 5841 5 5857 5857 5857 First Reading For Entire File .......... 5841.5 Last Reading For Entire File ........... 9742 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9624.0 11342.0 FCNT 9624.0 11342.0 NCNT 9624.0 11342.0 PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9639.0 9639.0 9639.0 9682.5 9689.5 9689.5 9689.5 9689.5 9689.5 9742.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP. LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11357.5 11357.5 11357.5 11401.5 11408.5 11408.5 11408.5 11408.5 11408.5 11456.0 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: 25-AUG-00 Insite 4.05.02 65.44 Memory 11456.0 71.1 73.7 TOOL NUMBER PB01588HAGR4 PB01588HAGR4 PB01428NL4 PB0t428NL4 7.500 LSND 9.60 46.0 9.3 4O0 3.2 3.000 1.628 2.500 3.100 68.0 131.0 68.0 68.0 # 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 NPHI MWD050 PU-S 4 1 68 FCNT MWD050 CP30 4 1 68 NCNT MWD050 CP30 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 1 68 PEF MWD050 B/E 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 Last Name Service Unit Min Max Reading DEPT FT 9624 11456 11456 ROP MWD050 FT/H 5.42 330.89 11456 GR MWD050 API 60.38 185.84 11401.5 RPX MWD050 OHMM 1.66 17.93 11408.5 RPSMWD050 OHMM 1.73 17.9 11408.5 RPM MWD050 OHMM 1.76 17.04 11408.5 RPD MWD050 OHMM 1.8 16.87 11408.5 FET MWD050 HR 0.67 28.51 11408.5 NPHI MWD050 PU-S 11.21 44.9 11342 FCNT MWD050 CP30 181.81 924.16 11342 NCNT MWD050 CP30 16333.4 32262.1 11342 RHOB MWD050 G/CM 1.94 3.03 11357.5 DRHO MWD050 G/CM -0.05 0.64 11357.5 Mean 10540 94.6822 135.497 5.4125 5.57697 5.79698 5.90279 2.00961 30.4961 324.845 21265.7 2.41542 0.0658028 Nsam 3665 3428 3439 3439 3439 3439 3439 3439 3437 3437 3437 3438 3438 First Readin¢ 9624 9742 5 9682 5 9689 5 9689 5 9689 5 9689 5 9689 5 9624 9624 9624 9639 9639 PEF MWD050 B/E 1.57 4.67 11357.5 2.69871 3438 9639 First Reading For Entire File .......... 9624 Last Reading For Entire File ........... 11456 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/03/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing,Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/03/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physic.al EOF End Of LIS File