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Home My WebLink About200-045Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the 0dginal file, may be scanned dudng the rescan activity or are viewable by direct inSpection of the file. Well History File Identifier RESCAN DIGITAL DATA Gr:'lor items: O Oiskettes, No. Grayscale items: o Other. NofType O Poor Quality Originals: 0 Other: TO'f AL PAGES: "-7~ NoTEs: ORGANIZED BY BEVERLY BREN( t~.~)SHERYL MARIA LOWELL OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) (3 Logs of various kinds (3 Other Project Proofing PROOFED 8¥ BEVERLY BREN .~~ SHERYL MARIA LOWELL [] Staff Proof P_,~ Oate SC/~.NNEOE~,' BEVEI:~L¥ BREt; VINC~MAI~:A LOWELt C~eneral Notes or C. ommenls aboul Ih~s file Oualdy Checked .~~~:.",.. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill No. 2000450 MD 7930 TVD DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. KUPARUK RIV U TABS 2T-217 Operator PHILLIPS ALASKA INC. 3459 Completion Date 5/15/2000 ~- Completion Status P&A Current Status AP1 No. P&A 50-103-20334-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples N___~o -- Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Log Log Run Interval OH / Scale Media No Start Stop CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments R LIS Verification R SRVY RPT ~D LIS ~~Res MD Well Cores/Samples Informa~'r'~/(~ ~6 Name FINAL 25 FINAL 0 7930 OH C 69 793O CH 2/22/2001 LIS Verification Paper Copy 6/1/2000 SPERRY 1/9/2001 Verification Listing 1/9/2001 BL, Sepia Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis Received? Y~..~..LN'- Daily History Received? Formation Tops Receuived? Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 14, 2000 RE' MWD Formation Evaluation Logs 2T-217, AK-MM-00026 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, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-217: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20334-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20334-0.0 ~1/Blueline ff' Folded Sepia vl/ Blueline ~l/Folded Sepia To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 2, 2000 MWD Formation Evaluation Logs 2T-217, AK-MM-00026 1 LDWG formatted Disc with verification listing. API#: 50-103-20334-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: I I ':t l MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Dan Seamount Commissioner DATE: May 11,2000 Blair Wondzell ~.,~ P.I. Supervisor Lou Gdmaldi L~ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 16 Arco/Phillips 2T-218 200-045 Kuparuk River Field Operator Rep.: Fred Herbert Contractor Rep.: Hanson/Greco Op. phone: 659-7075 Rig phone: 659-7562 Op. E-Maih N1333@ppco.com Rig E-Mail: Test Pressures Rams: 250~3000 MISC. INSPECTIONS: P/F Location Gen.: P Sign: Housekeeping: P Rig cond: PTD On Location P Hazard: Standing Order: P Annular: 25013000 Choke: 250/3000 TEST DATA FLOOR VALVES: MUD SYSTEM: P/F Quantity P/F Trip Tank P Upper Kelly 1 P Pit Level Indicators P Lower Kelly 1 P Flow Indicator P Ball Type 1 P Meth Gas Detector Inside BOP 1 P H2S Gas Detector BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8 P Pipe Rams 1 13 5/8 P Lower Pipe Rams 1 13 5/8 P Blind Rams 1 13 5/8 P Choke Ln. Valves 1 4 P HCR Valves 2 3&4 P Kill Line Valves 1 3 P Check Valve 0 Visual Alarm P P P P P P P P P P ACCUMULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi P/F Quantity P/F System Pressure 3050 P No. Valves 17 P After Closure 1600 P Man. Chokes 1 P 200 psi Attained :39 P Hyd. Chokes 2 P Full Pressure 3:16 P Blind Covers (All Stations): P N2 Bottles (avg): 6 (~ 2000 psi Test's Details The rig was standing by awaiting my arrival from previously scheduled meter proving at CPF 2. The test started as soon as I arrived. All BOPE components were tested with no failures observed. The rig and its surrounding area were dean and orderly. This rig is one of the converted Pool rigs and seems to be getting better at each of my visits. The crew was well versed in the testing procedure used here. If a additional paragraph is desired usc this block, type all pertinant information that occurred during the tests. The text will word wrap and continue on the next line. To see and print this text you will have to manually change the cell height by positioning the mouse over the line under row 39's marker on the left and moving it up or down. TOtal Test Time: 3 Number of failures: C.C: WinfreelOverstreet {Kuparuk DrillinQ) Attatchments: None BOP Nab 16E 5-11-00 LG RBDMS Markup.xls PLU.GGi~G & LOC3.T!0N CLE~-R~-~CE REPORT Review ~he well file, and-c=~mmn: an pluq~ing, well head scaCus,.~n~ !ocaClun clearance.- ur~vi~e.!o¢, clear-- code. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned J~J Servioe r'-J 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-045 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50--103-20334-00 4. Location of well at surface 9. Unit or Lease Name 755' FSL, 556' FWL, Sec. 1, T11 N, RSE, UMASP: 498944.8, 5970735) 1,I~)¢-;A'-''''-~'~ Kuparuk River Unit At Total Depth 11. Field and Pool 1839' FSL, 1493' FWL, Sec. 36, T12N, R8E, UM ( 499877, 5977097) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 34 feetI ADL 25548 ALK 2662 Tabasco Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 21,2000 May 13, 2000 May 15, 2000 (P&A'd)I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7930' MD/3459' TVD 5018' MD/2539' TVD YES ~] No n']I N/A feetMD 1624' (approx) 22. Type Electric or Other Logs Run MWD/G R/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER Fr. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 118' 24" 9 cu )/ds Hi,(]h Earl)/ 9.625" 40# L-80 Surface 6214' 12.25" 803 Sx AS III Lite & 871 Sx Class G 7" 26# L-80 6003' 6975' 8.5" 285 sx Class G 9-5/8" brid~le plug @ 5018' MD cement retainer @ 6880' MD 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. JUL 0 7 200) DEPTH INTERVAL (MO) AMOUNT & KIND OF MATERIAL USED Plugback: squeezed 13 bbls 15.8 ppg Class G ~aska Oi! & Gas Certs. 0ommissi~ An,~oraCe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > !Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Summary of 2T-217 Sidetrack Plug & Abandonment Operations. and Directional Survey: 32. I hereby certify that the following is true and correct to the best of my knowledge. -Randy T~oma~ Prepared by Sharon AIIsup-Drake Title Drill nq Team Leader Date 7/~ {Od) Questions? Call Tom Brockway 263-4135 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain.'~, [~ ~,,~ ,-~.', L,~ [~ ~'"~,. ~ii::~!. ~,~,~. ~ ~,~.~,~;". "~"" ~, Item 28: If no cores taken, indicate "none". Form 10-407 JUL 0 7 20O) Alask80it & Gas Cons. Commission i r /a. lg lg , SURVEYCALCULATION AND FIELD WORKSHEET Job No. 0450-00026 Sidetrack No. _ ...... Page ~ _2. .... of 4 J~~]~l~l~ COmpany PHILLIPS ALASKA, INC. Rig Contractor & No. NABORS - 16E Field KUPARUK RIVER UNIT Wl~ Well Name & No. PAD 2T/217 Survey Section Name Definitive Survey BHI Rep. R. BARNARD WELL DATA _. Target TVD (FT) Target Coord. N/S Slot Coord. N/S 768.00 Grid Correction 0.000 Depths Measured From: RKB [~ MSL~] SS I- Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.370 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m[-] 10m[-[ Vert. Sec. Azim. 8.51 Magn. to Map Corr. 26.370 Map North to: OTHER SURVEY DATA Survey i Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool ' Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (VIe) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 22-APR-00 MWD 2238.83 74.29 9.20 9~.86 1795.55 996.22 976.30 207.28 3.43 3.30 1.01 22-APR-00 MWD 2332.73 74.37 9.26 93.90 1820.91 1086.63 1065.54 221.78 0.11 0.09 0.06 .J- 22-APR-00 MWD 2427.50 74.37 8.19 94.77 1846.44 1177.89 1155.75 235.63 1.09 0.00 -I. 13 22-APR-00 MWD 2522.94 74.61 8.69 95.44 1871.96 1269.85 1246.71 249.13 0.56 0.25 0.52 22-APR-00 MWD 2619.34 74.07 6.75 96.40 1897.99 1362.66 1338.69 261.60 2.02 -0.56 -2.01 22-APR-00 MWD 2714.63 73.63 7.85 95.29 1924.49 1454.17 1429.47 273.23 1.20 -0.46 1.15 22-APR-00 MWD 2809.50 75.18 7.15 94.87 1950.00 1545.53 1520.07 285.15 1.78 1.63 -0.74 22-APR-00 MWD 2902.81 75.87 6.77 93.31 1973.32 1635.84 1609.75 296.10 0.84 0.74 -0.41 22-APR-00 MWD 2999.71 75.23 7.22 96.90 1997.50 1729.64 1702.88 307.52 0.80 -0.66 0.46 22-APR-00 MWD 3090.08 74.88 7.16 90.37 2020.81 1816.93 1789.51 318.45 0.39 -0.39 -0.07 22-APR-00 MWD 3184.67 75.31 7.32 94.59 2045.14 1908.32 1880.19 329.97 0.48 0.45 0.17 22-APR-00 MWD 3281.21 76.28 6.60 96.54 2068.83 2001.87 1973.09 341.31 1.24 1.00 -0.75 22-APR-00 MWD 3370.34 75.25 8.64 89.13 2090.74 2088.25 2058.71 352.76 2.50 -1.16 2.29 22-APR-00 MWD 3465.92 75.58 7.79 95.58 2114.81 2180.74 2150.26 365.98 0.93 0.35 -0.89 23-APR-00 MWD 3561.81 75.78 8.11 95.89 2138.53 2273.65 2242.28 378.83 0.38 0.21 0.33 23-APR-00 MWD 3656.00 75.47 8.21 94.19 2161.91 2364.89 2332.59 391.78 0.34 ~0.33 0.11 23-APR-00 MWD 3754.63 74.97 8.47 98.63 2187.08 2460.26 2426.95 405.61 0.57 -0.51 0.26 23-APR-00 MWD 3850.23 74.25 8.22 95.60 2212.45 2552.43 2518.15 418.99 0.79 -0.75 -0.26 ' 23-APR-O0 MWD 3941.10 73.53 9.00 90.87 2237.66 2639.73 2604.46 432.06 1.14 -0.79 0.86 JUL 07 23-APR-O0 MWD 4035.84 73.04 9.18 94.74 2264.91 2730.46 2694.06 446.39 0.55 -0.52 0.19 23-APR-O0 MWD 4128.62 72.84 9.46 92.78 2292.13 2819.15 2781.59 460.76 0.36 -0.22 0.30 /~,~ ~-~i ~ ~$ 23-APR-00 MWD 4225.31 74.40 8.28 96.69 2319.40 2911.91 2873.24 475.06 1.99 1.61 -1.22 ................. 23-APR-00 MWD 4318.01 74.47 8.92 92.70 2344.27 3001.21 2961.54 488.41 0.67 0.08 0.69 ___ 23-APR-00 MWD 4412.81 74.96 8.07 94.80 2369.26 3092.65 3051.98 501.92 1.01 0.52 -0.90 iiii .... Ilfllllf1111 II/[I I tiff i'1 f '~ta'ggll~':t,r~ :.-" [ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 04504)0026 Sidetrack No. _ ......... Page 3 of 4 Company PHILLIPS ALASKA, INC. Rig Contractor & No. NABORS - 16E Field KUPARUK RIVER UNIT ]I-' Il"! Well Name & No. PAD 2T/217 Survey Section Name Definitive Survey BHI Rep. R. BARNARD li~'r~~ WELL DATA Target TVD (I:T) Target Coord. N/S Slot Coord. N/S 768.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.370 Calculation Method MINIMUM CURVATURE Target Direction <DD~ Build\Walk\DL per: 100ft[~ 30m ~ 10m [--] Vert. Sec. Azim. 8.51 Magn. to Map Corr. 26.370 Map North to: OTHER I SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(_) DL Build (+) Right (+) Comment Type (vt) (D~) CDO~ ~F?) (FT) (FT) (FT) (Per 100 vr~ Drop (-) Left (-) 23-APR-00 MW'D 4507.94 73.92 7.55 9~i.13 2394.78 3184.29 3142.77 514.37 1.21 -1.09 -0.55 23-APR-00 MV4D 4603.77 74.27 7.42 95.83 2421.04 3276.43 3234.15 526.38 0.39 0.37 -0.14 23-APR-00 MWD 4696.84 74.05 7.70 93.07 2446.45 3365.96 3322.90 538.16 0.37 -0.24 0.30 23-APR-00 MWD 4792.58 73.70 7.80 95.74 2473.04 3457.92 3414.04 550.56 0.38 -0.37 0.10 23-APR-00 MWD 4887.74 73.28 8.46 95.16 2500.08 3549.16 3504.36 563.46 0.80 -0.44 0.69 23-APR-00 MWD 4976.89 72.76 7.76 89.15 2526.12 3634.42 3588.77 575.49 0.95 -0.58 -0.79 23-APR-00 MWD 5166.13 74.27 7.38 189.24 2579.81 3815.85 3768.64 599.39 0.82 0.80 -0.20 23-APR-00 MWD 5256.45 74.04 7.31 90.32 2604.47 3902.72 3854.81 610.50 0.27 -0.25 -0.08 .... 23-APR-00 MW-D 5354.50 73.76 7.42 98.05 2631.66 3996.90 3948.24 622.58 0.31 -0.29 0.11 23-APR-00 MW'D 5443.11 73.19 7.50 88.61 2656.87 4081.84 4032.47 633.61 0.65 -0.64 0.09 23-APR-00 MWD 5537.75 72.73 7.85 94.64 2684.60 4172.31 4122.15 645.69 0.60 -0.49 0.37 24-APR-00 . MXVD 5632.68 73.58 7.56 94.93 2712.11 4263.16 4212.18 657.87 0.94 0.90 -0.31 24-APR-00 MWD 5729.65 73.46 6.29 96.97 2739.62 4356.11 4304.49 669.08 1.26 -0.12 -1.31 . 24-APR-00 MWD 5827.20 73.03 5.83 97.55 2767.74 4449.43 4397.37 678.95 0.63 -0.44 -0.47 24-APR-00 MWD 5921.59 74.34 6.41 94.39 2794.26 4539.94 4487.44 688.60 1.51 1.39 0.61 __ 2n-APR-00 MWD 6014.00 73.93 6.76 92.41 2819.52 4628.78 4575.75 698.80 0.57 -0.44 0.38 . .......................... 24-APR-00 MWD 6108.36 75.55 8.38 94.36 2844.36 4719.79 4665.98 710.79 2.39 1.72 1.72 24-APR-00 MWD 6174.20 75.27 8.01 65.84 2860.94 4783.51 4729.05 719.88 0.69 -0.43 -0.56 29-APR-00 MWD 6291.64 74.60 7.84 117.44 2891.47 4896.91 4841.37 735.51 0.59 -0.57 -0.14 6-3/4~ MACH IX - 1.4 DEG AKO 29-APR-00 MWD 6385.00 73.71 8.48 93.36 2916.96 4986.71 4930.27 748.26 1.16 -0.95 0.69 29-APR-00 MWD 6478.40 73.20 8.58 93.40 2943.55 5076.25 5018.81 761.54 0.56 -0.55 0.11 29-APR-00 MWD 6571.00 72.74 7.99 92.60 2970.67 5164.79 5106.42 774.30 0.79 -0.50 -0.64 29-APR-00 MWD 6665.08 72.70 8.52 94.08 2998.62 5254.62 5195.33 787.20 0.54 -0.04 0.56 29-APR-00 MWD 6763.38 72.62 7.87 98.30 3027.92 5348.45 5288.20 800.57 0.64 -0.08 -0.66 -' l I~[[-' I ::::~"1~1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. NABORS - 16E Field KUPARUK RIVER UNIT m~ ~,,,lml~'~. Well Name & No. PAD 2T/217 Survey Section Name Definitive Survey BHI Rep. R. BARNARD ..... ~ELL DATA ..... 'Target TVD (FT) Target Coord. N/S Slot Coord. N/S 768.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.370 Calculation Method MINIMUM CURVATURE -- Target Direction (OD) Build\Walk\DL per: 100ft[~ 30m[3 10m [3 Vert. Sec. Azim. 8.51 Magn. to Map Corr. 26.370 Map North to: OTHER II I I Ill II II II Illl Ill SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / St-) Et+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per J00 FT) Drop (-) Left (-) 29-APR-00 MWD 6857.03 72.08 7.44 9~[.65 3056.31 . 5437.68 5376.65 812.46 0.72 -0.58 -0.46 ! 29-APR-00 MWD 6909.35 73.08 7.16 52.32 3071.97 5487.59 5426.16 818.80 1.98 1.91 -0.54 13-MAY-00 MWD 6998.75 72.73 8.01 89.40 3098.25 5573.03 5510.86 830.08 0.99 -0.39 0.95 4-3/4" MACH1 X - 1.2 DEG AKO , 13-MAY-00 MWD 7094.63 71.48 6.58 95.88 3127.72 5664.24 5601.36 841.67 1.93 -1.30 -1.49 .. 13-MAY-00 MWD 7195.80 70.30 7.40 101.17 3160.84 5759.80 5696.24 853.30 1.40 -1.17 0.81 13-MAY-00 MWD 7292.47 69.43 7.37 96.67 3194.12 5850.54 5786.25 864.97 0.90 -0.90 4).03 13-MAY-00 MWD 7387.73 68.00 8.20 95.26 3228.69 5939.30 5874.19 876.99 1.71 -1.50 0.87 13-MAY-00 MWD 7484.82 66.97 7.09 97.09 3265.87 6028,97 5963.08 888.92 1.50 -1.06 -1.14 , , 13-MAY-00 MWD 7579.08 65.53 7.04 94.26 3303.84 6115.22 6048.70 899.53 1.53 -1.53 -0.05 ,. 13-MAY-00 MWD 7672.98 64.70 7.18 93.90 3343.35 6200.38 6133.23 910.08 0.89 -0.88 0.15 13-MAY-00 MWD 7768.89 63.41 5.06 95.91 3385.31 6286.54 6218.97 919.28 2.40 -1.35 -2.21 13-MAY-00 -MWD 7864.89 62.71 5.65 96.00 3428.81 6371.99 6304.18 927.26 0.91 -0.73 0.61 -- 13-MAY-00 MWD 7930.00 62.71 5.65 65.11 3458.66 6429.78 6361.76 932.96 0.00 0.00 0.00 PROJECTED DATA - No Data ;,. . · I Ill I II II II Date: 06/23/00 ARCO ALASKA INC. WELL SLrMMARY REPORT Page: 1 WELL:2T-217 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WEST SAK SPUD:04/21/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20334-00 04/20/00 (D1) TD/TVD: 117/117 SUPV:G.R. WHITLOCK MW: 8.8 VISC: 295 PV/YP: 34/47 ( 117) CHANGING AIRBOOT IN BELL NIPPLE APIWL: 9.2 prep rig for move. Move rig to 2T-218. NU diverter system. Accept rig ~ 0900 hrs 4/20/00. Function test diverter and hold pre-spud meeting. 04/21/00 (D2) MW: 9.1 VISC: 220 PV/YP: 29/41 APIWL: 7.8 TD/TVD: 1169/1000 (1052) DRILLING ~ 1650' SUPV:G.R. WHITLOCK Tag ~ 96' Fill hole. Airboot in bell nipple leaking. POOH. Change airboot. RIH. Drill from 96' to 1169' 04/22/00 (D3) MW: 9.5 VISC: 205 PV/YP: 43/68 APIWL: 6.2 TD/TVD: 3333/2081 (2164) DRILLING ~ 3900' SUPV:G.R. WHITLOCK Drill from 1169' to 3333'. Pump sweep. Circ until clean. Short trip 10 stands to 2389' Tight @ 2768' and 2518'. RIH w/no problems. Circ after wiper trip. 04/23/00 (D4) MW: 9.8 VISC: 204 PV/YP: 33/49 APIWL: 5.4 TD/TVD: 5227/2081 (1894) DRILLING ~ 5700' SUPV:G.R. WHITLOCK Circ hole clean. Drill from 3333' to 4325' Well appears to be flowing on connections. Circ and increase weight to 9.8 ppg. Drill from 4325' to 5227'. 04/24/00 (D5) MW: 10.0 VISC: 188 PV/YP: 32/46 APIWL: 5.0 TD/TVD: 6228/2881 (1001) SUPV:G.R. WHITLOCK Drill from 5227' to 6228'. Pump sweep and CBU. Pull 5 stands. Pump out of hole to 3811'. POOH to 2350'. RIH. Pump Sweep. Circ. 04/25/00 (D6) TD/TVD: 6228/2881 ( SUPV:G.R. WHITLOCK MW: 10.0 VISC: 65 PV/YP: 29/34 APIWL: 6.2 0)CIRC AND CONDITION MUD PRIOR TO CEMENTING Circ and condition mud for casing run. POOH. Backream to HWDP ~ 1077'. Hold safety meeting. Run 9-5/8" casing. RIH to 3040'. Circ and condition mud. ,JUL 0 7 ooo Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/26/00 (D7) TD/TVD: 6228/2881 ( SUPV:G.R. WHITLOCK MW: 9.8 VISC: 47 PV/YP: 19/19 0 N/U BOPE APIWL: 6.8 RIH w/9-5/8" casing. CBU ~ 4560' RIH to 6213'. Circ and condition mud. Cement casing. Bump plug, floats, OK. ND diverter. N/U BOPE. 04/27/00 (D8) MW: 9.5 VISC: 44 PV/YP: 14/10 APIWL: 6.8 TD/TVD: 6228/2881 ( 0) M/U BHA SUPV:G.R. WHITLOCK NU BOPE and test to 250/5000 psi. Top rams failed test, change out. Test floor valves, IBOP's, blinds to 250/5000 psi. RIH to 6000'. Break circ. tag at 6085' 04/28/00 (D9) MW: 9.4 VISC: 43 PV/YP: 14/14 TD/TVD: 6248/2881 ( 20) DRILLING ~ 6675' SUPV:G.R. WHITLOCK APIWL: 7.4 Wash and work magnet. POOH. Circ out thick mud. Hold pre-job safety meeting. Perform stripping drill. Trip in to 6080'. Circ and condition mud. Test casing to 3000 psi for 30 min. OK. Drill cement and float equipment. Drill from 6228' to 6248'. CBU. Perform LOT to 16.1 ppg. perform PWD baseline test. 04/29/00 (D10) MW: 9.5 VISC: 47 PV/YP: 18/24 APIWL: 5.2 TD/TVD: 6975/3091 ( 727) RIH W/ 7" LINER SUPV:G.R. WHITLOCK Drill from 6248' to 6975'. Circ sweep around. Monitor well. POOH to 6173'. RIH. Circ sweep and add lubricants. POOH wet to shoe. Pump pill and drop rabbit. Safety meeting. 04/30/00 (Dll) TD/TVD: 6975/3091 ( SUPV:G.R. WHITLOCK MW: 9.6 VISC: 44 PV/YP: 15/17 0) RUNNING KILL STRING APIWL: 5.4 Safety meeting. RIH w/7" liner. CBU. Pump cement. Set liner hanger and liner top packer. Test casing and liner to 3000#, OK. 05/01/00 (D12) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6975/3091 ( 0) RIG RELEASED TO 2T-204. N/D XMAS TREE SUPV:G.R. WHITLOCK POOH. Safety meeting. Run 4.5" tubing. Freeze protect with diesel. Safety meeting. N/D BOP stack. N/U Xmas tree and test to 250/5000#, OK. Released rig @ 2400 hrs. 5/1/00. 05/11/00 (D13) TD/TVD: 6975/3091 ( SUPV:FRED HERBERT MW: 0.0 VISC: 0) P/U DP 0 PV/YP: 0/ 0 APIWL: 0.0 Jack up rig, move to 2T-218. Spot rig over well. Rig accepted on 2T-218 @ 1100 hrs. ND tree. NU BOPE. Pull 4.5" tubing Test BOPE to 250/3000 psi. JUL 0 7 2000 Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/12/00 (D14) MW: 9.2 VISC: 49 PV/YP: 14/24 TD/TVD: 7028/3108 ( 53) DRILLING AHEAD @ 7370 SUPV:FRED HERBERT APIWL: 4.0 Test BOPE complete to 250/3000. PJSM. Tag cement stringers ~ 6730' Clean out to 6750'. Displace well w/9.2 LSND mud. Vac truck problems unloading mud. Clean out cement stringers from 6750' to 6846' Circ out cement contaminated mud. Test casing to 3000psi. Drill cement. Drill 20' new hole to 6995'. Circ for FIT. Perform FIT to 13.7 ppg. Displace well w/baradrill-n mud. Drilling from 6996' to 7028' 05/13/00 (D15) MW: 9.3 VISC: 51 PV/YP: 20/29 APIWL: 4.6 TD/TVD: 7930/3459 (902) POOH SUPV:FRED HERBERT Drilling from 7028' to 7930'. Circ sweep around, monitor well, pump slug. POOH to shoe. 05/14/00 (D16) MW: 9.2 VISC: 46 PV/YP: 12/21 APIWL: 9.2 TD/TVD: 7930/3459 ( 0) RIH W/ CIBP SUPV:FRED HERBERT POOH 20 stands. Well flowing (breathing). RIH slow. Circ & even mud out ~ 9.3+ppg. Monitor well. POOH to shoe. PJSM. RIH with cement retainer. Set ~ 6880'. Sting into retainer. Pump cement. POOH. 05/15/00 (D17) MW: 9.2 VISC: 46 PV/YP: 12/21 APIWL: 9.2 TD/TVD: 7930/3459 ( 0) RIG RELEASED ~ 09:00 HRS F/ 2T-218 TO 2T-218A SUPV:FRED HERBERT/MOOSE CUNNINGHAM Hold PJSM. Circulate hole clean. Pick up bridge plug and RIH slow to 5014'. Drop ball. Pump ball to seat. Set bridge plug and check, OK. Release rig from 2T-218 ~ 0900 hrs. 5/15/00 WELL:2T-217A STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TABASCO SPUD:05/15/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: -- WI: 0% SECURITY:0 API NUMBER: 50-103-20291-01 05/15/00 (D1) MW: 9.8 VISC: 55 PV/YP: 21/30 APIWL: 6.4 TD/TVD: 0/3459 ( 0) CIRC FOR LOT SUPV:FRED HERBERT / MOOSE CUNNINGHA Hold PJSM. RIH slow with Whipstock, set ~ 5015' Change over mud system to 9.8# mud. Cut window from 4991' to 4996' Mills hung up, work pipe free while circulating sweep. Cut window from 4996' to 4997' ,JUL 0 7 2O00 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) .265-6224 July 6, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 2T-217 P&A (200-045) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the P&A operations on 2T-217. It will be sidetracked and re-named to 2T-217A. If you have any questions regarding this matter, please contact me at 265-6120 or Tom Brockway at 263-4135. Sincerely, G. C. Alvord Drilling Engineering Supervisor PA1 Drilling GCA/skad ] [[IfA'-I::~"l Company PHILLIPS ALASKA, INC. Rig Contractor & No. NABORS - 16E Field KUPARUK RIVER UNIT I1 I Well Name & No. PAD 2T/217 Survey Section Name Definitive Survey BHI Rep. R. BARNARD I~ WELL DATA Target TVD (Ir) Target Coord. N/S Slot Coord. N/S 768.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 26.370 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m ~ Vert. Sec. Azim. 8.51 Magn. to Map Corr. 26.370 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Ir) (DD) (DD) (FT) (FT) (FT) (Ir) (Per 100 Ir) Drop (-) Left (-) - 0.00 0.00 0.00 I 0.00 0.00 0.00 0.00 TIE IN POINT 21-APR-00 MWD 141.12 0.28 330.43 141.12 141.12 0.27 0.30 4).17 0.20 0.20 9.5" MACH lC - 1.6 AKO 21-APR-00 MWD 200.79 1.29 34.56 59.67 200.78 0.99 0.98 0.14 2.00 1.69 __ 21-APR-00 MWD 288.22 4.74 48.18 87.43 288.08 4.66 4.20 3.39 4.00 3.95 -- 21-APR-00 MWD 381.06 6.12 52.76 92.84 380.50 11.15 9.75 10.19 1.56 1.49 4.93 21-APR-00 MWD 469.80 7.06 53.46 88.74 468.65 18.40 15.86 18.34 1.06 1.06 0.79 2 I-APR4)0 MWD 561.54 7.79 47.16 91.74 559.63 27.25 23.45 27.43 1.19 0.80 -6.87 21-APR-00 MWD 649.13 9.16 38.28 87.59 646.26 37.94 32.96 36.10 2.16 1.56 -10.14 2 I-APR-00 MWD 743.97 11.84 27.53 94.84 739.51 53.69 47.51 45.27 3.49 2.83 -11.33 __ -. 2 I-APR4)0 MWD 835.96 15.75 16.92 91.99 828.85 74.98 67.84 53.27 5.05 4.25 -11.53 21-APR4)0 MWD 927.58 18.31 14.26 91.62 916.44 101.60 93.69 60.44 2.92 2.79 -2.90 21-APR4)0 MWD 1020.01 21.34 , 14.47 92.43 1003.39 132.78 124.05 68.22 3.28 3.28 0.23 21-APR-00 MWD 1111.95 24.42 12.18 91.94 1088.08 168.39 158.84 76.41 3.49 3.35 -2.49 2 I-APR-00 MWD 1206.00 29.23 10.00 94.05 1171.99 210.78 200.48 84.51 5.22 5.11 -2.32 22-APR4)0 MWD 1297.74 32.24 10.00 91.74 1250.84 257.64 246.65 92.65 3.28 3.28 0.00 22-APR4)0 MWD 1397.16 35.99 9.74 99.42 1333.13 313.38 301.57 102.20 3.77 3.77 -0.26 22-APR4)0 MWD 1490.99 39.02 9.85 93.83 1407.56 370.48 357.86 111.92 3.23 3.23 0.12 · 22-APR4)0 MWD 1586.10 44.67 9.44 95.11 1478.38 433.89 420.39 122.53 5.95 5.94 4).43 ~ ~ ~ v--~ ...... t.~" ~" ~ 22-APR-00 MWD 1675.20 49.78 8.55 89.10 1538.87 499.27 484.97 132.73 5.78 5.74 -1.00 22-APR-00 MWD 1774.11 55.02 8.02 98.91 1599.20 577.61 562.49 144.01 5.31 5.30 -0.54 ~ - 22-APR-O0 MWD 1863.77 59.04 8.66 89.66 1647.98 652.81 636.90 154.92 4.52 4.48 0.71 ................................................................ ~ - ~:~i--~ ?_; ..... ~--~ 22-APR-00 MWD 1962.81 62.29 8.78 99.04 ' 1696.50 739.14 722.23 168.01 3.28 3.28 0.12 ~185J~ L)~I c~ ~$ L~$ '~::::: ' · ' . ..................... 22-APR-00 MWD 2052.40 67.12 9.12 89.59 1734.77 820.11 802.22 180.62 5.40 5.39 0.38 · " 22-APR-00 MWD 2145.97 71.23 8.26 93.57 1768.03 907.55 888.65 193.82 4.48 4.39 4).92 24-May-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-217 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 7,930.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager JUN 01 2000 Alaska 011 & Gas Co'ns. Commission Anchorage Attachment(s) North Slope Alaska Alaska State Plane 4 Kuparuk 2T 2T-217 Surveyed: 14 May, 2000 SURVEY REPORT OR G 'qAL 24 May, 2000 Your Ref: API-501032033400 Surface Coordinates: 5970734.97N, 498944.82 E (70° 19' 52.5963" N, 150° 00' 30.8117" W) Kelly Bushing: 114.80ft above Mean Sea Level RECEIVED JUN 01 2000 Alaska 0ii & Gas Cons. Commission Anchorage hi:Il L LIH(] Survey Ref: svy9216 A 14ALI.IBUBTON COMPAN~ Sperry-Sun Drilling Services Survey Report for 2T-217 Your Ref: API-501032033400 SUrveyed: 14 May, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -114.80 0.00 100.00 0.000 0.000 -14.80 100.00 141.12 0.280 330.430 26.32 141.12 200.79 1.290 34.560 85.98 200.78 288.22 4.740 48,180 173.28 288.08 381.06 6.120 52.760 265.70 380.50 469.80 7.060 53.460 353.85 468.65 561.54 7.790 47.160 444.83 559.63 649.13 9.160 38.280 531.46 646.26 743.97 11.840 27,530 624.71 739.51 835.96 15.750 16.920 714.05 828.85 927.58 18.310 14.260 801.64 916.44 1020.01 21.340 14,470 888.59 1003.39 1111.95 24,420 12,180 973.28 1088.08 1206.00 29.230 10,000 1057.19 1171.99 1297.94 32.240 10,000 1136.21 1251.01 1397.16 35.990 9,740 1218.34 1333.14 1490.99 39.020 9,850 1292.77 1407.57 1586.10 44.670 9,440 1363.59 1478.39 1675.20 49.780 8.550 1424.08 1538.88 1774.11 55,020 8.020 1484.41 1599.21 1863.77 59.040 8.660 1533.19 1647.99 1962.81 62.290 8.780 1581.71 1696.51 2052.40 67,120 9.120 1619.97 1734.77 2145.97 71,230 8.260 1653.23 1768.03 0.00 N 0.00 E 5970734.97 N 0.00 N 0.00 E 5970734.97 N 0.09 N 0.05W 5970735.06 N 0.77 N 0.26 E 5970735.74 N 3.99 N 3.51E 5970738.96 N 9.54 N 10.31E 5970744.51N 15.65 N 18.46 E 5970750.62 N 23.23 N 27.55 E 5970758.20 N 32.74 N 36.22 E 5970767.71 N 47.30 N 45.39 E 5970782.27 N 67.63 N 53.39 E 5970802.59 N 93.48 N 60.56 E 5970828.44 N 123.84 N 68.34 E 5970858.80 N 158.62 N 76.53 E 5970893.58 N 200.27 N 84.63 E 5970935.22 N 246.53 N 92.79 E 5970981.49 N 301.35 N 102.32 E 5971036.31 N 357.64 N 112.04 E 5971092.59 N 420.17 N 122.65 E 5971155.12 N 484.74 N 132.85 E 5971219.70 N 562.27 N 144.13 E 5971297.22 N 636.67 N 155.04 E 5971371.62 N 722.00 N 168.13 E 5971456.95 N 801.99 N 180.74 E 5971536.94 N 888.43N 193.94 E 5971623.37 N Alaska State Plane 4 Kuparuk 2T Dogleg Vertical Rate Section (°/100ft) (ft) Comment 498944.82 E 0.00 498944.82 E 0.000 0.00 498944.77 E 0.681 0.08 498945.08 E 2.002 0.80 498948.33 E 4.003 4.46 498955.13 E 1.557 10.96 498963.28 E 1.063 18.21 498972,37 E 1.191 27.05 498981.04 E 2.159 37.74 498990.22 E 3.489 53.50 498998.22 E 5.046 74.78 499005,39 E 2.920 101.41 499013.18 E 3.279 132.59 499021.37 E 3.487 168.20 499029.47 E 5,219 210.58 499037,64 E 3.274 257.55 499047.18 E 3.782 313.17 499056.91E 3,230 370.28 499067.53 E 5.947 433.69 499077.74 E 5.782 499,07 499089.03 E 5.315 577.40 499099.95 E 4.523 652.61 499113.05 E 3.283 738.94 499125.67 E 5.402 819.91 499138.88 E 4.476 907.35 RECEIVED JUN 0 1 2000 Alaska Oii & Gas t,.~:~. ,.,u,,,,,,,o .... Anchorage Continued... 24 May, 2000 - 14:48 - 2 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for 2T-217 Your Ref: A PI-501032033400 Surveyed: 14 May, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2T Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section (°/100fi) (fi) Comment 2238.83 2332.73 2427.50 2522.94 2619.34 2714.63 2809.5O 2902.81 2999.71 3090.08 3184.67 3281.21 3370.34 3465.92 3561.81 3656.00 3754.63 3850.23 3941.10 4035.84 4128.62 4225.31 4318.01 4412.81 4507.94 74.290 74,370 74.370 74.610 74.070 73.630 75.180 75.870 75.230 74.880 75.310 76.280 75.250 75.580 75.780 75.470 74.970 74.250 73.530 73.040 72.840 74,400 74,470 74.960 73.92O 9.200 1680.75 1795.55 976.08 N 207.40 E 5971711.02 N 499152.36 9.260 1706.11 1820.91 1065.32 N 221.90 E 5971800.25 N 499166.87 8.190 1731.65 1846.45 1155.52 N 235.75 E 5971890.46 N 499180.73 8.690 1757.17 1871.97 ' 1246.49 N 249.25 E 5971981.43 N 499194.24 6,750 1783,19 1897.99 1338.47 N 261;72 E 5972073.40 N 499206.72 7.850 1809,70 1924.50 1429.25 N 273.35 E 5972164.18 N 499218.37 7.150 1835,20 1950.00 1519.85 N 285.27 E 5972254.78 N 499230.30 6.770 1858.53 1973.33 1609.53 N 296.22 E 5972344.46 N 499241.26 7.220 1882,71 1997.51 1702.66 N 307.64 E 5972437.59 N 499252.70 7,160 1906.01 2020.81 1789.29 N 318.57 E 5972524.21 N 499263.64 7.320 1930.34 2045.14 1879.97 N 330.09 E 5972614.89 N 499275.18 6,600 1954.03 2068.83 1972.86 N 341.43 E 5972707.79 N 499286.53 8.640 1975.95 2090.75 2058.49 N 352.88 E 5972793.41 N 499297.99 7,790 2000.02 2114.82 2150.04 N 366.10 E 5972884.96 N 499311.22 8.110 2023.74 2138.54 2242.06 N 378.95 E 5972976.97 N 499324.09 8.210 2047.12 2161.92 2332.37 N 391.90 E 5973067.29 N 499337.05 8.470 2072.28 2187.08 2426.73 N 405.73 E 5973161.64 N 499350.89 8,220 2097.65 2212.45 2517.93 N 419.11 E 5973252.84 N 499364.28 9.000 2122.87 2237.67 2604.24 N 432.18 E 5973339.15 N 499377,37 9.180 2150.12 2264.92 2693.84 N 446.51E 5973428.75 N 499391.71 9.470 2177.34 2292.14 2781.37 N 460.89 E 5973516.27 N 499406.10 8.280 2204.60 2319.40 2873.02 N 475.19 E 5973607.92 N 499420.42 8.920 2229.48 2344.28 2961.31N 488.55 E 5973696.21N 499433.78 8.070 2254.47 2369.27 3051.75 N 502.05 E 5973786.65 N 499447.30 7.550 2279.99 2394.79 3142.55 N 514.51 E 5973877.44 N 499459.77 E 3.434 996.02 E 0.105 1086.42 E 1.087 1177.69 E 0.564 1269.65 E 2.017 1362.46 E 1.201 1453.97 E 1.782 1545.33 E 0.838 1635.64 E 0.799 1729.44 E 0.393 1816.73 E 0.483 1908.12 E 1.238 2001.67 E 2.501 2088.05 E 0.927 2180.54 E 0.385 2273.45 E 0.345 2364.69 E 0.567 2460.05 E 0.794 2552.22 E 1.144 2639.52 E 0.548 2730.26 E 0.368 2818.95 E 1.999 2911.70 E 0.669 3001.00 E 1.008 3092.45 E 1.213 3184.08 RECEIVED 24 May, 2000 - 14:48 -3- JUN 0 1 2000 Alaska Oil & Gas Cons. Comm-J~sTo~ Continued... DrillQuest 1.05.05 Anchorage Sperry-Sun Drilling Services Survey Report for 2T-217 Your Ref: API-501032033400 Surveyed: 14 May, 2000 North Slope Alaska Measured Depth (ft) Incl. 4603.77 74.270 4696.81 74,050 4792.58 73.700 4887.71 73.280 4976.89 72.760 5071.79 72.990 5166.13 74,270 5256.45 74.040 5354.50 73.760 5443.11 73.190 5537.75 72.730 5632.68 73.580 5729.65 73.460 5827.20 73,030 5921.59 74,340 6014.00 73.930 6108.36 75.550 6174.20 75.270 6291.64 74,600 6385.00 73,710 6478.40 73,200 6571.00 72.740 6665,08 72.700 6763.38 72.620 6857.03 72.080 Azim. 7.420 7,700 7.800 8.460 7.760 6.460 7.380 7.310 7.420 7.500 7.850 7.560 6.290 5.830 6.410 6.760 8.380 8.010 7.840 8.480 8.580 7.990 8,520 7.870 7,440 Sub-Sea Depth (ft) 2306.25 2331.64 2358.24 2385.28 2411.32 2439.27 2465.86 2490.52 2517.71 2542.91 2570.64 2598.15 2625,66 2653,78 2680.30 2705.56 2730,40 2746,98 2777,51 2803.00 2829.60 2856,72 2884.66 2913.96 2942.35 Vertical Depth (ft) 2421.05 2446.44 2473.04 2500.08 2526.12 2554.07 2580.66 2605.32 2632.51 2657.71 2685.44 2712.95 2740.46 2768.58 2795.10 2820.36 2845.20 2861.78 2892.31 2917.80 2944.40 2971.52 2999.46 3028.76 3057.15 Local Coordinates Northings Eastings (ft) (ft) 3233.92N 526.51 E 3322.65 N 538.29 E 3413.81 N 550.70 E 3504.10 N 563.59 E 3588.54 N 575.63 E 3678.53 N 586.85 E 3768.39 N 597.76 E 3854,56 N 608.87 E 3947,99 N 620.94 E 4032,22 N 631.97 E 4121.89 N 644.06 E 4211.93 N 656.24 E 4304.24 N 667.45 E 4397.12 N 677.31E 4487.19 N 686.97 E 4575.49 N 697.16 E 4665.73 N 709.16 E 4728.79 N 718.24 E 4841.11 N 733.88 E 4930.02 N 746.62 E 5018.56 N 759.90 E 5106.17 N 772.66 E 5195.08 N 785.56 E 5287.95 N 798.94 E 5376.39 N 810.82 E Alaska State Plane 4 Kuparuk 2T Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/100fi) (ft) 24 May, 2000- 14:48 5973968.82 N 499471.79 E 0.388 3276.23 5974057.54 N 499483.58 E 0.374 3365.73 5974148.70 N 499496.00 E 0.379 3457.72 5974238.99 N 499508.91 E 0.798 3548.92 5974323.43 N 499520.95 E 0.951 3634.21 5974413.42 N 499532.19 E 1.331 3724.88 5974503.27 N 499543.11 E 1.648 3815.35 5974589.45 N 499554.23 E 0.265 ' 3902.22 5974682.87 N 499566.32 E 0.305 3996.41 5974767.10 N 499577.36 E 0.649 4081.35 5974856.77 N 499589.46 E 0.601 4171.82 5974946.81 N 499601.65 E 0,942 4262.67 5975039.11 N 499612.87 E 1.262 4355.62 5975132.00 N 499622.75 E 0.631 4448.94 5975222.06 N 499632.42 E 1.508 4539.45 5975310.37 N 499642.63 E 0.574 4628.29 5975400.60 N 499654.64 E 2.385 4719.30 5975463.66 N 499663.73 E 0.690 4783.02 5975575.98 N 499679.38 E 0,587 4896.41 5975664.88 N 499692.14 E 1.159 4986.22 5975753.42 N 499705.43 E 0.556 5075.76 5975841.03 N 499718.20 E 0.786 5164.29 5975929.93 N 499731.11 E 0.540 5254.13' 5976022.81 N 499744.50 E 0.636 5347.96 5976111.25 N 499756.40 E 0.724 5437.19 -4- RECEIVED JUN 0 t 2000 Comment Continued... Alaska Oil & Gas Anchorage DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for 2T-217 Your Ref: AP1-$01032033400 Surveyed: 14 May, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 6909.35 73.080 7.160 2958.02 3072.82 5425.91 N 817.17 E 6998.09 72.730 8.010 2984.10 3098.90 5509.99 N 828.36 E 7094.52 71.480 6.580 3013.73 3128.53 5601.00 N 840.02 E 7195.80 70.300 7.400 3046.89 3161.69 5695.99 N 851.66 E 7292.47 69.430 7.370 3080.17 3194.97 5786.00 N 863.33 E 7389.85 68.010 8.200 3115.51 3230.31 5875.90 N 875.62 E 7484.82 66.970 7.090 3151.87 3266.67 5962.85 N 887.29 E 7579.08 65.530 7.040 3189.83 3304.63 6048.47 N 897.90 E 7672.98 64.700 7.180 3229.34 3344.14 6132.99 N 908.44 E 7768.89 63.410 5.060 3271.31 3386.11 6218.74 N 917.65 E 7864.89 62.710 5.650 3314.80 3429.60 6303.94 N 925.63 E 7930.00 62.710 5.650 3344.65 3459.45 6361.53 N 931.33 E 5976160.76 N 499762.75 E 5976244.84 N 499773.96 E 5976335.85 N 499785.63 E 5976430.84 N 499797.28 E 5976520.84 N 499808.96 E 5976610.74 N 499821.26 E 5976697.69 N 499832.95 E 5976783.31 N 499843.57 E 5976867.84 N 499854.13 E 5976953.58 N 499863.34 E 5977038.78 N 499871.34 E 5977096.37 N 499877.04 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. Alaska State Plane 4 Kuparuk 2T Dogleg Vertical Rate Section (°ll00ff) (fi) 1.978 5487.10 0.997 5571.90 1.916 5663.64 1.394 5759.31 0.900 5850.05 1.660 5940.78 1.538 6028.50 1.528 6114.75 0.894 6199.90 2.400 6286.06 0.912 6371.52 0.000 6429.31 Comment Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 8.510° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7930.00ft., The Bottom Hole Displacement is 6429.34ft., in the Direction of 8.329° (True). R CF..lX/ED JUN 01 Aiask~ Oit & 6~s Co,~s. Oom.missio~ AnChorage Continued... 24 May, 2000 - 14:48 - 5 - DrillQuest ~.05.05 Sperry-Sun Drilling Services Survey Report for 2T-217 Your Ref: API-501032033400 SUrveyed: 14 May, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2T Comments Measured Depth (ft) 7930.00 Station Coordinates TVD Northings Eastings (fi) (ft) (ft) 3459.45 6361.53 N 931.33 E Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.oo o.oo To Measured Vertical Depth Depth (ft) (ft) 7930.00 3459.45 Survey Tool Description MWD Magnetic RE£EIVED JUN 0 ~ ~00~, 0it & G~s C0,~s. Commission 24 May, 2000 - 14:48 - 6. DrillQuest 1.05.05 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 _ Time extension _ Stimulate _ Other _× Change approved program _ Pull tubing _ Variance _ Perforate _ To re-name 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 service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 755' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-218 -'~'~COCJ~,~' At top of productive interval 9. Permit number/approval number 927' FSL, 2356' FEL, Sec. 36, T12N, R8E, UM 200-45 At effective depth 10. APl number 50-103-20334-00 At total depth 11. Field / Pool 1326' FSL, 1620' FEL, Sec. 36, T12N, R8E, UM Kuparuk River Field/Tabasco Oil Pool 12. Present well condition summary Total depth: measured 6975' feet Plugs (measured) true vertical 3091' feet Effective depth: measured 6975' feet Junk (measured) true vertical 3091' feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 82' 16" 9 cu yds High Early 117' 117' Surface 6178' 9-5/8" 803 sx AS III L & 871 Sx Class G 6213' 2880' Production 6940' 7" 2s5 sx Class (~ 6975' 3091' liner NOTE: The attached May 22,2000 letter from our Steve Davies to your Thomas Brockway explains that: 2T-218 becomes 2T-217 with PTD 200-045, APl 50-103-20334-00, . 2T-218A becomes 2T-217A with PTD 200-074, APl 50-103-20334-01 and APl 50-103-20291-01 is cancelled ns. C0~m~ssl° 'ago 13. Attachments Description summary of proposal__ Detailed operations program__ B~)P-~ketch __ 14. Estimated date for commencing operation 15. Status of well classification as: May 22, 2000 16. If proposal was verbally approved Oil __X Gas m Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Questions? Call Tom Brockway263-4135 Signed ,~ 1/' Title: Drilling Team Leader Date / FOR COMMISSION USE ONLY Conditions of approval: PlugNOtify Commission so representative may witneSSintegrity__ BOP Test_ Location clearance_ I Appr°val n°'~2~O(~' Mechanical Integrity Test_ Subsequent form required 10- JU'O~t Approved..b.¥ order o,..t.h.e Commi.~..ion ... D Taylor Seamount ~Q:[~ssioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 18-May-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ~0o. Oq ~ Re: Distribution of Survey Data for Well 2T-218 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 7,930.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) U/~¥ 25 2000 Alaska Oil & Gas Cons. Commisslor~ Anchorage Allen, Ken From: Sent: To: Subject: Jim Galvin [Jim Galvin at SSDSAK] Wednesday, May 24, 2000 3:05 PM Tim Flynn; Ken Broussard; Farrah Koecher; Judy Urbatsch; Rob Kalish; Greg Griffin; William Allen; Ken Allen Re:Renaming 2T-218/218A to 2T-217/217A All, Important - read below. A name change is being made to wells 2T-218 (AK-MM-00026)and 2T-218A (AK-MM-0047) . The new names will be 2T-217 and 2T-217A. The original job numbers assigned for 2T-218 / 2T-218A will NOT change with the new names. I have already gone into TRAX and edited the job data to reflect the new well names. Please review all billing, invoices, field data, survey data, etc. and insure this name change is incorporated to reflect the name changes. Jim Reply Separator Subject: Renaming 2T-218/218A to 2T-217/217A Author: "Thomas A Brockway" <TBROCKW@ppco.com> Date: 5/24/00 10:56 AM Team, As you may be aware, a surface location discrepancy discovered last week at Nabors 16E while drilling the planned 2T-218A sidetrack. It was found that the rig had inadvertently rigged up over the 2T-217 conductor slot~ located 12.5' south of the original 2T-218 location. Although the planned target and BHL coordinate's did not change for the affected original well and ongoing sidetrack, the positional surveys showing actual wellbore locations required a 12.5' shift to reflect the change in surface location. In addition, this discrepancy also created nomenclature (2T-217 vs 2T-218) differences between the drilling and surface facilities groups which could, if unchanged, result in a great deal of future confusion within Phillips and with the state regulatory agencies. After discussions within Phillips Alaska and with the AOGCC commisSioners, it was decided that the best way to head off any future problems would be to change the name of the original well and current sidetrack from 2T-218/218A to 2T-217/217A. By doing this we will match all of the downhole wellbore nomenclatures with existing surface as-builts and facilities documents. In order to complete the renaming process we will need to address the following: 1) The paperwork required by the AOGCC has been completed and will be submitted to the state today. 2) Sharon will begin revising the Lotus notes morning reports and ADOCS databases to reflect the name and location changes to 2T-217/217A. 3) I have revised wellplan for the current sidetrack reflecting the name and location change to 2T-217A and attached a copy below (there are no other changes to this wellplan from the 2T-218A version that was originally distributed) . In addition, I will also begin modifying the drilling web page. 4) name s AFCg's will not change, but should be modified to reflect the new well 5) Ail Inteq and Sperry directional and logging databases will need to be modified to reflect the name changes (these databases have already been revised to reflect the change in surface location). 6) Phillips internal survey geology databases will need to be modified to reflect the name and location changes 7) All rig generated reports and handover forms should be modified to reflect the name changes 8) Co-owners should be notified as necessary 9) All new billing should reflect the change to 2T-217/217A !0) All hard copy LWD, PWD, and drill pipe conveyed log headers should reflect the 2T-217 / 217A name change !1) The master well files for these wells will need to be modified to show the new name and location change. Please begin the change to the new well names ASAP. If you have any questions or comments or notice anything that I've missed on the above list please give me a call. Thanks for the help and sorry for the extra work and confusion that these changes are bound to create. Tom Brockway Operations Drilling Engineer 263-4135 tbrockw@ppco.com ALASKA OIL AND GAS CONSERVATION COPlPllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 22, 2000 Thomas Brockway Operations Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 RE: Change of Well Number and API Number for Selected Kuparuk River Unit Pad 2T Wells Dear Mr. Brockway: To cleanly recover from several errors, please make the following changes to your files, databases and on all information transmitted, to the AOGCC for the following wells: AOGCC Revised Well Revised API Obsolete Well Obsolete API Permit Name and Number Name and Number Number Number Number 200-045 KRU 2T-217 50-103-20334-00 KRU 2T-218 Unchanged 200-074 KRU 2T-217A 50-103-20334-01 KRU 2T-218A 50-103-20291- I 01 -AOGCC will reflect these changes in our weekly report that is posted to our website. Please accept my apology for any inconvenience that the mistaken API number may have caused. If you have any questions, please contact the undersigned at (907) 279-1433. Sincerely, Steve Davies Petroleum Geologist CC2 Robert Crandall Well File 200-045 Well File 200-074 PHi._'-IPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-6830 Fax: (907) 265-6224 May 23, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-218 and 2T-218A (Permit No. 200-45 & 200-074) Dear Mr. Commissioner: Enclosed are two sundry applications to re-name 2T-218 and 2T-218A to 2T-217. If there are any questions, please call 265-6830. Sincerely, G. C. Alvord Drilling Engineering Supervisor Phillips Drilling GCA/skad MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman DATE: May 11, 2000 THRU: BlairWondzell ~ P.I. Supervisor ~r~ 2 Ic~Q FROM: LOU Orimaldi fo~,- Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors rig 16E Arco/Phillips 2T-218 200-045 Kuparuk River Field Operator Rep.: Fred Herbert Contractor Rep.: Hanson/Greco Op. phone: 659-7075 Rig phone: 659-7562 Op. E-Mail: N1333@ppco.com Rig E-Mail: Test Pressures Rams: 250/3000 Annular: 250/3000 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P "" Standing Order: P ~' BOP STACK: Quantity Size P/F Annular Preventer I 13 5/8 P Pipe Rams I 13 5/8 P Lower Pipe Rams 1 13 5/8 P Blind Rams I 13 5/8 P Choke Ln. Valves I 4 P HCR Valves 2 3&4 P Kill Line Valves 1 3 P Check Valve 0 Choke: 250~3000 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly I P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 1 P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P ACCUMULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi P/F Quantity P/F System Pressure 3050 P No. Valves 17 P After Closure 1600 ,.- P Man. Chokes 1 P 200 psi Attained :39 P Hyd. Chokes 2 P Full Pressure 3:16 P Blind Covers (All Stations): P N2 Bottles (avg): 6 @ 2000 psi Test's Details The rig was standing by awaiting my arrival from previously scheduled meter proving at CPF 2. The test started as soon as I arrived. All BOPE components were tested with no failures observed. The rig and its surrounding area were clean and orderly. This rig is one of the converted Pool rigs and seems to be getting better at each of my visits. The crew was well versed in the testing procedure used here. Total Test Time: 3 Number of failures: cc: WinfreelOverstreet (Kuparuk Drilling) Attatchments: None BOP Nab 16E KRU 2T-218 5-11-00 LG 5/22/00 ALASKA OIL AND GAS CONSERVATION COPlPllSSION / ! ? ! TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 22, 2000 Thomas Brockway Operations Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 RE: Change of Well Number and API Number for Selected Kuparuk River Unit Pad 2T Wells Dear Mr. Brockway: To cleanly recover from several errors, please make the following changes to your files, databases and on all information transmitted to the AOGCC for the following wells: AOGCC Revised Well Revised API Obsolete Well Obsolete API Permit Name and Number Name and Number N~ Number Number ~_200-045~,) KRU 2T-217 50-103-20334-00 KRU 2T-218 [ Unchanged 200-074 KRU 2T-217A 50-103-20334-01 KRU 2T-218A] 50-103-20291- ~ t 01 AOGCC will reflect these changes in our weekly report that is posted to our website. Please accept my apology for any inconvenience that the mistaken API number may have caused. If you have any questions, please contact the undersigned at (907) 279-1433. Sincerely, Steve Davies Petroleum Geologist CC: Robert Crandall Well Fil~ Well File 200-074 Re: 2T-218 / 218A Surface Location Discrepancy - - P.E..~TD #200-074 ._ Subject: Re: 2T-218 / 218A Surface Location Discrepancy - - PTD #200-074 Date: Thu, 18 May 2000 16:06:32-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Thomas A Brockway <TBROCKW~ppco.com> Tom, Yes on the rename, Bob Crandall thinks its a good idea. I think you should make the request via a 10-403. Blair Thomas A Brockway wrote: Dear Blair, At 4:30 pm yesterday we received word that Nabors 16E may be rigged up over a different surface conductor than originally indicated on the 2T-218 and 2T-218A (Sidetrack) Permits To Drill (APD #'s 200-45 and 200-074). Further investigation has confirmed that the rig has been inadvertently positioned over an adjacent conductor slot, 2T-217, which is 12.5' south of the original planned 2T-218 location. Although the planned target and BHL coordinate's will not change for the affected original well and ongoing sidetrack, the positional surveys showing actual wellbore locations will need to be shifted by 12.5' to reflect this change in surface location. It should be noted that a complete proximity analysis has been performed on both the existing and planned wellbores from this revised 2T-217 surface location. The results showed that there were no close crossing occurrences with other pre-existing wells on 2T-Pad and no violations of the PAI Drilling Anti-Collision policy at any time during the drilling of either the original 2T-218 wellbore or subsequent 2T-218A sidetrack. I realize that this change to a different conductor location is bound to result in confusion from a paperwork and permitting standpoint and believe that the cleanest way to address this situation would be to rename the current 2T-218 / 218A wel!bores to 2T-217 /217A. This would allow the wellbore nomenclatures to conform to existing surface as-builts and facilities documents. However, if you would prefer to address this in a different manner, please let me know and I will follow your lead. Also, please let me know what type of documentation that you will need and I'll be happy to expedite it to you ASAP. If you have questions or require any further information please contact myself or Chip Alvord (265-6120). Sincerely, Thomas A. Brockway Operations Drilling Engineer Phone: 263-4135 Fax: 265-6224 E-mail: trockw~ppco, corn 5/18/00 4:07 PM 1 afl TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IMISSION 3001 PORCUPINE DRIVF ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Randy Thomas Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-218 ARCO Alaska, Inc. Permit No: 200-045 Sur Loc: 768'FSL, 556'FWL, Sec. 1, T11N, R8E, UM Btmhole Loc. 1863'FSL, 1511'FWL, Sec. 36, T12N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2T-218. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2T must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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. Sinc. Robert N.-Christenson, P.E. Chair BY ORDER OF TH_~OMMISSION DATED this ~ day of April, 2000 dlf/Enclosurcs cc; Department of Fish & Game. Habitat Section w/o encl. Depamnent of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill [~] Redrill D I l'l::;:"l:'~e ofwell.'"' Exploratory D StratigraphicTest D Development Oil Re-entry F! Deepen DI Service Development Gas D Single Zone i~1 Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25548 ALK 2662 Tabasco Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 768' FSL, 556' FWL, Sec. 1, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1560' FSL, 1469' FWL, Sec. 36, T12N, RSE, UM --'2-T-94,8 c~T- ,~ I 7 #U-630610 At total depth ' 9. Approximate spud date Amount 1863' FSL, 1511' FWL, Sec. 36, T12N, RSE, UM April 15, 2000 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1560' @ Targ~ feet 2T-220 23.4' @ 250' feet 2560 7869 ' MD / 3336 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 73.8 Maximum surface 1698 At total depth (TVD) 2015 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casin~l Wei~lht Grade Coupling Len~lth MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' 9 cu. Yds. High Early 12.25" 9.625" 40# L-80 BTCM 6193' 35' 35' 6228' 2878' 705 sx AS III, 870 sx Class G 8.5" 7" 26# L-80 BTCM 7171' 35' 35' 7206' 3151' 80 sx Class G 6.125" 4"x4.5" 9.5# L-80 HSLHT 783' 7086' 3118' 7869' 3336' dual screen pre-pack 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED Liner MAR 24.2000 Perforation depth: measured A/as/~a Oit ~ C~as Cons. true vertical Aq(~l~e 20. Attachments Filing fee [~] Property Plat BI BOP Sketch [~] Biverte, Sketch ~] Drilling program Drilling fluid program Time vs depth p~ot BRa*action analysis r-] Seabed report BI 20 AAC 25.050 requirements [~] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Carl Tom Brockway263-4135 Signed ~'~'-~.,--'--'~"~~~~ Title: Drilling Team Leader Date Randy Thomas ~ Prepared by Sharon Al~sup-Drake Commission Use Onl~ PermitNumber I APl number I Appr°vald'~O/O~ ISeec°verletter -~ co - ,5E,..¢" 50-/'~- ~ ~'~ ? . Ifor other re.uireme.ts Ip__.Ye' No I--I Ye. No Hydrogen sulfidemeasures D Yes ~ No Directional surveyrequired ~ Yes D No Required working pressure for DOPE E]2M; E~ 3M; F~ 5M; E~ lOM;F~ [~ ~.~'00 Other: / ORIGINAL SIGNED. BY by order of Approved by Robert N. Chdstenson Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE TABASCO PRODUCER 2T-218 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/6228 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: TAM Port Collar will be placed in the 7-5/8" casing 1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 2500 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. 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). 8. Directionally drill 8-1/2" hole to 7" intermediate casing point (+/- 7206 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run and cement 7" 26.0# L-80 BTCM liner with Baker liner top hanger and packer assembly. Bring cement back to +/- 500' MD above the liner casing shoe, displacing cement with mud. Hydraulically set hanger and packer +/- 150' above surface casing shoe to provide appropriate liner lap. 10. Shut in BOP's and pressure test liner to 2500 psi for 30 minutes per AOGCC regulations. Record results. 11. 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). 12. Drill 6-1/8" hole to well total depth (+/- 7869') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH. 13. Run open hole drill pipe conveyed logs as needed. 14. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 15. Pump caustic wash. Pump pickle job. Circulate brine. 16. Pump acid pill across formation. Reverse out with brine. POOH 17. Run in hole with 4"x4-1/2" Dual Screen Pre-Pack assembly. Set gravel pack packer. 18. Circulate well to non-freezing, clean completion brine. POOH 2T-218 Page 1 TAB, 03/20/00, v.1 19. 20. 21. 22. 23. 24. Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing. RIH with ESP assembly on 4-1/2" 12.6# L-80 BTCM production tubing with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to Production. 2T-218 Page 2 TAB, 03/20/00, v. 1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Tabasco 2T-218 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.5-9.5 16-26 25-50 150-25O* 10-20 10-30 8-15 8-10 4-6% Drill out to 7" Intermediate liner 9.0 - 9.5 8-15 20-50 70-1 O0 8-12 10-25 5-7 8.5-9.5 4-6% Drill out to TD 9.1 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated sudace pressure for the surface casing string is calculated using an expected leak-off of 13.4 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1698 psi. The leak off EMW was chosen based on an open hole LOT on 2T-220 taken to 13.4 ppg at 3061' TVD (0.70 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 2500 psi prior to drilling out of sudace casing. MASP = (2878 ft)(0.70 - 0.11 ) = 1698 psi Maximum anticipated surface pressure for the intermediate casing string is calculated using an expected casing leak-off of 13.4 ppg EMW (0.70 psi/Q) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1859 psi. The leak off EMW was chosen based on an open hole LOT on 2T-220 taken to 13.4 ppg at 3061' TVD (0.70 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 2500 psi prior to drilling out of the intermediate liner. MASP = (3151 ft)(0.70-0.11) = 1859 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1250 psi (0.40 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 8.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3162'. Well Proximity Risks: The nearest existing well to 2T-218 is 2T-220. As designed, the minimum distance between the two wells would be 23.4' at 250' MD. Drillincl Area Risks: Risks in the 2T-218 drilling area are limited to lost circulation, potential borehole instability, and below normal pressures in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Based on previous DS 2T drilling results, 9.6 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (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'"') i~"'2T-2~,8 4-1/2" x 7" and 4-1/2" x 9-5/8" tubing annuli will be filled with kill weight brine and diesel after setting the.,/ "~.4.;1/2 prOduction tubing string and prior to the drilling rig moving off of the well. Tabasco 2%218 Proposed Completion Schematic Dual Screen Pre-Pack ARCO Alaska, ]nc. 16" 62.5# H-40 ~ @ 80' MD TAM 9-5/8" Port Collar Stnd. Grade BTC Threads (W- 1000' MD / 980' TVD) Depths are based on Nabors 16E RKB Surface cs9. 9-5/8" 40.0¢ L-80 BTCM (+/- 6228' MD / 2878' TVD) Intermediate Liner 7" 26.0# L-80 BTCM (+/-7206' MD / 3151' TVD) 4" x 4-1/2" Dual Screen Pre-pack TD < 40' below Tabasco base (< 7869' MD / 3336' TVD) 4q/2" FMC Tubing Hanger w/4-1/2" L-80 IBT Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetretor, FMC Tabasco Producer style horizontal wellhead system. 125 amp penetrators 4-t/2" 12.6# L~80 IBT Spaceout Pups as Required for Heat Trace Raychem Heat Trace @ +/- 3000' MD 4-1/2" 12.6# L-80 IBT Tubing to Sudace XO sub, L-80 4-1/2" IBT box x 3-1/2" IBT Special Clearance pin 3 its, 3-1/2" 9.3# L-80 IBT Special Clearance Tubing, 3.865" Special Clearance couplings Baker 'Sentry' BHP gauge, 3~1/2" clamp on styte (suction) 3-t/2" Trico Y-block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" IBT Special clearance box on uphole end l-Tube Le~omponents (as listed below) w/bottom set @ +/- 6022' MD 2~7/8" Trico 'X' landing nipple w/2.312" profile, EU E8RD XO sub, L-80 EUE8RD box x Hydril1511 pin Swivel sub, 3-11/16" OD, 2.875" ID, Rydril1511 3 its, 2-7/8" 6.5# L-80 Hydrilt 511 tubing 2-7/8" Wireline entry guide, 2.347" ID, Hydrilt 5I 1 Motor Leq Components (as listed below} w/bottom set @ +/- 6018' MD Spaceout pup, 3-1/2" x 10', 9.3# L-80 EUE8RD tubing Landing pup, 3-1/27 x 10', 9.3# L-80 EUE8RD tubing Centilift Pump Discharge Centrilift ESP Pump: 83GC 10000 GPMTAR Centdlift Pump Intake: GPINTAR Centri~ift Seal Assembly: GST3 CLx5 Centrilift Motor: 418 HP KMH 2610/98A Liner Assembly (run on drillpipe}, set @ +F 6078' MD Baker 'C-2' tieback sleeve w/locator, t 0' tieback extension Baker 9-5/8" x 7" 'ZXP' Liner Top Isolation Packer Baker 9-5/8" x 7" 'HMC' Hydraulic Liner Hanger 7" 26.0# L-80 BTCM casing run to intermediate TD Pre-Peck Screen Assembly ~run on ddllpipe}, set @ +/~ 7086' MD Baker 7" Model SC-1R Gravel Pack Packer 4 jts, Baker 4" blank tubing, Hunting SeaFLock MT Baker Model C KOIV Baker 4" x 4~1/2" Dual Screen Pre-pack, 5~1" OD, Hunting Sea!-Leck HT 3 its, Baker 4" blank tubing, Hunting Seal.Lock HT Baker GPV Set Shoe, 5.0" OD, Hunting Sea!~Lock HT TAB, 3/20/00, v2 I V Oeated by rix$o FOR: BROCKWAY I Dots plotted; 2{-Mor-200O Plot Rsferencs Is 216 Vsre{on {~3 . I Coordinates ore fn fe~t reference slot ~1218. I True Vertical Depths ore reference RKB (Nahum 400 400 8O0 1200 1600 2000 2400 2800 3200 5600 400 ARCO Alaska, Inc. Sfruoture: Pod 2T Well : 218 Field : Kuporuk River Unlt Location: North Slope, Alosk; PROFILE COMMENT DATA ..... Point ..... MD tnt Bit TVD North East V. Sect Beg/lO0 Beg;n 1.5 Deg/lO0' B - 250.00 O. DO 0.00 2§0.00 0.00 O. O0 0.00 0.00 Begin ;5 Dsg~tO0' Bul - ~0.00 1.50 65.00 349.99 0.55 t.19 0.72 1,50 Beg}n 4 Dog/lO0' But - ~00.00 5.95 50.00 499.64 6.E'/ B.91 7.62 Bo~ of Permafrost 1624.01 49.39 10.11 1475.00 4~6.75 134.64 503.~2 4.00 Top ef Ugnu 1~9.B0 60.35 &95 1535.00 710.24 171.84 727.~ 4.00 EOC 2236. t8 73.B0 7.79 1764.0.5 1016.79 216.74 1037.67 4.00 TOI~ of We~ ~k 3805.5~ 73. B0 7.79 2202.00 2509.93 421.05 2544.~0 O.OO BOee of West Sek 5511.3.5 73.B0 7.79 2678.00 4152.80 ~43.12 4t82.47 0.00 g-5/B Cumin9 Pt 622B. 05 73. B0 7.79 2871~00 4814.67 ' 736.42 4870.~4 0.0{3 7 Casing Pt 7205.75 73.80 7.79 5150.84 5744.69 86.3.71 .5809.45 Top of ToboscO 7245.7.5 73. B0 7.79 5162.00 57B2.95 86B.92 5547.55 0.00 Target - Mid Tabasco - 75.50.33 73J0 7.79 ~246.99 6072.72 90B.57 8140.31 :Be~e at Tub~=¢o 7758.9.5 73. B0 7.79 330&00 62B0.72 937.0~ 5350.25 0.013 7.79 3335.72 6375.22 949.96 8445.61 0.013 ~D/4 Screen 788B.2/~ 73.80 i RKB ELEVATION: 115' n 7~ Beg~n 1.5 Dee/lO0' Build & Turn ~'~ Beg~n 5 Dee/lO0' Build & Turn 9'25 Begin 4 Deg/lO0' Build & Turn 1'~.96 ~16.B0 DLS: 4,00 dee per 100 ft ~20.70 ~ 24.65 ~ 28.58 '~X52.54 ',~0.48 ".~4B.44 Bose of Permafrost ~ 56.40 ~ ., ~ 64 ;38 Fop OT ugnu TANGENT ANGLE ~ 73.80 DEG Top of West Sak East (feet) -> 600 0 600 1200 i i i i i i i TD LOCATION: I 1~63' FSL, 1511' FWL TD/4 Screen SEC, 36, T12N, RSE Base of Tabasco Target - Mid Tabasco Top of Tabasco 7 Casing Pt I~F6~:TARGET LOCATION: 19-5/8 Casing Base of West Sak / Top of West Sak 8.51 AZIMUTH J 40' (TO TARGET) ***Plane of Proposal*** IEOC / Top of Ugnu I Base of Permafrost Begin 4 Deg/lO0' Bu;Id & Turn/ Begin 5 D~g/lO0' Bund & Turn/ Base of West Sak · I~n I.~ 0~/10()' Bu;kl ar Turn "~~~/8 Casrn9 Pt Tobosco~'~~~ 7 Casing Pt Top o~ Target - Mid Tabasco =~......_~ Base of Tabasco TD/4 Screen 600 600 SURFACE LOCATION: I 768' FSL, 556' FWL SEC. 1, T11N, R8E I I I I I I I 0 400 800 1200 I I I I I I I I ! II I II I I I I I 1 600 2000 2400 2800 3200 .3600 4000 4400 4800 5200 VerticalSection (feet)-> Azimuth 8.51 with roforonco 0.00 N, 0.00 Ir from slot //218 I I I I I I I I 5600 500(3 6400 6BOO 180( I 6600 6000 5400 4800 4200 I 3600 Z 0 3000 2400 (D 1800 1200 120 100 80 340 520 1 300 300 280 260 240 220 200 180 '+- 160 140* o ~' 120 1 O0 80 60 40 20 0 20 4O 12.0 1 O0 8O ARCO Alaska, Inc. Structure: Pad 2T Well : 218 Field: Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 60 40 20 0 20 40 60 80 190O 7OO 1700 1700 I I / I / / / / / I ~ 1100 / / / / / / / / / / / / / 900 / / 1500 / / / 700 / / / / ~, '~00 / / / / 1 //9oo / / 100 6O 40 20 0 20 40 East (feet) -> lO0 120 140 I ~ ~oo I / / / / / / I / / / / / 60 80 100 120 140 540 520 500 280 260 24O 220 2OO 180 A I Z 160 0 140 ~ .-h --I- 120 v 1 O0 80 60 40 20 2O c.o~ ~/~.~o~ For: T. Brockway[ Oot~ Motted: 21-~-~ I ~00 520 240 160 1680 1600 152O O0 2500 14-40 1560 ARCO Alaska, Inc. Structure: Pad 2T Well : 218 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 80 0 80 160 240 320 400 480 2100 2100 2900 2500 1280 A 1200 1120 1040 960 BBO 800 720 640 560 480 4OO 520 240 2500 400 520 240 160 80 1900 2500 1 700 2700 1900 1 _~500 I I I t I 15oo~ I I t 1900 / I 1 13oo/ / I l! o 80 160 240 ,t20 East (feet) -> 2100 / / / / / / / / 1900 560 640 720 1600 1520 1440 1360 /~ 1280 / / 2500 / 1200 2~00~ / / 1120 / / / 1040 / / 21 960 / / / / 88o 8OO 72O 640 560 480 2300 400 320 240 400 480 560 640 720 I Z ~ For: T. Brockway Dote i~otkad: 21-Mo~-2000 ~ot R~f~rmm~ ~e 2t8 V~ofl ~5. ~ o~ in ~ ~n~ ~t ~2t& 240 160 60 2960 2880 2800 2720 2640 ARCO Alaska, Inc. Structure: Pad 2T Well : 218 Field : Kuparuk River Unit Location : North Slope, Alaska Eesf (feet) -> 0 BO 160 240 520 400 480 560 2700 ~700 640 720 I 800 I 5500 2960 2880 2800 2720 2640 A 256o 2480 2400 2520 2240 2160 2080 25OO 5300 5500 4900 4700 5100 2560 2480 2400 2320 A I 2240 2160 2080 20OO 1920 2700 184O 2500 2500 5100 2000 1920 1840 1760 1760 1680 1680 1600 1520 1440 240 2500 15O 80 2100 2100 2900 i 0 80 160 240 520 400 480 560 Easf (feet) -> 2500 640 720 / / / 800 1600 1520 1440 4520 ARCO Alaska, Inc. Structure: Pad 2T Well : 218 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 960 720 480 240 0 240 480 720 960 1200 1440 1680 1920 2160 2400 I I I I I I I I I I I I I I ! I I I I I I I I I I t 6480 ~-J 4900, 4900 5240 ~ 3300 I I 4700 / 6000 700 5760 I 4500 5520 ~4500 3100 I I 5280 I 4500 I 5040 14300 53 2900 51 4800 4100, 4560 14100 4080 5840 3600 5560 5120 2880 2640 3900 4700 27C 6480 6240 6OO0 5760 5520 / / / 5280 3100~ / 5040 / / / / / 3900 5700 3500 3300 oo 3500 3100 2900 4500 4300 59OO 5700 ~ ~ 3500 5500 / 270( 4100 3900 5700 3500 4800 456o I Z 0 4520 ~ 4080 (o .-+. 3840 5600 5360 5120 2880 2640 2400 2900 5500 2400 2160 2160 960 720 480 240 0 240 480 720 960 1200 1440 1680 1920 2160 2400 East (feet) -> ARCO Alaska, Inc. Pad 2T 218 slot #218 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 218 Version#3 Our ref : prop3889 License : Date printed : 21-Mar-2000 Date created : 2-Mar-2000 Last revised : 2I-Mar-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 52.725,w150 0 30.800 Slot Grid coordinates are N 5970748.059, E 498945.215 Slot local coordinates are 768.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PGMS <0-7625'>,,15,Pad 2T PGMS <0-6975'>,,7,Pad 2T PGMS <O-6789'>,,11,Pad 2T PGMS <O-8262'>,,14,Pad 2T PMSS <0-4175'>,,201,Pad 2T PMSS <0-5340'>,,210,Pad 2T PMSS <0-4082' Depth Shifted NIII>,,209,Pad 2T PMSS <4022-4690'>,,209DO,Pad 2T PMSS <4135-4496'>,,207,Pad 2T MSS <4046-4427'>,,202,Pad 2T PGMS <O-7868'>,,13,Pad 2T PGMS <0-7650'>,,8,Pad 2T PGMS <0-6370'>,,9,Pad 2T PGMS <0-8208'>,,6,Pad 2T PGMS <0-7670'>,,5,Pad 2T PGMS <0-8160'>,,4,Pad 2T PMSS <1287-1725'>,,2,Pad 2T PGMS <O-8890'>,,2A,Pad 2T PMSS <4410-4967'>,,215DO,Pad 2T PGMS <0-8250'>,,lO,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T PGMS <O-6725'>,,12B,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <5917-7957'>,,16A,Pad 2T PGMS <0-8445'>,,17,Pad 2T Closest approach with 3-D Minimum Distance method Last revised 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 26-Aug-1998 4-Dec-1998 6-Apr-1999 6-Apr-1999 6-Apr-1999 26-Aug-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 26-Aug-1998 26-Aug-1998 6-Apr-1999 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 Distance 741.0 491.0 640.9 714.9 528.5 101.0 112.7 112 7 133 6 317 8 691 0 516 0 540 9 463 7 440.2 415.6 366.0 366.0 38.6 616.0 665.0 665.0 665.0 766.0 766.0 766.0 790.9 M.D. 0.0 0.0 262.5 287.5 100.0 80.0 275.0 275.0 360.0 530.0 0.0 0.0 180 0 380 0 287 5 275 0 O0 O0 300.0 100.0 325.0 325.0 325.0 0.0 0.0 0.0 160.0 Diverging from M.D. 0.0 0.0 262.5 287.5 100.0 80.0 275.0 275.0 360.0 530.0 0.0 0.0 180.0 380.0 287.5 275.0 477 8 477 8 300 0 100 0 325 0 325 0 325.0 0.0 0.0 0.0 160.0 PGMS <0-7897'>,,3,Pa J[ PMSS <469-10632'>,,18,Pad 2T PMSS <0-9845'>,,19,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <0-12821'>,,21,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <893 - 12977'>,,23,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <0-9298'>,,27,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <0-10570'>,,29,Pad 2T PMSS <4627 - 10686'>,,30A,Pad 2T PMSS <0-4749'>,,30,Pad 2T PMSS <380 - 11400'>,,31,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <650 - 11080'>,,37,Pad 2T PMSS <12144-13360'>,,38A,Pad 2T PMSS <853-4995'>,,220,Pad 2T PMSS <0-2140'>,,220PB1,Pad 2T PMSS <1664-4645'>,,220PB2,Pad 2T PMSS <5041-5752>,,220DO,Pad 2T 204 Version #15,,204,Pad 2T 217 Version #1,,217,Pad 2T 26-Aug-1998 21-0ct-1998 23-Jan-1998 23-Jan-1998 29-Feb-2000 23-~an-1998 25-Aug-1998 23-~an-1998 23-~an-1998 23-~an-1998 23-Jan-1998 16-~u1-1998 16-2u1-1998 23-Jan-1998 24-Feb-1998 29-Feb-2000 24-Feb-1998 23-~an-1998 23-Jan-1998 23-~an-1998 3~Feb-1999 3-Feb-1999 3-Feb-1999 5-Apr-1999 3-Feb-2000 16-Mar-2000 390.9 803.5 820.8 811.0 850.9 351.0 336.0 291.0 275.7 261.0 246.0 226.9 226.9 204.4 201.0 201.0 201.0 753.0 862.7 703.0 23.4 23.4 23.4 23.4 175.6 13.5 250.0 325.0 275.0 1800.0 200.0 100 0 100 0 262 5 287 5 240 0 100 0 444 4 444 4 570 0 00 00 0.0 100.0 411.1 100.0 250.0 250.0 250.0 250.0 360.0 250.0 250 0 325 0 275 0 1800 0 200 0 100 0 100 0 262 5 287 5 240.0 100.0 444.4 444.4 570.0 0.0 0.0 0.0 100.0 411.1 100.0 2236.2 2100.0 250.0 2236.2 360.0 250.0 Port Collar Cementinq Practices · We will run a TAM Port Collar (see below for running details). · Circulate with casing on bottom at 10 bpm or greater if possible without losing returns. Equipment for the stage job consists of: · TAM Port collar · TAM Combo tool · TAM Choke Ensure that all connections are compatible or that there are appropriate crossovers available. If needed, TAM personnel can be available on site to check the equipment and confirm shear pin settings with prior notice. Run and cement with the Port Collar as follows: I. Check that all materials are at the rig site · 7 5/8" TAM Combo Tool, with 3-1/2" EUE Box by Pin and 7 5/8" 29.7 ppf Packer Cups · 7 5/8" TAM Port Collar with 7 5/8" BTCM Box x Pin Connections · Choke Sub with 3-1/2" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers I1. Ensure that all connections are compatible or there are appropriate crossovers available II1. Pick up and run 7 5/8" 29.7 ppf casing with Port Collar placed at 1000' TVD. Note: If packing off problems were seen around this depth when drilling or tripping, consult with the Drilling Engineer. · Install centralizers in the center of the joints above and below the port collar. IV. Pump first stage of cement job (spacer, lead and tail) as specified in Drilling Plan. Pump until the plug bumps and pressure up to 500 psi above circulating pressure to insure the plug has landed. If floats do not hold, maintain 1500 psi on casing for a minimum of 4 hours before rechecking. V. If cement is not returned to surface, a top job or use of the port collar will be required. The Arco company representative should review the attached decision tree is order to determine which method should be used. · Do top job using 1" tubing if good lead slurry cement did not circulate to surface. Run 1" tubing and tag top of previous cement job. If tubing does not tag, run it as deep as possible and contact the Arco drilling engineer or engineer on call to discuss options. Circulate while RIH to keep tubing from packing off. Flush annulus with water, then circulate annulus to cement. · AOGCC and Arco drilling engineer (or engineer on call) must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. VI. If the Arco company representative determines that it is necessary to use the Port Collar, run in the hole with the 4" drillpipe until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. Port Collar Practices 1 TAB, 03/22/00, v. 1 · In order to trip in with the 4" drillpipe and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. VII. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure VIII.Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. IX. Establish circulation rate and pressure X. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing XI. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar Xll. Pressure up on workstring to confirm collar is closed XIII.With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar XlV. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub XV. Reverse out excess cement as required XVl. Pull out of hole with tools Port Collar Practices 2 TAB, 03/22/00, v.1 Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD), Pedorm Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One1 Stage Cement JobI to Surface Cement below Port Collar (1000' TVD) / If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Sudace and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfY the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. le The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. o o The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. 7. Bleed back mud from the well and compare with volume pumped on the test. . Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 ECEIVED ,qla~l~a Oil & Gas Cons. Commission ARCO Alaska, Inc. Diverter Schematic Nabors 16E Flowline 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 214,4" HYDRIL MSP 2,000 psi, WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. Nabors #16E 13-5/8" 5,000 PSI BOP COMPONENTS El 3" 5,000 psi WP OCT F--j MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / J I USA 13-5/8" 5,000 psi WP ....~1 / x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE F~Tl~]raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL w/two 3" 5M psi WP outlets I SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I DRILL SITE 2-T 2 1 11 112 · 31 · 30 · 29 ® 28 · 27 ® 26 · 202 · 22 · 2 ® 3 ® 5 · 6 · 7 · 8 201® · 9 · I0 · II · 12 · 13 3See 14 · 15 36e w 16 · 17 · 18 · 19 · 20 · 21 · 37 VICINITY MAP ,' = 2 MILES SEE SHEET 2 FOR NOTES AND LOCATION INFORMATION (NO SCALE) LEGEND o NEW CONDUCTOR LOCATIONS e EXISTING CONDUCTORS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. ~ DRAWING NO: LK622012 9/16//98 I AREA: 2T LOUNSBURY & ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS MODULE: XX DRILL SITE 2-T WELL CONDUCTORS 207-210,215,218 &: 220 AS-BUILT LOCATION J SHEET:IREV: ¢ ..... · .... -~- R?'~OD12 oo~ OF 2 1 UNIT: D2 2-T MONUMENTS PER LHD · ASSOCIATES. 2. COORDINATES SHO~ ARE A.S.P. ZONE 4, N.A.D. 27. ALL DISTANCES ARE TRUE. ~/ ~ ~. ELEVATIONS SHO~ ARE B.P.~.S.L. 4. WELLS ARE LOCATED ~THIN PROTRACTED 'SECTION 5. DATE OF SURLY: 9/13/9B, FIELD BK. L98-71 pg. 14-23. 6. DRILL SITE 2-T GRID NORTH IS ROTATED 179' 59' 40" ~.~ ( ~ t ~ ~-~ WEST FROM A.S.P. ZONE 4 GRID NORTH. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2-17 LOCATIONS, CEA-D2TX-6220D7 FOR CONDUCTOR 18-23, [ ~ClNI~ MAP r-2 a~L~S 26-32, 36-38 & TABASCO LOCATIONS, AND CEA-D2TX-6220D9 FOR CONDUCTOR 202. LOCATED IN SECTION 1, T 11 N, R 8 E, U.M. SEC. SEC. ~LL LINE LINE O.G. PAD NO. Y X LATITUDE , LONGITUDE j O/S ~ O/S ELEV. ELEV. F.S.L. F.W.L. 207 5,970,610.10 498,945.02 70'19'51.368" 150'00'30.805" 630' 556' 75.2' 80.4' I 208 5,970,622.69 498,944.87 70'19'51.492" 150'00'30.810" 642' 556' 75.2' 80.4' j ; 209 5,970,635.10 498,944.90 70'19'51.614" 150'00'30.809" ] 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.738" 150'00'30.814" 667' ' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.348" 150'00'30.807" 729' 556' 74.2' 80.4' 218 5,970,747.74 498,944.97 70'19'52.722" 150'00'30.807" 768' ~ 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150,00'30.810"[ 792' 556' [ 74.1' ~ 80.4' ~_ OF ~,~a~_ SURVEYOR'S CERTIFICATE ~~.;.. .... ...,.~.~. ~ : ~~ 't LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~ 497h ~ ~L~SKA AND THAT THIS PLAT REPRESENTS A SURVEY ~ ..... ~, .... ~ THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT t ~x,~OOKUS /~t A~ OF SEPTEMBER 16, 1~98. '"' LOUNSBU ,.. ~ss,o.~ _. C/j,5[ a ASSOCIATES, INC. AREA: 2T MODULE: XX UNIT: D2 ~ DRILL Sl~ 2-m ARCO Alaska,Inc. CONDUCTORS 207-210,215,218 & 220 Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON SEC. SEC. WELL LINE LINE O.G. PAD NO. ¥ X LATITUDE LONGITUDE O/S O/S ELEV. ELEV. F.S.L. F.W.L. 207 5,970,610.10 498,945.02 70'19'51.368" 150'00'.30.805" 6..50' 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70'19'51.492" 150'00'.30.810" 642' 556' 75.2' 80.4' 209 5,970,6,35.10 498,944.90 70'19'51.614" 150'00'30.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70'19'51.738" 150'00'30.814" 667' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.348" 150'00'30.807" 729' 556' 74.2' 80.4' 218 5,970,747.74 498,944.97 70'19'52.722" 150'00'.30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150,00'..30.810" 792' 556' 74.1' 80.4' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 March 22, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Tabasco 2T-218 768' FSL, 556' FWL, Sec 1, T11N, R8E, UM 1560' FSL, 1469' FWL, Sec. 36, T12N, R8E, UM 1863' FSL, 1511' FWL, Sec. 36, T12N, R8E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designated as a producer and is planned to penetrate the Tabasco sands using a 9- 5/8" surface casing, a 7" intermediate liner string and a dual screen pre-pack completion technique for sand control purposes. The well will be drilled and completed using Nabors 16E. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" I-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Steve Moothart, Geologist (20 AAC 25.071) 265-6965 Please note that the anticipated spud date for this well is April 15, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Randy Thomas at (907) 265-6830. Sincer~ Thomas ^. Brockway Operations Drilling Engiffeer Attachments: CC: KRU 2T-218 Well File Randy Thomas Tom McKay Tom Brockway Jack Walker Larry Gipson Lewis Ledlow ATO- 1 O38 ATO-1 O6O ATO-1 O40 ATO-1148 ATO-1146 ATO-1063 ARC.O Alaska, Inc. ~' AAI PAYABLES PiO. BoX 102776 Anchorage, AK 99'510-2776 TO THE ORDER ~OF: ' -i .. . STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE ~,.~. ~... 205093842 MARCH 13, 2000 *** VOID AFTER 90 DAYS *** 73-42( 839 o9~ .. EXACTLY . The' Ftrst Nationa Sank of Chicago-0710 Chicago, Illinois Payable Through Republic Rank Shelbyville, Kentucky *~*********'100 DOLLARS AND O0 CENTS $***********100., TRACE NUMBER: 2050.93842 ,' ;~0 5Q:'~] ~,R'u 2:11' -.~.:DR:'~:.c[D Dc]c] ? S ?ti,, WELL PERMIT CHECKLIST COMPANY .~,,'-,~c~ WELL NAME~ROGRAM: exp ~ dev ,~' redrll ~ serv ~ wellbore seg ann. disposal para req __ FIELD & POOL INIT CLASS __~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. 13. ENGINEERING GEOLOGY ,,~ - I~ATE2 Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 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 ~_.._5-'Q~D 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 ................. Gl ~OL AREA Y Y Y Y Y Y Y Y y: Y Y Y Y ¥ )N N ~ N ~)N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. Y 34. Contact name/phone for weekly progress reports [exploratory only] ANNULAR_ DISPOSAL35. With proper cementing records, this pla/0,-- (A) will contain waste in a suitable re/,pefving zone; ....... Y N APPR DATE (B) will not contaminate fresh~; or cause drilling waste... Y N to surface; (C) will not i~m~anical integrity of the well~qsefl for disposal; Y N (D) will noTdamage producing formation ~r recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N UNIT# ///.~_,~ ON/OFF SHORE .... o~). GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: TEM .~--~- Commentsllnstrucfions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. 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 Oct 30 20:13:27 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/30 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 ..................... 00/10/30 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 MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-00026 J. MARTIN G. WHITLOCK 2T-217 501032033400 PHILLIPS Alaska, Inc. Sperry Sun 28-0CT-00 MWD RUN 2 AK-MM-00026 J. MARTIN G. WHITLOCK MWD RUN 3 AK-MM-00026 TOM MCGUIRE F. HERBERT 1 liN 8E 768 556 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 114.75 80.20 OPEN HOLE CASING DRILLERS Bit SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 110.0 12.250 9.625 6213.0 8.500 7.000 6971.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. SHALLOW PHASE RESISTIVITY (SEXP) FAILED ON MWD RUN 3 AND IS NOT PRESENTED FOR THAT RUN. 5 . MWD DATA IS CONSIDERED PUC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL 2T-217 WITH API# 50-103-20334-00. THIS WELL REACHED A TOTAL DEPTH OF 7930' MD, 3459' 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 69 0 7886 0 ROP 110 5 7929 5 FET 6203 0 7893 0 RPD 6203 0 7893 0 RPM 6203 0 7893 0 RPS 6203 0 7893 0 SEXP 6203 0 6940 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 69.0 6228.0 2 6228.5 6975.0 3 6975.5 7929.5 MERGED FLAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 Name Service Unit Min Max DEPT FT 69 7929.5 ROP MWD FT/H 0.3 2037.55 GR MWD API 15.91 175.89 RPX MWD OHMM 0.8 12.89 RPS MWD OHMM 0.5 1767.97 RPM MWD OHMM 0.24 2000 RPD MWD OHMM 0.31 2000 FET MWD HR 0.12 325.56 Mean Nsam 3999.25 15722 153.979 15574 85.8231 15635 5.95716 1476 10.4108 3381 27.9957 3381 31.7753 3381 9.30743 3381 First Reading 69 110.5 69 6203 6203 6203 6203 6203 Last Reading 7929.5 7929.5 7886 6940.5 7893 7893 7893 7893 First Reading For Entire File .......... 69 Last Reading For Entire File ........... 7929.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/30 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 ....... 00/10/30 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 69.0 6186.5 ROP 110.5 6228.0 $ LOG HEADER DATA DATE LOGGED: 24-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 65.41 Memory 6228.0 .0 76.3 TOOL NUMBER PBO1501CVG8 12 . 250 SPUD MUD 10.00 188.0 8.5 300 5.0 .000 .000 .000 .000 .0 105.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 Name Service Unit Min Max DEPT FT 69 6228 ROP MWD010 FT/H 0.3 836.31 GR MWD010 API 15.91 133.5 Mean Nsam 3148.5 12319 167.487 12236 77.5361 12236 First Reading 69 110.5 69 Last Reading 6228 6228 6186.5 First Reading For Entire File .......... 69 Last Reading For Entire File ........... 6228 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/30 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 ....... 00/10/30 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 6187.0 6203 0 6203 0 6203 0 6203 0 6203 0 6228 5 STOP DEPTH 6931 5 6940 5 6940 5 6940 5 6940 5 6940 5 6975 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 29-APR-00 Insite 65.41 Memory 6975.0 72.1 74.6 TOOL NUMBER PB1507HWGVR6 PB1507HWGVR6 8.500 LSND 9.50 43.0 10.5 60O 7.4 1.400 .903 2.300 1.500 66.0 106.0 66.0 66.0 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 Name Service Unit Min DEPT FT 6187 ROP MWD020 FT/H 2.8 GR MWD020 API 53.86 RPX MWD020 OHMM 0.8 RPS MWD020 OHMM 3.76 RPM MWD020 OHMM 1.97 RPD MWD020 OHMM 0.31 FET MWD020 HR 0.12 Max 6975 2037.55 142 75 12 89 1358 59 926 59 1849 39 106 12 Mean Nsam 6581 1577 161.632 1494 109.241 1490 5.95716 1476 7.33637 1476 7.29242 1476 14.7485 1476 4.36 1476 First Reading 6187 6228.5 6187 6203 6203 6203 6203 6203 Last Reading 6975 6975 6931 5 6940 5 6940 5 6940 5 6940 5 6940 5 First Reading For Entire File .......... 6187 Last Reading For Entire File ........... 6975 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/30 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 ....... 00/10/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NTJMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6932 0 6941 0 6941 0 6941 0 6941 0 6975 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: STOP DEPTH 7886 0 7893 0 7893 0 7893 0 7893 0 7929 5 13-MAY- 00 Insite 0.41 Memory 7930.0 62.7 72.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PBO1414GR4 PBO1414GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.125 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: Water Based 9.20 49.0 8.4 29000 8.4 .140 · 112 .120 2.000 71.0 90.2 71.0 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : # REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 %PI 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 Name Service Unit Min Max DEPT FT 6932 7929.5 ROP MWD030 FT/H 8.05 179.07 GR MWD030 API 62.58 175.89 RPS MWD030 OHMM 0.5 1767.97 RPM MWD030 OHMM 0.24 2000 RPD MWD030 OHMM 1.24 2000 FET MWD030 HR 0.46 325.56 Mean 7430.75 58.1479 120.661 12.7929 44.0366 44.9676 13.1407 Nsam 1996 1844 1909 1905 1905 1905 1905 First Reading 6932 6975.5 6932 6941 6941 6941 6941 Last Reading 7929.5 7929.5 7886 7893 7893 7893 7893 First Reading For Entire File .......... 6932 Last Reading For Entire File ........... 7929.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/10/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File