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Home My WebLink About203-018 ) Image Project Well History File Cover Page ) XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0.3 - () J 8 Well History File Identifier Organizing (done) o Two-sided III" 11111111I11111 ~scan Needed r ¡ R~AN \Ø' Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, NolType: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: Helen ~?lria J. o Other:: I I z.A A/.n,'" Date:6 16 () $' /5/ rV~ Project Proofing 1- Scanning Preparation x 30 = + , DateS / b () ~ /5/ nt-O = ~TAL PAGES J 5 (Count doe '1C1 ir'clude cover sheet) ,A J () Date: 5'. / b t:J'S /5/ r V(1-" j I BY: Helen ~ BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: J (P (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1/ YES NO Helen~ . Date:;5"" /6 ~ /5/ ~ t If NO in stage 1, page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: /5/ I III r I 1111 II Date: /5/ Quality Checked III "1111111 "1111I Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • ~'~., - Il • 1 03~o~~zoos DO NOT PLACE m~~: ~K¢~ ~` arm - ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc Direct: (907) 564-4628 hubbletl@bp.com up Terrie Hubble ) Technical Assistant GPB Drilling & Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 May 6, 2003 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Permit to Drill, 203-018 To Whom It May Concern: Please find attached the Completion Report for 3N-18L1. At this time we would like to request that you cancel the second (planned) Permit to Drill for 3N-18L2. This leg was not drilled and there are no immediate plans to attempt to drill it. Thank you very much for your assistance in this matter. Sincerely, ,~IJ /I ~. .'1 I ~v u.-.e., Terrie Hubble .,. ,\1'.'11. -.....~ ~....~ ~..- --:...- ......~ -F"'~ ·'jJ'~~I\" ". p'20)-O¡g ~?!rÆ^ ~. íE 1 lJ ¡ i r .. .~ J Lb ~"E '1'[ ) IÆ~fÆ~:~!Æ ) ( AIfASIi& OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 w. rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer Phillips Alaska Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Unit 3N -18L2 Phillips Alaska Inc. Permit No: 203-018 Surface Location: 1561' NSL, 20' EWL, SEC. 28, TI3N, R09E, UM Bottomhole Location: 2676' SNL, 5207' EWL, SEC. 34, TI3N, R09E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellboresegment of existing we1l3N-18, Permit No 186-093, API 50- 029-21595-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7f.:!t- day of February, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. W6v\- 7--/4/01 ') STATE OF ALASKA ) ALASK,. ¿'IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 68' MD Kuparuk River Field / Oil Pool 6. Property Designation ADL 025520 7. Unit or Property Name Kuparuk River Unit 8. Well Number 3N-18L2 9. Approximate spud date 03/01/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11975' MD / 6522' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 92 Maximum surface 3150 psig, At total depth (TVD) 6568' / 3800 psig Setting Depth TaD Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 20251 9950' 8298' 11975' 65221 Uncemented Solid & Slotted Liner 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator Phillips Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 518422. Y = 6013800 1561' NSL, 20' EWL, SEC. 28, T13N, R09E, UM At top of productive interval x = 522756, Y = 6008238 4013' SNL, 4326' EWL, SEC. 33, T13N, R09E, UM At total depth x = 523775, Y = 6009578 2676' SNL, 5207' EWL, SEC. 34, T13N, R09E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025629, 2604' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10875' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weiaht Grade CouDlina 2-3/8" 4.6# L-80 ST-L Hole 3" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10630 feet 6826 feet 10517 feet 6746 feet Length 115' 5144' 16" 9-5/8" 10599' 11. Type Bond (See 20 AAC 25.025) Number U-630610 Plugs (measured) Junk (measured) Size Cemented MD TVD 242 sx Coldset II 115' 115' 1500 sx AS III, 400 sx Class 'GI 5144' 3621' 400 sx Class 'G', 175 sx PF 'C' 105991 6804' 7" Perforation depth: measured 9983' - 10001', 10179' - 10201', 10221' - 10247', 10256' - 10278', 103251 - 10329', 10333' - 10342' true vertical 6398' - 6408', 6518' - 6532', 6545' - 6562', 6567' - 6582" 6613' - 6616', 6618' - 6625' /HI Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch /HI Drilling Program /HI Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report /HI 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kara, 564-5667 21. I hereby certify that th~~M ue a~o:ect t~ the best of my knOwledge. Signed Dan Kara ~ ~ J ) Title CT Drilling Engineer COmmission.Use.Only API Number 50- 029-21595-61 Samples Required 0 Yes 81 No Hydrogen Sulfide Measures 181 Yes [J No Required Working Pressure for BOPE 0 2K Other: Ti'.-sf- 67 PE- +" tjsoo 17Ç':, ORIGINAL SiGNED BY M L. om 20. Attachments Permit Number <o~ -018 Conditions of Approval: Approved By Form 10-401 Rev. 12-01-85 Prepared By Name/Number: Terrie Hubble, 564-4628 Date 11~7/a3 See cover letter for other reauirements o Yes ~ No Directional Survey Required KI Yes 0 No o 3K D4K D5K D10K D15K 0 3.5K psi for CTU Ap~r1ifß~e Mud Log R~Uired r-'" rCommiS$ioner( ~: i, ¡ _-, \ !,,,~: U l\..)~~~ by order of the commission Date :?-11~ "7 Submit In Triplicate ) ) ~AU 3N-18L 1 &L2 Sidetrack - Coiled Tubing Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU 3N-18 using the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). This horizontal laterals (3N-18L1 & L2) will target Kuparuk A sand reserves for production. The Kuparuk A Sand perforation in the existing well, 3N-18 will not be abandoned and will be open to flow post CTD. Prior to CTD arrival, service coil will isolate with cement the existing C Sand perforations in the straddle interval of 3N-18 (sundry form 10-403 submitted) and set a flow-through whipstock. The existing A Sand perforations in 3N-18 can produce past the whipstock post CTD. CTD Drill and Complete 3N-18Ll & L2 proeram: Planned for March Ol~ 2003 1. Mill 2.80" dual string window at 10012' md (10006' ELM) and 10' of openhole. 2. Dri1l2.7"x3" bicenter hole horizontal sidetrack 3N-18L1 from window to -12000' TD targeting Kuparuk A3 sand interval. 3. Run and drop a slotted (pre-drilled) liner from TD of 12000', up to 10880' md. 4. Openhole sidetrack at 10875' in L1, above the 2-3/8" liner. 5. Dri1l2.7"x3" bicenter hole horizontal sidetrack 3N-18L2 from open-hole side track to -11975' TD targeting Kuparuk A2 sand interval. 6. Complete with 2 3/8" pre-drilled liner from the TD of L2 at 11975', up into the 3-1/2" tubing to -9950'. 7. Post CTD rig -Run GL V s. Bring on production. Mud Program: · Steps 1: 8.5 ppg Potassium-Formate biozan brine · Steps 2-3: Potassium-Formate based Flo-Pro (8.5 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · L1: 23/8",4.6#, L-80, STL slotted liner from 10880' md - 12000' md · L2: 23/8",4.6#, L-80, STL slotted liner from 10700' md - 11975' md Solid liner from 9950' md - 10700' md. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. . The annular pre venter will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 3N-18Ll & L2 · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. Kara 564-5667 office, 240-8047 cell 1/3 2RU 3N-18L 1 &L2 Sidetrack - Coiled T~bing Drilling Hazards · Two faults are expected to be crossed, one in the B sand/shale and one in the A sand, lost circulation risk is low. Res. pressure is estimated to be 11.1 ppg in the fault blocks. Well 3N-18 has a H2S reading of 110 ppm (measured 12/30/02). The highest H2S on 3N pad was measured at 156 ppm (3N-02, 12/31/02). 3N is an H2S pad. All H2S monitoring equipment will be operational. Reservoir Pressure · Res. pressure is approx. 3800 psi at 6568' TVD (6500' ss) 11.1 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 3150 psi. Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 8.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular pre venter will act as a secondary containment during deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the well bore after killing the well with kill weight fluid. Estimated reservoir pressure: 3800 psi at 6500' ss, 6568' TVD, 11.1 ppg EMW. Expected annular friction losses while circulating (ECD): 1000 psi Planned mud density: 8.5 ppg equates to 2900 psi hydrostatic bottom hole pressure. While circulating 8.5 ppg fluid, bottom hole circulating pressure is estimated to be 2900 psi, or 100 psi over- balanced to the reservoir. When circulation is stopped, a minimum of 900 psi surface pressure will be applied to balance the reservoir. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. Kara 564-5667 office, 240-8047 cell 2/3 ) ) -<RU 3N-18L 1 &L2 Sidetrack - Coiled T~bing Drilling Kuparuk 3N-18Ll&L2 Potential Drilling Hazards POST ON RIG 1. Please perform pre-job Hazard ill and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S - We1l3N-18 produces H2S at 110 ppm (measured 12130/02). The highest H2S on 3N pad was measured at 156 ppm (3N-02, 12/31/02). 3N is an H2S pad. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area, although KRU CTD sidetracks have not seen this in the past. The Pit watcher should always carry a calibrated personal H2S monitor. 3. Reservoir pressure - Reservoir. pressure is estimated at 3800 psi @ 6500' ss, 6568' TVD (11.1 ppg) in the adjacent fault blocks that will be penetrated with this well plan. Max. surface pressure with gas (0.1 psi/ft) to surface is 3150 psi. Reservoir frac gradient is -0.7 psi/ft or 13.5 EMW, 4600 psi. 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will be done with a less than kill-weight fluid (8.5 ppg Flo-Pro). While drilling and circulating at 1.5 BPM, hydrostatic head from the 8.5 ppg mud (2900 psi), plus 1000 psi of annular friction, plus 0 psi choked backpressure held on the return side will provide a 3900 psi BHP and overbalance the reservoir by -100 psi. However, when circulation is shut down, the reservoir could be underbalanced by -900 psi. Maintain at least 900 psi WHP when not circulating to prevent reservoir in-flux and to maintain formation stability by keeping static BHP close to circulating BHP seen during drilling. Adjust SlWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return- line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), divert those returns to an outside tank. 5. No gas saturated intervals are expected. However, always be prepared for the potential for gas influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Two faults are expected to be encountered along the wellbore trajectory. The faults are sealing and lost circulation is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate (1 BPM minimum) would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Pump only Liquid Casing or OM Seal fine through a slimhole drilling BHA. Do not pump MI Seal through a drilling BHA due to plugging potential. Kara 564-5667 office, 240-8047 cell 3/3 ') ~PHILLlPS Alaska, Inc. ;~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 3N·18 SSSV (1801~ 1802, 00:3.500) ....11111:,··...····.:', .-!I __m.""I, .1¡11:·,--"··'" IL...,.._ ' .I!!II''· .!rl'-'·'·¡' ~i'"" _,.:' PBR i~lilllilllllillllll:r i~II¡11 (9888-9889, 00:3.500) PKR (9902-9903, 00:6.151) ::II~I;!'-""" ill!L,....,",.:,/J, Perf (9983-10001) SLEEVE-O (10042-10043, 00:2.310) PKR (10057-10058, 00:6.151) NIP (10072-10073, 00:2.875) ::a:;:"' :t: Perf (10179-10201) Perf (10256-10278) Perf (10325-10329) Perf (10333-10342) API: 500292159500 SSSV Type: TRDP Annular Fluid: Reference Log: LastTag: 10170 Last Tag Date: 7/7/2002 Casing String· CASINGS· ALL Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String. TUBING Size Top 3.500 0 2.875 10067 ,Perforations Summary Interval TVD 9983 - 10001 6398 - 6408 Well Type: PROD Orig 6/4/1986 Completion: Last W/O: KRU 3N-18 Angle ~ TS: 54 deg ~ 9909 Angle @ TO: 45 deg @ 10630 Ref Log Date: TO: 10630ftKB Max Hole Angle: 59 deg ~ 2300 Rev Reason: Drift &Tag, set OV bylmO Last Update: 7/8/2002 Zone C-1,UNIT B A-3 A-3 A-3 A-3 A-3 A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-1 A-1 Top Bottom TVD Wt Grade Thread 0 116 116 62.50 H-40 0 5144 3621 36.00 J-55 0 10599 6804 26.00 J-55 TVD Wt Grade Thread 6448 9.20 J-55 8RD EUE ABM 6456 6.50 J-55 8RD ABM Status Ft SPF Date Type Comment 18 12 7/21/1986 IPERF 4" Jumbo Jet 11,120 deg ph Bottom 10067 10080 VMfr VMfr Cameo'TRDP-1A-SSA' Baker Baker 'FHL' AVA; BPC SLEEVE set 8/8199. AVA PORTED NIP Baker 'FB-1' Cameo 'D' Nipple NO GO Brown 18 o 2 o 2 o 20 o 2 o 2 o 1 o 22 4 9 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 9 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 9 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 1 7/21/1986 IPERF 4" Jumbo Jet II, 120 deg ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 9 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 9 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 9 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 8 1/6/1989 RPERF 21/8" EnerJet, 60 deg. ph 1 7/21/1986 IPERF 4" Jumbo Jet II, 120 deg ph 1 7/21/1986 (PERF 4" Jumbo Jet II, 120 deg ph 4 7/21/1986 ¡PERF 4" Jumbo Jet 11,120 deg ph 4 7/21/1986 IPERF 4" Jumbo Jet 11,120 deg ph. 10179-10197 6518-6529 10197 - 10197 6529 - 6529 10197 -10199 6529 - 6530 10199 - 10199 6530 - 6530 10199 - 10201 6530 - 6532 10201-10201 6532-6532 10221 - 10241 6545 - 6558 10241 - 10241 6558 - 6558 10241-10243 6558-6559 10243 - 10243 6559 - 6559 10243 - 10245 6559 - 6560 10245 - 10245 6560 - 6560 10245 - 10246 6560 - 6561 10247-10247 6562-6562 10256 - 10278 6567 - 6582 10325 - 10329 6613 - 6616 10333 - 10342 6618 - 6625 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2749 2269 Cameo KBUG 2 5546 3849 Cameo KBUG 3 7296 4862 Cameo KBUG 4 8333 5455 Cameo KBUG 5 8871 5764 Cameo KBUG 6 9369 6044 Cameo KBUG 7 9841 6315 Merla TPDX Production MandrelslValves St MD TVD Man Man Mfr Type 8 9942 6374 KBUG Other (?Iugs, equip., etc.: . JEWELRY Depth TVD Type 1801 1711 SSSV 9888 6342 PBR 9902 6350 PKR 10042 6433 SLEEVE-Q 10042 6433 NIP 10057 6442 PKR 10072 6451 NIP 10079 6456 SOS 10080 6456 TTL General Notes Date Note 10/9/1998 LOST RUNNING TOOL CORE IN TBG. 3/612002 E-LlNE CALIPERS INDICATE GAUGE PROBLEM AT TBG COLLARS - POSSIBLE CORKSCREW OR BALLOONED TBG 17 7/7/2002 DRIFTED TBG W/25.6' X 2.7' WEATHERFORD WHIPSTOCK DMY DRIFT TO 10042 RKB; NO PROBLEMS V Type V OD Latch Port TRO Date Run 1371 8/7/1999 1360 3/22/1998 o 3/15/1998 1381 3/22/1998 o 7/22/1986 o 3/15/1998 o 7/7/2002 Vlv Cmnt GLV GLV DMY GLV DMY DMY OV 1.0 1.0 1.0 1.0 1.0 1.0 1.5 BK BK BK BK BK BK RM 0.125 0.156 0.000 0.188 0.000 0.000 0.156 V Type V OD Latch Port TRO Date Vlv Run Cmnt 10/17/1998 Closed DMY 1.0 BTM 0.000 o Description ID 2.810 3.000 3.000 2.300 2.750 2.992 2.250 2.441 2.441 ) ) ,,'N-18 L 1 L2 Proposed Completion Tally .Length ~ ELM. X X Baker FHL 8.52' 9902' 9984' Packer 1 jt 3-1/2" tbg 31.53' 9910' 9902' Cameo GLM 1 jt 3-1/2" tbg 3-1/2" Blast Joint 6.55' 9942' . )1. 9934' . I I Il 31.03' 9949' 9941' . . .. . . . .. . . . . . 30.87 9980' . . 9972' .. . .. . .. . I I 10010' 10004·1. I I'~~ IJ¡ ~ ... :<:' II:t/I!; 10042' 10035' . 1004S' 10038·i I 10057' 1 0050' ~ 3-1/2" Joint 31.50' AVA BPL 2.95' 3-1/2" Pup Jt 10.10 Baker FB-1 Packer 9.08' " / 2-7/8" Pup Jt 6.09' 10066' 1 0059' Cameo D Nippe 2-7/8" Pup Jt 2-7/8" Tail Kara 1 .43' 10072' 10065' 6.12' 10073' 10066' 10080' 10073' A-sand Perforations ~ 7400' -7448 ELM Perfs to remain open to flow, post CTD ~ .. T' 26# Shoe @ 7670' 2-318" Top of liner 9950' 2-String Window at 11006' ELM 2-3/8" Slotted liner inside 3" openhole ~ L 1: Compete 2-3/8" liner from TO to 10880' L 1 TO 1 L2: Compete 2-3/8" liner from TO to QQ~n' L2 TO 1 . t 10171.00 eo.20 'II." I "OIÐ.OO 71.... ...... J ttONAJ' eo.OO ...... : ::~ ~::: ~::: . 1111LOO ".P ".21: 6100 - C ~ 6150 II) 6200 - i 6250 a. & 6300 "i 6350 - U ~ 6400 G,þ > G,þ 6450 ~ 6500 - --- - ------- Phillips Alaska, Inc. WIILL,.ATH DIITAlIA ",.11I2 "'.111.2 .00212U...1 ........ ."atlll Tie.. M01 1'100111.1 IN-tilt '''71.60 IIII bf'. a.t.... v.-- ""... JI..... 0.1t; = 11'- ::::;t.o ..... REFERENCE INFORMATION Co-ordinate (NÆ! Reference: Well Centre: 31'1·18. True North Vertical (TVD Reference: System: Mean Sea Level SectIon (VS Reference: slot - (O.OON,O.OOE) Measured Depth Refe(ence: 31'1-18 RKB 68.00 Calcutation Method: Minimum Curvalure aKTlOll .IT...... :=::: ::~::::: :::tn ~1~ 012.07 -4M2.ao "2:2.42 -42U.7. ..- ..n.~ ...... _02 10..... _t. ........ eL.. TF.. vaec T.-get 0.00 0.00 -:NOt... 12.00 1100.00 ·aue...u :t: ..:::: :==:: :::: :::: :~=:: ANNOTATION. TYD T\ID ..w..s ..~ 3H-1eL2T11 1!50592 -41£3,17 498281 Por.t 3H-U12T13 SSI,tS-4602.1S .f9Ool19 PtWII ~.1"2T12 6S1511 -t98291 4N:Iog Pont JH.la..2TU 651611 ...."91 49586a Pon 3U-tUTl5 652214 -C1M1.!6 517' eo PonI liD "'otal104l 147.... 11171.80 KO,. _2.' 1IM2M 2 ..1.... ""'''''' I IIU., 11M1,47 . Un.7 1110,47 . '122.42 1 tlUM TO --- --- ----- ---------- 5950 6000 6050 3N-I8(3N.18[ 6550 6600 6650 . 6700 rPHïUlN'\ .T!J"lI. ,..' , .... ~ Bíi_ a__ Contact Information: LEGEND T ~:1g!~~1.13N-1811)^ M ;~'~"" ¿ Plan: Plan #2 (3N-18/Plan#2 3N-18L2) Created By: Brij Potnis Dale: 1/23/2003 Azimuths to True North Magnetic North: 25.43· Magnetic Field Strength: 57491nT Dip Angle: 80.79· Date: 1/23/2003 Model: BGGM2002 Direct: (907) 267-6613 E-mail: brij.potnis.~inteq.com Baker Hughes INTEQ: (907) 267-õóOO h"1TEQ "" ~~ -4000 -_ ------"-- ---"-- -- -- ------ --- ------------ - - ------ ----- --~----- ----- - ---- -4100 i 3N-18L2 T1.S' - -- -------=-- --" ----------=-=- ~i-- ------- ------- --------~ -------~ - - ----- ---- -------- .---- 3N-18 (Plan#1.1 3N·18L 1~-- ----- ----- -- -4200 ------ . ------- - ---- --------- - ---- ---~------ -- - ---------- ------ --------- "-- ------ 4300 ~ n --:- ~-- -;/ß:"".',¡¡;~ --- --=-- -~---- .. -4400 - ~- - - -- --~ - ~- 3N-18L2 T1.47~~ - --- . ------ -~ -=''=- --====---======= i -4500 ~=-=---=c ~~ -- - --C - -- -b}:>: . n --e- ~=----- --- -- o -4600- -~~- --~3N-18L2T1_3>_f - - ------... ---- --~-- ---.--- o .. I ~-47oo=---- ---~ __~_~__n______\------ + - ------ ------- ---r -"'3] -~- @ -4800 ~-=::=-==-=-__- - ~~=----: ----:-: -----==-_=_- -=--~=~==- =-. -:- .::-- ~ _ _ ~=__d ~~-=~ _m~__ -=_=-==-~~--- o -49~ --- --- .__.._____.________.~-d.- -.--.-.----- ---.- ------ i:z~\~,~----~~~~~n---~;;;':'1!::n _~~_~ ~ _=---- - ->=~--- ~- = í - -1-- - -5400 -~-- -- --~ . -=-=----------=-=--=--. -/-_.-- ----..;:- --- ~--+-~-- / -- -- -------------- -5300- ----- -~-- ----- - .----.----------- "-----"-- ----- ---------- -------- -- - ------- -- --------- ---- -5SOO-= ----- ----------- --~-_. - - ------ -- --- --- / ----- - -------/------- - .--- ;/ - ~:=~-=-_= ~~-~:N-18(3N~18~~~~r~_:~-_-~--=-~-- __ ___----_ ~_-_-_ _-~~-=---~----_~~-~-~=~-~_ == - ---- 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 West(-)/East(+) [100ft/in] '- ------- ~---- ----- - --------- ~ - -=----==-=------=--=----=--=====-- -- --=------ -~ - -~--- - ------- ---~- -. - - -.::==-=-.::=~-- _~~ -)/" -..~ .~~~.jj~-::"iN""'"""~-~:'''~J=~ic,-~_ ____-' :'N:18~T~_. 3N-1812T1.3; -_-_-----i 3N-~_T1,:4~-~---i 3N-18L2.T1.~-_~-------== --- ----------~ --------~---~ . --- ------------- ------ --------- ----- ------ - - --- --- ------- -------- ---- - - -- ---- -------------- ----- ----------- ""--- --- ------- ------------- --- - ----------"----- --- ----- -" - -----------~-- -- -- - ----- ------------------- . -3300 -3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650-2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 -1550 -1500 -1450 -1400 Vertical Section at 25.000 [50ft/in] -----~- 1/23/2003 '1 :37 PM ) ) BP Baker Hughes INTEQ Planning Report .11. ... IN'''Ì'ÊQ .., ~''''''~'~''''__'''_''-:'''''_'''U'.__'_'''''''_'~''''__~_'_,.._'''''''':_·'~_'___','"''''_U_'__''''''''__-:-''''''.'U'-:-_'__,'''__''._''''_"-""'._'__''--:'''_'''~-'-~'U--:-_~._''''_'_''''.''''''_''_'''''~'''~''''.-~"'--~"""'--""'-''''~-'~'''-''''''''-~'''~--,''_.''.''''''''-,----1'''-~~-_'~__"""'''''_.''~_'____'''''_'''''_'','''_'''''''''''',''___''''_'''.___'~__'__"_""""U"__"" Compa~y: I::'hiips~¡:tska,l~c. Dat~:i112~1~()0:3..,... iY ......., 'fime:..16.:å.8:2S Page: Fie~d: KtJPI:ln.!k~iv~rOnit Ç~;-O"dina~e(~~)~~fe"~IÎ~e: ,,^,~n:~~~.1~}Tru~ NÞr1h.· ~ite: KRlJ~NPad . VertJcal(TVJ)lt~fe~IlC:~: '.'S~s~~m:Me~nS~!3L~ver . . Well: . 3f\J-H~.'.·.·....·····,..··· ...................... S~tion(VStRefe~en~e:,.... '..' . Well (Q.00N.0.00E,.25.00Azi).' .... ~~~c~~~.t~:-.·..:~~~~~'.~~:~:~~:;~c::~.:.7::::7'7::_:~-.:'·~.:7.::C:::::.:~::=':'.:::':::=.~.:.~':.::::::'·.:.::::.':..:~.:.=::::::::~~~~~:~~~~~~~i~~~~~~:~f:::::=-::~~~=~~.:~~.~~~u.~~:::::.::.~:=::.:~::::~~;::;=~:¥~~~:~....., Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: -'--'-'-'.---'-"-~ ".. ...,-.........,.-.."....,.....,,--.... -_,."~"""" ,,,_. _.. ....'_._..___.__.."_ _,~_ ~... , _ ..",". . ._..,.....__.__."...._....._._..,.... ,,_,_...~ .".,...,. '''..,._~....~,__.".._.__''',.. _'''M''_' _"..._._.._~_..__"..,._,,_.... ,_,_~__"_...._._....,,._'_ ..... .. ","' _",____'___.'_'.__.___,u_'u___.'".__._.._.",_.__. ___.._ ._.., ....__._... ._,,___ . _ .____0'. Site: -.,"-.,..." KRU 3N Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013799.38 ft 518425.12 ft Latitude: Longitude: North Reference: Grid Well: 3N-18 Slot Name: Alaska, Zone 4 Well Centre BGGM2002 70 26 55.947 N 149 50 58.873 W True 0.14 Well Position: +N/-S 0.00 ft Northing: 6013799.38 ft Latitude: 70 26 55.947 N +El-W 0.00 ft Easting: 518425.12 ft Longitude: 149 50 58.873 W Position Uncertainty: 0.00 ft "....-. --~. ."" ... --_... "- .." ".'.. _., ,..' n .....~._....."".. ,,_. ."_.."._._...._.,,__.._.._,,.__.__.__'.'_.____..~,_.._.._n._.__._____._ _".~.,,_._"_._~_._._._.___,,_........_. ,__,...._ ._ __.._....."__,,.._._.. ~'_ _'__".'''___'_..__...n... ..,,_ _ ._ _~ ..__.___. .___...,_ -~,. ....... -- ."" ,-" ,-,.-"._"-_._.,, ,,-..'''.-..-,... -_...... -.... ..-. ..-..".. Well path: Plan#2 3N-18L2 500292159561 Current Datum: 3N-18 RKB Magnetic Data: 112312003 Field Strength: 57491 nT Vertical Section: Depth From (TVD) ft 0.00 Height 68.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 - n_._._.._____ _._____ __.. '''___''_ ......._ - . ---....-.-. .".-,,-..----...--.-- --.-------.."...-.....--....-....-..-..-...-..-"'---..,-..--- ... -'- -~------ -.-".-...---.-.-..,-.."....-...-....- -~._-_......._.. -~. - Targets Plan#1.1 3N-18L 1 10875.00 ft Mean Sea Level 25.43 deg 80.79 deg Direction 25.00 . ..... .. ..... .......... ....... ....... .... ····_····S~r······_-_· ............-.-........-:.....:..........-....-..-...-.··-M;~·-~..--..·..·:M~;····_·..··_~·~:::··i~~tii~~~···:;~::;:··-~:···ï~gïi;d;-·::;·· Name Description TVD +N/-S+E/-W Nôrtbi~3 Easting ~eg.l\'Iin.· ..Se¢· . DegMin '. Sec . ....... ....m... ............ .............. ., ...... I?.~~.~......_..... .....:...~~~:_.._:_..:.._!!..._.,. ..._.._.,:, ._...~_~:... .'"_..._..._.._~._ ....._..__.....~_.:.__........_.~..._~......,~..........;.......__...._..._...,....._.~._.,..... . ........, __........_.......... ........ ... ...__.. 6505.92 -5143.17 4982.82 6008669.06 523420.14 70 26 5.349 N 149 48 32.648 W 3N-18L2 T1.1 3N-18L2 T1.3 3N-18L2 T1.2 3N-18L2 T1.4 3N-18L2 T1.5 6511.18 -4602.18 4904.79 6009209.80 523340.78 70 26 10.670 N 149 48 34.928 W 6515.27 -4982.91 4989.09 6008829.31 523426.02 70 26 6.925 N 149 48 32.461 W 6516.11 -4414.91 4958.68 6009397.18 523394.20 70 26 12.511 N 149 48 33.342 W 6522.78 -4159.36 5171.80 6009653.23 523606.67 70 26 15.023 N 149 48 27.082 W .--. -"..-....-...-.--.--...-.--.-. ....- ,----_....----. ~_..._...._._..- ....-. --..--.- .-....----.-.,,---.---...--- _.·_._......_____...n_.. -.. .-----.--.--..- .---- - ~~~~!.~~~~."-... ...5~__..._.. ..._......_._. ......... _ .... ._____...._..... ..._...___.._....__...__..___.. MD TVD ft ft ._ .._ ......_.____., ______ _ ___._ ~.._____ ____....__~.__._._. .....,_,,__. .._ .._ .. ._. ._ .'~M·.__·_._..,,~..__'L.' ____,,_. _.__.___....,_._..__._.__._..__..._ _._...._".. __,.__.._ ____...___ 10875.00 6476.94 KOP 10943.00 6492.96 2 11088.47 6514.95 3 11308.47 6511.91 4 11528.47 6513.07 5 11975.00 6522.42 TD _ ---.------------- .-.-.-- --.---. ....---.--- """._-._.-~...._.__." ...-------- ----~... ---.-'...-_......- .. ..-.--.,------.---.--- ---. ".- --. -.. ---...- - ..-.-. .-... ..----- -.-. .--_.. -.. -- .-.- . - --...- ----- .--. - - Plan: Plan #2 Maintain separation from steel in L 1 Principal: Yes Date Composed: Version: Tied-to: 1/23/2003 2 From: Definitive Path ') ) BP Baker Hughes INTEQ Planning Report ~ IN"rE.Q ··c;~;;~;~-··pj~¡iI¡p;7Àï~;k~.·T~~·~·-···-··-··-'····--..·.--·,·-··..--·.···---·----·,·,--,·.,--D~~~··;~í23i2õõ3--"-"'--"1irne:16;'~;~8'-""---"--'~-----'-"'-,'.;¡;;;-.-.....'.....'...-" Field: Kupal'4kRiyer Unit" Ç~:-Ør~in3te(NE)~~fe~~n~e: WeU:3~-18TruèNorth Site: 3KNR~1"'8" 3f:.¡Pad .Yel1!~al (1;Vl»Refere~cç: " .. S~~~ßm:Mec:l~$~a Level Well: . ' .S~ion(VS)Refç~nc~~ Well(0.OON,O~OOE.25.00Aii) ," ~~~I~~~.~..~..~~~D~__~~=~.~ç~....:.......,.....~.l::.._.'".",,:...:...c.....;.....,_:.._..,~. ,:._......~..__.......'_.~~t~!~.~l')~.-:!.~~~?~U~~!~~~?~._._;..._M~~~!fl.~~.2.~.~.~.~I~...___.._."_..:.~!~...~X~~~~..__... Plan Section Information .".".,,_....,-"',--,._'-_...,'.~"'-.._.._-'-"'-,_.,..,...~..-~...._'_..,_.,,_.-...-'--._....._''':'-...,----,....._.. '."--'-'..'-'---"---"'---'..-'.'.'---'."'.--" "._'-"--~-"'""._-'_.""-'-_.'''--''--''.'_.'..--- ,~~,-,,-,~-,--_._.,._",....._-,-_._......__.,---~..,'-'''-'.--,._~~--::._-_.""~-,--~"",....,,.~_.._~_..,,--...~-.--. --~"'''..'._.''-'-''._.''"":'' MD ft ....".-.....,..,......-."'.."...-'"'".,,.. 1 0875.00 1 0943.00 11088.47 11308.47 11528.47 11975.00 Incl .Azlm 1'VD " +N/-S +E/-W DLS Build Turn IFO Target ,;..~~~,L._:.c..,___~!._~~.~.:c:_._"___~__~..___.-'m_........~:__......c.:,_.:.L~~._._.~..;__~.~~~.~.~~~.~~~Q~8.~.~~~.~{1.?.9~~___.~~_~~c._c_...._.... ........_..._..._...___..__.....__._....... 80.20 12.96 6476.94 -5189.65 4973.42 0.00 0.00 0.00 0.00 72.54 15.88 6492.96 -5125.69 4989.83 12.00 -11.25 4.29 160.00 90.00 15.88 6514.95 -4987.93 5029.02 12.00 12.00 0.00 0.00 91.56 349.52 6511.91 -4770.13 5039.30 12.00 0.71 -11.98 -86.50 87.85 15.66 6513.07 -4552.30 5049.15 12.00 -1.69 11.88 98.00 89.93 69.22 6522.42 -4234.79 5339.62 12.00 0.47 11.99 88.50 . ...---......,-.-...-".."".... ..... ._,..... ,.. ...w",,"_ ",." ....... ....... .".."_"..._...'W'. _ "~'''.'' ._. _...._........ ..~,..,,,_,,.., .,..._..~,._,._.,._.,_.__.".. .,__,~..,..", "'..,.._"'._,,,.....,,_..._.......... .~..~,,~_ _.."...___.,__....,_._..·w._..· ..~ ._ ,_~. ~".. .....__."~.,...... ,,__........__,..~... ... 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L.~~~g",~:.:...._;,:_"J!._,., ,::,.,'""'_,.,.,"':.._~,_,,~::..~:~..,_.. ft 10875.00 80.20 12.96 6476.94 -5189.65 4973.42 10900.00 77.38 14.01 6481.80 -5165.80 4979.14 10925.00 74.57 15.09 6487.86 -5142.33 4985.23 10943.00 72.54 15.88 6492.96 -5125.69 4989.83 10950.00 73.38 15.88 6495.01 -5119.25 4991.67 10975.00 10995.49 11000.00 11025.00 11050.00 11075.00 11088.47 11100.00 11125.00 11150.00 11175.00 11200.00 11225.00 11250.00 11275.00 11300.00 11308.47 11325.00 11350.00 11375.00 11400.00 11425.00 11450.00 11475.00 11500.00 11525.00 11528.47 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11700.00 11725.00 11750.00 11775.00 11800.00 11825.00 76.38 78.84 79.38 82.38 85.38 88.38 90.00 90.08 90.27 90.45 90.63 90.81 90.99 91.16 91.33 91.50 91.56 91.28 90.86 90.43 90.01 89.58 89.16 88.74 88.32 87.91 87.85 87.92 88.00 88.10 88.19 88.30 88.40 88.51 88.63 88.75 88.87 88.99 89.12 15.88 15.88 15.88 15.88 15.88 15.88 15.88 14.50 11.50 8.51 5.51 2.52 359.52 356.53 353.53 350.54 349.52 351.49 354.46 357.43 0.40 3.37 6.34 9.31 12.28 15.25 15.66 18.25 21.25 24.25 27.25 30.25 33.25 36.25 39.25 42.25 45.24 48.24 51.24 6501.53 6505.92 6506.78 6510.74 6513.40 6514.76 6514.95 6514.94 6514.86 6514.71 6514.47 6514.16 6513.76 6513.30 6512.75 6512.13 6511.91 6511.50 6511.03 6510.75 6510.66 6510.74 6511.02 6511.48 6512.12 6512.94 6513.07 6513.87 6514.76 6515.61 6516.42 6517.18 6517.90 6518.58 6519.20 6519.77 6520.29 6520.76 6521.17 -5096.04 -5076.79 -5072.53 -5048.80 -5024.89 -5000.88 -4987.93 -4976.80 -4952.44 -4927.83 -4903.02 -4878.08 -4853.09 -4828.12 -4803.22 -4778.47 -4770.13 -4753.83 -4729.03 -4704.10 -4679.10 -4654.12 -4629.21 -4604.45 -4579.91 -4555.64 -4552.30 -4531.72 -4508.21 -4485.17 -4462.67 -4440.76 -4419.51 -4398.98 -4379.22 -4360.29 -4342.23 -4325.11 -4308.95 --- - _.. -- --..--- ~..- - 4998.27 5003.74 5004.95 5011.71 5018.51 5025.34 5029.02 5032.04 5037.66 5042.01 5045.06 5046.81 5047.25 5046.39 5044.23 5040.76 5039.30 5036.57 5033.51 5031.74 5031.27 5032.09 5034.20 5037.60 5042.28 5048.23 5049.15 5055.43 5063.87 5073.53 5084.38 5096.40 5109.55 5123.79 5139.09 5155.40 5172.68 5190.88 5209.96 ..._,..! .~_..._.~. '._'_"'___'~,._"__~__'__' .~__.. .___"_._. ..,,_.__._~__._~ ··._..h_._.._...._·~· ..._._._~......_.,,_......:___~_.. ....__._. _...,...._.. _..... _.._. MapN MapE VS DLS TFO Tool :,.........,~__..:..".: ':,:,.".~"';~;;,..,,. ..._,:~...." ...:...:~,;...,.."...:.."_.,...~.~,.,.."..'-.~,,...;:~.:~~~~9.~,.,_".:....~~~...,__".. """;.,,,.,. ......" .".". 6008622.56 523410.86 -2601.56 0.00 0.00 KOP 6008646.42 523416.51 -2577.53 12.00 160.00 MWD 6008669.90 523422.55 -2553.68 12.00 159.80 MWD 6008686.55 523427.11 -2536.66 12.00 159.54 2 6008692.99 523428.93 -2530.05 12.00 0.00 MWD 6008716.22 6008735.48 6008739.74 6008763.49 6008787.41 6008811.44 6008824.39 6008835.53 6008859.90 6008884.52 6008909.34 6008934.27 6008959.26 6008984.24 6009009.12 6009033.86 6009042.19 6009058.49 6009083.28 6009108.21 6009133.19 6009158.18 6009183.09 6009207.85 6009232.41 6009256.69 6009260.03 6009280.62 6009304.15 6009327.21 6009349.74 6009371.67 6009392.95 6009413.52 6009433.31 6009452.28 6009470.38 6009487.55 6009503.75 523435.47 523440.90 523442.10 523448.79 523455.53 523462.30 523465.95 523468.95 523474.51 523478.79 523481.78 523483.4 7 523483.85 523482.93 523480.70 523477.18 523475.69 523472.93 523469.81 523467.98 523467.44 523468.20 523470.25 523473.59 523478.21 523484.09 523485.01 523491.23 523499.61 523509.22 523520.01 523531.98 523545.07 523559.26 523574.51 523590.77 523608.01 523626.16 523645.19 -2506.22 -2486.46 -2482.09 -2457.72 -2433.18 -2408.54 -2395.24 -2383.88 -2359.43 -2335.28 -2311.51 -2288.17 -2265.33 -2243.06 -2221.41 -2200.45 -2193.51 -2179.89 -2158.70 -2136.85 -2114.40 -2091.41 -2067.95 -2044.07 -2019.84 -1995.34 -1991.92 -1970.62 -1945.74 -1920.78 -1895.79 -1870.86 -1846.05 -1821.42 -1797.05 -1773.00 -1749.33 -1726.11 -1703.42 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 ---- .-. - - ....-. -- --.-.-- "-.- --------- 360.00 MWD 0.00 3N-18L2 360.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 360.00 3 273.50 MWD 273.50 MWD 273.49 MWD 273.47 MWD 273.44 MWD 273.41 MWD 273.36 MWD 273.30 MWD 273.24 MWD 273.16 4 98.00 MWD 98.05 MWD 98.10 MWD 98.14 MWD 98.15 MWD 98.14 MWD 98.11 MWD 98.05 MWD 97.97 MWD 97.88 5 88.50 MWD 88.40 MWD 88.30 MWD 88.20 MWD 88.10 MWD 88.01 MWD 87.92 MWD 87.84 MWD 87.76 MWD 87.70 MWD 87.63 MWD 87.58 MWD "; » ) ..........il1,.... . . iI_. ...... BP Baker Hughes INTEQ Planning Report INl'EQ '_'_'_~_'_"_""___",".'.'_.,_n.~"_""""_""'~~'._"""_..,...,.__.._.,:__.__.,. Cømpany: phmipsAI~$ka,loc. ,Field: Kuparuk,~iver Unit Site:.. . K~U~Npad' Well: 3N;.18 . Wellpath: Plan#23N-18L2 .-.....---.. ......---...---. --.-.--~.--..._--......----..---.-"..--...--...-------...-.--.-".--..,..-..--..-..--.."..--..---.-..---.---.--.'--"--"--'"p;~~;~."-'--; . "--"'-1 , ···1)~te:i.1/23/~()03 ............... ·.TilDe:W:38:28'.. ...., ...... .......... Co~..di...te(NE)~ef~re..ce: W~n:3N:-t~,Tru~. No.rtH Yertic.I(1;VQ)R~fe~~c~:'Syst~m:Mean S~~ Levøl , S~tion{VS) ~efe..en(:e: '. Well(0;OON,0~OOE?,2~.00Azi) _____________~~~~~.~~I~~.~~~~~_l\!e.!~~~~..._.._ ~~~~~.~m_ ~_~r:"~.t~~~.._____.. _..~~~. ~~~~se u ._._ __ __ __ __ ..... __ ___ ______ .- -- -- -- "... . -.." Survey -.'. ,.,...,...... ',.-.... ,-, ,. ..",.'.'......,..---.",.,..,.-.. '.-...-....-....... ........_..,,".-.. "~-, '''.'.-...... 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", ._.... ___.~....__~____:._.._..~~_,.__""'.,. .. ..'"'' __"....~"'"._"....,__.._..~..~~_.____,_'__,_"'_.:_~~..._...._;_.~:~~~__~.~,......~:~_..~._.. ... .....~.. 11850.00 89.25 54.24 6521.53 -4293.82 5229.85 6009518.93 523665.05 -1681.29 12.00 87.53 MWD 11875.00 89.39 57.23 6521.82 -4279.75 5250.51 6009533.05 523685.67 -1659.81 12.00 87.49 MWD 11900.00 89.52 60.23 6522.06 -4266.77 5271.87 6009546.08 523707.00 -1639.02 12.00 87.45 MWD 11925.00 89.66 63.23 6522.24 -4254.93 5293.89 6009557.97 523728.98 -1618.99 12.00 87.42 MWD 11950.00 89.79 66.22 6522.36 -4244.26 5316.49 6009568.70 523751.56 -1599.76 12.00 87.40 MWD 11975.00 89.93 69.22 6522.42 -4234.79 5339.62 6009578.23 523774.66 -1581.40 12.00 87.39 TD , ". ". ... ..."..~,.... _~._~_".,__,,,_..., ._..""."._._.,,....~..". ._"....'H__'" _..,....._.....,,__,~ ..~,,___,_._.._...._ .....-...--...""...--..--..--. ..--....---........."'.-- --.----..-.--'-. --... ( l \ J BOP-Tree . KB Elevation I ';'~~'~:I~,:"l:"''''''''':'':''''':''''''i''''''''''''"""1:",:,,,::,1,,:,,:',""'::'::":: 1;,:"":,,:,,,,~;:,:~i9 Floor I, I Lubricator ID = 6.375" with 6" Otis Unions 171/16" 5000 psi BOP's. ID = 7.06" I I 13" 5000 psi 1/4TurnLTValve I I Choke Line I I 121/16" 5000 psi, RX-24 I 71/16" 5000 psi (RX-46) or 4 1/16" 5000 psi (RX-39) I Swab Valve I Tree Size I -+ SSV I I Master Valve I I Base Flanue I I Page 1 ! ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k f( U 3JJ-/'6hÅ PTD# 2(33 - O/~ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL ;/ (If API number last two (2) digits are between 60-69) "CLUE" The permit is. for a new wellbore segment of existing we1l3V -- yI" 7 Permit No/1'''''' 01.~API No. ..)0 ..ð.2....9-:J./.f?.5_ðO Production should continue to be reported as a function 'of the. original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07 II 0102 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANYc""V>#'_f:J/J/f~ WELL NAME k/(/4 FIELD & POOL t:-¡ 7 ó/ ð 0 INIT CLASS LJ"~J / -ð) 'J 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. W ell located proper distance from other wells.. . . . . . . . . APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Ø/J/ ~ .... ~ 7 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 4ß--. ~~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force.. . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wOn area & strata authorized by injection order #_ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .'. ENGINEERING APPR DATE ¡¡J4A- Z--/ ifl ð '; . (Service Well Only) GEOLOGY APPR DATE he ¿¿). , (ExpIO~~~ Only) 31J-/~L.2I?ROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Serv _ Wellbore seg ~ GEOLAREA 9J~ UNIT# /)/6'(') ON/OFFSHORE~ .;.~~ 1',c;- AJ-. /r,..,..~A:! ~.,.J ....I /'''¿4/'-~ Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N '!¥. AJ'~ yN t ¥--N- -¥--N-- Y N . III lit- -¥--N- d *"* c../ctfe . ~~ 1:V N N {it- ,~ -¥-N ¡J/A- ~~ µ4v N . Y N 15. Conductor string provided. . .. . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf O5g. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B& permafrost. . . . . . . 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. .... . . . . . . , . . 24. If diverter required, does It meet regulations. .. . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . .. . . . 27. BOPE press rating appropriate; test to 4~OO psig. 2S. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . , . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ,\ \ ( . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING ule ENGINEER COMMISSIONER: Comments/Instructions: RP~ TEM JDH JBR COT D 2-/~7J0.J DTS / MJW MLB ð:2/eJ.r-/03 SFD_ WGA Rev: 10/15/02 G:\geology\permits\checklist.doc