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Home My WebLink About197-179XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. iCl~... i r~L~ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: ~ GraYScale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. n Other, No/Type 'OVERSIZED n Logs of vadous kinds Other COMMENTS: Complete Scanned by~itdred- Daretha Nalhan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si J~1 STATE OF ALASKA) ALASKA IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1 a. Well Status: 0 Oil 0 Gas 0 Plugged B Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2911' SNL, 5033' WEL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 3695' SNL, 5029' WEL, SEC. 32, T11 N, R15E, UM Total Depth: . 5052' SNL, 3937' WEL, SEC. 32, T11 N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 697330 y- 5948538 Zone- ASP4 TPI: x- 697357 y- 5947754 Zone- ASP4 Total Depth: x- 698489 y- 5946426 Zone- ASP4 18. Directional Survey 0 Yes B No 21. Logs Run: MWD, GR 22. Zero Other 5. Date Comp., Susp., or Aband. 12/23/2004 6. Date Spudded 06/25/1998 7. Date T.D. Reached 07/06/1998 8. KB Elevation (ft): 71' 9. Plug Back Depth (MD+ TVD) 10765 + 9028 10. Total Depth (MD+ TVD) 10800 + 9027 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING, LINER AND CEMENTING RECORD CÄSÎNG . SeT'lNI3DePTHMD SETTiNG DePTfi tvo . HQI-E SIZE WT. PER FT. GRADE Top BOTTOM lOP BoTTOM SIZg 20" 91.5# H-40 Surface 115' Surface 115' 30" 13-3/8" 68# L -80 Surface 3512' Surface 3512' 16" 9-5/8" 47# L-80 Surface 8621' Surface 8454' 12-1/4" 7" 29# L-80 8291' 9323' 8179' 8909' 8-1/2" 4-1/2" 12.6# L-80 9265' 9322' 8881' 8908' 8-1/2" 2-318" 4.6# L-80 9141' 10800' 8817' 9027' 2-3/4" 23. Perforations op'en to Production (MD + TVD of Top and 24. Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED FES 11 2005 26. Date First Production: Not on Production Date of Test Hours Tested 27. SIZE 3-1/2", 9.3#, L-80 TVD 1 b. Well Class: B Development 0 Exploratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 197-179 304-410 13. API Number 50- 029-22137-01-00 14. Well Name and Number: PBU 05-20A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028329 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING. RECORD 2150 Lbs Poleset 1295 sx CS III, 400 sx Class 'G' 1420 sx Class 'G' 100 sx RAMP, 234 sx Class 'G' Uncemented 37 sx LARC TUBING RECORD DEPTH SET (MD) 4799' - 9265' AMOUNT PUllED PACKER SET (MD) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4730' Set EZSV w/ Whipstock on top GAs-McF W ATER-BBl CHOKE SIZE GAS-Oil RATIO PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR Oll-BsL TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BSL Press. 24-HoUR RATE GAs-MCF W ATER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 1 0-407 Revised 12/2003 RBDMS BFL FEB 0 8 2005 CONTINUED ON REVERSE SIDE Gf 28. ) GEOLOGIC MARKERS 29. ) FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8535' 8385' None Shublik A 8583' 8424' Sadlerochit 8673' 8494' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHUbble~ ~ Title TechnlcalAssistant Date mr()l{-OS PBU 05-20A 197-179 304-410 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Dave Wesley, 564-5153 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injectio~,<:1~lnjeqtion, S,hut-In, or Other (explain). kJ ..~. L . ITEM 27: If no cores taken, indicate "None". SubrT1i~f:;>ri~.j~iil, 9nly ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ) ) BP EXPLORATION Operations Summary Report ., Page 148Þ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 12/19/2004 00:00 - 13:00 13.00 MOB N WAIT PRE 13:00 - 00:00 11.00 MOB P PRE 12/20/2004 00:00 - 08:30 8.50 RIGU P PRE 08:30 - 09:00 0.50 RIGU P PRE 09:00 - 10:30 1.50 RIGU P PRE 10:30 - 14:00 3.50 WHSUR P DECOMP 14:00 - 18:00 WAfT DECOMP 4.00 PULL N 18:00 - 23:00 5.00 PULL C DECOMP 23:00 - 00:00 1.00 PULL C DECOMP 12121/2004 00:00 - 02:30 2.50 PULL C DECOMP 02:30 - 03:00 0.50 PULL C DECOMP 03:00 - 04:00 1.00 PULL C DECOMP 04:00 - 05:00 1.00 KILL P DECOMP 05:00 - 06:00 1.00 PULL C DECOMP 06:00 - 07:30 1.50 PULL C DECOMP 07:30 - 08:00 0.50 WHSUR C DECOMP 08:00 . 09:00 1.00 WHSUR P DECOMP 09:00 - 10:30 1.50 WHSUR P DECOMP 10:30 - 11 :30 1.00 WHSUR P DECOMP 11 :30 - 12:00 0.50 WHSUR P DECOMP 12:00 - 15:30 3.50 BOPSUP P DECOMP Start: 12/19/2004 Rig Release: 1 n /2005 Rig Number: Spud Date: 3/26/1991 End: 1/7/2005 Description of Operations Standby @ J-pad with full crews waiting on weather and road clearing. Phase 2. PJSM. Move sub from J-pad to DS 5-20B Spot sub over the well. Raise the derrick. RU the rig floor. Spot the pits cuttings tanks and the rig camp. Hold Pre-spud meeting with all hands. RU DSM and pull BPV with lubricator. 200 psi on tubing and 0 psi on annulus. Install secondary annulus valve and circulation lines. Rig accepted 12/20/04 @ 1030 hrs. Open up tubing through choke and blleed diesel to cuttings box. Line up to pump down the annulus - unable to pump. Shut in the well and verify no ice plugs in the surface lines. line up and open up to the tubing and attempt to circulate to cuttings box throught the choke - no returns. Bullhead tubing volume of 9.8 ppg brine down the tubing - 3 bpm, 300 psi. SI and monitor tubing pressure - 0 psi. RU and pump down annulus. Pressure increased to 3,000 psi with -8 bbls pumped. SI well. Pressure dropped off to 475 psi and held. No returns seen up the tubing or a pressure increase on the OA. Bleed off annulus pressure and RD circulation lines. Talk to town about plan forward. Wait on Slickline to arrive to pull GLM @ 5,201'. Performed injectivity test @ 0.5 bpm pumping in at 520 psi. Monitored tubing and OA pressures - 0 psi. Note: Surface casing @ 3,512' RU SLB Slickline. Change out SLB tools for rig use. RIH with slickline to pull dummy valve from GLM @ 5,201'. Some difficulty getting through the tree. RIH with slickline to pull valve from GLM @ 5,201'. Pulled valve from GLM on 2nd try. Valve pulled from the GLM was an orifice valve. Pumped total 30 bbls, 9.8 ppg fluid down tubing at 3 bpm and 400 psi. Attempt to circulate - unsuccessful. RIH and pull valve from GLM @ 3,208'. POH. Valve pulled from 3,208' was a dummy valve. Circulate diesel freeze protect from the well through the GLM @ 3,208' with 9.8 ppg brine - 4 bpm @ 150 psi. RD SLB Slickline. Rig up circulating lines to tubing. Pump 45 bbl soap pill. Displace surface to surface at 12 bpm, 1450 psi. Monitor well - on vacuum. Install BPV and attempt to test from below. Pumping fluid away at 3 bpm, 400 psi. NO tree and adapter. Hold PJSM. Bleed off chemical injection line to tank. (2,200 psi). Wait on CIC to break and plug non-purged chemical injection line. Filling annulus with fresh water using charge pump. Losses at 15 bph. PJSM with CIC. Disconnect chemical injection line. Pull tree and remove from cellar. Measure RKB. Install blanking plug and check hanger threads. NU DSA and BOP's. Printed: 1/10/2005 9:23:36 AM ') ) BP EXPLORATION Operations Summary Report Page 2'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Start: 12/19/2004 Rig Release: 1/7/2005 Rig Number: Spud Date: 3/26/1991 End: 1/7/2005 Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2004 15:30 - 22:30 7.00 BOPSUP P DECOMP Rig up and test BOP with 4.5" and 3.5" pipe. Test to 250 psi low and 3,500 high. Record on circular chart. Note: Test witnessed by AOGCC Rep., Jeff Jones. 22:30 - 23:30 1.00 WHSUR P DECOMP Rig up DSM lubricator and pull BPV. 23:30 - 00:00 0.50 PULL P DECOMP Pump 20 bbls seawater to fill tubing. MU landing joint. 12/22/2004 00:00 - 01 :00 1.00 PULL P DECOMP Make up landing joint. Back out lock down screws. Pull hanger free. Tubing not free. Max pick up 140K. Rig up to circulate. 01 :00 - 03:30 2.50 PULL P DECOMP Displace well to 9.5 ppg brine at 3 bpm, 110 psi through GLM at 3,208'. Lost 110 bbls during displacement. Well static with pumps off. 03:30 - 04:30 1.00 PULL C DECOMP Rig up Schlumberger a-line. 04:30 - 05:00 0.50 PULL C DECOMP Schlumberger run in hole with 2.68" jet cutter. 05:00 - 06:00 1.00 PULL C DECOMP Cut tubing at 4,785' ELM. POOH. LD sheave, packoff and pump in sub. Install HT-40 XO. 06:00 - 06:30 0.50 PULL C DECOMP Make up TDS and pull tubing free with 150K indicated. Pull hanger to rig floor with 100K up weight. Well on light vacuum. Loss of 9 bbls in one hour. 06:30 - 07:30 1.00 PULL C DECOMP Rig down SWS, break control lines and chemical injection line. Break out and lay down hanger and landing joint. 07:30 - 08:30 1.00 PULL C DECOMP PJSM. Rig up control line spooling unit, power tongs and rig tongs. 08:30 - 18:30 10.00 PULL C DECOMP Lay down 4.5" and 3.5" tubing from 4,794' SLM. Up weight 85K and steady. Recovered: 70 jts 4.5" tubing 57 jts 3.5" tubing 1 - 3.5" tubing cut off joint - 16.63' 1 SSSV 1 GLM 127 clamps (All accounted for) 7 SS bands. Note: Scaly deposit coating tubing from 3,746' to 4,431'. 18:30 - 20:00 1.50 BOPSURC DECOMP Rig up 4" test joint and test BOP's (upper and lower rams, Annular) to 250 psi low - 3,500 psi high. Pull test plug and install wear bushing. 20:00 - 21 :30 1.50 CLEAN C DECOMP Make up cleanout BHA. 21 :30 - 00:00 2.50 CLEAN C DECOMP Pick up 4" drill pipe to 3,772'. 12/23/2004 00:00 - 01 :30 1.50 CLEAN C DECOMP Continue picking up drill pipe for clean out run to 4,630'. PU weight = 120K, SO weight = 115K. Began taking weight, set down 40K over normal. Made up TDS and washed down single without difficulty. Well back flowing through drill pipe. 01 :30 - 02:30 1.00 CLEAN C DECOMP Circulate hole volume at 4,703'. 9.4 ppg brine, 300 gpm, 500 psi. At bottoms up saw sand and scale. Max fluid weight returned was 10.4 ppg. 02:30 - 03:00 0.50 CLEAN C DECOMP Rack back one stand in derrick and pick up last 3 singles of drill pipe. Wash down stand from derrick and tag tubing stump at 4,799' DPM. 03:00 - 04:00 1.00 CLEAN C DECOMP Circulate hi vis sweep surface to surface at 546 gpm , 1400 psi. Printed: 1/1012005 9:23:36 AM ') ) BP EXPLORATION Operations Summary Report)::r'_f:' I ¡",,,,L.J Page 3 418 05-20 05-20 REENTER+COMPLETE Start: 12/19/2004- NABORS ALASKA DRILLING I Rig Release: 1/7/2005 NABORS 2ES Rig Number: From - To I Hours Task Code NPT Phase 04:00 - 05:30 1.50 CLEAN C DECOMP 05:30 - 07:00 1.50 CLEAN C DECOMP 07:00 - 07:30 0.50 CLEAN C DECOMP 07:30 - 09:00 1.50 DHB C DECOMP 09:00 - 12:00 3.00 DHB C DECOMP 12:00 - 12:30 0.50 DHB C DECOMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/23/2004 12:30 - 15:00 C DECOMP 2.50 DHB 15:00 - 17:00 2.00 I DHB C DECOMP 17:00 - 18:00 1.00 DHB C DECOMP 18:00 - 19:00 1.00 DHB C DECOMP 19:00 - 21 :00 2.00 DHB C DECOMP 21 :00 - 22:00 1.00 DHB C DECOMP 22:00 - 23:00 1.00 CLEAN C DECOMP 23:00 - 00:00 1.00 CLEAN C DECOMP 12/24/2004 00:00 - 01 :00 1.00 CLEAN C DECOMP 01 :00 - 01 :30 0.50 CLEAN C DECOMP 01 :30 - 04:00 2.50 WHI P C WEXIT 04:00 - 07:30 3.50 WHIP C WEXIT 07:30 - 11 :30 4.00 WHIP C WEXIT 11 :30 - 12:00 0.50 WHIP C WEXIT 12:00 - 18:00 6.00 STWHIP C WEXIT 18:00 - 19:00 1.00 STWHIP C WEXIT 19:00 - 19:30 0.50 EV AL C WEXIT 19:30 - 21 :00 1.50 STWHIP C WEXIT 21 :00 - 23:00 2.00 STWHIP C WEXIT Spud Date: 3/26/1991 End: 1/7/2005 Description of Operations Slip and cut drilling line. Service TDS. POOH with clean out assy to 316'. Lay down jars, stand back DC's, laydown bit, mill, and bit sub. Pick up and make up RTTS BHA assembly to 295' RIH picking up drill pipe from 295' to 4,684'. Tag top of tubing stump at 4,799'. Break circulation. Set RTTS at 4,788'. Test casing to 3,500 psi for 30 minutes (good test). Bleed off pressure and attempt to establish injection rates. Pressured up to 3,000 psi and held, no injection noted. Release RTTS and pick up to 4,730'. Set RTTS and test casing to 3,500 psi for 10 minutes (good test). Attempt to establish injection rates without success, pressure built up to 3,000 psi and held. Release RTTS, pump dry job, blow down surface equipment. POOH with RTTS from 4,730' to 294'. Lay down BHA from 294'. Lay down RTTS. Make up EZSV BHA to 657'. RIH from 657' to 4,730'. PU Weight = 115K SO weight = 118K Set EZSV. Sheared off with 47K overpull. Set down 20K to test set. Tested 9-5/8" casing to 3,500 psi for 30 minutes (good test). Pump 45 bbl hi vis sweep. Displace well to 9.8 ppg LSND milling fluid. 365 gpm, 595 psi. PU weight = 115K - SO weight = 115K. POOH from 4,730' to 2,709'. POOH from 2,709' to 654' Stand back HWDP. Break off and lay down EZSV running tool. Pick up and make up whipstock / milling assembly to 1,006'. RIH with whipstock / milling assembly on 4" drill pipe. 1.5 minutes per stand running time. Tag EZSV at 4,730'. PU 140K SO 140K Rig up Gyro equipment and RIH with same on e-line. Orient tool face at 215 degrees azimuth. POOH with e-line and rig down Gyro equipment. Tag EZSV at 4,730'. Set bottom trip anchor with 25K down weight. Pick up 10K above neutral weight to verify whipstock set. Shear lugs with 45K down weight. Top of window at 4,706'. Mill window in 9-5/8" casing and 24' new hole from 4,706' to 4,738'. WOB 7/10 TQ 3/10 RPM 115 400 GPM 750 PSI. Recovered approximately 200 pounds of metal during miling operations. Top of window at 4,706 Bottom of window at 4,722' Undergauge hole drilled to 4,738' Pump sweep while reciprocating through window. PU 130K SO 135K RT 135K. Take SPR's. Perform FIT with 9.8 ppg LSND mud to 369 psi / 11.3 ppg EMW (good test). POOH from 4,738' to 982'. Stand back HWDP and DC's. Lay down UBHO, bumper sub Printed: 1/10/2005 9:23:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) Page 4 .. From - To Hours Task Code NPT Phase 12/24/2004 21 :00 - 23:00 23:00 - 00:00 12/25/2004 00:00 - 00:30 00:30 - 01 :30 01 :30 - 05:00 05:00 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 12:00 12:00 - 14:00 14:00 - 17:00 17:00 - 18:30 18:30 - 20:30 20:30 - 23:30 23:30 - 00:00 12/2612004 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 12:00 12:00 - 14:30 14:30 - 16:00 16:00 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 00:00 12/27/2004 00:00 - 22:30 BP EXPLORATION Operations Summary Report 05-20 05-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 2.00 STWHIP C WEXIT 1.00 STWHIP C WEXIT 0.50 STWHIP C 1.00 STWHIP C 3.50 STWHIP C WEXIT WEXIT WEXIT 1.50 STWHIP C 1.00 STWHIP C 1.00 STWHIP C 3.50 STWHIP C WEXIT WEXIT WEXIT WEXIT 2.00 STWHIP X 3.00 STWHIP X 1.50 STWHIP X SFAL WEXIT SFAL WEXIT SFAL WEXIT 2.00 DRILL C INT1 3.00 DRILL C INT1 0.50 DRILL C INT1 2.50 DRILL C 0.50 DRILL C 0.50 DRILL C 8.50 DRILL C INT1 INT1 INT1 INT1 2.50 DRILL X 1.50 DRILL X WAIT INT1 WAIT INT1 4.50 DRILL X WAIT INT1 1.00 DRILL X 0.50 DRILL X 2.00 DRILL C C INT1 1.50 DRILL C INT1 2.00 DRILL C INT1 Start: 12/19/2004 Rig Release: 1/7/2005 Rig Number: . SpOdDate: 3/26/1991 End: 1/7/2005 Description of Operations and mills. Note: Upper mill full gauge. Clean out under rotary table. Change out elevators. Pick up test joint and pull wear bushing. PJSM. Flush BOP stack. Lay down flush tool. Install wear bushing. Make up 8.5- directional drilling assembly to 1,172'. Orient, initialize and shallow test MWD. Rt H with drilling assembly from 1,172' to 4,628'. Service Drawworks and TDS. Rig up Sperry Sun E-line, Gyrodata and side door entry sub RIH with Gyro tool made 3 sets. Loss of E-Line power and signal. Wire pinched at side entry sub when tighting pack off. POOH with E-Line and rig down Sperry Sun E-Line unit. PJSM. Rig up SWS E-line, Gyrodata and side door entry sub. RIH with Gryo. Check shot at 2,500'. Latch in and orient to 240 degrees right and pass through window to 4,726'. Wash undergauge hole from 4,726' to 4,738'. Gyro toolface erratic. Pull back to 4,628' and re-seat tool. RIH to 4,738'. Slidedrillfrom4,738't04,911'. 512 GPM, 1,790 PSI. UPWT = 150K, DN WT = 150K. AST = 2.07 Blow down TDS and POOH from 4,911' to 4,628'. PO E-Line. POOH with gyro and rig down same. RIH from 4,628' to 4,814' Ream from 4,814' to 4,911' Directional drill and survey with M -GR-DDS-PWD from 4,911' to 5468' wI 545 gpm , 0 psi, 70 rpm, 6-10 k wob, ART 3.8 hours, AST 3.8 rs Phase 3 weathe onditions Circ Hole CI n at 210 spm 1550 psi Monitor II, Slugged pipe, POH inside 9 5/8" window, LD 27 Jts 468' - 4628' OW Phase 3 weather conditions, Monitor well, circ across top of well wI hole fill RIH picking up 27 jts DP from 4,628' to 5,468'. No fill encountered. Circulate bottoms up at 550 gpm, 2,300 psi. Directional drill and survey with MWD-GR-DDS-PWD from 5,488' to 5,640' wI 550 gpm ,2300 psi, 70 rpm, 3-10 k wob, ART .97 hours, AST 0.0 hours Phase 2 weather conditions Directional drill and survey with MWD-GR-DDS-PWD from 5,640' to 7,550' wI 569 gpm , 3250 psi, 100 rpm, 10 k wob, ART 11.18 hours, AST 2.54 hours. Pump sweep around at 569 gpm, 3200 psi. Prepare for short trip. POOH from 7,550' to 5,468'. Max overpull25K. Hole in good shape. Run back to bottom. Precautionary wash last stand. No fill noted. Printed: 1/10/2005 9:23:36 AM RE: [Fwd: 05-20B Update to the current Sundry and Permit to Drill] ) ) Subject: RE: [Fwd: 05-20B Update to the current Sundry and Permit to Drill] From: "Allen, Kenneth W (SSDS)" <AllenKW@BP.com> Date: Wed, 22 Dec 2004 15:38:20 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: James Regg <jimJegg@admin.state.ak.us> ",~y'Î"- n c¡ Tom, Thanks for the quick review of these changes. Attached is an updated sheet including all the Production information along with the 4-1/2" cementing information you requested. Thanks again guys! Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allenkw@bp.con1 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, December 22, 2004 2:48 PM To: Allen, Kenneth W (SSDS) Cc: James Regg Subject: Re: [Fwd: 05-20B Update to the current Sundry and Permit to Drill] Ken, This acknowledges our conversation of a little while ago. I am. reviewing the proposed changes to the abandonment ofDS 5-20A and the sidetrack DS 5-20B. As decompletion work has proceeded according to sundry 304-410, problems have been encountered. It has not been possible to pull the tubing as planned due to fill in the tubing x casing annulus. The tubing was successfully jet cut at about 4800' and the rig is presently laying it down. You are proposing to not attempt further fishing and P&A the DS 5-20A wellbore by setting a retainer at about 4730' and squeezing sufficient cement to effectively plug all the open tubulars. Your proposal to revise the P&A is acceptable. P &Aing the well at the shallower depth has resulting in a modification to the intended drilling plan. You will now be setting a fully cemented drilling liner between the window and the top of the Sag and then setting a fully cemented 4-1/2" production liner to TD. In the information you provided for the revision ofDS 5-20B, you did not include the 4-1/2" liner cementing information. It would be appreciated if you would respond to this message and send that information. Regardless, the plan you have submitted to revise the sidetrack is acceptable and you may proceed as planned. One thing you should note is that the well name and numbering information on the drawing for the "new" well is still listed as 5-20A. That information should be changed to 5-20B, with revision of the permit and API numbers as appropriate. Please call or message with any questions. Tom Maunder, PE AOGCC James Regg wrote: SCANNED DEC 2 2 2004 10f2 12/22/20043:57 PM RE: [Fwd: 05-20B Update to the current Sundry and Permit to Drill] ) ) I ask him to send changes in lieu of resubmitting a new sundry since work had not yet started and none of objectives change; they are kicking off shallower than was stated in approved sundry. Jim ---- ---- Original Message -------- Subject: 05-20B Update to the current Sundry and Permit to Drill Date: Wed, 22 Dec 2004 12:02:16 -0900 Prom: Allen, Kenneth W (SSDS) <AllenKW@JBP.coln> To: jinl rcgg(ã}adn1in.statc.ak.us Jim, Attached is the updated information for the Sundry P&A work and also the new information for a shallow kickoff and running 7" liner. Peel free to give me a shout on my cell phone if you have any questions. Please let me know if you are okay with all the operations. We are currently laying down tubing from ajet cut at 4,785'md. We should finish laying that down this afternoon. If you are OK with the updated P&A procedures we could be into the gauge ring runs and 9-5/8" testing by this evenIng. Thanks for the help and sorry to ao this to you on such short notice. Although, I guess we are somewhat lucky as we'll get this straightened out before the holidays. 1* !Ken Allen/* 1 IIOperations Drilling Engineerll Mobile: 907.748.3907 Office: 907.564.4366 e-mail: aHcnkw@?bp.com<mailto:allenk\v(á}bp.com> Updated information for Content-Description: production section of shallow KO plan.ZIP Content-Type: app1ication/x-zip-compressed Content-Encoding: base64 information for production section of shallow KO 20f2 12/22/20043:57 PM bp ) ) To: Jim Regg -AOGCC Date: December 21, 2004 From: Ken Allen - BPXA GPB Rotary Drilling Subject: Reference: 05-20A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22137-01 Approval is requested for the proposed P&A of PBU well 05-20A. Nabors 2ES is currently performing the previously approved work outlined in Sundry number 304-410. The decompletion phase has run into some problems. The IA is packed off somewhere between 5201'md and 3208'md. The pack off is mostly likely near the GLM at 5201 'md. The increased risk associated with successfully recovering the completion down to the original kick off point, along with the unknown 9-5/8" integrity, have led to the decision to abandon fishing attempts and sidetrack shallow. The well will be P&A'd as detailed in the outline below. The 05-20A P&A and 05-20B sidetrack will commence once the Sundry approval has been received. \ Ria Operations: ~ 1. Mil RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection "and displace the well to brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. - 4. RlU e-line and jet cut 3 %" tubing -4,800'md. RID e-line. \...o.""f\"'~ ~~~\p~ ~\ "CJC \';;)/;r;) 5. Pull the 4%" X 3 %" tubing from the jet cut at -4,785'md and above. Be prepared to spool up the Bal-O SSSV control lines and the Chemical Injection line. The CI mandrel is at 8,207'md. Determine at what depth the Clline parted. 6. M/U spear assy. Make a spear run (picking up 4" DP) to fish control line if needed. POOH. 7. M/U 8.5" gauge milling assy. RIH picking up 4" DP from pipe shed (if not previously picked up) and drift 9-5/8" 47# casing. POOH. 8. M/U 9-5/8" RTTS. RIH to the top of the tubing stub, set and test 9-5/8" casing to 3500 psi from above. If test passes move on to the next stop of setting a 9-5/8" EZSV. If test fails pull up hole testing to find leak location. 9. M/U a 9-5/8" EZSV and mechanical setting tool. RIH and set -4,730'. Unsting from EZSV and pressure test 9-5/8" casing and EZSV to 3500 psi for 30 minutes. Record the test. Sting into the 9-5/8" EZSV and P&A 05-20A perforations by bull heading with 61 BBLS of 15.8ppg cement. a. Cement Calculations include the following:/ i. 90' of 9-5/8" casing = -6.6 BBLS 0/ ii. 4341' of 3-1/2" TBG = -38 BBLS iii. 1658' of 2-3/8" TBG = -6.4 BBLS ,/ iv. Squeeze volume = -10 BBLS v. Total volume to P&A is 61 BBLS 10. M/U a Baker 9-5/8" whip stock assembly with UBHO sub for gyro orientation. RIH to EZSV. RlU e-line and gyro tools. Orient as desired and set the whip stock on the EZSV. 11. Shear free from the whip stock. Displace the well to 9.8ppg LSND drilling fluid. Verify that the mud ~. ß weight is at least 9.8ppg prior to cutting the window. S'c:}--" 12. Mill a window in the 9-5/8" casing at -4,710'md. Drill/mill approximately 20 feet beyond the middle of the window. Circulate the well clean. Pull into the 9-5/8" casing and conduct an FIT to 11.3ppg EMW. POOH. ' 13. MU the 8-1/2" drilling assembly with DIR/GR/DDS/PWD and RIH. Kick off and drill 8-1/2" intermediate interval as per directional plan. ~ - ,j:) ~ ? 05-20A Application for Sundry - Version 2.0 ) ) 14. Drill ahead weighting up to 10.3ppg by the top of the HRZ at -8300'md. Continue drilling to the 7" casing point C!t Top ~ag River to an estimated depth of 8,654'md. 15. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to 4,560' MD. Set hanger / liner tQtLpacker and displace cement with mud. POOH. '--r 16. M/U a 6-1/8" DIR/GR/RES/ABI drilling assembly. RIH to landing collar. 17. Pressure test wellbore to 3500 psi for 30 minutes. 18. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0ppg. 19. Drill ahead, per directional proposal, to planned TD of -11 ,590'md. ,f 20. Condition the hole for running 4 1/2", 12.6#, L-80, IBT-M liner. 21. Run and cement the 4 %" production liner, extending the liner lap to -8,504'md. POOH. 22. P/U and RIH with Schlumberger 2 %" DPC perforating guns. Perforate approximately 1,000' of Z1A/1 B interval, per subsurface team. POOH. 23. R/U and run a 4 1/2", 12.6#, L-80, IBT-M completion, stinging into the 4 1/2" liner tie back sleeve. 24. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 25. Install a TWC. 26. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 27. Freeze protect the well to -2,200'. Install BPV. Secure the well. 28. Rig down and move off. Post-Ria Operations: 1. MI / RU slick line. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: Completed Estimated Spud Date: Currently on well with Nabors 2ES Ken Allen Operations Drilling Engineer 564-4366 05-20A Application for Sundry - Version 2.0 FMC GEN 4 FMS OTIS ~ 71'¡ 34.1 ' TREE == WELLHEAD == A CTUA TOR ::: ."...,.,...,..w.w,~~ KB. ELEV ::: >------- --_._-~--_._----- - -._--- "---- ..--- IVIax Angle::::: 95 @ 10078' bàtÙmtv1D-;--' ,.. 9244'¡ ." H .-"...- H"'."..'...'''.'''.''.''.'¡ Datum ND :::: 8800' 55! 13-3/8",68.0#, l-80, - casing ID::: 12.415" 3512' Collapsed Tubing -: (06/13102 VIDEO) 5424' I TOP OF 7" LNR I-{ 8292' , 9-5/8",47.0#, L-80, ¡- casing ID::: 8.681" 8620' .. Minimum ID =1.85" @ 91451 2..3/S" CASING JOINTS [Top of 2 3/8" Liner 1-1 9141' 3 1/2", 9.3#, l-80, ....; tubing, ID = 2.992" 9265' ¡Top of 41/2" liner 1-1 9265' 7",29#, L-80, liner, - ID = 6.184" 9790' 4 1/2", 12.6#, L-80, - liner, 10 = 3.953" \ 10385' DATE 1991 07/08/98 : 02127/02 . 06/18/02 .. 08/18/03 10/27/04 COMMENTS ORIGINAL COM PlEnON SIDETRACKED RNfTP CORRECTIONS JrvVTP COLLAPSED TBG CIV10/TLP PERF ANGLE CORRECTION dew Pre rig condition REV BY 05-~DA P&A ) SAFETY NOTES: MAY NEED TO LIMIT INNER ANNULUS TESTING & OP PRESSURES. LNR DIDN'T PT TO 2000# {LOST 500# IN 30 MIN-ON 07/08/98 HO. 3-1/2" OTIS X NIP @ 9156' MILLED W/2.81 " MILL DRL'DTHRU PACK- Off BUSHING 07/31/93. 70° @ 9507' AND 90° @ 9747' ~ - 4730' - 9-5/8" HES EZSV ;?10 " '=\ \' \;L. ~\:Y£èJ Ö-";.Oo-T 7d(}-à~ ~ I GAS UFT MANDRELS . ST MD. TVD DEV TYPE VLV LATCH PORT DATE , 1 3208; 3208 i 0 TGPB TG 2 . 5201 5201 0 TGPB TG 3 6313 6313 0 TGPB TG 4 6902 i 6900 11 TGPB TG I ~. . 5 7430 7406 21 TGPB TG . 6 7803 7742 27 TGPB . TG I .., 7 8114 8021 26 TGPB !, TG CHEMICAL MANDRELS : .. .lsTI MOl TVDI DEVI. TYÆ l.vLvl LATCH 1 PORT..I DATE..I 1 8207 8104 26 MMG-7-L TS RK I /1 ~I ~/ 9141' 1-12-3/8" DEPLOYMENT 5LV, iD = 1.969" I 9156' 1-{3-1/2" OTIS XN NIP, 10 = 2.81" (BEHIND LNR) I 9244' 1-1 3~1/2" TIW OVERSHOT SEAL A5SY (BEHIND LNR) I 9255' 1-17" X 3-1/2" TIW 55 HYDRO SET PKR (BEHIND LNR) I - 10 BBL5 squeezed into perf's ÆRFORA TION SUMMARY REF LOG: I'v1WD GR ON 07/05/98 ANGLEAT TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL . Opn/Sqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 .~. : :,¡,. ~. 'f.~,~ I 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' I 2-3/8" LNR, 4.6#, L-80, ,00387 bpf, 10::: 1.995" 10799' ~ DATE REV BY J CŒv1MENTS PRUDHOE BAY UNIT WELL: 05-20A ÆRMIT No: 1971790 APJ No: 50-029-22137-01 SEe 32, T11N, R15E 3938.91' FEL & 5050.68' FNL BP Exploration {Alaska} . ' ) ) ~:~uŒ (Q~ &\~ ~~«~ / AI1ASIiA. OIL AlWD GAS / CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 i~C}J q "."'",..',.."'1,'."',,.,,,,",:,"¡¡?" ".,.j"""'"/,, ~""" ',"" ',',,' " , " t.,.' \0 :~:", ,~ . , Re: Prudhoe Bay 05-20A Sundry Number: 304-410 Dear Mr. Isaacson: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requeste . ~ . Norman Chairman BY ORDER OF .JjIE COMMISSION DATED this~ day of November, 2004 Enel. SCANNED NOV 0 8 2004 \¡JGA- i ¡ (1/ 2C<J 4- ') STATE OF ALASKA) I:;~ ~"~,. E:¡C~\l""":,~ ALASKA OIL AND GAS CONSERVATION COMMISSION }/ 1~2oo4 APPLICATION FOR SUNDRY APPROVAL i 20 MC 25.280 1. Type of Request: II Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 71' 4. Current Well Class: / a Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 197-179/ 6. API Number: / 50- 029-22137-01-00 99519-6612 9. Well Name and Number: PBU 05.20A / 10. Field / Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Pool , " """" ,PRfF$SNTWþll.,C()NQrrI9N$QMM~R~""",'; Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): 9027 10765 9028 None Length Size MD TVD Burst 8. Property Designation: 11. ' Total Depth MD (ft): 10800 Casing Structural Conductor Surface Intermediate Production Liner Junk (measured): None Collapse Liner Liner 115' 20" 115' 115' 1490 470 3512' 13-3/8" 3512' 3512' 4930 2270 8621' 9-5/8" 8621' 8454' 6870 4760 1032' 7" 8291' - 9323' 8179' - 8909' 8160 7020 57' 4-1/2" 9265' - 9322' 8881' - 8908' 8430 7500 1659' 2-3/8" 9141' - 10800' 8817' - 9027' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9673' - 10760' 9021' - 9028' 4-1/2", 12.6# x 3-1/2",9.3# Packers and SSSV Type: 7" x 3-1/2" TIW 'SS' Hydro Set packer; 4-1/2" Camco 'Bal-O' SSSV Nipple Tubing Grade: L-80 Packers and SSSV MD (ft): 9255' 1976' Tubing MD (ft): 9265' 12. Attachments: 181 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Signature [}.J.v t \ ~ . . Phone 564-5521 Date II " /0 'i Commission Use Only D BOP Sketch 13. Well Class after proposed work: / D Exploratory 181 Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ 181 Abandoned D WDSPL November 15, 2004 Date: Contact Dave Wesley, 564-5153 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 30,/.. ~Ò D Plug Integrity 0 BOP Test D Mechanical Integrity Test D Location Clearance Ot~£ S (- Bo~E to sSOo p ~¿ d' () " 1_-1" /.ARl"1 OC-2ÞGY\NNED NOV 0 82004 Ap p j~ \led I 0 .- 4 0 l \f"'€ ~ L.U 'v t--<Y ¡r ~ t ClR tYv-tIL (", ..) . COMMISSIONER APPROVED BY THE COMMISSION Date i~~Plicate "- ORIGINAL RBDMS 8FL NOV - 8 2004 bp ) ) 0 To: Winton Aubert - AOGCC Date: November 04, 2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: Reference: 05-20A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22137-01 Approval is requested for the proposed P&A of PBU well 05-20A. This well is currently shut-in, awaiting /" the proposed rig sidetrack. A new horizontal well bore into Z1 is planned. The planned kick-off point is below the conglomerate, into upper Zone 2. This kick-off point is immediately above the existing Z1 horizontal well bore, 05-20A. Isolation from the existing well is not required for ,/ reservoir management reasons; therefore, it is not planned to plug and abandon the perforations with cement. Alternatively, the well will be isolated with a bridge plug, once de-completed. The integrity of the bridge plug will be confirmed with a pressure test. Once the proposed 5-20B well path has been dri~, a 4 %" liner will be run and fully cemented into the liner lap. The 05-20B sidetrack is scheduled for Nabors 2ES. Current estimates have it beginning around ~ November 28, 2004, following the completion of the 05-24A. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Ria Operations: 1. The 3 %",9.2#, L-80 tubing is collapsedlparted at 5,424'md, based upon a video log run 8/21/2002. 2. Currently, it is not possible to conduct an MIT-IA with the parted tubing and with open perforations. /' 3. MIT-OA passed to 2,OOOpsi on 10/25/2004. 4. A PPPOT-IC passed to 3,100psi, and a PPPOT-T passed to 5,OOOpsi on 10108/2004. All LDS functioned and were re-torqued to 450 ft-Ibs. 5. Circulate the well to brine, as necessary to balance, by bull heading down the tubing to the open perforations. Attempt to circulate through the tubing part, taking returns up the IA. Reverse-circulate from the IA to the tubing to confirm the IA is clear. Freeze protect to -2,200' MD with diesel. /' 6. Bleed casing and annulus pressures to zero. 7. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. MI 1 RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. RIU. Pull the 4%" X 3 %" tubing from the collapse 1 part at -5,424'md and above. Be prepared to spool up the Bal-O SSSV control lines and the Chemical Injection line. The CI mandrel is at 8,207'md. Determine at what depth the Clline parted. 5. M/U a Baker overshot 1 dressing assembly, with -100 feet of wash over pipe. RIH, wash over down to the tubing stub. Dress the tubing stub in preparation for the outside cutter. POOH. / 05-20A Application for Sundry ') ) ^ 6. M/U Baker overshot I outside cutter assembly. RIH to 3 Y2" tubing stub. Make an outside cut on the 3 Y2" tubing below the point of collapse/part. POOH with fish. 7. M/U an overshot, with a grapple dressed for the 3 Y2" tubing. RIH and overshot I engage the tubing stub. 8. RlU SWS E-line. RIH with the 2 3/8" chemical cutter or jet cutter. Confirm all drill pipe and assembly components will allow passage of the tubing cutter. Cut the 3 Y2" tubing at -9,125'md. POH and RID E-line. /' 9. POOH and LID the remaining 3 Y2" tubing. Spool up the remaining chemical injection line. 10. RlU E-line. RIH with a full gauge GRlJB for the 7",29.0#, L-80 liner. Tag the tubing stub at 9,125'. POOH. 11. Alternatively, M/U a milling assembly and RIH while P/U 4" drill pipe. Tag the tubing stub. POOH. 12. M/U a HES 7" EZSV bridge plug. RIH with the EZSV, on E-line, and set at -9,070'md. POOH and RID E-line. 13. Attempt to pressure test the 7" liner X 9 5/8" casing to 3,500psi for 30 minutes. Record the test. 14. If the pressure test fails, prepare to P/U a 9 5/8" RTTS to locate the leak point. A contingency plan to run a 7" scab liner is in place, should the casil1g fail the pressure test. Otherwise, continue with the plan to RIH with the whip stock.TlvL S l Ð ~ 40'"5 o-1lprotl'^-l. 15. M/U a Baker 7" whip stock assembly. RIH to EZSV retainer. Orient as desired and set the whip stock on the EZSV. 16. Shear free from the whip stock. Displace the well to 8.5ppg Flo-Pro drilling fluid. 17. Mill a window in the 7" liner at -9,050'md. Drilllmill approximately 20 feet beyond the middle of the window. 18. Circulate the well clean. Pull into the 7" liner and conduct an FIT to 10.0ppg EMW. POOH. 19. M/U a 6" Dir/GRlRes/ABI drilling assembly. RIH to the window. 20. Drill ahead, per directional proposal, to planned TD of -12,075'md. 21. Condition hole for running 4 1/2", 12.6#, L-80, IBT-M liner. 22. Run and cement the 4 Y2" production liner, extending the liner lap to -8,900'md. POOH. 23. P/U and RIH with Schlumberger 2 Y2" DPC perforating guns. Perforate approximately 1,000' of Z1A11B interval, per subsurface team. POOH. 24. RlU and run a 4 1/2", 12.6#, L-80, IBT-M completion, stinging into the 4 1/2" liner tie back sleeve. 25. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 26. Install a TWC. 27. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 28. Freeze protect the well to -2,200'. Install BPV. Secure the well. 29. Rig down and move off. /~ /' Post-Ria Operations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 11/15/04 Estimated Spud Date: 12/10/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 05-20A Application for Sundry 05-20A >re Rig 4-112",12.6#, l-80, - tubing, ID = 3.958" 2978' --- I \ l TOP OF 3-1/2" TBG 1-1 2978' 13-3/8",68.0#, L-80, - 3512' casing ID = 12.415" L Collapsed Tubing - (06/13/02 VIDEO) ~ 5424' ') FMC GEN 4 FMC " OTis 71' 34.1 6936' .<........ .n.... ............ 95 @ 10078' ''''"....,......m,u........ .m........ ..., 9244' ............. . ~,... .. .. 8800' SS TREE = WB...LHEA D = . .. ..' .. ><, ....a.....,,,,,,.. .."..... '"'' ACTUATOR = Rs. REV = ....... ,,,..,.. . . . '"au,,,,,,,, CB. B...EV = KOF>';'.. ...... Max. A ngïeU;; "'''''''''''''......"......"..""""",,,, Datum MD = . DatÙiñiVb;'" ... 1976' 1-141/2" CAMCO BAL-O SSSV NIP, ID = 3.813" 1 2978' 1-14-1/2" X 3-1/2" XO 1 GAS LIFT MANDRB...S DEV TYPE VL V LATCH PORT DA TE 0 TGPS TG 0 TGPS TG 0 TGPS TG 11 TGPS TG 21 TGPS TG 27 TGPS TG 26 TGPS TG CHEMICAL MANDRB...S 1ST MD TVD I' DEV TYPE IVLV LATCH I" PORT DATE 1 8207 8104 26 MMG-7-L TS RK ST MD. TVD 1 3208 3208 2 5201 5201 3 63136313 4 6902 6900 5 7430 7406 6 7803,7742 7 8114 8021 c¡:~ I TOP OF 7" LNR I' :I 1-1 8292' 9-5/8",47.0#, L-80, - casing ID = 8.681" 8620' Minimum ID =1.85" @ 9145' 2-3/8" CAS IN G JOINTS /1 H/' ~~: Top of 23/8" liner 1-1 9141' 31/2",9.3#, L-80, tubing, ID = 2.992" 9265' TOP of 4 1/2" liner 1-1 9265' 7",29#, L-80, liner, - ID = 6.184" 9790' 41/2",12.6#, L-80, - 10385' liner, ID = 3.953" DATE REV BY COMMENTS 1991 ORIGINAL COMPLETION 07/08/98 SIDETRACKED 02/2.7/02 L.-2QN/TP CO~T1ONS -. - 06/18/02 JrvvTP COLLAPSED TBG 08/18/03 CMQITLP PffiF ANGLE CORRECTION 10/27/04 dew Pre rig condition SAFETY NOTES: MAY NEED TO LIMIT INNER ANNULUS TESTING & OP PRESSURES. LNR DIDN'T PT TO 2000# (LOST 500# IN 30 MIN~ON 07/08/98 HO. 3.1/2" OTIS X. NIP @ 9156' MILLEDW/2.81" MILL DRL'D THRU PACK. OFFBUSHING07/31/93. 70° @ 9507' AND 90° @ 9747' 9141' 1--12-3/8" DEPLOYMENT SLV, ID = 1.969" 1 9156' 1-13-1/2" OTIS XN NIP, ID = 2.81" (BEHIND LNR) 1 9244' 1-13-1/2" TIW OVERSHOT SEAL ASSY (BB-IIND LNR) 1 9255' 1-1 7" X 3-1/2" TIW SS HY DRO SET PKR (BB-IIND LNR) 1 PffiFORA TION SUMMARY REF LOG: MIND GR ON 07/05/98 ANGLE AT TOP PffiF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' 2-3/8" LNR, 4.6#, L-80, .00387 bpf, ID = 1.995" 10799' DA TE REV BY --!-- COMMENTS PRUDHOE BAY UNrr WB...L: 05-20A ÆRMrr No: 1971790 .^ P, N.J: 50-029-22137-()1 - ~2, T11N, R1S'E, 3938.91' Fa. & 5050.68' FNL ' BP Exploration (Alaska) '05~20A Dec<,lnpletion phasb'1 4-112", 12.6#, L-BO, - tubing, 10 = 3.95B" 2978' 13-3/8",68.0#, L-80, - 3512' casing Ð = 12.415" Collapsed Tubing (06/13/02 VIDEO) ~ -'\)/' 5424' -¡: -¡: -¡: C L I TOP OF 7" LNR 1-1 8292' I . 9-5/8",47.0#, L-BO, - casing Ð = B.681" 8620' Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS /1 H/1 ~.~: TOp of 23/8" Liner 1-1 9141' 31/2",9.3#, L-80, tubing, 10 = 2.992" 9265' Top of 4 1/2" liner Ii 9265' 7", 29#, L-BO, liner, - 10 = 6.184" 9790' TREE = WB-LHEAD = AcruÄiÖR; '" 'KEf'ELêl^;''' ,www", , ..... ."..,...~ ",U<H.M"«<n,,,.. CB. B-EV = KOP= Max'Ängie;' , .."...,......,"',."...,......................,. Datum MD = Öaiunïi\ïÖ ~ m FMC GEN 4 FMC "'OtiS 71' 34.1 "'6936' "95@10Öiã" ......................................... 9244' '8ãoOïSS I PUn 4 1/2" X 3 1/2" tubing from part at 5,424' I GAS LIFT MANDRELS ST MD lVD DEV lYÆ VLV LATCH PORT DATE 3 63136313 4 6902, 6900 5 7430 7406 6 7803 7742 7 8114 8021 ST MD lVD 1 8207 8104 0 TGPB TG 11 TGPB TG 21 TGPB TG 27 TGPB TG 26 TGPB TG CHEMICAL MANDRELS DEV lYÆVLV LATCH PORTI DATE 26 MMG-7 -L TS RK 9141' 1-12-3/8" DEPLOYMENTSLV, 10= 1.969" I 9156' 1-13-1/2" OTIS XN NIP, 10 = 2.81" (BEHIND LNR) 1 9244' 1-13-1/2" Trw OVERSHOT SEAL ASSY (BEHIND LNR) I 9255' 1--i7" x 3-1/2" Trw SS HYDRO SET PKR (BEHIND LNR) I ÆRFORA TION SUMMARY REF LOG: MWD GR ON 07/05/98 ANGLE A T TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 7" X 4-1/2" MILLOLJT WINDOW - 9323' - 9331' 10799' 41/2",12.6#, L-80, - 10385' liner, 10 = 3.953" DATE 1991 07/08/98 0?l'}7'02 06/18/02 08/18/03 10/27/04 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACKED RN/TP CORRFCTIONS , JlWfP COLLAPSED TBG CMOITLP ÆRF ANGLE CORRECTION dew Decompletion 1 DA TE REV BY COMMENTS 2-3/8" LNR, 4.6#, L-80, .00387 bpf, 10 = 1.995" PRUDHOE BA Y UNff WELL: 05-20A ÆRMff No: 1971790 API No: 50-029-22137-01 ' SEC 32, T11 N, R15E, 3938:9'FFEL & 5050-.68' FNL BP Exploration (Alaska) '05~20A Dec<,}npletion phas& ~ TREE = WB...LHEAD = AcruÄfóïr;"o" ,., KEf'ELsr;"" '^"""m.w 'CS:"ELEV";""" ,KOP;" www Max'Angie;' , ..,........................................ Datum MD = oatumiVÖ;;; '. FMC GEN 4 FMC "ÖfíS" 71' 34.1 .m 6936' ., 9S'@1ööis' ...m........... .... .............. 9244' ............. ,...................' 8800' SS 4-1/2",12.6#, L-80, - 2978' tubing, ID = 3.958" 13-3/8",68.0#, l-80, - casing Ð = 12.415" 3512' ~ I Dress I outside cut the tubing stub damage. I '-<: 1--1 8292' GAS LIFT MANDRB...S ST MD lVD DEV TYÆ VLV LATCH PORT DATE :--¡: ---c 3 6313 6313 0 TGPB TG -¡: 4 6902.6900 11 TGPB TG 5 7430 7406 21 TGPB TG 6 7803 7742 27 TGPB TG C L 7 8114 8021 26 TGPB TG CHEMICAL MANDRB...S I STI MD lVD DEV TYÆ VLV LATCH PORT DATE I 1 8207 8104 26 MMG-7-L TS RK 1 TOP OF 7" LNR .I 9-5/8",47.0#, L-80, - casing ID = 8.681" 8620' Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS 9265' /1 J{/I ~ ~: 9141' 1--12-3/8" DEPLOYMENTSLV,ID= 1.969" 1 9156' 1--13-1/2" OTIS XN NIP, ID = 2.81" (BB-iIND LNR) 1 1 Top of 23/8" Liner 1--1 9141' 3 1/2",9.3#, L-80, tubing, ID = 2.992" 9244' 1--13-1/2" TIW OVERSHOT SEAL ASSY (BB-iIND LNR) 1 9255' 1--17" X 3-1/2" TIW SS HY DRO SET PKR (BB-iIND LNR) 1 ITop of 41/2" liner 1--1 9265' 9790' ÆRFORA TION SUMMARY REF LOG: MWD GR ON 07/05/98 ANGLE A T TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 7",29#, L-80, liner, - ID = 6.184" 7" X 4-1/2" MILLOlJT WINDOW - 9323' - 9331' 2-3/8" LNR, 4.6#, L-80, .00387 bpf, ID = 1.995" 10799' 41/2",12.6#, L-80, - 10385' liner, ID = 3.953" DATE REV BY COMMENTS 1991 ORIGINAL COMPLETION 07/08/98 SIDETRACKED 02127/02 RN/TP CORRECmN~ 06/18/02 JrwTP COLLAPSED l8G 08/18/03 CMOITLP ÆRF ANGLE CORRECTION 10/27/04 dew Decompletion 2 DA TE REV BY COMMENTS PRUDHOE BAY UNfT WB...L: 05-20A : ÆRMfT No: 1971790 : API No: 50-029-22137-01 I . SEC 32, T11 N, R15E, 3938.91' FEL & 50S0.68~ t BP Exploration (Alaska) '05.;20A Dec<.,Jnpletion phasE:~ 4-1/2", 12.6#, L-80, - tubing, ID = 3.958" 2978' TREE = FMC GEN 4 W8...LHEAD = FMC 'Ä'CfüÄTOïir;;"'''''''''''''''''''''''ofìS KB.ELE\1w;WW^"d"'" "'""'7'1'¡ cB"."ELèJ"; "3ïLf kÒF> = ' 6936' 'MåxAñglê ~ ",~~@:!.~~!.~,:: bätum'Ni6;'" 9244' oatÚmTVÖ;' "âäööïss 13-3/8",68.0#, L-80, - casing ID = 12.415" 3512' 1 TOP OF 7" LNR 1-1 8292' r--ç GAS LIFT MANDR8...S ST MD TVD DEV ìYÆ VLV LATCH PORT DATE :L --¡: 3 63136313 0 TGPB TG -¡: 4 6902 6900 11 TGPB TG 5 7430 7406 21 TGPB TG 6 7803 7742 27 TGPB TG C L 7 8114 8021 26 TGPB TG CHEMICAL MANDR8...S 1ST MD TVD DEV ìYÆ VLV LATCH PORT DATE . I ,. 1 8207 8104 26 MMG-7 -L TS RK 9-5/8",47.0#, L-80, - casing ID = 8.681" 8620' Minimum ID =1.85" @ 9145' 2..3/8" CASING JOINTS Overshot the tubing stub. RIH and chemical ~ cut the 3 1/2" tubing at -9,125' md. ::.~::: 9141' 1-12-3/8" DEPLOYMENTSLV, ID= 1.969" 1 Top of 2 3/8" Liner 1-1 9141' 31/2",9.3#, L-80, tubing, ID = 2.992" 9265' 9244' 1-13-1/2" TIW OVERSHOT SEAL ASSY (BB-IIND LNR) 1 9255' 1-17" X 3-1/2" TIW SS HYDRO SETPKR (BB-IIND LNR) I Top of 4 1/2" liner 1-1 9265' 9790' ÆRFORA TION SUMMARY REF LOG: MWD GR ON 07/05/98 ANGLEATTOPÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 7",29#, L-80, liner, - ID = 6.184" 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' 2-3/8" LNR, 4.6#, L-80, .00387 bpf, ID = 1.995" 10799' 41/2",12.6#, L-80, - 10385' liner, ID = 3.953" DA TE REV BY COMMENTS 1991 ORIGINAL COM PLETION 07/08/98 SIDETRACKB> 02/27/02 RNITP CORRECTIONS 06/18/02 JrvvTP COLLAPSED TBG 08/18/03 CMOfTLP ÆRF ANGLE CORRECTION 10/27/04 dew Decompletion 3 DA TE REV BY COMMENTS PRUDHOE BA Y UNIT W8...L: 05-20A PERMIT No: 1971790 API No: 50-029-22137-01 ~;~C 32, T11 N, R15E, 3938.9',' F8... & 5050.68' FNL -r BP Exploration (Alas ka) '05~20A Dec~lnpletion phast)4 TREE = WELLHEAD = ....,..,n"h.""....""",,,,,,,,,,,,,,,,,,,,,,,,,,, ACTUATOR = 'KB:"I~[BT;;'"" " ëB~ "RBi ';" KOP';"""" 'Max 'Angle ;;; m.............. .. n........ Datum MD = oatUm iVO; , FMC GEN 4 FMC ''''öïiS ''''''''''''''''''71Î 34.1 "6936' '95@1ööià' .. . .m............... . ...... 9244' m 8806;5$ 4-1/2",12.6#, L-80, -' 2978' tubing, ID = 3.958" 13-3/8",68.0#, L-80, - 3512' casing Ð = 12.415" 1 TOP OF 7" LNR 1-1 8292' I I 9-5/8",47.0#, L-80, - casing ID = 8.681" 8620' Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS ~ I POOH and UD the remaining 3 1/2" tubing I r-<:: 1 9141' 1-12-3/8" DEPLOYMENT SLV,ID = 1.969" 1 Top of 2 3/8" Liner 1-1 9141' 3 1/2",9.3#, L-80, tubing, ID = 2.992" 9265' 9244' 1-13-1/2" TIW OVERSHOT SEAL ASSY (BB-iINO LNR) 1 9255' 1-17" X 3-1/2" TIW SS HYDRO SET PKR (BB-iINO LNR) 1 I Top of 4 1/2" liner 1-1 9265' 9790' ÆRFORA TION SUMMARY REF LOG: M\NO GR ON 07/05/98 ANGLE A T TOP ÆRF: 84 @ 9673' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 7",29#, L-80, liner, - 10 = 6.184" 7" X4-1/2" MILLOlffWINDOW - 9323' - 9331' 2-3/8" LNR, 4.6#, L-80, .00387 bpf, 10 = 1.995" 10799' 41/2", 12.6#, L-80, - 10385' liner, 10 = 3.953" DATE 1991 07/08/98 . 02/27/02 06/1'8/02 08/18/03 1 0/27/04 REV BY DA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 05-20A ÆRMIT No: 1971790 API No: 50-029-22137-01 I SEe 32, ri 1 Ñ, R15E, 3938.H1 ¡ FB... & t>050.68' fNL COMMENTS ORIGINAL COM PLETION SIDETRACKED RN/TP CORRECTIONS .~ COLLAPSED TBG CMOffiP ÆRF ANGLE CORRECTION dew Decompletion 4 BP Exploration (Alas ka) 05-20A DeccÎnpletion phase.:S /' 4-1/2", 12.6#, L-80, - tubing, 10 = 3.958" 2978' TREE = WELLH(;AO = .n. ....,.......,.".~......~........um..m.,.."",...." ACTUATOR = ^KB':ELB/;;;'w" ..... ...<..c.." h'C, . N.'.' CB. ELEV = koÞ; , ' Max Aiigië'~U' ........................................... Datum MO = -............................................'-....... Datum 1V0 = FMC GEN 4 FMC ,,' M'ÖfïS 71' 34.1 6936' un... ..... .c. 95 @ 10078' ...... '''''''''''''''''''''''''''''''''''''' 9244' moo..', .,. ... . .... ~ 8800' SS 13-3/8",68.0#, L-80, - 3512' casing ID = 12.415" 1 TOP OF 7" LNR 1-1 8292' I I 9-5/8",47.0#, L-80, - casing 10 = 8.681" 8620' 3 1/2",9.3#, L-80, tubing, 10 = 2.992" 9265' ~ I RIH and set EZSV bridge plug at -9,070'. 1 9141' 1-12-3/8" OEPLOYMENT SLV, 10 = 1.969" 1 / I 9156' 1-13-1/2" OTIS XN NIP, 10 = 2.81" (BEHIND LNR) 1 /1 9244' 1-13-1/2" TIW OVERSHOT S(;AL ASSY (BEHIND LNR) 1 f / I 9255' H 7" x 3-1/2" TIW SS HYDRO SET A<R (BEHIND LNR) I ÆRFORA TION SUMMARY REF LOG: MVVO GR ON 07/05/98 ANGLEATTOPÆRF: 84 @ 9673' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 1-11/16" 4 9673 - 9805 0 07/07/98 1-11/16" 4 10057 - 10760 0 07/07/98 Minimum ID =1.85" @ 9145' 2-3/8" CASING JOINTS ITop of 2 3/8" Liner 1-1 9141' Top of 4 1/2" liner 1-1 9265' 7",29#, L-80, liner, - 10 = 6.184" 9790' 7" X 4-1/2" MILLOUT WINDOW - 9323' - 9331' 2-3/8" LNR, 4.6#, L-80, .00387 bpf, 10 = 1.995" 10799' 41/2",12.6#, L-80, - 10385' liner, 10 = 3.953" OATE 1991 07/08/98 , 02/27/0? I' ' ,,' ~ 06/18/02 08/18/03 10/27/04 REV BY OA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 05-20A ÆRMIT No: 1971790 , API No: 50-029-77137-01 SEC 32, T11N, R1t>E, 3938.91' FEL &'5050.öl:S' FNL" COMMENTS ORIGINAL COM PLETION SIDETRACKED RN/TP I CORRECTIONS "JMITP 'COLLAPS8JTBG CMOfTLP ÆRF ANGLE CORRECTION dew Decompletion 5 BP Exploration (Alaska) "05'-208 Proþbsed completioh 4-1/2",12.6#, L-80, - 2978' tubing, 10 = 3.958" 13-3/8",68.0#, L-80, ~ casing 10 = 12.415" 3512' I TOP OF 7" LNR 1-1 8292' 9-5/8",47.0#, L-80, - casing 10 = 8.681" 8620' I HES 7" EZSV 1-1 9,070' 1 Top of 2 3/8" Liner 1-1 9141' 1 3 1/2", 9.3#, L-80, tubing, 10 = 2.992" 9265' Top of 41/2" liner 1-1 9265' 7",29#, L-80, liner, - 10 = 6.184" 9790' 41/2",12.6#, L-80, - 10385' liner, 10 = 3.953" 2,200' 1-1 41/2" - 'X' landing nipple 1 ~ ---¡ --¡ ST MD 5 TBD 4 TBD 3 TBD 2 TBD 1 TBD --¡ --¡ I I g g 8,830' 1-1 8,850' 1-1 8,870' 1-1 8,890' 1-1 8,897' 1-1 l . J . 8,900' f\ GAS LIFT MANDRELS ìVD DEV TYÆ TBD TBD 4 1/2" X 1 1/2" MMG TBD TBD 41/2" X 1 1/2" MMG TBD TBD 4 1/2" X 1 1/2" MMG TBD TBD 4 1/2" X 1 1/2" MMG TBD TBD 4 1/2" X 1 1/2" MMG VALVE OCR DV DV DV DV 4 1/2" - 'X' landing nipple 1 4 1/2" X 7" Baker 8-3 A<r 41/2" - 'X' landing nipple 1 4 1/2" - 'XN' landing nipple 1 4 1/2", 12.6#, L-80, IBT-M - 5" X 7" Baker HMC liner hanger, ZXP liner top packer w / Tie Back Sleeve. TREE = WELLHEAD = A'cruÄ fOR;" kB.EL8l';'~' , -<'''''«'>«'''U<OU,,,,,,-,, .., ,., , CB. ELEV = ,KÖÞ'~ ' MaxÄñgie; , batumMb;mm Dâtum~wtS ;:;m FMC GEN 4 FMC ,uÓf5 71' "'34:1 6936' ,,~~,@',~,~~!.~: 9244' "880ÖïuSS LATCH RK RK RK RK RK I 12,073' 1--141/2",12.6#, L-80, IBT-M liner DA TE REV BY 1991 07/08/98 f'2:'27 íO~ '''06/1 a7õi 08/18/03 1 0/27/04 COMMENTS ORIGINAL COM PLETION SIDETRACKED RN'TP COPHECT!C:--~S jM1TPCõïIAPSEDTBG=~--- CMOITLP ÆRF ANGLE CORRECTION dew 5-20B Proposed cOJll)letion DA TE REV BY ~ 'Ili: ,.... - ; - . --=.-.---: ...~ --- COMMENTS PRUDHOE BAY UNIT WELL: 05-20B ÆRMIT No: API No: 50-029-22137-G2 SEe 32, T11 N, R15E, 3938.91' FEL & 5050.68' FNL BP Exploration (Alas ka) 197-179-0 MD 10800 Microfilm Roll PRUDHOE BAY UNIT 05-20A TVD 09027 Completion Date: / Roll 2 / 50- 029-22137-01 BP EXPLORATION (ALASKA) INC 7/8/98 Completed Status: 1-OIL Current: - Elevation: KB 0071 Name D 8875 L GR-MD L GR-TVD L TDTQ R EOW RPT Interval Run BH GR OH FINAL 9317-10800 OH FINAL 8826-8956 OH FINAL 8000-9050 CH BHI 9233.-10165. OH Sent Received 12/30/98 1/11/99 12/30/98 1/11/99 12/30/98 1/11/99 11/20/97 11/21/97 9/10/98 9/1/98 T/C/D D D Monday, August 28, 2000 Page 1 of 1 ARCO Alaska Inc. AOGCC, Lori Taylor Well Reference Data: Well No: 05-20A Field: County: State: Date' Prudhoe Bay Unit API No' North Slope Alaska 12/30/98 500292213701 BHI Job#' 98833 Enclosed is the following data as listed below: Log Type Bluelines Navig~ma BDEN MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~mma BDEN MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tapes LIS Verification Listings Upon Receipt, Please sign and fax to: Received by: Bake~ .HDghes INT~Q Attn- 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 X Gas Suspended Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-179 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22137-01 4 Location of well at surfaceJ~' '~{'~7"5'7" ~x~ .,~' - ' v__,'aJ": ;-_ ! ,;i.:,:j: i~. ' - '} !~~ 9 Unit or Lease Name 2911' FNL, 5033' FEL, Sec 32, T11 N, R15E, UM t ~', ,;-:: i PRUDHOE BAY UNIT 5-20A At Total Depth ¢~~,. ~ , 11 Field and Pool 5050' FNL, 3951 FEL, Sec 32, T11N, R15E, UM. ,:¢~~~; PRUDHOE BAY FIELD 5 Elevation in feet (indi~te KB, DF, etc.) 16 Lease Designation and Serial No. 71' RKB ADL 28329 PRUDHOE BAY OIL POOL 12 Date Spudded i13 Date T.D. Reached i14 Date Comp., Susp., or Aband. 15 Water Depth, ~ offshore 16 No. of Completions 6/25/98 7/6/98 7/8/98 N/A 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thic~ess of Per,frost 10800' MD/9027' TVD 10765' MD / 9028' ~D YES_X NO~ 1976' MD 1900' (approx) 22 Type Electric or Other Logs Run MWD & GR. 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~ING RECORD AMT PULLED 20" 91.5¢ H-40 Surfa~ 115' 30" 2150 lbs Poleset 13-3/8" 68¢ L-80 Surface 3512' 16" 1295 Sx CS III & 400 Sx Class G - 9-5/8" 47¢ L-80 Surface 8621' 12-1/4" 1420 Sx Class G - 7" 29¢ L-80 8291' 9323' 8-1/2" 100 Sx RAMP Cmt & 234 Sx Class G - 4-1/2" 12.6¢ L-80 9265' 9322' 8-1/2" U n ce me nted - 2-3/8" 4.6¢ L-80 9141' 10800' 2-3/4" 8 bbls 15.8 ppg ~RC - 24 Pedorations open to Pr~uction (MD+~D of Top and BoSom and 25 - TUBING RECORD inte~al, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 2978' 9255' 9673' - 9805' MD; 9021' - 9028" ~D; ~ 4 spf. 3-1/2" Tbg 9265' 10057' - 10760' MD; 9030' - 9028' TVD; ~ 4 spf. ~ 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Produ~ion Method of Operation (Flowing, gas I~, etc.) 7/1~98 Flowing Date of T~t Hours Tested PRODUCTION FOR OIL - BBL ~S - MCF WATER - BBL CHOKE SIZE ~ GOR 7/16/98 4.0 TEST PERIOD ~~ 5127 Flow Tubing Press Casing Pressure CALCU~TED OIL - BBL ~S - MCF WATER - BBL OIL GRAVI~ - APl (coif) 516 - 24 HOUR ~TE _X 985 5050 83 28 CORE DATA Brief description of lithology, poros~, fra~ures, apparent dips and presence of oil, gas, or water. Subm~ core chips. * This 10-407 is submi~ed as directed per the 10-401 form approved 9/25/97 (Permit ¢ 97-179). G'NAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Shublik Sadlerochit Top (other pics) GEOLOGIC MARKERS MEAS DEPTH 8589' 8679' TRUE VERT DEPTH FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. 8428' 8499' 31 LIST OF ATTACHMENTS Summary of 5-20A CT Sidetrack Drilling Operations + Survey. 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Erin Oba Engineering Supervisor INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt , water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 7-1-80 5-20A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 6/22/98 - 6/23/98: MIRU CTU. Tested BOPE. RIH & PT'd cmt. Tagged TOC @ 9297' MD. POOH. RIH w/BHA & UR cmt from 9270' to 9317' MD. POOH w/BHA. 6/24/98: RIH w/BHA & tagged BTM @ 9317' MD. Milled to 9318 & POOH. RIH w/BHA to 6800'. 6/25/98: RIH slowly because BHA was hanging up on tbg collars. POOH. RIH & sat down on 3-1/2" collar @ 3010' & every collar thereafter. Milled from 9317' to 9321.6'. POOH. 6/26/98: RIH but unable to get past 5448' so POOH. PT'd 9-5/8" by tbg annulus to 2000 psi. RU slickline & RIH w/ LIB. POOH. Ran several swedges to test tbg restrictions. RD slickline. RIH w/BHA & reamed to 9321' POOH. RIH w/formation mill & reamed tbg from 5447' to 5457'. 6/27/98: Reamed tbg from 5446' to 5461'. POOH w/BHA. RIH & tagged BTM @ 9318' MD. Reamed cement pilot hole from 9318' to 9323'. Swept wellbore w/Biozan while POOH. RIH to BTM & started milling window @ 9322'. Window will go through 4-1/2" & 7" liners. 6/28/98: Milled window from 9323' to 9330'. Drilled into formation to 9336'. POOH. RIH w/BHA. 6/29/98: Dressed window area & drilled ahead to 9345'. POOH. Tested BOPE. Performed LOT to EMW of 9.5 ppg. RIH w/bi-centered bit & drilled from 9341' to 9450'. 6/30/98: Drilled to 9548' w/short trips to window. POOH. RIH & drilled to 9606'. 7/01/98: Drilled from 9606' to 9678' (end of build section). Drilled horizontally from 9678' to 9986'. 7/02/98: Continued to drill horizontal sectiora to 10200' & POOH. RIH to BTM & drilled to 10212'. 7/03/98: Drilled to 10224' & lost MWD signals. POOH. RIH w/BHA. 7/04/98: Drilled to 10442'. Differentially stuck @ 10436'. Spotted 5 bbls of Crude & freed pipe. Drilled ahead to 10450' & pipe became stuck again. 7105198: Spotted 7 bbls of Crude &freed pipe. Drilled to 10533' & POOH. RIH & drilled to 10663'. Page I 5-20A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 7/06/98: Drilled from 10663' to TD @ 10800'. Cleaned up hole & displaced well w/new mud. Well kicked while POOH. RBIH & circulated 2 annular volumes of new mud to kill well. POOH pumping down CT. 7/07/98: Tested BOPE. RIH w/2-3/8" liner & landed it @ 10800' MD. Cemented liner in place w/8 bbls of 15.8 ppg LARC Cement. Unstung from the flapper valve @ 10765' MD & cleaned out liner w/Biozan flush to 9200'. RBIH to PBTD pumping clean mud pill. POOH. WOC. 7/08/98: RIH w/perforating guns. PT'd liner lap. Shot 835' of Initial Perforations @: 9673'- 9805' MD (Z1B) 10057' - 10760' MD (Z1B) Used 1-11/16' carriers & shot all perfs at 4 SPF. POOH w/perf guns. ASF. RDMOL. Placed the well on initial production w/gas lift & obtained a valid well test. Page 2 ORIGINAL ARCO ALASKA, Inc. Well: 5-20A Prudhoe Bay North Slope, Alaska Rig: Nabors 3s DIS Unit #4 End of Well S u rvey Re port Provided in: True - Grid - ASP BHI Rep: Dwain Young Job Number: 98833 AFE Number: AP1265 APl Number: 500292213701 Reviewed by: Date: Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth from: ARCO Alaska? Inc. 5-20A Minimum Curvature 132.460 GRID 133.960 TRUE RKB Sea level EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Rig: Nabors 3s/CTU#4 Location: Prudhoe Bay~ Alaska Mag. Declination: 28.400 Grid Correction: 1.500 Total Correction: 26.900 ORiGiNAL Job No: AFE No: BHI Rep: Job Start Date: Job End Date: DLS (°/100 ft): 98833 AP-1265 Dwain Young 20-Jun-98 06-Jui-98 100.00 Meas. Incl. Depth Ang~ (deg) 9233.00 59.70 9258.00 60.84 9283.00 61.98 9300.00 62.75 9337.00 59.10 9362.00 58.70 9396.00 60.30 9427.00 62.90 9450.00 64.60 9479.00 67.10 9507.00 70.10 9540.00 73.10 9570.00 78.70 9600.00 84.10 9627.00 86.40 9655.00 84.90 9691.00 84.00 9722.00 88.10 89.60 9781.00 86.90 9820.00 86.60 9852.00 89.80 9881.00 90.20 9912.00 89.00 994 87.70 9983.00 89.80 10015.00 90.40 93.10 10078.00 95.20 10119.00 91.70 10165.00 93.00 Subsea Coords.- TRUE TVD N(+VS(-) E(+)/W(-) (R) Lat.(Y) Dep.(X) 8794.59 -1195.21 55.85 Coords. - ASP GRID N(+)/S(-) E(+)/W(-) Azi. Lat. (Y) Dep. (X) 5947345.00 697417.10 166.00 8806.99 -1216.41 60.52 5947323.93 697422.32 8818.95 -1237.86 65.18 5947302.61 697427.54 8826.84 -1252.59 68.34 5947287.97 697431.09 8844.81 -1284.09 75.63 5947256.67 697439.20 8857.73 -1304.60 81.70 5947236.32 697445.81 8874.99 -1331.94 92.20 5947209.27 697457.02 8889.74 -1356.73 103.54 5947184.78 697469.00 8899.91 -1375.26 112.60 5947166.49 697478.54 8911.78 -1399.15 123.99 5947142.92 69749(I.55 8921.99 -1422.88 134.77 5947119.48 697501.96 8932.41 -1451.13 148.26 5947091.59 697516.17 8939.72 -1477.25 161.05 5947065.81 697529.64 8944.20 -1504.43 172.89 5947038.95 697542.19 8946.44 -1529.53 182.57 5947014.11 697552.53 8948.56 -1556.13 191.01 5946987.74 697561 8952.04 -1590.77 200.19 5946953.36 697571.75 8954.18 -1620.35 209.16 5946924.02 697581.48 -1643.80 217.81 8954.68 8955.72 -1674.67 231.97 252.22 271.66 290.93 313.49 336.75 372.97 402.12 432.23 461.21 497.97 536.19 8957.94 -1707.90 8958.94 -1733.28 8958.94 -1754.94 8959.16 -1776.17 8959.99 -1793.45 8960.91 -1814.65 8960.86 -1827.81 8959.88 -1838.57 8957.63 -1849.31 8955.16 -1867.24 8953.27 -1892.69 Coords.-GRID N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) -1193.30 87.20 Dogleg (Deg/100ft) 4.57 166.16 -1214.37 92.42 4.59 166.32 -1235.69 97.64 4.: 166.43 -1250.33 101.19 4.57 164.50 -1281.63 109.30 10.87 159.50 -1301.98 155.50 -1329.03 152.40 -1353.52 -1371.81 -1395.38 115.91 17.20 127.12 11.17 139.10 12.15 148.64 7.40 Vertical Section (from TI P) 0.00 18.08 36.32 48.82 75.93 94.54 121.08 146.45 165.83 160.65 9.18 190.61 152.50 153.50 154.60 151.40 153.40 156.50 158.30 -1418.82 172.06 -1446.71 186.27 -1472.49 199.74 -1499.35 212.29 -1524.19 222.63 163.50 -1550.56 163.80 -1584.94 159.50 -1614.28 11.32 214.85 12.93 244.16 19.75 271.50 20.70 298.89 10.80 323.29 231.76 19.28 241.85 2.63 251.58 19.14 260.84 11 5946900.81 697590.74 157.00 -1637.49 697605.71 150.70 -1667.98 275.81 20.15 697626.82 143.60 -1700.67 296.92 18.19 697646.92 138.50 -1725.53 317.02 18.81 697666.75 135.20 -1746.69 336.85 697689.86 128.30 -1767.32 359.96 697713.56 121.90 -1783.98 383.66 697750.32 115.80 -1804.23 420.42 697779.81 109.80 -1816.62 449.91 697810.20 106.50 -1826.58 480.30 697839.45 111 -1836.57 509.55 697876.66 117.80 -1853.53 546.76 697915.54 126.50 -1877.96 585.64 22.59 22.51 15.36 347.83 378.48 405.47 459.59 497.23 528.85 557.76 588.73 617.47 658.26 18.84 688.38 13.32 717.52 16.57 745.84 18.19 784.75 5946870.32 5946837.63 5946812.77 5946791.61 5946770.98 5946754.32 5946734.07 5946721.68 5946711.72 5946701.73 5946684.77 5946660.34 19.11 829.92 Comments Tie in Position '0 Meas. Incl. TRUE Subsea Coords. - TRUE Coords. - ASP GRID Coords. - GRID Dogleg Vertical Depth Angle Azi. TVD N(+VS(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Azi. N(+VS(-) E(+)/W(-) Section Comments (deg) (deg) (fl) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (de~) Lat. (Y) Dep. (X) (De~/100fl) /from 10201.00 91.80 130.60 8951.77 -1915.47 564.02 5946638.29 697943.95 129.10 -1900.01 614.05 7.95 865.77 10255.00 90.70 131.90 8950.59 -1951.06 604.61 5946603.77 697985.46 130.40 -1934.53 655.56 3.15 919.69 10286.00 89.20 129.20 8950.62 -1971.21 628.16 5946584.25 698009.53 127.70 -1954.05 679.63 9.96 950.63 10330.00 89.80 125.40 8951.00 -1997.87 663.16 5946558.51 698045.21 123.90 -1979.79 715.31 8.74 994.33 10364.00 89.70 122.00 8951.15 -2016.73 691.44 5946540.40 698073.98 120.50 -1997.90 744.08 10.00 1027.78 10398.00 90.30 117.80 8951.15 -2033.68 720.91 5946524.23 698103.88 116.30 -2014.07 773.98 12.48 1060.75 , 10432.00 86.20 117.30 8952.19 -2049.39 751.03 5946509.31 698134.40 115.80 -2028.99 804.50 12.15 1093.34 10467.00 88.00 117.10 8953.96 -2065.37 782.12 5946494.15 698165.90 115.60 -2044.15 836.00 5.17 1126.81 10498.00 90.00 115.50 8954.50 -2079.10 809.90 5946481.15 698194.03 114.00 -2057.15 864.13 8.26 1156.34 10530.00 89.90 110.90 8954.53 -2091.70 839.31 5946469.32 698223.76 109.40 -2068.98 893.86 14.38 1186.26 10560.00 88.90 106.00 8954.84 -2101.19 867.76 5946460.58 698252.44 104.50 -2077.72 922.54 16.67 1213.32 10613.00 88.30 104.40 8956.131 -2115.09 918.88 5946448.03 698303.92 102.90 -2090.27 974.02 3.22 1259.77 I 10645.00 88.50 102.10 8957.03i -2122.42 950.02 5946441.52, 698335.23 100.60 -2096.78 1005.33 7.21' 1287.27 10687.00 89.50 99.20 8957.76 -2130.18 991.28 5946434.84 698376.69 97.70 -2103.46 1046.79 7.30 1322.36 10719.00 90.90 96.701 8957.65 -2134.60 1022.97 5946431.25 698408.48 95.20 -2107.05 1078.58 8.95 1348.24 10752.00 90.90: 94.70 8957.13 -2137.88 1055.80 5946428.83 698441.39 93.20 -2109.47 1111.49 6.06 1374.15 10786.00 90.90 94.00 8956.60 -2140.46 1089.70 5946427.14 698475.34 92.50 -2111.16 1145.44 2.06 1400.34 T.D. TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 25. 1997 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Prudhoe Bav Unit 5-20A ARCO Alaska. Inc. Permit No. 97-179 Sur. Loc. 291 I'FNL. 5033'FEL. Sec. 32. T1 IN. R15E. UM Btmnhole Loc. 254'FNL. 437'FWL. Sec. 5. T10N. RISE. UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blo~vout prevention equipment (BOPE) must be tested in accordance v,,-ith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to alloxv 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. Robert N. Christenson Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill X lb. Type of Well Exploratory_ Str. atigraphic Test -, Development Oil X__ Re-Entry__ Deepen _ ~ Service_ Development Gas _ Single Zone X_~ Multiple Zone 2. Name of Operator I 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. I RKB 64' 3. AddressI 6. Property Designation P.O. Box 100360~1 Prudhoe Bay Field Anchorage, AK 99510-0360 I ADL 28329 Prudhoe Bay Oil Pool 4. Location of well at surfaceI 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2911' FNL, 5033' FEL, Sec 32, T11N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 5-20A 976' FSL, 340' FWL, Sec 32, T11N, R15E, UM I 9. Approximate spud date I #U-630610 At total depth Amount (Proposed) 254' FNL, 437' FWL, Sec 5, T10N, R15E, UM. October, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ! No Close Approach !,I 10960' MD / 9031' TVD 16. To be completed for deviated wellsII 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9855' MD Maximum hole angle 90° I Maximum surface 2800 psig At total depth (TVD) 9000' 18. Casing program t I Setting Depth Size Specification Top, Bottom Quantity of cement Hole I Casin~i [ Wei,qht I Grade Coupling ,Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 1200' i 9760' 9025' 10960' 9031' N/A (slotted liner) . ' 10. To be completed for Reddll, Reentry, and Deapen Operations. Present well condition summary Total depth: true measured vertical 9040 10865 foot feet Plugs(measured) ORI6[NAL Effective depth: measured 10865 feet Junk (measured) true vertical 9040 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 115' 20" 2150 lbs Poleset 115' 115' Surface 3441' 13-3/8" 1295 Sx CS III & 400 Sx Cl G 3513' 3512' Production 8550' 9-5/8" 1420 Sx CIG 8621' 8453' Liner 1498' 7" 1000 Sx RAMP & 234 Sx CIG 9790' 9026' Slotted Liner 1120' 4-1/2" Uncemented 10385' R~~V~ Slotted Liner 453' 2-3/8" Uncemented 10670' Perforation depth: measured Slotted Liners: 9457 - 10670'; Open Hole: 10670 - 10865' '"'i:-P , "- 1997 true vertical Slotted Liners: 8960 - 9040'; Open Hole: 9040 - 9040' g/as~a .0il .& Gas Cons, 20. Attachments Filing fee ~ Property plat _ BOP Sketch X Diverter Sketch _ Drilling program x Drilling fluid program Time vs depth plot Refraction analysis Seabed report~ 20 AAC 25.050 requirements _ 21. ~hereby~ertifythatthef~reg~ingistrueandc~rrectt~thebest~fmyk~w1edgeL~`~.`~e.~i~>v~~ ,-~1'~/6 ~'~,~¢'c~ ¢--65'-130-¢¢'. Signed ~~,,- '~ · ~/~6/~ Titllo Engineering Supervisor Date ¢-/' * '" ? 2 Commission Use Only Permit Number i APl number I Appr°val~tl 1~ See cover letter for ~,~--~,/~ ~. 50-~,2-'~-- ,~,~..,/~ 7-" O/ .~'~1 other requirements Conditions of approval Samples required __Yes ~'No Mud Icg required / Yes ,~_No Hydrogen sulfide measures ,~Yes _ No Directional survey required --_~_ Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15MX_ 3500 psi for CTU Other: ORIGINALRobert N. ChristensonSIGNED'BY by order of ~ )~ Approved by Commissioner the commission Date DS 5-20A CT Drilling and Completion Intended Procedure Ob. iecfive: Directionally drill -1100', 2-3/4" horizontal extension from the Complete with 2-3/8" slotted liner. existing wellbore. Intended Procedure: RU CTU and spot 18 ppg mud in 2-3/8" x 4-1/2" x 8-1/2" annuli and up to 10000' md in 4-1/2" slotted liner. Lay-in 17 ppg cement plug in 4-1/2" and 4-1/2" x 8.5" annulus from 10000' to N 9800'. RD CTU. RU CTU/Nabors 3S. Mill window in 4-1/2" liner at - 9855' md. Load well with +8.9 ppg polymer mud. Directionally drill -1100' of 2-3/4" horizontal hole to access Romeo reserves. Run 2-3/8" slotted liner to TD. RD CTD, return well to production. September 15, 1997 4-1/2" Tubing to 2978' 4-1/2" Camco Bal-o SSSV @ 1976' DS 5-20A PROPOSED CT ST AND COMPLETION 2-3/8" Perf'd liner 3-1/2" Production Tubing Window cut in 4.5" liner and cmt in 8.5" annulus @ 9855' 9255' MD TIW SSHS Pkr. MD 7" Liner shoe 2.75" hole 18 ppg mud in openhole 8.5" Openhole 284' .5" GS FN @ 10217' 10669' MD End of 2-3/8" liner & 8.5" OH 17 ppg cement plug in 4-1/2" liner and 4.5"x 8.5" annulus 4-1/2" Slotted Liner 928'( shoe at 10385') 2.375" Preperf'd Liner 2.75" Openhole 199' 10868' MD , s.*,¥.~ ×~ 5-20 A REV. 0 :~:**.. S~'1~p71'~'~ ............... ~ ............... IT~-~ ................... *~i-;IN~ ........... ~ild ........ T'~r~' ~gl~ ~SP Y ~S~"X C~"I~ ............. ~ " .... ~ .................. % .......... ~!.~. ....d~°_ ~ ~ ~ · ..... ~.~ ~.oo .~7~ 2~ ~9.~ .......0-0~ ....... ~.~ ............. E~ ..... '~';~.'~ ....... ~'9~.~o.~"~. ~i~ n ~oi~ ..................... . ~ ' "~ 73 ..... ~ ~ ............. ~"~ ..... ~'~-~-~ ~ ........ ~-~.~ .............. ~'~60 ........ ff".~" :l~'f.fO" ~.~ , . , · ...... .................................................... ~ ........ . ............. ~90 ~, 5~.84 ~7~ eg. ' ~';~0 .... '~:;~ ..... ;i~¥ i~T ....... i~.~ 4.~.~ 0.~. ¢7o 5.9~ ~zs.co ...... ~}2~'~'~- ......... ~;~ ......... f)'~*.:~ ........ ~.so ....... ~ ........ ;'i~i~~" ~ 4.70' ~.~ ........ 47b ~'.~;~ ....... ~9'7.-~03.~ ............................... .... 9~-6;~' ....... ~;~F ........... i'f~'T~T ..... ~.?~ ........ ~'.~ ...... -i'~'~b': ..... i~.~ 4.70' 0.~~. ..... i~--~:~'~6" '~fi~.')O ..................................... .................................................. ~ ..................... ~ ................. ~ ................................................ ....... ......... ................ , s.9~,~7.00 ~7.s~.so ........................... '6m~/~ ....... ~ ~ ......... ~;~ -'~f~ ....... ¢~.~'t ..... :~'~3s.~ .... ~-~ .............. ~;fb- .............. -0.-~' 4.70~ ~.~,~ so ~7.s~930 ........................ ........ 98~:~ ..... ~:b~: ..... ~ ~2.~ 8~.~ ~=.~ -~85.-b ............. i~;90' 4Zo- 0~' '~;'~t'--5;~.~TS~ .... ~.s~.~ ................... 9852. ~0 89 45 172.53 8958.g0~ ~ 35.20; -~ 777.-90 ...... ~70.;::)0 ~,.q. 48 ! '{ 70';'~i 8959 10 1~ 50. 4794.80 .... ~6~;.~; ......... ~e.~'~ 168.18 8~0.~. 1~7.~ .1824.!0 99~.,~: 89. ~ ~; ~62':~'4 - -- ~:~ ............. ~9.-7~ ........ -~ 8~.00 14,8.61:) 4.70 0.40 ..... '~f-2~- ................ :U~i 0 ........ -f3.40 t57.30! 01C-i -13.40 185.50i 0 1[I. -13.40' 75.70; 0.2o; ....... '--i:~;~'i 13.40 5,946.690.531 697,543.1~3: 99i)0.0(3' 89.66 'I'~.O~' .....8980.00 238.30 -1908.601 187.90? 0.20---13.-10i '13.'40 .... 5'.~.'~3-5'~,~ .... 697.567.70': ...................... 10020.00 89.7~ 150. C4 8S6&20 ;2~:~4.~ .... :19;~ 101 2~51.9(~ 0.20 -13.40; 13 40 5.948.8Cle.~9 697.582.,33 1005600: 8976 1'~6.C(}! 896D.;J~ .......... ;~'~.4(I-." ' ':i-~i~--r~'! ..... 21780 0.20 -*--~51~,~'" 13.50:, 5.94~.584.00 697,599.00 .... ~o0~O'.-,3b ....... 8~618-1 141.~7 8960.40 3i93(i'I -1984. fi0' ~5.40 0.20 -'3 40 '.'.3.40~i 5.946,560.50 6-~f.61 ~:5~ ........................................................ --t b'~"f'Q-O0 ........... -8_c~'7 ......... 157.~3! agra.50 347.801 .200?.eh ......... -~-~-?-6 ........... ~ ;~.'~ ......... -' ;~.40 ~ ~-.~"' 519~,53&00' 6~7 83?2o ........................................ .................................................... ,~ ....................................... . ............................... !0:40 O0 !~.92 133.901 8960.60 377.00; -2029.30 275 80 0.20: :3 44) 13.40 5.946.517.00 697 65860. ...................... lo!?o~o ssg~ .... ~'~ia~~ ...... -bg~o--~ ......... ~i~-~b- .... ¥2649.30 ~9790; .......... O~b'i ...... .~3.40 13.~ ~.9~.~97sc., eaT~ 4c. ' ..... , ........ ~ .................. ! .............................................................. ....................................................... - _ ~ : . ........ ~ .................... ; ............................................... ; 10200. D0 ~003i '.'2583 6960. fl0[ 4~'6.-4~''-2067.70 321~)~ ........... ~.'~3~ .......... ;'1-340'= 1340 5.g48..479.50; ....................................... ~'-' - ................ 10230.~c 9o c~ '..-a 79 s~o. so. 4~s.40 -20e4.A3. 3465o O.~a ...... :ii~? .......... ~i~"--~i~7~s3:~: ....... ~7S~T~o;'~O" 10260.C42 9~:14 '... '7 76 Bg60.50: 496.40 -2099 3(,..:.." ........ 3~Z:60 0.20 -.13.40 ..... 10290.00 ' 90.2C 113 .'~ 8~;J~C,.40 526~'3 -Z112 ~i 3~.60 0.20 -13.40 ....... ......... ..... . .so ...... o'2o' ...... ....... 10350.00 90.30 . _ 10380 O0 D0.35 .... -T6'~95'~o .... ~.~" 10410.00 9,,?5'6: · '13440.0C' 90.32' 105.66 89~3.2D 58a 70: -2?32.60 45600 ...... ;3';26: ........ ::'3.40' ~O'.-..~2' "egsd;i~ ..... ~i3';~ :~-~.-6b- .... 485.2o 0 2~ -~3.~-' ~ .59 8~9. ~ 627.10 -2142.~ 5~ ~. 0 ~ - 13 ~, -~ ~' ....... ~'6 ~: .........6~T~- ' --~i-~.~, 514 70 "-6'~'~' ......... b 80~ ...... ~ ................................................ ~3 50- 5.946.437.00 697.784.70 { ',.3 40~ 51946,427.00 697.812_9~ ................................ i 12~. ~--- - -~;!;~u~,~ ~-~ -~6-. ....... ~-.-I~:; 60i ............................................... 13.40 5,946.412.0E: 897 8,7? L'~! 1:3.40 '5,9'.-i640~.5Ci eJ:J78~.9~..]3. T~, ~.C.'rie,~i!O~'~'. ' 5~ ...... ~:§~-4b',~.-5;:' ¢97.9oo~3 , ......................... 0.90 5,946.403,.53 697.930.40 .............................................. .................................... ; ..................................................... ; ................... ,,~.; ;O'~OC,OO 90.24 95.7.~ ,~59.30 723 6C~ -,"'.'59.10 6,33.60 -3 i0 ' .0'$9 .... 0'.~::-'5.9;~6,396.00' 6~7.969.90- ' ' ...... ; 0~0 ~0 ......9b'~6 9S.44' ~95a20 fs~--oC'"---- '--~{~3'~0 ''~3 ~ ........ ;~T~ ........ :'6~6 .............. 0:9C' '$i~.--T~9--~.§--6 .... ~'.5i9 60 ........... 10590--''6D' ~' 12 '-- ~i ~' ag"~9 i6' ' - '8'~s:8o - - :2i7~'~G- 692 ~0 -0 1C' 0.~0 ~.90 5,~45.365.C0: ' !~,7-g2~ ...... II¢~C :~'- ~ ; ~ ~'''~ ' ='~'~ ~'4 ' ~? ,:2 59593';7. ' ~.~,'=~-~:; ~;..... ........................................................................................................ -21EC 13 7~; 3 '..0680.00 90.0,3 97.17 8969.30' 887.50 -2183. i¢3 .... ,-"8: .90' ..... ~'0'?~'0"0~ .............. ~"{1'6' ........... 96 at ' ..~.qSPO0' ~':4'~8 ........ -::'-::~f¥~ .......... ~ii ~9 ..... ~'i07 ---0.~' O.2O' S.'~.3~'5--0'- 6.~.l~ie'~'C,' ........ 10',;',~1 O0 6992 96?_,6 8959.00 94~ 7C -~191 ~ 8-'1 4,::) -C i9 -D ~-':.. C,.90 5.946.370.00 6EZ:3 2Z8 4. C ....... ; II MD Inc. Dir SS DEI:rrH VS N,~-5: B:-W Build Turn. Dogleg ASP Y A~ X ........ ~t ....... d'~ d'~ .......... . ............ ~ ................. .~: .......... ~ ........ ~;~60 ....... de~ .~ ..... n'~ n: .......................................... ' ~'0~.~C "~.~8 .... ~'~ ....... ~'ib '~ ~; :~'.'~ ...... ~7'~ 20 ~ i~' ' ~'.~0 ............. 0;~- S'~'~'~. ~9~.~s-~'.'~ ' i~.-~'~ ....-i~6 ............... ~'- ' .~.2o ' ~02~.~~. '.~0i"~b ........ ~.~ ...... :0.'i:5; ..... :6:~ .... 9.9o ' 5.9~.'~.~ ..... i'iS.jl~.io ................................... --i'~.00 ~" ~ 76 ~.~ ;~ ...... > ................ ~ ................................. ~.~ 1~.~. -~.o,..o ~..o .~ ~o .~.~ .~ ~'~.~.~' ~9,.a~o ..................................... ':!~ :.'.:~7~:'~,~'-~:~';" ,~'.~ ..... ~,.~, .... .~ ....... ~:~ ................ :~:~ ............... :~-~ ............. ~-.~ .... ~.~:~..~. ...... ~-:~-~.~ ........ 5 946,356 gO ~J96,407.90 5.946,~ 50 69a,,,~t8 60 4 TD ;3i*[~'Total Footage .................. VERTICAL SECTI~i~I' U~ ~)- ....... ~' 122.3" RELATIVE T'O "~R'~''lqO'R'fH .......................................... RKB i !': -71' ' ............................................................................. NOTE [: Relative Coordinates are off of true No?th/ASP are relative to griU' Nodh .~JRFACE X .................... · 697~29.90 i ' ' ~, '~ .......... ';: .................. ~ .... := ........ --'-~ .................................................... DRILEX- BAKER I-IUC2_AtES'IKTEO ~L~SKA 5-2"3AT 5-20ORTR I PLANE OF VERT SECTn 122.30- REL. TO TRUE NORTH .......................................................................... '-12.,3C .. t il - .- __ · ,. -18OR -2~ --~ - 2 2 01~ -..1 .... .- .. : .... . -2~00 ---- ......I I~! "~ Iii:jill I~i, --il · , E:~'Scale: :nch ~ tt .5-20 A C T Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick Connect ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser II II Alignment Guide Flange I III' 7-1/16", 5M Ram Type Dual ~ ~]~ ~ - Gate BOPE Flanged Fire Resistant Man e Kelly Hose to Dual HCR Choke Manifold \ ... Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure (3.5") Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manualover .Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve o.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus Mu, Tanks 60/40 I TrplxI l-ire Ext, Shop Fuel Boilers Water Pump Roor Fire Ext. hire Ext. ,~Pipe r a 7,,~ r-r/) -~c Dowell Drilling Equipment Traire Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY ,~,,,,--~__~, WELL NAME 2'¢;',~,,,~ 5"'..~,~ PROGRAM: exp [] de ed serv [] wellbore seg El ann. disposal para req FIELD & POOL ~,~_~./__<;',,"3 INIT CLASS ,~~ ,/- ~:~j ~EOL ~REA ~'C.) UNIT# //~'_(",,~ ON/OFF SHORE 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. Perrhit can be issued without administrative approval ...... 13. Can Permit be approved before 15-day wait ........... ENGINEERING REMARKS N ~N GEOLOGY APPR DC, TE, 14. Conductor string provided .......... : ........ Y N 15. Surface Casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N '~ ~ r /q . 17. CMT vol adequate to tie-in long string to surf csg ........ Y N ~../ , 18. CMT will cover all known productive horizons .......... .~Y'~~"~/'¢--¢:~ f<j-'v,,t~- 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... (-~N 22. Adequate wellbore separation proposed ............. (-Y-~, N ~. r ,L~/~,j,/.~ V 23. If diver[er required, does it meet regulations .......... 24. Drilling fluid prograr~ schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to -'~A~ 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 ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... Y./,~ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ // Y N 34. Contact name/phone for weeklyproc~ress reports .... ,,/f.. Y N [expiora'fory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 07/97