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2-OI - 02.3 240 a? Co Gyrodata Incorporated • 'data 23000 Northwest Lake Dr. gyro Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 070 pO CC scute SEP 0 62.01a SURVEY REPORT BP Exploration Drill Site: 17 #17-04B Wellhead Prudhoe Bay, North Slope Borough, AK AK1114GCM201 15 November 2014 RIGHT PLACE FIRST TIME \SGS i www.gyrodata.com m'°"' Gyrodata Incorporated • 23000 Northwest Lake Dr. gyroldata Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 • State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 17, Well #17-04B Prudhoe Bay, Alaska Enclosed, please find one (1) copy, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. 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J-1 O C • f O 1 X _ i I i t , l I ' I ; I I l ' , , l l i , , , I 1 W ,R) U I ! 1 r I O n- �j O CO t0 Ct' N O co l0 J- N 0 ir1 J T-i Ti '1..'i ,--i ri (4001/6aP) ) Fd9AAS D 1DOa • Survey QC - RGS-Clkontinuous Specification Sheet gyro/data SURVEY QUALITY CONTROL—SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION (ROLL TEST) System Parameter dGx dGy dmbo Mean Gravity Error* Stdev Gravity Error Standard Deviation 0.005 0.005 0.005 -0.00017 0.00003 Tolerance 0.033 0.033 0.087 0.00591 0.00720 GYRO VERIFICATION (ADVANCED INITIALISATION) Gyro Compass Parameter Gyro noise dGx dGy dmbo Max corr coef Standard Deviation 0.021 0.004 0.003 0.000 0.08 Tolerance 0.141 0.033 0.033 0.087 0.42 Initialisation inclination standard deviation 0.08 Initialisation azimuth standard deviation 0.26 Initialisation azimuth uncertainty in percent of error model -Tolerance < 100% 34% ACCELEROMETER VERIFICATION (G-TC sL TEST) -not applicable for 2 accelerometer systems G-Total Test Parameter Mean Gravity Error Mean Gravity Error Standard Deviation Error -0.00029 0.00002 Tolerance 0.00590 0.02468 CALIBRATION Tool Number F0052 Calibration Date 117 May 2014 tiATING TEMPERATURE Calibration range From 50.48 To 120.02 Gyro operating range From 61.72 To 93.09 In-Spec if+/- 2.5 °C of Calibration CONTINUOUS DRIFT CORRECTION Linear Drift Uncertainty 0.29 Random Walk Uncertainty 0.05 Tolerance 0.46 Tolerance 0.23 CONTINUOUS MISALIGNMENT CORRECTIt Misalignment Parameter dMx dMy Cross corr coef Standard Deviation Tolerance DFPTH CONTROE. Wireline Company Line type Encoder SF Max Depth (TD) _ CCL Corrected Zero Depth (Rig up) Rezero Depth Given pup joint depth Measured P3 Strech cor. At TD divided by TD/1000 Spec'- 1.5/1000 Dif. Between riqup and rezero depths divided by TD/1000 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 Spec'- 2.0/1000 INDIVIDUAL STATION REPOR1 °AD of Total stations accepted Tolerance > 80% 100% Consecutive Interval out of Specification Tolerance < 100 m (300 ft) 174 feet SURVEY RUNNING TIME Rig up 11/15/2014 12:00:00 PM Rig down 11/15/2014 12:10:00 PM Start Inrun 11/16/2014 10:16:00 AM Field Survey Presented 11/15/2014 12:10:00 PM End outrun 11/16/2014 12:10:00 PM Lost Time Comments SURV-Q163 December 2011 Page 1 of 2 Created:16-Dec-15 12:26 AK1114GCM201 1 • Survey QC - RGS-CCContinuous Specification Sheet gYiMidatia 110111111111111110. M ACCEPTANCE SUMMAR`` Accept NAME AND DATE Yes/ No Pre-job calibration verification (roll test) `ft Click here to enter text. Gyro Verification (Advanced Initialisation) VI Accelerometer verification (G-Total Test) YES Operating temperature within calibration range (+/- 2.5°) YES SIGNATURE Continuous Drift Correction YES Click here to enter text. Continuous Misalignment Correction N/A Depth Control Individual Station Report YES Note : Any modifications or amendments to this sheet must be reported to the client representative and the Gyrodata survey focal point. SURV-Q163 December 2011 Page 2 of 2 Created:16-Dec-15 12:26 AK1114GCM201 RECEIVED STATE OF ALASKA APR 0 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOGJGCC la. Well Status: ❑Oil El Gas ❑SPLUG 0 Other ®Abandoned ❑Suspended 1b. Well Class 20AAC 25 105 20AAC 25.110 0 Exploratory El Stratigraphic CI GINJ ❑WINJ ❑WAG El WDSPL El Other No.of Completions_ Zero ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp.,pr Aban> 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 3/13/2015 204-023 - 315-035 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 3/1/2004 50-029-20498-02-00 ' 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: - 3/9/2004 PBU 17-04B 2486' FNL, 450' FWL, Sec.22,T1ON, R15E, UM 8. KB(ft above MSL): 63 15. Field/Pool(s) Top of Productive Horizon: 129' FNL, 1707' FEL, Sec.28, T1ON, R15E, UM GL(ft above MSL): 34.3' • Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 377' FNL, 3327' FEL, Sec.28, T1ON, R15E, UM 10520' , 8998' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 708703 • y- 5928144 • Zone- ASP4 12048' • 9009' ' ADL 028331 &028334 TPI: x- 706634 y- 5925163 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 705021 y- 5924871 Zone- ASP4 None 18. Directional Surve Y ❑Yes ® No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD, DIR, GR, PWD, RES, AIM 6829' • 6273' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 32' 112' 32' 112' 32" 390 sx Arcticset II 13-3/8" 72# L-80 32' 2606' 32' 2606' 17-1/2" 1975 sx Fondu, 400 sx Permafrost II 9-5/8" 47# L-80/S00-95 29' 6829' 29' 6273' 12-1/4" 800 sx Class'G', 300 sx PF'C' 7" 26# L-80 6696' 10322' 6185' 8885' 8-1/2" 184 sx Class'G' 4-1/2" 12.6# L-80 10157' 12048' 8759' 9009' 6-1/8" Uncemented Slotted Liner 24. Open to production or injection? 0 Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#, L-80 10168' 10111'/8724' - '•I` .et•4,...•.,.4.:, 26. ACID,FRACTURE,CEMENT SQUEEZE, ETC. SNNF,p MAY 2 0 2015 : �5 WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No - FDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED rJt1' 1. `s.-�,1 10520' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing, Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ® No • Sidewall Core(s)Acquired? ❑Yes ® No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each), and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips,photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 v`F CONTINUED ON REVERSE Submit Original Only 57/0//5- ,/Y/ RBDMS.� APR - 9 2015 4 & . ..,,\7 -i�; -`7G 29. GEOLOGIC MARKERS(List all formations at rkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Coleville Mudstone 9319' 8123' None HRZ 9749' 8453' Base of HRZ 9978' 8625' Top JB 10082' 8702' Top JA 10206' 8796' Sag River 10330' 8891' Shublik 10365' 8915' Shublik B 10394' 8934' Shublik C 10425' 8953' Sadlerochit 10500' . 8990' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Trevor Hyatt,564-4627 Email: Trevor.Hyatt@bp.com Printed Name: Joe Lastu a Title: Drilling Technologist / Signature: A. Phone 564-4091 Date: `q/24 15 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only 17-04B, Well History (Pre-Rig Sidetrack) Date Summary 02/11/15 DRIFTED W/20'x 3.70" DUMMY WHIP STOCK W/ 1.75" SAMPLE BAILER TO 9641' SLM&WORKED T 9,757 SLM, PUH & LOSE WHIP STOCK. ATTEMPTED TO PULL DUMMY WHIP STOCK W/4-1/2" GR FROM 9,905' SLM. 02/12/15 RAN 3.70" CENT, 2'x 1-7/8"STEM, 3.75"CENT, 3.75" LIB TO 9,805' SLM (inconclusive impression). RAN 4-1/2" BRUSH W/2.50" SAMPLE BAILER TO 9,831'SLM (recovered -2 cups of paraffin). ATTEMPTED TO PULL DUMMY WHIP STOCK FROM 9,831' SLM W/4-1/2" GR. RAN 2.80" CENT, 10' x 2.5" PUMP BAILER TO 9,559' SLM (recovered -1-1/2"qts of paraffin). ATTEMPTED TO PULL DUMMY WHIP STOCK FROM 9,849' SLM W/4-1/2" GR. 02/13/15 MADE 3 RUNS W/ 11'x 3.50" PUMP BAILER TO 9,880'SLM TO 9950'SLM (recovered-9 gallons of solid paraffin). NOTE: 20'x 3.70" DUMMY WHIPSTOCK FELL FROM 9950' SLM TO 10,286' SLM LRS PUMPED 5 BBLS METH, 30 BBLS DIESEL,30 BBLS XYLENE,140 BBS CRUDE. 02/13/15 T/I/0=525/489/137 Pump 5 bbl neat spear folowed by 30 bbls 180 deg dsl 30 bbls dsl/xyl and 140 bbls crude. 02/14/15 Assist slickline .Pumed 107 bbls crude and 29 bbls of diesel down tubing as directed. Pumped 5 bbls crude to pre test plug set to 1000 psi. CMIT TXIA to 2500 PASSED (see mit data) Pumped 8,7 bbls crude to resach test pressure bled well back to 100 rig down (slickline on well has control annulus valves open to gauges) (fluid packed tags hung on IA and wing placard on master) FWHP=84/117/150. 02/14/15 FISHED LOST 3.70" DUMMY WHIPSTOCK FROM 10,286' SLM. BRUSHED TUBING & NIPPLES FROM 9,500' SLM TO 10,556' SLM W/4-1/2" BRUSH &3.70"G-RING WHILE LRS PUMPED 60 BBLS CRUDE&20 BBLS DIESEL. SET 4-1/2"XXN PLUG IN XN-NIP AT 10127'SLM/10156' MD PULL BK-DGLV FROM STA#1 AT 9527' MD/9558' MD. LRS PERFORMED PASSING PRESSURE TEST T. x I.A. 02/14/15 CTU#6- 1.75"CT. Job Scope: Circ Out, Pull TTP, Mill NX Nip. Standby for slickline to complete work. 02/15/15 CTU#6- 1.75"CT. Job Scope: Circ Out, Pull TTP, Mill NX Nip, Dummy WS drift. Standby for slickline to complete work and Wells Support to RU hardline. MIRU. RIH with 2.67"JSN for circ out. Park coil at 10100'and circulate 640bbIs of slick 1% KCI BU taking comingled returns from the tubing and IA to Well 17-21. Flow check the Tbg and IA independently and confirm 8.3ppg water returns. Line up and FP IA w/ 144bbIs of diesel while POOH. Lay in 60/40 methanol from 2500'. MU BKR fishing BHA w/4" GS spear. 02/16/15 CTU#6- 1.75" CT. Job Scope: Circ Out, Pull TTP, Mill NX Nip, Dummy WS drift. MU BKR fishing BHA w/4"GS spear. RIH and latch XXN plug at 10153'ctm/10156'MD. Hit 3 jar licks down and pulled plug free. POOH. Recovered XXN plug (missing 5 elements). MU BKR 3-1/8" motor w/3.80"string reamer& diamond parabolic mill. RIH and mill XN nipple at 10151'. Drift to 10,650'with milling BHA. POOH. Freeze protect well with 38bbls diesel capped with 5bbls 60/40 MEOH. RIH with 3.780" Dummy Whipstock drift to 10,650'. POOH. RDMO. 02/23/15 RAN 20'x 3.70" DMY WHIPSTOCK TO 10,303' SLM (unable to pass). 03/04/15 T/I/0=87/150/0. Pre CTD, Install TS-03, set 5" ISA BPV#537, and install temp#63 on IA. Final WHP's 0/150/0. Page 1 of 2 17-04B, Well History (Pre-Rig Sidetrack) Date Summary 03/04/15 T/I/O= BPV/18/145.Temp=SI. MIT-OA to 1200 psi (Pre CTD). No well house, FL or AL. Drilling schaffolding is installed around well. OA FL @ 50',2.9 bbls. 03/05/15 T/I/O= BPV/18/145.Temp=Sl. MIT-OA PASSED to 1200 psi (Pre CTD). OA FL @ 50',2.9 bbls. Bled OAP to 18 psi, FL unchanged. Used 3.5 bbls of diesel to reach test pressure of 1202 psi. OA lost 49 psi in 1st 15 min and 16 psi in 2nd 15 min,for a 30 min total loss of 65 psi. Bled OAP to 0 psi in 30 min w/1 bbls of returns. Monitor OAP for 30 min. OAP unchanged.AFE tags hung on OA casing and WV's.Job complete. Final WHPs=BPV/17/0. SV/WV/SSV=Closed. MV=Open. IA,OA=OTG. NOVP(0500 hrs). Page 2 of 2 North America-ALASKA-BP Page 1 a Operation Summary Report Common Well Name:17-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/10/2015 End Date: X3-016PH-C:(3,120,065.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:NORDIC 1 Spud Date/Time:8/28/1980 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292049800 Active datum:DS17-04B @63.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/10/2015 11:00 - 11:30 0.50 MOB P PROD1 HOLD PJSM FOR MOVING OFF WELL 11:30 - 12:30 1.00 MOB P PROD1 MOBILIZE RIG OFF WELL AND STAGE ON PAD 12:30 18:00 5.50 MOB P PROD1 NORDIC PERFORM PLANNED MAINTENANCE TO CHANGE OUT LOWER RAM BODY 18:00 - 19:00 1.00 MOB P PROD1 NORDIC AND CH2M HILL CREW CHANGE 19:00 - 19:30 0.50 MOB P PROD1 HOLD PJSM WITH NORDIC,BP AND CH2M HILL FOR MOVING RIG;STAGE RIG ON EDGE OF PAD AND WAIT ON SECURITY ESCORT "'AOGCC REPRESENTATIVE JOHNNIE HILL WAIVED WITNESS TO BOP TEST ON 3/10/2015 @ 1927 HOURS*** 19:30 - 22:00 2.50 MOB N WAIT PROD1 WAIT ON SECURITY ESCORT 22:00 - 00:00 2.00 MOB P PROD1 MOBILISE RIG TO 17-04 3/11/2015 00:00 - 06:00 6.00 MOB P PRE MOBILIZE RIG TO 17-04 06:00 - 08:30 2.50 MOB P PRE MOVE RIG ONTO DS 17 -SET T-MATS AROUND WELL -OPEN WELL WORK TRANSFER WITH PAD OPERATOR -VERIFY IA/OA PRESSURE ZERO -POSITION RIG FOR PULLING OVER WELL -HELD PJSM WITH NORDIC SUPERINTENDANT,WSL,TOOLPUSHER& CREW FOR PULLING OVER WELL -PULL OVER WELL "'ACCEPT RIG ON 03/11/2015 @ 08:30 HRS 08:30 - 10:30 2.00 MOB P PRE RIG UP EQUIPMENT ON LOCATION -SPOT ANCILLARY EQUIPMENT -INSTALL GUARDS ON EQUIPMENT IN CELLAR -RU SENSORS ON IA/OA LEAK TIGHT TEST/REMOVE TREE CAP 10:30 - 17:00 6.50 MOB P PRE NIPPLE UP BOP -RU HARDLINE TO TIGER TANK -INSTALL INJECTOR RISER FILL BOP STACK WITH WATER 17:00 - 17:30 0.50 MOB P PRE PERFORM RIG EVAC/H2S DRILLS -HOLD PRE-SPUD MEETING WITH CREW 17:30 - 18:30 1.00 BOPSUR P PRE SHELL TEST BOP PRESSURE TEST 250 LOW/4000 HIGH 18:30 - 19:00 0.50 BOPSUR P PRE CREW CHANGE -CONDUCT WALK AROUNDS -INSPECT EQUIPMENT REVIEW PJSM FOR TESTING BOP 19:00 - 21:00 2.00 BOPSUR P PRE SHELL TEST FAIL;PULL RAMS,INSPECT AND CHANGE OUT COMB!DOOR SEALS Printed 3/16/2015 12:40:25PM • North America-ALASKA-BP Page 2 Operation Summary Report Common Well Name:17-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/10/2015 End Date: X3-016PH-C:(3,120,065.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:NORDIC 1 Spud Date/Time:8/28/1980 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292049800 Active datum:DS17-04B©63.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 BOPSUR P PRE TEST BOP TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES PER AOGCC,BP,NORDIC AND PTD#204-023 "'TEST MANUAL LOCKDOWN SCREWS ON NEW VBR AND LOWER COMBI RAMS*** STATE GIVEN NOTIFICATION OF BOPE TEST 03/10/2015 01:18 AM STATE INSPECTOR JOHNNIE HILL WAIVED WITNESS 03/10/2015 AT 19:24 PM 3/12/2015 00:00 - 03:30 3.50 BOPSUR P PRE CONTINUE TESTING BOP TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES PER AOGCC, BP,NORDIC AND PTD#204-023 STATE GIVEN NOTIFICATION OF BOPE TEST 03/10/2015 01:18 AM STATE INSPECTOR JOHNNIE HILL WAIVED WITNESS 03/10/2015 AT 19:24 PM 03:30 04:00 0.50 BOPSUR P PRE HOLD RIG EVACUATION AND H25 DRILL WITH II NORDIC,CTD AND BP 04:00 - 05:00 1.00 BOPSUR P PRE CONTINUE TESTING BOP TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES PER AOGCC, BP,NORDIC AND PTD#204-023 STATE GIVEN NOTIFICATION OF BOPE TEST 03/10/2015 01:18 AM STATE INSPECTOR JOHNNIE HILL WAIVED WITNESS 03/10/2015 AT 19:24 PM 05:00 - 06:30 1.50 BOPSUR P PRE TEST INNER REEL VALVE/PACK-OFF -HOLP PJSM WITH NORDIC,CTD AND BP -CUT COIL CONNECTOR,BOOT ELINE,STAB ON INJECTOR -PRESSURE TEST INNER REEL VALVE/ PACK-OFF TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 06:30 - 12:00 5.50 BOPSUR P PRE E-LINE SLACK MANAGEMENT -REVERSE CIRCULATE COIL AND PUMP SLACK BACK TO REEL -CUT 300'COIL -INSTALL SLB COIL CONNECTOR -PULL TEST PRESSURE TEST CONNECTION -HEAD-UP WITH BHI 12:00 - 15:00 3.00 BOPSUR P PRE PULL BACK PRESSURE VALVE -INSPECT LUBRICATOR CERT'S/EQUIPMENT -LOAD LUBRICATOR INTO PIPE SHED -HELD PJSM FOR PULLING BPV -MU LUBRICATOR ONTO RISER -PRESSURE TEST 250 LOW/3500 HIGH -PULL BPV/ 89 PSI UNDER BPV -RD LUBRICATOR/INSTALL NIGHT CAP 15:00 - 17:30 2.50 BOPSUR P PRE BULLHEAD KILL WELL PER PLAN -HELD PJSM FOR KILLING WELL -PUMP 5 BBLS AHEAD OF NEAT METHANOL, -PUMP 240 BBLS 1%KCL, -PUMP 40 BBLS 8.6 PPG HIGH VIS PILL, -PUMP 116 BBLS 8.6 PPG POWER PRO -BPM: 4.75 INITIAL WHP: 333 END WHP:284 17:30 - 18:00 0.50 BOPSUR P PRE FLOW CHECK Printed 3/16/2015 12:40:25PM • North America-ALASKA-BP Page 3 ot�9 Operation Summary Report Common Well Name:17-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) • Start Date:3/10/2015 End Date: X3-016PH-C:(3,120,065.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:NORDIC 1 Spud Date/Time:8/28/1980 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292049800 Active datum:DS17-04B @63.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - (usft) 18:00 - 20:00 2.00 BOPSUR N WAIT PRE FILL HOLE WELL TOOK 15 BBLS TO FILL BEFORE RETURNS WERE SEEN -1 HR PVT LOSS RATE:PVT START=131,PVT END= 81,STATIC LOSS RATE=50 BPH -MW IN/OUT:8.51 PPG/8.6 PPG -INITIAL BPM IN/OUT:1.87/0.38 i••"ADJUST FLOW RATES ACROSS TOP OF WELL TO MINIMIZE LOSSES. -REDUCED IN RATE BPM IN:1.2 BPM OUT: 0.57.LOSSES -AVG LOSS 45-50 BPH 20:00 - 23:30 3.50 BOPSUR N WAIT PRE CONTINUE TO KEEP HOLE FULL. SWAP TO KCL.ARRANGE TRUCKS TO ROUNDTRIP FOR FLUIDS AND WAIT ON POLYSWELL OCN. 23:30 - 00:00 0.50 BOPSUR N DPRB PRE HOLD PJSM FOR PUMPING POLYSWELL PILL. 3/13/2015 23:30 - 00:00 0.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.79/2.49 -FREE SPIN:1550 PSI MOTORWORK:200 PSI MW IN/OUT:8.39 PPG/8.39 PPG WOB:2.5K -PVT LOSSES=20 BPH 00:00 - 01:00 1.00 BOPSUR N DPRB PRE PUMP 32 BBL POLYSWELL PILL,FOLLOWED BY 150 BBLS 1%KCL PER OCN#3. 01:00 - 02:00 1.00 BOPSUR N DPRB PRE PUMP ACROSS TOP TO KEEP HOLE FULL. MONITOR WELL FOR LOSS RATE. 1 HOUR PVT LOSS RATE=13 BPH. RIG UP FOR SLACK MANAGEMENT. 02:00 - 02:30 0.50 BOPSUR P PRE HOLD PJSM FOR MAKING UP WHIPSTOCK BHA. 02:30 - 04:00 1.50 BOPSUR P PRE PUMP SLACK FORWARD.TEST COIL CONNECTOR AND DUAL CHECKS. MU 4-1/2" BAKER MONOBORE WHIPSTOCK BHA. 04:00 - 07:00 3.00 WHIP P WEXIT RIH WITH WHIPSTOCK SETTING BHA#1. STATIC LOSSES DECREASED TO 5 BPH PRIOR TO RIH. 07 00 - 08:00 1.00 WHIP P WEXIT LOG TIE-IN -DEPTH CORRECTION(-21') -LOG CCL PRIOR TO WHIPSTOCK SETTING _ I VERIFY SETTING LOCATION FROM CCL LOG 08:00 - 08:30 0.50 WHIP P WEXIT I SET WHIPSTOCK PER BOT PROCEDURES -TOP OF WHIPSTOCK @ 10,520'MD -BOTTOM OF WHIPSTOCK©10,532'MD -PRESSURE UP TO 3060 PSI AND RELEASE FROM WHIPSTOCK -SET DOWN 5K ON WHIPSTOCK TO CONFIRM GOOD SET 08:30 - 10:30 2.00 WHIP P WEXIT POOH WITH WHIPSTOCK RUNNING TOOLS -BPM IN/OUT:1.84/1.18 CIRC PSI:535 -MW IN/OUT:8.37 PPG/8.38 PPG -CONSTANT LOAD OF POLYSWELLACROSS SHAKERS 10:30 - 12:00 1.50 WHIP P WEXIT CHANGE OUT BHA -FLOW CHECK(GOOD) -LD WHIPSTOCK RUNNING TOOLS -MU MILLING BHA/GET ON WELL PRESSURE TEST QTS(GOOD) Printed 3/16/2015 12:40:25PM • North America-ALASKA-BP Page 4pray Operation Summary Report Common Well Name:17-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/10/2015 End Date: X3-016PH-C:(3,120,065.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:NORDIC 1 Spud Date/Time:8/28/1980 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI:500292049800 Active datum:DS17-04B @63.00usft(above Mean Sea Level) - Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 14:30 2.50 WHIP P WEXIT RIH WITH MILLING ASSEMBLY -BPM IN/OUT:0.52/0.75 -MW IN/OUT:8.34 PPG/8.4 PPG 14:30 - 15:00 0.50 WHIP P WEXIT LOG TIE-IN DEPTH CORRECTION(-18.5) -RECORD SLOW PUMP RATES 15:00 - 18:00 3.00 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN - DRY TAG PINCH POINT AT 10,523.5'MD • wv� -PUMP ON PINCH POINT AT 10,522.5'MD 11.014CI -START MILLING OPERATIONS AT 10.521.5' 1 MD -BPM IN/OUT:2.93/2.46 CIRC PSI:1392 -MW IN/OUT:8.39 PPG/8.26 PPG "`FIRST TAG WITH PUMPS ON STALLED MOTOR USING NEW HCC 3.8"IR112E. DIFFICULT TO START MILLING OPERATION AT PINCH POINT.PICK UP 1'ABOVE PINCH POINT AND BEGIN MILLING OPERATIONS. 18:00 - 19:30 1.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.71/2.36 -FREE SPIN:1350 PSI MOTORWORK:100 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:0.8K -PVT LOSSES=20 BPH 19:30 21:00 1.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.85/2.54 -FREE SPIN:1550 PSI MOTORWORK:450 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:2.8K -PVT LOSSES=20 BPH 21:00 - 22:30 1.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.78/2.46 -FREE SPIN:1550 PSI MOTORWORK:230 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:1.7K -PVT LOSSES=20 BPH 22:30 - 23:30 1.00 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.79/2.49 -FREE SPIN:1550 PSI MOTORWORK:120 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:1.7K PVT LOSSES=15 BPH 3/14/2015 00:00 - 00:30 0.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.74/2.45 -FREE SPIN:1550 PSI MOTORWORK:180 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:2.2K -PVT LOSSES=20 BPH Printed 3/16/2015 12:40:25PM * North America-ALASKA-BP Page 5 of - Operation Summary Report Common Well Name:17-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/10/2015 End Date: X3-016PH-C:(3,120,065.00) Project:Prudhoe Bay Site:PB DS 17 Rig Name/No.:NORDIC 1 Spud Date/Time:8/28/1980 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292049800 Active datum:DS17-04B @63.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 01:00 0.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.75/2.46 -FREE SPIN:1550 PSI MOTORWORK:120 PSI MW IN/OUT:8.39 PPG/8.39 PPG -WOB:2.2K -PVT LOSSES=20 BPH 01:00 - 01:40 0.67 STMILL P WEXIT I MILL 3.80"WINDOW PER PLAN MILL STRATEGY:0.05 PER 3 MINUTES -BPM IN/OUT:2.78/2.48 FREE SPIN:1550 PSI MOTORWORK:175 PSI -MW IN/OUT:8.39 PPG/8.39 PPG WOB:2.1K -PVT LOSSES=17 BPH • 01:40 - 03:00 1.33 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.72/2.45 -FREE SPIN:1550 PSI MOTORWORK:200 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:1.0K -PVT LOSSES=17 BPH 03:00 - 04:30 1.50 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.73/2.43 -FREE SPIN:1550 PSI MOTORWORK:125 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:0.24K -PVT LOSSES=16 BPH *REACH BOTTOM OF WINDOW BASED OFF BOT SCHEMATIC 04:30 - 05:15 I 0.75 1 STMILL P WEXIT MILL 3.80"WINDOW PER PLAN -MILL STRATEGY:0.05'PER 3 MINUTES -BPM IN/OUT:2.71/2.46 -FREE SPIN:1550 PSI MOTORWORK:110 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:0.17K -PVT LOSSES=18 BPH *CONTINUE CONTROL MILLING,ALLOWING STRING REAMER TO PASS THROUGH AND DRESS OFF WINDOW 05:15 - 06:00 0.75 STMILL P WEXIT MILLING AND DRESSING OFF 3.80"WINDOW AND DRILL RATHOLE PER PLAN -BPM IN/OUT:2.67/2.40 -FREE SPIN:1550 PSI MOTORWORK:150 PSI -MW IN/OUT:8.39 PPG/8.39 PPG -WOB:0.30K -PVT LOSSES=16 BPH *10,531'SAMPLE CAME BACK WITH A SMALL AMOUNT OF FORMATION Printed 3/16/2015 12:40:25PM TREE= 5-1/16"OW " VVt3LhEAD FMC B SAR JOTES:WELL ANGLE MAX DOGLEG:2 9- 110645',70 ' 10536`':* AdTUATOR= AXELSON KB.ELEV= 69.78' /I I BF.H..EV= NA , 2210' 41/2 FES X NP D=3.813" KOP= 4250' Max Angle= 97°@ 11273' Datum tuff= 10286' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2983 2983 1 MING-M DMY RK 0 03/13104 'CONDUCTOR, #, •D= " -H ? 4 4102 4101 7 MMG-M DMY RK 0 08/11/14 3 6439 6018 50 MMG-M DMY RK 0 08/11/14 13-5/8'CSG,72#,L-80,D=12.347" H 2606' '2 7593 6806 42 KBG-2 "DMY BK 0 10/06/11 '1 9558 8309 40 KBG-2 DMY BK 0 10/06/11 Minimum ID = 3.80" @ 10156' 'TUBING LEAKS N BTM VAO MANDRELS @ 7593'&9558' 4-1/2" HES XN NIPPLE "STA#2=DMY HAS EX IDL )PACKNG 6696' H9-5/8"X 7"BKR ZXP LTP,ID=6.29' 9 5/8"?NOCK(XX/XX/04) ? ` 6713' H9-5/8"X 7"BKR HMC LNR HGR,ID=6.28" 9-5/8"CSG,47#,L-80,ID=8.681" H 6829' MLLOUT WLJDOW(17-04B) 6829'-6845' 10090' _4-1/2"HES X NP,ND=3.813' S 10111' H7"X 4-1/2"BKR S-3 PKR,D=?? ' • 10135' —141/2"HES XMP,D=3.813" 10156' —14-1/2"HES XN NP,MIL.LLED TO 3.80'(02/16/15) �1 10157' —7"X 5"BKR TttK SLV(6') 4-1/2"TBG,12.6#,L-80 BT-IW TCI H 10168' 1 w/HMG LNRtiGR ID=??" .0152 bpf,D=3.958' 10168' —14-1/2'WLEG,D=3.958" ? H5"X41/2"XO,D=3.958" 7"1 NR,26#,L-80 BTC-M,.0383 bpf,D=6.276" --� 10322' 4-1/2'BKR WHIPSTOCK(03/13/15) J— —10520 PERFORATION SUNRAARY I I I I REF LOG:BHCS ON??? I ANGLE AT TOP RETE:WA I I Note:Refer to Production DB for historical perf data I I SIZE SPF INTERVAL Opn/Sqz SEDT $C]7 I I I I 4-1/2" SLID 10348-12046 0 03/11/04 I I I I 4-1/2'LNR,12.6#,L-80 BT,.0158 bpf,ID=3.958" — 12048' 12046' FBTD DATE REV BY COMMBITS DATE REV BY COMtuU'TTS PRUDHOE BAY UMT 10/12/80 ORIGINAL COMPLETION 02/14/15 SFT/PJC STA#1 EMPTY MANDREL WELL: 17-04B 03/19/88 RWO 02/16/15 PJC STA#2 DMY HAS EXT PACKING PERMT No: 2040230 05/01196 IVES MULTI LAT ST(17-04A/All) 02/17/15 TTR/PJC14.1 XN/PLUG(02/16/15) AR No: 50-029-20498-02 03/13/04 N7ES RIG SIDETRACK(17-048) 02/17/15 T-VPJC TBG LEAKS N BTM TWO MANDRELS SEC 22,T1ON,R15E,2485'FNL&450'RAI._ 09/03/14 MGS/PJC PUL PATO ICS/NP RED(8/12-13/14 03/31/15 PJC SET WHPSTOCK(03/13/15) 09/03/14 MGS/PJC GLV C/O(08/11/14) BP Exploration(Alaska) • OF Tfj�(•-i-; \�����jy's� THE STATE Alaska Oil and Gas �, of Conservation Commission _ __ ALASIc:A s ,i iit ___, _- 333 West Seventh Avenue virt.tGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 : .T-, Main: 907.279.1433 ALApi S' 1.' P Fax 907 276.7542 www.aogcc.alaska.gov John McMullen � � �:;�- t,,, 5 L t.1,% Engineering Team Leader ' —0 BP Exploration(Alaska), Inc. `/-t" P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-04B Sundry Number: 315-035 Dear Mr. McMullen: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, f?4-.1t..4,V--- __ Cathy P. erster ,, Chair DATED this day of January, 2015 Encl. STATE OF ALASKA RECEIVED ALAS,.,,OIL AND GAS CONSERVATION COMMISSION JAN 2 2 2015 APPLICATION FOR SUNDRY APPROVAL r. f/z(S 20 AAC 25.280 AOGCC Type of Request: • ElAbandon ®Plug for Redrill ❑Perforate New Pool ❑ Repair Well ❑Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ❑ Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory 0 Stratigraphic 204-023 . 3. Address: 6. API Number: e,Alaska 99519-6612 ®Development ❑Service P.O. Box 196612,Anchorage, 50.029-20498-02-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool PBU 17-04B • Will planned perforations require a Spacing Exception? ❑Yes No 9. Property Designatior - 10.Field/Pool(s): ADL 028331 &028334 Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured) 12048' • 9009' • 12048' • 9009' • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32'- 112' 32'- 112' 1530 520 Surface 2574' 13-3/8" 32'-2606' 32'-2606' 4930 2670 Intermediate 6800' 9-5/8" 29'-6829' 29'-6273' 6870 4760 Production Liner 3626' 7" 6696'- 10322' 6185'-8885' 7240 5410 Slotted Liner 1891' 4-1/2" 10157'- 12048' 8759'-9009' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): Slotted Liner: 10348'- 12005' Slotted Liner:8904'-9006' 4-1/2", 12.6# L-80 10168' Packers and SSSV Type' 7"x 4-1/2"Baker S-3 Packer Packers and SSSV 10111'/8724' MD(ft)and TVD(ft): 12. Attachments. 13.Well Class after proposed work: 0 Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation. February 2,2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval. Date 0 Gas ❑GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Trevor Hyatt,564-4627 Printed Name: J. n ; /�' _„ Title. Engineering Team Leader Email. Trevor.Hyatt@bp.com Signatur . f'/ / Phone: 564-4711 Date' (/2 (715— YCommission Use Only Conditions of approval: Notify Commission so that a representative may witness ��r Sundry Number: `� 0 3 ❑Plug Integrity Lr BOP Test 0 Mechanical Integrity Test ❑ Location Clearance .--- Other 0 0 P tc574. fa 35--00p511/vlP5P 15 Zr,odt /)5' ) N - fVIvIvLaV pvcv—gtr fry 1500 p5 I - �4-G tt�� rc l vc� p1 t G r i,tZ-t h '1` <4_09 v,, v e-ci p r r ,2 U - — G Z5, / z l c J 03w U- Spacing Exception Required? 0 Yes et No Subsequent Form Required: `Q —40 L. APPROVED BY Approved By: COMMISSIONER THE OMMISSIONDate: / U) X30_ Q Form 10-403 Revised 10/ 12rO1fl3hNML° Till I for 12 months from the date of approval _/ Submit In Duplicate m l/TL 1/7--/1 5 /f,�1 /'..-z_ /O g44- ,,, ,./... i - ' fY To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt CI bp CTD Engineer Date: January 20, 2015 Re: 17-04B Sundry Approval Sundry approval is requested to plug the 17-04B slotted liner as part of the drilling and completing of the proposed 17-04C coiled tubing sidetrack. History of 17-04B: DS 17-04 was originally completed in October, 1980 as a Sag producer, but did not flow. It was SI until March, 1988 when a RWO to pull what was thought to be collapsed tubing was done, but found no collapsed tubing. The well was re- completed in Z4, but production rates were still low. The well remained SI because an asphaltene emulsion was suspected of causing upsets in process equipment. The well was sidetracked in March, 1996 with a 1500' horizontal section drilled in Z4, and a 1700' lateral drilled in the Sag. An isolation packer was set between the two so that contributions from each lateral could be determined. Tests before and after a plug set in the isolation packer showed no difference in rates indicating communication between Sag and Z4. The well was sidetracked again to 17-04B in March 2004 and completed with slotted liner. Reason for sidetrack: The well has low remaining value and no remaining wellwork. Proposed plan for 17-04C: Drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around March 5th, 2015 with Nordic 1. The sidetrack, 17-04C, will exit the existing 4- 1/2" slotted liner and kick off in Zone 4. This sidetrack will be completed with a 3-1/2" x 2-7/8" 13Cr solid liner, cemented in place. This Sundry covers plugging the existing 17-04B slotted liner via primary liner cement job and 17-04C liner top packer (if the liner lap pressure test fails) (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. �r �u/P ell �y ✓� l o CO 6t/4 � P714:614e):7 q / ‘ta2 well 's u�•t .4 (A,17.4 q !!? i/ca PL 60'`f fe refetJ 7*e Pacf/1,90 4'' r4 e i t f Pre-Rig Work (scheduled to begin February 2nd, 2015) 1. S Drift for 4-1/2" Mono-Bore Whipstock to deviation. 2. E Mill XN-nipple at 10,156' MD to 3.80". 3. E Set 4-1/2" Mono-Bore Whipstock at 10,520' MD. • 4. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 5. 0 Remove wellhouse and level pad. 6. V Set BPV & leave for the rig. Rig Work (scheduled to begin March 5th, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (2,689 psi MASP). 2. Mill 3.8" window at 10,520 MD and 10' of rathole. 3. Drill build section: 4.25" OH, -450' (30° deg/100 planned). 5. Drill lateral section: 4.25" OH, -2560' (12° deg/100 planned) with resistivity. 6. Run 3-1/2" x 2-7/8" 13Cr liner leaving TOL at 10,150' MD. Pump primary cement leaving TOC at TOL (-10,150' MD), 35.8 bbls of 15.8 ppg 7.* liner cmt planned. 8. Perform liner cleanout with mill, motor and GR/CCL log. 9. Perforate liner based on log interpretation (-500' of perfs) 10. Freeze protect well to 2500' MD 11. Set BPV, RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set liner top packer with Slickline (if needed) & test to 2,500psi. 3. Set generic GLV's, SBHPS, ASRC flow back, SIT. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 TREE=. 5-1/16"CNV MELLF EAD= FMC 17-04B SAFETY NOTES:WELL ANGLE>700 @ 10536'. •ACTUATOR= AXELSON KB EEV= 69.78' BF.ELEV= NA I [ . KOP= 4250' 2210' —{4-1/2"HES X NP,D=3.813" Max Angle= 97°@ 11273' Datum MD= 10286' GAS T MAM3 S Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE OOCONDUCTOR ? 5 2983 2982 1 MMKrUFT OM'( l ( 0 03/13/04 2 4 4102 4100 7 MMG M OMY RFC 0 08/11/14 3 6439 6011 50 MIAG-M DMY RK 0 08/11/14 13-5/8"CSG,72#,L-80,13=12.347' --I 2606' 2 7593 6802 42 KBG-2 DMY BK 0 10/05/11 1 9558 8312 40 KBG-2 DMY BK 0 10/05/11 Minimum ID =3.725" @ 10156' 4-1/2" HES XN NIPPLE L i6696' —I9-5/8"X 7"BKR ZXPLTP,D=6.29" 9-5/8"?WHPSTOCK(XX/XX/04) —1 ? -- J 6713' —19-5/8"X 7"BKR HMC LICHGR,D=6.28" 9-5/8"CSG,47#,L-80,D=8.681" —1 6829' I\ MLLOUT WI4DOW(17-046) 6829'-6845' / PERFORATION SUMMARY ' I 10090' —14-1/2"HES X NP,D=3.813" REF LOG:BHCS ON??? ANGLE AT TOP PERF:NA >l< LE10111* Hr X 4-12"BKR S-3 FKR ID=?? Note:Refer to Production DB for historical perf data SIZE SPF t1TERVAL Opn/Sgz DATE ' 10135' H4-1/2"FES X NP,ID=3.813" 4-12" SLID 10348- 12046 0 03/11/04 ' {_ 10156' I—4-1/2"HES XN NP,D=3.725" 10157' 7"X 5"BKR TFFBK SLV(6') 41/2"TBG,12.64,L-80 ST-MI TCI, — 10168' I--- w/MAC LW FIGID=??" i 0152 bpf,D=3.958' L 10168' —14-1/2"WLE1G,D=3.958" ? —{5'X 412"XO,13=3.958" 7"LM,26#,L-80 BTC-M,.0383 bpf,D=6.276" —1 10322' IJ , I 1 I I I I I I I I I I I i FB1D — 12046' 1 412"UV2,12.6#,L-80 BT,.0158 bpf,D=3.958" -I 12048' l DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/80 ORIGINAL COMPLETION 08/08/12 FO/JM) PBTDTYFO(08/03/12) WELL: 17-04B 03/19/88 RWO 09/03/14 MGS/PJC RLL PATCFES/NP R110(8/12-13/14) PERMIT No:82040230 05/01/96 N2ES MULTI LAT ST(17-04A/AL1) 09/03/14 MGS/PJC GLV CIO(08/11/14) AR No: 50-029-20498-02 03/13/04 N7Pr5 RIG SIDETRACK(17-04B) SEC 22,T1ON,R15E,2485'FTI_&450'FVVL 05/24/12 GJF/JMD GLV C/O(05/22/12) 1 05/24/12 GJF/JM)PULL®XX PLUG(05/23/12) BP Exploration(Alaska) TREE_ 5-1/16"CNV 17 0 4 C W ILFEAD= FMC SAFEI JTES:WELL ANGLE>70°@ 10536'"' •ACTUATOR=. AXELSON PROPOSED MAX DOGLEG:21.9°@ 10645'"' KB BEV= 69.78' BF.ELEV= NA2210' H4-1/2"I£S X NP,0=3.813'_ Max Angle= 970 @ 1127 20"CONDUCTOR -i 110' Datum MD= 10286' 94#,F-40 _ ' ST MD GAS LFT MAN Datum TVD= 8800'ss D=19.124 TVD DEV TY PE VLV LATCH POR DATE 5 2983 2983 1 Mu1GM DAA1'DRELS RK 0 03/13/04 13-5/8"CSG,72#,L-80 BTRS R3,D=12.347" I-2606' 4 4102 4101 7 MM3-M DUN RK 0 08/11/14 3 6439 6018 50 MMG-M DMY RK 0 08/11/14 9-5/8"X 7"BKR ZXP LIP,D=6.29" 6696' L 2 7593 6806 42 KBG-2 DMY BK 0 10/06/11 9-5/8"X 7'BKR FMC LNR HGR,D=6.28" -6696 1 9558 8309 40 KBG-2 DMY BK 0 10/06/11 9-5/8"WHPSTOCK(XX/XX/04) H ? I9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 6829' MLLOUT WIM)OW(17-04B) 6829'-6845' / Minimum ID =2.377" @ 10510' 3-1/2" x 2-7/8" LNR XO _ I 1-- I 10090' H4-1/2"HES X NP,D=3.813" - z X. 10111' H7"X 4-1/2"BKR S-3 PKR,D=?? ' • 10135' -14-1/2"FES X NP,D=3.813" -10150 - 3.70"DEPLOY SLV,D=3.00" TOP OF 3-1/2"X 2-7/8"LNR(CEMENTS)) -10160 H3-1/2" X NP,D=2.813' y - i --I 10156' -14-1/2"HES XN NP,MLLE)TO 3.80"(XX/XX/15) a 10157' -17"X 5"BKR TEBK SLV(6')w/HMC LNR HGR,D=??" pr-,3I, ►t 4-1/2'TBG,12.6#,L-80 BT-M, 10168' -7 `1 10168' 4-1/2"WLEG,D=3.958" 0152 bpf,D=3.958' I I I ? --I 5"X 4-1/2'XO,ID=3.958" LI 17"LMR,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 10322' + r , 3-1/2"LNR-#,13CR- , -1 -10510 + .0087 bpf,0=2.992' ' 4-1/2"BKR WHIPSTOCK(XX/XX/15) H -10520 ►. • �` -10510 -13-1/2"X 2-7/8"XO,D=2.377' [4-1/2'LNR 12.6#,L-80 BT,.0158 bpf,D=3.958" H -10520 ; ,+ I ► N AMLLOUT WDOW(17-04C) -10520'- FBFFORATION SU MMRY I • y� REF LOG: ANGLE AT TOP PERF:_°@ ' I • • Note:Refer to Production DB for historical perf data I. -12-7/8"SHORT PUP JOINT w/RA TAG SEE SPF NTERVAL Opn/Sgz SHOT SCiZ 4 4 I • -12-7/8"SHORT PUP JOINT w/RA TAG •I • I • H PBT) 1 2-7/8'LNR,_#,13CR-_ , H -13530 I'1‘I.‘ .0058 bpf,D=2.441" DATE REV BY COMMENTS 1DATE REV BY COMMENTS PRUDHOE BAY INT 10/12/80 ROW 35 ORIGINAL COMPLETION 01/12/15 PJC LOCATE TALLIES&FNALVE PROP WELL: 17-04C 03/19/88 RWO FERMI No: 05/01/96 WEB MULTI LAT ST(17-04A/AL1) API ND: 50-029-20498-03 03/13/04 N7ES SIDETRACK(17-04B) SEC 22,T10N,R15E,2485'FN..&450'FWL XX/XX/15 CTD SIDETRACK(17-04C) _ _ 101/09/15 PJC BU1_D FROPOSAI BP Exploration(Alaska) or e r © 'llv I- 1101 � 2 LL I d I n Qg. 0. Ili U $_ I5 E S LL 0 1 I 1- INE 4° t• _ f 2 I111 II 1 m- . s V m ir i m . M i 41 (. m F i a • 0 0 ' U .a..„, Ii i m Ci f d 6 C V a $ _ = 1 Om aa , Q o1 • I m 6 o � 1 I II : I i iI O 1111 11. O§, ) I un In — U S99 r I t o —\ 0 - 0 r Z I I c: ® '31913 1111 u H III n III I 1I� 0u, I °° - 0 0 P '; - , I 8 Iil 111 J0 p =0 I. U § � ki ° 10 N a 1 "'Iai E q • 11 U j M ■ _ Il * ��d� ' � J s E W Ce Iti F11 a a V LLIr o II 3 Y t 01 ffi== =i i I 2 Ia V cc C9 m Ce a NM 0)1 — N »• H_ Q I $: U I 1 Ci m' I y ce l I Mill Zi0 jg ILI i : I y 1Ii v 1 I 11 I11 C a C gRIS W P I ,. 111 _ c 1 I11 g I i Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" —' boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work)the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states"Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. e e 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. ~ () 1J - 0 ~3 Well History File Identifier Organizing (done) o Two-sided III" 111111" 111111 o Rescan Needed "I II III11I II 11111I RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. ~ o Other, Noffype: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: BY: o Other:: Date tj-f¡'l /()~ Date lJ/ 17 /~(;z d..... + 3 = TOTAL PAGES~ (Count does not include cover sheet) /5/ /5/ 'VJJ1l BY: ~ Project Proofing III 11111111 11111111 BY: ~ /5/ wtfJ Scanning Preparation Date: Production Scanning Stage 1 Page Count from Scanned File: ..i.a.J¡:- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY ~ Date 4-/'7100 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111/111111111 11111 /5/ NO 'YVl f NO BY: Maria Date: /5/ 11I11111111I" /111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: /5/ Comments about this file: Quality Checked 1/1 "1111111 "11111 1 0/6/2005 Well History File Cover Page.doc • • • RECEIVED STATE OF ALASKA ,JUN 12 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L( Repair Well L Plug Perforations IA Perforate LJ Other U Tubing Patch Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension Ill 7585' -7605' Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 9554 ' - 9569 ' 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ 204 -023 3. Address: P.O. Box 196612 Stratigraphic III Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 20498 -02 -00 7. Property Designation (Lease Number): VI 4l 'a. 8. Well Name and Number: d ADL 028334 3r PBU 17 -04B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12048 feet Plugs measured NONE feet true vertical 9 017 feet Junk measured NONE feet Effective Depth measured 10246 feet Packer measured 6696, 10111 feet true vertical 8833 feet true vertical 617 9, 8730 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 20" 94# H -40 40' -110' 40' -110' 1530 520 Surface 2567' 13 -3/8" 72# L -80 39' -2606' 39' -2606' 4930 2670 Production 6791' 9 -5/8" 47# L -80 38'-6829' 38' -6267' 6870 4760 Liner 3626' 7" 26# L -80 6696'- 10322' 6179' -8890' 7240 5410 Liner 1891' 4 -1/2" 12.6# L -80 10157'- 12048' 8765' -9017' 8430 7500 Perforation depth Measured depth SEE ATTACHED feet �� True Vertical depth feet a 1j a i' ' 2 4 2.n Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12 .6# L -80 37' - 10168' 37' -8773' 7" BKR ZXP LTP 6696' 6179' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 10111' 8730' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 84 900 2 92 9 411 Subsequent to operation: 101 947 3 611 272 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development © Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ' © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name Ni u Ale a s Title Petrotechnical Data Technician /A/ Signatur- �� 40r irigrAM ��i�_ Phone 564 -4035 Date 06/12/2012 , 1. F I 7/46- DMS JUN 13 201 Submit Original Only Form 10-404 Revised 11/ 3/ 1 1 9 Y 17 -04B 204 -023 PERF ATTACHMENT Sw Nam a Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 17 -04B 3/11 /04 10,322. 12,048. 8,890.39 9,016.79 17-04B 10/6/11 BPS 10,156. 12,048. 8,764.2 9,016.79 17 -04B BPP 10,156. 12,048. 8,764.2T 9,016.79 i 17-04B t 4/19/12' BPS 10,156. 12,048. 8,764.2 9,016.79 17-04B 5/23/12 BPP 10,156. 12,048. 8,764.2 9,016.79 AB IABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER j BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEA K STO 'STRADDLE PACK, OPEN OH OPEN HOLE 1 • • • 17 -04B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE 1 4/18/2012 ** *WELL SHUT IN ON ARRIVAL * ** (Patch Tbg /Liner) PULLED 4 -1/2" XXN PLUG FROM XN NIPPLE (a 10,139' SLM BRUSFFXN NIP & PATCH SETTING DEPTHS @ 7585' -7605' MD, 9954' -9569' MD RAN SBHPS AS PER PROGRAM (GOOD DATA) * * *CONT WSR ON 4- 19 -12 * ** 4/19/2012 * * *CONT WSR FROM 4- 18 -12 * ** (Patch Tbg /Liner) COMPLETE SBHPS AS PER PROGRAM (good data recorded on 4 -18 -12 AWGRS) DRIFT TO 9600' W /20' x 3.70" DUMMY WHIPSTOCK SET 4 -1/2 XN x 2 -7/8 X NIPPLE REDUCER IN XN NIPPLE @ 10137' SLM/10156' MD (2nd lock down, no eq dev) RAN CHECK SET TO 4 -1/2 x 2 -7/8 NIPPLE REDUCER, CHECK SET SHEARED (good set) SET 2 -7/8 XX PLUG IN NIPPLE REDUCER @ 10156' MD (8 x 3/16 eq ports) ATTEMPT TO CMIT TO 3000psi, RESULTS INCONCLUSIVE ** *WELL LEFT S /I, DSO NOTIFIED * ** 4/22/2012 T /I /O = 470/450/90. Temp = SI. CMIT -TxIA to 3000 psi PASSED (Mitigate TxIA comm). ALP = 0, SI @ casing valve. T Fl near surface. IA FL @ surface. Bled TP to 390 psi in 5 min (fluid to surface). Used —8 bbls diesel to reach test pressure (3000/2957/88). Lost 43/42 psi & 21/20 psi (T /IA) in 15/30 min for a total of 64/62 psi (T /IA) in 30 min test. Bled back —7.75 bbls to slop. See log for details. Job complete. Final WHPs = 434/389/87. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 14:00. 5/5/2012 ** *WELL SHUT IN UPON ARRIVAL * ** (E -LINE: TUBING PATCH) INITIAL T /I /O = 550/400/40 PSI INITIAL VALVE POSITIONS: SSV /SWAB/WING = CLOSED, MASTER = OPEN CORRELATED TO SCHLUMBERGER MEMORY LEAK DETECT LOG DATED 03- OCT -2011 RIH WITH BAKER 4.5" L -80 TUBING PATCH (15' UPPER ME TO LOWER ME, OAL = 21.2', MIN ID = 2.45 "). SET TUBING PATCH AT 9554' - 9569' CCL TO TOP ME = 8.2' CCL STOP DEPTH = 9545.8' FINAL VALVE POSITIONS: SSV /SWAB/WING = CLOSED, MASTER = OPEN FINAL T /I /O = 570/360/40 PSI ** *JOB CONTINUED ON 6- MAY - 2012 * ** 5/6/2012 ** *WELL SHUT IN ON ARRIVAL * ** (ELINE SET PATCH) INITIAL T /I /O = 250/350/100 RIGGED UP PRESSURE EQUIPMENT AND TOOLS TO SET PATCH. ** *JOB CONTINUED ON 7- MAY - 2012 * ** • 5/7/2012 ** *JOB CONTINUED FROM 6- MAY - 2012 * ** RIH WITH PEHEF /ERS /UPCT /SETTING TOOL/ 4.5" BAKER KB STRADDLE PATCH CORRELATED TO SCHLUMBERGER MEMORY LEAK DETECT LOG DATED 03- OCT -2011. RIH WITH BAKER 4.5" L -80 TUBING PATCH (20' UPPER ME TO LOWER ME, OAL = 26.1', MIN ID = 2.45 "). SET PATCH AT INTERVAL 7585' - 7605' - CCL STOP DEPTH = 7576.9' CCL TO ME = 8.1' RIGGED DOWN TOOLS AND PRESSURE EQUIPMENT FINAL T /I /O = 600/500/50 ** *WELL SHUT IN ON DEPARTURE. PAD OP NOTIFIED * ** 5/8/2012 T /I /O = SSV /560/90. Temp = SI. Tubing, IA & OA FLs. (Pre MIT). ALP = 0+ psi, AL SI @ casing valve. Unable to get tubing fluid level, DSO not available @ this time. IA FL @ surface. OA FL @ 330' (20 bbls). SV, WV, SSV = C. MV = 0. IA & OA = OTG. NOVP. 03:25 Hrs. p( 5/12/2012 T /I /0= 405/552/85, Temp =S /I, MIT -IA PASSED to 2500 psi (Mitigate TxIA) Pressured up IA with 5 bbls diesel to reach a test pressure of 2500 psi. MIT -IA lost 61 psi in 1st 15 minutes and 22 psi in 2nd 15 minutes for a total of 82 psi in a 30 minute test. Bled IAP ( -5 bbls). SV,WV,SSV,AL= Shut/MV,IA,OA =Open. FW H P's= 405/410/85. 5/22/2012 ** *WELL SHUT IN ON ARRIVAL * ** (post patch) SET 4 -1/2" WHIDDON CATCHER SUB @ 7560' SLM PULLED RK -DGLV FROM ST #3 @ 6429' SLM & ST#4 @ 4088' SLM SET RK -LGLV IN ST# 4 @ 4088' SLM & RK-OGLV IN ST #3 @ 6429' SLM PULLED EMPTY WHIDDON CATCHER SUB FROM 7560' SLM RAN 2 -7/8" EQ PRONG TO EQUALIZE XX PLUG @ 10145' SLM/10156' MD * * *CONT. ON 05/23/12 WSR * ** 5/23/2012 ** *CONT. FROM 05/22/12 WSR * ** (post patch) PULLED 2 -7/8" XX PLUG FROM NIPPLE REDUCER @ 10145' SLM/10156' M D ** *LEFT WELL SHUT IN, DSO NOTIFIED TO POP * ** FLUIDS PUMPED BBLS 9 DIESEL 9 TOTAL " TREE= 5- 1/16" CJW W • ELLHEAD = FMC 4 7 � f D SAFETY NOTES: W ELL ANGLE 70° @ 10 536'. ACTUATOR = AXELSON KB ELEV = 69.78' BF ELEV = NA 1 1 KOP = 4250' Max Angle = 9T © 11273 1 I 2210' - -14 -1/2" HES X NIP, ID = 3.813" I Datum MD = 10286' GAS LIFT MANDRELS Datum TV D = 8800' SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 2983 2982 1 MMG M DMY RK 0 03/13/04 ICONDUCTOR H ? 4 4102 4100 7 MMG-M DOME RK 16 05/22/12 3 6439 6011 50 A/IMG -M SO RK 22 05/22/12 13 -5/8" CSG, 72 #, L -80, ID = 12.347" —1 2606' *2 7593 6802 42 KBG-2 DMY BK 0 10/05/11 *1 9558 8312 40 KBG-2 DM ' BK 0 10/05/11 Minimum ID = 2.31" @ 10156' *STA #2 & 1 BENIND TBG PATCH (DM'w /EXTPACKING) 4 -1/2" X 2 -718" NIPPLE REDUCER i 6696' — js -s/a' x 7 BKRZXPLTP, ID= 6.29 9 -5/8 "? WHIPSTOCK (XX/XX/04) ? 1 6713' 1— I9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.28" I9 -5/$" CSG, 47 #, L -80, ID = 8.681" —1 6829' I— , MILLOUT WINDOW (17- 048) 6829' - 6845' 7585' - 7605']— 4 -1/2" BKR KB TBG PATCH, '- ID = 2.45" (05/07/12) 1 9554' - 9569' j —J 4 -1/2" BKR KB TBG PATCH, ID = 2 45" (05/05/12) PERFORATION SUMMARY I 10090' —14-1/2" HES X NIP, ID = 3.813" 1 REF LOG. BHCS ON ? ?? ANGLE AT TOP PERF N/A S C 10111' 1-17" X 4-1/2" BKR S -3 PKR, ID = ?? Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE , 10135' 1-14-1/2" HES X NIP. ID = 3.813 4 -1/2" SLTD 10348 - 12046 0 03/11/04 10156' H4 -1/2" X 2 -7/8" NIP REDUCER, ID 2.31" (4/19/12) 1 I 10156' I— I 4 -1/2' HES XN NIP, ID = 3.725" 10157' I— 7" X 5" BKR TIEBK SLV (6') 4-1/2" TBG, 12 6 #, L -80 IBT -M / TCII, — 10168' w / HMC LNR HGR ID = ? ?" 0152 bpf, ID= 3.958" 1i 10168' — 14 -1/2" WLEG, ID = 3.958" 1 ? I--15" X 4-1/2" X0, ID = 3.958' 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" —1 10322' 1--41 , I I I I I I 1 I I I I I I I I PBTD I-j 10246' 14-1/2" LNR, 12.6 #, L -80 IBT, 0158 bpf, ID = 3 958" —1 12048' j L DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 10/12180 ORIGINAL COM PLETION 04/19/12 RCT/ PJC NIP RDCR/ XX PLUG (4/19/12) WELL. 17 -04B 03/19/88 RWO 04/22/12 PJC DRAWING CORRECTIONS PERMMT No "`2040230 05101/96 N2ES MULTI LAT ST (17 -04A/ AL1) 05/09/12 JLS /JMD TBG PATCHES (05/05- 07/12) API No: 50- 029 - 20498 -02 03/13/04 N7ES RIG SIDETRACK (17- 048) 05/24/12 GJF /JMD GLV C/0 (05/22/12) SEC 22, T1ON, R15E, 2485' FNL & 450' FWL 10/10/11 CJN/ PJC GLV C/O (10/05/11) 05/24/12 GJF /JMD PULLED XX PLUG (05/23/12) 10/10/11 CJN/ PJC SET XX PLUG (10/06 /11) BP Exploration (Alaska) • • 034./t i 7 0¢8 2,040 230 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] Sent: Sunday, May 20, 2012 3:40 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Wills, Shane M; Huebel, Ross; Mcconkey, Anthony; Olson, Andrew Subject: OPERABLE: Producer 17 -04B (PTD #2040230) MIT -IA Passed Attachments: 17- 04B.pdf All, Producer 17 -04B (PTD #2040230) passed an MIT -IA on 05/12/2012 after tubing patches were set to restore tubing integrity. The passing test proves two competent barriers and the well is reclassified as Operable. Once the downhole plug is pulled and gas lift valves set, the well can be placed on production. An updated wellbore schematic is attached for reference: «1 7 -04 B. pdf» Thank you, Mehreen Vazir (>1/terncite: Gerald ,t' /trr^ph1'j Well Integrity Coordinator BP Alaska Drilling & Wells I1Jl4 a12 Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1 • TREE = 5-1/16" CNN 9 • WaLHEAD = FM SAFETY NOTES: WELL ANGLE > 70* @ 10536'. ACTUATOR =: AXELSON 1 7 -0 4 B I KB ELEV. 6978' BF. ELEV = NA 1 [ KOP = 4250' VBX Angle = 97* .• 11273' 2210 —14-1/2' HES X NIP, ID = 3.813" Datum MD = 10286' 1 GAS LIFT MANDRELS Datum IVO = 8800' SS ST MD WC DEV TYPE VLV LATCH PORT DATE 5 2983 2982 1 M DMY RK 0 03/13/04 CONDUCTOR —j ? Fz il 4 4102 4100 7 NVIAG-M DMY RK 0 09/30/11 64MY 13-5/8" CSG, 72#, L- ID= 12.347 H 2606' 3 39 6011 50 MMG-M D RK 0 0911 2 7593 6802 42 KBG-2 DMY BK 0 10/05/11 1 9558 8312 40 KBG-2 DMY 1 BK 0 10/05/11 Minimum ID = 2.31" @ 10156' 4-1/2" X 2-7/8" NIPPLE REDUCER l 1 i■.__I 664' —1 XT BKR ZXP LTP, ID = 6 29' 19-5/8"? WHIPSTOCK (XYJXX/04) — ? 1 - -1 6713' 1- 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.28" 19-5/8" CSG, 47#, L-80, ID = 8,681" H 6829' 1 — ,..o. . ,t- .,' -. , 1.:1 1 *II / NILLOUT WINDOW (17-04B) 6829' - 6845' 7585' - 7605' — 4-1/2" BKR KB TBG PATCH, ID = 2.45" (05/07/12) 1 1.1 1 - 9569' — 4-1/2" BKR KB TBG PATCH, ID = 2.45" (05/05/12) .2 PERFORATION SUMMARY 1 10090' 1-14-1/2 HES X NP, ID = 3.813" 1 REF LOG: BHCS ON ??? ANGLE AT TOP FERF: N/A S ... 10111. — 7" X 4-1/2" BKR S-3 FKR, ID = ?? Note: Refer to Ft oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 10135' 1H HES X NP, ID = 3.813" 4-1/2" SLTD 10348 - 12046 0 03/11/04 ' 10156' 1 — 4-1/2' X 2-7/8" NIP REDUCER ID 2.31" (4/19/12) 1 10156' —14-1/2" HES XN NIP, ID = 3.725" pH 1 10156' — 2-7/8" XX PLUG (4/19/12) 1 10157' — T X 5" BKR TIEBK SLV (6') ' w / HMC LNR HGR, ID= ??" 4-1/2" TBG, 12.6#, L-80 IBT-M / TCII, — 10168' 1' 0152 bpf, ID = 3958" ■ 10168' — 14 - 12' VVLEG, ID = 3.958" ? —15" X 4-1/2" X0, ID = 3.958" 1 IT' LNR, 26#, L-80 BTC-M, .0383 bpi, ID = 6.276" — 10322' 1 FeTD 1— 10246' [4-1/2" LNR, 12 6#, L-80 IBT, .0158 bpf, ID = 3.958" H 12048' DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 10112/80 ORIGINAL COM PLETION 10/10/11 PJC SET XX PLUG (10/06/11) WELL: 17-048 03/19/88 RWO 04/19/12 PJC NIP RDCR/ XX PLUG (4/19/12) FF_RMIT t■ t ): 2040230 05/01/96 N2ES MULTI LAT ST (17-04AI AL1) 04/22/12 PJC DRAWING CORRECTIONS A F o' 50-029-20498-02 03113104 N7ES RIG SIDETRACK (17-049) 05/09/12 ' JLS/JMD TBG PATCHES (05/05-07/12) / SEC 22, T1 ON, R15E, 2485' FNL & 450' FWL 10/10/11 MSS/ PJC GLV CiO (09/30/11) 10/10/11 CJN/ PJC GLV C/0 (10/05/11) ri''' Exploration (Alaska) X4 . 023 24 -OCT -2011 21 Schhnekerger No. 5802 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -21A BG4H -00097 PPROF W /DEFT & GHOST 9- Oct -11 1 1 13 -15 BINC -00066 PRIMARY DEPTH CONTROL LOG 21-Sep-11 1 1 13 -25 BJGT -00070 PRIMARY DEPTH CONTROL LOG 26- Sep -11 1 1 R -12A AWJI -00158 USIT 16- Aug -11 1 1 2 -65 BX69 -00003 ISOLATION SCANNER 5- Oct -11 1 1 lir A -25B AV1 P -00098 USIT 6- Aug -11 1 1 18 -12C AWJI -00162 MDT 13-Sep-11 1 1 _ S -09 BVYC-00011 USIT 11- Oct -11 1 1 R -12A BBSK -00098 PRIMARY DEPTH CONTROL LOG 28-Sep-11 1 1 Y-36 BVYC -00007 PPROF 2 -Oct -11 1 1 06 -21B BD88 -00173 MEMORY DEPTH DETERMINATION 28- Sep -11 1 1 06-21B BD88 -00173 PPROF W /DEFT & GHOST 29-Sep-11 1 1 W -10A BCRC -00132 PPROF 11- Sep -11 1 1 N-04A BVYC-00009 CROSSFLOW CHECK 5- Oct -11 1 1 A -256 BG4H -00096 SCMT 7- Oct -11 1 1 17 -04B BR12 -00019 LEAK DETECT LOG apt- •" 3- Oct -11 1 1 W -16A BCRC -00133 PPROF 12-Sep-11 1 1 Z -21A BR12 -00020 MEMORY STP SURVEY 5- Oct -11 1 1 Z -29 BD88 -00168 PPROF W/DEFT & GHOST 22-Sep-11 1 1 3- 45/M -39 BD88 -00175 IPROF 3- Oct -11 1 1 R -12A BBSK -00098 SCMT 29-Sep-11 1 1 R -12A BVYC -00005 ISOLATION SCANNER 12-Sep-11 1 1 14-30A BG4H -00093 PRIMARY DEPTH CONTROL LOG 3- Oct -11 1 1 N -04A BINC -00069 PPROF 14- Oct -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnicai Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 JUN 2 0 nia RE: UNDER EVALUATION: Producer-04B (PTD #.19-7-2+60) TxIA Communjition Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) l l v' 1 , i t Sent: Friday, October 07, 2011 10:11 AM I To: 'Reynolds, Charles (Alaska)' Subject: RE: UNDER EVALUATION: Producer 17 -04B (PTD #1972160) TxIA Communication wrong PTD - again. It should be 2040230 if this is really PBU 17 -04B you are referencing. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Reynolds, Charles (Alaska) [mailto:Charles.Reynolds @bp.com] Sent: Friday, October 07, 2011 9:55 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Huebel, Ross ; Mcconkey, Anthony Subject: RE: UNDER EVALUATION: Producer 17 -04B (PTD #1972160) TxIA Communication All, Zv4a 23 r, Following a passing OART, Producer 17 -04B (PTD #147zfi61) failed an MIT -IA on 10/06/11 confirming a lack of two competent barriers in the wellbore. A leak detect log has shown leaks at gas lift valve stations #1 ar . #2 following a GLV change out. A downhole plug has been set and CMIT -TxIA passed on 10/06/11 confirming the well is secure. The well has been reclassified to Not Operable until tubing integrity is restored. The plan forward is: 1. APE: Eval well for tubing repair Thank you, Charles Reynolds Filling in for... Mehreen Vazir (Alternate; Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/7/2011 RE: UNDER EVALUATION: Produce -04B (PTD #1972160) TxIA Commuoation Page 2 of 2 From: AK, D &C Well Integrity Coordinator Sent: Sunday, September 11, 2011 9:34 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Huebel, Ross Subject: UNDER EVALUATION: Producer 17 -04B (PTD #1972160) Sustained OA Pressure Above MOASP All, Producer 17 -04B (PTD #2040230) was found with sustained casing pressure above MOASP on the OA. The wellhead pressures were tubing /IA/OA equal to 322/2000/1040 psi on 09/08/11. The well has been reclassified as Under Evaluation and may be produced while diagnostics are conducted. The plan forward is as follows: 1. DHD: OA Repressurization Test - PASSED A TIO plot and wellbore schematic have been included for reference. « File: 17 04B.pdf » « File: 17 - 04B TIO Plot 09 11 11.doc » Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/7/2011 UNDER EVALUATION: Producer 17 or (PTD #.19-7216 Sustained OA Preere Above MO... Page 1 of 1 2-011oz3Q Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Sunday, September 11, 2011 9:34 PM 4' �(( /w To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Huebel, Ross Subject: UNDER EVALUATION: Producer 17 -04B (PTD #197 2-4801 - Sustained OA Pressure Above MOASP Attachments: 17- 04B.pdf; 17 -04B TIO Plot 09- 11- 11.doc 204 o 2-30 All, Producer 17 -04B (PTD #2040230) was found with sustained casing pressure above MOASP on the OA. The wellhead pressures were tubing /IA/OA equal to 322/2000/1040 psi on 09/08/11. The well has been reclassified as Under Evaluation and may be produced while diagnostics are conducted. The plan forward is as follows: 1. DHD: OA Repressurization Test A TIO plot and wellbore schematic have been included for reference. «17- 04B.pdf» «17 -04B TIO Plot 09- 11- 11.doc» - Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 9/12/2011 PBU 17-04B PTD #2040230 9/11/2011 TIO Pressure Plot Welt 17-04 4,000 - , • 3.000 Tbg 2,000 • • • OA 00A 000A On 1,COO 06/ 1/11 06/1 06/25/11 07/02/11 07/09/11 07/16111 07/23/11 07/30/11 • 08/06/11 08113/11 • 09/20/11 • 09/27/11 • 09/03/11 • 09/10/11 - - TREE= 5- 1/16" CM/ • WELLHEAD = FMC ACTUATOR = AXELSON -04B , SAFETY NOTES: KB. ELEV = 69.78' BF. ELEV = NA ' KOP = 4250' Max Angle = 97 @ 11273' ' I i f 2210' H4-1/2" HES X NIP, ID = 3.813" 1 Datum MD = 10286' Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -5/8" CSG, 72 #, L -80, ID = 12.347" H 2606' I A ® ST MD TVD DEV TYPE VLV LATCH PORT DATE ID 5 2983 2983 1 MMG -M DMY RK 0 03/13/04 ' 4 4102 4100 7 MMG -M DOME RK 16 05/29/05 3 6439 6011 50 MMG -M DOME RK 16 05/29/05 2 7593 6802 42 KBG -2 DOME RK 16 05/29/05 1 9558 8312 40 KBG -2 SO RK 24 05/29/05 Minimum ID = 3.725" @ 10156' 4 -1/2" HES XN NIPPLE t J E 3) 1 6695' H 9 -5/8" X 7" BKR ZXP LNR TOP PKR I PERFORATION SUMMARY REF LOG: BHCS ANGLE AT TOP PERF: MILLOUT WINDOW 6829' - 6845' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE SLTD 10390 - 12048 0 03/11/04 10090' I—E 4-1/2" HES X NIP, ID = 3.813" I ` 10111' Fl 7" X 4 -1/2" BKR S -3 PKR J 1 EZSV H 6856' I ( 10135' I-1 4 -1/2" HES X NIP, ID = 3.813" I 1 0156' 1-I 4 -1/2" HES XN NIP, ID = 3.725" �►� / 1 9 -5/8" CSG, 47 #, L -80, ID = 8.6811_ ♦ •: ♦• ♦• ♦ ♦ ..* 10168' 1-i 4 -1/2 " WLEG, ID = 3.958" ...... 10157' 1- 7" X 5" BKR HMC 1 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I— ...- .— .'��■ Ai! 0 LNR TOP PKR 12046' W 1-I PBTD I I4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I--i 10168'1 • • 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 10322' I ` 4-1/2" SLTD LNR, 12.6 #, L -80, ID = 3.958" H 12048' I DATE REV BY - COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10113180_ ORIGINAL COMPLETION 05/31/05 KDC /PJC GLV C/O WELL: 17 -04B 03119/88 RWO PERMIT No: ° 12040230 05/01/96 RIG SIDETRACK API No: 50- 029 - 20498 -02 03/15/04 SRB/KAK RIG SIDETRACK (17 -04B) SEC 22, TION, R15E, 2795' FSL & 4830' FEL 03/18/04 JBM/KAK GLV C/O 06/16/04 SRB /KAK CORRECTIONS BP Exploration (Alaska) • q ._:.:. ^~ ,~~"' ~_ ,,~,. -- MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc Scblum~erger SCANNED SEP 14 2000 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dDt..I-~3 tt It{ / f)') R'· ~ .r'" r- . , - \;.2 ":, t:: l., ,.,' ."'~ j. "'W .) 08/28/06 ~I.YÒ ~œ&GasCons.c~ Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3941 Company: Field: Prudhoe Bay Well Job# Log Description Date BL Color CD C-11A 11225983 LDL 07/02/06 1 8-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 8-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02/06 1 G-03A 11211493 LDL OS/24/06 1 C-26A 11225979 LDL 06/07/06 1 F-26B N/A MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y -08A 11221604 SCMT 08/20/06 1 C-068 11212883 USIT 08/15/06 1 X-27 11217274 USIT 08/26/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-1OA 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-048 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . . Schlumberger RECEIVED NO. 3914 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth , "I1J~' .~ rlOPS AUG 1 Ü 2006 SCANNED.\I \.1 I ,t :"~" ~ aska Oil & Gas Cons. eommis$on Anchorage ...I-. d04-0'd3 ~/'IOI</ Field: Prudhoe Bay Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 D C Well Job# Log Description ate BL Co or D z-30A 40010092 OH EDIT OF MWD/LWD 01/27/04 2 1 17-048 40010183 OH EDIT OF MWD/LWD 03/09/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Surte 400 Anchorage, AK 99503·2838 ATTN: Beth 08/09/06 . . J J ~r?t"I'{ ~ ~ ~ lð DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040230 Well Name/No. PRUDHOE BAY UNIT 17-04B Operator BP EXPLORATION (ALASKA) INC API ~~0{29-{0!:t.~0~ V( MD 12048 /" TVD 9017"-- Completion Date 3/13/2004"-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -------- -~----- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, PWD, RES, AIM Well Log Information: (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop Log Log Run Interval OH/ . Scale Media No Start Stop CH Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 2/6/2004. A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/6/2004. 6793 12048 3/23/2004 Also an Excel spreadsheet 6793 12048 3/23/2004 6793 11635 3/23/2004 Also an Excel spreadsheet - PB1 6793 11635 3/23/2004 PB1 . Sample Set Sent Received Number Comments Log/ Data Type I ! Electr Digital Dataset Med/Frmt Number Name I lED i4t kb k. D Wrd Directional Survey Directional Survey Directional Survey D Wrd Directional Survey Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y i~ Chips Received? ~ Analysis ~ Received? Daily History Received? (PN f;N Formation Tops comme~;~-e.. ~~, It)!. A--~ ~'f'VN.1f' I ~ ~ M-0\o ~- C Ä",-àil\.lJIJ. f\J\r"W\Il<f ~ b II' c,~",,^- ) ~ ~~. hrl tj¡. DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040230 Well Name/No. PRUDHOE BAY UNIT 17-04B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20498-02-00 MD 12048 TVD 9017 Completion Date 3/13/2004 Completion Status 1-01L Current Status 1-01L UIC N --~-_.,--~--- ----t -Date:' 1~\ ~--.--.------: t ---- ._~~._,---- "---- Compliance Reviewed By: . . · e STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/13/2004 204-023 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/1/2004 50- 029-20498-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 3/9/2004 PBU 17 -04B 2795' NSL, 4830' WEL, SEC. 22, nON, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 196' SNL, 1583' WEL, SEC. 28, T10N, R15E, UM 63' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 430' SNL, 3182' WEL, SEC. 28, T10N, R15E, UM 12048 + 9017 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 708703 y- 5928144 Zone- ASP4 12048 + 9017 Ft ADL 028334 ------~ 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 706759 y- 5925099 Zone- ASP4 -------_.~ (Nipple) 2210' MD Total Depth: x- 705168 y- 5924822 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD , DIR , GR , PWD , RES, AIM 22. CASING, LINER AND CEMENTING RECORD CASING SETtiNG UEPTH MD. ~ETTING D~PTH."ND HOLE AM~Ut'n SIZE WT.PERFT. GRADE TOP BOTTOM TOP I BOTTOM SIZE i PULLED 20" 94# H-40 Surface 110' Surface 110' 32" 390 sx Arcticset II 13-3/8" 72# L-80 Surface 2606' Surface 2606' 17-1/2" 1975 sx Fondu, 400 sx Permafrost II 9-5/8" 47# L-80 / S0095 Surface 6829' Surface 6267' 12-1/4" 800 sx Class 'G', 300 sx PF 'C' 7" 26# L-80 6696' 10322' 6179' 8890' 8-1/2" 184 sx Class 'G' 4-112" 12.6# L-80 10157' 12048' 8765' 9017' 6-1/8" Uncemented Slotted Liner 23. Perforations op'en to Production (MD + TVD of Top and 24. TUBING RECORD :i,: : Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 10168' 10111 ' MD TVD MD TVD 10348' - 12005' 8910' - 9014' 25. ACID,.. F'RACTURE,CEMENT ~ '. ETC> i i .i DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 130 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 29,2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 4/24/2004 10 TEST PERIOD .. 353 8411 6949 64 23834 Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF W A TER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 847 2019 16678 27. CORE DATA - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attac'l "\'~'l.tA ~t" ary). Submit core chips; if none, state "none". - - ........, None r5õí0i;'''i~rT;n APR 2 9 2004 ._. j~Jj% ~¡ r -.....:: ...., OR\G\NAL Alaska Oil & Gas Cons. Commission .....=- ~-~ G31:1I!lJM Anchorage -"'",-,~ Form 10-407 Riev,is¡~vt12./20~3 CONTINUED ON REVERSE SIDE l!:OdJ7d 1 ¡ ~~t; ~BfL {j MAY 0.1!2Ø1 ~ ~ ~ 28. GEOLOGIC MARKERS NAME MD TVD CM1 9319' 8126' Top HRZ 9749' 8457' Base HRZ 9978' 8630' Top JB 10082' 8708' Top JA 10206' 8802' Sag River 10330' 8896' Shublik 10365' 8922' Shublik B 10394' 8941' Shublik C 10425' 8959' Sadlerochit 10500' 8998' 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED APR 2 9 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant 204-023 Permit No. / A roval No. 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. PBU 17 -04B Well Number Date Dq- Zg-()l Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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 Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ORIGINAL 2/29/2004 3/6/2004 FIT FIT 6,829.0 (ft) 10,322.0 (ft) 6,267.0 (ft) 8,891.0 (ft) 9.70 (ppg) 8.40 (ppg) 926 (psi) 742 (psi) 4,084 (psi) 4,622 (psi) 12.54 (ppg) 10.01 (ppg) e Printed: 3/15/2004 10: 15:04 AM e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -04 17 -04 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 2/24/2004 3/13/2004 Spud Date: 8/28/1980 End: 3/13/2004 2/21/2004 00:00 - 06:00 6.00 MOB N PRE Waiting on the Wells Group to release DS 17-04 to drilling. VECO removed the well house & flow line. Well turned over to Drilling @ 06:00 Hrs. Perform general rig maintenance & rig down as much as posible while waiting on VECO. 06:00 - 11 :30 5.50 MOB N PRE Tool Service shot grade on pad & leveled same. 11 :30 - 12:30 1.00 MOB P PRE Disconnect Pit Module from Sub Base. Move Pits ahead 5' to Clear Sub. Prepared to Move Rig. 12:30 - 18:30 6.00 MOB P PRE Move Sub off DS 17-07. Drive rig to other side of Pad. Set matting boards & spread Herculite over area. 18:30 - 19:00 0.50 MOB P PRE Start backing Sub Base into position & line up with the DS 17-04 well. At +/- 18:45 hrs the rig was about 30' from being in position over the well when the hydraulic lift cylinder rod (Forward drivers side) broke off at the base plate that is attached to the Main Drive Axle Assembly. No one was injuried & there was no environmental damage. Note: After performing inspection on the Drive Axle Assembly there was minimum damage to the surrounding rig equipment. 19:00 - 00:00 5.00 MOB N RREP PRE Nabors consulting with their Anchorage office & the manufacture of the Drive Axle "Columbia Corp" on most expedient course of action to take in repairing the rig. The plan is to reposition the Drive Axle to the lift cylinder in their original position & weld the cylinder rod to the base plate. Then move the rig over the well. Spot same & rig up for drilling operations. While the well is being drilled Nabors will replace the Drive Axle Assembly. Currently the Rig Welder is grinding the damaged part on the cylinder rod & base plate in preparation for welding. 2/22/2004 00:00 - 05:00 5.00 MOB N RREP PRE Repair Rig. Welder grinding the damaged part on the cylinder rod & base plate in preparation for welding. 05:00 - 12:00 7.00 MOB N RREP PRE Rig up chain hoist & related equipment to help reposition Drive Axle under hydraulic lift cylinder. 12:00 - 22:30 10.50 MOB N RREP PRE Align Drive Axle to lift cylinder. 22:30 - 00:00 1.50 MOB N RREP PRE Start welding front DS lift cylinder to Drive Axle base plate. 2/23/2004 00:00 - 20:00 20.00 MOB N RREP PRE Repair Rig by welding front DS lift cylinder to Drive Axle base plate. After welding let cool to the touch. 20:00 - 22:30 2.50 MOB P PRE Back Sub over Well 17-04. Spot Sub. Center and level Rig. 22:30 - 00:00 1.50 MOB P PRE Spot Pit Complex & level same. 2/24/2004 00:00 - 02:00 2.00 MOB P PRE Hook up all lines between sub & pit complex. Prepared to take on seawater. Move & spot camp. 02:00 - 04:30 2.50 WHSUB P DECOMP ACCEPT RIG @ 02:00 HRS 2/24/2004. Take on Seawater. R/U Lines to Tree Flowline valve and 3-1/2" x 9-518" Annulus to Choke Manifold in Preparation to displace diesel from wellbore. Checked 3-1/2" Tubing x 9 5/8" Annulus - static. 04:30 - 05:30 1.00 WHSUB P DECaMP RIU DSM Lubricator & pull BPV. R/D Lubricator. 05:30 - 08:30 3.00 WHSUB N WAIT DECOMP Load of Seawater Halted by Security at Sag Bridge. 08:30 - 13:00 4.50 WHSUB P DECOMP PJSM. Pressure test Lines to 3500 psi. Pump 28 Bbls Seawater down fA @ 3 BPM & 350 psi to clear Diesel from Tubing. Switch & Pump seawater down tubig to Clear Diesel from IA. Displace well bore fluid to tubig Cut @ 7525'. With heated Seawater @ 4 BPM / 520 psi. 13:00 - 13:30 0.50 WHSUB P DECOMP Shut down Pumps & observe well. Out of balance. U - Tube for 20 minutes - Still not balanced fluid. 13:30 - 16:30 3.00 WHSUB P DECOMP Pump Seawater around to Clean Out wellbore, Tubing & balance. Pump @ 4 BPM / 520 psi. Printed: 3/15/2004 10:15:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 Set B PV & Test from Below to 1 000 psi. N/D Tree & Adapter Flange. Inspect Hanger & threads. Integral hanger & Good Threads. N/U 135/8" BOP & Assc. Equipment. Set Blanking Plug into BPV. Fill stack & R/U To Test. Test Bind rams to to 250 psi. Low & 3500 psi. High. Pull Blanking Plug & run Test Jt. Test Remainder of BOPE to Same 250 psi Low & 3500 psi High. R/U DSM Lubricator. Pull BPV. RID DSM. P/U 5 1/2" Landing Jt., Screw into Hanger. B.O.L.D.S. Pull Hanger off seat wI 95K. Pull up to 190K. Tubing not Parted. Work pipe in attempt to pull free. No Success. Change out to long bails in preparation for SWS E·Line wI Chemical Cut. DFAL DECOMP PJSM wI SWS. R/U E-Line. DFAL DECOMP RIH wI String Shot. Correlate wI CCL. Pull 150K on Tubing string & Shoot String Shot - 7,506' to 7,520' No Surface indication of Shot. Release tension on Tubing. POH & UD String Shot ( Had Fired). DFAL DECOMP M/U 21/8" Extended Reach Chemical Cutter. RIH, Correlate to Tubing Collar and Set Cutter @ 7,514'. Pull 150K Tension on Tubing & Fire Chemical Cutter. Observed 5K loss of Weight on Tubing. Work pipe up to 190K. Pipe not Free. Land tubing & POH wI Chemical Cutter. DFAL DECOMP POH wI Chemical Cutter & LID Same. Chemical Cutter came out with SSSV Sleeve Attached. RID SWS - leave Sheaves up for run wI Jet Cutter after Slick Line. Work Tubing while waiting on Slick Line Unit. Attempted to work 2600 ftllbs Torque down to cut. Pulled up to 200K. No Success. PJSM with HES Slick Line Crew. R/U Slick line to safe Out Camco SSSV Flapper. Make Following Runs: 1. Flapper checker· Flapper Closed 2. Z-5 Lock-out Tool - Spang off Tool 3.2.7" Blind Box - Beat down for 45 minutes. 4.3" JDC WI Z-5 Core - Latch & Pull Z-5 Tool 5. Flapper Checker - Flapper still closed. DFAL DECOMP Decided to make one more attempt to lock out SSSV Flapper with additional weight bars to beat down. Doug Varble, Wells Group Wire Line Supv., on Site supervising HES Slick Line Crew. Make the following runs: 1. Z-5 Lock-out Tool - Spang off Tool 2. 2.7" Blind Box with added wt. bars - Beat down for 90 minutes. 3.3" JDC WI Z-5 Core - Latch & Pull Z-5 Tool 4. Flapper Checker -Indicates Flapper Open. 5.2.80 Drift - went through SSSV @ 2219 RJH to 2260' POH - Successfully Locked out SSSV Flapper Valve. RID HES Slick Line. 19:30 - 00:00 4.50 DECOMP 2/25/2004 00:00 . 07:00 7.00 DECOMP 07:00 - 09:30 2.50 DECOMP 09:30· 10:00 0.50 DECOMP 10:00 - 16:00 6.00 DFAL DECOMP 16:00 . 17:30 17:30 - 21 :30 1.50 FISH 4.00 FISH N N 21 :30 - 00:00 2.50 FISH N 2/26/2004 2.00 FISH 00:00 - 02:00 N 02:00 - 05:00 3.00 FISH N DFAL DECaMP 05:00 - 06:00 1.00 FISH N DFAL DECOMP 06:00 . 16:00 10.00 FISH N DFAL DECOMP 16:00 - 23:00 7.00 FISH N Printed: 3/15/2004 10: 15: 17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 2/26/2004 16:00 - 23:00 7.00 FISH N DFAL DECaMP 23:00 - 00:00 1.00 FISH N DFAL DECOMP PJSM wI SWS Crew on 2.68" Jet Cutter Run. R/U to run Jet Cutter. 2/27/2004 00:00 - 02:00 2.00 FISH N DFAL DECOMP RIH wI 2.68" Jet Cutter. Correlate collars & position Cutter @ 7500' 02:00 . 02:30 0.50 FISH N DFAL DECaMP Latch onto Landing jt & P/U wI 150K on Weight Indicator Fire Jet Cutter - No Indication on String WI. - Pull up to 200K - Tubing not Free. 02:30 - 03:30 1.00 FISH N DFAL DECOMP POH wI Jet Cutter. Confirm jet Cutter has Fired. LID Tools. 03:30 . 06:30 3.00 FISH N DFAL DECOMP Screw in with Top Drive & Circulate down tubing. Stage up to 250 GPM @ 575 psi. - Packed Off. shut down pumps, pressure bled off. Regained cirulation & staged up to 480 GPM @ 1970 psi. Continue working pipe with no success - tubing not free. Contaminated Cement (10.5 Ph.) to Surface on Bottoms Up. Pack -off was due to position of 13 3/8" OD Tubing Hanger in 135/8" ID BOP Stack. 06:30 . 08:00 1.50 FISH N DFAL DECOMP PJSM wI SWS. M/U & RIH wI Free Point Tool. 08:00 - 11 :00 3.00 FISH N DFAL DECOMP Free Point Tool failed. POH. Found Moisture in E-Line. Cut Line & Re-Head. 11 :00 - 14:30 3.50 FISH N DFAL DECOMP RIH wI Free Point Tool and take Stretch Readings at various depths. 100 % Stuck @ 7221'. 93% Free @ 7004' 14:30 . 18:30 4.00 FISH N DFAL DECOMP MIU 2.68" Jet Cutter & RIH. Correlate & position cutter @ 6950'. Attempt to Fire Cutter. No Success - Misfire. POH 18:30·21:30 3.00 FISH N DFAL DECOMP Run diagnostic checks. Found Electrical Short in CCL. Repaired Same & RIH. Postion tool @ 6,950' Latch on to landing Jt & pull 150K tension. Fire tool. Surface indication of success. Lost 30K. Pulled up 10 Ft wI 20 to 30K drag. POH wI Cutter - Tool fired. 21 :30 - 23:00 1.50 FISH P DECOMP Pull Hanger above Rotary. Drag 10 to 20K. Circulate, staging up to 480 GPM @ 1300 psi. Considerable amount of Contaminated Cement over Shakers. Work pipe - Completely Free 23:00 - 00:00 1.00 FISH P DECOMP RlU Tongs & control line spooler. LID Landing JI. & Hanger. 2/28/2004 00:00 - 01 :00 1.00 PULL P DECOMP Blow down Top Drive C/O to Short Bails. 01 :00 - 11 :00 10.00 PULL P DECOMP POH w/3 1/2", 9.2#, L-80, TDS Tubing Completion String, LID 220 Jts + 20' Cut-off, Jewelry & Spool Control Line. All Tubing & Jewelry N.O.R.M. Tested. Item Radioactvity = 0 to 3 uREM I hr. Tubing Hanger = 1 to 3 uRem I hr. 11 :00 - 11 :30 0.50 PULL P DECOMP RID Tubing Equipment & Clear Rig Floor. 11 :30 - 12:00 0.50 CLEAN P DECOMP M/U Wear Bushing on Running Tool & Install Same. 12:00 - 14:30 2.50 CLEAN P DECOMP Load rig floor wI CIO BHA. MIU Same + 9 DC's & 20 Jts, 5" HWDP. RIH. 14:30 - 17:00 2.50 CLEAN P DECOMP P/U & RIH wI 75 Jts, 5" DP from Shed. 17:00 - 19:00 2.00 CLEAN P DECOMP Continue RIH with Stands of 5" DP from Derrick. Take Weight @ 6,612'. 19:00 . 20:00 1.00 CLEAN P DECOMP Wash & Ream from 6,612' to Tubing Stub @ 6,955' (DP Measurement) 500 GPM @ 860 psi & 80 RPM. Reaming through numerous stringers taking up to 10K. 20:00 - 21 :30 1.50 CLEAN P DECOMP Circulate 50 Bbl. Hi - Vis Sweep, Considerable amount of Cement over Shakers throughout Circulation. Rotating @ 110 RPM - 550 GPM @ 980 psi. Casing Clean. Pump Slug. Printed: 3/15/2004 10:15:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 2/24/2004 3/13/2004 Spud Date: 8/28/1980 End: 3/13/2004 2/28/2004 21:30 - 22:15 0.75 CLEAN P DECOMP 22:15 - 00:00 1.75 CLEAN N RREP DECOMP 2/29/2004 00:00 - 03:00 3.00 CLEAN P DECOMP 03:00 - 04:30 1.50 CLEAN P DECOMP 04:30 . 10:00 5.50 DHB P DECOMP 10:00 - 11 :00 1.00 DHB P DECOMP 11 :00 - 13:00 2.00 STWHIP P WEXIT 13:00 - 17:00 4.00 STWHIP P WEXIT 17:00 - 17:30 0.50 STWHIP P WEXIT 17:30 - 18:45 1.25 STWHIP P WEXIT 18:45 - 21 :45 3.00 STWHIP P WEXIT 21 :45 - 22:45 1.00 STWHIP P WEXIT 22:45 - 23:45 1.00 STWHIP P WEXIT 23:45 - 00:00 0.25 STWHIP P WEXIT 3/1/2004 00:00 - 03:30 3.50 STWHIP P WEXIT 03:30 - 06:00 2.50 STWHIP P WEXIT 06:00 - 07:30 1.50 BOPSU P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 10:30 2.00 STWHIP P WEXIT 10:30 - 14:30 4.00 STWHIP P WEXIT 14:30 - 15:30 15:30 - 16:30 1.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT 16:30 - 00:00 7.50 DRILL P INT1 POH Standing back 5" DP. Iron Roughneck Failed. Repair Iron Roughneck. Gland packing on Clamp Cylinder loose - Tighten Same. POH Standing back 5" DP. Stand back 5" HWDP & DC's. UD Mills. PJSM wI SWS,HES & Crew. R/U SWS. M/U SWS CCL & HES EZ-DRILL Bridge Plug. RIH, Correlate wI GR & Set EZ DRILL BP @ 6,856'. R/U & Test 9 5/8" Casing to 3500 psi. Hold & Chart for 30 Minutes. RID P/U & M/U Whipstock BHA. RIH wI Whipstock BHA on 5 " DP to 6815' Orient to 81 Degrees & Set Whipstock. Displace seawater with 9.7 ppg LSND Mud. 480 GPM @ 1800 psi. Cut Window in 9 5/8' Casing from 6,829' to 6,845'. Mill additional Hole for FIT to 6,858'. 480 GPM @ 1850 psi. Pump Hi Vis Sweeps as needed. Work Assembly through Window while circulating final Hi Vis Sweep. Recovered 256 Ibs of Metal Cuttings. Perform FIT. Mud Weight = 9.7 ppg. MD = 6829' TVD = 6267' Surface Pressure = 926 psi. FIT = 12.54 EMW RID from FIT & Pump Slug POH Standing Back 5" DP. UDWhipstock BHA: DC's, Mills & MWD. Pull Wear Bushing, M/U Jetting Tool on Stand of 5" DP. Function & Clean Out BOP. Install Wear bushing. Service Top Drive, Blocks & Crown. Held PJSM. M I U 8-1/2" Directional BHA: 8-1/2" Smith MGR75HPX PDC Bit Ser# JP3797 dressed w/7 x 13 Jets- 6-3/4" 5.0 Stg XP Mud Motor w/1.15 deg Bend - 8" Stabilizer - CDR Assembly - MWD Assembly - 8-1/2" Stabilizer· 3 x 6-3/4" Flex Collars - XO - Jars - 20 Jts 5" HWDP - 8 1/2" Ghost Reamer - XO. Total BHA Length: 819.87'. Oriented Motor to MWD. Pulsed Tested MWD, OK. RIH, Picking Up & Rabbiting, 99 Jts of 4" DP from Shed. Change Out Elevators & Slips for 5" DP. RIH wI 5" DP from Derrick to 6,618'. M I U Top Drive, Established Parameters: String Weight Up 155,000#, String Weight Down 140,000#, Pump Rate 560 gpm, 1550 psi, ECD 10.4 ppg. Oriented Tools 80 Degrees, Shut Down Pumps, RIH Through Window. Re-Engaged Pumps, Washed Down as Precaution from 6,848' to 6,858'. Pump Rate 500 gpm, 1,420 psi. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 6,858' to 7,289'. WOB Sliding 12,000# - 22,000#, WOB Rotating 10,000# - 18,000#, RPM 100, Motor RPM 157, Torque Off Bottom 4,000 ft Ilbs - On Bottom 7,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 1,980 psi, On Bottom 2,275 psi. String Weight Up 155,000#, String Weight Down 140,000#, String Weight Rotating 145,000#. Calculated ECD 10.42 ppg PWD ECD 10.65 ppg. Pumping 30 bbl Hi·Vis Printed: 3/15/2004 10: 15: 17 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 17 -04 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 2/24/2004 3/13/2004 Spud Date: 8/28/1980 End: 3/13/2004 3/112004 16:30 - 00:00 7.50 DRILL P INT1 Weighted Sweeps as Needed to Clean Hole. ART 0.7 hrs, AST 3.4 hrs. 3/2/2004 00:00 - 09:30 9.50 DRILL P INT1 Held PJSM. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 7,289' to 8,289'. WOB Sliding 15,000# - 20,000#, WOB Rotating 10,000# - 15,000#, RPM 100, Motor RPM 157, Torque Off Bottom 4,000 ft Ilbs - On Bottom 7,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,000 psi, On Bottom 2,300 psi. String Weight Up 185,000#, String Weight Down 160,000#, String Weight Rotating 165,000#. Calculated ECD 10.40 ppg PWD ECD 10.75 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. Slide Sheet Depth Tool Face 7,289' - 7,365' 120.0 R 7,478' - 7,508' 165.0 R 7,575' - 7,585' 170.0 L 7,640' - 7,671' 180.0 R 8,235' - 8,280' 110.0 R 09:30 - 10:00 0.50 DRILL P INT1 Circulated Hole wI Mud Pump #2, Changed Out Swab on Mud Pump #1. Note: Crew Members in Pit Complained of Eye and Respiratory Irritation Due to Ammonia Vapors from Mud. Meter Readings Indicated 20 ppm Ammonia in Pits. Rig and Anchorage Team Made Decision to Displace Wellbore to New 10.5 ppg LSND. 10:00 . 12:00 2.00 DRILL P INT1 Drilled 8-1/2" Directional Hole by Rotating and Sliding from 8,289' to 8,424'. WOB Sliding 15,000# - 20,000#, WOB Rotating 10,000# - 15,000#, RPM 100, Motor RPM 157, Torque Off Bottom 4,500 ft Ilbs - On Bottom 7,500 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,050 psi, On Bottom 2,300 psi. String Weight Up 190,000#, String Weight Down 160,000#, String Weight Rotating 165,000#. Calculated ECD 10.55 ppg PWD ECD 10.85 ppg. Last 12 Hrs - ART = 4.0 hrs, AST = 2.36 hrs. Slide Sheet Depth Tool Face 8,330' - 8,390' 110.0R 12:00·17:30 5.50 DRILL P INT1 Held PJSM. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 8,424' to 9,083'. WOB Sliding 15,000# - 30,000#, WOB Rotating 10,000# - 20,000#, RPM 100, Motor RPM 157, Torque Off Bottom 6,000 ft Ilbs - On Bottom 8,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,400 psi, On Bottom 2,850 psi. String Weight Up 195,000#, String Weight Down 170,000#, String Weight Rotating 170,000#. Calculated ECD 10.60 ppg PWD ECD 10.95 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. Slide Sheet Depth Tool Face 8,424' - 8,484' 90.0R 8,518' - 8,575' 80.0R 8,612 - 8,672' 90.0R 8,706' - 8,736' 100.0 R 8,896' - 8,941' 70.0R 17:30 . 18:30 1.00 DRILL P INT1 Circulated Hole wI Mud Pump #2, Changed Out Two Swabs on Printed: 3/15/2004 10:15:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 2/24/2004 3/13/2004 Spud Date: 8/28/1980 End: 3/13/2004 3/212004 17:30 - 18:30 1.00 DRILL P INT1 Mud Pump #1. 18:30 - 00:00 5.50 DRILL P INT1 Drilled 8-1/2" Directional Hole by Rotating and Sliding from 9,083' to 9,558'. WOB Sliding 15,000# - 25,000#, WOB Rotating 15,000# - 20,000#, RPM 100, Motor RPM 157, Torque Off Bottom 7,000 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,600 psi, On Bottom 3,000 psi. String Weight Up 200,000#, String Weight Down 170,000#, String Weight Rotating 175,000#. Calculated ECD 10.65 ppg PWD ECD 11.20 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. Last 12 Hrs - ART = 2.90 hrs, AST = 3.74 hrs. Slide Sheet Depth Tool Face 9,178' - 9,213' 40.0 R 9,367' - 9,415' 45.0R 9,462 - 9,512' 50.0 R 3/3/2004 00:00 - 02:00 2.00 DRILL P INT1 Held PJSM. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 9,558' to 9,747'. WOB Sliding 10,000# - 15,000#, WOB Rotating 15,000# - 20,000#, RPM 100, Motor RPM 157, Torque Off Bottom 8,000 ft Ilbs - On Bottom 10,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,500 psi, On Bottom 3,050 psi. String Weight Up 205,000#, String Weight Down 170,000#, String Weight Rotating 180,000#. Calculated ECD 10.60 ppg PWD ECD 10.95 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. Slide Sheet Depth Tool Face 9,558 - 9,628' 15.0 L 02:00 - 05:00 3.00 DRILL P INT1 Held PJSM. POOH Stood Back 1 Stand. Pumped 30 bbl Hi-Vis Sweep. Displaced Well bore to New 10.5 ppg LSND. Pump Rate 500 gpm, 1,950 psi. Rotated 100 RPM, Reciprocated Drill String While Displacing. 05:00 - 06:00 1.00 DRILL P INT1 RIH to 9,747'. M I U Top Drive and Engaged Pumps. Attempted to Take Check Shot Survey. Experienced MWD Signal Loss. Checked Surface Equipment. Found Excess Noise from #1 Mud Pump. 06:00 - 07:00 1.00 DRILL P INT1 Cleaned Suction Screens. Changed Out 2 Valves on #1 Mud Pump. Tested MWD, Good Signal. Took Check Shot Survey. 07:00 - 12:00 5.00 DRILL P INT1 Drilled 8-1/2" Directional Hole by Rotating and Sliding from 9,747' to 10,127'. WOB Sliding 15,000#, WOB Rotating 15,000# - 17,000#, RPM 100, Motor RPM 157, Torque Off Bottom 6,000 ft Ilbs - On Bottom 8,500 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,350 psi, On Bottom 2,550 psi. String Weight Up 225,000#, String Weight Down 175,000#, String Weight Rotating 195,000#. Calculated ECD 11.20 ppg PWD ECD 11.50 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. ART = 1.79 hrs, AST = 2.93 hrs. Slide Sheet Depth Tool Face 9,747 - 9,814' 10.0 L 9,936 - 9,965' 30.0R 10,031 - 10,063' 10.0 R 12:00 - 13:30 1.50 DRILL P INT1 Drilled 8-1/2" Directional Hole by Rotating and Sliding from Printed: 3/1512004 10: 15: 17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17 -04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/312004 12:00 - 13:30 1.50 DRILL P INT1 10,127' to 10,317'. WOB Sliding 20,000#, WOB Rotating 10,000# - 15,000#, RPM 100, Motor RPM 157, Torque Off Bottom 6,500 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,350 psi, On Bottom 2,650 psi. String Weight Up 225,000#, String Weight Down 175,000#, String Weight Rotating 195,000#. Calculated ECD 11.30 ppg PWD ECD 11.55 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed. ART = 0.85 hrs, AST = .038 hrs. Slide Sheet Depth Tool Face 10,221 - 10,250' 20.0 R 13:30 - 14:30 1.00 DRILL P INT1 Circulated for Samples, Pump Rate 550 gpm, 2,750 psi. 14:30 - 15:00 0.50 DRILL P INT1 Drilled 8-1/2" Directional Hole by Rotating from 10,317' to 10,322'. WOB 15,000#, RPM 100, Motor RPM 157, Torque Off Bottom 6,500 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 570 gpm, SPP Off Bottom 2,350 psi, On Bottom 2,650 psi. String Weight Up 225,000#, String Weight Down 175,000#, String Weight Rotating 195,000#. 15:00 - 16:00 1.00 DRILL P INT1 Circulated for Samples, Pump Rate 550 gpm, 2,750 psi. 16:00 - 17:00 1.00 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep. Pump Rate 550 gpm, 2,750 psi. 17:00 - 23:00 6.00 DRILL P INT1 Monitored Well, Well Static. POOH for Wiper Trip from 10,322' to 9,710'. No Problems. Pumped Dry Job, Blew Down Top Drive. POOH from 9,710' to 8,800', No Problems. Observed 20,000# Overpull from 8,800' to 7,500', No Swabbing. Experienced 50,000# Overpull at 7,500'. M I U Top Drive, Pumped and Rotated Out of Hole. Pump Rate 450 gpm, 1,750 psi. RPM 25, Torque 3,500 ft Ilbs. Experienced 15,000# Overpull at 7,450', Torque Increased to 10,000 ft Ilbs, Torque Broke Back to 3,500 ft Ilbs, Lost Overpull. Increased RPM to 40, Torque 4,500 ft Ilbs to 6,000 ft Ilbs, Drag 5,000# - 10,000# from 7,450' to 7,250'. Continued to POOH While Pumping and Rotating from 7,250' to 6,950'. Pump Rate 450 gpm, 1,750 psi, RPM 50, Torque 4,000 ft Ilbs to 5,500 ft Ilbs. Drag 5,000#. POOH from 6,950' to 6,790' Without Pumps or Rotation, No Problems. 23:00 - 23:30 0.50 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep wI BHA in 9-5/8" Casing. Pump Rate 550 gpm, 2,250 psi, Rotated Drill String 120 RPM. Observed Hole Unload Fair Amount of Cuttings wI Sweep. Circulated Until Returns Over Shaker were Clean. 23:30 - 00:00 0.50 DRILL P INT1 Serviced Top Drive and Blocks. 3/4/2004 00:00 - 02:00 2.00 DRILL P INT1 Held PJSM. Slipped and Cut Drilling Line. Inspected and Adjusted Brakes. 02:00 - 04:00 2.00 DRILL P INT1 Oriented Tool Face 80 deg Right. RIH after Wiper Trip to 10,230'. Tagged Up at 10,230'. Attempted to Work Through Tight Spot wI No Success. 04:00 - 05:00 1.00 DRILL P INT1 M I U Top Drive, Washed and Reamed from 10230' to 10,322'. Pump Rate 475 gpm, 2,200 psi. RPM 45, Torque 6,500 ft Ilbs. 05:00 - 07:00 2.00 DRILL P INT1 Pumped and Circulated Around 2 - 30 bbl Hi-Vis Sweeps. Pump Rate 500 gpm, 2,470 psi. Total Circulation 3 x Bottoms Up. Rotated 120 RPM, Torque 6,500 ft Ilbs and Reciprocated Pipe While Circulating. Printed: 3/15/2004 10: 15: 17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/412004 07:00 - 14:00 7.00 DRILL P INT1 Monitored Well, Well Static. POOH wI 5" DP to 9,700'. Pumped Dry Job, Blew Down Top Drive. POOH wI 5" DP to 6,800'. No Excessive Drag, No Overpull Pulling BHA Through Window. Dropped Rabbit Down Drill String. Continued to POOH wI 5" DP to 3,980'. Calculated Fill 45 bbls, Actual Fill = 50.5 bbls. 14:00 - 16:30 2.50 DRILL P INT1 Changed Out 5" DP Equipment f/ 4" DP Equipment. POOH wI BHA. Stood Back 4" DP in Derrick. Broke Out and LID Directional BHA. 16:30 - 17:30 1.00 DRILL P INT1 Cleared and Cleaned Rig Floor. 17:30 - 18:00 0.50 CASE P LNR1 R I U 7" Casing Equipment. 18:00 - 18:30 0.50 CASE P LNR1 Held PJSM wI Rig Crew, Casing Crew, Toolpusher and Drilling Supervisor. 18:30 - 19:00 0.50 CASE P LNR1 M I U Float Shoe Joint, 1 Jt of 7" Casing wI Float Collar and 3rd Joint wI Insert Landing Collar. Filled Casing and Checked Float Equipment, OK. Bakerloc'd All Connections on Shoe Track. 19:00 - 23:30 4.50 CASE P LNR1 M I U and RIH wI 87 Joints 7", 26#, L-80, BTC Casing. Average M I U Torque 8,500 ft Ilbs. Filled Every Joint on the Fly, Stopped and Completely Filled Casing String Every 10 Joints. 23:30 - 00:00 0.50 CASE P LNR1 RID 7" Handling Equipment, R I U 5" DP Handling Equipment. P I U and M I U 7" x 9-5/8" Baker HMC Liner Hanger wI 7" x 9-5/8" ZXP Liner Packer and Tie Back Sleeve. 3/5/2004 00:00 - 01 :00 1.00 CASE P LNR1 Held PJSM. M I U 1 Stand of 5" DP, R I U Circulating Head and Lines. Pumped and Circulated 1 x Liner Volume. Pump Rate 5 bpm, 500 psi. Monitored Well, Well Static. Blew Down Lines. 01 :00 - 03:30 2.50 CASE P LNR1 RIH wI 7" Liner on 5" DP to 6,832' 03:30 - 05:00 1.50 CASE P LNR1 M I U Cementing Manifold onto 5" DP, Set Back on Pipe Skate. R I U Circulating Head and Lines. Pumped and Circulated 2 x 5" DP and Liner Volume. Pump Rate 10 bpm, 1,150 psi. Established Parameters: String Weight Up 175,000#, String Weight Down 160,000#. Monitored Well, Well Static. Blew Down Lines. 05:00 - 07:00 2.00 CASE P LNR1 RIH wI 7" Liner on 5" DP to 10,300'. Observed Slight Drag While Running Liner Through Kingak. No Adverse Hole Conditions or Fill. 07:00 - 08:00 1.00 CASE P LNR1 M I U Cement Head wI DP Dart to 5" DP. R I U Cementing Hose and Secured wI Safety Lines. 08:00 - 11 :00 3.00 CASE P LNR1 RIH to 10,322', Tagged Bottom. Engaged Pump and Staged up from 0.85 bpm, 150 psi to 4.0 bpm, 600 psi. Reciprocated Stretch in Pipe 150,000# to 250,000#, Kept Shoe Off of Bottom. Attempted to Increase Pump Rate from 4 bpm, 600 psi to 4.5 bpm, Hole Packed Off. Reduced Pump Rate and Staged Back up to 4 bpm, 600 psi. Attempted to Increase Pump Rate from 4 bpm, 600 psi to 4.5 bpm, Hole Packed Off. Reduced Pump Rate and Staged Back up to 4 bpm, 600 psi. Without Moving Pipe. Total Volume Pumped 1-1/2 times Bottoms Up Prior to Cement Job. 7" Liner Set As Follows: Item Length Depth Float Shoe 1.65' Printed: 3/15/2004 10:15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/512004 08:00 - 11 :00 3.00 CASE P LNR1 10,322.00' 1 Jt 7" 26.0# L-80 BTC Csg 41 .45' 10,278.90' Float Collar 0.94' 10,277.96' 1 Jt 7" 26.0# L-80 BTC Csg 41.50' 10,236.46' 1 Jt 7" 26.0# L-80 BTC Csg wllnsrt Ld Collar 41.47' 10,194.99' 84 Jts 7" 26.0# L-80 BTC Csg 3,474.96' 6,720.03' 7" x 9-5/8" HMC Liner Hanger 6.67' 6,713.36' 7" x 9-5/8" ZXP Liner Top Packer 6.07' 6,707.29' 7" Tie Back Sleeve 11.63' 6,695.66' 11 :00 - 12:30 1.50 CEMT P LNR1 Held PJSM wI Dowell Crew, Rig Crew, Truck Drivers, Toolpusher and Drilling Supervisor. Switched Over to Dowell. Pumped 5 bbls of Water at 2.8 bpm, 490 psi. Shut in Cement Manifold and Tested Lines to 4,000 psi. OK. Pumped 25 bbls 11.5 ppg Mud Push Pump Rate 3.1 bpm, 550 psi. Pumped 38 bbls, (184 sX), 15.8 ppg Premium Tail Cement wI 0.20 %bwoc Antifoam - 0.30 %bwoc Dispersant - 0.40 %bwoc Fluid Loss - 0.08 %bwoc Retarder. Pumped Cement at the Following Rates: Pumped Rate Pressure 5.0 bbls 2.90 bpm 670 psi 10.0 bbls 3.00 bpm 630 psi 15.0 bbls 2.50 bpm 640 psi 20.0 bbls 2.60 bpm 600 psi 25.0 bbls 2.50 bpm 350 psi 30.0 bbls 2.60 bpm 515 psi 35.0 bbls 2.60 bpm 220 psi 38.0 bbls 2.70 bpm 350 psi Dropped DP Dart and Pumped 5 bbls of Water at 2.5 bpm, 230 psi. Switched to Rig Pumps and Displaced wI 244.0 bbls Mud at the Following Rates: Pumped Rate Pressure 15.0 bbls 4.00 bpm 100 psi 50.0 bbls 4.00 bpm 120 psi 100.0 bbls 4.00 bpm 325 psi Drill Pipe Dart Latched Up, Pressure Increased to 700 psi, Observed Wiper Plug Shear, Pressure Decreased to 350 psi 150.0 bbls 4.00 bpm 425 psi 200.0 bbls 4.00 bpm 500 psi 240.0 bbls 4.00 bpm 950 psi Wiper Plug Bumped wI 249.5 bbls Total Displacement Pumped. Pressured up to 3,700 psi. Cement in place @ 1235 hrs. 100% Returns wI No Losses While Cementing and Displacing. 12:30 - 13:00 0.50 CEMT P LNR1 Pressured Up to 3,700 psi to Set Liner Hanger. Slacked Off and Stacked 50,000# on Hanger to Confirm Hanger Set. Bled Printed: 3/15/2004 10:15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 2/24/2004 3/13/2004 Spud Date: 8/28/1980 End: 3/13/2004 3/512004 12:30 - 13:00 0.50 CEMT P LNR1 Off Pressure and Checked Floats, Floats Held. Rotated Drill String to the Right 15 Turns to Release From Liner, Torque 4,500 ft Ilbs. Pressured Up to 1,000 psi and Picked Up on Drill String. Pressure Bled Off Indicating Liner Running Tool Released from Liner. Engaged Pumps and Circulated Hole to Clear Possible Cement and Contaminated Mud Off Liner Top. Pump Rate 14 bpm, 875 psi. Total Volume Pumped 40 bbls. Slowed Pump Rate to 1.75 bpm, 170 psi. RIH and Stacked 50,000# on Liner Top, Good Surface Indication of ZXP Packer Setting, Continued to Slack Off, Stacked Total of 100,000# on ZXP Packer. Picked Up and Repeated Process of Stacking 100,000# on ZXP Packer, Rotated and Stacked 100,000# on ZXP Packer to Ensure Packer Set. PI U on Drill String Leaving Tool Stinger Inside of Liner Top Appx 5'. 13:00 - 14:00 1.00 CEMT P LNR1 Engaged Pumps and Circulate Bottoms Up to Clean Up Well bore. Pump Rate 14 bpm, 875 psi. Did Not Circulate Back any Cement. 14:00 - 14:30 0.50 CEMT P LNR1 Broke Out and LID Cement Manifold. Blew Down Lines. 14:30 - 17:30 3.00 CEMT P LNR1 POOH wI 5" DP. 17:30 - 18:30 1.00 CEMT P LNR1 Broke Out and LID 5" HWDP and Liner Running Tool. 18:30 - 19:00 0.50 BOPSU P LNR1 Held PJSM. M I U Retrieving Tool, Latched and Pulled Wear Bushing. R I U BOPE Test Equipment. 19:00 - 23:30 4.50 BOPSU P LNR1 Held PJSM. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves to 3,500 psi High I 250 psi Low. Tested Annular Preventer to 3,500 psi High 1250 psi Low. All Above Tests Held fl 5 Min wI No Leaks or Pressure Loss. Witness of BOPE Test Waived by AOGCC Rep Chuck Scheve. 23:30 - 00:00 0.50 BOPSU P LNR1 RID BOPE Test Equipment. Ran and Set Wear Bushing. 3/6/2004 00:00 - 06:00 6.00 DRILL P PROD1 Held PJSM. M I U 6-1/8" Directional BHA: Hycalog 6-1/8" DS277 - 7/8 3-Stage Motor Set at 1.83 cut fl Float - NM Pony Collar - MWD - 3 x NM Flex Collars - Circulation Sub - Jars - 183 Jts 4" DP - XO. Total BHA Length 6,034.77, Oriented Motor to MWD. Pulse Tested MWD, OK. PI U 84 Jts 4" DP from Pipe Shed. 06:00 - 08:30 2.50 DRILL P PROD1 RIH wI 6-118" BHA on 5" DP to 10,232'. Filled DP Every 30 Stands. 08:30 - 09:00 0.50 DRILL P PROD1 Held PJSM. M I U Topdrive. Engaged Pump and Established Circulation. 250 gpm @ 1650 psi Shut Down Pump and Blew Down Topdrive. 09:00 - 10:00 1.00 EVAL P PROD1 Closed Pipe Rams. Pressure Tested?" x 9-5/8" and Liner Top to 3,500 psi fl 30 minutes, OK. Calculated Strokes to Pressure Up to 3,500 psi, 114 - 6.5. bbls, Actual Strokes 117 - 6.75 bbls. Bled off Pressure, Opened Rams. 10:00 - 12:30 2.50 DRILL P PROD1 Drilled Out Cement and Float Equipment from 10,232' to Ip 10,322. WOB 5,000# - 10,000#, RPM 10, Torque 5,500 ft Ilbs, Pump Rate 250 gpm, 1,650 psi. 12:30 - 15:30 3.00 DRILL PROD1 Held PJSM wI Drilling Crew, Mud Engr, Truck Drivers, Tool Pusher and Drilling Supervisor. Pumped 100 bblsl Water Followed by 50 bbl Spacer Ahead, Displaced Wellbore to 8.4 ppg Flo-Pro Mud. Beginning Pump Rate 230 gpm, 1,450 psi. 15:30 - 16:30 1.00 DRILL P PROD1 Drilled New Hole f/1 0,322 to 10,420' by sliding Drilling Printed: 3/15/2004 10:15:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/612004 15:30 - 16:30 1.00 DRILL P PROD1 Parameters 5,000# to 10,000# WOB 250 gpm at 1,650 psi. AST.= .75 Pulled Back into Casing. 16:30 - 17:00 0.50 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Performed FIT. Strokes Pmp'd Pressure 2 110 psi 4 164 psi 6 230 psi 8 285 psi 10 336 psi 12 395 psi 14 452 psi 16 509 psi 18 571 psi 20 632 psi 22 690 psi 24 742 psi MW 8.4 ppg, Shoe TVD 8,890', Pressure 742 psi = 10.01 ppg EMW. Held Pressure f/10 minutes Lost 42 psi. Bled down Pressure, Opened Pipe Rams. 17:00 - 22:30 5.50 DRILL P PROD1 Drilled 6-1/8" Directional Hole by Sliding from 10,342' to 10,440'. WOB 10,000#, Motor RPM 85, Pump Rate 260 gpm, SPP Off Bottom 1,350 psi, On Bottom 1,650 psi. String Weight Up 195,000#, String Weight Down 165,000#. AST 4.53 hrs. Slide Sheet Depth Tool Face 10,322' - 10,342' HS 10,342 - 10,384 HS 10384' - 10,416 HS 10,416' - 10,440' HS Observed Gas in Mud at Bell Nipple, Flow Increased From 25% to 35%, No Pit Gain. 22:30 - 23:00 0.50 DRILL P PROD1 Picked Up Off Bottom and Shut Down Pump. Observed Well for Flow Due to Possible Gas I Mud Swap in Shublick. Mud Rolling in Bell Nipple wI Slight Drop in Fluid Level. 23:00 - 00:00 1.00 DRILL P PROD1 Circulated Bottoms Up, Pump Rate 260 gpm, 1,350 psi. Circulated Out Gas. Flow 35% - 29%, Losses While Circulating 10 bbls. MW wI Pressure Scales 8.4 ppg, MW wI Balance Scales 7.9 ppg. At Bottoms Up, Flow 25%, No Gas at Bell Nipple, No Losses. Shut Down Pumps, Flow Checked Well, Well Static. 3/7/2004 00:00 - 06:00 6.00 DRILL P PROD1 Drilled 6-1/8" Directional Hole by Sliding from 10,440' to 10,550'. WOB 10,000#, Motor RPM 85, Pump Rate 260 gpm, SPP Off Bottom 1,350 psi, On Bottom 1,550 psi. String Weight Up 195,000#, String Weight Down 165,000#. Circulated Up Connection Gas on Bottoms Up After Pump Restart. Average Connection Gas 4 bbls, After Circulating Out Connection Gas, Average Losses 6 bbls, Net Loss 2 bbls. Slide Sheet Depth Tool Face 10,440' - 10,450' HS 10,450' - 10,478' 20R 10,478' - 10,510' 20R Printed: 3/15/2004 10: 15: 17 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17 -04 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/7/2004 00:00 - 06:00 6.00 DRILL P PROD1 10,510' - 10,541' 20R 06:00 - 12:00 6.00 DRILL P PROD1 Drilled 6-1/8" Directional Hole From 10,550' to 10,790'. WOB 10,000#, Motor RPM 85, Drill String RPM 50, Pump Rate 250 gpm, SPP Off Bottom 1,380 psi, On Bottom 1,680 psi. String Weight Up 195,000#, String Weight Down 175,000#. Rotating Wt# 188,000 Total Losses from Midnight to Noon 45 bbls. Slide Sheet Depth Tool Face 10,541' - 10,572' 0 10,572' - 10,603' 25R 10,603' - 10,634' 25R 10,634' - 10,664' 25R 10,664 - 10,698' 0 10,698' - 10,729' 150R 10,729' - 10,760' 0 10,760' - 10,794' 0 12:00 - 00:00 12.00 DRILL P PROD1 Held PTM and PJSM For All Tasks, Drilled 6-1/8" Directional Hole From 10,790' to 11,484'. WOB 10,000#,to 15,000# Motor RPM 87, Drill String RPM 60, Pump Rate 260 gpm, SPP Off Bottom 1,660 psi, On Bottom 1,860 psi. String Weight Up 210,000#, String Weight Down 175,000#. Rotating Wt# 186,000 @ 10,950' a 25 BBL High Vis Sweep was pumped, Which Did Not bring Back any Additional Cuttings. Continue To Observe Gas at The Bell Nipple,Once Bottoms Up is Achieved After Connections. Adding H20 At 10 bbl/hr Losses From Noon to Midnight Were 9 BBLS. Slide Sheet Depth Tool Face 10,794' - 10,810' 150R 10,900' - 10,951' 30R 11,000' - 11,041' 50R 11,090' - 11,130' 100R 11 ,170' - 11,200' 100R 11,200 - 11,213' 100R 11,296' - 11,311' 180 11,364' - 11,380' 0 11,453' -11,461' 180 3/8/2004 00:00 - 04:30 4.50 DRILL P PROD1 Held PJSM. Drilled ahead From 11,484' to 11,635' WOB 10,000# To 15,000# Motor RPM 87, Drill String RPM 60, Pump Rate 265 gpm, SPP Off Bottom 1,680 psi, On Bottom 1,880 psi. String Weight Up 210,000#, String Weight Down 175,000#. Rotating Wt# 185,000. 04:00 - 06:30 2.50 DRILL P PROD1 Racked Back One Stand, Pump and Circulated around 25 BBL High Vis Sweep Pump Rate 270 GPM SPP 1500 psi. 60 RPM. At 11,635' The MWD Logs and also Bottoms up Samples indicated That we had Drilled into the Shublik, At This Point We discused With Geology The options,The Best seems to be Pulling Back to 11,365' Were in the original Well bore there was a 20' Slide made with a HS TF, And Sidtrack the well at this depth. 06:30 - 07:00 0.50 DRILL C PROD1 Held PJSM Pump Out of the Hole To 11,365' TVD 8,996' P/U WT. 210,000# 265 GPM. SPP 1,510 PSI. 07:00 - 09:00 2.00 DRILL C PROD1 Began Trenching From 11,340' To 11,365' Holding a 180 Deg Printed: 3/15/2004 10:15:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -04 17 -04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/812004 07:00 - 09:00 2.00 DRILL C PROD1 Toolface Pumping 265 GPM 1,510 PSI 09:00 - 15:00 6.00 DRILL C PROD1 Started Time Drilling At 11,365' to 11,368' @ 1 fph. 11,368' to 11,370' @ 2 fph 11 ,370' to 11,381' @ 5 fph. Holding a 180 deg Toolface, 260 Gpm, SPP 1,530 psi. At 11,381' We were seeing Good Differential Pressure, and some reactive torque from the Motor and were able to start applying more weight to the Bit. At 11,422' Survey Indicates that the well is Sidetracked. Losses from Midnight to Noon 39 BBLS Slide Sheet Depth Tool Face 11,365' - 11,422' 180 15:00 - 00:00 9.00 DRILL C PROD1 Drilled 6-1/8" Directional Hole From 11,422' to 11,866'. WOB 10,000#,15,000# Motor RPM 89, Drill String RPM 60, Pump Rate 272 gpm, SPP Off Bottom 1,510 psi, On Bottom 1,820 psi. String Weight Up 200,000#, String Weight Down 175,000#. Rotating Wt# 188,000 Total Losses bbls. Slide Sheet Depth Tool Face 11,365' - 11,381' 180 11,381' - 11,396' 150R 11 ,396' - 11 ,422' 120R 11,453' - 11,468' 45L 11,549' - 11,555' 150L 11,555' - 11,575' 90L 11,645' - 11,690' 90L 11,738' - 11,766' 20R 11,801 - 11,831' 50L 3/9/2004 00:00 - 07:00 7.00 DRILL C PROD1 Held PTSM and PJSM, Drilled 6-1/8" Directional Hole From 11,866' to 12,048'. WOB 10,000#, 15,000# Motor RPM 89, Drill String RPM 60, Pump Rate 272 gpm, SPP Off Bottom 1,510 psi, On Bottom 1,820 psi. String Weight Up 200,000#, String Weight Down 175,000#. Rotating Wt# 188,000 07:00 - 09:00 2.00 DRILL C PROD1 Pump 25 BBL High Vis sweep and Circulate hole clean, Pump rate 260 gpm. 1,800 psi. Total strokes pumped 12,500. 09:00 - 12:00 3.00 DRILL C PROD1 Monitor well for 15 min. Circulate Bottoms up at 150 gpm. @ 800 psi. check for gas, Total Strokes pumped 9,400 Total gas 12:00 - 13:30 I cut mud back 198 bbls. 1.50 DRILL C PROD1 Held PJSM. POH 10 stands back reaming From 12,048' to 11,138' circulating rate 150 gpm. @ 800 psi. 20 rpm. with 5,000 # Torque. Pickup wt. 200,000# Down wt. 180,000# Rotating wt. 188,000# 13:30 - 16:00 2.50 DRILL C PROD1 Circulate Bottoms up, Gas at surface, 5,784 strokes, and cleaned up by 7,688 strokes = 109 bbls. Gas cut to 8.0 ppg. 16:00 - 17:00 1.00 DRILL C PROD1 Held PJSM. POH 10 stands back reaming From 11,138' to 10,289' circulating rate 150 gpm. @ 800 psi. 20 rpm. with 4,000 # Torque. Pickup wt. 200,000# Down wt. 180,000# Printed: 3/15/2004 10:15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/912004 16:00 - 17:00 1.00 DRILL C PROD1 Rotating wt. 188,000# 17:00 - 19:30 2.50 DRILL C PROD1 Circulate Bottoms up, Gas at surface, 5,820 strokes, and cleaned up by 8,000 strokes = 129 bbls. Gas cut to .7.9 ppg. 19:30 - 20:00 0.50 DRILL C PROD1 Held PJSM. Service Rig and Topdrive. 20:00 - 21 :30 1.50 DRILL C PROD1 Held PJSM. Trip in the Hole from 10,289' to 12,048' Did not encounter any tight hole, Trip went smooth 21 :30 - 00:00 2.50 DRILL C PROD1 Pump 25 bbl High vis sweep @ 270 gpm 1,600 psi., started seeing gas cut mud 5,430 strokes into the Bottoms up The Calculated Bottoms up was 7,780 stks. At 11,000 stks. returns cleared up. Had a total of 324 bbls of gas cut mud. The lowest mud weight coming back was 7.8 ppg. with balanced scale. Monitor well for 15 min. Well Static. 3/10/2004 00:00 - 02:30 2.50 DRILL C PROD1 Held PTSM and PJSM. POH to the 7" casing shoe, By pumping out at 270 gpm. with 1,600 psi. pickup wt. 200,000#, did not rotate. While Pumping out pumped a total of 221 bbls. Did not see excess drag while Tripping out. 02:30 - 04:30 2.00 DRILL C PROD1 Circulate Bottoms up inside the 7" casing shoe. 270 gpm with 1,450 psi. At 3,700 stks. (215 bbls) started getting gas cut mud back to surface. Then at 5100 stks. returns cleaned up. Circulated a total of 81 bbls of gas cut mud. Stop circualting At 04:20 to monitor well 04:30 - 06:30 2.00 DRILL C PROD1 Monitor well For Two hours. 4 bbl Loss 06:30 - 08:00 1.50 DRILL C PROD1 Circulate Bottoms up to check for gas cut mud, No gas cut mud. Mud weight out with Balanced scale was 8.5 ppg. Total stks pumped 11,000 = 641 bbls. Pump rate 270 gpm with 1 ,420 psi. 08:00 - 09:30 1.50 DRILL C PROD1 Monitor Well, for 30 min. well is static. Pump and spot 27 bbl High vis Pill at 7" Shoe. Total stks pumped = 2,830 at 270 gpm 1,500 psi. Monitor well for 15 min. well static. 09:30 - 14:30 5.00 DRILL C PROD1 Held PTSM, PJSM. POH, 15 fpm. From 10298' to 6,873' No problem 14:30 - 15:30 1.00 DRILL C PROD1 Drop Ball to shear circulating Sub, sheared with 2,000 psi. Circulate and condition Mud form Liner job. pump rate 461 gpm. @ 700 psi. Monitor well for 15 min. Well static. 15:30 - 19:00 3.50 DRILL C PROD1 Held PJSM. POH From 6,873' to 190' Hole taking proper Fill. 19:00 - 20:00 1.00 DRILL C PROD1 Lay Down BHA. Clear Floor (Bit was cored out) 20:00 - 21 :00 1.00 CASE P COMP RIU Casing Tools Held PJSM with all Rig Personel 21 :00 - 00:00 3.00 CASE P COMP Pickup 4 1/2" Slotted Liner As follows Float Shoe 1jt 41/2" L-80 IBT 12.6# Solid Liner - 40 jts.4 1/2" L-80 IBT 12.6# Slotted Liner - 4 jts. IBT L-80 Solid Liner - Baker HMC Hydraulic liner hanger. 3/11/2004 00:00 - 02:00 2.00 CASE P COMP Held PTSM. RIH With 41/2" Slotted Liner on 4" DP To a depth of 4769' (4 1/2" Float shoe Depth) Stage In with Liner Stopping every 3,000' to circulate gas from well bore. 02:00 - 03:00 1.00 CASE P CaMP Circulate Bottoms up, At 4,769' With initial pump rate of 230 gpm @ 400 psi. had to slow pumping rate down in order for shakes to handle the thick mud coming back. (pressure limit while circulating is 800 psi as-per Baker Hand, Liner is pinned to set at 1,250 psi.) Pumped a total of 200 bbls and did not have any indication of gas to surface. Mud weight in and out was 8.5 ppg. with balanced scale. 03:00 - 05:00 2.00 CASE P COMP Held PJSM. RIH with 4 1/2" Liner on 4" DP To 7,770 ,Running Printed: 3/15/2004 10:15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17 -04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 3/11/2004 03:00 - 05:00 2.00 CASE P COMP speed 1.5 min. per stand as per Baker Rep. Hole giving the proper displacment. 05:00 - 06:30 1.50 CASE P COMP Circulate bottoms up, At 7,770, pump rate 200 gpm. At 470 psi. No gas back to surface Pumped,402 bbls. Blow down Topdrive. 06:30 - 08:30 2.00 CASE P COMP RIH with 41/2" Slotted Liner to 10,293' 08:30 - 1 0:30 2.00 CASE P COMP Circulate bottoms up, At 10,293' pump rate 145 gpm. At 480 psi. No gas back to surface Pumped,443 bbls. Blow down Topdrive. 10:30 - 11 :30 1.00 CASE P CaMP RIH with 41/2" Slotted Liner to 11,960' (no problems) 11 :30 - 12:00 0.50 CASE P CaMP Makeup 10' Pup for space out, and circulate from 11,960' to 12,048', pump rate= 60 gpm with 440 psi. 12:00 - 13:00 1.00 CASE P CaMP Drop Ball, Pressure up to 2,500 psi to set Liner Hanger, Slack off 30k to ensure hanger is set, pressure up to 3,200 psi to shear out. Pulled setting tool out off liner hanger. Top of Tie Back Sleeve @ 10,157' Pickup weight prior to setting liner hanger= 200,000# Down weigth = 170,000# Released from Hanger up weigth = 190,000# 13:00 - 15:00 2.00 CASE P CaMP Circulate Bottoms up, Pump rate 380 gpm. with 940 psi. Gas Cut Mud to surface at 7,800 stks. (454 bbls) Clean mud to surface 11,000 stks. (641 bbls) for 30 bbls mud was Gas cut to 7.4 ppg. 15:00 - 17:30 2.50 CASE P CaMP Held PJSM POH lay down 5" DP. From 10158' to 5855' (Hole taking proper fill) 17:30 - 00:00 6.50 CASE P COMP Held PJSM Change over to 4" handling equipment, Lay down 4"DP 3/12/2004 00:00 - 01 :30 1.50 CASE P COMP Held PTSM. Change Handling equipment to 5" and RIH with 24 stds. of 5" DP 01 :30 - 02:30 1.00 CASE P COMP Held PJSM. Cut Drilling Line and Service Rig. 02:30 - 05:00 2.50 CASE P CaMP POH Lay down 72 jts. 5" DP 05:00 - 06:00 1.00 RUNCO CaMP Pull Wear ring, Make Dummy run with Tubing Hanger 06:00 - 07:30 1.50 RUNCO CaMP Held PJSM. Rig up Casing Equipment. 07:30 - 14:00 6.50 RUNCO CaMP M/U & run 4.5 Completion Tail Assy, 'X' Nipple Assy & Baker S-3 Permanent Packer Assy. Continue running 4.5" 12.6# L-80 IBT-M Tubing as per Program. Makeup Torque 3,900 ftllbs. Ran a total of 154 Jts. + jewelry to 6664' 14:00 - 17:00 3.00 RUNCO CaMP R/U to Circulate, Displace the 9 5/8" x 4 1/2" annulus and tubing to 8.5 ppg. seawater @ 3 bpm. 275 psi. 17:00 - 20:30 3.50 RUNCO COMP Continue Running 4.5" 12.6# L-80 IBT-M Completion as-per Program. Ran a total of 237 jts. Tagged up With WLEG @ 10,168', Picked up out of Tie Back sleeve, and rotated string 90 deg. tagged up at 10,168' to confirm space out. Layed down Jt.# 237. Pick up weight 135,000#, Down weight 120,000# 20:30 - 00:00 3.50 RUNCO COMP Held PJSM. RIU to Reverse circulate.To changing remainder of well over to 8.5 ppg. seawater. Began pumping down annulus @ 2 bpm. @ 330 psi. Pumped at this rate for 20 bbls. to monitor Losses. Hole not taking fluid. Then increased rate to 3 bpm. @ 395 psi. Pumped 155 bbls 8.5 ppg. Seawater, Followed by 203 bbls 8.5 ppg seawater with corrosion inhibitor, 219 bbls Final Circulating pressure, 280 psi @ 3 bpm. 3/13/2004 00:00 - 05:00 5.00 RUNCO CaMP MIU Tubing Hanger and Landing Joint, Land Tubing and RILDS. WLEG @ 10165' Drop BOT 1-7/8" packer setting Printed: 3/15/2004 10:15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 7-04 1 7-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 05:00 - 06:00 1.00 BOPSU P CaMP 06:00 - 10:30 4.50 BOPSU P COMP 10:30 - 13:00 2.50 WHSUB P CaMP 13:00 - 14:00 1.00 WHSUR P COMP 14:00 - 14:30 0.50 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 - 18:00 3.00 WHSUR P COMP 18:00 - 19:00 1.00 WHSUR P COMP 19:00 - 22:00 3.00 WHSUR P COMP 22:00 - 23:30 1.50 WHSUR P COMP 23:30 - 00:00 0.50 RIGD P COMP Ball/Rod down 4.5" tubing. PJSM. Set packer by pressuring up on tubing to 3500 psi, lost 400 psi in 25 minutes. Pressured back up to 3,500 psi. Continued Bleeding off at same rate. Removed test Lines from annulus and tubing, No leaks. Bled pressure on tubing to 1800 psi. Then Pressured up on the annulus to 3,500 psi to test Packer, Held pressure for 30 min. OK Pressure on Tubing continued Bleeding off at the previous rateWhile testing packer. Noticed Fluid movement on top of Tubing hanger. Bled pressure off annulus, and Tubing, Pulled Landing joint, The rubber seal on the left hand thread connection was cut causing the leak. Retest Tubing to 3,500 psi. by closing Blind rams, held pressure for 30 min. Ok Pressured up on Annulus to shear DCR valve in Gas lift mandrel. sheared @ 2,400 psi. Pumped 3 bbls Down tubing to confirm valve is open. Install BPV.in tubing Hanger and test to 1,000 psi. Rig Down Testing equipment. Held PJSM. Nipple down BOP. Install BPV. Blow down circulating lines Nipple down Hyrdrill and install BOP lifting Ring, Continue Nipple down. Nipple Up Adapter Flange and Tree. Rig Up Lubricator and Pull BPV. Install TWC. Test Tree to 250 psi. Low, 5,000 High Rig Up Lubricator & Pull TWC. PJSM wI Little Red Hot Oilers. R/U HP pumping lines from Hot Oil truck to wellhead. Test lines to 3,000 psi. Pump 130 Bbls heated diesel down 41/2" X 9-5/8" Annulus. Freeze Protect Tubing & Annulus to 2200' TVD. U Tube Diesel From Annulus to Tubing. Install BPV in tubing hanger. Test to 1000 psi from below. RID Little Red's equipment. Secure well. Remove excess Sea water form pits and brine tanks. Clear Floor and Cellar areas of all drilling equipment. Rig Realeased from 17-04B @ 24:00 hrs 3/13/2004 Printed: 3/15/2004 10:15:17 AM e e DS17-04B Survey Report Schlumberger Report Date: 1D-Mar.()4 cr..nl: BP Exploration Alaska Field: Prudhoe Bay Un~ - EOA Structure I Slot: DS-17/17-04 Well: 17·04 Borehole: 17-04B UWVAPIII: 500292049802 Survey Name I Date: 17 -04B I March 10, 2004 TortI AHD/DDl/ERD ratio: 279.587" 15553.15 ft/6.3151 0.616 Grid Coordinate System: NAD27 Alaska State Planes. Zone 04, US Feet Location LatILong: N 70 12 25.285. W 148191.809 Location Grid NIE YIX: N 5928141.860 ftUS, E 708703.670 ftUS Grid Convergence Angle: +1.58346530' Grid Scale Factor: 0.99994948 Survey I DlS Computation Method: Minimum Curvature 1 Lubinski Vertical Section Azimuth: 192.210' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 63.00 ft relative to MSL Sea Bed I Ground Level Elevation: 34.50 ft relative to MSL Magnetic Declination: 25.491' Total Field Strength: 57598.310 nT Magnetic Dip: 80.844' Declination Date: March 08. 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North -> True North: +25.491' Local Coordinate. Referenced To: Well Head 493.00 0.25 32.00 493.00 430.00 0.37 1.00 -0.33 -0.19 0.25 0.25 0.00 5928141.52 708703.49 N 70 12 25.282 W 148191.815 593.00 0.25 50.00 593.00 530.00 -0.01 1.44 -0.01 0.09 0.08 0.00 18.00 5928141.86 708703.76 N 70 1225.285 W 148 19 1.807 693.00 0.50 125.00 693.00 630.00 -0.02 2.01 -0.12 0.62 0.50 0.25 75.00 5928141.76 708704.29 N 70 12 25.284 W 148 19 1.791 793.00 0.25 176.00 792.99 729.99 0.36 2.63 -0.59 0.99 0.39 -0.25 51.00 5928141.30 708704.68 N 70 1225.279 W 148 19 1.780 893.00 0.25 204.00 892.99 829.99 0.79 3.06 -1.00 0.92 0.12 0.00 28.00 5928140.88 708704.61 N 70 1225.275 W 148 19 1.783 993.00 0.00 180.00 992.99 929.99 1.00 3.27 -1.20 0.83 0.25 -0.25 0.00 5928140.68 708704.53 N 70 12 25.273 W 148191.785 1093.00 0.50 121.00 1092.99 1029.99 1.14 3.71 ·1.43 1.20 0.50 0.50 0.00 5928140.47 708704.91 N 70 12 25.271 W 148 19 1.774 1193.00 0.50 147.00 1192.99 1129.99 1.59 4.57 -2.02 1.81 0.22 0.00 26.00 5928139.89 708705.54 N 70 12 25.265 W 148 19 1.757 1293.00 0.50 110.00 1292.98 1229.98 1.95 5.41 -2.53 2.46 0.32 0.00 -37.00 5928139.40 708706.20 N 70 1225.260 W 148 19 1.738 1393.00 0.75 135.00 1392.98 1329.98 2.37 6.48 -3.14 3.33 0.36 0.25 25.00 5928138.81 708707.09 N 70 12 25.254 W 148 19 1.712 1493.00 0.50 121.00 1492.97 1429.97 2.86 7.57 -3.83 4.17 0.29 -0.25 -14.00 5928138.15 708707.95 N 701225.247 W 148 19 1.688 1593.00 0.50 92.00 1592.97 1529.97 2.93 8.42 -4.07 4.98 0.25 0.00 -29.00 5928137.93 708708.76 N 70 12 25.245 W 148 19 1.665 1693.00 0.25 148.00 1692.97 1629.97 3.00 9.03 -4.27 5.53 0.42 -0.25 56.00 5928137.74 708709.32 N 70 1225.243 W 148 19 1.649 1793.00 0.50 123.00 1792.96 1729.96 3.32 9.68 -4.69 6.01 0.29 0.25 -25.00 5928137.33 708709.81 N 70 12 25.239 W 148191.635 1893.00 0.75 46.00 1892.96 1829.96 2.93 10.62 -4.48 6.85 0.80 0.25 -77.00 5928137.57 708710.64 N 70 1225.241 W 148191.610 1993.00 2.00 27.00 1992.93 1929.93 0.70 13.00 -2.47 8.11 1.31 1.25 -19.00 5928139.62 708711.85 N 70 12 25.261 W 14819 1.574 2093.00 1.75 19.00 2092.88 2029.88 -2.51 16.27 0.53 9.40 0.36 -0.25 -8.00 5928142.65 708713.05 N 701225.290 W 148191.536 2193.00 1.00 30.00 2192.85 2129.85 -4.85 18.66 2.73 10.34 0.79 -0.75 11.00 5928144.87 708713.93 N 70 1225.312 W 14819 1.509 2293.00 1.00 48.00 2292.83 2229.83 -6.39 20.39 4.07 11.42 0.31 0.00 18.00 5928146.24 708714.97 N 70 1225.325 W 148 191.478 2393.00 0.75 78.00 2392.82 2329.82 -7.37 21.88 4.79 12.71 0.51 -0.25 30.00 5928147.00 708716.24 N 70 1225.332 W 148 191.440 2493.00 0.75 107.00 2492.81 2429.81 -7.58 23.17 4.73 13.98 0.38 0.00 29.00 5928146.98 708717.51 N 70 1225.332 W 148 191.404 2593.00 1.00 118.00 2592.80 2529.80 -7.29 24.69 4.13 15.37 0.30 0.25 11.00 5928146.42 708718.92 N 70 1225.326 W 148191.363 2693.00 1.00 137.00 2692.79 2629.79 -6.56 26.42 3.09 16.74 0.33 0.00 19.00 5928145.41 708720.32 N 70 1225.315 W 148 19 1.323 2793.00 0.75 155.00 2792.77 2729.77 -5.54 27.93 1.85 17.61 0.37 -0.25 18.00 5928144.20 708721.22 N 70 12 25.303 W 148 19 1.298 2893.00 0.75 163.00 2892.77 2829.77 -4.44 29.24 0.64 18.08 0.10 0.00 8.00 5928142.99 708721.72 N 70 12 25.291 W 148 19 1.285 2993.00 0.50 146.00 2992.76 2929.76 -3.57 30.32 -0.35 18.51 0.31 -0.25 -17.00 5928142.02 708722.19 N 70 1225.281 W 148191.272 3093.00 0.50 137.00 3092.76 3029.76 -3.02 31.19 -1.03 19.06 0.08 0.00 -9.00 5928141.35 708722.75 N 70 12 25.275 W 148191.256 3193.00 0.50 131.00 3192.75 3129.75 -2.56 32.06 -1.64 19.68 0.05 0.00 ·6.00 5928140.77 708723.39 N 70 12 25.269 W 148191.238 3293.00 0.25 156.00 3292.75 3229.75 -2.17 32.71 -2.12 20.10 0.29 -0.25 25.00 5928140.29 708723.82 N 70 12 25.264 W 148191.226 3393.00 0.50 150.00 3392.75 3329.75 -1.68 33.36 -2.70 20.41 0.25 0.25 ·6.00 5928139.72 708724.14 N 70 12 25.258 W 148191.217 3493.00 0.50 160.00 3492.74 3429.74 -0.98 34.23 -3.49 20.77 0.09 0.00 10.00 5928138.95 708724.53 N 701225.251 W 148 19 1.206 3593.00 0.50 171.00 3592.74 3529.74 -0.21 35.10 -4.33 20.99 0.10 0.00 11.00 5928138.11 708724.77 N 70 1225.242 W 148 19 1.200 3693.00 0.50 196.00 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15.00 199.00 4483.40 4420.40 105.63 142.67 -104.01 -18.80 1.25 1.25 0.00 5928037.38 708687.75 N 70 12 24.262 W 148 192.355 4593.00 17.00 194.00 4579.52 4516.52 133.10 170.21 -130.43 -26.55 2.43 2.00 -5.00 5928010.75 708680.73 N 70 12 24.002 W 148 192.580 4693.00 19.00 192.00 4674.63 4611.63 163.99 201.11 -160.54 -33.47 2.09 2.00 -2.00 5927980.46 708674.65 N 701223.706 W 148 192.781 4793.00 21.75 192.00 4768.36 4705.36 198.80 235.92 -194.59 -40.71 2.75 2.75 0.00 5927946.23 708668.35 N 70 1223.371 W 148 192.991 4893.00 23.75 194.00 4860.58 4797.58 237.46 274.59 -232.26 -49.44 2.14 2.00 2.00 5927908.33 708660.67 N 70 12 23.001 W 148 193.244 SurveyEditor Ver 3.1 RT-SP3.03-HF4.oo Bld( d031 rt-546 ) 17-04\ 17-04\17-04B\17·04B Generated 4/15/2004 4:29 PM Page 1 of 3 e e 5493.00 38.50 191.00 5374.22 5311.22 544.25 581.41 -531.97 -114.98 2.57 2.50 -1.00 5927606.95 708603.43 N 70 1220.053 W148195.146 5593.00 42.00 191.00 5450.53 5387.53 608.84 646.02 -595.38 -127.31 3.50 3.50 0.00 5927543.22 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11938.23 92.78 265.15 9010.80 8947.80 3881.86 5443.61 -3211.08 -3515.01 7.69 -7.09 -3.00 5924835.04 705278.91 N 70 11 53.696 W 1482043.777 11967.26 86.67 261.81 9010.93 8947.93 3891.17 5472.63 -3214.38 -3543.83 23.98 -21.05 -11.51 5924830.96 705250.19 N 70 11 53.663 W 1482044.613 11993.80 85.68 262.95 9012.70 8949.70 3900.15 5499.11 -3217.89 -3570.08 5.68 -3.73 4.30 5924826.72 705224.06 N 70 11 53.629 W 1482045.374 12048.00 85.68 262.95 9016.79 8953.79 3917.98 5553.15 -3224.52 -3623.72 0.00 0.00 0.00 5924818.61 705170.63 N 70 11 53.563 W 1482046.930 Leaal DescriDtion: Northina IV) [ftUS] Eastina IXI [ftUS] Surface: 2792 FSL 4829 FEL S22 T10N R15E UM 5928141.86 708703.67 BHL; 4847 FSL 3180 FEL S28 T10N R15E UM 5924818.61 705170.63 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) 17-04\17-04\ 17-04B\ 17-04B Generated 4/15/2004 4:29 PM Page 3 01 3 e e bp DS17-04BPB1 Survey Report Schlumberger Report Date: 8-Mar-04 Client: BP Exploration Alaska Field: Prudhoe Bay Unü - EOA Structure I Slot: DS-17/17-04 Well: 17-04 Borehole: 17-04BPB1 UWUAPI': 500292049871 Survey Name I Date: 17-04BPB11 March 08, 2004 TortI AHD I DDI I ERD ratio: 235.280' 15139.73 ft 16.1911 0.571 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatIlon9: N 70 12 25.285. W 148 19 1.809 Location Grid NlE Y/)(: N 5928141.860 ftUS, E 708703.670 ftUS Grid Convergence An91e: +1.58348530' Grid Scale Factor: 0.99994948 Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 248.150' Vertical Section Ori9in: N 0.000 ft, E 0.000 ft TVD Reference Datum: RTE TVD Reference Elevation: 63.00 ft relative to MSL Sea Bed I Ground Level Elevation: 34.50 ft relative to MSL Ma9netic Declination: 25.506' Total Field Strength: 57597.368 nT Magnetic Dip: 80.843' Declination Date: February 25, 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North -> True North: +25.506' Local Coordinates Referenced To: Well Head 493.00 0.25 32.00 493.00 430.00 0.30 1.00 -0.33 -0.19 0.25 0.25 0.00 5928141.52 708703.49 N 70 12 25.282 W 148191.815 593.00 0.25 50.00 593.00 530.00 -0.08 1.44 -0.01 0.09 0.08 0.00 18.00 5928141.86 708703.76 N 70 12 25.285 W 148191.807 693.00 0.50 125.00 693.00 630.00 -0.53 2.01 -0.12 0.62 0.50 0.25 75.00 5928141.76 708704.29 N 70 1225.284 W 148191.791 793.00 0.25 176.00 792.99 729.99 -0.70 2.63 -0.59 0.99 0.39 -0.25 51.00 5928141.30 708704.68 N 70 1225.279 W 148191.780 893.00 0.25 204.00 892.99 829.99 -0.48 3.06 -1.00 0.92 0.12 0.00 28.00 5928140.88 708704.61 N 70 1225.275 W 148 191.783 993.00 0.00 180.00 992.99 929.99 -0.32 3.27 -1.20 0.83 0.25 -0.25 0.00 5928140.68 708704.53 N 70 12 25.273 W 148 19 1.785 1093.00 0.50 121.00 1092.99 1029.99 -0.59 3.71 -1.43 1.20 0.50 0.50 0.00 5928140.47 708704.91 N 70 12 25.271 W 148191.774 1193.00 0.50 147.00 1192.99 1129.99 -0.93 4.57 -2.02 1.81 0.22 0.00 26.00 5928139.89 708705.54 N 70 1225.265 W 148191.757 1293.00 0.50 110.00 1292.98 1229.98 -1.34 5.41 -2.53 2.46 0.32 0.00 -37.00 5928139.40 708706.20 N 70 1225.260 W 148191.738 1393.00 0.75 135.00 1392.98 1329.98 -1.92 6.48 -3.14 3.33 0.36 0.25 25.00 5928138.81 708707.09 N 70 12 25.254 W 148 19 1.712 1493.00 0.50 121.00 1492.97 1429.97 -2.45 7.57 -3.83 4.17 0.29 -0.25 -14.00 5928138.15 708707.95 N 70 1225.247 W 148191.688 1593.00 0.50 92.00 1592.97 1529.97 -3.11 8.42 -4.07 4.98 0.25 0.00 -29.00 5928137.93 708708.76 N 70 1225.245 W 148191.665 1693.00 0.25 148.00 1692.97 1629.97 -3.55 9.03 -4.27 5.53 0.42 -0.25 56.00 5928137.74 708709.32 N 70 1225.243 W 148191.649 1793.00 0.50 123.00 1792.96 1729.96 -3.84 9.68 -4.69 6.01 0.29 0.25 -25.00 5928137.33 708709.81 N 70 12 25.239 W 148191.635 1893.00 0.75 46.00 1892.96 1829.96 -4.69 10.62 -4.48 6.85 0.80 0.25 -77.00 5928137.57 708710.64 N 701225.241 W 148191.610 1993.00 2.00 27.00 1992.93 1929.93 -6.61 13.00 -2.47 8.11 1.31 1.25 -19.00 5928139.62 708711.85 N 70 1225.261 W 14819 1.574 2093.00 1.75 19.00 2092.88 2029.88 -8.93 16.27 0.53 9.40 0.36 -0.25 -8.00 5928142.65 708713.05 N 70 1225.290 W 148191.536 2193.00 1.00 30.00 2192.85 2129.85 -10.61 18.66 2.73 10.34 0.79 -0.75 11.00 5928144.87 708713.93 N 70 12 25.312 W 148191.509 2293.00 1.00 48.00 2292.83 2229.83 -12.12 20.39 4.07 11.42 0.31 0.00 18.00 5928146.24 708714.97 N 70 12 25.325 W 148191.478 2393.00 0.75 78.00 2392.82 2329.82 -13.58 21.88 4.79 12.71 0.51 -0.25 30.00 5928147.00 708716.24 N 70 1225.332 W 148191.440 2493.00 0.75 107.00 2492.81 2429.81 -14.73 23.17 4.73 13.98 0.38 0.00 29.00 5928146.98 708717.51 N 70 1225.332 W 148191.404 2593.00 1.00 118.00 2592.80 2529.80 -15.81 24.69 4.13 15.37 0.30 0.25 11.00 5928146.42 708718.92 N 70 12 25.326 W 148191.363 2693.00 1.00 137.00 2692.79 2629.79 -16.68 26.42 3.09 16.74 0.33 0.00 19.00 5928145.41 708720.32 N 701225.315 W 148191.323 2793.00 0.75 155.00 2792.77 2729.77 -17.04 27.93 1.85 17.61 0.37 -0.25 18.00 5928144.20 708721.22 N 70 1225.303 W 148191.298 2893.00 0.75 163.00 2892.77 2829.77 -17.02 29.24 0.64 18.08 0.10 0.00 8.00 5928142.99 708721.72 N 70 1225.291 W 148191.285 2993.00 0.50 146.00 2992.76 2929.76 -17.05 30.32 -0.35 18.51 0.31 -0.25 -17.00 5928142.02 708722.19 N 70 12 25.281 W 148191.272 3093.00 0.50 137.00 3092.76 3029.76 -17.30 31.19 -1.03 19.06 0.08 0.00 -9.00 5928141.35 708722.75 N 70 12 25.275 W 148191.256 3193.00 0.50 131.00 3192.75 3129.75 -17.66 32.06 -1.64 19.68 0.05 0.00 -6.00 5928140.77 708723.39 N 70 1225.269 W 148191.238 3293.00 0.25 156.00 3292.75 3229.75 -17.87 32.71 -2.12 20.10 0.29 -0.25 25.00 5928140.29 708723.82 N 70 1225.284 W 14819 1.226 3393.00 0.50 150.00 3392.75 3329.75 -17.94 33.36 -2.70 20.41 0.25 0.25 -6.00 5928139.72 708724.14 N 70 1225.258 W 148 191.217 3493.00 0.50 160.00 3492.74 3429.74 -17.98 34.23 -3.49 20.77 0.09 0.00 10.00 5928138.95 708724.53 N 70 12 25.251 W 148191.206 3593.00 0.50 171.00 3592.74 3529.74 -17.87 35.10 -4.33 20.99 0.10 0.00 11.00 5928138.11 708724.77 N 70 12 25.242 W 148191.200 3693.00 0.50 196.00 3692.74 3629.74 -17.51 35.96 -5.18 20.94 0.22 0.00 25.00 5928137.26 708724.74 N 70 1225.234 W 14819 1.202 3793.00 2.50 206.00 3792.70 3729.70 -15.62 38.58 -7.56 19.86 2.01 2.00 10.00 5928134.85 708723.73 N 70 1225.211 W 148191.233 3893.00 4.00 208.00 3892.53 3829.53 -11.34 44.25 -12.60 17.27 1.50 1.50 2.00 5928129.74 708721.28 N 70 1225.161 W 148191.308 3993.00 6.00 209.00 3992.15 3929.15 -4.62 52.96 -20.25 13.10 2.00 2.00 1.00 5928121.98 708717.32 N 70 12 25.086 W 148 19 1.429 4093.00 7.25 204.00 4091.48 4028.48 3.96 84.49 -30.59 8.00 1.38 1.25 -5.00 5928111.51 708712.51 N 70 12 24.984 W 148191.577 4193.00 9.00 201.00 4190.47 4127.47 13.81 78.62 -43.66 2.63 1.80 1.75 -3.00 5928098.30 708707.50 N 70 1224.856 W 148 191.733 4293.00 11.25 200.00 4288.91 4225.91 25.84 96.20 -60.13 -3.51 2.26 2.25 -1.00 5928081.66 708701.82 N 70 1224.694 W 148191.911 4393.00 13.75 199.00 4386.53 4323.53 39.92 117.84 -80.53 -10.72 2.51 2.50 -1.00 5928061.07 708695.18 N 70 12 24.493 W148192.120 4493.00 15.00 199.00 4483.40 4420.40 56.16 142.67 -104.01 -18.80 1.25 1.25 0.00 5928037.38 708687.75 N 70 12 24.262 W 148 192.355 4593.00 17.00 194.00 4579.52 4516.52 73.19 170.21 -130.43 -26.55 2.43 2.00 -5.00 5928010.75 708680.73 N 70 1224.002 W 148 19 2.580 4693.00 19.00 192.00 4674.63 4611.63 90.82 201.11 -160.54 -33.47 2.09 2.00 -2.00 5927980.46 708674.65 N 70 12 23.706 W 148 192.781 4793.00 21.75 192.00 4768.36 4705.36 110.21 235.92 -194.59 -40.71 2.75 2.75 0.00 5927946.23 708668.35 N 70 12 23.371 W 148192.991 4893.00 23.75 194.00 4860.58 4797.58 132.33 274.59 -232.26 -49.44 2.14 2.00 2.00 5927908.33 708660.67 N 70 12 23.001 W 148193.244 SurveyEditorVer 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) 17-04\ 17-04\ 17-04BPB1\17-04BPB 1 Generated 3/19/2004 2:41 PM Page 1 of 3 e e 5493.00 38.50 191.00 5374.22 5311.22 304.71 581.41 -531.97 -114.98 2.57 2.50 -1.00 5927606.95 708603.43 N 70 12 20.053 W 14819 5.146 5593.00 42.00 191.00 5450.53 5387.53 339.75 646.02 -595.38 -127.31 3.50 3.50 0.00 5927543.22 708592.87 N 701219.429 W 148 195.504 5693.00 45.00 191.00 5523.06 5460.06 377.09 714.84 -662.94 -140.44 3.00 3.00 0.00 5927475.32 708581.60 N 70 12 18.765 W 148195.885 5793.00 47.75 190.00 5592.04 5529.04 415.81 787.22 -734.11 -153.62 2.84 2.75 -1.00 5927403.82 708570.40 N 70 12 18.065 W 148 196.267 5893.00 50.00 189.00 5657.81 5594.81 454.98 862.54 -808.40 -166.04 2.37 2.25 -1.00 5927329.22 708560.04 N 70 12 17.334 W 148 196.627 5993.00 49.75 188.00 5722.26 5659.26 493.62 939.01 -884.03 -177.34 0.80 -0.25 -1.00 5927253.32 708550.83 N 701216.591 W 148 196.955 6093.00 49.25 192.00 5787.22 5724.22 533.72 1015.03 -958.88 -190.53 3.08 -0.50 4.00 5927178.13 708539.72 N 70 12 15.854 W 148 197.338 6193.00 49.75 193.00 5852.16 5789.16 576.63 1091.07 -1033.12 -206.99 0.91 0.50 1.00 5927103.47 708525.31 N 70 1215.124 W 148 197.816 6293.00 49.75 193.00 5916.78 5853.78 620.24 1167.40 -1107.49 -224.16 0.00 0.00 0.00 5927028.66 708510.21 N 70 12 14.393 W 148 198.314 6393.00 50.00 195.00 5981.22 5918.22 665.02 1243.86 -1181.67 -242.66 1.55 0.25 2.00 5926954.00 708493.77 N 70 12 13.663 W 148 198.851 6493.00 49.00 195.00 6046.17 5983.17 710.62 1319.90 -1255.12 -262.34 1.00 -1.00 0.00 5926880.04 708476.12 N 70 12 12.941 W 148 199.422 6593.00 49.00 196.00 6111.78 6048.78 756.41 1395.37 -1327.84 -282.51 0.75 0.00 1.00 5926806.79 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1929.299 8539.60 39.34 232.66 7526.96 7463.96 1825.68 2726.06 -2427.43 -993.63 3.26 0.51 5.11 5925688.03 707777.55 N 70 121.410 W 14819 30.637 8633.39 40.08 236.22 7599.12 7536.12 1883.88 2785.98 -2462.25 -1042.36 2.55 0.79 3.80 5925651.87 707729.79 N70121.068 W1481932.050 8726.68 40.68 239.23 7670.19 7607.19 1943.31 2846.41 -2494.51 -1093.46 2.19 0.64 3.23 5925618.22 707679.62 N 70 120.751 W 148 1933.533 8822.78 39.99 239.19 7743.44 7680.44 2004.75 2908.61 -2526.35 -1146.89 0.72 -0.72 -0.04 5925584.92 707627.08 N 70 120.437 W 148 19 35.083 8915.93 40.22 240.93 7814.69 7751.69 2064.16 2968.61 -2556.30 -1198.89 1.23 0.25 1.87 5925553.55 707575.94 N 70 120.143 W 148 19 36.591 9010.44 39.83 241.70 7887.06 7824.06 2124.51 3029.39 -2585.47 -1252.21 0.67 -0.41 0.81 5925522.91 707523.45 N 70 11 59.856 W 1481938.138 9108.19 38.88 241.66 7962.65 7899.65 2186.10 3091.38 -2614.88 -1306.77 0.97 -0.97 -0.04 5925492.01 707469.72 N 70 11 59.566 W 148 19 39.721 9203.11 39.58 242.61 8036.17 7973.17 2245.79 3151.41 -2642.93 -1359.84 0.97 0.74 1.00 5925462.50 707417.45 N 70 11 59.290 W 1481941.260 9293.64 38.87 244.10 8106.30 8043.30 2302.84 3208.65 -2668.61 -1411.01 1.30 -0.78 1.65 5925435.42 707367.02 N 70 11 59.038 W 1481942.744 9389.18 38.65 245.37 8180.81 8117.81 2362.54 3268.46 -2694.14 -1465.09 0.86 -0.23 1.33 5925408.41 707313.66 N 70 1158.787 W 1481944.313 9485.35 38.84 244.00 8255.81 8192.81 2422.62 3328.65 -2719.87 -1519.50 0.91 0.20 -1.42 5925381.18 707259.99 N 70 1158.533 W 1481945.892 9579.41 40.10 241.81 8328.43 8265.43 2482.15 3388.44 -2747.12 -1572.71 2.00 1.34 -2.33 5925352.48 707207.55 N 70 11 58.265 W 148 1947.435 9675.01 40.87 241.40 8401.14 8338.14 2543.81 3450.50 -2776.63 -1627.31 0.85 0.81 -0.43 5925321.47 707153.79 N 70 11 57.975 W 148 1949.019 9768.56 40.16 241.28 8472.26 8409.26 2604.16 3511.28 -2805.78 -1680.64 0.76 -0.76 -0.13 5925290.86 707101.29 N 70 11 57.688 W 148 19 50.566 9863.80 41.48 241.02 8544.33 8481.33 2665.95 3573.53 -2835.82 -1735.17 1.40 1.39 -0.27 5925259.33 707047.61 N 70 1157.393 W 1481952.148 9958.15 41.29 241.60 8615.12 8552.12 2727.88 3635.91 -2865.77 -1789.89 0.45 -0.20 0.61 5925227.88 706993.75 N 70 1157.098 W 1481953.735 10053.86 41.27 242.24 8687.04 8624.04 2790.65 3699.05 -2895.49 -1845.60 0.44 -0.02 0.67 5925196.63 706938.88 N 70 11 56.805 W 148 1955.351 10150.93 40.84 242.49 8760.35 8697.35 2853.95 3762.68 -2925.00 -1901.96 0.67 -0.65 0.26 5925165.58 706883.35 N 70 11 56.515 W 1481956.986 10243.75 40.30 242.64 8830.97 8767.97 2913.91 3822.92 -2952.76 -1955.43 0.38 -0.37 0.16 5925136.35 706830.68 N 70 11 56.242 W 148 1958.537 10329.86 40.93 241.21 8896.33 8833.33 2969.63 3878.98 -2979.14 -2004.89 1.31 0.73 -1.66 5925108.61 706781.97 N 70 1155.982 W 1481959.971 10363.18 46.35 240.74 8920.44 8857.44 2992.44 3901.96 -2990.30 -2024.98 16.30 16.27 -1.41 5925096.91 706762.19 N 70 11 55.873 W 148200.554 10395.14 50.96 240.32 8941.54 8878.54 3016.21 3925.95 -3002.10 -2045.87 14.46 14.42 -1.31 5925084.53 706741.65 N 70 11 55.756 W 14820 1.160 10425.04 54.95 240.06 8959.55 8896.55 3039.84 3949.81 -3013.96 -2066.57 13.36 13.34 -0.87 5925072.10 706721.28 N 70 11 55.640 W 148 20 1.760 10456.94 58.84 241.22 8977.02 8914.02 3066.30 3976.50 -3027.04 -2089.83 11.96 11.57 3.84 5925058.39 706698.39 N 70 1155.511 W 148 20 2.435 10488.24 62.51 243.88 8992.40 8929.40 3093.42 4003.75 -3039.60 -2114.02 14.41 12.36 8.50 5925045.17 706674.56 N 70 11 55.387 W 148203.137 10518.42 67.71 243.65 9005.10 8942.10 3120.71 4031.12 -3051.70 -2138.57 17.24 17.23 -0.76 5925032.40 706650.35 N 70 11 55.268 W 148203.849 10552.61 71.73 245.79 9016.94 8953.94 3152.72 4063.18 -3065.38 -2167.56 13.14 11.76 6.26 5925017.92 706621.75 N 70 11 55.134 W 148 20 4.690 10580.74 73.73 245.60 9025.30 8962.30 3179.55 4090.04 -3076.44 -2192.04 7.14 7.11 -0.68 5925006.19 706597.59 N 70 11 55.025 W 148 20 5.400 10612.91 79.80 245.92 9032.66 8969.66 3210.82 4121.34 -3089.29 -2220.58 18.89 18.87 0.99 5924992.56 706569.41 N 70 1154.898 W 148206.228 10644.80 86.43 246.28 9036.48 8973.48 3242.45 4152.99 -3102.10 -2249.51 20.82 20.79 1.13 5924978.94 706540.85 N 7011 54.772 W 148207.067 SurveyEditor Ver 3.1 RT-SP3.03-HF4.oo Bld( do31rt-546 ) 17-04\ 17-04\17-04BPB 1\ 17-04BPB 1 Generated 3/19/2004 2:41 PM Page 2 of 3 e e '. "' 10707.04 88,56 249,98 9038.21 897521 3304,64 421520 -3125,70 -2307,06 9.07 -2M 8-13 5924953.76 706483,98 N 70 11 54,540 W 148208-136 10740,86 86.26 252M 9039.74 8976,74 3338.38 4248,98 -3136,59 -2339.04 9.95 -6,80 7-27 5924942,00 706452.31 N 70 11 54.433 W 148209.664 107n93 86,33 252,10 9041,81 8978,81 3370,30 4280,98 -3146,33 -2369.52 1,08 022 -1.06 5924931-42 706422.11 N 70 11 54.337 W 14820 10,548 10802.18 85,33 253.75 9043,94 8980,94 3399,37 4310,15 -3154,90 -2397,41 6,58 -3.42 5,64 5924922.09 706394.48 N 70 11 54,253 W 14820 11.357 10832,86 84.82 252,30 9046,58 8983,58 3429,82 4340.72 -3163.82 -2426,84 4,99 -1-66 -4-13 5924912,36 706365,50 N 70 1154,165 W 148 20 12205 10864.74 84.40 252,24 9049,57 8986.57 3461 .48 4372.46 -3173-49 -2456,87 1-33 -1.32 -0,19 5924901.86 706335,55 N 70 1154,070 W 1482013.082 10895.87 84$4 25224 9052,57 8989.57 3492,38 4403.45 -3182.94 -2486,38 0.45 0.45 0,00 5924891,60 706306,32 N 70 11 53W7 W 14820 13,937 10927M 88.01 252,30 9054,62 8991-62 3523.80 4434,94 -3192,53 -2516,39 10.99 10,99 0,19 5924881.18 706276,59 N 70 11 53,882 W 1482014-808 10959,30 90,76 254,28 9054.96 8991,96 3555,53 4466,80 -3201-69 -2546.89 10.84 8,63 6.21 5924871-19 706246.35 N 70 11 53.792 W 14820 15,693 10990W 90,82 253.10 9054.54 8991.54 3586,15 4497,57 -3210,33 -2576.42 3,84 0,19 -3.83 5924861.73 706217.07 N 70 11 53.707 W 14820 16,549 11022,84 93.85 255.51 905320 8990.20 3618,70 4530,31 -3219.19 -2607,94 11,81 9,25 7,35 5924852.01 706185.82 N 70 11 53,620 W 148 20 17.463 11054.49 95.35 25824 9050,66 8987,66 3649.88 4561.85 -3226.35 -2638,66 9,82 4.74 8,63 5924844,00 706155,31 N 70 11 53,549 W 1482018.354 11084.10 95.04 257.36 9047.98 8984.98 3678.95 4591.34 -3232.58 -2667.48 3.14 -1.05 -2.97 5924836.98 706126.67 N 70 11 53.488 W 1482019.190 11115.95 95.73 262.61 9044.99 8981.99 3709.97 4623.05 -3238.09 -2698.69 16.55 2.17 16.48 5924830.60 706095.62 N 70 11 53.433 W 1482020.096 11146.02 95.77 264.09 9041.98 8978.98 3738.84 4652.97 -3241.56 -2728.41 4.90 0.13 4.92 5924826.32 706066.01 N 70 11 53.399 W 1482020.958 11177.08 95.97 265.61 9038.80 8975.80 3768.44 4683.87 -3244.33 -2759.18 4.91 0.64 4.89 5924822.70 706035.33 N 70 1153.372 W 1482021.851 11209.54 96.42 271.05 9035.30 89n30 3798.71 4716.14 -3245.27 -2791.43 16.72 1.39 16.76 5924820.86 706003.13 N 70 11 53.362 W 148 20 22.786 11242.31 96.46 273.77 9031.62 8968.62 3828.40 4748.70 -3243.90 -2823.96 8.25 0.12 8.30 5924821.33 705970.57 N 70 11 53.376 W 1482023.730 11272.87 96.53 272.20 9028.16 8965.16 3855.95 4779.06 -3242.32 -2854.28 5.11 0.23 -5.14 5924822.08 705940.22 N 70 11 53.391 W 148 20 24.609 11308.40 94.05 273.50 9024.89 8961.89 3888.09 4814.44 -3240.56 -2889.61 7.87 -6.98 3.66 5924822.86 705904.86 N 70 11 53.408 W 148 20 25.634 11337.66 93.70 272.33 9022.91 8959.91 3914.60 4843.63 -3239.08 -2918.77 4.17 -120 -4.00 5924823.54 705875.67 N 70 1153.423 W 1482026.480 11367.23 94.73 271.58 9020.74 8957.74 3941.58 4873.12 -3238.07 -2948.24 4.30 3.48 -2.54 5924823.73 705846.19 N 70 11 53.433 W 1482027.335 11398.51 96.53 271.98 9017.67 8954.67 3970.10 4904.25 -3237.11 -2979.35 5.89 5.75 1.28 5924823.84 705815.06 N 70 11 53M2 W 1482028.238 11430.75 96.28 272.26 9014.07 8951.07 3999.37 4936.29 -3235.92 -3011.37 1-16 -0.78 0.87 5924824.14 705783.02 N70 1153.454 W 1482029.166 11463.02 94.83 273.12 9010.95 8947.95 4028.59 4968.40 -3234.41 -3043.45 5.22 -4.49 2.67 5924824.76 705750.92 N 70 11 53.468 W 1482030.097 11495.05 94.77 272.48 9008.27 8945.27 4057.60 5000.32 -3232.85 -3075.33 2.00 -0.19 -2.00 5924825.43 705719.01 N 70 11 53.484 W 1482031.022 11526.87 94.88 274.10 9005.59 8942.59 4086.30 5032.03 -3231.03 -3106.98 5.08 0.35 5.09 5924826.38 705687.32 N 70 11 53.501 W 148 20 31,940 11557.92 94.67 273.32 9003.01 8940.01 4114.22 5062.97 -3229.03 -3137.86 2.59 -0.68 -2.51 5924827.53 705656.40 N 70 11 53.521 W 148 20 32.836 11580.40 95.29 272.35 9001.06 8938.06 4134.56 5085.37 -3227.92 -3160.23 5.11 2.76 -4.31 5924828.01 705634.01 N 70 11 53.532 W 1482033.485 11635.00 95.29 2n35 8996.02 8933.02 4184.15 5139.73 -3225.70 -3214.55 0.00 0.00 0.00 5924828.74 705579.65 N 70 11 53.553 W 1482035.061 Leaal Descriotion: Northina IYI InUS! Eastina IXI Inus! Surface: 2792 FSL 4829 FEL S22 T10N R15E UM 5928141.86 708703.67 BHL: 4846 FSL 2770 FEL S28 T10N R15E UM 5924828.74 705579.65 SurveyEditorVer 3.1RT-SP3.03-HF4.00 Bld( do31rt-546) 17-04\17-04\17 -04BPB 1 \17 -04BPB 1 Generated 3/19/2004 2:41 PM Page 3 of 3 or SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field................. ...: Pudhoe Bay Unit - EOA Well. . . . . . . . . . . . . . . . . . . . .: DS17-04B API number...... .........: 50029-20498-02 Engineer......... ........: B. Barnes RIG LABEL:......... ......: Nabors 7ES STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS......... ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. .........: MEAN SEA LEVEL Depth reference... .......: Driller's Pipe Tally GL above permanent.......: 28.5 ft KB above permanent.......: n/a - Top Drive OF above permanent.......: 63.0 ft ----- Vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-) ........: -999.25 ft Azimuth from rotary table to target: 192.21 degrees RECE'VED t·1,~P 2::¡ ?Ouíl4 ; ~; H \ .. '- }::jle~kaOU& Gas Cons,Commilion ¡1¡!l~orage ''0~, ... -" t""··. b l) lì\~ 10-Mar-2004 10:42:15 Spud date............. . . . : Last survey date...... ...: Total accepted surveys...: MD of first survey.. ... ..: MD of last survey... ... ..: (}CJLI -Od. :5 Page 1 of 5 29-Feb-04 10-Mar-04 95 6793.00 ft 12048.00 ft e ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2003 Magnetic date.,..........: 08-Mar-2004 Magnetic field strength..: 1151.99 HCNT Magnetic dec (+E/W-) .....: 25.49 degrees Magnetic dip.............: 80.85 degrees ----- MWD survey Reference Reference G..............: Reference H..............: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.67 mGal 1151.99 HCNT 80.85 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees - ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.49 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.49 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction · [ (c) 2004 IDEAL 108 1C 01] SCHLUMBERGER Survey Report 10-Mar-2004 10:42:15 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 6793.00 49.00 194.00 0.00 6243.00 1508.40 -1474.28 -319.02 1508.40 192.21 0.00 TIP None 2 6829.00 49.18 194.00 36.00 6266.58 1535.59 -1500.68 -325.60 1535.60 192.24 0.50 Window Top 3 6845.00 49.54 196.49 16.00 6277.00 1547.72 -1512.39 -328.79 1547.72 192.27 12.02 Window Bottom 4 6859.00 49.54 196.49 14.00 6286.08 1558.34 -1522.60 -331.82 1558.34 192.29 0.00 Mill Rat Hole 5 6932.12 48.46 200.33 73.12 6334.06 1613 .18 -1574.95 -349.23 1613.20 192.50 4.23 MWD IFR MSA 6 7025.55 47.90 205.38 93.43 6396.38 1681.57 -1639.08 -376.24 1681. 70 192.93 4.07 MWD IFR MSA e - - 7 7119.96 46.68 210.65 94.41 6460.44 1748.28 -1700.29 -408.77 1748.74 193.52 4.30 MWD IFR MSA - - 8 7214.78 45.42 212.73 94.82 6526.25 1812.64 -1758.38 -444.62 1813.72 194.19 2.06 MWD IFR MSA - 9 7310.26 43.75 216.15 95.48 6594.26 1874.67 -1813.65 -482.49 1876.73 194.90 3.06 MWD IFR MSA - 10 7406.52 42.73 217.17 96.26 6664.39 1934.70 -1866.55 -521.85 1938.13 195.62 1. 28 MWD IFR MSA 11 7502.69 42.17 218.09 96.17 6735.35 1993.33 -1917.96 -561.48 1998.46 196.32 0.87 MWD IFR MSA - 12 7598.21 42.17 218.37 95.52 6806.14 2050.95 -1968.33 -601.16 2058.09 196.98 0.20 MWD IFR MSA - 13 7691. 40 40.26 219.09 93.19 6876.24 2105.89 -2016.23 -639.57 2115.24 197.60 2.11 MWD IFR MSA - 14 7786.11 40.14 218.86 94.71 6948.58 2160.47 -2063.76 -678.02 2172.28 198.19 0.20 MWD IFR MSA - 15 7879.85 40.28 218.20 93.74 7020.17 2214.72 -2111.10 -715.72 2229.13 198.73 0.48 MWD IFR MSA 16 7974.06 40.38 217.98 94.21 7091.99 2269.57 -2159.09 -753.33 2286.74 199.23 0.18 MWD IFR MSA - - 17 8068.28 40.50 218.43 94.22 7163.70 2324.51 -2207.11 -791.13 2344.62 199.72 0.33 MWD IFR MSA - 18 8162.61 40.62 217.94 94.33 7235.36 2379.65 -2255.32 -829.05 2402.88 200.18 0.36 MWD IFR MSA - 19 8258.74 39.74 219.06 96.13 7308.81 2435.25 -2303.87 -867.65 2461. 83 200.64 1.18 MWD IFR MSA - - 20 8351.12 38.77 222.88 92.38 7380.35 2486.49 -2348.00 -905.95 2516.71 201.10 2.82 MWD IFR MSA 21 8444.43 38.85 227.80 93.31 7453.08 2535.43 -2389.07 -947.52 2570.11 201. 63 3.31 MWD IFR MSA e - - 22 8539.60 39.34 232.66 95.17 7526.96 2582.67 ~2427.43 -993.63 2622.92 202.26 3.26 MWD IFR MSA - 23 8633.39 40.08 236.22 93.79 7599.12 2627.01 -2462.25 -1042.36 2673.80 202.94 2.55 MWD IFR MSA - 24 8726.68 40.68 239.23 93.29 7670.19 2669.34 -2494.51 -1093.46 2723.64 203.67 2.19 MWD IFR MSA - - 25 8822.78 39.99 239.19 96.10 7743.44 2711.76 -2526.35 -1146.89 2774.49 204.42 0.72 MWD IFR MSA 26 8915.93 40.22 240.93 93.15 7814.69 2752.03 -2556.30 -1198.89 2823.47 205.13 1.23 MWD IFR MSA - - 27 9010.44 39.83 241. 70 94.51 7887.07 2791.82 -2585.47 -1252.21 2872.75 205.84 0.67 MWD IFR MSA - - 28 9108.19 38.88 241.66 97.75 7962.65 2832.10 -2614.88 -1306.77 2923.22 206.55 0.97 MWD IFR MSA - - 29 9203.11 39.58 242.61 94.92 8036.18 2870.74 -2642.93 -1359.84 2972.25 207.23 0.97 MWD IFR MSA - 30 9293.64 38.87 244.10 90.53 8106.31 2906.66 -2668.61 -1411. 01 3018.67 207.87 1. 30 MWD IFR MSA [(c)2004 IDEAL 108 1C_01] SCHLUMBERGER Survey Report 10-Mar-2004 10:42:15 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 9389.18 9485.35 9579.41 9675.01 9768.56 36 37 38 39 40 9863.80 9958.15 10053.86 10150.93 10243.75 41 42 43 44 45 10329.86 10363.18 10395.14 10425.04 10456.94 46 47 48 49 50 10488.24 10518.42 10552.61 10580.74 10612.91 51 52 53 54 55 10644.80 10676.23 10707.04 10740.86 10772.93 56 57 58 59 60 10802.18 10832.86 10864.74 10895.87 10927.44 38.65 38.84 40.10 40.87 40.16 41. 48 41.29 41. 27 40.64 40.30 40.93 46.35 50.96 54.95 58.64 62.51 67.71 71.73 73.73 79.80 86.43 89.32 88.56 86.26 86.33 85.33 84.82 84.40 84.54 88.01 245.37 244.00 241.81 241. 40 241.28 241.02 241. 60 242.24 242.49 242.64 241.21 240.74 240.32 239.96 241.22 243.88 243.65 245.79 245.60 245.92 246.28 247.29 249.98 252.44 252.10 253.75 252.30 252.24 252.24 252.30 95.54 96.17 94.06 95.60 93.55 95.24 94.35 95.71 97.07 92.82 86.11 33.32 31. 96 29.90 31. 90 31. 30 30.18 34.19 28.13 32.17 31. 89 31. 43 30.81 33.82 32.07 29.25 30.68 31. 88 31. 13 31. 57 8180.81 8255.82 8328.43 8401.14 8472.26 8544.33 8615.12 8687.05 8760.36 8830.97 8896.33 8920.44 8941. 54 8959.55 8977.02 8992.40 9005.09 9016.94 9025.29 9032.66 9036.48 9037.64 9038.21 9039.74 9041.81 9043.94 9046.57 9049.57 9052.57 9054.62 2943.05 -2694.14 -1465.09 2979.71 -2719.87 -1519.50 3017.59 -2747.11 -1572.71 3057.99 -2776.63 -1627.31 3097.76 -2805.78 -1680.64 3138.65 -2835.82 -1735.17 3179.49 -2865.77 -1789.89 3220.32 -2895.49 -1845.60 3261.09 -2925.00 -1901.96 3299.53 -2952.76 -1955.43 3335.77 -2979.14 -2004.89 3350.93 -2990.30 -2024.98 3366.88 -3002.10 -2045.87 3382.87 -3013.98 -2066.56 3400.59 -3027.08 -2089.81 3417.97 -3039.63 -2114.00 3434.99 -3051.73 -2138.55 3454.50 -3065.42 -2167.54 3470.48 -3076.47 -2192.02 3489.08 -3089.32 -2220.56 3507.72 -3102.14 -2249.49 3525.93 -3114.52 -2278.35 3542.96 -3125.74 -2307.04 3560.36 -3136.62 -2339.02 3576.33 -3146.37 -2369.50 3590.60 -3154.93 -2397.39 3605.51 -3163.86 -2426.62 3621.35 -3173.52 -2456.85 3636.83 -3182.98 -2486.36 3652.55 -3192.57 -2516.36 3066.74 3115.54 3165.45 3218.36 3270.62 3324.56 3378.80 3433.67 3489.00 3541.54 3590.94 3611.43 3632.93 3654.42 3678.39 3702.48 3726.45 3754.33 3777.52 3804.58 3831. 90 3858.90 3884.93 3912.72 3938.80 3962.46 3987.29 4013.40 4038.98 4065.04 208.54 209.19 209.79 210.37 210.92 211.46 211.99 212.51 213.03 213.51 213.94 214.11 214.27 214.44 214.62 214.82 215.02 215.26 215.47 215.71 215.95 216.19 216.43 216.71 216.98 217.23 217.49 217.75 217.99 218.25 DLS (deg/ 100f) 0.86 0.91 2.00 0.85 0.76 1. 40 0.45 0.44 0.67 0.38 1. 31 16.30 14.46 13.38 12.03 14.41 17.24 13.14 7.14 18.89 20.82 9.74 9.07 9.95 1. 08 6.58 4.99 1. 33 0.45 10.99 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA · [ (c) 2004 IDEAL 108 1C 01] - SCHLUMBERGER Survey Report 10-Mar-2004 10:42:15 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 10959.30 90.76 254.28 31.86 9054.96 3667.95 -3201. 73 -2546.87 4091.16 218.50 10.64 MWD IFR MSA - - 62 10990.07 90.82 253.10 30.77 9054.54 3682.64 -3210.37 -2576.40 4116.34 218.75 3.84 MWD IFR MSA - - 63 11022.84 93.85 255.51 32.77 9053.20 3697.96 -3219.22 -2607.92 4143.02 219.01 11.81 MWD IFR MSA - - 64 11054.49 95.35 258.24 31. 65 9050.66 3711.46 -3226.39 -2638.64 4167.97 219.28 9.82 MWD IFR MSA e - - 65 11084.10 95.04 257.36 29.61 9047.98 3723.65 -3232.62 -2667.46 4191. 08 219.53 3.14 MWD IFR MSA 66 11115.95 95.73 262.61 31. 85 9044.99 3735.64 -3238.13 -2698.67 4215.25 219.81 16.55 MWD IFR MSA - - 67 11146.02 95.77 264.09 30.07 9041.98 3745.31 -3241.60 -2728.39 4236.99 220.09 4.90 MWD IFR MSA - 68 11177.08 95.97 265.61 31. 06 9038.80 3754.53 -3244.37 -2759.16 4258.98 220.38 4.91 MWD IFR MSA - - 69 11209.54 96.42 271.05 32.46 9035.29 3762.27 -3245.31 -2791.40 4280.65 220.70 16.72 MWD IFR MSA - 70 11242.31 96.46 273.77 32.77 9031. 62 3767.81 -3243.94 -2823.94 4300.90 221.04 8.25 MWD IFR MSA 71 11272.87 96.53 272.20 30.56 9028.16 3772.68 -3242.36 -2854.26 4319.69 221. 36 5.11 MWD IFR MSA - 72 11308.40 94.05 273.50 35.53 9024.89 3778.43 -3240.60 -2889.59 4341. 80 221. 72 7.87 MWD IFR MSA - - 73 11337.66 93.70 272.33 29.26 9022.91 3783.14 -3239.12 -2918.74 4360.15 222.02 4.17 MWD IFR MSA - - 74 11366.71 92.57 273.54 29.05 9021.32 3787.82 -3237.63 -2947.71 4378.50 222.32 5.69 MWD IFR MSA - - 75 11399.33 89.66 275.73 32.62 9020.69 3792.12 -3234.99 -2980.21 4398.51 222.65 11.16 MWD IFR MSA - 76 11434.46 89.66 281.71 35.13 9020.89 3794.25 -3229.67 -3014.92 4418.20 223.03 17.02 MWD IFR MSA - 77 11462.04 90.48 279.08 27.58 9020.86 3795.13 -3224.70 -3042.04 4433.14 223.33 9.99 MWD IFR MSA - - 78 11495.59 91. 47 279.34 33.55 9020.29 3796.88 -3219.33 -3075.16 4452.04 223.69 3.05 MWD IFR MSA - - e 79 11527.16 91.75 280.73 31. 57 9019.40 3798.08 -3213.83 -3106.23 4469.60 224.02 4.49 MWD IFR MSA - 80 11558.45 90.03 278.71 31.29 9018.92 3799.44 -3208.55 -3137.07 4487.31 224.35 8.48 MWD IFR MSA 81 11590.56 89.59 276.97 32.11 9019.02 3801.89 -3204.17 -3168.87 4506.49 224.68 5.59 MWD IFR MSA - - 82 11621.92 90.07 277.42 31. 36 9019.12 3804.63 -3200.24 -3199.99 4525.64 225.00 2.10 MWD IFR MSA - 83 11652.15 89.38 275.73 30.23 9019.26 3807.60 -3196.78 -3230.02 4544.49 225.30 6.04 MWD IFR MSA - - 84 11684.19 87.36 269.44 32.04 9020.17 3812.95 -3195.33 -3261.99 4566.26 225.59 20.61 MWD IFR MSA - 85 11714.59 87.12 267.86 30.40 9021.64 3820.07 -3196.05 -3292.35 4588.49 225.85 5.25 MWD IFR MSA 86 11749.49 89.31 266.77 34.90 9022.72 3829.03 -3197.68 -3327.19 4614.69 226.14 7.01 MWD IFR MSA - - 87 11779.83 92.27 267. 62 30.34 9022.31 3836.89 -3199.17 -3357.49 4637.61 226.38 10.15 MWD IFR MSA - 88 11811.69 93.43 265.42 31. 86 9020.72 3845.50 -3201.10 -3389.25 4661.98 226.64 7.80 MWD IFR MSA - - 89 11843.25 95.01 264.60 31. 56 9018.40 3854.80 -3203.84 -3420.60 4686.69 226.87 5.64 MWD IFR MSA - - 90 11874.79 94.90 265.80 31. 54 9015.67 3863.99 -3206.46 -3451.91 4711. 38 227.11 3.81 MWD IFR MSA ", .. [(c)2004 IDEAL 108 1C_01] SCHLUMBERGER Survey Report 10-Mar-2004 10:42:15 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 Azimuth Course TVD Vertical Disp1 Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (de g) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 11907.61 94.95 266.07 32.82 9012.86 3873.16 -3208.78 -3484.53 4736.90 227.36 0.83 MWD IFR MSA - - 92 11938.23 92.78 265.15 30.62 9010.79 3881. 89 -3211.12 -3514.99 4760.93 227.59 7.69 MWD IFR MSA - - 93 11967.26 86.67 261.81 29.03 9010.93 3891.20 -3214.42 -3543.81 4784.46 227.79 23.98 MWD IFR MSA e - 94 11993.80 85.68 262.95 26.54 9012.70 3900.18 -3217.93 -3570.06 4806.28 227.97 5.68 MWD IFR MSA - - 95 12048.00 85.68 262.95 54.20 9016.79 3918.01 -3224.56 -3623.70 4850.67 228.34 0.00 Projected to TO [(c)2004 IDEAL ID8_1C_01] e ,-...... SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field........... .........: Pudhoe Bay Unit - EOA Well. . . . . . . . . . . . . . . . . . . . .: DS17-04BPBl API number.. ........... ..: 50029-20498-71 Engineer.. ... ............: B. Barnes RIG LABEL:...............: Nabors 7ES STATE: .. . . . . . . . . . . . . .. . . .: ALASKA ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum........ ..: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent..... ..: 28.5 ft KB above permanent.......: n/a - Top Drive OF above permanent.......: 63.0 ft ----- Vertical section origin---------------- Latitude (+N/S-) ....... ..: 0.00 ft Departure (+E/W-) ...... ..: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 248.15 degrees REceIVED t;1 2 :~ ?f\\,iO'J4 . \ ,.v~.. ':!1ð~ka Oil & Gas Cons. Commis8i0n ß,rmhorage [(c)2004 IDEAL 108 lC 01] ~Dn\,--~ 8-Mar-2004 16:45:39 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: oOLI-C&3 Page 1 of 4 29-Feb-04 08-Mar-04 82 6793.00 ft 11635.00 ft e ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2003 Magnetic date............: 25-Feb-2004 Magnetic field strength..: 1151.97 HCNT Magnetic dec (+E/W-) ... ..: 25.51 degrees Magnetic dip.......... ...: 80.84 degrees ----- MWD survey Reference Reference G..............: Reference H..............: Reference Dip......... ...: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.67 mGal 1151. 97 HCNT 80.84 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees e ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.51 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.51 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 8-Mar-2004 16:45:39 -------- ------ ------- ------ -------- -------- ---------------- -------- ------ ------- ------ -------- -------- ---------------- Seq Measured # depth (n) Incl angle (deg) Azimuth angle (deg) Course length (n) TVD depth (n) Vertical section (n) Displ +N/S- (n) Displ +E/W- (n) Page 2 of 4 49.00 49.18 49.54 49.54 48.46 47.90 46.68 45.42 43.75 42.73 42.17 42.17 40.26 40.14 40.28 40.38 40.50 40.62 39.74 38.77 38.85 39.34 40.08 40.68 39.99 40.22 39.83 38.88 39.58 38.87 194.00 194.00 196.49 196.49 200.33 205.38 210.65 212.73 216.15 217.17 218.09 218.37 219.09 218.86 218.20 217.98 218.43 217.94 219.06 222.88 227.80 232.66 236.22 239.23 239.19 240.93 241. 70 241.66 242.61 244.10 [(c)2004 IDEAL 108 1C 01] --------------- --------------- Total displ (n) -------- ------ ------- ------ -------- -------- ---------------- -------- ------ ------- ------ -------- -------- ---------------- 1 2 3 4 5 6793.00 6829.00 6845.00 6859.00 6932.12 6 7 8 9 10 7025.55 7119.96 7214.78 7310.26 7406.52 11 12 13 14 15 7502.69 7598.21 7691. 40 7786.11 7879.85 16 17 18 19 20 7974.06 8068.28 8162.61 8258.74 8351.12 21 22 23 24 25 8444.43 8539.60 8633.39 8726.68 8822.78 26 27 28 29 30 8915.93 9010.44 9108.19 9203.11 9293.64 0.00 36.00 16.00 14.00 73.12 93.43 94.41 94.82 95.48 96.26 96.17 95.52 93.19 94.71 93.74 94.21 94.22 94.33 96.13 92.38 93.31 95.17 93.79 93.29 96.10 93.15 94.51 97.75 94.92 90.53 6243.00 6266.58 6277.00 6286.08 6334.06 6396.38 6460.44 6526.25 6594.26 6664.39 6735.35 6806.14 6876.24 6948.58 7020.17 7091.99 7163.70 7235.36 7308.81 7380.35 7453.08 7526.96 7599.12 7670.19 7743.44 7814.69 7887.07 7962.65 8036.18 8106.31 844.80 -1474.28 860.73 -1500.68 868.05 -1512.39 874.66 -1522.60 910.30 -1574.95 959.24 -1639.08 1012.22 -1700.29 1067.11 -1758.38 1122.83 -1813.65 1179.06 -1866.55 1234.97 -1917.96 1290.55 -1968.33 1344.03 -2016.23 1397.40 -2063.76 1450.01 -2111.10 1502.78 -2159.09 1555.74 -2207.11 1608.88 -2255.32 1662.77 -2303.87 1714.74 -2348.00 1768.61 -2389.07 1825.68 -2427.43 1883.88 -2462.25 1943.31 -2494.51 2004.75 -2526.35 -319.02 -325.60 -328.79 -331.82 -349.23 -376.24 -408.77 -444.62 -482.49 -521. 85 -561. 48 -601.16 -639.57 -678.02 -715.72 -753.33 -791.13 -829.05 -867.65 -905.95 -947.52 -993.63 -1042.36 -1093.46 -1146.89 2064.16 -2556.30 -1198.89 2124.51 -2585.47 -1252.21 2186.10 -2614.88 -1306.77 2245.80 -2642.93 -1359.84 2302.84 -2668.61 -1411.01 At Azim (deg) --------------- --------------- 1508.40 1535.60 1547.72 1558.34 1613.20 1681.70 1748.74 1813.72 1876.73 1938.13 1998.46 2058.09 2115.24 2172.28 2229.13 2286.74 2344.62 2402.88 2461.83 2516.71 2570.11 2622.92 2673.80 2723.64 2774.49 2823.47 2872.75 2923.22 2972.25 3018.67 192.21 192.24 192.27 192.29 192.50 192.93 193.52 194.19 194.90 195.62 196.32 196.98 197.60 198.19 198.73 199.23 199.72 200.18 200.64 201.10 201. 63 202.26 202.94 203.67 204.42 205.13 205.84 206.55 207.23 207.87 DLS (deg/ 100f) 0.00 0.50 12.02 0.00 4.23 4.07 4.30 2.06 3.06 1. 28 0.87 0.20 2.11 0.20 0.48 0.18 0.33 0.36 1.18 2.82 3.31 3.26 2.55 2.19 0.72 1. 23 0.67 0.97 0.97 1. 30 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIP None Window Top Window Bottom Mill Rat Hole MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 8-Mar-2004 16:45:39 -------- ------ ------- ------ -------- -------- ---------------- -------- ------ ------- ------ -------- -------- ---------------- Seq Measured # depth (n) Incl angle (deg) Azimuth angle (deg) Course length (n) TVD depth (n) Vertical section (n) Displ +N/S- (n) Displ +E/W- (n) Page 3 of 4 --------------- --------------- Total displ (n) -------- ------ ------- ------ -------- -------- ---------------- -------- ------ ------- ------ -------- -------- ---------------- 31 32 33 34 35 9389.18 9485.35 9579.41 9675.01 9768.56 38.65 38.84 40.10 40.87 40.16 41. 48 41. 29 41.27 40.64 40.30 40.93 46.35 50.96 54.95 58.64 62.51 67.71 71.73 73.73 79.80 86.43 89.32 88.56 86.26 86.33 85.33 84.82 84.40 84.54 88.01 245.37 244.00 241.81 241.40 241.28 241.02 241.60 242.24 242.49 242.64 241.21 240.74 240.32 240.06 241.22 243.88 243.65 245.79 245.60 245.92 246.28 247.29 249.98 252.44 252.10 253.75 252.30 252.24 252.24 252.30 [(c)2004 IDEAL ID8 1C 01] 36 37 38 39 40 9863.80 9958.15 10053.86 10150.93 10243.75 41 42 43 44 45 10329.86 10363.18 10395.14 10425.04 10456.94 46 47 48 49 50 10488.24 10518.42 10552.61 10580.74 10612.91 51 52 53 54 55 10644.80 10676.23 10707.04 10740.86 10772.93 56 57 58 59 60 10802.18 10832.86 10864.74 10895.87 10927.44 95.54 96.17 94.06 95.60 93.55 95.24 94.35 95.71 97.07 92.82 86.11 33.32 31. 96 29.90 31. 90 31. 30 30.18 34.19 28.13 32.17 31. 89 31. 43 30.81 33.82 32.07 29.25 30.68 31. 88 31.13 31. 57 8180.81 8255.82 8328.43 8401.14 8472.26 8544.33 8615.12 8687.05 8760.36 8830.97 8896.33 8920.44 8941. 54 8959.55 8977.02 8992.40 9005.09 9016.94 9025.29 9032.66 9036.48 9037.64 9038.21 9039.74 9041. 81 9043.94 9046.57 9049.57 9052.57 9054.62 2362.54 -2694.14 -1465.09 2422.62 -2719.87 -1519.50 2482.15 -2747.11 -1572.71 2543.81 -2776.63 -1627.31 2604.16 -2805.78 -1680.64 2665.95 -2835.82 -1735.17 2727.88 -2865.77 -1789.89 2790.65 -2895.49 -1845.60 2853.95 -2925.00 -1901.96 2913.91 -2952.76 -1955.43 2969.63 -2979.14 -2004.89 2992.44 -2990.30 -2024.98 3016.21 -3002.10 -2045.87 3039.84 -3013.96 -2066.57 3066.30 -3027.04 -2089.83 3093.42 -3039.60 -2114.02 3120.71 -3051.69 -2138.57 3152.72 -3065.38 -2167.56 3179.55 -3076.43 -2192.04 3210.83 -3089.28 -2220.58 3242.45 -3102.10 -2249.51 3273.84 -3114.48 -2278.38 3304.64 -3125.70 -2307.06 3338.38 -3136.58 -2339.04 3370.30 -3146.33 -2369.52 3399.37 -3154.90 -2397.41 3429.82 -3163.82 -2426.64 3461.48 -3173.49 -2456.87 3492.39 -3182.94 -2486.38 3523.80 -3192.53 -2516.39 At Azim (deg) DLS (deg/ 100f) --------------- --------------- 3066.74 3115.54 3165.45 3218.36 3270.62 3324.56 3378.80 3433.67 3489.00 3541.54 3590.94 3611.43 3632.93 3654.41 3678.37 3702.46 3726.43 3754.31 3777.50 3804.56 3831.89 3858.89 3884.91 3912.71 3938.79 3962.44 3987.27 4013.38 4038.96 4065.03 208.54 209.19 209.79 210.37 210.92 211.46 211.99 212.51 213.03 213.51 213.94 214.11 214.27 214.44 214.62 214.82 215.02 215.26 215.47 215.71 215.95 216.19 216.43 216.71 216.98 217.23 217.49 217.75 218.00 218.25 0.86 0.91 2.00 0.85 0.76 1. 40 0.45 0.44 0.67 0.38 1. 31 16.30 14.46 13.36 11.96 14.41 17.24 13.14 7.14 18.89 20.82 9.74 9.07 9.95 1. 08 6.58 4.99 1. 33 0.45 10.99 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA · .. SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 8-Mar-2004 16:45:39 Page 4 of 4 ------ ------- ------ -------- -------- ---------------- --------------- ------ ------- ------ -------- -------- ---------------- --------------- Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) -------- ------ ------- ------ -------- -------- ---------------- -------- ------ ------- ------ -------- -------- ---------------- 61 62 63 64 65 10959.30 10990.07 11022.84 11054.49 11084.10 90.76 90.82 93.85 95.35 95.04 95.73 95.77 95.97 96.42 96.46 96.53 94.05 93.70 94.73 96.53 96.28 94.83 94.77 94.88 94.67 95.29 95.29 254.28 253.10 255.51 258.24 257.36 262.61 264.09 265.61 271. 05 273.77 272.20 273.50 272.33 271.58 271.98 272.26 273.12 272.48 274.10 273.32 272.35 272.35 [(c)2004 IDEAL 108 lC 01] 66 67 68 69 70 11115.95 11146.02 11177.08 11209.54 11242.31 71 72 73 74 75 11272.87 11308.40 11337.66 11367.23 11398.51 76 77 78 79 80 11430.75 11463.02 11495.05 11526.87 11557.92 81 82 11580.40 11635.00 31.86 30.77 32.77 31. 65 29.61 31. 85 30.07 31. 06 32.46 32.77 30.56 35.53 29.26 29.57 31. 28 32.24 32.27 32.03 31. 82 31. 05 22.48 54.60 9054.96 9054.54 9053.20 9050.66 9047.98 9044.99 9041.98 9038.80 9035.29 9031. 62 9028.16 9024.89 9022.91 9020.74 9017 .67 9014.07 9010.95 9008.27 9005.59 9003.00 9001.05 8996.02 3555.53 -3201.69 -2546.89 3586.15 -3210.33 -2576.42 3618.70 -3219.18 -2607.94 3649.88 -3226.35 -2638.66 3678.95 -3232.58 -2667.48 3709.97 -3238.09 -2698.69 3738.84 -3241.56 -2728.41 3768.44 -3244.33 -2759.18 3798.71 -3245.27 -2791.43 3828.40 -3243.90 -2823.96 3855.95 -3242.32 -2854.28 3888.09 -3240.56 -2889.61 3914.60 -3239.08 -2918.77 3941.58 -3238.07 -2948.24 3970.10 -3237.10 -2979.35 3999.37 -3235.92 -3011.37 4028.59 -3234.41 -3043.45 4057.60 -3232.85 -3075.33 4086.30 -3231.03 -3106.98 4114.22 -3229.03 -3137.86 4134.56 -3227.92 -3160.23 4184.15 -3225.69 -3214.55 At Azim (deg) DLS (deg/ 100f) --------------- --------------- 4091.15 4116.33 4143.00 4167.95 4191. 06 4215.23 4236.97 4258.96 4280.64 4300.89 4319.67 4341. 78 4360.14 4379.18 4399.47 4420.35 4441.17 4461.95 4482.51 4502.53 4517.36 4553.95 218.50 218.75 219.01 219.28 219.53 219.81 220.09 220.38 220.70 221.04 221.36 221.72 222.02 222.32 222.63 222.94 223.26 223.57 223.88 224.18 224.39 224.90 10.64 3.84 11.81 9.82 3.14 16.55 4.90 4.91 16.72 8.25 5.11 7.87 4.17 4.30 5.89 1.16 5.22 2.00 5.08 2.59 5.11 0.00 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA Projected to TOe Completi~n "If * * Or ~ GAS LA MANDRELS ST W lVD DEV TYPE VLV LTCH 1 29B2 3000 0" 4 112" X 1.S" MI.1G eN RK 2 4101 4100 7" 4 112" X 1.5" MI.1G OCR RK 3 6439 6000 50" 4 112" X 1,S" MI.1G eN RK 4 7592 6800 4S" 4112" X 1" KBG-2 eN BK 5 9558 8300 39" 4112" X 1" KBG-2 eN BK TREE '" 5-1m¡" CM WElLHEAD'" FMC AC1UA TOR'" AxaSON RT, aEV '" 63.00' ca. aEV '" 34.50' KOP= 7,450' Max Angle '" 94.3"@ 11222' ~umW- 10.733' Datum lVD '" 8990' SS .. 112" 'X' landing Î 2210' I nipple to. 3.813" 113-518" CSG, 72#, L- H 2606' I 80. D'" 12.347" 17-048 Fin Baker 9 5/8" lM1íp stock set on EZSV. 9-5/8" CSG, 47#. L-SO, D'" 8.681" 1 6,629' I 9-5/8" CSG MLLOUT WKXJW, 7700' - 7745' (SECTION MU) 7" lNR, 26#, L·80, .0383 bpf, D'" 6.27S" 0A1E 10/13180 03/19/88 05101/96 02127101 t 1109101 9 S18" X 7" Baker HMC Lnr hogr and IXP pkr 10,090' H 4112" 'X'landìng nipple. D= 3813"' 10,111' H 7" X 4-112" Baker S-3 Packer I I 1 O;í 34' H 4 1/2" 'X' landing nipple. D'" 3.813"' 10,155" H4 112" 'XN' Landing nipple. D= 3.725"' I 10,156' H4112", 12.6#. 9 CrTCIlBox ! 10,157" H ~5" Baker~Lnrhngr Withl - / 12,048' 1-14112", 12.6#, L-80. !BT, slotted liner 14112" LNR. 12.6#.l-80, .0152 bpf, D= 3.958" H 12894' I I 12814' H BTM OF 4 112" SL rD LNR I REV BY COMv£NTS ORIGINAL COMPlETON RWO RIG SIOETRACI< SIS·LG FINAL ŒlllII¡ CORRECTIONS PRUDHOE BAY UNrr WELL: 17-048 ÆRMIT No' API No 50-029-20498-02 2795' FSL &4830' FEi.. Sec. 22. TION, R15E BP Exploration (Alaska) OA IE REV BY cot.fvENTS 01109102 GClKAK SLOTTED LNR CORRECTON 01106/04 Œ?N R'oposed Cor\'Ø!tìon (~04) e e é)C)J-/-Oa3 Schlumberger Drilling & Measurements MWD/lWD log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: lisa Weepie Well No DS-17-04B Date Dispatched: 29-Feb-04 Installation/Rig Nabors 7ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 1 RE ~EIVE[ ) M,~¡ hf'\- 2004 ¡,.. II .: L'.:¡ ¡"¡~..¡',,,N!i:I ^ - '-"">.~ " c:;:: Please sign a-nífr'eturn t~~~~ohnson Received By: ';'-~\> '<' "V"'\ ç")~ 9 C<. ~~ ß "~ xp ation (Alaska) Inc. . Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsoih@bp.com LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private ~·~j---.,fl\ ~ - e ðOJ( -093 Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No DS-17-04BPB1 Date Dispatched: 29-Feb-04 Installation/Rig Nabors 7ES Dispatched By: F.Alabi Data No Of Prints No of Floppies Surveys 2 1 REC:EIVEC t,1" D 2 -~ 0004 . ./-.l \ \... L ÄJ~(I$ka Oil & Gc s Cons. Commillon ¡::.ri horage -~ ~ "'<",.,~ Please sign and return to: James H. Johnson Received By: ~) \ ). ~......"^' _,,')\ c.....c~.~ BP Exploration (Alaska) Inc. . "-... Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address:johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ~~~\\\ ~ ·' . FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 17-04B BP E~ploration (Alaska), Inc. . ... '~\., Permit No: 203 023 20 <-\ . 02:3 . Surface Location: 2795' NSL, 4830' WEL, Sec. 22, TlON, RI5E, UM Bottomhole Location: 452' SNL, 3354' WEL, Sec. 28, TI0N, RI5E, UM Dear Mr. Isaacson: 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. 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./Ple se provide at least twenty-four (24) hours notice for a representative of the Commissio to tness any required test. Contact the Commission's North Slope petroleum fie' ct a -3607 (pager). BY ORDER <}F THE COMMISSION DATED this~ day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W6A- I[ ~O{20o(t .. STATE OF ALASKA _ ALASKA OI~D GAS CONSERVATION COM~ION PERMIT TO DRILL 20 MC 25.005 / 1a. Type of work 0 Drill B Redrill '1b. Current Well Class 0 Exploratory ORe-Entry 0 Stratigraphic Test 0 Service 2. Operator Name: 5. Bond: IBI Blanket 0 Single Well BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 3. Address: 6. Proposed Depth: P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12255' TVD 8975 4a. Location of Well (Governmental Section): 7. Property Designation: . Surface: ADL 02833¥' o~:>3' 2795' NSL, 4830' WEL, SEC. 22, T10N, R15E, UM ' Top of Productive Horizon: 8. Land Use Permit: ,.it> 13. Approximate Spud Date: 309' SNL, 1856' WEL, SEC. 28, nON, R15E, UM February 21,2004 / Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 452' SNL, 3354' WEL, SEC. 28, T10N, R15E, UM I 2560 19,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan RTE 15. Distance to Nearest Well Within Pool Surface: x-708703' y-5928144 Zone;6.SP4 (Height above GL): = 63 feet 17-10 is 828' away at 8751' MD' 16. Deviated Wells: > 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Kickoff Depth 7450 ft Maximum Hole Angle 950 Downhole: 3800' psig Surface: 2920' psig ../ 1ª.~:~:inai:J:::~: Weiaht $:::tio~:uDlingi ~enath MDT(:~:~pe~iotto~D fincltcd~~:.i' 8-1/2" 7" 26# L-80 BTC-M 3054' 7300' 6572' 10354' 8890' 169 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT 2051' 10204' 8771' 12255' 8975' Uncemented Slotted Liner ,/ B Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU 17-04B / 12. Field 1 Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD (ft): 12894 8994 I None 12894 I 8994 . . . . . I .' '.' !ffi! c' '.' .' " MD I Conrlur.tor Junk (measured): None , TVD Int . tP. Proi'1I Ictinn Linp.r Liner f17-04A) Liner (17 -04AL1) 110' 2606' 7745' 20" 13-3/8" 9-518" 390 sx Arcticset II 1975 sx Fondu, 400 sx Permafrost II 800 sx Class 'G' 110' 2606' 7745' 110' 2606' 6878' 3764' 1529' 1711' 7" 190 sx Class 'G' Uncemented Slotted Liner Uncemented Slotted Liner1 7547'-11311' 11287' - 12816' 1183' - 12894' 6744' - 9008' 8998' - 9068' 8951' - 8994' 4-112" 4-1/2" Perforation Depth MD (ft): (17-04A) 11399' -12814' (17-04AL111202' -12871' 20. Attachments IBI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 9035' - 9067' 8959' - 8993' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Date: Contact Dave Wesley, 564-5153 Prepared By Name/Number: Sianature L ) Jk. A. t~_ Phone 564-5521 Date Ill:'rlo~\ Terrie Hubble, 564-4628 ··Ii!Xi. ···Xi';Vi..:,.!........)"../ ·p,y.;(i/i/ic"·i;" '/i/ '"reii·;';;;i. 'c"i:';;j;; Permit To Drill· IAPI Numbe~ Permit Apwo~~, ) / / J See cover letter for Number: )..Dc.¡.- 02. =3 50- 029-20498~02-00 Date: ;;:::-¡ 1// I ~ L (ot~ fftq . ts Conditions Of, A.pproval: Samples Rel1Gir~¡ D Yes~o Mud Log Rfquir~ Y"'" - D'JeY ~ H drogen ~",~asures .~es . 0 No Directional Survey Requ1~ ~~ezba;r No Other: Test ß E. /7,,'t; 1's.¡. .n Pow Æ ~ ft:IftÅ"'/ '. O' ~ (hJ ( l \ / tt,..lt¥~(.. is 0 PE ; <; A1asp¡QK'&~«s<t6ns. comrn¡S:;¡CHl¡ , . BY ORDER OF AnChora~ ¡; /. ¿.., Annroved Bv: I .A""\ r, I f' I Þ.. I ^ I THE COMMISSION Dat¿..'1 h II) , . I Form 10-401 Rev~ 12/2'Oð~._,../ - \~) ~\ ! lJ II \I!-\ L ¡SJbtt In Duplicate Well 17-048 e e Planned Well Summary Horizontal Sidetrack I Target I Zone 48 I' Objective . I AFE Number: I P8D 4P2185 I I API Number: 50-029-20498-02 Surface Location . Offsets 2,485' FNL / 450' FWL TRS 10 N, 15 E, 22 .- TRS 10N,15E,28 TRS 10N,15E,28 ' Target Location Offsets 309' FNL /1,856' FEL Bottom Location Northin 5,924,795.00 Offsets ; 452' FNL /1,926' FWL I Planned KOP: I 7,450' md I / 1 Nabors 7ES I I Rig: Maximum Hole Inclination: Proximity Issues: I Planned TD: 112,255' md I CBE: 134.50' 1 RTE: 163.00' Directional Program W 04 Exit oint: 7,450' md 16,614' sstvd -500 at 5,900' in the original well bore. -94.50 in the planned 6 1/8" horizontal section from 11,200' md to 11,800' md. There are no close approach issues in drilling 17-048. All surrounding f wells ass ma'or risk criteria. Standard MWD with IIFR 1 Cassandra. Well 17-10, with center-to-center distance of 828' at 8,751' md. 19,000' to the nearest P8U ro e line. Logging Program Hole Section: Required Sensors I Service 8 Y:z" intermediate: Real time MWD Dir/GRlPWD throughout the interval. 6 1/8" production: Real time MWD Dir/GRlRes/AIM throughout the interval. Two sample catchers will be reauired at company man call out. ' Cased Hole: None planned Open Hole: None planned 17-048 Sidetrack Page 1 e e Mud Proaram Set Whi PV YP 15 - 25 40+ Drillin 8 Yz" interval window to -200' above THRZ PV YP Tau 0 API FL H 12 -15 25 - 28 3 -7 4 - 6 9.0 Drillin 8 Yz" interval from -9,600' to BHRZ PV YP Tau 0 API FL H 12-15 25-28 3-7 4-6 9.0 Drillin 8 Yz" interval from BHRZ to section TD PV YP Tau 0 API FL H 12 -15 25 - 28 3 - 7 4 - 6 9.0 Densi 8.5-8.6 . PV 10 -12 H 9.0-9.5 Casina I Tubina Proaram Hole Casing/Tubing Wt. Gr~ Connec~ Length Top Bottom Size Size md/tvd md/tvd 8 Yz" 7" 26.0# L-80 BTC-M 3,054' 7,300 / 6,572 10,354 1 8,890 61/8" 4 Yz" slotted 12.6# L-80 IBT 2,051' 10,204/8,771 12,255/8,975 Tubina 4Yz" 9.3# 13Cr-80 VAM TOP 10,204' Surface 10,204/8,771 Cementina Proaram Slurry Design Basis: Fluids Sequence 1 Volume: roduction liner Slurry Design Basis: Fluids Sequence 1 Volume: 17 -04B Sidetrack Page 2 e e Casinq I Formation Inteqritv TestinQ Test Test Point Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500 si surface /' 12.5 EMW 3,500 si surface 10.0 EMW Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. r Disposal Annular In"ection: Cuttings Handling: Fluid Handling: No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo e Borou h. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for in"ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 17 -04B Sidetrack Page 3 e e Casina I Formation Intearitv Te$tfha ,¡r ß' i' Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500 si surface 12.7 EMW 3,500 si surface 10.0 EMW Test !.~ ,l J Well Control / é iil ~f /) Well control equipment consisting 9( 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and ,.án annular preventer will be installe(¥and is capable of handling maximum potential surface pressures,r',1"he ram configuration will be:,,/ .." /" / - /~,,,- BOPE and drilling fluid ~yStem schematics are currently on file with the AOGCC. ,,,,,/" '" ;I' / 0.10 psi/ft) EMW FIT. Well Interval: Maximum antici ated BHP: Maximum surface ressure: Calculated kick tolerance: Planned BOPE test ressure: Planned com letion fluid: 0.10 psi/ft) Disposal Annular In e . n: ¡ff/ CuttingsfHãndling: Fh,Jid Handling: / / /' 17 -04B Sidetrack Page 3 e e Geoloaic Proanosis Formation MD TVDbkb TVDss Comments WS1 6,463 WS2 CM3 6,720 CM2 7,270 CM1 9,381 8,138 8,075 THRZ 9,821 8,478 8,415 BHRZ 10,032 8,641 8,578 LCU 10,079 8,678 8,615 TJG TJF TJE TJD TJC TJB 8,678 8,615 TJA 10,234 8,797 8,734 TSGR 10,354 8,890 8,827 Est. pore pressure 3,200 psi (7.0ppg EMW) ..-/ TSHA 10,387 8,915 8,852 TSHB N/R TSHC N/R TSAD 10,499 8,988 8,925 Est. pore pressure 3,200 psi (6.9ppg EMW) ./ 45N N/R MHO N/R HOT N/R TAR N/R OWC N/R TZ4A N/R 3,300psi is maximum pressure expected in aquifer TZ3 N/R TZ2 N/R BSAD N/R TD Criteria I TD Criteria: Intersect the TSAD at the planned X, Y coordinate. Fault Proanosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 N/A N of traiectory -25' +1- 10O' Fault #2 N/A S of trajectory -4O' +1- 10O' Fault #3 N/A TD + -400' +1- 10O' 17 -04B Sidetrack Page 4 e e Qperations Summary Pre-Ria ODerations: ./ 1. RIH with Coil Tubing. Plt¿g & abandon, with 15.8ppg class 'G' cement, both the 17-04A and 17-04AL 1 well bores. Place cement by-reèiprocating coil above the Sag River lateral window and bull-heading cement from that point. Continue pumping until pressure bumps to -1 ,OOOpsi. Pump sufficient cement to fill both the A and AL 1 well bores, plus squeeze approximately 10bbls, and leave the cement top up in the tubing tail at -10,650'md. The estimated volume of cement required is 80bbls. 2. RlU slick-line. Drift the 3 %" tubing to confirm top of cement, follówing P&A. Also, to confirm the tubing is clear to the required cut depth of -7,525' md. 3. Fluid-pack the 3 %" tubing and 9 5/8" x 3 %" annulus to surface. Test to 3,000 psi. 4. RlU E-line. RIH with the appropriate chemical cutter and cut the 3 %", 9.2#, L-80 tubing at -7,525' md. 5. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 6. Test the 9 5/8" pack-off and tubing hanger seals to 5,000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. Level the pad as necessary. Ria ODerations: 1. Mil RU Nabors rig 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. /' 4. RlU. PuIl3%" tubing from the cut at -7,525' MD and above. 5. RlU E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH and tag tubing stump at -7,525'. POOH. 6. RIH with HES EZSVon E-line. Set bridge plug at -7,470', and as required to avoid cutting a casing /" collar while milling the window. POOH. RID E-line. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. . 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, / and set on bridge plug. Shear off of whip stock. 9. Displace the well to 9.7ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at ± 7,450' MD, plus approximately 20' beyond middle of window. .~ Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 12. M/U 8 %" Dir/GRlPWD assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of /" the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. r' 14. M/U 61/8" Dir/GRlRes/AIM assembly. RIH to the landing collar. ./ 15. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.5ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0ppg /' EMW. Drill ahead to TD per directional proposal. 19. Circulate well bore clean, short trip to shoe, circulate. POOH. // 20. Run a 4 %", 12.6#, L-80 slotted production liner. POOH. 21. RlU and run a 41/2",12.6#, 13Çr-80 tubing completion, stinging into the 41/2" liner tie back sleeve. 22. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 23. Set a BPV. 24. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. /' 25. Freeze protect the well to -2,200'. Secure the well. 26. Rig down and move off. 17 -04B Sidetrack Page 5 - e Post-Ria ODerations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. 17-048 Sidetrack Page 6 e e Phase 1: Move In I Ria UP I Test BOPE Planned Phase Time 22 hours Planned Phase Cost $58,338 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 17-048. However, 17-20 is 59.50' to the North, and 17-21 is 60.67' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters are to be used at all times. ~ The 17-04A well bore will be secured with 2 barriers, (the cement P&A plug and seawater). Prior to pulling the tree, verify a static column of seawater to surface and that no pressure exists. ~ DS 17 is not designated as an HzS site. Standard Operating Procedures for HzS precautions" /' should, however, be followed at all times. Recent HzS data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 17-20 81ppm 17-03 18ppm 17-21 24ppm 17-10 N/A I The maximum level recorded of H2S on the pad wa&m, in 12/2000. . ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time 48 hours Planned Phase Cost $165,157 Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ The 17-04A well bore will be secured with 2 barriers, (the cement P&A plug and the seawater). Prior to pulling the tree, verify a static column of seawater to surface and that no pressure exists. ~ Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ Note that this wellhead is FMC Gen II. The tubing hanger is a 135/8" X 51/2" OCT hanger, with 5 %" RH Acme lifting thread. This is likely a K-Monel hanger. The preferred method of retrieval is by utilizing a spear. Be prepared with appropriate equipment. ~ There is a 3%" CAMCO TRDP-1A SSSV nipple with a single X" control line. 17-048 Sidetrack Page 7 e e ~ There is a 1 %" 0.0. X 2 W' long tubing head alignment pin down hole. It was lost during the completion operation during the 1996 sidetrack. It should not present a problem during the de- completion. It is most likely resting at the 7" liner top. Phase 3: Run Whip Stock Planned Phase Time 35 hours Planned Phase Cost $202,160 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards ~ A 9 5/8" whip stock will be run and set in the existing intermediate casing. ~ There will be no cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 5: Drill 8%" Intermediate Hole Interval Planned Phase Time 130 hours Planned Phase Cost $715,720 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards ~ This well bore will exit the original well in the lower WS1, and drill the Colville, the Kingak, into the Sag River formation. Previous OS 17 wells drilled the Kingak with 9.8 to 10.5ppg mud weights. For this well, the HRZ will require a mud weight of 10.0ppg and the Kingak will require 10.3ppg. " Maintain mud weight at 10.3ppg, minimally, from above the Kingak to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ There is some uncertainty regarding the depth at which the top Sag River will be encountered, once crossing the fault to the downthrown side. ~ Distinguishing the top of the Sag River has proven to be difficult in some of the nearby wells, due to the LAG deposit just on top of the Kingak. In drilling the 3-34B, all indications were that the top of the Sag River had been reached. After drilling out the intermediate liner shoe, it was discovered that there was yet 39 feet of Kingak shale below the shoe. This required increasing the mud weight to attempt to control sloughing shale. It is recommended to take the necessary time to circulate up samples for confirmation of top Sag River penetration in determining casing point. ~ KICK TOLERA¡E: In the worst-case scenario of 9.5ppg pore pressure at the Sag River depth, a fracture gra.l.e. nt of 11.8ppg at the 9 5/8" casing window, and 10.3ppg mud in the hole, the kick tolerance is ~s. 17 -04B Sidetrack Page 8 e e Phase 6: Run and Cement 7" Intermediate Liner Planned Phase Time 31 hours Planned Phase Cost $215,603 Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab I surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 106 hours Planned Phase Cost $611,182 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ There are three near-by faulted areas, with the potential for intersection, while drilling 17-04B. Theses are deemed a low I moderate risk. » The horizontal section of the planned 17-04B well will lie between the two East-West trending faults. The fault to the South is of greater throw, -40 feet. The fault to the North poses less threat. The planned trajectory parallels closer to the Northern fault, and remains -400 feet from the Southern fault at all points along the well path. There is a third fault beyond planned TD of the 17- 04B well. The total depth of the well was planned such that the toe will remain approximately 400 feet from this fault. The uncertainties associated with the position of these faults leads to a higher risk that one of these faults or its associated rubble zone may be penetrated by this sidetrack. Due awareness and preparation will be prudent. Phase 9: Run 4%" Production Liner Planned Phase Time 27 hours Planned Phase Cost $147,592 Reference RP .:. NI A 17 -04B Sidetrack Page 9 e e Issues and Potential Hazards ~ The completion design is to run a 4 Y;z", 12.6#, L-80 slotted liner throughout the production interval. ~ Differential sticking is possible, particularly if some solid liner is placed within the string. The 8.6ppg Flo-Pro will be -650psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner hanger is set prior to POOH. ~ Sufficient 4 Y:z" liner will be run to extend -150' back up into the 7" liner. Phase 12: Run 4 Yz"ComDletion Planned Phase Time 23 hours Planned Phase Cost $440,537 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ The completion, as designed, will be to run a 4Y2", 12.6#, 13Cr-80 production tubing string, stinging into the 4 Y2" liner tieback sleeve. Phase 13: ND/NU/Release Ria Planned Phase Time 16 hours Planned Phase Cost $53,927 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ There are two close proximity surface issues, 17-20 to the North, and 17-21 to the South. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig away from the well and about the pad. 17-048 Sidetrack Page 10 &. THIS NOTICE IN THE DOGHOUSE e 17 -048 Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 134 ppm, December 2000. ./ NORM test all retrieved well head and completion equipment. ./ All wells pass major risk criteria. The closest neighboring wells, at surface, are 17-20 and 17-21. Well 17-20 is approximately 60' to the North, 17-21 is approximately 60' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ Due to sidetracking into the West Sak and drilling the HRZ and Kingak shale, mud weight will be maintained at 10.0ppg through the HRZ, increasing to 10.3ppg through the Kingak to section TD. Monitor ECD closely. ./ There are no known fault crossings expected, during the drilling of the 17-048. No significant losses are expected, but due attention should be paid to the possibility. ./ There are two near-by faulted areas, once the well has landed horizontally in the Z48. The planned well trajectory crosses neither of these, but again, due diligence is warranted. The uncertainty of the positions of these two faults, and the associated rubble zones, increases the risk of incurring some lost circulation. The lost circulation decision tree should be followed if lost fluid returns are encountered. ./ Differential sticking may be encountered. Overbalance is approximately 650 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE OS 17 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 17-048 750 'a' ;¡§ g ~ .¡;¡ "" Q -¡;¡ G 800 ~ ~ COMPANY DETAILS rw Anmw MWD REFERENCE INFORMATION SURVEY PROGRAM DeptII Pm rkptb To Stl.fWylPtan 7450.00 12255.16 f'Lm:ned: Ji-ù4B wp04 Vl Too' CASING DET AfLS Name +N/-S "'B'·W Northing 11-04 191411:5 349JM 59:t&1442{j 108102.55 70"!1'25J08N 148º19'OL&4úW 04 Basting stmpe No< TVD MD Natne Size 7" 4112" 7<000 4.500 ""'" TVD +N!-S +flJ·W Plan: 17-04B wp04 07-D4!Phm 17-04B) Created By: Ken Allen Checked: Date: J 212312003 Date:_ Thite:_ Reviewed: WElL DETAlLS F.aming Lraitudc LùngiWdc Slot TARGET DETAILS Northing FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 9 Azi See MD Inc TVD I 2 3 4 5 6 7 8 9 !O 700 End Dir : 8189.58' MD, 72n8' TVO 8500 Start Dir 141100'; 10372.07' MD. 8903Æ5'TVO SECTION DETAiLS +NI·S +EI·W DLeg Tl'aoo VS"" Target 17-03B T3a ¡ 7-03B T2 Start Oír 5/WO' ; 0817.76' MD,89í!U6'TVD Start Oir41100'; EndDir ; 900 Vertical 17-04B wp04 6000 COMPANY DETAILS MWD REFERENCE INFORMA TlON SURVf:.'Y PROGRAM Depth Fro [);:Pili Tv SurveyIPlan 74:5{tOO J225:5,16 f>1anoed: J7-04B wp04 V2 Plan: 17-û4B wp04 {!7-ú4!Pìan 17-ú4B} BP.A.mo\:;o TDOI Created By: Ken ABen Chedœd: DAte: 2/1311-003 Dti!c Reviewed: Dti!c -200 FORMATION TOP DETAILS No. TYDPath MDPath Formation I 9380.87 CMI 2 9821.02 THRZ 3 10032.04 BHRZ 4 J 0079.94 JKU 5 10234,00 TJA ¡; HJ354AO TSGR 7 HJ3S¡;.99 TSHU S 10499A9 TSAD 9 10604.84 45N CASING DETAlLS No. TVD MD Name Size J 10354AO 7" 7.000 2 12255.15 4112" 4.500 WFLL DETAILS Name ;-NI-8 ~E!-W Northing 17..04 1914.&5 349114 592814420 FASting Latitude Long~ Slot 1œ7ü2.55 1{i"12'25308N 148"WOLß40W 04 L\RGET DETAILS N_ '['VD ;·N/~S +EJ-W Northing E::I$ting Shape SECTION DETAILS See +NI·S MD Inc Azi TVD +EI-W DLeg TFace 0.00 J2.oo 4.00 0.00 14_00 6.00 0.00 5,00 4,00 0.00 VSee Target 1 2 3 4 5 ¡; 7 g 9 10 17-03B n. !7-03B T2 Start Dir 121100' : 7450' MD, 6677.06'TVD Siìm!}if 4/100' : 7470' MD. 6690.35'TVD -25 " :§ 5 ~ +" :;:;: g ~ :;:;: § -3 '" -350 -4500 -4000 -3500 -3000 -2500 -2000 West(-)lEast(+) [500ft/in! ·1500 -1000 -500 o ~Y-SLr1 D.UL.L.INIS ....VIC.. "1~1It1UNt."-4N" terry-Sun - Draft Copy e KW A Planning ObP Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 17 17..()4 Plan 17..()4B Date: 12/2312003 Time: 07:37:59 Page: 1 ~=in=~~:~=e: ~~~.1~3~' True North Seetlon (VS) Reference: Well (O.OON,O.OOE,229.47Azi) Survey Caletdatioø Method: Minimum Curvature Db: Oracle Plan: 17-04B wp04 Date Composed: Version: Tied-to: Principal: Yes Field: Prudhoe Bay 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: Site: PB DS 17 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5926220.53 ft 708405.69 ft Latitude: 70 12 Longitude: 148 19 North Reference: Grid Convergence: Well: 17-04 Slot Name: 17-04 Well Position: +N/-S 1914.85 ft Northing: 5928144.20 ft Latitude: +EI-W 349.84 ft Easting : 708702.55 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan 17-04B Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 63.00' 12/10/2003 57591 nT Depth From (lVD) ft 29.00 +N/-S ft 0.00 Height 63.00 ft Casing Points 12/23/2003 2 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 6.476 N 11.993 W True 1.58 deg 04 70 12 25.308 N 148 19 1.840 W 17-04 7450.00 ft Mean Sea Level 25.59 deg 80.84 deg Direction deg 229.47 MD TVD DIameter HoleSIzé ft ft in in 10354.40 8890.00 7.000 8.500 7" 12255.15 8975.13 4.500 6.125 4 1/2" Formations MD TVD Formations Lith.~ ft ft 9380.87 8138.00 CM1 0.00 0.00 9821.02 8478.00 THRZ 0.00 0.00 10032.04 8641.00 BHRZ 0.00 0.00 10079.94 8678.00 JKU 0.00 0.00 10234.00 8797.00 TJA 0.00 0.00 10354.40 8890.00 TSGR 0.00 0.00 10386.99 8915.00 TSHU 0.00 0.00 10499.49 8988.00 TSAD 0.00 0.00 10604.84 9033.00 45N 0.00 0.00 Targets D~riptioD I)ip, Dlr. 17-03B Fault 1 8943.00 -3699.29 -2551.87 5924376.00 706254.00 70 11 48.921 N 148 20 15.863 W -Polygon 1 8943.00 -3699.29 -2551.87 5924376.00 706254.00 70 11 48.921 N 148 20 15.863 W -Polygon 2 8943.00 -3865.67 -4169.17 5924165.00 704642.00 70 11 47.278 N 148 21 2.774 W -Polygon 3 8943.00 -3699.29 -2551.87 5924376.00 706254.00 70 11 48.921 N 148 20 15.863 W 17-03B Fault 2 8943.00 -3026.42 -3296.60 5925028.00 705491.00 70 11 55.536 N 148 20 37.474 W -Polygon 1 8943.00 -3026.42 -3296.60 5925028.00 705491.00 70 11 55.536 N 148 20 37.474 W AI~tI(I t...-A..W terry-Sun - Draft Copy e KW A Planning ObP 5ip&I .....y-sun PAIL-LINØ ....VIC.. Company: BP Amoco Date: 1212;ªI2()03 . Time:.07:37:!)9 P~ge: Field: Prudhoe Bay Co-orda..ate(NE) ReferFlife: Well: 17~''''l'lIeþ, .orw Site: PB DS 17 Vertieal(TyD) Reference: 63..00' 63.0 Well: 17-04 Seetion{VS).ßeference: W~I (0.00N,O.ooE,229A7Azi) WeUpath: Plan 17 -04B Survey CalewlitiOnMetbod: Minimum Curvature Db: Oracle Targets Map Map <-. Latitúde -..> <...,.Longitúde-> Name Deseription TVD +N/-S +EI-W Northing Jj;~ng Deg Min .See Deg~" ...Sec; Dip. Dir. ft ft ft ft ft -Polygon 2 8943.00 -3100.76 -4154.03 5924930.00 704636.00 70 11 54.801 N 148 21 2.347 W -Polygon 3 8943.00 -3026.42 -3296.60 5925028.00 705491.00 70 11 55.536 N 148 20 37.474 W 17-03B T2 8976.00 -3211.12 -3599.84 5924835.00 705193.00 70 11 53.718 N 148 20 46.268 W 17 -o3B Geo-Poly 8976.00 -3211.12 -3599.84 5924835.00 705193.00 70 11 53.718 N 148 20 46.268 W -Polygon 1 8976.00 -2593.93 -1860.03 5925500.00 706915.00 70 11 59.795 N 148 19 55.802 W -Polygon 2 8976.00 -3502.45 -1566.01 5924600.00 707234.00 70 11 50.860 N 148 19 47.267 W -Polygon 3 8976.00 -3440.71 -3799.27 5924600.00 705000.00 70 11 51.459 N 148 20 52.050 W -Polygon 4 8976.00 -3667.06 -4296.74 5924360.00 704509.00 70 11 49.230 N 148 21 6.477 W -Polygon 5 8976.00 -3235.75 -4409.87 5924788.00 704384.00 70 11 53.472 N 148 21 9.766 W 17 -03B T3a 9053.00 -3103.01 -2299.29 5924979.00 706490.00 70 11 54.786 N 148 20 8.541 W Plan Section Information MD Incl Azlm TVD +N/..s +EI-W DLS BuUd Turn TFO Target ft deg deg ft ft ft deg/1 OOftdeg/1 ooft deg/100ft deg .... 7450.00 48.25 199.43 6677.06 -1943.46 -469.94 0.00 0.00 0.00 0.00 7470.00 48.50 202.62 6690.35 -1957.41 -475.31 12.00 1.27 15.96 85.00 8189.58 39.43 242.58 7217.80 -2319.03 -788.39 4.00 -1.26 5.55 122.12 10372.07 39.43 242.58 8903.65 -2957.42 -2018.68 0.00 0.00 0.00 0.00 10733.32 90.00 242.58 9053.00 -3103.01 -2299.29 14.00 14.00 0.00 0.01 17-03B T3a 11222.82 94.33 271.66 9034.10 -3211.04 -2770.87 6.00 0.89 5.94 81.14 11817.76 94.33 271.66 8989.16 -3193.88 -3363.86 0.00 0.00 0.00 0.00 12055.16 92.00 260.00 8976.00 -3211.12 -3599.84 5.00 -0.98 -4.91 -100.97 17-03B T2 12105.16 90.00 260.00 8975.13 -3219.80 -3649.07 4.00 -4.00 0.00 180.00 12255.16 90.00 260.00 8975.13 -3245.85 -3796.79 0.00 0.00 0.00 0.00 Survey MD Inel Azlm TVD Sy. TVD MapN MriiE VS. DLS TFO .... ·...901·. ft deg deg ft ft ft ft deg/100ft deg .7450.00 48.25 199.43 6677.06 6614.06 5926188.60 708286.52 1620.07 0.00 0.00 MWD 7470.00 48.50 202.62 6690.35 6627.35 5926174.51 708281.54 1633.21 12.00 85.00 MWD 7500.00 47.87 203.99 6710.35 6647.35 5926153.74 708273.27 1653.28 4.00 122.12 MWD 7600.00 45.90 208.76 6778.71 6715.71 5926087.49 708242.72 1720.37 4.00 121.20 MWD 7700.00 44.13 213.84 6849.42 6786.42 5926026.08 708207.73 1787.51 4.00 117.94 MWD 7800.00 42.61 219.22 6922.14 6859.14 5925969.81 708168.46 1854.37 4.00 114.35 MWD 7900.00 41.35 224.90 6996.51 6933.51 5925918.96 708125.11 1920.63 4.00 110.43 MWD 8000.00 40.38 230.84 7072.16 7009.16 5925873.77 708077.89 1985.97 4.00 106.21 MWD 8100.00 39.73 236.97 7148.73 7085.73 5925834.45 708027.03 2050.07 4.00 101.72 MWD 8189.58 39.43 242.58 7217.80 7154.80 5925804.39 707978.58 2106.17 4.00 97.02 MWD 8200.00 39.43 242.58 7225.84 7162.84 5925801.18 707972.79 2112.62 0.00 0.00 MWD 8300.00 39.43 242.58 7303.09 7240.09 5925770.39 707917.26 2174.47 0.00 0.00 MWD 8400.00 39.43 242.58 7380.33 7317.33 5925739.59 707861.72 2236.33 0.00 0.00 MWD 8500.00 39.43 242.58 7457.58 7394.58 5925708.79 707806.18 2298.18 0.00 0.00 MWD 8600.00 39.43 242.58 7534.82 7471.82 5925878.00 707750.64 2360.04 0.00 0.00 MWD 8700.00 39.43 242.58 7612.07 7549.07 5925647.20 707695.10 2421.89 0.00 0.00 MWD 8800.00 39.43 242.58 7689.31 7626.31 5925616.41 707639.56 2483.75 0.00 0.00 MWD 8900.00 39.43 242.58 7766.56 7703.56 5925585.61 707584.03 2545.60 0.00 0.00 MWD 9000.00 39.43 242.58 7843.80 7780.80 5925554.82 707528.49 2607.46 0.00 0.00 MWD 9100.00 39.43 242.58 7921.05 7858.05 5925524.02 707472.95 2669.31 0.00 0.00 MWD 9200.00 39.43 242.58 7998.29 7935.29 5925493.22 707417.41 2731.17 0.00 0.00 MWD 9300.00 39.43 242.58 8075.54 8012.54 5925462.43 707361.87 2793.02 0.00 0.00 MWD 9380.87 39.43 242.58 8138.00 8075.00 5925437.53 707316.96 2843.04 0.00 0.00 CM1 9400.00 39.43 242.58 8152.78 8089.78 5925431.63 707306.34 2854.88 0.00 0.00 MWD 9500.00 39.43 242.58 8230.03 8167.03 5925400.84 707250.80 2916.73 0.00 0.00 MWD !!!!ipE!rof'1y-!5LS1 terry-Sun - Draft Copy e ObP a..ILLINII ....VIC.. "1~UfIIl~ANY KW A Planning Company: BPAmócò Dlltèf .. 1212312003 Time:. 07:37:59 ),>age: 3 Field: Prudhoe BaY Có-ðnllnate(NE)~c ferenee: VIIell:17..04, True NQM Site: PB DS 17 VertieaJ (fVD)J{eferenee: 63.00'63.0 WeD: 17..04 SectIon (VS)Referenee: Well(O,99N.O.ooE.229.47~) WeDpath: Plan 17..048 Survey CakUlatiOlIMethod: MinimurnCurvaWreÐb: 0ta<:Ie Survey MD Inel ..ùim TVD Sys TVD ft deg (leg ft ft 9600.00 39.43 242.58 8307.27 8244.27 5925370.04 707195.26 2978.59 0.00 0.00 MWD 9700.00 39.43 242.58 8384.51 8321.51 5925339.25 707139.72 3040.44 0.00 0.00 MWD 9800.00 39.43 242.58 8461.76 8398.76 5925308.45 707084.18 3102.30 0.00 0.00 MWD 9821.02 39.43 242.58 8478.00 8415.00 5925301.98 707072.51 3115.30 0.00 0.00 THRZ 9900.00 39.43 242.58 8539.00 8476.00 5925277.66 707028.65 3164.15 0.00 0.00 MWD 10000.00 39.43 242.58 8616.25 8553.25 5925246.86 706973.11 3226.00 0.00 0.00 MWD 10032.04 39.43 242.58 8641.00 8578.00 5925236.99 706955.31 3245.82 0.00 0.00 BHRZ 10079.94 39.43 242.58 8678.00 8615.00 5925222.24 706928.71 3275.45 0.00 0.00 JKU 10100.00 39.43 242.58 8693.49 8630.49 5925216.06 706917.57 3287.86 0.00 0.00 MWD 10200.00 39.43 242.58 8770.74 8707.74 5925185.27 706862.03 3349.71 0.00 0.00 MWD 10234.00 39.43 242.58 8797.00 8734.00 5925174.80 706843.15 3370.74 0.00 0.00 TJA 10300.00 39.43 242.58 8847.98 8784.98 5925154.47 706806.49 3411.57 0.00 0.00 MWD 10354.40 39.43 242.58 8890.00 8827.00 5925137.72 706776.28 3445.21 0.00 0.00 7" 10372.07 39.43 242.58 8903.65 8840.65 5925132.28 706766.47 3456.15 0.00 0.00 MWD 10375.00 39.84 242.58 8905.91 8842.91 5925131.37 706764.83 3457.97 14.00 0.01 MWD 10386.99 41.51 242.58 8915.00 8852.00 5925127.58 706758.00 3465.58 14.00 0.01 TSHU 10400.00 43.34 242.58 8924.61 8861.61 5925123.33 706750.32 3474.13 14.00 0.01 MWD 10425.00 46.84 242.58 8942.25 8879.25 5925114.74 706734.84 3491.37 14.00 0.01 MWD 10426.09 46.99 242.58 8943.00 8880.00 5925114.36 706734.15 3492.14 14.00 0.01 17-03B Fault 1 10450.00 50.34 242.58 8958.79 8895.79 5925105.65 706718.45 3509.62 14.00 0.01 MWD 10475.00 53.84 242.58 8974.15 8911.15 5925096.09 706701.20 3528.83 14.00 0.00 MWD 10478.15 54.28 242.58 8976.00 8913.00 5925094.85 706698.97 3531.32 14.00 0.00 17 -03B Geo-Poly 10499.49 57.26 242.58 8988.00 8925.00 5925086.30 706683.55 3548.50 14.00 0.00 TSAD 10500.00 57.34 242.58 8988.28 8925.28 5925086.09 706683.17 3548.92 14.00 0.00 MWD 10525.00 60.84 242.58 9001.12 8938.12 5925075.70 706664.42 3569.80 14.00 0.00 MWD 10550.00 64.34 242.58 9012.63 8949.63 5925064.94 706645.01 3591.41 14.00 0.00 MWD 10575.00 67.84 242.58 9022.76 8959.76 5925053.86 706625.03 3613.67 14.00 0.00 MWD 10600.00 71.34 242.58 9031.48 8968.48 5925042.50 706604.54 3636.48 14.00 0.00 MWD 10604.84 72.01 242.58 9033.00 8970.00 5925040.27 706600.52 3640.96 14.00 0.00 45N 10625.00 74.84 242.58 9038.75 8975.75 5925030.90 706583.63 3659.78 14.00 0.00 MWD 10650.00 78.34 242.58 9044.55 8981.55 5925019.11 706562.36 3683.46 14.00 0.00 MWD 10675.00 81.84 242.58 9048.85 8985.85 5925007.18 706540.83 3707.44 14.00 0.00 MWD 10700.00 85.34 242.58 9051.64 8988.64 5924995.13 706519.11 3731.63 14.00 0.00 MWD 10725.00 88.84 242.58 9052.92 8989.92 5924983.03 706497.27 3755.94 14.00 0.00 MWD 10733.32 90.00 242.58 9053.00 8990.00 5924979.00 706490.00 3764.04 14.00 0.00 17 -03B T3a 10750.00 90.15 243.57 9052.98 8989.98 5924971.04 706475.34 3780.26 6.00 81.14 MWD 10800.00 90.62 246.53 9052.64 8989.64 5924948.70 706430.62 3828.42 6.00 81.14 MWD 10850.00 91.08 249.50 9051.90 8988.90 5924928.72 706384.80 3875.81 6.00 81.16 MWD 10900.00 91.53 252.46 9050.77 8987.77 5924911.13 706338.02 3922.31 6.00 81.21 MWD 10950.00 91.99 255.43 9049.23 8986.23 5924895.99 706290.40 3967.79 6.00 81.27 MWD 11000.00 92.43 258.40 9047.30 8984.30 5924883.34 706242.07 4012.13 6.00 81.36 MWD 11050.00 92.87 261.37 9044.99 8981.99 5924873.22 706193.17 4055.20 6.00 81.48 MWD 11100.00 93.31 264.34 9042.29 8979.29 5924865.64 706143.83 4096.88 6.00 81.62 MWD 11150.00 93.73 267.32 9039.22 8976.22 5924860.64 706094.18 4137.07 6.00 81.78 MWD 11200.00 94.15 270.30 9035.78 8972.78 5924858.23 706044.37 4175.64 6.00 81.96 MWD 11222.82 94.33 271.66 9034.10 8971.10 5924857.99 706021.61 4192.69 6.00 82.16 MWD 11300.00 94.33 271.66 9028.27 8965.27 5924858.08 705944.66 4249.71 0.00 0.00 MWD 11400.00 94.33 271.66 9020.71 8957.71 5924858.21 705844.95 4323.60 0.00 0.00 MWD 11500.00 94.33 271.66 9013.16 8950.16 5924858.34 705745.24 4397.49 0.00 0.00 MWD 11600.00 94.33 271.66 9005.60 8942.60 5924858.47 705645.53 4471.38 0.00 0.00 MWD 11700.00 94.33 271.66 8998.05 8935.05 5924858.60 705545.82 4545.26 0.00 0.00 MWD 11800.00 94.33 271.66 8990.50 8927.50 5924858.73 705446.11 4619.15 0.00 0.00 MWD Company: Field: Site: Well: Wellpath: EipliU"T'Y-!IIiLr1 D'ULL'Nø ....VII::.. Ii, UALUtll"WJUN t'DMl'A/IfI BP Amoco Prudhoe Bay PB DS 17 17·04 Plan 17 -04B Survey MD Incl Azim ft deg deg 11817.76 94.33 271.66 11900.00 93.54 267.61 12000.00 92.55 262.70 12055.16 92.00 260.00 12105.16 90.00 260.00 12200.00 90.00 260.00 i 12255.16 90.00 260.00 terry-Sun - Draft Copy e KW A Planning ObP Date: 12/2312003 Time: CO-Ordinate(NE) Reference: Vertical (fVD) Reference: Sediøn (VS) Reference: Survey Calculation Method: 'fVD Sys 'fVD MapN ft ft ft 8989.16 8926.16 5924858.75 705428.40 4632.27 0.00 0.00 MWD 8983.51 8920.51 5924855.96 705346.43 4694.96 5.00 259.03 MWD 8978.19 8915.19 5924844.79 705247.23 4776.05 5.00 258.75 MWD 8976.00 8913.00 5924835.00 705193.00 4822.84 5.00 258.49 17-038 T2 8975.13 8912.13 5924824.96 705144.03 4865.90 4.00 180.00 MWD 8975.13 8912.13 5924805.92 705051.13 4947.60 0.00 0.00 MWD 8975.13 . 8912.13 5924794.84 704997.10 4995.11 0.00 0.00 4 1/2" p 055205 DATE 11/25/2003 CHECK NO. 055205 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 11/25/200 PR 1118030 PERMIT TO DRILL EES \7·0\.lb H RECE\V ~.D JAN 2 ß 20 4 . & G s Cons. Commìs:;lon Alaska 01\ a Anchorag TOTAL ~ e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK995t9-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 055 205 CONSOLIDATED COMMERCIAL ACCOUNT PAY: e TO THE ORDER OF: II' 0 5 5 20 5 II' I: 0.... ¡. 2 0 :H] g 5 I: 0 ¡. 2 ? 8 g ¡; II' e e TRANSMJTAL LETTER CHECKLJST CJRCLE APPROPRJATE LETTERlPARAGRAPHS TO BE JNCLUDED IN TRANSMJTT AL LETTER WELL NAME f?8¿{ /7-0<1/:5 20'1-023 PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) M1JL TI Tbe permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. . (If API number Productionsbould continue to be reported as last two (2) digits a function of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dum ber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fun EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrougb target zones. ." Rev: 07/10/02 C\jody\templates e ~ o o Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name PRUDHOE BAY UNIT 17-04B Program DEV PTD#: 2040230 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV/PEND GeoArea 890 Unit 11650 On/Off Shore On Administration 1 Permittee attachejj . . . . . . . - - - - - - - - - · . . . . . . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 .Leasenumber .apRropriate. . . . . . - - - - - -- - - - - - __...Yes. - - - - - - -- - - - - - - - - - - - - - - - - - - 3 .UJllque well.rlame.aod Ol!mb.er . . . . . . . . . . . . . . . . . . . . . - · . . . . . . . .Yes. . _ _ _ _ 4 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - -- - - - - - - - -- 4 We.IIJQcated In.a.d.efjned-pool. . . . . . . . . . . . . . . . . .Yes. - - - - - - - - - - - - - - - - - - - 5 WellJQcaled proper .dlstance. from driJling unitb.ound.ary. - - - - - . . Yes . - - - - - - - -- 6 We.ll JQcated proper .dlstance. from Qtber wells - - - - - .Yes. . - - - - - - - - - - - -- - - - - - - - - - 7 .S.utfjcient.acreag.e.aYailable In.drilJiog. unjt. - - - - - - - - - - · . . . . .Yes. - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - 8 Jf.deviated, js. weJlbore plaUncJu.ded - - - - - - - - - - - - - - . · . . . . .Yes. - - - - - - -- - - - - - - - - - 9 .D-peJ'ator onl}l affected party. . . . . - - - - - - - - - - - - - - · . . . . .Yes. - - - - - - - - - - - - - - - - 10 .0-peJ'ator bas.approprlate.b.ond lnJQrce. . . . . . . . . . . . . . . . . - · . . . . . . . .Y.es. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - -- 11 Permil cao be issued witlJQut co.nserva.tion order. . - - - - · . . . . . . . .Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Permit. c.ao be lssued witbout administratille.a-pprovaJ . . . . - - - - - - .Yes. . - - - - - - - - - - - - - - - - - SFD 1/30/2004 13 Can permit be approved before 15-day wait Yes 14 We.ll Jocated within area and.strata .authorlzed by lojectioo Ord.er # (pulIO# in.comm.eots). (For. NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 .AII wel!s.wittltn .1 14. mite.are.a.of reyieW ideotified (For ~ervj~ well onl}lL . . . . . . . . . . . . . . NA. . . - - ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - ~ - - - - - 16 Pre-produ.ced injector; jjuration.of pre-produc;tioo les~ than.:3 months. (For.servtœ welt QnJy) . NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 ACMP.Fïndjng.of Con.si.stel1cy.h.as Þee.nj~sued. for.this proiect . . . . __ NA - - - - - - - - - - - - - - - - - - - - - Engineering 18 .C.oodu.ctor st(ing.provided . . . . . . . . . . . . . . . . . NA. - - - - - - -- - - - - - - - - - - - - - - 19 .S.urfaœcasing.pJQtec;t~ alLk.nowrl USQWs . . . . . . - - - - - - __ ..NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - 20 .CMT vol. adequ.ate. to circ.u tate. on .cond.uctor. & surf csg . . - - - - -- NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 .CMT vol. adequ.ate. to tie-iJlJQng .striog to surf C&g. . - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 .CMT will çoyera]l koown .produc;tiye bori¡!:Orls. - - - - - - No. . . Slotte.d, . - - - - - -- - - - - - - - - - - - - - - - - - - - - - 23 .C.asiog de.sigos adeQua.te for C,. T~ B .&. p-ermafrost . . . · . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 .Adequ$ite.tan.kage.oJ re.serve pit. . . . . . . . . . . - - - - - - -- Yes. . Nab.ors.7ES, . . . . . . . . - - - - - - - - - - - - - - - - - - - -- 25 Jf.a.re-d(il~ has.a. t~03 for abandonme.nt beeo apPJQved . . . . . . . . . . . . Yes. * - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 26 Adequate .wellb.ore. $.eparatio.n .propo$.ed. . . . . . . . . . . . . . . . . . . . . . . · . . .Yes. . - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Jf.diVertenequired, does jLmeet reguJations. . . . . . . . . . . . . . . . . . .NA Sidetrack.. . . . . - - - - - - - - - - - - - - - - - - - - Appr Date 28 .DriUiog fluid. program sc.hematic.& eq.uip Jistadequate. . - - - - - - -- . . .Yes. Max MW.1.0,3.ppg. - - - - - - - - - - -- WGA 1/30/2004 29 .BOPEs,d.o.they meelreguJa.tion . . . . . . . . . - - - - - - - - - - - - - - - -- · . . .Yes. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 30 .BOPE.pre.ss raiiog ap-propriate; .testto .(put psig tn .comments). . . . . · . . .Yes. Test to .3500. Rsi. .MSF' 29.20 psi. . . . . . . . . . . - - - - - - - - - 31 .C.hoke.manjfold compJies w/API. RF'-5:3 (May 64). . . . . . . . . . . . . . . . . . Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur withoutoperatio.n .shutdown. . . . . . . . . . . . . Yes - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - 33 J$. Rre~el1ce. of H2S gas. pTob.able. . - - - - - - - - - - - - - - - - - - - - - - -- No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Meçba.nlcaLcoodit[oo ofwe.lIs wlthin AOß yerified (for. service wel! only). . __. NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Geology 35 .Permit cal1 be lssu.ed wlo hydr.ogen s.utfide measur.es. . - - - - - - · . . No. . Close.st we.IUQ 17.-04BaHL.is 17.-03~ wbich measur.ed18 PRm H2S.. . . . . . 36 .D.ata.preseoted Orl Rote.ntial ove.rpre$.sure .zones. . . . . . . . . . . . . . . . . . · . . .Yes. Expected rese.rvojr -pre.ssure i.s .6,9.ppg EMW; will.be .drilled wjtb 8.6 ppg mud. Appr Date 37 .Sei.smlc.analysjs of sbaJlow gas.zooes. . . . . . . . . . . __ ..NA - - - - - - - - SFD 1/30/2004 38 .Seabed .conditioo survey -<if off-shore) . . . . . .NA - - - - - - - - - - - - -- 39 . Conta.ct namelpÌ1QneJor.weekly progre~s.reRorts [exploratory Qoly] . . . . . . ...NA - - Geologic Engineering Public Date Commissioner Date: Commissioner: Date Commissioner D')\J ~<..) -¿( <1-
