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Home My WebLink About201-175 { STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la Well Status Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned iyJ'/�f uopd--�ondielb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name. 5 Date Comp.,Susp., 12.Permit to Drill Number ConocoPhillips Alaska, Inc. orAband August 6,2014 201-175/314-306 ' 3 Address 6 Date Spudded 13.API Number. P.O. Box 100360,Anchorage,AK 99510-0360 September 9,2001 50-103-20389-00 . 4a.Location of Well(Governmental Section) 7.Date TD Reached 14.Well Name and Number Surface: 161'FNL, 1186'FEL,Sec. 3,T9N, R7E, UM September 28,2001 kQV 2N-350 - Top of Productive Horizon 8.KB(ft above MSL): 154'RKB 15 Field/Pool(s). 1294'FNL, 1919'FEL,Sec.5,T9N, R7E, UM GL(ft above MSL). 119'AMSL Kuparuk River Field - Total Depth 9.Plug Back Depth(MD+TVD) 1536'FNL,2606'FEL,Sec. 5,T9N, R7E, UM 12092'MD/4521'TVD Tarn Oil Pool - 4b Location of Well(State Base Plane Coordinates,NAD 27). 10 Total Depth(MD+TVD) 16.Property Designation. Surface: x-460406 y- 5911849 Zone-4 13929'MD/5018'TVD ADL 375075 ' TPI: x-449111 y- 5910784 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit Total Depth. x-448423 y- 5910546 Zone-4 nipple @ 433'MD/433'TVD 4306 18 Directional Survey Yes ❑ No❑✓ 19 Water Depth,if Offshore: 20 Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25 050) N/A (ft MSL) 1236'MD/1196'TVD 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 Gyro,Temp log not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 31' 134' 31' 134' 24" 260 sx AS I 9.625" 40# L-80 30' 3736' 30' 2285' 12.25" 553 sx AS Lite,346 sx CI G 7" 26# L-80 31.5' 12818' 31.5' 4725' 8.5" 503 sx Class G 4.5" 12.6# L-80 12607' 13929' 4666' 5018' 6.125" 205 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) 4.5" 12567' 12592'MD/4662'ND and perfs squeezed off: 12614'MD/4668'ND 13 10'-13620'MD 4934'-4936'ND 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC. aolle Yes No a RECEIVED Was hydrauDEPTH INTERVALduring (MD)completion? AMOUNT AND KIND❑OF MATERIAL USED �LNOV 1 2 2014 cement plug @ 12092'MD 54 bbls of 15.8 ppg Class G ,, AOGCC 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071 NONE Form 10-407 Revised 10/2012 v rG Z/G //.s CONTINUED ON REVERSE Submit original only � y/ 3' )I'1`� RBDM JAN — 6 2015 ✓G 29. GEOLOGIC MARKERS(List all formations and m. .rs encountered): 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1236' 1196' needed,and submit detailed test information per 20 AAC 25 071. Top T-3 13175' 4823' Top T-2 13626' 4938' N/A Formation at total depth: 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Tyson Wiese @ 263-4250 Email Tyson.M.Wiese@conocophillips conn Printed Name cirIKurnia Title: Supervising Engineer Completions Signature Phone 263-4692 Date /116-1 i T INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed Item 1a: Classification of Service wells' Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this 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:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP PROD 2N-350 Conoc i'hillip5 �_ Well Attributes Max Angle&MD TD Alaska.Inc. �^' Wellbore API/UWI Field Name Wellbore Status ncl(') MD(RKB) Act Btm(MB) r r:« ,R,II m '' 501032038900 TARN PARTICIPATING AREA PROD 76.91 11479.30 11929.0 ... Comment H2S(ppm) Date Annotation End Date 68-Grd(ft) -Rig Release Date 2N-350,8/3/20143'.20:47 PM SSSV:NIPPLE Last WO: 9/30/2007 35.00 10/2/2001 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11587.0 5/6/2014 Rev Reason:CEMENT PLUG,TUBING CUT hipshkf 8/3/2014 I)p Casing Strings �r Casing Description OD(in) ID(n) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER;29.3 • al 1 CONDUCTOR 16 15.062 31.0 134.0 134.0 62 50 H-40 WELDED }. Casing Description OD(in) ID(in) Top(ftK8) Set Depth(ttKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.697 30.0 3,736.0 2,2853 4000 L-80 BTCM yg Casing Description OD(in) ID(in) Top(ftK8) Set Depth(RKB) Set Depth(ND)...WULen(I...Grade Top Thread ��I''� PRODUCTION 7 6.276 31.5 12,818.1 4,725.1 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �I ass,LINER 4 12 3.958 12,607.0 13,929.0 5,018.1 1260 L-80 NSCT Liner Details .AA/CONDUCTOR;31.0-134.0 I _ - Nominal ID Top(RKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) NIPPLE,432.6 12,607.0 4,665.7 74.05 SLEEVE LINER TIEBACK SLEEVE 5.250 12,614.4 4,667.7 74.04 PACKER ZXP LINER TOP PACKER 5.000 SURFACE 30.0-3.736.0 12,621.1 4,669.6 74.03 HANGER BAKER FLEX LOCK LINER HANGER w/RS NIPPLE 5.000 12,633.8 4,673.1 73.97 XO Reducing CROSSOVER 5.5"x4.5" 4.500 GAS LIFT,4,510.2 Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..i Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.950 29.3 12366.6 4,654.6 12.60 L-80 IBT GAS LIFT,8,229.7 :Completion Details Nominal ID Top(RKB) Top(TVD)(RKB) Top Ind(°1 Item Des Com (in) 29.3 29.3 0.13 HANGER FMC TUBING HANGER 4.500 GAS LIFT;10,593.7 4326 432.5 5.09 NIPPLE CAMCO LANDING DB-6 NIPPLE 3.875 I12,540.0 4,647.3 74.09 NIPPLE CAMCO LANDING DB-6 NIPPLE 3.813 Tubing Cut,n,367.6 12,547.3 4,649.3 74.09 LOCATOR BAKER NO GO LOCATOR 3.870 111 12,547.6 4,649.4 74.09 SEAL ASSY BAKER 192-47 LOCATOR SEAL ASSEMBLY-STABS 3.870 INTO ORIGINAL PBR @ 12559' GAS LIFT;12,492.7 a Tubing Description String Ma...ID(in) Top(RKB) -Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection _... TUBING Original 5.525 4.000 12,559.4 12,630.6 4,672.2 (3.5"TBG OD) NIPPLE 12,540.0 Completion Details Nominal ID Top(RKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) 12,559.4 4,652.6 74.08 PBR BAKER 80-47 POLISHED BORE RECEPTACLE 4.000 LOCATOR 12,547.3 !. 12,592.1 4,661.6 74.06 PACKER BAKER S-3 HYDRO SET PACKER 3.875 12,611.8 4,667.0 74.04 NIPPLE CAMCO DB-6 NIPPLE 3.750 SEAL ASSY,12.547.6 12,629.2 4,671.8 73.99 WLEG WIRELINE ENTRY GUIDE 3.956 I 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) POR 12.559.4 Top(ND) Top In Top(RKB) (ttKB) r) Des Com Run Date ID(in) 11,367.6 4,323.0 74.16 Tubing Cut TUBING CUT 8/1/2014 , 13,330.0 4,865.9 74.94 Cement 3.6"x 4'CEMENT RETAINER 6/29/2014 PACKER 12,592.1 Retainer Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f NIPPLE:12.611 8 i Top(MB) Btm(RKB) (ftK8) (ttKB) Zone Date t) Type Com 13,610.0 13,620.0 4,933.7 4,9362 S-3,2N-350 11/30/2001 6.0 IPERF 2 7/8"HSD,60 deg BH I Stimulations&Treatments .I Min Top Max Btm •5 t Depth Depth Top(ND) Btm(TVD) .. RKB RKB ( ) ( ) (RKB) (ttKB) Type Date Com WLEG,12,629.2 13,610.0 13,620.0 4,933.7 4,936.2 FRAC 12/2/2001 BERMUDA FRAC,236,0009 16/20 8 12/18 CARBOLITE,10 PPA ON PERFS Cement Squeezes Top(ND) Btm(ND) Top(RKB) Btm(NKS) (RKB) (RKB) Des Start Date Com 12,092.0 13,610.0 4,520.9 4,933.7 Cement Plug 6/29/2014 Pump 54 BBLS of 15.8 PPG Class G Cement Mandrel Inserts St ati C on No Top(RKB) (ftK8) Make Model OD(in) Sent 7 ) Valve Latch Port Size TRO Run ( Type Type ( (in) (psi) Run Date in 1 4,510.2 2,482.0 CAMCO KBG-2- 1 Gas Lift DMY BK 0.000 0.0 5/13/2014 1R PRODUCTION;31.512,818.1 2 8,229.7 3,490.6 CAMCO KBG-2- 1 Gas Lift DMY BK- 0.000 0.0 5/14/2014 1R EXT 3 10,593.7 4,112.8 CAMCO KBG-2- 1 Gas Lift DMY BK-5 0.000 0.0 9/30/2007 1R 4 12,492.7 4,634.3 CAMCO KBG-2- 1 Gas Lift OPEN 5/21/2014 1R Notes:General&Safety Cement Retainer;13,330.0 End Date Annotation 1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 FRAC;13,610 0 IPERF.13.610.0-13.620.0-1 I LINER;12.607.0-13.929.0 2N-350 WELL WORK SUMMARY DATE SUMMARY 3/28/2014 (PRE RWO) : FUNCTION TEST ALL LDS (ALL GOOD), POT-T(PASSED), PPPOT-T (PASSED), POT-IC (PASSED), PPPOT-IC (PASSED), 5/6/2014 (STANDBY FOR VALVE CREW UNTIL 14:30) DRIFT TBG WITH 3.50" BLR ASSEMBLY &TAG @ 12,587' SLM ( EST 7' OF FILL) MEASURED BHP @ 13,602' RKB: 2699 PSI. IN PROGRESS. 5/7/2014 BRUSH n' FLUSH TBG DOWN TO 12540' RKB W/PUMPING @ 2-2.3 BPM @ 1650 PSI (UNABLE TO PASS D-NIPPLE); DRIFT W/ DMY CEMENT RETAINER DOWN TO 13425' SLM; ATTEMPT TO SET 3.75" PLUG BODY AND LEFT PLUG IN PACKER @ 12592' RKB; PULLED PLUG BODY. IN PROGRESS. 5/8/2014 SET 3.75" CAT SV @ 12,612' RKB; DEPLOYED 3.78" x 33" CATCHER FROM SURFACE & CHASED WITH KOT (ENCOUNTERED HYDRATES @ 3410' SLM); DRIFTED TBG WITH 3.50" BAILER &TAGGED HYDRATES @ 962' SLM. (DIESEL PUMPED IN WELL WAS LOADED FROM UPRIGHT @ KIC). JOB SUSPENDED 5/10/2014 PUMP 450 BBLS HOT DIESEL DOWN IA AND UP TBG JOB COMPLET 5/11/2014 (MISC)AL LINE VALVE TEST (AL LINE HEADER VALVE HOLDS, CHOKE AND BLOCK VALVE LEAK BY). 5/12/2014 TAG CATCHER @ 4483' SLM & PUSH DOWN TO 12562' SLM; ATTEMPT TO PULL GLV'S @ 8230' &4510'. IN PROGRESS. 5/13/2014 PULLED BENT LATCH GLV @ 4510' RKB AND GLV @ 8230' RKB. SET DV @ 4510' RKB. IN PROGRESS. 5/14/2014 SET EXTENDED PKG DV @ 8230' RKB. ATTEMPTED MIT TBG, IA TRACKING. PULLED OV (CHECK FOULED) @ 12492' RKB; ATTEMPTED SET DV @ SAME. IN PROGRESS. 5/19/2014 ATTEMPTED CHECK SET DV @ 12492' RKB, NO SUCCESS. PULLED CATCHER ON CAT SV @ 12612' RKB, NO VALVE. ATTEMPTED RE-SET CATCHER, LEFT IN GLM @ 12492' RKB. IN PROGRESS. 5/20/2014 PULLED CATCHER @ 12512' SLM. RAN 3.80" LIB ON DE-CENTRALIZER TO GLM @ 12492' RKB; INCONCLUSIVE. SET CATCHER ON CAT SV @ 12612' RKB. CHECK SET DV @ 12492' RKB. MIT- IA 2000 PSI: PASS. IN PROGRESS. 5/21/2014 PULLED DV @ 12492' RKB, LEFT OPEN POCKET. PULLED CATCHER AND CAT SV @ 12612' RKB. READY FOR CTU. 6/19/2014 GAUGED TBG TO 2.80"w/ 1.875"x 35'TO 12,620' SLM. READY FOR GYRO. 6/28/2014 RIH TO LOCATE DB-6 NIPPLE AT 12,584' CTMD, PAINT FLAG FOR DEPTH CORRELATION, F/P TBG WHILE POOH, JOB IN PROGRESS. 6/29/2014 RIH TO FLAG, CORRECT DEPTH TO 12,618.73', SET CEMENT RETAINER AT 13,330' RKB, PUMP 54 BBLS OF 15.8 PPG CLASS G CEMENT AS FOLLOWS: 25 BBLS THROUGH THE RETAINER, LAY IN 13 BBLS UP 4 1/2"TBG, PUSH 10 BBLS INTO THE IA, LAY IN REMAINING 6 BBLS UP THE 4 1/2"TBG, CONTAMINATE TO TOC @ 12092' RKB, CHASE CONTAMINATE OOH WITH SLICK DIESEL WHILE MAINTAINING 1:1 RETURNS, ALLOW 24 HRS TO CURE BEFORE DSL GETS A TAG/CBL AND P/T, JOB IN PROGRESS. 7/7/2014 LOG GYRO SURVEY FROM SURFACE TO 3106'AND BACK TO SURFACE. UNABLE TO WORK GYRO STRING BEYOND 3196'. READY FOR PRESSURE/TEMPERATURE SURVEY. 7/17/2014 MAKE MULTIPLE ATTEMPTS TO GET DOWN TO TOC. HAD TO BEAT TOOL FROM 6200'- 6700'. UNABLE TO GET DEEPER. RECOVER CEMENT IN 2.25" PUMP BAILER @ 6700' SLM JOB IN PROGRESS. 7/17/2014 MITT AND MIT IA PASSED. T/IA DDT PASSED. 7/20/2014 SLB CTU #5: CLEAR CEMENT STRINGERS IN TUBING FROM FROM 10221'TO 11860' CTMD WITH BAKER 3.80"TURBO MILL. WELL LEFT SHUT IN AND FREEZE PROTECTED. READY FOR DSL. 7/21/2014 ATTEMPT TO DRIFT DOWN TO TOC, UNABLE TO MAKE DEPTH, DOWN ON WIND JOB IN PROGRESS. 7/22/2014 LOG BASELINE TEMP SURVEY DOWN TO 9880' RKB, LOG GRADIENT STOP @ 9880' RKB = 1756#/100degf, LOG GRADIENT @ 900' RKB = 357#/34degf, LOG GRADIENT STOP @ 700' RKB = 286#/34degf, LOG GRADIENT STOP @ 350' RKB = 159#/38degf, LOG GRADIENT STOP @ 100' RKB = 68#/32degf, RECOVER BAILER FULL OF CEMENT FROM 9935' SLM....JOB SUSPENDED. 8/1/2014 STATE WAIVED TAG & MITT/IA. TAG TOC 11,869' RKB. MITIA PASSFD TO 2000 PSI. MITT PASSED ON THIRD TRl 2000 PSI. CUT TBG AT 11,367.6' RKB. AIN FOR CUT. GOOD COMMUNICATION DOWN TUBING UP IA, BUT IA PRESSURES UP bvHEN PUMPING DOWN IA UP TBG. PUMPED 317 BBLS 10.8#CI BRINE (KWF)AND FP'D TO 2000' IN TBG AND IA. *READY FOR DSL* 8/6/2014 CUT TUBING @ 4144' RKB. JOB COMPLETE 9/16/2014 Move the rig from 2N-303A to 2N-350A. Secure 2N-303A and pick up any debris around the cellar. Lay mats and herculite for the sub. Spot rig and RU over well 2N-350A. Take on 8.6 ppg seawater into the mud pits. ***RIG ACCEPTED © 15:00 HOURS 9/16/14*** Help get hardline RU to the tiger tank. Start loading the pipe shed with 5" DP (303 joints). OA= 200 psi & IA= 175 psi. PT lines to 2500 psi. Bad valve off the tiger tank, shut-in both main choke valves, Good test. Pump down the IA and test the tubing, casing, and BPV to 2000 psi for 10 minutes (charted, good test). Pull 'H' BPV as per FMC rep. RU on top of the tree to kill the well taking returns to the tiger tank. Bring on 290 bbls of 9.6 ppg LSND mud to the pits. Build 50 bbl Hi-Vis spacer. Pump 50 bbl Hi-Vis spacer and chase with hot H2O circulating @ 5 BPM = 600 psi on the pump, 350 psi on the IA returns. 9/16/2014 9/17/2014 Set two-way check and pressure up on the IA to 1500 psi to test the two-way check from below. Test for 10 minutes, good test(charted). Bleed off pressure to 0 psi. ND the tree and adaptor flange and remove from cellar. Set blanking plug pre FMC rep. NU BOPE. Test BOPE 250 psi low and 3500 psi high. Witness of BOPE test waived by AOGCC Jeff Jones on 9/15/14 @ 11:44 hours. IBOP failed, rebuilt, and re-tested (good test). PU landing joint to pull blanking plug. Suck out the stack and found two large balls of mud laying on top of the blanking plug. Flush out the stack to remove the mud off the top of the blanking plug. 9/18/2014 Wash mud debris off blanking plug. PU 4-1/2"test joint and pull blanking plug. MU FMC bumper sub and pull two-way check with annular closed. Well static. Pull the tubing hanger to the rig floor. POOH laying down 4-1/2"tubing. Laid down a total of 132 joint + 11' cut off joint. OA pressure = 250 psi, open up and bleed off pressure to the tiger tank. RD de-completion equipment. Install short wear ring and RILDS. . PU Dutch riser and install. RILDS on riser and close the bag. PJSM with E-line crew. RU E-line. MU and RIH with 7"gauge ring (OD = 6.151"). Gauge ring hung up and would not go pass 2750'. POOH with gauge ring and prep Welltec tractor. PU Welltec tractor with 7" gauge ring (OD = 6.151"). Test tractor on the rig floor. RIH with gauge ring and tractor to 2700'. Tractor from 2700'to 4138'. POOH with gauge ring and tractor assembly. Lay down gauge ring assembly. PU and MU Baker setting tool and Baker K-1 bridge plug. 9/18/2014 ***NABORS 9ES RIG JOB*** PERFORMED JUNK BASKET RUN.PLUG SET AND CASING CUT WITH ASSISTANCE FROM WELTEC TRACTOR AND WELLTEC MECHANICAL CUTTING TOOLS. RAN JUNK BASKET FROM SURFACE TO 4100' WITH 6.00" GAUGE RIGN. CORRELATED TO CASING COLLARS AND SET PLUG WITH MIDELEMNT AT 3915'. PERFORED CASING CUT WITH WELLTEC MECHANIC CUTTER AND CUT CASING @ 3886' 9/19/2014 RIH and set Baker K-1 bridge plug at 3915'. Pressure test bridge plug to 2500 psi for 10 minutes, good test(charted). Attempt to cut the 7" casing with the Welltec cutter, no indication on surface of a cut. Spear 7" casing and attempt to pull; no luck. Unable to get 7" casing mandrel to re-land. Pull 7" packoff. Change out top drive saver sub to 4" HT-40. Test with 4"test joint test to 250 psi low/3500 psi high. Single in the hole with Baker Multi-String Cutter(MSC) on 4" DP to 2136'. 9/20/2014 RIH with 4" DP and tag top of bridge plug at 3908'. PU 7' and cut 7" casing at 3901' per Baker rep. Make second 7" casing cut at 3625' per Baker rep. TOOH standing back 4" DP. Change out upper rams from 3-1/2"x 6"VBR's to 4-1/2"x 7"VBR's. Test with 5" and 7"test joint test to 250 psi low/ 3500 psi high. Spear 7" casing and pull casing hanger to the rig floor. POOH and lay down 7 joints of 7" casing. Monitor the well, well out of balance. RU and start circulating 9.6 ppg LSND mud. 9/21/2014 Pull out of hole laying down 7" casing, pulled 84 joints, 1 cut joint and 4 centralizers. Change out 4- 1/2" HT-40 Saver sub to 5" NC-50; test to 250 psi low, 3500 psi high. PU 7" casing spear BHA and RIH on 5" DP to top of fish at 3625'. No-go out on top of fish, fire the jars, and fish is free. Circulate and condition the mud. Shut down and monitored the well. Well static. TOOH standing back 5" DP. 9/22/2014 Lay down (9)6-1/4" DC, 5 inints of 7", and (1) 7" cut joint(total of 3 centralizers). Single in the hole with the 3-1/2" cement sti RIH with 5" DP from the pipe shed to 1 f bridge plug at 3915'. Circulate and condition the mud per MI. Pressure test lines and pump balance cement plug. TOOH 4 stands of 5" DP circulate the well to 9.6 ppg LSND mud. Trouble shooting top drive issue, suspect is the lube pump. 9/22/2014 STANDBY FOR CALIPER SURVEY ON 9ES 9/23/2014 ***9ES RIG JOB*** CORRELATE TO DRILL FLOOR AND PERFORM CALIPER SURVEY FROM 1500'TO SURFACE. 9/23/2014 POOH LD 3 1/2" cement string, RU "E" line and run Caliper log to 1500', RU and test BOP's 250 psi low, 3500 psi high. 9/24/2014 Finish testing BOP's, single 21 joints of 5" DP in the hole, stand back 7 stands of DP in the derrick. PU 8 1/2" Intermediate hole#1 BHA, single in the hole with 5"DP, tag cement at 3247', wash and ream to 3388' and perform casing test. Attempted casing test, pressure leaked off at 280 psi, shut-in pressure bled off to 140 psi in 1 minute. 2nd test pressure leaked off at 240 psi, shut-in pressure bled off to 140 psi. Wash and ream T/3550', circulate until mud is clean and attempt 3rd test. 9/25/2014 Perform 3rd casing test, leak off at 225 psi. POOH and PU Retrievamatic Packer. TIH with Packer and test the TAMPORT Collar. Attempted test to 2500 psi, leaked off at 225 psi. Pumped down the DP and tested the casing and cement plug to 2500 psi. Pull up to 1,026' and test casing above the TAMPORT Collar to 2500 psi. POOH and PU a COMBO tool to close the TAMPORT Collar. 9/26/2014 POOH - LD BAker packer- MU Combo tool - RIH & engage TAM PC @ 1025' - Pulled 15 k over the close PC - Pressure test to 1000 psi (OK)- release toolf/ PC - PU above PC &test to 2000 psi (OK 0 Retest to 2200 psi - POOH & LD combo tool - Service TD - MU BHA#2 ( Same as BHA# 1) RIH to 3550' - Drilled cmt f/3550'to 3764' 9/27/2014 Cont. drilling cmt f/3764' to 3820' - Sidetracked off plug @ 3820' - Driled 20' new hole to 3840'-Circ hole clean - Pull back to 3700' - Chnage over to new 9.6 ppg LSND mud - Performed FIT to 15.9 ppg EMW- RIH to 3840'- Drilled 8 1/2" hole w/ motor f/3940'to 4041'-Trouble shoot TD - Pulled back to 3670'-Work on TD G+:,t•,,.,:.., � :t��,yc,.ds-.... _. Ais;':"'�u'. , . n-s.,7_,.1.,s ^.. r •-,.; Lanzo - Y. ,,.c: e=lr:3L.`......F ,rca..w.aa..._;m..��f,1;c.1+ _4:iv .;lwOWe. 1,:'-::-.:Wj_ :. 7--- B ":! - , (2:.A ' RN OR C! ,A" �� ' L' I. Anchor°ct / 'OSKC. 995( 3572 . fes t,u : - - M�� 7 , -4.. y JUL 16 sc Tyson Wiese 02 d � -- � 7.s---Sr. Wells EngineerConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-350 Sundry Number: 314-306 Dear Mr. Wiese: 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, k i ''- ie-v))4--- Cathy P. oerster Chair DATED this 22 day of May, 2014. Encl. STATE OF ALASKA RECEIVED AL .A OIL AND GAS CONSERVATION COMM, ,ON • APPLICATION FOR SUNDRY APPROVALS '' MAY 0 9 2014 20 AAC 25.280 IJ 'S I 1.Type of Request: Abandon r ` Rug for Redrill r� Perforate New Pool r Repair well r Chan9e�°�P ram r Suspend '' Rug Perforations P'• Perforate r Pull Tubing E Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r• 201-175 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20389-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P' KI'1,kx.2N-350 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 375075 . Kuparuk River Field/Tarn 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): 13929• 5018 ' 13654' 4945' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 103 16 134' 134' SURFACE 3706 9.625 3736' 2285' PRODUCTION 12787 10 12818' 4725' LINER 1322 4.5 13929' 5018' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): `13610'-13620' • 4934'-4936' 4.5 L-80 12567 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER S-3 HYDRO SET PACKER ' MD=12592 TVD=4662 PACKER-ZXP LINER TOP PACKER ' MD=12614 TVD=4668 NIPPLE-CAMCO LANDING DB-6 NIPPLE . MD=433 TVD=432 12.Attachments: Description Sunmary of Proposal • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/27/2014 Oil r Gas r WDSPL r Suspended P'• 16.Verbal Approval: Date: VVINJ r GINJ r WAG E Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson.M.Wiese[J_conocoohillips.com Printed Name Tyson Wiesex,\' Title: Sr. Wells Engineer (� u Signature 1 Phone:263-4250 Date SPb/r_ -019 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\�306 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: a op t G i t• f-O 3 5 o d es i Spacing Exception Required? Yes ❑ No [►f Subsequent Form Required: /72 _- ¢0 -2, APPROVED BY z- Approved by: -�i�^' — COMMIS$$10 ER THE COMMISSION Date: �7 -�-(� pproved apORril>�91ld i 7�ri�onthfrom tti a a of approval. Form 10-403(Revised 10/2012) u II VV ''vv HH LL w3 Submit Form and Attachments n upjitat;Q 2 3 2fy vL�•s72///4, . .� y RBCP MAT 2N-350 Plug for Redrill Permit to Drill #: 201-175 2N-350 was drilled in 2001, and originally completed as a Pre-Produced Injection Well. At the time it was decided to leave the well in service as a producer. In 2007 a RWO was performed to swap out the tubing string and install an adequate gas lift completion design. The well was shut in August 2008 due to high water cut of approx. 99.5%. The objective of the 2N-350 RST is to improve Bermuda oil recovery and pattern sweep efficiency, as part of the Tarn EOR project. 2N- 350A will provide offtake between wells 2N-335 and 2N-343, which are both MWAG injectors. coAcvr'. 7 '` ,, at 11�if &.- e' ovr- god fokset ll ctry•e4lier 775 re r ' P4 t'T i Pitoavice-ion 4.e 4/400 cb/l T/AC46* M'S we i/ Procedure Summary: filo"( pr Akee , -, Ty'S D 004 Slick Line/ LRS: (Well Prep) ��„/ 1. DMY off GLD, Pull OV and leave GLM #4 open @ 12,493' KB. Load well with diesel. 2. Set nipple plug, Perform C-MIT to 2,000 psi, Pull Plug. 3. Brush and Flush / DMY drift for cement retainer tool string. 4. Perform Injectivity Test with diesel to ensure perfs take adequate rate for cementing. Coil Tubing: (Cement Squeeze and Isolation Cement Plug) 1. Ensure the 10-403 Sundry has been approved by the AOGCC. 2. RIH and set cement retainer @ approx. 13,320' KB. 3. Using diesel, confirm injection through the cement retainer and into the perfs. 4. Pump 25 bbls of 15.8#cement through the retainer, squeezing 20 bbls into the Bermuda perfs and leaving 5 bbls in the liner below the retainer. 5. Unsting from retainer. Lay in 13 bbls of cement up to the open GLM @ 12,493' KB. 6. Open the IA, Close TxCT, and displace 10 bbls of cement into the IA. 7. Close the IA, Open TxCT, and lay in the remaining 6 bbls of cement up to the planned TOC of 12,092' (500' plug above production packer). 8. POOH contaminating and circulating any excess cement to surface. RDMO. Digital Slick Line/ LRS: (Tag/Test plug/CBL/Tubing Punch/Tubing Cut) 1. WOC at least 24 hours prior to tag and test. 2. Notify the AOGCC (AOGCC.Inspectors@alaska.gov) of the timing of the cement plug tag and PT. Provide at least 24 hour notice. 3. Tag TOC @ 12,092' KB. Perform MIT-T and MIT-IA to 2,000 psi. Record Results. 4. Perform memory CBL from tubing tag to at least 500' above TOC in IA, if any is found. 5. Punch tubing holes approx. 100' above TOC in IA (mid joint). 6. Circ. 338 bbls of 10.8 ppg Corr. Inh. KWF and 68 bbls diesel F.P. U-Tube at surface. 7. Perform Tubing Cut mid joint @ 4,144' KB (approx. 300' below KOP) with jet cutter. 8. Set BPV. Well is ready for RST. RDMO. TW Current Well Schematic: t KUP 2N-350 ConocoPhillips 0.3 Well Attributes Max An la&MD TD N.i�..i I,n \Velar...APTUWI Feld Name Well Status Incl(') ttIL IftKHI Act Mtn(hKB) cre,6sy 501032038900 TARN PARTICIPATING AREA PROD 76.91 13,479 30 13.929.0 -. Comment Li-2S(ppm) Owe Annotation End Date KB-Grd Ill) Rig Release Date wase Conl'.c.-sN350 6�1Gr20131^.A'.S4 c1.1 SSSV:NIPPLE 65 1/13/2009 Last WO: 9/30/2007 35.00 10:222001 !<rvm3n.0.Anum nAnnotation Depth 18881 nil Date annotation Last Mod...End Dat Last Tag.SLM 13,602.0 5+31+2013 Rev Ronson:WELL REVIEW,TAG oaborl 6/10/2013 Casing Strings lasing Description String u.,, String ID...Top(ft et epi ...Set Depth(IVO)... String Wt.,,Suing... String Top Thrd -.. -- CONDUCTOR 16 15.062 31.0 13..0 134.0 62.50 H-40 WELDED ring Thrd SURFACE 9 5'8 8.697 30 a3 736 0f...Set Depth 5.3 ... Saint,40.00__.St L-8... String toots PRODUCTION 7 6.276 31.5 12.818.1 4.725.1 2600 L 80 BTC Casing Description tong ... String -.Top ) Set Depth it.. Set pt )... String 2 ming Description String U.,. String lU,,.Top(RString•- String Top 3 hrd HANGER 29 -_ LBTC-MOD C'ssmq Description Siting 0... Stung ID...Top IRKS) Set Depth(f... Set Depth(IVO)... Swing WL..Stung... String Top Thrd LINER 41/2 3.958 12.607.1 13-929.0 5,018.1 12.60 1-80 NSCT II Liner Details Op pm Al (TVD) _Top1,011 Non). Top 1.6501:719. IhKB) 1°I Comment ID On) TOR 12.607.1 4,665.7 7405 LINER TIEBACK SLEEVE 5250 31-134 12,614 4 4,667.7 74.04 - ZXP LINER TOP PACKER 5.000 NIPPLE 433i. 12.621.1 4,669.6 73.90 HANGER BAKER FLEX LOCK LINER h1ANGER w/RS NIPPLE 5.000 12.633.8 4,673.1 73 86 XO Reducing CROSSOVER 5.5'x4.5' 4.500 SURFACE TubingQ Strings x-3136 Tubing C)escnptlon String 0,,, Strin9 IO_. op(RKB) Depth if,..Set Depth ITVD)-188117.6"t0 ., 8818 WL.-Sting•.- String Top Thrd TUBING I 41/2 I 3.950 I' 29,3 'SI 2,566.6 I 4,654.6 I 12.60 I L-80 I IBT Com letion Details - GAS`FT p apth ,510 oITVD) Top Incl Npnl... 11y■ IttKBI 1't Comment ID hnl ' - 29.2 0.48 FMC TUBING HANGER 4.500 GAS UFT_ CAMCOLANDINGDB-6NIPPLEr" 1 .5400_432.5_5l8pl 17.34- NI L CAMEO LANDING DB-6 NIPPLE 3813 12.5473649.3409 LOCATOR BAKER NOGO LOCATOR 3870 10594 12.517.6649.44.09 SEAL ASSY BAKER 192.47 LOCATOR SEAL ASSEMBLY-STABS INTO ORIGINAL 3.870 [ PBR&12559' G.LIFT Tubing Descrtpbon --Stnng ... StinID op MKS) 581 Depth I1..,5Depth(TVDL ).,.'String W.. n Strg,., Strg Top Thrd 12.493 =G TUBING Original 5.525 'Stung ...4.000 12.559 4 I 12.630.6 ISM 4.672.2 v - - (3. TBG OD) J fn . -._- • Completion Details raPSLE,12.540 _- Top Depth (TVD) Top Incl Monti.. Top(1180) IRKS) l') Item Desctiption Comment 10 On) 12,559 4 4,652.6 74 08 PBR BAKER 80-47 POLISHED BORE RECEPTACLE 4.000 LOCATOR 12,692.1 4.661.6 74.06 PACKER BAKER S-3 HYDRO SET PACKER 3.875 2.147 12,611.8 4,667.0 74 04 NIPPLE CAMCO DB-6 NIPPLE 3.750 SEAL ASSY, /2,644 __ 12,629.2 4,671.9 7388 WLEG WIRELINE ENTRY GUIDE 3.956 PER 12.551---- ` Perforations&Slots shot Tor(TVD) atm(TVot Dena Top(1180)Ellin 11)88) 111801 (hKB) Zone Date Ia8.. Type Comment . �. 13.610.0 13.620-0 4,93.4.0 4,936.4 S-3,2N-350 11/30/2001 6.0!PEW' 2 7/8"HSD,60 deg BH nA 2,59FR 2 Stimulations&Treatments Bottom Min Top Man Bun Top Depth Depth Depth Depth ITVU) ITVOI 1 IRKS) IttKBI LIKE) (EKE) Type Date Comment CPc.E 12 512 M; 13.610.0 13,620.0 4,934.0 4,936.4 FRAC 12/2/2001 BERMUDA FRAC.236,000816/20612"18 CARBOLITE.10 PPA ON PERFS 1 '1 Notes:General S.Safety 4. . End Date Annotation 1/13/2011 NOTE:View Schematic w/Alaska Schemahc9.0 _b - N • • OROIXlCTG . ' 31_u,e A Mandrel Details Top Depth Top Port S. (TVD) Inc' 00 Valve Latch Sign TRO Run (PERF N...Top ItIKBI 0088) (`) Make Model (in) Sere Type Type 11111 (psi) Run0410 Com.., O13 10!13..120\20El 1 4.510.2 2482.0 75,36 CAMCO KBG-2-1R 1 Gas LM GLV 00-5 0.125 1,642.0 3142008 le,13!10 uwan 2 8.229.7 3489.6 72.83 CAMCO KBG-2-1R 1 Gas Lia GLV BK-5 0.156 1.729.0 3:4/2008 3 10.593.7 4,112,8 75,42 CAMCO KBG-2-1R 1 Gas Lift DMV BK-5 0.000 0.0 9/30.2007 4 124LA 92.7 4.634.4 74.12 CAMCO KBG-2-1R ' 1 Gas LOV 'BKS 0.313 0.0 228/2008 _ 12,601-13.925 l TO . .J TD.13829 ---- TW • Proposed Schematic: TW 5-8-2014 2N-350 Plug Back for RST PTD #: 201-175 Planned Plug Back 16"62.50#H-40 Conductor @ 134'KB ^ I® 3.875"DB-6 Nipple @ 433'KB 0 0 10.8#KWF to 2,000'KB with Diesel F.P to surface 9 5l8"40#1-80 Surface Casing l 3,736'KB A Summary: Tubing Cut @approx.4,144'KB(=300'below planned KOP) T GLM's ISlickiine: DMY @ 4,510'KB 1.)DMY off the GLD.Leave GLM#4 open. DMY(N 8,230'KB DMY I)10,594'KB I 2.)Set plug in nipple g 12.612'. OPEN @ 12,493'KB 3.)Load T and IA with 432 bbls Diesel. 4.)C-MIT to 2,000 psi.Pull plug from nipple. Est Original 7"Prod Casing TOC nn 5.)DMY drift for cement retainer and B&F planned 8,208'KB(104 bbls cement pumped) 1111 set depth. 6.)Perform injection test with diesel to ensure Planned Plugback TOC g approx.12,092'KB )f'j2 rates for cementing. (500'plug above top packer) /!`� - ✓ CTU: 1.)RIH and set retainer @ approx.13.320'. 2.)Pump 25 bbls of 15.8#Class G cement 3.813"Camco DB-6 Nipple«v 12,540'KB ✓' % through the retainer,squeezing 20 bbls into ✓// / the perforations. 3.)Lay in remaining 29 bbls of 15.8#cement /%/4 in Tubing and IA to a planned TOC of 12,092' KB(500'above the top packer). Baker S-3 Hydro Set Packer 8 12,592'KB I/7 Digital Slickline: 1.)WOC 24 hours. Notify AOGCC 24 hrs in 375"Camco DB-6 Nipple @ 12.612'KB advance for witness. 2.)Tag TOC c@ approx.12,092'KB.' 3.)MIT-T and MIT-IA to 2.000 psi. ' J 4.)Run CBL Log to locate TOC in IA(if any) 5.)Punch holes In Tubing mid-joint above TOC. ZXP Liner Top Packer @ 12,614'KB r_ ;,;; 6. Circ.338 bbls of Corr.inh.10.8#KWF and 68 4, bbls of Diesel F.P. U-Tube at Surface. 7.)RIH with Jet Cutter and cut 4 l,"Tubing g 7"260 L-80 Prod L in approx.4.144'KB(mid joint.approx 300'below os gto12,818'KB planned RST KOP). RDMO. Cement Retainer @ approx.13,320'KB PeInterval. 13,610'KB—13,66 20'KB(Tarn S-3 Zone) Latest SBHP=2.699 psi Ca)4,932'ND(EMW=10.6#) - 4''1"Liner from 12,607'KB—13,929'KB Fill Tag @ 13,603'KB TW • • • Nabors 9ES 2N-350 Suspend Procedure 1. MIRU Nabors 9ES onto 2N-350. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi, pull CIW"H" BPV. 4. Circulate diesel freeze protect out through the tubing cut at-4,200' MD w/ hot SWI swapping over to 9.6 ppg kill weight mud through tree, taking returns to tiger tank. 5. Set BPV and test through inner annulus to 2,000 psi. 6. Set blanking plug & ND tree. 7. Notify AOGCC field inspector 24 hours prior to BOPE test. 8. Nipple up BOPE and test to 250/3500 psi. 9. Remove blanking plug and BPV. 10. Pull & lay down 4-1/2" tubing (pre-cut at-4,200 MD). 11. Run 7" casing scraper to -4,150' MD 12. Run 7" Baker CIBP on 4" DP and set at-4,100' MD. PT to 2,500 psi 13. Pressure test lower rams with 3.5" (cement stinger) and 4" (drillpipe)test joints. 14. Run in hole with mechanical casing cutter on 4"drillpipe and cut casing at 3,950' &3,580' MD. 15. Flush 7"x 9-5/8" annulus with 9.6 ppg mud taking returns to tiger tank. 16. Swap 3.5"x 6" rams to 7" casing rams and pressure test to 250/3500 psi. 17. Pull 7" casing to surface and lay down. RIH with jars and retrieve casing stub at bottom. 18. Swap 7"casing rams to 3.5"x 6" rams and pressure test. 19. RIH with 3.5"cement stinger and set cement kick off plug from the top of bridge plug to 200' inside the surface shoe. Cement open hole and into existing 9518" surface casing from +1-4,100' MD to 3,536' MD (564' of fill) with Class G + Adds @ 17.0 ppg. Assume 100% excess in the open hole and 0% excess inside surface casing. Plug: (4,100' -3,736') x 0.3941 ft31ft x 2.00(100% excess)=287 ft3 in open hole (3,736' -3,536') x 0.4257 ft3/ft x 1.00(0% excess)= 85.2 ft3 inside surface csg Total volume=287 ft3+85.2 ft3=372.2 =>369 Sx @ 1.010 ft3/sk Vvvr, System: 369 Sx Class G @ 17.0 PPG 20. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and KO plug toji\ 2,300 psi. 29 Dress off cement kickoff plug and control drill to below surface casing shoe 22. Drill out 20' of new formation and perform FIT/LOT. 23. Ready to move into drilling phase under new PTD. 24. Begin new PTD. Begin two-week BOPE testing cycle. TW eLAi TO . RECt:I'!5,U STATE OF ALASKA. OCT 2+¡' 2.007 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 & G Cons. commission REPORT OF SUNDRY WELL OPERA Tldtt!a 01 8S Anr.horaoe 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 , Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0- Exploratory 0 201~1751 ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20389-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 29', 154' AMSV 2N-350 . 8. Property Designation: 10. Field/Pool(s): ADL 375075, 'ALK 4306 Kuparuk River Field 1 Tarn Oil Pool , 11. Present Well Condition Summary: Total Depth measured 13929' /' feet true vertical 5018' , feet Plugs (measured) Effective Depth measured 13654' feet Junk (measured) true vertical 4945' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 105' 16" 134' 134' SURFACE 3707' 9-5/8" 3736' 2285' PRODUCTION 12789' 7" 12818' 4725' LINER 1322' 4-1/2" 13929' 5018' Perforation depth: Measured depth: 13610'-13620' true vertical depth: 4934'-4936' SCANNED OCT :1 1 2007 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 12565' MD. Packers & SSSV (type & measured depth) pkr= BAKER S-3 HYDRO SET pkr= 12592' Cameo landing DB-6 nipple @ 434' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable fRBDMS SF ." T .. ...-. h . L 0 C! 3 {} 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 501 2132 2071 -- 273 Subsequent to operation 694 ' 8848 2907 -- 316 14. Attachments 15. Well Class after work: Exploratory 0 0 . 0 Copies of Logs and Surveys run _ Development Service Daily Report of Well Operations _X 16. Well Status after work: Oil0 " GasD WAG 0 GINJD WINJD WDSPL 0 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: none Contact Howard Gober @ 263-4220 Printed Name HowarE Title Wells Engineer ~:~re! p(Z;;o~{~l:e 263-4612 Signature ~..f.....¿ Phone L I ~ /.41 ....... , Form 10-404 Revised 04/2006 OR\G\NAL 1J'\~f~ /t~o/ ./S b ,.~. ....b~07 sû'b~it Original Only . 2N-350 Well Events Summary . DATE Summary 8/26/07 MULTI-FINGER CALIPER TOOL - LOGGED FROM 100' - 12400' AT 0.5 INCH RESOLUTION AND A REPEAT SECTION FROM 8900' - 9400' AT 0.1 INCH RESOLUTION, TUBING IS IN GOOD SHAPE, THE SECTION FROM 9000' - 9300' HAS SOME CORROSION - THE DATA NEEDS TO BE PROCESSED FOR MORE DETAIL, TAGGED AT 12486'. WELL LEFT SHUT- IN. 9/1/07 TAGGED @ 12474' WLM W/1.80 LIB; IMPRESSION OF GLV LATCH. IN PROGRESS 9/2/07 PULLED OV @ 12512' RKB, IN PROGRESS 9/2/07 (PRE RWO) TPOT - PASSED, TPPPOT - PASSED, ICPOT/PPPOT- PASSED. FUNCTION TESTEDITORQUED T & IC LDS. INITIAL TII/O= 950/460/230. STUNG INTO T PO TP WITH 0+ PSI. PRESSURED UP THE T PO TP TO 4700 PSI WITH HYD FLUID, PRESSURE BLED QUITE RAPIDLY. TORQUED T LDS TO 450 FT LBS. PRESSURED UP T P 0 TP TO 4700 PSI, 15 MIN READING: 4400 PSI, 30 MIN. 4325 PSI, FOR A LOSS OF 275 IN 30 MIN. STUNG INTO IC PO TP WITH 200 PSI, BLED TO ZERO WITH NO BUILD-UP IN 15 MINUTES. PRESSURED UP THE IC PO TP TO 3000 PSI WITH HYD FLUID. 15 MIN READING: 2825 PSI, 30 MIN 2825, FOR A TOTAL LOSS OF 175 IN 30 MIN. FUNCTION TESTED AND TORQUED THE IC LDS. FINAL T/I/O= 950/460/230. 9/5/07 BLEED MI OFF IA DOWN FLOWLlNE,DISPLACE IA WITH 250 BBL'S 1% CRW-132.SET DV IN CGLM IN CMU,VERIFY DV SET WITH CHECK-SET. ATTEMPT MITIA- FAILED.PULLED 1" DV FROM CGLM. Note: IA LEFT LOADED W/INH. SW & 95 BBL DIESEL CAP. 9/25/07 Move rig from 2N-31 0 to 2N-350. Spot rig over well. Accept rig at 1000 on 9/25/07. Rig up circ. lines. Fill mud tanks w/ seawater. Circulate seawater to kill well. 9/26/07 Finish killing well with seawater. Nipple down tree & nipple up BOPE. Test BOPE to 250/2500 psi. Test good. Pull BPV. Pull Hanger to floor. Circulate bottoms up. Losses are 2 bpm while circulating and 1 bpm while keeping the hole full on the trip tank 9/27/07 Lay down 4.5" Tbg. Recovered all tubing and jewelry. Concentric GLM was stuck inside the sliding sleeve. Load new 4.5" Tbg in pipe shed. Drift and tally as it is loaded. 9/28/07 Finish loading-drifting & tallying 4.5" Tbg. Begin running 4.5" gas lift completion in the hole. 9/29/07 Finish running completion. Load annulus with corrosion inhibited seawater. Land tbg. Shear SOV. Set 2 way check. Nipple down bope & nipple up tree. Test tree to 5000 psi. Pull 2 way check. Prepare to freeze protect. 9/30/07 Freeze protect well by pumping 160 bbls down the tubing. Equalize tubing and IA to U tube diesel. Set BPV. Release rig at 0800 on 9/30/07. 10/8/07 TAGGED @ 13,575' SLM, SET CATCHER SUB @ 12,611' RKB, IN PROGRESS. 10/9/07 PULLED SOV @ 4510' RKB, REPLACED WITH DV. MITIA 2500 PSI, GOOD. PULLED DV @ 12493' RKB, PUMP 150 BBL DSL DOWN IA. ATTEMPTED SET OV @ 12493' RKB, WOBBLE RING COCKED. IN PROGRESS. 10/10/07 SET OV @ 12493' RKB, PULLED CATCHER @ 12611' RKB. COMPLETE. . . KRU 2N-350 ConocoPhillipsA.laska, Inc. API: 501002038900 Well Tvoe: PROD Anale (cì) TS: dea (âJ TUBING SSSV Type: NIPPLE Orig 10/212001 Angle @ TD: 74 deg @ 13929 (0-12565, Comoletion: OD:4.500, ID:3.958) Annular Fluid: Last w/o: 9/30/2007 Rev Reason: WORKOVER Reference Loa: 29.25' RKB Ref Loa Date: Last Uodate: 10/12/2007 Last Taa: 13654 TD: 13929 ftKB Last T ii.¡r 2/26/2003 Max HOle-'13479 DescriDtion Size Ton Bottom TVD WI Grade Thread , RODUCTlON CONDUCTOR 16.000 0 134 134 62.50 H-40 WELDED (0-12818, SURFACE 9.625 0 3736 2285 40.00 L-80 BTCM OD:7.000, PRODUCTION 7.000 0 12818 4725 26.00 L-80 BTCM Wt:26.00) LINER 4.500 12607 13929 1392!r 12.60 L-80 NSCT IfIIE'i1 I Size I TaD I Bottom TVD WI Grade T Thread I Gas Lift 1 4.500 I 0 1 12565 1 4654. 12.60 ì L-BO ¡ IBT 1 MandrelNalve 2 (8230-8231, I Interval I TVD I Zone I Status I Ft Date Tvne I Comment 113610 - 13620 1 4934 - 4936 1 1 1 10 I 6 111/30/20011IPERFT2 7/8'1i60dea BH 1 ,"w..¡:'i I Interval I Date I TVDe I Comment 13610 - 13620 12/2/2001 FRAC BERMUDA FRAC, 236,000# 16/20 & 12/18 CARBOLlTE, 10 PPA ON PERFS St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Part TRO Date Run VIv Cmnt 1 4510 2482 CAMCO KBG-2-1 R DMY 1.0 BK-5 0.000 0 10/9/2007 2 8230 3491 CAMCO KBG-2-1 R DMY 1.0 BK-5 0.000 0 9/30/2007 3 10594 4113 CAMCO KBG-2-1 R DMY 1.0 BK-5 0.000 0 9/30/2007 4 12493 4634 CAMCO KBG-2-1 R OV 1.0 BK-5 0.313 0 1 0/1 0/200 Deoth TVD TVDe DescrTritlon 10 29 29 HANGER FMC TUBING HANGER 4.500 NIP 434 434 NIP CAMCO LANDING DB-6 NIPPLE 3.875 12540-12541, OD:5.250) 12540 4647 NIP CAMCO DB-6 NIPPLE 3.813 12547 4649 SEAL BAKER 192-47 LOCATOR/SEAL ASSEMBLY 3.870 12559 4653 PBR BAKER PBR 80-47 SEAL ASSY 10/2/2001 4.000 12565 4654 WLEG BAKER WIRELlNE GUIDE 3.870 12592 4662 PKR BAKER S-3 HYDRO SET PACKER 10/2/2001 3.875 SEAL 12611 4667 NIP CAMCO 'DB-6 NIPPLE 10/212001 3.750 12547-12548, ODA.750) 12629 4672 WLEG WIRELlNE GUIDE 10/2/2001 3.956 12630 4672 TTL 3.958 PBR i------ 12559-12560, OD:5.525) PKR 12592-12593, 00:5,968) LINER 12607-13929, ODA.500, Wt:12.60) WLEG 12629·12630, OD:5.000) Perf ~ ¿ '13610-13620) FRAC 13610-13620) ~ ~ --!- -\ ..01 . . Page 1 of2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 30, 2007 8:29 AM To: 'Gober, Howard' Cc: Eggemeyer, Jerome C.; Cawvey, Von Subject: RE: 2N-350 Workover Thanks Howard. ------- From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Tuesday, October 30,20078:25 AM To: Maunder, Thomas E (DOA) Cc: Eggemeyer, Jerome C.; Cawvey, Von Subject: RE: 2N-350 Workover Tom, I have answered your questions below. Please let me know if there is any other information you need. I will communicate to Nordic 3 and Nabors 3S that this is some of the information you are looking for on the daily summaries. I appreciate your help this past weekend. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 -263-4220 Office 907-240-5515 Cell Howard. Gober@conocophillips.com -- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, October 26,20073:32 PM To: Gober, Howard Cc: Eggemeyer, Jerome C. Subject: 2N-350 Workover I am reviewing the 404 report for the recent workover on this well and have a couple of questions. 1. What rig performed the work? It is not identified in the operations summary. Nordic 3 2. I presume no AOGCC witness was present. What Inspector waived the test? Chuck Scheve 3. Was a BPV set prior to ND the tree? Yes - 9/26/07 at 0400 4. Was the tubing cut or was a seal assembly pulled out of the packer? Seal assembly was pulled out of the PBR 5. Was a new packer run? Ran new seal assembly into the existing PBR along with a new 4-112" tubing string. 10/30/2007 . . Page 2 of2 6. Was the tubing and annulus pressure tested? To what values and what time interval? There was no plug in the well during the workover. We were pulling the tubing due to a stuck concentric gas lift mandrel. Therefore we had communication with the peñs at all times. At the end of the job we pumped into the peñs down the tubing with no returns on the IA. We pressure tested the IA to 1000 psi for 30 min. We then sheared the SOV at 1575 psi. Post rig MIT-IA to 2600 psi and lost 90 psi in 30 min. During some slickline work on 10/27/07, we set a plug in the nipple at 12540' RKB Oust above the seal assembly in the new tubing string). The tubing was tested to 2000 psi for 30 min. Thanks in advance. Tom Maunder, PE AOGCC 10/30/2007 4 2007 08/30/07 SC'._."I8JtO\\0;. NO. 4398 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /1\ ~ Field: Kuparuk Well Job# Date Color CD Log Description BL 2H-02 11846438 INJECTION PROFILE l )ï:l' ~4-ÛT-~ 08/21/07 1 2P-427 11846437 INJECTION PROFILE l j , (' ,!. :)()~ - N~ 08/20/07 1 1A-07 11850429 INJECTION PROFILE ) II' , 1;1-'~~ 08/22/07 1 10-08 11850427 SBHP SURVEY I~ -(').ç~ 08/20/07 1 3A-09 11850426 GLS 14:: 1-ICjq 08/20/07 1 2W-09 11850428 INJECTION PROFILE U:rc. /~- Q,q 08/21/07 1 1 L-17 11839642 INJECTION PROFILE UT't' /0, I-Ö4~ 08/23/07 1 2M-13 11839643 PRODUCTION PROFILE 08/24/07 1 1 G-04 11837494 INJECTION PROFILE () II' . 14r :1-/(/\/ 08/24/07 1 2N-350 11839644 DDL 9bl- I~.<; 08/25/07 1 2N-350 11839645 PMIT .::Jh I - ,":} (~ 08/26/07 1 1A-05 11839646 INJECTION PROFILE l)T ('. ,<Çr /-IÞI-I 08/27/07 1 2H-15 11837498 INJECTION PROFILE Üí"C- l~-""~~ 08/29/07 1 2A-04 11839649 INJECTION PROFILE I) -:rl' _ 11rfI- 6~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . eonocóPhillips Alaska RECEIVED SEP 1 2 Z007 Alukt 0" & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 sCANNED SEP 12 2007 ao'" 115 a~'" :;sO Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of we Us trom the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a con-osion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The con-osion inhibitor/sealant was pumped on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. SinG#_ ~. JLnd ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-327 207-069 12" nla 12" nla 3.5 9/8/2007 2N-329 198-067 24" nla 24" nla 6 9/8/2007 2N-331 198-117 26" nla 26" nla 2 9/8/2007 2N-332 200-079 8" nla 8" nla 2 9/8/2007 2N-333 206-025 29" nla 29" nla 8.5 9/8/2007 2N-349 200-139 3" nla 3" nla 1 9/8/2007 2N-350 201-175 11" nla 11" nla 4.5 9/8/2007 2P-438 201-082 4' 10" nla 4'10" nla 2 9/8/2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc J I 11-v. DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permitto Drill 2011750 Well Name/No. KUPARUK RIV U TARN 2N-350 Operator CONOCOPHILLlPS ALASKA INC A~ ~:?sO-~3-~~~ ( MD 13929 -- TVD 5018 /' Completion Date 11/30/2001'" Completion Status 1-01L Current Status 1-01L UIC N ---_._-~- - REQUIRED INFORMATION Mud Log No Samples No Directional Survey- ~'i ~ '--- ---- --. -- - DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: ~..~-----,{ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name 4Pf> D 10638 ¥D D 10642 i ~ C 11255 Name Interval Start Stop Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 1 3687 13872 Open 2/22/2002 3687 13872 Open 3/4/2002 134 13929 Case 10/30/2002 Digital Data: Rate of Penetration, Dual Gamma Ray, and Electromagnetic Wave Resistivity -------- - --- - Sample Set Sent Received Number Comments Well Cores/Samples Information: ADDITIONAL INFORMATION Y~ ~--"J'\ Well Cored? Daily History Received? Y/N Chi~e('.Pilf~d? Y .' ~~ Analysis Y / N Receiv~ Formation Tops ff)/N -------- -- Comments: \ I ------=- -~--= -----.- I - ----. ) ~ k ~ s { dD}-J 7 5 ] Id 55 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIn. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 October 30, 2002 RE: MWD Formation Evaluation Logs 2N-350, AK-MM-l1153 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., i\nchorage, AK 99518 2N-350: Digital Log Images 50-103 -203 89-00 1 CD Rom ~o~ I"~ [:.~ (: [}:: i~, Aì i;':; r";~ . ""-", ~~" b- 11 V ~= ß.",) Of" 'r .,,~ f"\ .~, '" ,., !'\ '\,,' ,) \) L',J;~'~: flJé1~lr3 U" Ii: (::r. ',- , . .~ ~~ f: ,"....~:' ~~~~,'~'~~;:lJ~fÛ'~n J ;,'~r: ;:~.~ .Jf~~~J]''';;' I' ( WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage,AJaska RE: MWD Formation Evaluation Logs 2N-350, February 26, 2002 AK-MM-11153 1 LDWG formatted Disc with verification listing. API#: 50-103-20389-00 dOJ-/7S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, AJaska 99518 D\'~ . \\)\~. \lJ~ Signed:0~,~ Date: RECEIVED r{AR 0 4 2002 Alaska OiJ & Gas Cons. Commission Anchorage .1 , WELL LOG TRANSMIITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, AJaska February 20, 2002 RE: MWD Formation Evaluation Logs 2N-350, AK-MM-11153 aò J-/7'S 1 LDWG formatted Disc with verification listing. API#: 50-103-20389-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Sign~ I~ Q~f2...J Date: RECEIVED FES 22 2002 Alaska Oil & Gas Cons. Comml8ion Anchorage (" (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone(907)265~4 Fax: (907) 265-6224 January 15, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7lh Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2N-350 (201-175) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Tarn well 2N-350. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, f :::!ð Drilling Engineering Supervisor P AI Drilling RECEIVED JAN 1 6 2002 Alaska Oil & Gas C ."' . Anchor~~~ ComrmSSìop CM/skad ORIGtNAL ( PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Putnam Phone (907) 265-6970 January 14, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Addendum to Completion Report for 2N-350 (201-175) Dear Commissioner: (' Well 2N-350 was originally permitted as an injection well. Analysis of data acquired after penetration of the pay zone requires the original service of this well be changed to production service. This matter was discussed with Tom Maunder on November 26, 2001. He requested that an attachment to the completion report be made specifying the change that will be made and stating the reason for the change in service. This addendum is meant to satisfy that request. Completing 2N-350 as a producer will allow the Tam Pool to maintain reserves while maximizing near-term production rate. If you have any questions regarding this matter, I can be reached at 265-6970. Sincerely, ~ ~mn Tam Coordinator PAl ORIGlf~AL RECEiVED JAN 1 6 2002 .Alaska Oil & Gas Cons. Commission Anchorage ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D Suspended D Abandoned D Service D 2. Name of Operator ¡ --. -. - 7. Permit Number Phillips Alaska, Inc. y~. 201-175 't I"'" 3. Address tS::~~, 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 ; 1,. ~-7. ~'i!..C!.- ?\ 50-103-20389-00 4. Location of well at surface - .:,,'~.~r ....."":_'~~'::~..., ,.:...~. 9. Unit or Lease Name .~ '. ~-", : U~l,; Kuparuk River Unit 161' FNL, 1186' FEL, Sec. 3, T9N, R7E, UM (ASP: 460406, 5911849) 1,..', ,. ~ At Top Producing Interval ~ J ¡. 36 . ó I 10. Well Number ,Ii .........-..,-~,.._... ,--'~._'. 1294' FNL, 1919' FEL, Sec. 5, T9N, R7E, UM (ASP: 449111, 5910784)' .'1" . 2N-350 At Total Depth ..-,.-'.. ::¿P 11. Field and Pool 1536' FNL, 2606' FEL, Sec. 5, T9N, R7E, UM (ASP: 448423, 5910546) ., Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Tarn River Pool RKB 153.9' AMSL ADL 375075 ALK 4306 12. Date Spudded 13. Date T.D. Reached 14. Date~rS~:% Or Aband. 15. Water Depth, if offshore 16. No. of Completions C> .-; September 9,2001 September 28,2001 , 001 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13929' MD 1 5018' TVD 13831' MD 14991' TVD YES 0 No D Camco Landing Nipple @ 522' 1236' (approx) 22. Type Electric or Other Logs Run GR/Res/Neu Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 134' 24" 260 sx AS 1 9.625" 40# L-80 Surface 3737' 12.25" 553 sx AS Lite & 346 sx Class G 7" 26# L-80 Surface 12818' 8.5" 503 sx Class G 4.5" 12.6# L-80 12607' 13929' 6.125" 205 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 12630' 12592' 13610' - 13620' MD 4934' - 4936' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13610' - 13620' 236M# proppant (16/20 and 12/18) behind pipe, 10 ppa on the perfs 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 20,2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/4/2002 7.5 hours Test Period> 763 3271 0 27% 5145 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. 491 psi 649 psi 24-Hour Rate> 2115 1 0881 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECE\\fED N/A JAN 1. H zaGL A\aska Oil & Gas Coos. Commission -.. '!Aochorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RsnMS BFl 0 r'\ ¡ f' t . I, -1'.'''<. \. i ...oJ I j\\~'I;..",t , ~- Submit in duplicate JAN 2 4 2002 c.,r 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top T-3 Top T-2 13175' 13626' 4823' 4938' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Scott Lowry 265-6869 Signed e Title Drillina Enaineerina SUDervisor Date I Y Jã" ð'J- Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. . Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In~..ftÞ Gas Injection, Shut-in, Other-explain. ' Tt::'C~ Item 28: If no cores taken, indicate "none", ,!.qN lVS:D 4/aS4; l (J Form 10-407 q Oq .æ'G~ ; a'!1:) ~C < 4/J1'J. Q.7$ If" ""'IQr . i\.-Q ¡trUe ~I/J~ð' 6.'P1On nf1,r"IN\ ~L ' ' .,.0.. f-'f;:\ I,' ,-.",,: : \ ~! I:".." I ~ ': I .... ...... ~ 1/pHiuiPs) ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/9/2001 9/10/2001 9/11/2001 9/12/2001 (' ( Page 1 of 7 PHilliPS ALASKA INC. Operations Summary Report 2N-350 2N-350 ROT - DRILLING n1333@ppco.com Nabors 16E Sub From - To Hours Code Code Phase 00:00 - 02:30 02:30 - 03:30 2.50 MOVE DMOB MOBMIR 1.00 MOVE MOVE MOBMIR 03:30 - 05:00 1.50 MOVE RURD MOBMIR 05:00 - 09:00 4.00 WELCTL NUND SURFAC 09:00 - 13:00 4.00 DRILL RIRD SURFAC 13:00 - 14:00 1.00 WELCTL BOPE SURFAC 14:00 - 18:00 4.00 DRILL PULD SURFAC 18:00 - 18:30 0.50 DRILL CIRC SURFAC 18:30 - 19:30 1.00 DRILL DRLG SURFAC 19:30 - 20:00 0.50 DRILL TRIP SURFAC 20:00 - 21 :30 1.50 DRILL DRLG SURFAC 21 :30 - 23:00 1.50 DRILL SURV SURFAC 23:00 - 00:00 1.00 DRILL DRLG SURFAC 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01 :00 - 03:00 2.00 DRILL TRIP SURFAC 03:00 - 06:00 3.00 DRILL TRIP SURFAC 06:00 - 07:30 1.50 DRILL TRIP SURFAC 07:30 - 09:00 1.50 DRILL TRIP SURFAC 09:00 - 10:30 1.50 DRILL TRIP SURFAC 10:30 - 11 :00 0.50 DRILL DRLG SURFAC 11 :00 - 13:00 2.00 DRILL TRIP SURFAC 13:00 - 14:30 1.50 DRILL TRIP SURFAC 14:30 - 15:30 1.00 DRILL TRIP SURFAC 15:30 - 17:00 1.50 DRILL DRLG SURFAC 17:00 - 19:30 2.50 DRILL TRIP SURFAC 19:30 - 21 :30 2.00 DRILL TRIP SURFAC 21 :30 - 00:00 2.50 DRILL DRLG SURFAC 00:00 - 04:30 4.50 DRILL DRLG SURFAC 04:30 - 05:30 1.00 DRILL SURV SURFAC 05:30 - 08:30 3.00 DRILL TRIP SURFAC 08:30 - 15:30 7.00 WAlTON OTHR SURFAC 15:30 - 18:00 2.50 DRILL TRIP SURFAC 18:00 - 00:00 6.00 DRILL DRLG SURFAC 00:00 - 00:00 24.00 DRILL DRLG SURFAC 9/13/2001 00:00 - 07:00 7.00 DRILL DRLG SURFAC 07:00 - 09:00 2.00 DRILL CIRC SURFAC 09:00 - 12:30 3.50 DRILL WIPR SURFAC 12:30 - 14:30 2.00 DRILL WIPR SURFAC 14:30 - 17:00 2.50 DRILL CIRC SURFAC 17:00 - 21 :00 4.00 DRILL TRIP SURFAC 21 :00 - 22:30 1.50 DRILL PULD SURFAC 22:30 - 23:00 0.50 CASE SFTY SURFAC 23:00 - 00:00 1.00 CASE RURD SURFAC Spud Date: 9/12/2001 End: 10/3/2001 Group: Start: 9/9/2001 Rig Release: 10/3/2001 Rig Number: 16E Description of Operations Prep. to move rig, Move Ball mill Jack up rig, Pull mates, Move rig f/ 2N-348 to 2N-350 Note; Found approximatly 10 gal. mud on ground from 2N-348 spill on 8/19/0, Cleaned up same.1 Set mates, Berm cellar, Install landings and hand rails Accept rig, Nipple up Diverter, Take on water & mud in pits, Spot ball mill, Mix spud mud Clear floor, Pick up subs, slips, etc. f/5" DP, Perform pre-spud walk around, Install top drive pipe handler, Install 4-1/2" saver sub Function test 20" Diverter, perform accum.ldiverter drill Test waived by AOGCC Jeff Jones Pick up 28 jts. HWDP, Make up BHA Fill hole & check for leaks Drill f/ 134' to 163' ART = 1 hr. Stand back stand of HWDP, Pick up 3 flex collars Drill f/ 163' to 255' ART = 1.5 hrs Circ. clean, Run GYRO survey Drill f/ 255' to 314' AST= 1 hr. Drill f/ 314' to 346' AST=.5 hrs Run GYRO survey POOH, Lay down MWD, Set motor at 1.8 RIH, Wash f/ 134' to 346', Run GYRO survey POOH, Stand back BHA Make up UBHO sub on DP, RIH, Run GYRO survey, POOH Set motor at 2.68, RIH to 346', Run GYRO survey Drill f/ 346' to 376' AST = .25 hrs POOH & stand back BHA Make up UBHO sub on DP, RIH, Run GYRO survey, POOH RIH w/ motor to 376' (30' fill) Drill f/ 376' to 402' AST = 1.0 hrs POOH, Make up UBHO sub on DP, RIH, Run GYRO survey, POOH Set motor to 1.8, RIH to 402', Run GYRO survey Drill f/402' to 444' AST = 1.5 hrs (GYRO survey every 30') Drill & Gyro survey f/ 444' to 582' AST = 2.25 hrs Circ btm's up, Gyro survey, Monitor well POOH (Tight spots @ 556' & 516'), Handle BHA, Pick up MWD Shut down rig due to Nation wide FAA flight shut down Program & orient MWD, RIH to 582' (No problems) Drill f/ 582' to 961' AST = 3 hrs ART = 1.75 hrs Drill f/ 961' to 3199' ART= 10.25 hrs AST= 6.0 hrs Note; Incountered Hydrates between 1200' to 2100', Max gas 1600 units, Back ground gas 200 to 900 units. Drld 12-1/4" hole f/ 3199 - 3750' md. ART=3.25 hrs & AST=1.0 hrs. Pumped hi dense sweep & circ'd 3 bttms up. Flow checked well, no flow. Pumped slug. POOH to drill collars. Tight spot @ 3680'. TIH & washed last stand to bttm, no problems. Circ'd and conditioned mud wt & rheology. Circulated 25 bbl hi dense sweep & 3.75 bttms up. Flow checked well, no flow. Pumped slug. POOH to BHA. Flow check well, OK. Laid down accelerator and jar. Racked HWDP back. Laid down flex drill collars + mud motor + MWD + bit. Cleaned floor. Pulled stripomatic to side & cleaned same. Rigging up casing running eqpt. Printed: 10/22/200 1 11: 46:22 AM ~ ~ ~ ~~PHILLlPS} IW Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( (' PHilliPS ALASKA INC. Operations Summary Report 2N-350 2N-350 ROT - DRILLING n1333@ppco.com Nabors 16E Date From - To Hours Code Sub Phase Code 9/14/2001 00:00 - 01 :30 1.50 CASE RURD SURFAC 01 :30 - 07:30 6.00 CASE RUNC SURFAC 07:30 - OS:OO 0.50 CASE RUNC SURFAC OS:OO - 09:45 1.75 CEMEN"' CIRC SURFAC 9/15/2001 9/16/2001 09:45 - 10:30 0.75 CEMENl PULD SURFAC 10:30 - 12:15 1.75 CEMENl CIRC SURFAC 12:15 - 12:30 0.25 CEMENl SEaT SURFAC 12:30 - 14:30 2.00 CEMENl PUMP SURFAC 14:30 - 15:30 1.00 CEMENl DISP SURFAC 15:30 - 17:30 2.00 CEMEN' PULD SURFAC 17:30 - 1S:00 0.50 CEMEN' OTHR SURFAC 1S:00 - 19:30 1.50 DRILL RIRD SURFAC 19:30 - 20:30 1.00 WELLSR NUND SURFAC 20:30 - 00:00 3.50 WELCTL NUND SURFAC 00:00 - 02:00 2.00 WELCTL NUND INTRM1 02:00 - 03:30 1.50 WELCTL BOPE INTRM1 03:30 - 05:30 2.00 WELCTL BOPE INTRM1 05:30 - 06:00 0.50 DRILL PULD INTRM1 06:00 - OS:OO 2.00 DRILL PULD INTRM1 OS:OO - 09:00 1.00 DRILL PULD INTRM1 09:00 - 17:00 S.OO DRILL PULD INTRM1 17:00 - 21 :00 4.00 DRILL PULD INTRM1 21 :00 - 00:00 3.00 DRILL PULD INTRM1 00:00 - 01 :00 1.00 DRILL PULD INTRM1 01 :00 - 02:30 1.50 DRILL CIRC INTRM1 02:30 - 03:30 1.00 WELLSR DEQT INTRM1 Page 2 of 7 Spud Date: 9/12/2001 End: 10/3/2001 Group: Start: 9/9/2001 Rig Release: 10/3/2001 Rig Number: 16E Description of Operations Finished rigging up long bails, power tongs, fillup tool, etc to run 9-5/S" casing. PJSM. Ran 90 joints of 9-5/S" L-SO BTC 40 ppf used casing to 3736.8'md. Had one spot that took extra weight to push thru @ +1- 800 ft. M/U 9-5/8" hanger for 16" conductor landing ring (aD confirmed) and landing joint. Measured thru rotary table, OK. Circulated & reciprocated casing while staging up flowrate to full flowrate. Conditioned mud weight down from spots of 10.5-10.6 to 10.1 + ppg. Added mainly water plus some small amount of Desco to get the YP down. Held PJSM for cement job whilie circulating. P/U wt= 175k & S/O wt= 125-130k. Dowell Schlumberger arrived as planned. Loaded cmt head & observed plugs being loaded, OK. Laid down fillup tool & M/U 2 plug cementing head & cementing lines & line to check floats. Finished circulating & conditioning mud. Over 4 bottoms up circulated at the end of this. Tested cmt lines + 3 valves to cmt head to 3600 psi, OK. Mixed & pumped the following. 20 bbls of CW100 @ 8.4 ppg, released bttm plug, pumped 40 bbls of MudPush @ 10.2 ppg + (437.6 bbls 1553 sxs) of Lead Slurry @ 10.7 ppg + (72.0 bbls 1346 sxs) of Tail Slurry @ 15.8+ ppg. Lead Slurry mixed @ +1- 6 bpm & Tail Slurry mixed @ +1- 5.S - 3.6 - 4.5 bpm (some problem keeping steady wt & rate). Released top plug & put 3 bbls of cmt + 7 bbls of water behind plug. Reciprocated the casing continuously until we had just started the tail slurry, slack off wt getting sticker. Landed hanger and opened 16" conductor valves to vacuum trucks to avoid any chances of packing off the hanger and broaching the conductor. Displaced with one rig pump at 8 bpms (as per DS recommendations). During last 410 strokes slowed pumps to 3 bpm to bump the plug with. Had full returns throughout & bumped the plug and raised pressure from 600 to 1100 psi (500 over circ press). Held 5', no bleed off. Bled off & checked floats, OK. (Estimate we recovered 169 bbls of lead slurry to surface). RID cementing head + lines + long bails. R/U drlg bails. R/U & flushed thru stack,etc to clean excess cmt. N/D diverter lines + annular, hang stack. N/U speed head & oriented as per FMC. N/U BOP eqpt. Set BOP on speed head, torqued flanges, N/U choke HCR & lines + riser & turnbuckles. N/U BOP's. Installed test plug & R/U to test BOP's. Tested BOP eqpt as per PPCO spec's. Pulled test plug & ran 9-5/S" wear bushing & secured hold down bolts. Blew down lines. RIH w/9 stds of HWDP & POOH laying down same. Put 5" dp in pipe shed, PJSM, hooked up kelly hose to topdrive. P/U and racked in derrick 5" dp. PJSM, P/U BHA, adjusted motor, make up bit & oriented motor to mwd. Shallow test motor, AGS & mwd's, OK. Continue in hole picking up remainder of 5" dp. Finished P/U G-105 dp to 3460'. Circ'd 2 bottoms up. RlU to pump down kill line & dp, using chart recorder. Tested 9-5/8" Printed: 10/22/2001 11:46:22 AM ~ .... ~ ~'PHILLlPS~ I[Ð f { ~ PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2N-350 Common Well Name: 2N-350 Event Name: ROT - DRILLING Contractor Name: n1333@ppco.com Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 9/16/2001 02:30 - 03:30 1.00 WELLSR DEQT INTRM1 03:30 - 04:00 0.50 DRILL TRIP INTRM1 04:00 - 06:15 2.25 CEMEN" COUT INTRM1 06: 15 - 06:30 0.25 DRILL DRLG INTRM1 06:30 - 07:00 0.50 DRILL CIRC INTRM1 07:00 - 08:00 1.00 RIGMNT RGRP INTRM1 08:00 - 09:00 1.00 DRILL CIRC INTRM1 09:00 - 10:30 1.50 CEMEN" FIT INTRM1 10:30 - 11 :00 0.50 DRILL DRLG INTRM1 11 :00 - 12:00 1.00 DRILL CIRC INTRM1 12:00 - 13:30 1.50 DRILL CIRC INTRM1 13:30 - 14:30 1.00 DRILL CIRC INTRM1 14:30 - 00:00 9.50 DRILL DRLG INTRM1 9/17/2001 9/18/2001 9/19/2001 9/20/2001 00:00 - 00:00 24.00 DRILL DRLG INTRM1 00:00 - 10:00 10:00 - 10:30 10:30 - 10:45 10:45 - 12:30 12:30 - 16:00 10.00 DRILL DRLG 0.50 DRILL CIRC 0.25 RIGMNT RGRP 1.75 DRILL DRLG 3.50 DRILL CIRC INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 16:00 - 21 :30 5.50 DRILL WIPR INTRM1 21 :30 - 23:00 23:00 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 00:00 1.50 RIGMNT RURD 1.00 RIGMNT RSRV 2.50 DRILL WIPR 1.50 DRILL CIRC 20.00 DRILL DRLG INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 00:00 - 11 :00 11 :00 - 12:30 11.00 DRILL DRLG INTRM1 1.50 DRILL CIRC INTRM1 Page 3 of 7 Spud Date: 9/12/2001 End: 10/3/2001 Group: Start: 9/9/2001 Rig Release: 10/3/2001 Rig Number: 16E Description of Operations casing to 2500 psi for 30', OK. Finished TIH to 3614', tag top of cmt. Drld cmt f/3614-3655'. Drld wiper plugs + float cllr + cmt + float shoe & rathole to 3750'. Cleaned rathole. Drld 20' of new hole for F.I. T. Circ'g to condition mud for F.I.T. Had to replace a section of auger in the cuttings system. Circ'd 1.5 bttms up for F.I.T. R/U to pump down kill line & dp +chart recorder. Performed formation integrity test using 9.8+ppg mud. Pressured to 750 psi, giving 16.1 ppg EMW. Good test. Drld 8-1/2" hole f/ 3770-3820' md. Did this prior to displacing out the old mud. Reason, so that we could keep the AGS in open hole while working the pipe during the displacement. Circ'd 1.5 bttms up. Displaced out old LSND mud with glycol mud @ 9.6 ppg. Established 4 PWD baselines for the various flowrates we might use. Drld 8-1/2" hole f/ 3820 - 4562' md ( 2492' tvd). ART =6.5 & AST =1.25 hrs - these numbers include the time from 3770-3820'. After drlg a couple of stands, we took 14 Casandra check shot surveys. NOTE: Had to start trucking cuttings + mud to 3R-11 yesterday, as we have now reached our limit on the 2N-332 annulus. 2N-332 has been properly freeze protected. Drld 8-1/2" hole f/ 4562-7020'md /3169'tvd. ART=15.25 hrs & AST =1.25 hrs. Plans are to drill to just past 81 OO'md and make a wiper trip to the shoe. Drld 8-1/2" hole f/ 7020 - 7880' md. Circ'd & worked dp while cleaning the hole up to bring the ECD's down. Repaired cap gasket on mud pump no. 2. Drld 8-1/2" hole f/ 7880 - 8068' md / 3450 tvd. Circ'd & conditioned mud for wiper trip. Circ'd 2 x 20 bbl hi-density sweeps & 4 bttms up while rotating and reciprocating dp. Racked 1 std per hr of circ'g. Flow chk'd well, static. Pumped slug. ECD's cleaned up from 12.3 to 11.5 ppg (it clearly takes 4 bttms up). POOH to 9-5/8" casing shoe. The hole looks excellent, the only problems were due to the gauge on this slickbore bit. The hydraulic jars Popped Every Time we had wipe a sand. We had to pull the dp at 4.5'/std to avoid swabbing. No bad spots in the well bore other than the very occassional spots of thick wall cake across sands. Wiped clean. Trip took about 3 hrs longer than planned due to bit design. The gauge is longer than normal PDC's and it is full wrapped (looking from the top of the bit it looks like a gauge ring). PJSM. Slipped & cut 84' of drlg line. Serviced topdrive & drawworks & safety inspection. Finish RIH. Hole in good shape, no problems. Circulated slug out of well and cleaned hole up (ECD's) prior to drilling. Drld 8-1/2" hole f/ 8068 - 9755' md /3904' tvd. ART =11 hrs & AST =3.25 hrs. More sliding today due to making planned left hand turn on azimuth. Drlg w/21 - 100 units of background gas. Drld 8-1/2" hole f/9755 - 10886' md. ART =7.25 hrs & AST =1.0 hrs. Background gas rose to over 10%. PVT was OK, decided to circulate until gas units below 1%... came down to 3.6% and stayed there even Printed: 10/22/2001 11 :46:22 AM ( Page 4 of 7 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-350 2N-350 ROT - DRILLING n1333@ ppco.com Nabors 16E Date Sub From - To Hours Code Code Phase 9/20/2001 11 :00 - 12:30 1.50 DRILL CIRC INTRM1 12:30 - 15:30 3.00 DRILL DRLG INTRM1 15:30 - 16:00 0.50 DRILL CIRC INTRM1 16:00 - 00:00 8.00 DRILL DRLG INTRM1 9/21/2001 00:00 - 10:45 10.75 DRILL DRLG INTRM1 10:45 -15:15 4.50 DRILL CIRC INTRM1 15:15 - 15:30 0.25 RIGMNT SFTY INTRM1 15:30 - 21 :00 5.50 DRILL WIPR INTRM1 21 :00 - 21 :30 0.50 WELCTL OBSV INTRM1 21 :30 - 00:00 2.50 DRILL WIPR INTRM1 9/22/2001 00:00 - 06:00 6.00 DRILL CIRC INTRM1 06:00 - 06:30 0.50 DRILL OBSV INTRM1 06:30 - 13:45 7.25 DRILL TRIP INTRM1 13:45 - 14:00 0.25 DRILL OBSV INTRM1 14:00 - 16:30 2.50 DRILL TRIP INTRM1 16:30 - 19:30 3.00 DRILL PULD INTRM1 19:30 - 20:30 1.00 RIGMNT RGRP INTRM1 20:30 - 22:30 2.00 CASE RURD INTRM1 22:30 - 00:00 1.50 RIGMNT RGRP INTRM1 9/23/2001 00:00 - 04:30 4.50 CASE RUNC INTRM1 04:30 - 05:00 0.50 CASE CIRC INTRM1 05:00 - 06:30 1.50 CASE RUNC INTRM1 06:30 - 07:00 0.50 CASE CIRC INTRM1 07:00 - 09:00 2.00 CASE RUNC INTRM1 09:00 - 09:30 0.50 CASE CIRC INTRM1 09:30 - 12:00 2.50 CASE RUNC INTRM1 12:00 - 12:45 0.75 CASE CIRC INTRM1 12:45 - 15:30 2.75 CASE RUNC INTRM1 15:30 - 16:00 0.50 CASE CIRC INTRM1 16:00 - 17:30 1.50 CASE RUNC INTRM1 Spud Date: 9/12/2001 End: 10/3/2001 Group: Start: 9/9/2001 Rig Release: 10/3/2001 Rig Number: 16E Description of Operations after bottoms up. Flow checked, no flow. Circulated bttms up and no connection gas increase. (( During this time, discovered that we had made a massive mud dilution with brand new mud and that 2 drums of mud lube had been added quite rapidly... this problem was self induced )). Before getting this 2nd bttms up, back ground gas was below 0.5%. Drld 8-1/2" hole f/ 10886 - 11167' md. ART =1.75 hrs & AST = 0.0 hrs. Flow checking all connections now. Slight flow during connection, circulated bttms up and no gas and no PVT gain, mud out of balance. Drld 8-1/2" hole f/ 11167 - 11827' md /4446' tvd. ART =3.75 hrs & AST =1.0 hrs. Drld 8-1/2" hole to interval TD from 11827 - 12834' md (4728' tvd). Circulated & conditioned mud for wiper trip. Flow checked well, no flow. Pumped 12.1 ppg slug. Found a large nut on the rig floor. Prior to POOH, checked topdrive, guide rail supports, monkey board and crown for missing nut... did not find source of nut. POOH to 7022' ( over 1000' into old wellbore from prior wiper trip, hole looks good). Eventually able to POOH at 1.5 min/std... much better than last trip. Monitored well & pumped out trip tank for TIH. TIH with 59 stands. Circulated 2 x 20 bbls hi-dense sweeps & circulated over 4 bttms up. ECD cleaned up to 11.0 ppg. Spotted new fresh mud in open hole with mud lubricants.. Flow checked well, no flow. Pumped 12.1 ppg slug & blew down topdrive. POOH at 1.5'/std up to +/- 5250'. No swabbing tendency with bit. Finished POOH to 9-5/8" shoe @ 2.25 - 3'/std (precaution for Camp Sd & C80 marker). Flow checked well at shoe, no flow. POOH to BHA. UD BHA & downloaded LWD data. Electrical short in power cord going to pedestal crane. Lost most rig power. R/D bails & elevators & R/U long bails, fillup tool, spiders, etc. Repairing damage to pipe skate. Skate track damaged when stabilizer roller onto it. (All of this occurred down in the catwalk area on the pipe shed level). PJSM. Ran 7" casing as per program. Used dog collar on first 20 jts until we had 20k-lbs. Controlled running speed 50-60 fVmin. Circulated bottoms up at 9-5/8" shoe. Ran 7" casing to 5008'... bottom of Camp Sands. Circulated bottoms up.. 10 ppg mud, no signs of CO2. Ran 7" casing to 6578' & taking a little wt. Circ'd bottoms up at 70 spm. Ran 7" casing to 8872'. Circulated 1.5 bttms up. (Decided to circulate good here before casing enterred Left Turn in well trajectory. On 2N-348 it took them 4.5 hrs to get thru the turn). Ran 7" casing to 11,049'. Broke circulation & circ'd bttms up. Ran 7" casing to 12,651'. Unable to get joint down. This was the 4th Printed: 10/22/2001 11 :46:22 AM t ~ ~ ~ 1~ PH I LLI PS) IW) ....., í' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2N-350 Common Well Name: 2N-350 Event Name: ROT - DRILLING Contractor Name: n1333@ppco.com Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 9/23/2001 16:00 - 17:30 1.50 CASE RUNC INTRM1 17:30 - 20:30 3.00 CASE CIRC INTRM1 20:30 - 21 :30 1.00 CASE RUNC INTRM1 21 :30 - 22:30 1.00 CASE CIRC INTRM1 22:30 - 23:00 0.50 CASE RURD INTRM1 23:00 - 00:00 1.00 CASE CIRC INTRM1 9/24/2001 00:00 - 00:30 0.50 CEMEN" SEaT INTRM1 00:30 - 01 :30 1.00 CEMEN"' PUMP INTRM1 01 :30 - 02:30 1.00 CEMEN" DISP INTRM1 02:30 - 03:00 0.50 RIGMNT RGRP INTRM1 03:00 - 03:30 0.50 CEMENl DISP INTRM1 03:30 - 04:00 0.50 CEMENl RURD INTRM1 04:00 - 05:00 1.00 CMPL TN NUND INTRM1 05:00 - 09:30 4.50 RIGMNT RGRP INTRM1 09:30 - 11 :00 1.50 DRILL RIRD INTRM1 11 :00 - 12:00 1.00 WELCTL EaRP INTRM1 12:00 - 14:00 2.00 DRILL PULD INTRM1 14:00 - 14:30 0.50 DRILL PULD INTRM1 14:30 - 20:00 5.50 DRILL PULD INTRM1 20:00 - 00:00 4.00 RIGMNT RGRP INTRM1 9/25/2001 00:00 - 00:30 0.50 RIGMNT RGRP PROD 00:30 - 06:30 6.00 DRILL PULD PROD 06:30 - 09:00 2.50 DRILL PULD PROD 09:00 - 13:00 4.00 WELCTL BOPE PROD 13:00 - 19:30 6.50 WELCTL EaRP PROD Page 5 of 7 Spud Date: 9/12/2001 End: 10/3/2001 Group: Start: 9/9/2001 Rig Release: 10/3/2001 Rig Number: 16E Description of Operations joint that was taking some wt to push down. Decided to stop & clean the well up good before pushing thru bridge. Broke circulation and circulated 3 bottoms up. Had to work flow rate up from 40 spm to 75 spm. Had to be patient, as when I tried to rush it, we tended to loose ground on while working the casing up and down. After 3 bttms up, washed jt down. Washed final 3 joints + landing joint down & hanger. No problems washing down or working pipe up and down. Circ'd and conditioned mud wt & rheology for cementing. RID fill up tool. R/U 2 plug cementing head & lines. Continued conditioning mud. Working casing up and down, no problems & full returns. PJSM. Tested cmt head & lines to 3500 psi for 5', OK. Cmt'd 7" casing as follows: Pumped 20 bbls of CW1 00 & released the bttm plug. Mixed 31.3 bbls MudPush @ 12.0 ppg + 104 bbls (503 sxs) Class G cmt mixed at 15.8 ppg. DS had difficulty keeping a steady 12 ppg on the MudPush again on this well. Released the top plug and displaced with the rig's mud pump at 7 bpm. Slowed rate down to 6 bpm before cement exited the shoe (as rq'd by program). We were able to keep reciprocating the casing until 25% of cement had exited the shoe. Landed the 7" mandrel hanger and after pumping 406.2 bbls of a planned 482.2 displacement the rig lost all power. Rig lost transformers and we could not deliver mud or water to DS. Removed Rinse Aid truck from DS and moved a vacuum truck that we had taken mud from the pits with earlier around the rig to DS. Hooked up vac truck & took on mud for displacement. Finished displacing cement at 6 bpm and slowed to 3 bpm in last 20 bbls, with full returns and no additional pressure. Bumped the plug & pressured from 785 - 1300 psi. Held 5', OK. Bled off & floats holding. RID cmt line & cmt head & landing jt. P/U test joint & made up 7" packoff. Cleaned the stack of mud with water hose. Ran packoff, engaged all hold down bolts & tested packoff to 5000 psi, OK. Rig transformer down. Removed 2 transformers. (( It appears a nut above the transformers worked itself loose and struck one transformer and shorted it out and then this damaged another transformer ». RID casing bails & R/U drlg bails & elevators. Changed out saver sub to 4" HT-38. Changed out lower pipe rams to 4". Top pipe rams still have 3-1/2" x 6" VBR's. UD csg eqpt + 8-1/2" BHA eqpt & P/U 6-1/8" BHA eqpt. Prepare for 4" dp. Prepare to lay down 5" dp. UD 5" dp. Changed out transformers. Install new SCR transformers Lay down 5" DP from derrick Pick up 4" DP and stand back in derrick to drill 6-1/8" hole section Rig & Test all BOPE to 250 low & 5000 psi high- Attempt to test Hydrill- No Good BOPE Test waived by AOGCC John Spaulding Rig down time- Change out Hydril Rubber Printed: 10/22/200 1 11: 46:22 AM ~ ...... ~ t'pHiLùP~ PHilliPS ALASKA INC. Page 6 of 7 lœ Operations Summary Report Legal Well Name: 2N-350 Common Well Name: 2N-350 Spud Date: 9/12/2001 Event Name: ROT - DRILLING Start: 9/9/2001 End: 10/3/2001 Contractor Name: n1333@ppco.com Rig Release: 10/3/2001 Group: Rig Name: Nabors 16E Rig Number: 16E Date From - To Hours Code Sub Phase Description of Operations Code 9/25/2001 19:30 - 22:00 2.50 WELCTL BOPE PROD Test Hydril to 250 low & 3500 psi high- OK, Install wear bushing 22:00 - 00:00 2.00 DRILL PULD PROD Pick up 6-1/8" BHA 9/26/2001 00:00 - 02:00 2.00 DRILL PULD PROD Pick up BHA, Program MWD/LWD tools, Test tools 02:00 - 15:00 13.00 DRILL PULD PROD Pick up 4" DP & tag cmt @ 12712' 15:00 - 16:30 1.50 DRILL CIRC PROD Circ. btm's up fl csg test 16:30 - 18:30 2.00 RIGMNT RURD PROD PJSM, Slip & cut drilling line 94' 18:30 - 19:30 1.00 CASE DEOT PROD Rig & test 7" csg to 3500 psi fl 30 min- OK 19:30 - 22:30 3.00 DRILL DRLG PROD Drill out cmt, Float collar @ 12731' & Shoe @ 12818', Drill new hole to 12860' 22:30 - 00:00 1.50 DRILL CIRC PROD Circ. hole clean & condition mud for LOT 9/27/2001 00:00 - 00:30 0.50 DRILL CIRC PROD Circ & cond mud fl LOT 00:30 - 01 :30 1.00 DRILL FIT PROD Rig & perform FIT of 16.0 ppg EMW wI 1650 psi @ 4736' TVD & 9.3 ppg mud 01 :30 - 02:00 0.50 DRILL DEOT PROD Perform PWD base line 02:00 - 19:00 17.00 DRILL DRLG PROD Drill fl 12860' to 13582' ART = 13.5 hrs AST = 3.5 hrs Note; Rotating build rate 1.3 deg/1 00', Extreme difficulty sliding from 13574', Add glass beads & mud lubes with not much help. 19:00 - 21 :00 2.00 DRILL WIPR PROD Wipe hole to shoe- Hole in great shape 21 :00 - 00:00 3.00 DRILL DRLG PROD Drill fl 13582' to 13600' AST = 3 hrs. (Difficulty sliding) 9/28/2001 00:00 - 06:30 6.50 DRILL DRLG PROD Drill fl 13600' to 13929' ART= 4 hrs AST= 1 hr 06:30 - 09:30 3.00 DRILL CIRC PROD Pump sweep & circ hole clean, Monitor well, Pump dry job 09:30 - 10:00 0.50 DRILL WIPR PROD Wipe hole to shoe- Hole in great shape 10:00 - 11 :30 1.50 RIGMNT RSRV PROD Service top drive & drawworks, Adjust brakes on drawworks 11 :30 - 12:00 0.50 DRILL WIPR PROD RIH to 13929'- No problems 12:00 - 15:00 3.00 DRILL CIRC PROD Pump sweep, Circ & condo mud fl 4-1/2" liner, Monitor well, Pump dry job 15:00 - 21 :30 6.50 DRILL TRIP PROD Drop rabbit & POOH to BHA- Hole in great shape- (SLM- No correction) 21 :30 - 00:00 2.50 DRILL PULD PROD Remove RIA sources, Down load LWD tools, Lay down 6-1/8" BHA 9/29/2001 00:00 - 00:30 0.50 DRILL PULD PROD Finish laying down BHA 00:30 - 02:00 1.50 CASE RURD PROD PJSM, Rig to run 4-1/2" liner 02:00 - 04:30 2.50 CASE RUNC PROD Make up & Run 41 joints 4-1/2" liner, Pick up hanger 04:30 - 13:30 9.00 CASE RUNL PROD RI H (slow) to shoe @ 12818' w/liner on 4" DP 13:30 - 15:30 2.00 CASE CIRC PROD Circ btm's up, Check rotary torque values 15:30 - 16:30 1.00 CASE RUNL PROD RIH to 13929' wI liner, Make up Baker cmt head 16:30 - 22:00 5.50 CEMEN" CIRC PROD Circ. & condo mud fl cmt. job, PJSM, Batch mix Cmt. & Spacers 22:00 - 00:00 2.00 CEMEN" PUMP PROD Pump 1 0 bbls CW1 00, Test lines to 4500 psi, Pump 10 bbls CW1 00, 20 bbls MudPush @ 13.0 ppg, Followed by 205 sxs 43.8 bbls Class G cmt w/.10% D800, 3.0% G, .60% D53, .10% D65, .20gal/sk D47, 2.0gal/sk D600G @ 15.8 ppg, Shut down, Flush lines, Drop plug, Displace cmt wI 145.4 bbls mud, Bump plug wI 2800 psi, Had good circ thru out job, CIP @ 2330 hrs 9/29/01, Set hanger & release from same 9/30/2001 00:00 - 00:30 0.50 CEMEN" OTHR PROD Close rams & reverse out est. 12 bbls cmt., MudPUSH & CW100 00:30 - 01 :30 1.00 CEMEN" OTHR PROD Open well & circ 2 btm's up 01 :30 - 02:30 1.00 CEMEN" PULD PROD Rig down Baker cmt head & lines 02:30 - 06:30 4.00 CEMEN" PULD PROD POOH & lay down Baker liner running tool 06:30 - 08:30 2.00 WELCTL BOPE CMPL TN Change btm pipe rams to 2-3/8" & test doorseals to 250 low & 5000 high 08:30 - 18:00 9.50 CMPLTN TRIP CMPL TN Make up 3-3/4" Mill, Motor, Float sub & Circ. sub, Pick up 2-3/8" DP & 7" scrape, RIH & tag top of liner with scraper @ 12607' with mill @ 13825' 18:00 - 00:00 6.00 CMPLTN CIRC CMPL TN Break circ, Drop ball & open circ sub, Flush both pumps wI water, Pump 50 bbls rinsate, 40 bbls water, 290 bbls seawater, Flush out BOP f ( Printed: 10/22/2001 11 :46:22 AM ( ( ( ~ ..... ~ ~'PHILLlPS) PHilliPS ALASKA INC. Page 7 of 7 ~) Operations Summary Report Legal Well Name: 2N-350 Common Well Name: 2N-350 Spud Date: 9/12/2001 Event Name: ROT - DRILLING Start: 9/9/2001 End: 10/3/2001 Contractor Name: n1333@ppco.com Rig Release: 1 0/3/2001 Group: Rig Name: Nabors 16E Rig Number: 16E Date From - To Hours Code Sub Phase Description of Operations Code 9/30/2001 1S:00 - 00:00 6.00 CMPLTN CIRC CMPL TN stack, Change over to 9.3 ppg Brine, Clean surface equip. & trip tank 10/1/2001 00:00 - 01 :00 1.00 CMPL TN TRIP CMPL TN Rig & lay down 4" DP 01 :00 - 03:00 2.00 RIGMNT RURD CMPLTN Service top drive & drawworks, Cut drilling line 69' 03:00 - 14:30 11.50 CMPL TN TRIP CMPL TN Lay down 4" DP Note; Perform injection test on 9-5/S"x 7" annulas = 675 psi wI 9.3 ppg mud- 15.0 EMW, Flush ann. wI 210 bbls water & freeze protect wI 50 bbls diesel 14:30 - 15:30 1.00 RIGMNT RGRP CMPL TN Rig down time- Replace injectors on lay down machine 15:30 - 17:00 1.50 CMPL TN TRIP CMPL TN Finish laying down 4" DP, Jars, Scraper, XO's 17:00 - 1S:30 1.50 CMPL TN TRIP CMPL TN Rig & lay down 2-3/S" DP & BHA 1S:30 - 20:00 1.50 CMPL TN RURD CMPL TN Clear floor, Pull wear bushing, Rig to run 4-1/2" completion string 20:00 - 20:30 0.50 CASE DEaT CMPL TN Test 4-1/2" & 7" casing to 3500 psi fl 30 min.- OK 20:30 - 00:00 3.50 CMPL TN RUNT CMPL TN Pick up & run 4-1/2" completion string Note; Run DB-6 nipple wI Ball in place on RHC plug 10/2/2001 00:00 - 09:00 9.00 CMPL TN RUNT CMPL TN Run 4-1/2" completion string & tag btm of liner tie back sleeve @ 12614', Rig to set packer 09:00 - 10:00 1.00 CMPL TN PCKR CMPL TN Pressure tbg to 3000 psi & set packer @ 12596' (Tbg. measurements), Pick up & shear release from Polish bore receptacle 10:00 - 11 :00 1.00 CMPL TN SOHO CMPL TN Space out & make up tbg. hanger, Land tbg & run in lock down screws 11 :00 - 13:00 2.00 CMPL TN DEaT CMPL TN Rig & test tbg to 3500 psi fl 15 min.- OK, Bleed tbg to 1500 psi, Test 4-1/2"x 7" annulas to 3500 psi fl 15 min.-OK, Bleed tbg. & shear RP valve 13:00 - 15:00 2.00 CMPL TN FRZP CMPL TN Pump & freeze protect well wI SO bbls diesel thru RP valve @ 2214', Blow down & rig down lines & equip. 15:00 - 16:00 1.00 CMPL TN RURD CMPL TN Pull landing joint & set BPV 16:00 - 22:30 6.50 CMPL TN NUND CMPL TN Nipple down BOP equip. (Flush & removed all rams) 22:30 - 00:00 1.50 CMPL TN NUND CMPL TN Nipple up Production tree 10/3/2001 00:00 - 02:00 2.00 CMPL TN SEaT CMPL TN Rig to test tree, Pull BPV, Install 2 way check, Test tree to 250 psi low & 5000 psi high, Pull 2 way check, Install BPV, Secure tree Release rig for summer maintenance @ 0200 hrs 10/3/01 Printed: 10/22/2001 11 :46:22 AM Date 11/12/01 11/19/01 11/23/01 11/30/01 12/01/01 12/02/01 ( 2N-350 Event History ( Comment PULLED BALL & ROD @ 12,611' RKB; PULLED 1" SOY @ 2214' RKB, IN PROGRESS. [PERF] SET 1" DV @ 2214' RKB; ATTEMPTED TO PULL RHC PLUG BODY @ 12,611' RKB, ENCOUNTERED FILL. [PERF] PULLED RHC PLUG BODY @ 12611' RKB. UNABLE TO DRIFT TBG W /3.45" X 22' DUMMY GUN. DRIFTED TBG (3.40") & TAGGED FILL @ 13839' RKB. [TAG] PERFORMED A MEM LOG FROM 13,823' TO 12,400'. THIS INCLUDES A CORRECTED JEWELRY LOG. PERFORATED 10' OF 27/8" 38C-6 SPF FROM 13,610' TO 13,620' CORRECTED DEPTH. CORRELATED TO SPERRY-SUN MWD LOG DATED 09-SEP-01 TO 29-SEPT-01. WELL BORE FLUID 95% DIESEL - PERFORMED SBHP SURVEY, W/ DUAL PANEX GAUGES, DEPTH 13610' WLM, COMPLETE. [PRESSURE DATA] PUMPED INITIAL FRAC. PLACED 236M# PROPPANT (16/20 AND 12/18) BEHIND PIPE, 10 PPA ON THE PERFS, 97% OF DESIGN. HAD NWBSO 183 BBLS INTO 200 BBL FLUSH. LEFT 9M# PROPPANT IN WELLBORE. [FRAC-REFRAC] Page 1 of 1 1/4/2002 f (' AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 2N-350 GYRO að I~ / 7 5 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , MD (if applicable) 'MD Please call me at 273-3545 if you have any questions or concerns. Regards, William Allen Survey Manager RECEIVED NDV 0 7 2001 Alaslcs Oil & Ga f"o- " S ~ns, ComflusS;cJr¡ Anctr.Drage Attachment(s) 05-Nov-01 ~) ""- 1 0 f() DEFINITIVE -~~~ Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-350 2N-350 Gyro Job No. AKMM11153, Surveyed: 28 September, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 501032038900 Surface Coordinates: 5911848.87 N, 460406.45 E (700 10'12.3757" N, 1500 19' 07.1355" W) Kelly Bushing: 153.50ft above Mean Sea Level '-- spel'r'v-suf1 DRIL-L-ING seRVIc:es A Halliburton Company 5U1vey Ref: svy9625 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth' (ft) (ft) (ft) 0.00 0.000 0.000 -153.50 0.00 174.00 0.800 34.000 20.49 173.99 ~~ 265.00 1.000 45.000 111.48 264.98 297.00 1.000 32.000 143.48 296.98 330.00 0.900 40.000 176.47 329.97 354.00 0.300 282.000 200.47 353.97 387.00 2.600 237.000 233.46 386.96 442.00 5.600 250.000 288.31 441.81 507.00 8.500 238.000 352.82 506.32 535.00 9.500 232.000 380.48 533.98 Sperry-Sun Drilling Services Survey Report for 2N-350 Gyro Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 .~ ~ ~ DEFINITIVE North Slope, Alaska Kuparuk 2N Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section (o/100ft) Comment O.OON O.OOE 5911848.87 N 460406.45 E 0.00 Tolerable Gyro 1.01 N 0.68E 5911849.87 N 460407.13 E 0.460 -0.79 2.10 N 1.60 E 5911850.96 N 460408.06 E 0.289 -1.82 2.53 N 1.94 E 5911851.39 N 460408.40 E 0.707 -2.22 2.97N 2.26E 5911851.83 N 460408.73 E 0.503 -2.58 3.13 N 2.32E 5911851.99 N 460408.79 E 4.475 -2.66 2.74 N 1.61 E 5911851.60 N 460408.07 E 7.264 -1.91 1.14 N 1.96W 5911850.02N 460404.50 E 5.676 1.82 2.49 S 9.02W 5911846.43 N 460397.42 E 4.981 9.24 5.01 S 12.59 W 5911843.93 N 460393.83 E 4.894 13.08 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 161' FNL & 1186' FEL. Magnetic Declination at Surface is 25.583° (08-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 161' FNL & 1186' FEL and calculated along an Azimuth of 263.480° (True). . Based upon Minimum Curvature type calculations, at a Measured Depth of 535.000., .,~ The Bottom Hole Displacement is 13.55ft., in the Direction of 248.312° (True). 5 November, 2001 - 14:37 Page 2 of 3 DrillQuest 2.00.08.005 Kuparuk River Unit Survey tool program for 2N-350 Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Sperry-Sun Drilling Services Survey Report for 2N-350 Gyro Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . North Slope, Alaska Kuparuk 2N Survey Tool Description 0.00 0.00 535.00 533.98 Tolerable Gyro 5 November, 2001 - 14:37 Page 3 of 3 DrillQuest 2.00.08.005 (' AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~ 05-Nov-01 Definitive Re: Distribution of Survey Data for Well 2N-350 dD/- /75 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 535.00' MD , M D (if applicable 13,929.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William Allen Survey Manager Attachment( s) RECEIVED IVov 0 ? 2001 Alaska Oil & Gas Co .", ., . An(.\~ora~~ Lormmssicm . . DEFINITIVE "-....., Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot.2N-350 2N-350 Job No..AKZZ11153, -- " SURVEY REPORT 5 November, 2001 Your Ref: API 501032038900 Surface Coordinates: 5911848.87 N, 460406.45 E (70010' 12.3757" N, 150019' 07.1355" W) Kelly Bushing: 153. 50ft above Mean Sea Level ¡a.." sper'''''''y-suf! DRILLING SERVICES A Halliburton Company Survey Ref: svy9684 Sperry-Sun Drilling Services . Survey Report for 2N-350 Your Ref: AP/501032038900 DEFINITIVE Job No. AKZZ11153, North Slope, Alaska KuparukRiver Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth. Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 535.00 9.500 232.000 380.48 533.98 5.01 S 12.59 W 5911843.93 N 460393.83 E 13.08 AK-6 BP _IFR-AK 1""', 573.02 10.780 229.670 417.90 571.40 9.245 17.78 W 5911839.72 N 460388.63 E 3.535 18.71 665.78 11.930 223.210 508.85 662.35 21.84 S 30.95 W. 5911827.19 N 460375.38 E 1.847 33.23 755.15 12.640 230.540 596.18 749.68 34.79 S 44.83 W 5911814.31 N 460361.44 E 1.916 48.48 848.54 13.250 244.940 687.22 840.72 45.82 S 62.42 W 5911803.37 N 460343.79 E 3.506 67.21 947.29 16.020 256.220 782.77 936.27 53.86 S 85.91 W 5911795.46 N 460320.26 E 4.012 91.46 1035.09 23.480 263.470 865.36 1018.86 58.75 S 115.10 W 5911790.73 N 460291.04 E 8.928 121.02 1129.95 27.010 263.950 951.15 1104.65 63.17 S 155.31 W 5911786.52 N 460250.81 E 3.727 161.46 1225.59 32.470 255.910 1034.19 1187.69 71.72 S 201.86 W 5911778.21 N 460204.22 E 7.059 208.68 1319.33 33.950 255.440 1112.62 1266.12 84.42 S 251.60 W 5911765.76 N 460154.41 E 1.603 259.55 1412.88 34.680 256.890 1189.89 1343.39 97.03 S 302.81 W 5911753.43 N 460103.14 E 1.171 311.85 1506.90 36.540 258.130 1266.32 1419.82 108.85 S 356.26 W 5911741.88 N 460049.63 E 2.122 366.29 1600.24 39.860 259.230 1339.67 1493.17 120.165 412.85 W 5911730.87 N 459992.98 E 3.631 423.80 1694.74 43.680 260.660 1410.14 1563.64 131.125 474.82 W 5911720.24 N 459930.95 E 4.166 486.62 1787.27 47.380 260.720 1474.94 1628.44 141.805 539.97 W 5911709.90 N 459865.74 E 3.999 552.56 1880.94 52.460 261.460 1535.24 1688.74 152.88 5 610.76 W 5911699.19 N 459794.90 E 5.457 624.14 1978.41 55.990 261.280 1592.21 1745.71 164.75 S 688.93 W 5911687.73 N 459716.67 E 3.625 703.16 2071.61 59.660 261.440 1641.83 1795.33 176.59 S 766.91 W 5911676.29 N 459638.63 E 3.940 781.97 ~, 2165.67 63.190 261.170 1686.81 1840.31 189.08 S 848.55 W 5911664.23 N 459556.92 E 3.761 864.50 2258.76 66.950 264.100 1726.05 1879.55 199.87 S 932.25 W 5911653.88 N 459473.17 E 4.945 948.88 2351.81 69.950 265.610 1760.23 1913.73 207.61 S 1018.43 W 5911646.59 N 459386.95 E 3.560 1035.39 2448.01 73.520 267.520 1790.37 1943.87 213.07 S 1109.60 W 5911641.61 N 459295.75 E 4.162 1126.59 2542.71 74.150 270.540 1816.74 1970.24 214.61 S 1200.53 W 5911640.55 N 459204.81 E 3.134 1217.11 2636.30 74.520 271.120 1842.02 1995.52 213.30 S 1290.63 W 5911642.32 N 459114.72 E 0.716 1306.49 2730.62 76.080 271.040 1865.95 2019.45 211.58 S 1381.85 W 5911644.52 N. . 459023.51 E 1.656 1396.92 2824.69 74.980 270.420 1889.45 2042.95 210.42 S 1472.92 W 5911646.16 N 458932.44 E 1.332 1487.28 2918.63 74.580 . 272.230 1914.12 2067.62 208.33 5 1563.54 W 5911648.73 N 458841.84 E 1.907 1577.08 3013.36 73:870 273.020 1939.87 2093.37 204.155 1654.61 W 5911653.38 N 458750.80 E 1.098 1667.08 3106.68 74.720 273.550 1965.13 2118.63 199.00 S 1744.29 W 5911658.99 N 458661.14 E 1.062 1755.61 3200.01 75.630 273.400 1989.01 2142.51 193.54 5 1834.35 W 5911664.93 N 458571.11 E 0.987 1844.47 5 November, 2001- 14:41 Page 2 017 DrillQ(/(?st 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 2N-350 Your Ref: API 501032038900 Job No. AKZZ11153, North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3294.17 74.740 273.510 2013.09 2166.59 188.05 5 1925.21 W 5911670.90 N 458480.28 E 0,952 1934.12 -., 3388.84 73.450 274.290 2039.03 2192.53 181.865 2016.05 W 5911677.56 N 458389.48 E 1.576 2023.67 3486.04 74.090 271.290 2066.20 2219.70 177.325 2109.25 W 5911682.59 N 458296.30 E 3.036 2115.76 3577.84 74.880 270.890 2090.76 2244.26 175.64 5 2197.69 W 5911684.73 N 458207.87 E 0.958 2203.44 3673.72 74.980 270.170 2115..69 2269.19 174.785 2290.26 W 5911686.07 N 458115.30 E 0.733 2295.32 3783.97 74.920 268.410 2144.32 2297.82 176.105 2396.72 W 5911685.31 N 458008.84 E 1.543 2401.24 3875.86 74.930 266.470 2168.22 2321.72 180.06 5 2485.35 W 5911681.81 N 457920.19 E 2.039 2489.76 3968.04 74.660 266.310 2192.40 2345.90 185.67 S 2574.13 W 5911676.67 N 457831.38 E 0.337 2578.60 4061.19 75.190 266.940 2216.62 2370.12 190.965 2663.92 W 5911671.85 N 457741.57 E 0.866 2668.41 4154.11 75.250 268.750 2240.33 2393.83 194.34 5 2753.70 W 5911668.94 N 457651.77 E 1.885 2757.99 4248.26 75.950 270.720 2263.75 2417.25 194.765 2844.88 W 5911669.00 N 457560.59 E 2.159 2848.63 4342.50 75.830 271.090 2286.72 2440.22 193.31 5 2936.27 W 5911670.92 N 457469.21 E 0.401 2939.27 4437.16 75.500 270.990 2310.16 2463.66 191.655 3027.96 W 5911673.06 N 457377.52 E 0.363 3030.19 4534.71 75.310 270.790 2334.74 2488.24 190.185 3122.35 W .5911675.03 N 457283.14 E 0.278 3123.80 4627.00 75.130 270.160 2358.28 2511.78 189.44 S 3211.59W 5911676.23 N 457193.92 E 0.688 3212.38 4723.21 75.300 270.990 2382.83 2536.33 188.51 S 3304.61 W 5911677.65 N 457100.90 E 0.853 3304.69 4816.29 75.120 270.490 2406.60 2560.10 187.355 3394.59 W 5911679.29 N 457010.92 E 0.554 3393.97 4910.61 75.060 272.380 2430.87 2584.37 185.065 3485.71 W 5911682.04 N 456919.82 E 1.937 3484.24 .~ 5003.46 74.850 272.550 2454.97 2608.47 181.21 S 3575.29 W 5911686.37 N 456830.26 E 0.287 3572.81 5096.67 74.610 272.150 2479.52 2633.02 177.52 S 3665.13 W 5911690.53 N 456740.44 E 0.488 3661.66 5190.70 74.220 271.670 2504.78 2658.28 174.505 3755.66 W 5911694.02 N .456649.93 E 0.643 3751.25 5285.44 73.520 271.560 2531.10 2684.60 171.94 5 3846.63 W 5911697.06 N 456558.97 E 0.747 3841.35 5377.50 73.140 270.810 2557.51 2711.01 170.11 5 3934.80 W 5911699.35 N 456470.81 E 0.883 3928.75 5471.77 73.320 272.430 2584.71 2738.21 167.565 4025.02 W 5911702.37 N 456380.61 E 1.656 4018.10 5566.10 73.140 271.800 2611.93 2765.43 164.23 5 4115.28 W 5911706.18 N 456290.37 E 0.667 4107.40 5659.81 72.690 271.250 2639.46 2792.96 161.84 S 4204.82 W 5911709.03 N 456200.84 E 0.738 4196.09 5755.60 74.800 272.820 2666.27 2819.77 158.57 5 4296.71 W 5911712.78 N 456108.97 E 2.707 4287.03 5850;59 74.800 273.020 2691.18 2844.68 153.905 4388.26 W 5911717.93 N 456017.44 E 0.203 4377.46 5945.18 74.490 272.700 2716.22 2869.72 149.355 4479.36 W 5911722.96 N 455926.37 E 0.462 4467.46 6038.93 74.290 272.020 2741.45 2894.95 145.63 S 4569.58 W 5911727;15 N 455836.17 E 0.730 4556.67 -------- 5 November, 2001 - 14:41 Page 30f 7 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 2N-350 Your Ref: AP/501032038900 Job No. AKZZ11153, North Slope, Alaska KuparukRiver Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) --~- 6130.04 74.040 272.100 2766.31 2919.81 142.48 S 4657.17 W 5911730.76 N 455748.60 E 0.287 4643.34 ~ 6224.98 73.900 272.150 2792.53 2946.03 139.10 S 4748.36 W 5911734.62N 455657.43 E 0.156 4733.56 6317.79 73.630 272.190 2818.48 2971.98 135.72 S 4837.40 W. 5911738.46 N 455568.40 E 0.294 4821.65 6411.44 73.210 271.580 2845.20 2998.70 132.77 S 4927.11 W 5911741.88 N 455478.71 E 0.769 4910.44 6507.39 72.870 271.220 2873.19 3026.69 130.53 S 5018.86 W 5911744.60 N 455386.98 E 0.504 5001.35 6601.53. 72.370 271.050 2901.31 3054.81 128.75 S 5108.68 W 5911746.85 N 455297.16 E 0.558 5090.39 6695.51 74.810 271.580 2927.86 3081.36 126.68 S 5198.80 W 5911749.39 N 455207.05 E 2.652 5179.70 6789.84 74.350 272.020 2952.94 3106.44 123.82 S 5289.69 W 5911752.73 N 455116.18 E 0.663 5269.68 6884.70 74.090 271.890 2978.74 3132.24 120.71 S 5380.92 W 5911756.32 N 455024.97 E 0.304 5359.97 6979.80 73.650 271.110 3005.16 3158.66 118.31 S 5472.25 W 5911759.19 N 454933.66 E 0.914 5450.44 7075.67 73.000 270.920 3032.67 3186.17 116.69 S 5564.07 W 5911761.29 N 454841.84 E 0.704 5541.49 7169.31 72.360 270.460 3060.54 3214.04 115.61 S 5653.46 W 5911762.84 N 454752.46 E 0.829 5630.18 7263.29 74.480 270.180 3087.36 3240.86 115.11 S 5743.52 W 5911763.81 N 454662.40 E 2.274 5719.61 7356.25 75.120 269.670 3111.73 3265.23 115.23 S 5833.23 W 5911764.16 N 454572.70 E 0.868 5808.75 7447.60 74.810 269.340 3135.43 3288.93 115.99 S 5921.45 W 5911763.86 N 454484.47 E 0.487 5896.49 7543.56 76.450 271.280 3159.25 3312.75 115.48 S 6014.40 W 5911764.86 N 454391.53 E 2.599 5988.78 7635.91 75.890 270.790 3181.32 3334.82 113.86 S 6104.06 W 5911766.95 N 454301.88 E 0.796 6077.68 7730.18 .75.250 270.330 3204.81 3358.31 112.97 S 6195.35 W 5911768.32 N 454210.60 E 0.827 6168.28 ~ 7824.84 74.800 270.010 3229.27 3382.77 112.69 S 6286.79 W 5911769.07 N 454119.15 E 0.577 6259.11 7917.49 74.170 269.530 3254.06 3407.56 113.05 S 6376.06 W 5911769.18 N 454029.88 E 0.844 6347.84 8011.39 74.870 271.990 3279.12 3432.62 111.85 S 6466.54 W 5911770.85 N 453939.41 E 2.632 6437.60 8105.10 74.800 272.060 3303.64 3457.14 108.65 S 6556.93 W 5911774.52 N 453849.04 E 0.104 6527.05 8199.17 74.220 271.580 3328.76 3482.26 105.77 S 6647.54 W 5911777.88N 453758.45 E 0.789 6616.75 8292.05 73.590 271.460 3354.51 3508.01 103.41 S 6736.75 W 5911780.71 N 453669.26 E 0.690 6705.11 8386.06 74.740 272.650 3380.16 3533.66 100.16 S 6827.13 W 5911784.43 N. 453578.89 E 1.726 6794.54 8479.82 74.360 272.760 3405.14 3558.64 95.90 S 6917.40 W 5911789.17 N 453488.65 E 0.421 6883.75 8574.21 74.100 272.720 3430.79 3584.29 91.55 S 7008.13 W 5911793.98 N 453397.94 E 0.278 6973.41 8666.27 73.580 272.270 3456.41 3609.91 87.70 S 7096.47 W 5911798.29 N 453309.62 E 0.734 7060.74 8759.48 73.000 271.970 3483.21 3636.71 84.40 S 7185.68 W 5911802.06 N 453220.43 E 0.694 7149.01 8852.75 75.180 271.660 3508.78 3662.28 81.56 S 7275.33 W 5911805.37 N 453130.79 E 2.359 7237.75 5 November, 2001- 14:41 Page 4 of7 DrillQuest 2.00.08.005 " . Sperry-Sun Drilling Services Survey Report for 2N-350 Your Ref: API 501032038900 Job No. AKZZ11153, North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8945.99 74.810 271.550 3532.92 3686.42 79.04 5 7365.35 W 5911808.37 N 453040.78 E 0..413 7326.92 -- 9040.34 74.420 271.240 3557.95 3711.45 76.82 5 7456.30 W 5911811.06 N 452949.85 E 0.521 7417.02 ) 9136.49 74.040 270.450 3584.08 3737.58 75.46 5 7548.82 W 5911812.91 N 452857.34 E 0.884 7508.79 9230.94 73.270 264.980 3610.68 3764.18 79.06 5 7639.34 W 5911809.78 N 452766.81 E 5.617 7599.14 9325.73 74.030 259.600 3637.38 3790.88 91.27 S 7729.43 W 5911798.04 N 452676.65 E 5.505 7690.03 9417.62 74.740 255.990 3662.13 3815.63 109.985 7815.91 W 5911779.78 N 452590.07 E 3.862 7778.08 9512.51 74.870 255.640 3687.00 3840.50 132.42 5 7904.69 W 5911757.81 N 452501.17 E 0.381 7868.83 9606.28 75.310 253.120 3711.13 3864.63 156.825 7991.95 W 5911733.87 N 452413.79 E 2.639 7958.29 9701.10 74.930 252.860 3735.48 3888.98 183.625 8079.58 W 5911707.52 N 452326.02 E 0.480 8048.39 9795.35 74.670 251.990 3760.19 3913.69 211.095 8166.29 W 5911680.51 N 452239.17 E 0.933 8137.65 9887.78 74.230 251.690 3784.97 3938.47 238.84 5 8250.90 W 5911653.20 N 452154.42 E 0.570 8224.86 9982.66 75.700 252.600 3809.58 3963.08 266.93 5 8338.11 W 5911625.56 N 452067.05 E 1.805 8314.70 10076.10 75.760 253.340 3832.61 3986.11 293.45 5 8424.70 W 5911599.50 N 451980.33 E 0.770 8403.73 10170.51 75.370 253.010 3856.15 4009.65 319.925 8512.21 W 5911573.49 N 451892.68 E 0.534 8493.68 10265.61 76.010 254.340 3879.65 4033.15 345.82 5 8600.65 W 5911548.05 N 451804.11 E 1.513 8584.47 10359.39 76.330 255.040 3902.07 4055.57 369.86 5 8688.47 W 5911524.47 N 451716.16 E 0.801 8674.46 10454.81 75.820 254.350 3925.03 4078.53 394.31 5 8777.80 W 5911500.49 N 451626.70 E 0.882 8765.98 10549.49 75.750 254.980 3948.28 4101.78 418.585 å866.32 W 5911476.68 N 451538.06 E 0.649 8856.68 .~ 10644.13 75.250 254.210 3971.98 4125.48 442.92 5 8954.65 W 5911452.81 N 451449.60 E 0.948 8947.20 10738.13 74.930 253.900 3996.17 4149.67 467.875 9041.99 W 5911428.31 N 451362.14 E 0.466 9036.80 10831.16 74.670 253.510 4020.56 4174.06 493.06 5 9128.16 W 5911403.57 N 451275.84 E 0.492 9125.27 10924.46 74.290 253.850 4045.52 4199.02 518.325 9214.43 W 5911378.76 N 451189.43 E 0.538 9213.85 11020.36 73.840 252.710 4071.85 4225.35 544.85 5 9302.75 W 5911352.70 N 451100.98 E 1.236 9304.60 11111.10 73.410 252.920 4097.43 4250.93 570.57 5 9385.92 W 5911327.41 N 451017.67 E 0.523 9390.15 11206.91 73.010 252.970 4125.11 4278.61 597.475 9473.61 W 5911300.97 N 450929.84 E 0.420 9480.33 11300.61 74.430 252.590 4151.38 4304.88 624.105 9559.52 W 5911274.79 N 450843.79 E 1.565 9568.70 11395.15 74.050 252.220 4177.06 4330.56 651.605 9646.25 W 5911247.74 N 450756.92 E 0.551 9657.98 11489.11 74.670 252.480 4202.39 4355.89 679.045 9732.47 W 5911220.76 N 450670.56 E 0.712 9746.76 11583.63 74.680 253.640 4227.37 4380.87 705.60 5 9819.67 W 5911194.65 N 450583.22 E 1.184 9836.41 11677.71 74.550 253.850 4252.33 4405.83 730.99 5 990,6.76 W 5911169.72 N 450496.00 E 0.256 9925.80 5 November, 2001- 14:41 Page 5 of 7 DrillQucst 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 2N-350 Your Ref: AP/501032038900 Job No. AKZZ11153, North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11771.61 74.290 253.920 4277.55 4431.05 756.09 S 9993.65 W 5911145.07 N 450408.98 E 0.~86 10014.98 I'" 11865.90 73.850 253.160 4303.43 4456.93 781.78 S 10080.61 W 5911119.83 N 450321.89 E 0.905 10104.29 11957.51 73.660 252.760 4329.05 4482.55 807.56 S 10164.70 W 5911094.50 N 450237.67 E 0.468 10190.76 12052.12 73.270 252.880 4355.98 4509.48 834.35 S 10251.35 W 5911068.17 N 450150.88 E 0.430 10279.88 12146.75 73.840 254.920 4382.77 4536.27 859.51 S 10338.54 W 5911043.46 N 450063.55 E 2.154 10369.37 12240.37 73.710 254500 4408.93 4562.43 883.22 S 10425.25 W 5911020.21 N 449976.72 E 0.453 10458.20 12334.59 73.450 254.360 4435.56 4589.06 907.48 S 10512.31 W 5910996.40 N 449889.54 E 0.311 10547.45 12430.70 73.200 253.630 4463.14 4616.64 932.86 S 10600.81 W 5910971.48 N 449800.90 E 0.773 10638.25 12524.35 74.100 255.100 4489.51 4643.01 957.088 10687.34 W 5910947.72 N 449714.24 E 1.787 10726.98 12617.86 74.040 254.670 4515.17 4668.67 980.52 S 10774.15 W 5910924.73 N 449627.31 E 0.447 10815.88 12709.79 73.650 254.440 4540.75 4694.25 1004.04 8 10859.26 W 5910901.66 N 449542.08 E 0.488 10903.11 12777.47 73.460 254.930 4559.91 4713.41 1021.188 10921.87 W 5910884.84 N 449479.39 E 0.749 10967.25 12811.12 73.170 255.200 4569.57 4723.07 1029.498 10953.01 W 5910876.70 N 449448.20 E 1.155 10999.14 12903.14 74.450 255.530 4595.23 4748.73 1051.828 11038.52 W 5910854.82 N 449362.58 E 1.433 11086.62 12998.64 74.950 254.720 4620.43 4773.93 1075.46 S 11127.54 W 5910831.64 N 449273.43 E 0.971 11177.75 13090.69 73.350 252.780 4645.57 4799.07 1100.238 11212.55 W 5910807.31 N 449188.30 E 2.670 11265.01 13190.79 73.360 252.780 4674.24 4827.74 1128.63 S 11304.16 W 5910779.40 N 449096.54 E 0.010 11359.25 13287.45 74.370 252.030 4701.11 4854.61 1156:708 11392.66 W 5910751.79 N 449007.89 E 1.283 11450.36 ~ 13382.55 75.640 251.890 4725.71 4879.21 1185.148 11480.01 W 5910723.80 N 448920.40 E 1.343 11540.37 13479.29 76.910 251.530 4748.66 4902.16 1214.648 11569.23 W 5910694.78 N 448831.02 E 1.362 11632.36 13571.78 75.580 250.750 4770.65 4924.15 1243.67 S 11654.25 W 5910666.18 N 448745.86 E 1.655 11720.11 13674.82 75.140 250.120 4796.70 4950.20 1277.068 11748.18 W 5910633.29 N 448651.75 E 0.730 11817.23 13764.52 74.630 249.480 4820.09 4973.59 1306.968 11829.45 W 5910603.82N 448570.32 E 0.893 11901.36 13859.15 74.180 247.980 . 4845.53 4999.03 1340.02 S 11914.39W 5910571.20 N 448485.21 E 1.599 11989.50 13929.00 74.180 247.980 4864.57 5018.07 1365.22 S 11976.69 W 5910546.33 N. .448422.78 E 0.000 12054.25 Projected Survey ----------- ---_.---- - 5 November, 2001 - 14:41 Page 60f7 DrillQlIest 2.00.08.005 . . , . Sperry-Sun Drilling Services Survey Report for 2N-350 Your Ref: API 501032038900 Job No. AKZZ11153, . Kuparuk River Unit North Slope, Alaska Kuparuk 2N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 161' FNL & 1186' FEL. Magnetic Declination at Surface is 25.582° (08-Sep-01) (- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 161' FNL & 1186' FEL and calculated along an Azimuth of 263.497° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13929.00ft., The Bottom Hole Displacement is 12054.25ft., in the Direction of 263.497° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13929.00 5018.07 1365.22 S 11976.69W Projected Survey ~-. Survey tool program for 2N-350 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 535.00 0.00 - 533.98 535.00 13929.00 533.98 5018.07 Tolerable Gyro (2N-350 Gyro) AK-6 BP _IFR-AK (2N-350) -- ----_.------_.--- --------- 5 November, 2001- 14:41 Page 7 of 7 DrillQuest 2.00.08.005 ,1" ~. { t 05-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-350 MWD ÒDJ-J7S Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 535.00' MD Window / Kickoff Survey , MD Projected Survey: 13,929.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William Allen Survey Manager Attachment(s) RECE~'/ED f"~OV 0 7 2001 Alaska Oil & Gas Cons, Commission Anc~orage (() l' .......... I ............ 0 \() c_- Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-350 2N-350 MWD Job No. AKMM11153, Surveyed: 28 September, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 501032038900 Surface Coordinates: 5911848.87 N, 460406.45 E (70010' 12.3757" N, 1500 19' 07.1355" W) Kelly Bushing: 153.50ft above Mean Sea Level - spe""""v-sul! DRILLJNG seRVices A Halliburton Company Survey Ref: svy9685 ,,: , '"'.. . Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 535.00 9.500 232.000 380.48 533.98 5.01 S 12.59 W 5911843.93 N 460393.83 E 13.08 MWD Magnetic 573.02 10.780 228.800 417.90 571.40 9.285 17.74 W 5911839.68 N 460388.66 E 3.677 18.68 665.78 11.930 223.540 508.85 662.35 21.95 S 30.87 W 5911827.08 N 460375.46 E 1.667 33.17 -,-~ 755.15 12.640 230.990 596.17 749.67 34.80 S 44.84 W 5911814.31 N 460361.43 E 1.942 48.50 848.54 13.250 245.530 687.22 840.72 45.67 S 62.52 W 5911803.53 N 460343.69 E 3.539 67.30 947.29 16.020 256.880 782.77 936.27 53.45 S 86.10 W 5911795.87 N 460320.07 E 4.025 91.61 1035.09 23.480 264.030 865.36 1018.86 58.03 S 115.34 W 5911791.45 N 460290.81 E 8.916 121.18 1129.95 27.010 264.060 951.15 1104.65 62.22 S 155.57 W 5911787.46 N 460250.55 E 3.721 161.63 1225.59 32.4 70 255.750 1034.19 1187.69 70.80 S 202.11 W 5911779.13 N 460203.97 E 7.142 208.84 1319.33 33.950 255.430 1112.62 1266.12 83.58 S 251.84 W 5911766.61 N 460154.18 E 1.590 259.70 1412.88 34.680 256.990 1189.89 1343.39 96.14 S 303.05 W 5911754.31 N 460102.90 E 1.222 312.01 1506.90 36.540 257.420 1266.32 1419.82 108.26 S 356.44 W 5911742.48 N 460049.45 E 1.996 366.42 1600.24 39.860 258.920 1339.67 1493.17 120.07 S 412.93 W 5911730.97 N 459992.90 E 3.693 423.89 1694.74 43.680 259.930 1410.14 1563.64 131.60 S 474.80W 5911719.76 N 459930.97 E 4.104 486.67 1787.27 47.380 261.330 1474.95 1628.45 142.32 S 539.94 W 5911709.38 N 459865.77 E 4.142 552.61 1880.94 52.460 262.070 1535.24 1688.74 152.64 S 610.84 W 5911699.42 N 459794.82 E 5.457 624.22 1978.41 55.990 261.900 1592.21 1745.71 163.67 S 689.13 W 5911688.81 N 459716.47 E 3.624 703.26 2071.61 59.660 261.930 1641.83 1795.33 174.76 S 767.22 W 5911678.12 N 459638.33 E 3.938 782.10 2165.67 63.190 263.220 1686.82 1840.32 185.42 S 849.12 W 5911667.89 N 459556.37 E 3.941 864.68 2258.76 66.950 264.780 1726.05 1879.55 194.22 S 933.05 W 5911659.53 N 459472.39 E 4.315 949.07 -=-' 2351.81 69.950 266.900 1760.23 1913.73 200.49 S 1019.36 W 5911653.72 N 459386.06 E 3.858 1035.53 2448.01 73.520 268.550 1790.37 1943.87 204.10 S 1110.62W 5911650.59 N 459294.78 E 4.053 1126.61 2542.71 74.150 271.600 1816.74 1970.24 203.97 S 1201.56 W 5911651.18 N 459203.84 E 3.164 1216.95 2636.30 74.520 273.820 1842.02 1995.52 199.71 S 1291.57 W 5911655.92 N 459113.85 E 2.318 1305.89 2730.62 76.080 274.290 1865.95 2019.45 193.26 S 1382.57 W 5911662.85 N 459022.89 E 1.723 1395.57 2824.69 74.980 277.800 1889.46 2042.96 183.68 S 1473.13W 5911672.90 N 458932.38 E 3.797 1484.46 2918.63 74.580 274.290 1914.13 2067.63 174.13 S 1563.26 W 5911682.92 N 458842.30 E 3.630 1572.92 3013.36 73.870 272.380 1939.89 2093.39 168.82 S 1654.26 W 5911688.70 N 458751.33 E 2.080 1662.73 3106.68 74.720 278.160 1965.17 2118.67 160.57 S 1743.67 W 5911697.43 N 458661.96 E 6.031 1750.63 3200.01 75.630 277.210 1989.05 2142.55 148.50 S 1833.08 W 5911709.96 N 458572.62 E 1.385 1838.09 ------- ---- -- 5 November, 2001 - 14:47 Page 2 of 7 DrillQuesf 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: AP/501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) "- 3294.17 74.740 275.570 2013.13 2166.63 138.37 S 1923.54 W 5911720.56 N 458482.21 E 1..931 1926.81 3388.84 73.450 274.680 2039.07 2192.57 130.24 S 2014.22 W 5911729.17 N 458391.58 E 1.635 2015.98 3486.04 74.090 271.510 2066.24 2219.74 125.20 S 2107.40 W 5911734.70 N 458298.43 E 3.200 2107.98 '=-' 3577.84 74.880 270.980 2090.80 2244.30 123.28 S 2195.83 W 5911737.08 N 458210.01 E 1.025 2195.63 3673.72 74.980 270.480 2115.73 2269.23 122.10 S 2288.40 W 5911738.74 N 458117.44 E 0.514 2287.47 3783.97 74.920 268.290 2144.36 2297.86 123.24 S 2394.86 W 5911738.16 N 458010.98 E 1.919 2393.36 3875.86 74.930 266.480 2168.26 2321.76 127.29 S 2483.49 W 5911734.57 N 457922.33 E 1.902 2481 .88 3968.04 74.660 266.170 2192.44 2345.94 132.99 S 2572.26 W 5911729.34 N 457833.53 E 0.437 2570.72 4061.19 75.190 266.890 2216.66 2370.16 138.44 S 2662.04 W 5911724.36 N 457743.72 E 0.938 2660.54 4154.11 75.250 268.490 2240.37 2393.87 142.06 S 2751.81 W 5911721.21 N 457653.94 E 1.666 2750.14 4248.26 75.950 271.760 2263.79 2417 .29 141.85 S 2842.99 W 5911721.89 N 457562.76 E 3.445 2840.71 4342.50 75.830 270.870 2286.76 2440.26 139.76 S 2934.36 W 5911724.47 N 457471.40 E 0.925 2931.25 4437.16 75.500 271.090 2310.20 2463.70 138.19S 3026.06 W 5911726.52 N 457379.71 E 0.415 3022.18 4534.71 75.310 271.090 2334.78 2488.28 136.39 S 3120.44 W 5911728.80 N 457285.34 E 0.195 3115.75 4627.00 75.130 270.380 2358.33 2511.83 135.25 S 3209.67 W 5911730.42 N 457196.12 E 0.769 3204.27 4723.21 75.300 271.290 2382.88 2536.38 133.89 S 3302.68 W 5911732.26 N 457103.11 E 0.931 3296.53 4816.29 75.120 268.710 2406.64 2560.14 133.89 S 3392.67 W 5911732.73 N 457013.13 E 2.687 3385.93 4910.61 75.060 269.890 2430.91 2584.41 135.00 S 3483.81 W 5911732.09 N 456921.99 E 1.211 3476.60 5003.46 74.850 272.910 2455.02 2608.52 132.81 S 3573.43 W 5911734.75 N 456832.37 E 3.149 3565.40 5096.67 74.610 272.180 2479.57 2633.07 128.82 S 3663.26 W 5911739.21 N 456742.56 E 0.798 3654.20 ~~ 5190.70 74.220 270.800 2504.83 2658.33 126.47 S 3753.80 W 5911742.04 N 456652.04 E 1.473 3743.89 5285.44 73.520 271.080 2531.15 2684.65 124.97 S 3844.80 W 5911744.01 N 456561.05 E 0.792 3834.13 5377.50 73.140 271.200 2557.56 2711.06 123.22 S 3932.98 W 5911746.23 N 456472.88 E 0.431 3921.53 5471.77 73.320 272.870 2584.76 2738.26 120.01 S 4023.18 W 5911749.91 N 456382.70 E 1.707 4010.78 5566.10 73.140 271.160 2611.98 2765.48 116.84 S 4113.43 W 5911753.55 N 456292.46 E 1.746 4100.10 5659.81 72.690 270.470 2639.51 2793.01 115.56 S 4203.00 W 5911755.30 N 456202.90 E 0.852 4188.94 5755.60 74.800 272.350 2666.33 2819.83 113.29 S 4294.92 W 5911758.05 N 456111.00 E 2.899 4280.01 58!;0.49 74.800 273.370 2691.21 2844.71 108.72 S 4386.38 W 5911763.10 N 456019.57 E 1.037 4370.35 5945.18 74.490 271.820 2716.28 2869.78 104.59 S 4477.59 W 5911767.71 N 455928.38 E 1.612 4460.51 60:38.93 74.290 271.490 2741.51 2895.01 101.98S 4567.84 W 5911770.79 N 455838.14 E 0.401 4549.88 --- -"-- 5 November, 2001 - 14:47 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical . Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) --. 6130.04 74.040 272.240 2766.37 2919.87 99.13 S 4655.45 W 5911774.10 N 455750.55 E 0.838 4636.59 6224.98 73.900 272.810 2792.59 2946.09 95.11 S 4746.61 W 5911778.60 N 455659.41 E 0.596 4726.71 -c:- 6317.79 73.630 272.920 2818.53 2972.03 90.65 S 4835.61 W 5911783.52 N 455570.44 E 0.312 4814.62 6411.44 73.210 271.200 2845.26 2998.76 87.43 S 4925.30 W 5911787.21 N 455480.76 E 1.816 4903.37 6507.39 72.870 270.500 2873.25 3026.75 86.06 S 5017.07 W 5911789.05 N 455389.00 E 0.783 4994.39 6601.53 72.370 270.240 2901.37 3054.87 85.48 S 5106.91 W 5911790.11 N 455299.17 E 0.593 5083.58 6695.51 74.810 272.240 2927.92 3081.42 83.52 S 5197.02 W 5911792.54 N 455209.06 E 3.303 5172.89 6789.84 74.350 273.350 2953.00 3106.50 79.09 S 5287.85 W 5911797.45 N 455118.26 E 1.235 5262.63 6884.70 74.090 273.330 2978.80 3132.30 73.77 S 5378.98 W 5911803.24 N 455027.16 E 0.275 5352.56 6979.80 73.650 271.720 3005.22 3158.72 69.75 S 5470.24 W 5911807.74 N 454935.92 E 1.691 5442.78 7075.67 73.000 271.310 3032.73 3186.23 67.32 S 5562.05 W 5911810.65 N 454844.13 E 0.792 5533.72 7169.31 72.360 270.530 3060.61 3214.11 65.88 S 5651.43 W 5911812.56 N 454754.75 E 1.049 5622.36 7263.29 74.480 270.310 3087.42 3240.92 65.22 S 5741.49 W 5911813.69 N 454664.69 E 2.267 5711.76 7356.25 75.120 269.150 3111.80 3265.30 65.65 S 5831.20 W 5911813.73 N 454574.99 E 1.387 5800.94 7447.60 74.810 268.890 3135.49 3288.99 67.15 S 5919.41 W 5911812.69 N 454486.77 E 0.437 5888.75 7543.56 76.450 271.630 3159.31 3312.81 66.72 S 6012.35 W 5911813.60 N 454393.83 E 3.251 5981.04 7635.91 75.890 269.610 3181.39 3334.89 65.75 S 6102.01 W 5911815.04 N 454304.18 E 2.209 6070.01 7730.18 75.250 269.220 3204.88 3358.38 66.68 S 6193.30 W 5911814.59 N 454212.88 E 0.788 6160.82 7824.84 74.800 269.670 3229.34 3382.84 67.57 S 6284.74 W 5911814.18 N 454121.44 E 0.661 6251.77 7917.49 74.170 265.520 3254.14 3407.64 71.31 S 6373.92 W 5911810.91 N 454032.25 E 4.369 6340.79 - 8011.39 74.870 272.050 3279.22 3432.72 73.22 S 6464.33 W 5911809.47 N 453941.82 E 6.743 6430.84 8105.10 74.800 271.610 3303.74 3457.24 70.33 S 6554.73 W 5911812.83 N 453851.44 E 0.459 6520.33 8199.17 74.220 271.530 3328.86 3482.36 67.85 S 6645.35 W 5911815.79 N 453760.83 E 0.622 6610.08 8292.05 73.590 271.180 3354.61 3508.11 65.74 S 6734.57 W 5911818.37 N 453671.63 E 0.769 6698.47 83136.06 74.740 272.840 3380.26 3533.76 62.56 S 6824.95 W 5911822.02 N 453581.27 E 2.093 6787.91 8479.82 74.360 272.630 3405.24 3558.74 58.25 S 6915.22 W 5911826.80 N 453491.02 E 0.459 6877.11 85'14.21 74.100 272.590 3430.89 3584.39 54.11 S 7005.96 W 5911831.41 N 453400.30 E 0.278 6966.79 86136.27 73.580 272.560 3456.52 3610.02 50.14 S 7094.29 W 5911835.85 N 453311.99 E 0.566 7054.10 8759.48 73.000 272.050 3483.32 3636.82 46.55 S 7183.49 W 5911839.90 N 453222.81 E 0.814 7142.32 8852.75 75.180 271.340 3508.88 3662.38 43.90 S 7273.15 W 5911843.02 N 453133.17 E 2.449 7231.09 - ---._--~-~- 5 November, 2001 - 14:47 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) 8945.99 74.810 271.300 3533.02 3686.52 41.82 5 7363.18 W 5911845.57 N 453043.15 E 0.399 7320.31 9040.34 74.420 270.980 3558.05 3711.55 40.01 S 7454.13 W 5911847.85 N 452952.21 E 0.527 7410.47 9136.49 74.040 271.540 3584.19 3737.69 37.98 S 7546.64 W 5911850.37 N 452859.71 E 0.686 7502.14 ~-- 9230.94 73.270 265.310 3610.79 3764.29 40.46 5 7637.19 W 5911848.37 N 452769.16 E 6.381 7592.39 9325.73 74.030 259.600 3637.49 3790.99 52.41 S 7727.31 W 5911836.89 N 452678.97 E 5.835 7683.28 9417.62 74.740 255.850 3662.24 3815.74 71.22 S 7813.77 W 5911818.53 N 452592.42 E 4.005 7771.32 9512.51 74.870 256.350 3687.11 3840.61 93.22 S 7902.66 W 5911797.00 N 452503.41 E 0.527 7862.13 9606.28 75.310 253.200 3711.24 3864.74 117.01 S 7990.08 W 5911773.66 N 452415.87 E 3.280 7951.69 9701.10 74.930 253.370 3735.59 3889.09 143.37 S 8077.85 W 5911747.76 N 452327.96 E 0.437 8041.88 9795.35 74.670 252.090 3760.30 3913.80 170.37 S 8164.70 W 5911721.22 N 452240.97 E 1.339 8131.23 9887.78 74.230 251.560 3785.08 3938.58 198.155 8249.30 W 5911693.88 N 452156.23 E 0.729 8218.45 9982.66 75.700 251.920 3809.69 3963.19 226.86 5 8336.32 W 5911665.63 N 452069.06 E 1.592 8308.16 10076.10 75.760 252.340 3832.72 3986.22 254.64 5 8422.50 W 5911638.29 N 451982.73 E 0.440 8396.94 10170.51 75.370 252.120 3856.26 4009.76 282.55 S 8509.57 W 5911610.85 N 451895.52 E 0.471 8486.62 10265.61 76.010 254.340 3879.77 4033.27 309.13 S 8597.79 W 5911584.72 N 451807.16 E 2.360 8577.29 10359.39 76.330 255.060 3902.18 4055.68 333.16 S 8685.63 W 5911561.16 N 451719.20 E 0.820 8667.28 10454.81 75.820 253.830 3925.15 4078.65 357.995 8774.85 W 5911536.79 N 451629.85 E 1.361 8758.75 10549.49 75.750 255.420 3948.40 4101.90 382.33 S 8863.34 W 5911512.92 N 451541.23 E 1.630 8849.43 10644.13 75.250 253.680 3972.10 4125.60 406.73 S 8951.65 W 5911488.97 N 451452.79 E 1.857 8939.94 10738.13 74.930 253.210 3996.28 4149.78 432.61 5 9038.72 W 5911463.55 N 451365.59 E 0.591 9029.39 ~ ,-' 10831.16 74.670 252.980 4020.68 4174.18 458.72 5 9124.62 W 5911437.89 N 451279.56 E 0.367 9117.69 10924.46 74.290 253.580 4045.64 4199.14 484.58 S 9210.72 W 5911412.48 N 451193.33 E 0.742 9206.17 11020.36 73.840 252.110 4071.97 4225.4 7 511.785 9298.83 W 5911385.74 N 451105.07 E 1.547 9296.80 11111.10 73.410 252.740 4097.55 4251.05 538.07 S 9381.82 W 5911359.89 N 451021.94 E 0.817 9382.24 11206.91 73.010 252.830 4125.23 4278.73 565.22 S 9469.44 W 5911333.20 N 450934.19 E 0.427 9472.37 11300.61 74.430 252.490 4151.49 4304.99 592.02 S 9555.29 W 5911306.85 N 450848.19 E 1.555 9560.71 11395.15 74.050 251.830 4177.17 4330.67 619.905 9641.90 W 5911279.43 N 450761.44 E 0.783 9649.93 11489.11 74.670 252.000 4202.50 4356.00 647.985 9727.91 W 5911251.79 N 450675.28 E 0.682 9738.57 11583.63 74.680 253.510 4227.49 4380.99 675.01 5 9814.97 W 5911225.22 N 450588.08 E 1.541 9828.13 11677.71 74.550 253.640 4252.45 4405.95 700.66 S 9901.97 W 5911200.03 N 450500.95 E 0.192 9917.49 5 November, 2001 - 14:47 Page 5 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11771.61 74.290 254.270 4277.67 4431.17 725.66 S 9988.90 W 5911175.48 N 450413.89 E 0,703 10006.69 11865.90 73.850 253.170 4303.55 4457.05 751.07 S 10075.93 W 5911150.52 N 450326.73 E 1.215 10096.05 11957.51 73.660 253.290 4329.17 4482.67 776.45 S 10160.14 W 5911125.59 N 450242.38 E 0.243 10182.60 '~~ 12052.12 73.270 253.010 4356.10 4509.60 802.74 S 10246.95 W 5911099.75 N 450155.44 E 0.500 10271.82 12146.75 73.840 255.180 4382.89 4536.39 827.61 S 10334.23 W 5911075.34 N 450068.04 E 2.280 10361.36 12240.37 73.710 254.360 4409.05 4562.55 851.22 S 10420.96 W 5911052.18 N 449981.18 E 0.852 10450.22 12334.59 73.450 254.190 4435.68 4589.18 875.71 S 10507.95 W 5911028.14 N 449894.06 E 0.326 10539.43 12430.70 73.200 253.360 4463.26 4616.76 901.44S 10596.36 W 5911002.88 N 449805.52 E 0.867 10630.18 12524.35 74.100 254.860 4489.63 4643.13 926.04 S 10682.78 W 5910978.73 N 449718.97 E 1.813 10718.84 12617.86 74.040 254.130 4515.29 4668.79 950.08 S 10769.43 W 5910955.15 N 449632.20 E 0.753 10807.65 12709.79 73.650 254.020 4540.87 4694.37 974.30 S 10854.34 W 5910931.37 N 449547.16 E 0.440 10894.77 12777.47 73.460 254.940 4560.03 4713.53 991.67 S 10916.88 W 5910914.33 N 449484.53 E 1.334 10958.88 12811 . 12 73.170 258.330 4569.69 4723.19 999.12 S 10948.24 W 5910907.04 N 449453.14 E 9.688 10990.88 12903.14 74.450 255.690 4595.36 4748.86 1018.99 S 11034.33 W 5910887.62 N 449366.94 E 3.086 11078.67 12998.64 74.950 254.520 4620.56 4774.06 1042.67 S 11123.35 W 5910864.41 N 449277.80 E 1.292 11169.80 13090.69 73.350 249.720 4645.71 4799.21 1069.83 S 11207.60 W 5910837.69 N 449193.41 E 5.309 11256.59 13190.79 73.360 249.970 4674.38 4827.88 1102.88 S 11297.63 W 5910805.11 N 449103.20 E 0.239 11349.79 13287.45 74.370 250.890 4701.24 4854.74 1133.98 S 11385.12 W 5910774.47 N 449015.56 E 1.388 11440.25 13382.55 75.640 251.580 4725.85 4879.35 1163.52 S 11472.09 W 5910745.38 N 448928.42 E 1.508 11530.01 13479.29 76.910 251.910 4748.80 4902.30 1192.96 S 11561.34 W 5910716.41 N 448839.03 E 1.354 11622.03 ~- 13571.78 75.580 251.400 4770.79 4924.29 1221.24 S 11646.61 W 5910688.58 N 448753.61 E 1.534 11709.96 13674.82 75.140 250.160 4796.84 4950.34 1254.05 S 11740.75 W 5910656.26 N 448659.30 E 1.240 11807.21 13764.52 74.630 247.280 4820.23 4973.73 1285.475 11821.43 W 5910625.26 N 448578.46 E 3.151 11890.94 13859.15 74.180 246.020 4845.67 4999.17 1321.605 11905.11 W 5910589.57 N 448494.59 E 1.368 11978.18 13929.00 74.180 246.020 4864.71 5018.21 1348.91 S 11966.51 W 5910562.58 N 448433.04 E 0.000 12042.29 Projected Survey -__~___n- --- nO 5 November, 2001 - 14:47 Page 6 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-350 MWD Your Ref: API 501032038900 Job No. AKMM11153, Surveyed: 28 September, 2001 . Kuparuk River Unit North Slope, Alaska Kuparuk 2N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 161' FNL & 1186' FEL. '.---- Magnetic Declination at Surface is 25.582° (08-Sep-01) 'Z=,"" The Dogleg Severity is in Degrees per 1 00 feet (US). Vertical Section is from 161' FNL & 1186' FEL and calculated along an Azimuth of 263.480° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13929.00ft., The Bottom Hole Displacement is 12042.30ft., in the Direction of 263.569° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13929.00 5018.21 1348.91 S 11966.51 W Projected Survey Survey tool program for 2N-350 MWD '~~.- From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 535.00 0.00 533.98 535.00 13929.00 533.98 5018.21 Tolerable Gyro (2N-350 Gyro) MWD Magnetic (2N-350 MWD) ------ 5 November, 2001 - 14:47 Page 7 of 7 DrillQuest 2.00.08.005 PHILLf....s Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: sllowry@ppco.com dO\-\~Ç August 28, 2001 Tom Maunder, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1250 Re: Change of completion schematic, Tarn Injector 2N-350 Dear Mr. Maunder: I have made some changes to the completion schematic for this well. After running tube movement calculations, we discovered we need a longer set of seals above the liner top. If you have any questions or require any further information, please contact me at 265-6869. Sincerely, $4/~1 Scott Lowry Drilling Engineer RECEIVED AUG 2 8 2001 Alaska Oil & Gas Cons. Commission Anchorage 2N-350 Injectf~ Proposed Completion Schbillatic 16" 62.58# B @ +1- 153' MD Depths are based on Nabors 15E AKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+1- 3750' MD 12300' TVD) Intermediate csg. 7" 26.0# L-80 BTCM (+1- 11,650' MD I 4441' TVD) Future Perforations Production Liner 4-1/2" 12.6# L-80 NSTC (+1-14,112' MD I 5108' TVD) p~ LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT-MOD pin down 4-1/2" 12.6# L-80 IBT-MOD Spaceout Pups as Required 4-1/2" 12.6# L-80 IBT-MOD Tubing to Surface 4-1/2" Camco 'DB-5' nipple wi 3.875" Top No-Go Profile. 4-1/2" x 6' L-80 IBT-MOD pup installed above and below, set at +1- 500' MD 4-1/2" 12.6# L-80 IBT-MOD tubing 4-1/2" X 1" Camco 'KBG2' Mandrel wi shear valve and latch (Max. OD 6.059", ID 3.833"), @ +1- 2200' MD wi 6' L-80 handling pups installed above and below on GLM. 4-1/2" 12.6# L-80 IBT-MOD Baker CMD sliding sliding sleeve w/3.813'Camco "DB" no-go profile. 1 jt 4-1/2" 12.6# L-80 IBT-MOD tubing 17 Ft. Baker locator seal assembly. 15 Ft. effective stroke. 4.75" OD, 3.88" ID. 4-1/2" L-80 IBT-MOD box up 17 Ft. Baker 80-47 Seal bore receptacle wi 4.75" seal bore. 1 1 Oft. Pup joint 4-1/2" 12.6# L-80 IBT-MOD tubing 7" 26# Baker 83 Packer wI 3.875" 10 110ft. Pup joint 4-1/2" 12.6# L-80 IBT-MOD tubing 4-1/2" Camco 'DB-5' nipple wi 3.75" Top No-Go profile. 4-1/2" x 6' L-80 IBT-MOD handling pups installed above and below 16ft. Pup joint 4-1/2" 12.6# L-80 IBT-MOD tubing wi wireline entry guide Liner Assembly (run on drillpipe). set @ +1- 11.350' MD Liner will use 4-112" L-80 tubing with NSTC connections Baker 5" x 7" "ZXP' Liner Top Isolation Packer with C-2 profile wi 6' Tie back Recl Setting Sleeve Baker 5" x 7" 'HMC' Liner Hanger XO Sub, 5" BTC box x 4-1/2" NSCT pin 4-1/2" 12.6# L-80 NSCT liner as needed RECEIVED 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 tubing 4-1/2" Baker Float Collar 2 jts 4-1/2" 12.6# L-80 tubing 4-1/2" Baker Float Shoe AUG 2 8 2001 Alaska Oil & Gas Cons. Commission Anchorage 08/28/01 .,r f ( ~u!A\uŒ lID~ !A\~~~æfÆ f ~. .I / TONY KNOWLES, GOVERNOR AlAS KA 0 IL AND GAS CONSERVATI ON COMMISSION 333 W. ""fTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 29,2001 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2N-350 Phillips Alaska, Inc. Permit No: 201-175 Sur. Loc. 161' FNL, 1186' FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 1413' FNL, 2794' FEL, Sec. 5, T9N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 2N-350. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC . 25.412 and 20 AAC I ( ( Kuparuk RiverUnit 2N-350 August 29,2001 Page 2 of 2 ~, 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, C~Dutv~ ~ Cammy &echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 29th day of August, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( PHILLI'J'S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 'I" ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com August 21, 2001 Tom Maunder, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1250 Re: Application for Permit to Drill, Tarn Injector 2N-350 Dear Mr. Maunder: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, #2N-350, an injector well to provide pressure support for Tarn production. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~U~M~ Drilling Engineering Supervisor ¡RECEIVED AUG 2 3 2001 Alaska Oil & Gas Cons. Commission Anchorage ( ( h <iJ'ð ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of work: Drill 0 Redrill bJ 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone ø 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 375075 ALK 4306 Tarn River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) 161' FNL, 1186' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1301' FNL, 1941' FEL, Sec. 5, T9N, R7E, UM 2N-350 # 59-52-180 At total depth 9. Approximate spud date Amount 1413' FNL, 2794' FEL, Sec. 5, T9N, R7E, UM September 12, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVO) 1301' @ Target feet 2N-349 14' @ 500' feet 2560 14112 ' M D / 51 08 . TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300' MD Maximum hole angle 74° Maximum surface 1647 psig At total depth (TVD) 2180 psig 18. Casing program SettlnQ Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 120' 35' 35' 155' 155' 260 sx AS I 12.25" 9.625" 40# L-80 BTCM 3715' 35' 35' 3750' 2300' 530 sx AS Lite & 340 sx Class G 8.5" 7" 26# L-80 BTC-Mod 11615' 35' 35' 11650' 4441' 240 sx Class G 6.125" 4.5" 12.6# L-80 NSCT 2762' 11350' 4359' 14112' 5108' 370 sx Class G wi Gasblok 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEiVED AUG 2 3 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I. hereby certify r¡::;e r~g is lrue ""þ:fJ.. to Ihe besl of my knowledge QuesVons? S:: LO;7:J; Signed 'J t?~ -" /' Title: Drilling Engineering SupeNisor C. a a ~~ - ~/ - hv." .111<:>1 In-nr::¡f<¡: ( Commission Use Onl\ Permit Numbe/ ? S API number V 3 ~ I Approval date -:9, æ. ~'11 See cover letter 20/ ..... 50- /d ~ - .z.. c::::>, .. )1 for other requirements Conditions of approval Samples required 0 Yes ~ No Mud log required ,¡¡'" 0 Yes ø No Hydrogen sulfide measures 0 Yes 18J. No Directional survey required 121 Yes 0 No Required working pressure for BOPE D2~ 0 3M; 0 5M; 0 10M;D ~ ~~()~~\ 'f'y"\~'\~~"'" \=S'tJ'Ç -\~~ Other: ~ \\ ~ c.Q.(V\Qt'-..~~,,~ \:\~ \0 ~ ß ~ ~ ,ð ( by order of "'.. . "'~- . Au Commissioner " """" .. . J Approved by the 0þ11 ~is~lqn, ., O""te , . - ... . t./ I 11\.,111 V fi ~- Cammy Oechsli Form 10-401 Rev. 12/1/85. , .,'" Submit in triplicate "f' ( t ation for Permit to Drill, Well 2N-350 Saved: 21-Aug-01 Permit It - Kuparuk Well 2N-350 (Tarn) Application for Permit to Drill Document MoximizE W~II ValUE; Table of Contents 1. Well Name.................................. ............................................................................... 2 Requirements of 20 AAC 25.005 (f)........................................................................................................ 2 2. Location Sum mary .................................. ................................................................. 2 Requirements of 20 AAC 25. 005(c)(2) ..... ................ ..... ..... ..... ........ ..................... .................................. 2 Requirements of 20 AAC 25.050(b)........................................................................................................2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25. 005( c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information.... ............................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementing Program .... ...................................................... ... ................3 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................... 3 7. Diverter System Information............................ ~...................................................... 4 Requirements of 20 AAC 25. 005(c)(7) ................................................................................................... 4 8. Dri II i ng FI u id Prog ram............................ ....................................... .... ...................... 4 Requirements of 20 AAC 25. 005( c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seism ic Analysis............................................................ .................... ...... ................ 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng................ ...................................... .................... ...................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Dri II i ng prog ram............................................ .......................................... 5 Requirements of 20 AAC 25.005 (c)(13) ............................................................... .................................5 2N-350 PERMIT IT.DOC 0 Page 1 of 6 Þw ". .. .. Pr..¡n~ed: 21-Aug-O1 n U i rWt1L. ( ( cation for Permit to Drill, Well 2N-35Q Saved: 21-Aug-O1 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ... .... ............... ............... ....... .... ........................................ ........6 15. Attachments............................................................................................................. 6 Attachment 1 Directional Plan................................................................................................................ 6 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic..............................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Eacl7 well must be identl/ìed by a unique name designated by t/7e operator and a unique API number as...',-igned by the commission under 20 AAC 25:040(b). For a well with multiple well branches, each branch must sirT1llatiy be Identitìed by a unique name and APi number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commi!>'"51ol7. The well for which this application is submitted will be designated as 2N-350. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Onll must be accompanied by each of the following item:.,~ except (or an item already on file with the comrTJIssio!7 and identified in the applic:Jtion: (2) a plat idenlïfying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the ~';I.J/fäce/ at the top of each of?jeäive ¡'Ormation! and at total depth ret"erenced to governmental section lines: (8) the coordinates of the propos-ed location otthe well at the surf'ac¿~ referenced to the state plane mordinate system for tliis state as maintained by the National Geodetic Swvey in the National Oceanic and Atmosplmnc Administr'r.¡tio!7/ (C) the proposed depth of the well at the top of' each objective formation and at total depth; Location at Surface 1161' FNL, 1186' FEL, Sec 3 T9N, R7E, UM NGS Coordinates RKB Elevation 153.9' AMSL Northings: 5,911,849 Eastings: 460,406 Pad Elevation 119.3' AMSL Location at Top of Productive Interval Ku aruk "A3" Sand NGS Coordinates Northings: 5,910,777 1301' FNL, 1941' FEL, Sec 5, T9N, R7E, UM Eastings: 449,087 Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 13 137' 4844' 4690' Location at Total De th 1413' FNL 2794' FEL NGS Coordinates Northings: 5,910,660 Eastings: 448,155 14 112' 5108' 4955' and (D) other li7formation required by 20 AAC 25050(fJ)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated/ the application for a Permit to Drill (Fom7 .10-40.1) must (1) include a plat; drawn to a suitable scale/ showing the path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any portion of the proposed well' Please see Attachment 1: Directional Plan and (2) ¡'Or all wells within 200 feet of the proposed wellÖore 2N-350 PERMIT IT. DOC Page 2 of 6 0 HfG1/~1ft ( f , ~ation for Permit to Drill, Well 2N-350 Saved: 21-Aug-O1 (A) list the names of the operators of tlJOse wells~ to the extent tllat tl70se names are known or discoverable /Ìl public records.- and show that each named operator has been furnished a copy of the application by certified mail;' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pel7mt to Dr/II must be accompanied by each of the follováng ¡tem~ except for an item already on file with the commission and identIfied in tht' application: (3) a diagram and descdption of the blov%ut prevention equipment (BOPE) as required by 20 AAC 25.03_~ 20 AAC 25.036( or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nabors 16E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must" be accompanied by each of the têJllowing items, except tê7r an item already on file with the commiSSïOI1 and identified in the app!tÒìtion: (4) information on drilling Ila2ards~ including (A) the maximum downhole pressure that may be encounterect CrIteria us,-ed to deter/mile it;, and maxtinum potential surface pres:S"lJf('; based 0/7 a methane gradient; Based on offset well data, the expected reservoir pressure in the T3 Bermuda sand for the Tarn well 2N- 350 is -2200 psi at 4844' tvd, 0.45 psi/ft or 8.7 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 2N-350 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the T3 sand target at 4844' tvd: MPSP =(4844 ft)*(0.45 - 0.11 psi/ft) = 1647 psi (8) data on potential gas 20ne5/ The well bore is not expected to penetrate any gas zones. and (CI data concerning potentic']l causes of hole problems sIKh as abnormally geopressured strata, lost circulation zone.5, and zones that have a propensity !êJr differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following item:..'"" except for a/7 item already 0/7 tHe wIth the commission and Identified 1/7 the application: (5) a description of the procedure for conductJi7g formation integrity tests~ as required under 20 AAC 25'{)30(f); Drill out surface and intermediate casing shoes and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for c1 Permit to Drill must be accompanied by each of the following items~ except for an item already 0/7 tile with the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a desC/iptlon of any slotted liner;, pre.. perforated liner;, or screen to be installed; 2N-350 PERMIT IT. DOC 0 RrG-I1V Å L ( ( .:;ation for Permit to Drill, Well 2N-350 Saved: 21-Aug-O1 Casinc¡ and Cementing Pro~lram I Hole Top Btm CsglTb Size Weigh Length MO/TVO MO/TVO g (in) t (Ibltt) Grade Connection (tt) (tt) (ft) Cement Program 00 (in) 16 24 62.5 H-40 Welded 120' 35'/35' 155'/155' 260 sx 15.8 ppg ASl 9-5/8 12-1/4 40.0 L-80 BTC-Mod 3715' 35'/35' 3750'/2300' Lead: 530 sx 10.7 ppg AS Lite Tail: 340 sx 15.8 ppg 'G' w/ add. Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 11,615' 35'/35' 11,650'/4441' 240 sx 15.8 ppg 'G' w/ add. Planned TOC= 10,461' 4-1/2 6-1/8 12.6 L-80 NSCT 2762' 11,350'/4359' 14,112'/5108' 370 sx 15.8 ppg 'G' w/ Gasblok Planned TOC=11,150' 4-1/2 12.6 L-80 BTC-M 11,315' 35'/35' 11350'/4359' 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a PermIt to Dol! must be accompanied by each of the following items~ except for an item already on tHe with the commi,,:<;iol1 and identIfied in tile applicatIon: (7) a diagram and des-cliption of the diverter .system as required by 20 AAC 25: 035~ unles_,,' this requirement is waìved by the commission under 20 AAC 25J)35(f¡)P)~' Please reference diverter schematic on file for Nabors 16E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accvmpanied by each of the f'ollowìng ítem~ except tar an item already on (¡le with thE' commiss'ion and identified in the application: (8) a drilling fluid prograrn including a dl;9gram and description of the drilling fluid system~ as required by 20 AA C 25. OJ3,- Drilling will be done using mud systems having the following properties: Spud to surface Intermediate Drill out casin oint Hole to TD Extended bentonite slur Freshwater GEM Freshwater GEM 9.8-10.0 9.3-9.6 9.3 50-120* 35-50 35- 50 15-35 5-20 5-8 14- 28 6-18 6-13 10-20 2-6 2-5 15-40 4-8 4-8 6-15 5-10 <5 9.5-10 9-9.5 9-9.5 +10 <11 <11 *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Diagram of Nabors 16E Mud System on file. 2N-350 PERMIT IT DOC 0 RtaTf{~ L ( ( .::ation for Permit to Drill, Well 2N-350 Saved: 21-Aug-O1 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the followli7g items, except for an item already on file witl7 the commission and identified in the application: (9) for an exploratory or stratigrapl7ic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.0J3(f)/ N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item:,--- except for an itt?m already on file ~vlth me commission and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 AAC 2S.06.1(a)/ N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fÓr a Permit to Drill must be accompanied by each of the following item:,--- except for an item already on fIle with the commi8sion and Identified in the application: (1.1) for a well df/lled from an off!...11Of'e platfom~ mobile boltomnf()und(,;d strvct(jœ~ jack..up rig/ or floaflj7g drilling vesse¿ an analysis of seabed conditions as required by 20 AAC 25'JJ6.l(b)/ N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill {mIst be accompanied by eac.:h or the following items~ except f'or an item already on fìle with tIle Lì)mmisSìon and IdentIfied in the appliœtion: (12) evIdence showing that the requirements of 20 MC 25.025 (8onding}have been met/ Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a PermIt to Drill must be accompanied by each of the following Item.~ except for an item already 017 file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 16E. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 40#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry and pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill 8-1/2" hole to intermediate casing point according to directional plan. Run LWD logging equipment with GR and resistivity. 7. Run and cement 7" 26#, L-80 BTC-Mod intermediate casing string. Pressure test casing to 3500 psi. Note: If significant hydrocarbon zones are present above the intermediate casing point, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 2N-350 PERMIT IT.DOC , til~A; L : 0 Ht~:, IV"R° ( t cation for Permit to Drill, Well 2N-350 Saved: 21-Aug-O1 9. Drill 6-1/8" hole to TD according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron tools. 10. Run 4-1/2" 12.6#, L-80 NScr liner on drill pipe with Baker liner top packer and hanger and cement liner. 11. Pressure test liner to 3500 psi. 12. Run 4-1/2" 12.6#, L-80 BTC-MOD completion string. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3500 psi. 13. Set TWC and ND BOPE. Install and pressure test production tree. 14. Secure well. Rig down and move out. 15. Handover well to Operations Personnel. . r'\ ~,,~ Q-.)(). \~ \'-{ ~ ~ \~ ~'.)\,~cJ 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items/ except for an item alæadyon me with the commis.9'on and Identified in the application: (14) a general description of how the operator pkgns to d£<ipose of drilling mud and cuttings ami a statement of whether t/1e operator intends' to request authorization under 20 AAC 25.080 (or an annular dispo!:tal operation in the well./ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2N pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 2N pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2N-3s0 for annular pumping of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 2N-350 PERMIT IT DOC 0 F1r(jffl~ L ( , \ " American Express~ Cash Advance Draft 160 " , . DATE 23 ~()S i 2LJt;J I ",-",OM' ~~~::-Æ~i!1!:Þ~~ ~ !~o Sl/o~ C:llARSI Issued by Integrated Payment System, Inc. Englewood. Colorado Payable at Norwest Bank of Grand Junction - Downtown. NA Grand Junction. Colorado PERIOD ENDING d.~ - 6$-(~ I: ~ 0 2 ~ 0 0 ... 0 0 I: j 5 II. 0 ~ ? 5 000 5 j b III 0 ~ b 0 ~ Kuparuk River Vni( North Slope?.,"lâ~lfq . Kuparuk 2N,'Jgl¡2f~~5lJ . 2N~150 ~. 20 May, 2001 Your Ref: Well plan Based on Nabors 16E RKB e/e. Surface Coordinates: 5911848.87 N, 460406.45 E (70010'12.3757" N, 150019' 07.1355" W) Surface Coordinates relative to Project H Reference: 911848.87 N, 39593.55 W (Grid) Surface Coordinates relative to Structure: 93.24 S, 393.76 W (True) Kelly Bushing: 153.9Oft above Mean Sea Level .- C =0 - - ~ - - ~ r--- 5pE!~Y~5UI'1 ~:s:B:b;] N:~::: =.::5::fi]~L2]~ &i :!jL ~ ».d"U1:urltil CÚMp.inf Proposal Ref: pro9525 Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Well plan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -153.90 0.00 0.00 N 0.00 E 5911848,87N 460406.45 E 0.00 SHL: Y = 5911848.87' & X= 460406.4 (161' FNL & 11867' FEL, SEC. 3-T9N R7E)-- 100.00 0.000 0.000 -53.90 100.00 0.00 N O.OOE 5911848;87 N 460406.45 E 0.000 0.00 200.00 0.000 0.000 46.10 200.00 0.00 N 0.00 E 5911848.87 N 460406.45 E 0.000 0.00 300.00 0.000 0.000 146.10 300.00 0.00 N E 5911848.87 N 460406.45 E 0.000 0.00 Begin Dir @ 2.50"/10Oft (in 12-1/4" Hole) : 300.00ft MD, 300.00ft TVD 400.00 2.500 220.000 246.07 399.97 W 5911847.21 N 460405.04 E 2.500 1.56 450.00 3.750 220.000 295.99 449.89 5911845.13 N 460403.28 E 2.500 3.51 Continue Dir @ 3.000/100ft : 450.00ft MD, 449.89ft TVD 500.00 5.052 229.816 ..- ~.43 S 5.89W 5911842.47 N 460400.53 E 3.000 6.50 600.00 7.871 239.186 . 12.78 S 15.13 W 5911836.17 N 460391 .25 E 3.000 16.33 700.00 10.787 243.579 20.46 S 29.40 W 5911828.57 N 460376.95 E 3.000 31.29 800.00 13.739 246.110 29.43 S 48.64 W 5911819.69 N 460357.66 E 3.000 51.33 900.00 16.708 39.68 S 72.81 W 5911809.57 N 460333.43 E 3.000 76.40 1000.00 19.686 51.19S 101.84 W 5911798.22 N 460304.35 E 3.000 106.42 1100.00 22.670 63.91 S 135.65 W 5911785.67 N 460270.47 E 3.000 141 .33 1150.00 24.163 70.71 S 154.31 W 5911778.97 N 460251.77 E 3.000 160.58 Continue Dir @ 4.00°/1 OOft : 1150.00t MD, 1126.06tt TVD 1200.00 26.051 .700 1017.44 1171.34 77.64 S 174.37 W 5911772.15 N 460231.68 E 4.000 181.22 -~. 1236.46 27.437 252.709 1050.00 1203.90 82.65 S 189.99 W 5911767.22 N 460216.03 E 4.000 1 97.27 Base Permafrost 1300.00 29.868 254.259 1105.75 1259.65 91.29 S 219.20 W 5911758.73 N 460186.78 E 4.000 227.19 1400.00 33.724 256.284 1190.73 1344.63 104.63 S 270.15 W 5911745.65 N 460135.75 E 4.000 279.22 1484.96 37.021 257.706 1260.00 1413.90 115.68 S 318.07 W 5911734.86 N 460087.78 E 4.000 328.00 Top West Sak 1500.00 37.606 257.935 1271 .96 1425.86 117.60 S 326.98 W 5911732.98 N 460078.86 E 4.000 337.06 1600.00 41 .508 259.319 1349.05 1502.95 130.12S 389.41 W 5911720.79 N 460016.37 E 4.000 400.42 a 1700.00 45.424 260.505 1421.61 1575.51 142.14S 457.12 W 5911709.12 N 459948.59 E 4.000 469.00 1800.00 49.351 261.540 1489.30 1643.20 153.61 S 529.80 W 5911698.04 N 459875.85 E 4.000 542.46 :::0 1900.00 53.286 262.460 1551.79 1705.69 164.45 S 607.09 W 5911687.60 N 459798.50 E 4.000 620.44 ----. 2000.00 57.228 263.290 1608.77 1762.67 174.63 S 688.62 W 5911677.85 N 459716.93 E 4.000 702.57 tT) ---..... ~C" --:: ~ r--- 20 May, 2001 -18:57 Page 2 of 10 Dril/Quest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Wellplan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eästings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 Daft) 2050.00 59.200 263.678 1635.11 1789.01 179.45 S 730.84 W 5911673.25N 459674.68 E 4.000 745.07 Continue Dir @ 4.000/100ft : 2050.00f MD, 1789.01ft TVD ~ 2100.00 60.937 264.822 1660.06 1813.96 183.78 S 773.95MI 5911669114 N 459631.55 E 4.000 788.39 2200.00 64.439 266.999 1705.94 1859.84 190.09 S . 86a.~6W 5911663.29 N 459542.91 E 4.000 877.19 2300.00 67.970 269.052 1746.28 1900.18 193.22 S .953'[98 W 59JJ660.64 N 459451.47 E 4.000 968.47 2400.00 71 .526 271 .005 1780.89 1934.79 193.16 S ..;t047:78W. 5911661 .20 N 459357.67 E 4.000 1061.80 2480.00 74.385 272.509 1804.34 1958.24 190.81I& 1124.22 W 5911663.95 N 459281.25 E 4.000 1137.62 End Dir, Start Sail @ 74.385° : 2480.00ft MD, 1958.24ft TVD 2500.00 74.385 272.509 1809.72 1963.62 1143.46 W 5911664.89 N 459262.01 E 0.000 1156.69 2600.00 74.385 272.509 1836.64 1990.54 1239.68 W 5911669.61 N 459165.82 E 0.000 1252.01 2601.34 74.385 272.509 1837.00 1990.90 1240.97 W 5911669.67 N 459164.53 E 0.000 1253.28 Base West Sak (WS1O) 2700.00 74.385 272.509 1863.56 201,,{,,46 .. 1335.90 W 5911674.33 N 459069.62 E 0.000 1347.33 2800.00 74.385 272.509 1890.47 20~y+.37 177.32 S 1432.11 W 5911679.05 N 458973.43 E 0.000 1442.65 2900.00 74.385 272.509 19~7è39.. . 207:,1 .29 173.10 S 1528.33 W 5911683.77 N 458877 .23 E 0.000 1537.97 3000.00 74.385 272.509 .1944,;31 ....2098.21 168.88 S 1624.55 W 5911688.49 N 458781.04 E 0.000 1633.29 3100.00 74.385 272.509. .1971,:22 2125.12 164.67 S 1720.76 W 5911693.21 N 458684.85 E 0.000 1728.61 3200.00 74.385 272,509 .. 1998:14 2152.04 160.45 S 1816.98 W 5911697.93 N 458588.65 E 0.000 1823.93 3300.00 . 74;385 .. 272.509 ..2025.06 2178.96 156.24 S 1913.20W 5911702.64 N 458492.46 E 0.000 1919.25 3400.00 74:385 272:509 2051.97 2205.87 152.02 S 2009.42 W 5911707.36 N 458396.27 E 0.000 2014.57 3500.00 74.385 . 272.509 2078.89 2232.79 147.81 S 2105.63 W 5911712.08 N 458300.07 E 0.000 2109.89 - 3600.00 'Z4.385 272:509 2105.81 2259.71 143.59 S 2201 .85 W 5911716.80 N 458203.88 E 0.000 2205.21 3700.00 74.385 272.509 2132.72 2286.62 139.37 S 2298.07 W 5911721.52 N 458107.69 E 0.000 2300.53 3750.00 74.385 272.509 2146.18 2300.08 137.27 S 2346.18 W 5911723.88 N 458059.59 E 0.000 2348.19 9-5/8" Casing Pt ... Drill out 8-1/2" HolE 9-5/8" Casing 3800.00 74.385 272.509 2159.64 2313.54 135.16 S 2394.28 W 5911726.24 N 458011.49 E 0.000 2395.85 3900.00 74.385 272.509 2186.56 2340.46 130.94 S 2490.50 W 5911730.96 N 457915.30 E 0.000 2491.17 a 4000.00 74.385 272.509 2213.47 2367.37 126.73 S 2586.72 W 5911735.68 N 457819.10 E 0.000 2586.49 4100.00 74.385 272.509 2240.39 2394.29 122.51 S 2682.94 W 5911740.40 N 457722.91 E 0.000 2681.81 :::t:J ~ ~ .,.# ~ ~.. ~~ - ~ r--- 20 May, 2001 - 18:57 Page 3 of 10 Dril/Quest 2.00.08.006 c ~ ~ C'::' ~c~ ~~-. <:.. ~~ r--- Kuparuk River Unit Measured Depth (ft) 4200.00 4300.00 4362.32 4400.00 4500.00 4548.08 4600.00 4680.00 4700.00 4800.00 4900.00 4919.29 5000.00 5100.00 5200.00 5300.00 5400.00 . 5500.00 5600.00 . 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 20 May, 2001 - 18:57 Incl. 74.385 74.385 74.385 74.385 74.385 74.385 74.385 74.385 74.358 74.268 74.256 74.263 74.263 74.263 74.263 74.263 7.4.263' . 74<263 '. . 74.263 74.263 74.263 74.263 74.263 74.263 74.263 74.263 74.263 74.263 74.263 74.263 Azim. 272.509 272.509 272.509 272.509 272.509 272.509 272.509 272.509 271 .679 267.525 263.369 262.567 262.567 262.567 '.' 262.'567 262. 262.567 . 262.567 . 262.567 262.567 262.567 262.567 262.567 262.567 262.567 262.567 262.567 262.567 262.567 262.567 Sub-Sea Depth (ft) 2267.31 2294.22 2311.00 2321.14 2348.06 2361.00 2374.97 2396.51 2401 .90 2428.95 2564.57 2591.69 2618.81 2645.93 2673.06 2700.18 2727.30 2754.42 2781.54 2808.67 2835.79 2862.91 2890.03 2917.15 2944.28 Vertical Depth (ft) 2421.21 2448.12 2464.90 2475.04 2501 .96 2514.90 2528.87 2550.41 2718.47 2745.59 2772.71 2799.83 2826.96 2854.08 2881.20 2908.32 2935.44 2962.57 2989.69 3016.81 3043.93 3071 .05 3098.18 Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Well plan Based on Nabors 16E RKB e/e. Revised: 20 May, 2001 Local Coordinates Northings Eastings (ft) (ft) 118.30 S 114.08 S 111 .45 S 109.86 S 105.65 S 105.66 S 107.94 S 117.99 S 130.44 S 142.89 S 155.34 S 167.79 S 180.24 S 192.69 S 205.14 S 217.59 S 230.05 S 242.50 S 254.95 S 267.40 S 279.85 S 292.30 S 304.75 S 317.20 S 329.65 S 2779.15 W 2875.37 W 2935.34 W 2971)59 W . 3067:80W 3114.0TW '3164.02 W 3240.99 W 3260.24 W 3356.49 W 3452.41 W 3470.84 W 3547.87 W 3643.32 W 3738.76 W 3834.20 W 3929.64 W 4025.09 W 4120.53 W 4215.97 W 4311.42 W 4406.86 W 4502.30 W 4597.75 W 4693.19 W 4788.63 W 4884.08 W 4979.52 W 5074.96 W 5170.40 W Page 4 of 10 Global Coordinates Northings I;astings (ft) (ft) . 5911745J 2 N 5911749.'83 N . 59117.52.78N 5911754.55N 5911759.27 N 5911761 .54 N 5911763.99 N 5911767.77 N 5911768.57 N 5911768.41 N 5911761 .27 N 5911759.09 N 5911749.45 N 5911737.50 N 5911725.54 N 5911713.59 N 5911701 .64 N 5911689.69 N 5911677.74 N 5911665.79 N 5911653.83 N 5911641.88 N 5911629.93 N 5911617.98 N 5911606.03 N 5911594.08 N 5911582.13N 5911570.17 N 5911558.22 N 5911546.27 N 457626.72 E 457530.52 E 457470.57 E 457434.33 E 457338.14 E 457291 .88 E 457241 .94 E 457164.99 E 457145.74 E 457049.49 E 456953.53 E 456935.10 E 456858.01 E 456762.50 E 456666.99 E 456571 .49 E 456475.98 E 456380.47 E 456284.97 E 456189.46 E 456093.95 E 455998.45 E 455902.94 E 455807.43 E 455711 .93 E 455616.42 E 455520.91 E 455425.41 E 455329.90 E 455234.39 E Dogleg Rate (0/100ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 2777.14 2872.46 2931.86 2967.78 3063.10 3108.93 3158.42 3234.67 3253.76 3349.59 3445.80 3464.36 3542.01 3638.22 3734.43 3830.64 3926.84 4023.05 4119.26 4215.47 4311.68 4407.89 4504.09 4600.30 4696.51 4792.72 4888.93 4985.14 5081.34 5177.55 North Slope, Alaska Kuparuk 2N Comment C80 (K1 0) --- Camp SS Begin Dir @ 4.000/100ft : 4680.0Oft MD, 2550.41ft TVD End Dir, Start Sail @ 74.263° : 4919.29ft MD, 2615.21ft TVD ---. DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Well plan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6800.00 74.263 262.567 2971.40 3125.30 342.10 S 5265.85 W 5911534.32 455138.88 E 0.000 5273.76 6900.00 74.263 262.567 2998.52 3152.42 354.56 S 5361 .29 W 5911522.37 455043.38 E 0.000 5369.97 "-" 7000.00 74.263 262.567 3025.64 3179.54 367.01 S 5456.73 W - 5911510.42 N 454947.87 E 0.000 5466.18 7100.00 74.263 262.567 3052.76 3206.66 379.46 S 5552.18W 5911498;46 N 454852.36 E 0.000 5562.38 7200.00 74.263 262.567 3079.88 3233.78 391.91 S 5647.62W - 5911486.51 N 454756.86 E 0.000 5658.59 7300.00 74.263 262.567 3107.01 3260.91 5743iO6W 5911474.56 N 454661.35 E 0.000 5754.80 7400.00 74.263 262.567 3134.13 3288.03 5838:51 W 5911462.61 N 454565.84 E 0.000 5851.01 7500.00 74.263 262.567 3161.25 3315.15 5933.95 W 5911450.66 N 454470.34 E 0.000 5947.22 7600.00 74.263 262.567 3188.37 3342.27 6029.39 W 5911438.71 N 454374.83 E 0.000 6043.43 7700.00 74.263 262.567 3215.49 3369.39 6124.83 W 5911426.76 N 454279.32 E 0.000 6139.63 7800.00 74.263 262.567 3242.62 S 6220.28 W 5911414.80 N 454183.82 E 0.000 6235.84 7900.00 74.263 262.567 3269.74 479.07 S 6315.72 W 5911402.85 N 454088.31 E 0.000 6332.05 8000.00 74.263 262.567 3296.86 491.52 S 6411.16W 5911390.90 N 453992.80 E 0.000 6428.26 8100.00 74.263 262.567 3323:98 -.-. 503.97 S 6506.61 W 5911378.95 N 453897.30 E 0.000 6524.47 8200.00 74.263 262.567 3351.10 516.42 S 6602.05 W 5911367.00 N 453801.79 E 0.000 6620.68 8300.00 74.263 262¡567 3532.13 528.87 S 6697.49 W 5911355.05 N 453706.28 E 0.000 6716.88 8400.00 74.263 262.567- 3559.25 541.32 S 6792.94 W 5911343.09 N 453610.77 E 0.000 6813.09 -- 8500.00 74 .263 262.5671 - 3432.47 3586.37 553.77 S 6888.38 W 5911331.14 N 453515.27 E 0.000 6909.30 8600.00 74;263 -_2621567 3459.59 3613.49 566.22 S 6983.82 W 5911319.19 N 453419.76 E 0.000 7005.51 8667\88 - 74:263 - - 262[C567 3478.00 3631.90 574.67 S 7048.61 W 5911311.08 N 453354.93 E 0.000 7070.81 C50 ~--. 8700.00. 74:263 - - 262.567 3486.71 3640.61 578.67 S 7079.27 W 5911307.24 N 453324.25 E 0.000 7101.72 8800.00 74.263 262.567 3513.83 3667.73 591.12 S 7174.71 W 5911295.29 N 453228.75 E 0.000 7197.92 8900.00 74.263 262.567 3540.96 3694.86 603.58 S 7270.15 W 5911283.34 N 453133.24 E 0.000 7294.13 9000.00 74.263 262.567 3568.08 3721 .98 616.03 S 7365.59 W 5911271.39 N 453037.73 E 0.000 7390.34 9100.00 74.263 262.567 3595.20 3749.10 628.48 S 7461.04 W 5911259.43 N 452942.23 E 0.000 7486.55 9200.00 74.263 262.567 3622.32 3776.22 640.93 S 7556.48 W 5911247.48 N 452846.72 E 0.000 7582.76 C) 9300.00 74.263 262.567 3649.44 3803.34 653.38 S 7651.92 W 5911235.53 N 452751.21 E 0.000 7678.97 9353.67 74.263 262.567 3664.00 3817.90 660.06 S 7703.15 W 5911229.12 N 452699.95 E 0.000 7730.60 C40 (K5) ::x::J 9400.00 74.263 262.567 3676.57 3830.47 665.83 S 7747.37 W 5911223.58 N 452655.71 E 0.000 7775.17 9500.00 74.263 262.567 3703.69 3857.59 678.28 S 7842.81 W 5911211.63 N 452560.20 E 0.000 7871.38 - --- ~ ~-. """"--"'0 -==:::: ~- 20 May, 2001 - 18:57 Page 5 of 10 DrillQuest 2.00.08.006 r--= Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Wellplan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 0 Oft) 9600.00 74.263 262.567 3730.81 3884.71 690.73 S 452464.69 E 0.000 7967.59 9700.00 74.263 262.567 3757.93 3911 .83 703.18 S 452369.19 E 0.000 8063.80 ......~-- 9800.00 74.263 262.567 3785.05 3938.95 715.64 S 452273.68 E 0.000 8160.01 9855.11 74.263 262.567 3800.00 3953.90 722.50 S 452221.04 E 0.000 8213.03 C37 9900.00 74.263 262.567 3812.17 3966.07 728.09 S 452178.17 E 0.000 8256.22 10000.00 74.263 262.567 3839.30 740.54 S 1151.87 N 452082.66 E 0.000 8352.42 10100.00 74.263 262.567 3866.42 752.99 S 5911139.92 N 451987.16 E 0.000 8448.63 10200.00 74.263 262.567 3893.54 765.44 S 5911127.97 N 451891.65 E 0.000 8544.84 10300.00 74.263 262.567 3920.66 777.89$ 5911116.02 N 451796.14 E 0.000 8641.05 10400.00 74.263 262.567 3947.78 790.34.'£ 5911104.06 N 451700.64 E 0.000 8737.26 10500.00 74.263 262.567 802.79 S 8797.24 W 5911092.11 N 451605.13 E 0.000 8833.46 10600.00 74.263 262.567 815.24 S 8892.68 W 5911080.16 N 451509.62 E 0.000 8929.67 10700.00 74.263 262.567 827.69 S 8988.13 W 5911068.21 N 451414.12 E 0.000 9025.88 10800.00 74.263 262.567 840.15 S 9083.57 W 5911056.26 N 451318.61 E 0.000 9122.09 10900.00 74.263 262.567 852.60 S 9179.01 W 5911044.31 N 451223.10 E 0.000 9218.30 4253.90 860.22 S 9237.45 W 5911036.99 N 451164.62 E 0.000 9277.20 Iceberg 4264.42 865.05 S 9274.46 W 5911032.36 N 451127.60 E 0.000 9314.51 4291 .54 877.50 S 9369.90 W 5911020.40 N 451032.09 E 0.000 9410.71 4318.66 889.95 S 9465.34 W 5911008.45 N 450936.58 E 0.000 9506.92 4345.78 902.40 S 9560.78 W 5910996.50 N 450841 .07 E 0.000 9603.13 ~. 11400.00 74.263 262.567 4219.00 4372.90 914.85 S 9656.23 W 5910984.55 N 450745.57 E 0.000 9699.34 11500.00 74.263 262.567 4246.12 4400.02 927.30 S 9751.67 W 5910972.60 N 450650.06 E 0.000 9795.55 11600.00 74.263 262.567 4273.25 4427.15 939.75 S 9847.11 W 5910960.65 N 450554.55 E 0.000 9891.75 11650.00 74.263 262.567 4286.81 4440.71 945.98 S 9894.84 W 5910954.67 N 450506.80 E 0.000 9939.86 7" Casing Pt ... OriIl6-1/8" Hole to TO 7" Casing 11650.71 74.263 262.567 4287.00 4440.90 946.07 S 9895.51 W 5910954.59 N 450506.12 E 0.000 9940.54 T7 11700.00 74.263 262.567 4300.37 4454.27 952.20 S 9942.56 W 5910948.69 N 450459.05 E 0.000 9987.96 C 11800.00 74.263 262.567 4327.49 4481.39 964.66 S 10038.00 W 5910936.74 N 450363.54 E 0.000 10084.17 11900.00 74.263 262.567 4354.61 4508.51 977.11 S 10133.44 W 5910924.79 N 450268.03 E 0.000 10180.38 ::0 12000.00 74.263 262.567 4381.73 4535.63 989.56 S 10228.89 W 5910912.84 N 450172.53 E 0.000 10276.59 ........... 12100.00 74.263 262.567 4408.86 4562.76 1002.01 S 10324.33 W 5910900.89 N 450077 .02 E 0.000 10372.80 ~ ......... ~ 20 May, 2001 - 18:57 Page 6 of 10 DrillQuest 2.00.08.006 r--- Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Wellplan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea!ijtings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12200.00 74.263 262.567 4435.98 4589.88 1014.468 10419.77 W 5910888.94 N 449981.51 E 0.000 10469.00 12300.00 74.263 262.567 4463.10 4617.00 1026.91 8 10515.22 W 59t0876.99 N 449886.01 E 0.000 10565.21 --~ 12400.00 74.263 262.567 4490.22 4644.12 1039.36 8 10610.66 W 5910865.03 N 449790.50 E 0.000 10661.42 12500.00 74.263 262.567 4517.34 4671 .24 1051.81 8 1 0706.1 O..w 591085æ08 N 449694.99 E 0.000 10757.63 12600.00 74.263 262.567 4544.47 4698.37 1 064.26 8 10801 .54W 59j0841.13 N 449599.49 E 0.000 10853.84 12700.00 74.263 262.567 4571 .59 10896;99 W 5910829.18 N 449503.98 E 0.000 10950.05 12800.00 74.263 262.567 4598.71 10992.43W 5910817.23 N 449408.47 E 0.000 11046.25 12900.00 74.263 262.567 4625.83 11087.87 W 5910805.28 N 449312.96 E 0.000 11142.46 13000.00 74.263 262.567 4652.95 11183.32 W 5910793.33 N 449217.46 E 0.000 11238.67 13073.91 74.263 262.567 4673.00 11253.86 W 5910784.49 N 449146.86 E 0.000 11309.78 T3.1 13100.00 74.263 262.567 4680.07 11278.76 W 5910781.37 N 449121.95 E 0.000 11334.88 13136.60 74.263 262.567 4690.00 11313.69 W 5910777 .00 N 449087.00 E 0.000 11370.09 T3 Target - T1 (2N-350), 100.00 Radius., Geological 13200.00 74.263 4861.10 1138.978 11374.20 W 5910769.42 N 449026.44 E 0.000 11431.09 13300.00 74.263 4888.22 1151.428 11469.65 W 5910757.47 N 448930.94 E 0.000 11527.29 13400.00 74.263 4915.34 1163.87 S 11565.09 W 5910745.52 N 448835.43 E 0.000 11623.50 4788.56 4942.46 1176.328 11660.53 W 5910733.57 N 448739.92 E 0.000 11719.71 4790.00 4943.90 1176.988 11665.59 W 5910732.93 N 448734.86 E 0.000 11724.81 T2 4815.68 4969.58 1188.778 11755.98 W 5910721.62 N 448644.42 E 0.000 11815.92 ..--... 4819.00 4972.90 1190.30 8 11767.64 W 5910720.15 N 448632.74 E 0.000 11827.68 C35 (K3) 4842.81 4996.71 1201.228 11851.42 W 5910709.66 N 448548.91 E 0.000 11912.13 74.263 262.567 4869.93 5023.83 1213.688 11946.86 W 5910697.71 N 448453.40 E 0.000 12008.34 13900.00 74.263 262.567 4897.05 5050.95 1226.138 12042.30 W 5910685.76 N 448357.90 E 0.000 12104.54 14000.00 74.263 262.567 4924.17 5078.07 1238.58 8 12137.75 W 5910673.81 N 448262.39 E 0.000 12200.75 14100.00 74.263 262.567 4951.29 5105.19 1251 .03 8 12233.19 W 5910661 .86 N 448166.88 E 0.000 12296.96 14112.00 74.263 262.567 4954.55 5108.45 1252.52 8 12244.64 W 5910660.42 N 448155.42 E 0.000 12308.51 Total Oepth: 14112.00ft MO, 5108.45- C TVO 4-1/2" Liner :::t:J ~~.c ~:>- -..,.~ ~ <:.;~ ~. 20 May, 2001 - 18:57 Page 7 of 10 DrillQuest 2.00.08.006 ~. C ::0 ........... G:) ........... 5;: r--- Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Wellplan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 Kuparuk River Unit All data is in Feet (US) unless otherwise stated. Oirections and coordinates are relative to True North. Vertical depths are relative to RKB = 153.9' MSL. Northings and Eastings are relative to 161' FNL & 1186' FEL. The Oogleg Severity is in Oegrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 264.291 ° (True). Based upon Minimum Curvature type calculations, at a Measured Oepth of 14112.00ft., The Bottom Hole Oisplacement is 12308.54ft., in the Oirection of 264.159° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Easti (ft) (ft) ent 0.00 300.00 450.00 1150.00 2050.00 SHL: Y = 5911848.87' & X= 460406.45' (161' FNL & 1186" FELt SEC. 3-T9N-R7E) Begin Oir @ 2.500/100ft (in 12-1/4" Hole) : 300.00ft MO, 300.00ft TVO Continue Oir @ 3.000/100ft : 450.00ft MO, 449.89ft TVO Continue Oir @ 4.00°/1000 : 1150.00ft MO, 1126.06ft TVO Continue Oir @ 4.00°/1000: 2050.00ft MO, 1789.01ft TVO 1124.22 W 2346.18 W 3240.99 W 3470.84 W 9894.84 W End Oir, Start Sail @ 74.385° : 2480.00ft MO, 1958.24ft TVO 9-5/8" Casing Pt ... Orill out 8-1/2" Hole Begin Oir @ 4.00°/1000: 4680.00ft MO, 2550.41ft TVO End Oir, Start Sail @ 74.263° : 4919.29ft MO, 2615.21ft TVD 7" Casing Pt ... Orill 6-1/8" Hole to TO 1252.52 S Total Oepth : 14112.00ft MO, 5108.45ft TVO 12244.64 W North Slope, Alaska Kuparuk 2N -- ~- 20 May, 2001 - 18:57 Page 8 of 10 DrillQuest 2.00.08.006 C ::0 ---- t7:) ---- ~ r--- Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Well plan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northin9s (ft) 1050.00 1260.00 1 837.00 2311.00 2361.00 1203.90 1413.90 1990.90 2464.90 2514.90 1050.00 1260.00 1837.00 2311.00 .00 4673.00 4690.00 4790.00 4819.00 574.67 S 660.06 S 722.50 S 860.22 S 946.07 S 7048.61 W 7703.15 W 8181.74W 9237.45 W 9895.51 W North Slope, Alaska Kuparuk 2N --- Base Permafrost Top West Sak Base West Sak (WSlO) C80 (K1 0) CampSS C50 C40 (K5) C37 Iceberg T7 1123.27 S 1131.08 S 1176.98 S 1190.30 S 11253.86 W T3.1 11313.69W T3 11665.59 W T2 11767.64 W C35 (K3) Page 9 of 10 0.000 359.700 0.000 359.700 0.000 359.700 0.000 359.700 0.000 359.700 1236.46 1484.96 2601 .34 4362.32 4548.08 3478.00 3664.00 3800.00 4100.00 4287.00 0.000 359.700 0.000 359.700 0.000 359.700 0.000 359.700 0.000 359.700 4673.00 4690.00 4790.00 4819.00 20 May, 2001-18:57 DrillQuest 2.00.08.006 C ::0 ........... G:) ........... §: r--- Kuparuk River Unit Casing details Fro m Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this well path Target Name T1 (2N-350) To Measured Vertical Depth Depth (ft) (ft) 3750.00 11650.00 14112.00 2300.08 4440.71 5108.45 Sperry-Sun Drilling Services Proposal Report for 2N-350 Wp02 Your Ref: Well plan Based on Nabors 16E RKB ele. Revised: 20 May, 2001 Casing Detail 9-518" Casing 7" Casing 4-1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 4843.90 4690.00 1131.08 S 11313.69 W 5910777.00 N 449087.00 E 700 10' 01.1672" N 1500 24' 34.8732" W North Slope, Alaska Kuparuk 2N ( Target Target Shape Type Circle Geological 100.00ft ( '.-.-'.-.---...--.--..'_._0-_--.-.---------..---.....-----..----.------------.--..--.----...--.--..------.-----..---.-----.---.-----..-..---------------.------.--.-.-.--.---.-..-__M___.__' 20 May, 2001 - 18:57 Page 10 of 10 DrillQuest 2.00.08.006 1500 ..c ã. Q) 0 ëõ 2 3000 êi5 > 4500 ~rillQuest 2.00.08.006 Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit Tarn (2N Pad) 2N-350 (wp02) RKB Elevation: North Reference: Units: .-- Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 2N-350 5911848.87 N, 460406.45 E 93.24 S, 393.76 W 700 10' 12.3757" N, 1500 19' 07.1355" W 161' FNL & 1186' FEL, Sec. 3 - T9N - R7E 153.9Oft above Mean Sea Level True North Feet (US) SHL: Y = 5911848.87' & X= 460406.45' (161' FNL & 1186" FEL, SEC. 3 - T9N - R7E) 0 Begin Dir @ 2.50"J100ft (in 12-114" Hole) : 300.000 MD, 300.00ft TVD Continue Dir @ 3.000/100ft : 450.00ft MD, 449.89ft TVD Continue Dir @ 4.00"/100ft : 1150.00ft MD, 1126.06ft TVD ~ontinue Dir @ 4.000/100ft: 2050.00ft MD, 1789.01ft TVD End Dir, Start Sail @ 74.385° : 2480.000 MD, 1958.24ft TVD ..~~5¿8"Çéisi ngpt .. . prill outß~1J2 "nlj()le egin Dir @ 4.00°/1000 : 4680.00ft MD, 2550.41ft TVD End Dir, Start Sail @ 74.263° : 4919.29ft MD, 2615.21ft TVD ,o.ifJ .-'. spar' r'\j-5.U I! gJ:!IL~) f!.I f3-:-'S. EFf\Tr~e"s A H:1lhburton C.omp.3rt)' .-.. T! r2N-35fJ) (;. .J84.1.9fJ JT/). 113jJ),\j S ,\- J JJU.(;f)' n ilJ.'.jffJ, .'òoo.ifJ UfJJ' F:\l. & JW{'¡'Ff.. '~ \ec .:; - flJS - {(7F ~çß.ifJ 7' Casing . ,., / . 2""35, ifJ 11650.00' MD / 0 WpO \'/.çß. 4440.71' TVD 2 ~OifJ.ifJ // 7" Casing Pt ... Drill 6-1/8" Hole to TO . ... . '/.'òifJ.ifJ ,/ ~'Ý>(fJ,ifJ /' 4.1/2' Liner 14112.00' MD 5108.45' TVD 0 1500 3000 6000 7500 4500 Scale: 1 inch = 1500ft 9000 10500 12000 ale1Tln~-- 20Mny.zrX>1-2':23 -1 500 -3000 Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit Tarn (2N Pad) 2N..350 (wp02) N (-j~; Reference is True North -12000 -10500 -9000 -7500 -6000 1500 Tl (2N-350¡ ({y 4SJ3.90 TVD.< 113I.fJ8' S &- ! 1313.69' 'W o{SHL DOl' PYL & 1941' FEL. Sec. 5 - T9N - R7E Well: Current Well Properties ------.------.-..-... ..-..----'-'.--. 2N-350 Horizontal Coordinates: Ref. Global Coordinates: 5911848.87 N, 460406.45 E Ref. Structure: 93.24 S, 393.76 W Ref. Geographical Coordinates: 700 10' 12.3757" N. 1500 19' 07.1355" W 161' FNL & 1186' FEL, Sec. 3 - T9N - R7E RKB Elevation: North Reference: Units: 153.90ft above Mean Sea Level True North Feet (US) SpE!r'r'Y-SUIl Q~2hb~!~~§_.=-~._~- RSt[Çj;;js A ttaliiburton c.ompa",)' ~. -4500 -3000 -1 500 0 3aoo. ¡;u -1 500 1500 End Dir, Start Sail @ 74.263° : 4919.29ft MD, 2615.21ft Begin Dir @ 4.00°/1000 : 4680.000 MD, 2550.41ft TVD t'% U 7' Casing 11650.00' MD 4440.71' TVD .-e 4Soo.. 4<!o.o.¡;u ZN-350 W~ 3~o.¡;u 3600.'00 7" Casing Pt ... Drill 6-1/8" Hole to TD -12000 -7500 -6000 -10500 -9000 DrillQuest 2.00.08.006 Scale: 1 inch = 1500ft 0 3oa0..00 ~ End Dir, Start Sail @ 74.385° : 2480.000 MD, 1958.24ft TVD -3000 -4500 -3000 -1 500 0 Prepared by: Dave Egedahl DalefTin-e: 20 May, 2001 - 22:00 C :::x:J .......... ~ ---- ~ r--- Kuparuk River Unit 2N-350 (wp02) ,Çomment (°/1 OOft: (ft) 0.00 0.00 0.00 -153.90 0.00 0.00 N 0.00 E 5911848.87 N 460406.45 E 0.00 SHL 300.00 0.00 0.00 146.10 300.00 0.00 N 0.00 E 5911848.87 N 460406.45 E 0.00 0.00 Begin Dir (12-1/4" Hole) I .-- 450.00 3.75 220.00 295.99 449.89 3.76 S 3.15 W 5911845.13 N 460403.28 E 2.50 3.51 Continue Dir 1150.00 24.16 250.14 972.16 1126.06 70.71 S 154.31 W 5911778.97 N 460251.77 E 3.00 160.58 Continue Dir 2050.00 59.20 263.68 1635.11 1789.01 179.45 S 730.84 W 5911673.25 N 459674.68 E 4.00 745.07 Continue Dir 2480.00 74.39 272.51 1804.34 1958.24 190.81 S 1124.22 W 5911663.95 N 459281.25 E 4.00 1137.62 End Dir, Start Sail 74.39 272.51 2146.18 2300.08 137.27 S 2346.18 W 5911723.88 N 458059.59 E 0.00 2348.19 9-5/8" Csg Pt, Drill 8-1/2" Hole 4680.00 74.39 272.51 2396.51 2550.41 98.06 S 3240.99 W 5911767.77 N 457164.99 E 0.00 3234.67 Begin Dir 4919.29 74.26 262.57 2461.31 2615.21 107.94 S 3470.84 W 5911759.09 N 456935.10 E 4.00 3464.36 End Dir, Start Sail 74.26 262.57 4286.81 4440.71 74.26 252.57 4590.00 14112.00 74.26 262.57 4954.55 5108.45 1252.52 S 12244.64 W 5910660.42 N 448155.42 E 0.00 12308.51 Total Depth 4843.90 945.98 S 9894.84 W 5910954.67 N 450506.80 E 0.00 9939.86 7" Csg Pt, Drill 6-1/8" Hole 1131 . De s 11313J39 W 59î0777.00 N ~ 449087.00 E 11370.09 T3! Target - T1 0.00 I( Sperry-SUD Anticollision Report I Compan~': Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 2N Pad Plan 2N-350 2N-350 Date: 5/20/2001 Time: 18:30:37 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan 2N-350, True North Nabors 16E Rig @ 2N-350 153.9 Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cytinder North Ellipse + Casing GLOBAL SCAN APPLIED: All wellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.00 ft Depth Range: 153.90 to 14112.00 ft Maximum Radius: 1595.81 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Well path Date: 4/10/2001 Validated: No Planned From To Survcy ft ft 153.90 800.00 800.00 14112.00 Planned: 2N-350 WP02 V1 Planned: 2N-350 WP02 V1 5 Version: Toolcode Tool Name Casing Points CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MO TVD ft ft -- 269.30 269.30 13590.05 4965.73 Diameter in Hole Size in Name 13.375 4.500 17.500 6.000 Case2 51/2" -- Summary <---------------------- Offset Wellpath ----------------------> Site Well Wellpath Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad 2N-329 2N-331 2N-332 2N-332 2N-335 2N-337 2N-337 2N-339 2N-341 2N-343 2N-345 2N-347 2N-347 2N-347 2N-349 2N-349 Plan 2N-348 Reference Offset Ctr-Ctr No-Go Allowable MO MO Distance Area Deviation Warning ft ft ft ft ft 300.00 300.00 315.47 4.26 311.21 Pass: Major Risk 1163.00 1300.00 256.90 20.16 237.40 Pass: Major Risk 1184.00 1300.00 223.13 23.54 202.35 Pass: Major Risk 1184.00 1300.00 223.13 23.54 202.35 Pass: Major Risk 299.98 300.00 225.69 4.33 221.36 Pass: Major Risk 576.47 600.00 197.79 8.09 189.84 Pass: Major Risk 576.47 600.00 197.79 8.09 189.84 Pass: Major Risk 299.99 300.00 166.14 4.35 161.79 Pass: Major Risk 2158.00 2200.00 148.28 75.49 76.36 Pass: Major Risk 253.90 105.10 104.91 3.08 101.83 Pass: Major Risk 300.00 300.00 74.57 4.36 70.21 Pass: Major Risk 593.58 600.00 43.92 8.07 36.07 Pass: Major Risk 593.58 600.00 43.91 8.24 35.93 Pass: Major Risk 593.59 600.00 43.79 8.08 35.95 Pass: Major Risk 498.78 500.00 14.12 6.17 8.05 Pass: Major Risk 498.78 500.00 14.12 6.17 8.05 Pass: Major Risk 497.65 500.00 30.94 7.23 23.74 Pass: Major Risk '-------'--'----"-'----'-'-""----"--------~----,--._._--~----_._-_.,_._---_._--------_..- 2N-329 V2 2N-331 V2 2N-332 V4 2N-332PB1 V3 2N-335 V2 2N-337 V1 2N-337 A V1 2N-339 V8 2N-341 V1 2N-343 V4 2N-345 V1 2n-347 testa VO 2N-347 V1 2n-347testn VO 2N-349 V1 2N-349A V1 Plan 2N-348 V4 Plan: 2 ORIGINAL WBl.. DETAILS A,,-TI-COLLISION SETTINGS \'aJre +NI.S Interpolation MethodMO Interval: 50.00 o"pth Range From: 153.90 To: 141I2.<XJ Maximum Range: 1595.81 Reference: Plan: 2N-350 WP02 +I'l-W Nl.¡iJmg EasÜ!1g Latiudc Long~ude Sbl Pkn 1N-350 -124.05 -525.21 5911>!4K87 4f,<}JlliA5 70'11JJ2376N ISO'1907.13SW NJA 371 Colour 300 ~~ ~-.. ~*~/.- ~/ -'.\" "I í ,.\.'~ /"" ::~~ (~'NI1j!l; 200 100 0 90 . ... . n__.___- 100 \" !;' '* ü' ",t. 'i.r- ~\.J ',-"Z J~ 0t. 'i.-/ ,'y ~ -z, 200 300 ~ : ì?:'~."._-..,--- . '''"i, :...-- . --- '... . ..~=. . ...- 'õ""" ....-. 371 i ~! i ~ \"" ~~ I J ~¿.\ j i I J Trave]jng Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] COMPAl',y DEI All.S WalPATH DET"".s 21'..'50 1).)J,h Fin Depth T" Surn'1/PIaJl P~s Ahska In.;. F.ngi1eering Kuparuk CakubliJn Me~Jd: Minã1mm Cun"3turc F_ITor SYS!cm: ISCWSA Scan ~~~: ~~'.~~:rnd~ ~Ith Rig: eL Datum: Na~t)r.; IN: Rig (tf 2N-3~) '<'<J(.~l~: .;(.J.fO Plmncú: 2N .,.c:,O WI'I12 VI l'¡IJ2.lX) PLUHk"¡" 2N-_"OWPlIZ VI V.SocliJß Angl: 2M.16. ~~ Origin .\'l.W 0.00 Star1il1~ FllImnlJ 1S~.1.}f) WamEg ~1ctOC.d: Rule> fu,oo 0.00 0 '35 30 20 10 0 27 10 20 30 :35 'tc.lh..-..J 11)-; >,J\"C F}:t.,l.Jhl 'h:dL\1 \PI',uwJ. Sl'RVI:Y I'R(X;RAM 1'",,1 II eß (;YRO SS M\\lh1l'R..\K-C,\Z.SI I From Colour To MD 15-1 - SOO suo - 1000 I O(O 2 ()()( 2(X)O - 3(XJO 3(X)O -teXJO 4(X)0 - 5(X)O 5fX)O (,IXJO (,(X)O - 7(X)1I 7(X)O - !HXJO 2~WI¡ (2N-3-1())\) (}()Oll . 'J1)('¡(1 lCXIOO I()(X)O - 110110 , ()O - 12000 J IJOI)() 1-1000 15000 16000 I I ~J- 1 Plan 2N-3-1X :)0 ~l JILIn: ZN..~:'-(J \VI'U2 f..kln 2N..~.c;(~N l~) 1>,11c:."i!2h'1fU. Travelling Cylinder Azimuth (TFO+AZi) [deg] vs Ccntrc to Ccntrc Separation [20fllin] LEGEND 2N-32;; ... 9). ~fu.'pr Rfok - 2N.3.\! .. "I).MaFrR~k 2N-532:: ... - .2). Maj-H Ri;k 2N-33¡ - ~' - ,2PBl), Ma~Jr Ri-k ............... 2N-J.J.5; -, . -5i- Mapr Rio;.k 2N-33i ... .7). AbjH Ri->k ~ 2N-33; ~. - .7Aj, Mapc ltiõk 21'-339 ',. .9). Mapr R~k - 2N-3-t1 - .... - ~]). MajH Rir;;k 2N-34:- ... ~3). ~ia.þr Rf>k -- 2N-J4~ - "''1 - ~5). MaJ:Jr Rt;k - 2N--:.4i .:1 (estol. Mapr Rfo¡k - 2N-3-!;. ... ~7). Ma;'1r Rr-k - 2N-~; "7Iest.1).Maj.JrRisk - 2N-34o;;. ... - ~9). Mapr Rr-k - 2N-}4Ç ..... ,9Aj. It-L"1þI Rj;;k - Pill 2~. - :'Ill 21'1-348). Maior R~k SITllON !JET,\IIS TVI> +~.") MD Inç Src /vj 15.\.9(1 1O:U)f} '¡'¡~H9 1I2b.lY, 17,;'1.01 195X.24 z~~n.11 2~1,.17 4S4).')(} 5IOS.IJ cu.) oeo 0_01) oto -.~.ï(l -~.1'') .711.7/ .,~ .II .17\J.,1tii -714UW -II}O.XI -112.s~~ .QS.IY, Q..III.91J fl7.Y2 .. '-170..70 IIW..~J 11:I1-I<¡< .)251.(,2 -122J.1.XC¡ 1:".1.90 f).(X} O.il) .1,00.00 O.c.-J 0.00 3 4:"0.00 :..7~ 2ZO.I.~) ~ 1150.00 24./(, 2."O.I, 5 1050.00 59.20 l{¡\J~ 6 24&>.00 7LW ~7.2.SI 7 .\óHO.OO 701.,9 272.51 X 4919.14 701.27 26257 () 1.1137.h5 74_27 2f>:!.5i7 1('1 14112.00 7~.27 26257 .¡.I~-W I>I.L'!! IT,u:c \'.';\"1,; T,u~c{ O,t, (IIX) fI.ft) flUI 2.'iU 2211.m J.m .11m .1.t:O :!O.f.i) I.no -'0.0.) 00.) I),{,) .1 (., 1/2 I)') fun 0.(0 nUl fJ,IX) UJ..) f{~~ (1J7I 7,lj..~) 11.'7.)1,1) .\2.li.1h ~1{¡l.M 11.171.17 TI f2~.'5~IJ 11~OXRci 2N-l JO Drillin~ Hazards 511 ~marv (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) 12-1/411 Hole /9-5/8" Casina Interval Event Conductor Broach Well Collision Running Coal and Gravel Shaker/Trough Cuttings S stem Overflow Gas Hydrates Risk Level Low Moderate Low Low Moderate Low 8-1/2" Hole /7" Casina Interval Event Sticky clay and tight hole first 2000' below shoe Hole cleaning in long, high an Ie tan ent Swabbing Camp sands durin tri Elevated pressure in sand lenses in Iceberg Thick, low pH mud during trips Risk Level Moderate Moderate Moderate High Moderate 6-1/8" Hole / 4-1/2" Liner Interval Event Hole cleaning and high ECD in hi h an Ie hole Swab 1 sur e Differential sticking Risk Level Moderate Low Moderate M iti ation Strate Set 120' of conductor. Monitor cellar continuousl durin interval Careful well planning, surveys (Cazandra and IFR corrections), adherence to anti-collision olic Elevated mud viscosity from spud and high densit swee s Controlled ROP Mud gas detection, controlled drilling, increased mud weights, lower viscosity, cold make-u water, and re-treat with lecithin Reduced pump rates, and lightweight tail cement M iti ation Strate Attention to hole cleaning and wiper trips using PWD to monitor Good drilling practices, circulate 3-4 bottoms u rior to tri s, and mud lubes Mud weight at 9.6 ppg by cao marker, control tri seed, flow checks Well path intersects Iceberg 4000' west of potential problem, frequent flow checks while drillin interval, bar on location to wei ht u . Displace well with 11 pH mud prior to POH. Circulate bottoms up at +1-500' below Camp sands when RIH. Miti ation Strate Good drilling practices and sweeps, using PWD to monitor Monitor PWD and um Irotate out on tri s Good drilling practices, mud lubes, keep string movin , avoid sto in wi BHA across sands 2N-350 Drilling Hazards Summary. doc 08/20/01 ORIGTNÃL ( 2N-350 Injector' Proposed Completion Schematic 16" 62.58# B @ +/- 153' MO Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 3750' MO I 2300' TVO) Intermediate csg. 7" 26.0# L-80 BTCM (+/- 11,650' MD / 4441' TVD) Future Perforations Production Liner 4-1/2" 12.6# L-80 NSTC (+1- 14,112' MD 15108' TVO) ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 BTC-MOO pin down 4-1/2" 12.6# L-80 BTC-MOO Spaceout Pups as Required ~~¡ 4-1/2" 12.6# L-80 BTC-MOO Tubing to Surface 4-1/2" Camco 'DB-6' nipple wi 3.875" Top No-Go Profile. 4-1/2" x 6' L-BO BTC-MOO pup installed above and below, set at +1- 500' MO 4-1/2" 12.6# L-BO BTC-MOD tubing to landing nipple 41/2" GLM Placement TBD ¡.' "~!M. 4-1/2" Camco 'DB-6' nipple w/ 3.812" Top No-Go profile. 4-1/2" x 6' L-BO BTC-MOD handling pups installed above and below 1 jt 4-1/2" 12.6# L-80 BTC-MOO tubing 4-1/2" Baker GBH-22 locator tbg seal assembly w/1?' stroke, 4-1/2" L-80 BTC-MOO box up Liner Assemblv (run on drillDiDe), set @ +1- 11.350' MO Liner will use 4-1/2" L-80 tubing with NSTC connections Baker 5" x 7" "ZXP' Liner Top Isolation Packer with C-2 profile w/1?' Tie back Recl Setting Sleeve Baker 5" x 7" 'HMC' Liner Hanger XO Sub, 5" Stub Acme box x 4-1/2" NSCT 4-1/2" 12.6# L-80 NSCT liner as needed 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 tubing 4-1/2" Baker Float Collar 1 jt 4-1/2" 12.6# L-80 tubing 4-1/2" Baker Float Shoe O¡UG1 N A L ( (. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAMEJf£t¡ 2¡{j-.~S- ò CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL V INJECTION WELL REDRILL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNULAR DISPOSAL <->NO ANNUL~~,SAL ~S ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHE ANNULU~ / ~YES+ SPACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated. . . Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME.ZU -3 .:)"Ò PROGRAM: exp - dev - redrtl - serv FIELD & POOL !j c¡ (') / r; S INIT CLA S GEOl AREA S? /' ¡j UNIT# ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. lease number appropriate. .. . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool. ... . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient aaeage available- in drilling unit.. . . . . . . . . . . Y N. 8. If deviated, is wellbore plat induded.. . . . . . . . . . . .'. . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can.be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y. N 14. Conductor string provided .. . . . . . . .. . . . . . . . . . ~ N 15. Surtace casing protects all known USDWs. . .. . . . . . . . N 16. CMT vol adequate to cirQJlate on condudor & suñ csg. . . . . Y N. . 17. CMT v~1 adequate to tie-in long s~ng t~ suñ csg. . . .' . . . . ~(N) . 18. CMT Will cover all known productIVe honzons. . . . .. . . . . ))( 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N 20. Adequate tankage or reseNe pit.. . . . . . . . . . . . . . . . Y N ~-ßc:....\-\~~ ,\ ~ I ~Q ~~ ?~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~~ Þ\. ~ :::> \. ~ (' ~ c::;. . . 22. Adequate weilbore separation proposed.. . . . . . ; . . . .. . <2> N ~\a~ (,1.~~Ckr ~ '\ Ù\L~\~,<r-J ':;;s:ç."-. ~'c\..~c0 23. If diverter required, does it meet regulations. . . . . . . . . . IN . 24. Drilling .fluid program schematic & equip list adequate. . . . . N . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . .. . . . N .. ... . . " Þj'~IJI/1/1 D'~ . 26. BOPE pres~ rating app'ropriate; test.to ~D Dsig. ' . N \--\~~'¥ ~~~~ ~ \lüSÔ ~\ . .~( D ~o.~ ~. ~,,~~ çr::l::::D'\¡'5> \ ß;J;¡;[..lL{. ~ 27. Choke mamfold complies w/API RP 53 (May 84). . . . . . . .. . N . . ~ 28. Work wiP occur without operation shutdown. . . . . . . . . . . Y ~ . . . .' :: :=~~: i~~::::~~n.s~I~~ ~~~s~r~~. . .. .. .... ~ N ~ . , . . . '. . 31. Da~a ~resented. on potential overpressure zones. . . . . . . Y ~LJ." .. 32. Seismic analysIs of shallow gas zones. . . . . . . . . . .. . Y ~ - -' L!. A ~ ~!~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . .. - -~ N' . .. ~ 34. Contact name/phone for weekly progress reports [exploratory on!YI Y N . . 1:.... . ANNULAR DISPOSAL35. With proper cementing records, this plan . ?\~~. -\Ð ~ ~ ~~'I...!(è~~<è~\... '\..-\ o-.'{ a.\>~\'( ~, ~ \) o...ç~ \\\~11I (A) will contain waste in a suitable receiving zone; . . . . . . . Y N . (B) will not contaminate freshwater; or cause drilling waste. .. Y N to suñace; .. " (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and . E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N G~: ENGINEERING:. .UIC/Annular COMMISSION: ~þ WM well bore seg _ann. disposal para req - $fÇ"ð ON/OFF SHORE ollJ ENGINEERING c 0 Z 0 -I :E :::0 ( ~. m -. GEOLOGY Z -I , :E:. en :Þ :::0 m » ( APPR DATE Commentsllnstructions: 812õ/D 1 c:\msoffice\wordian\diana\checklist (rev. 11/01/100) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Wen Pennitting Process but is part of the history fHe. To improve the readabiHty of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special. effort has been made to chronologically . . organize this category of information. aO/-IIS () (~" Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 25 09:49:42 2002 Reel Header Service name.............LISTPE Date.....................02/02/25 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/ 02/25 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LTS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn / Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2N-350 501032038900 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 20-FEB-02 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3 T9N R7E 161 Ð~ \1\ ~} \L£ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-11153 T. MCGUIRE R. ROSS MWD RUN 5 AK-MM-11153 P. SMITH M. THORTON 1186 153.50 119.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3734.0 6.125 7.000 12818.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT \ ( (""~ PRESENTED. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). 5. MWD RUN 4 COMPRISED DIRECTIONAL, DGR, EWR4, STABILIZED LITHO- DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. CTN DATA WERE REPROCESSED USING A FORMATION WATER SALINITY OF 19149 PPM CHLORIDES; FIELD DATA WERE PROCESSED WITH A FORMATION WATER SALINITY OF 31000 PPM CHLORIDES. 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 1/04/02, QUOTING AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 8. MWD RUNS 3 AND 4 REPRESENT WELL 2N-350 WITH API# 50-029-20389-00. THIS WELL REACHt;D A TOTAL DEPTH OF 13929' MD / 5018' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHgD PHASE SHIFT-DERIVED RESISTIVITY ( EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLIDE = NON-ROTATED INTERVALS SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 9.3 PPG MUD SALINITY: 600- 1200 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Heqder Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 ("( Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3687.5 3720.5 3720.5 3720.5 3720.5 3720.5 3750.5 12732.5 12733.0 12733.0 12748.0 12813.0 12813.0 STOP DEPTH 13872.5 13879.5 13879.5 13879.5 13879.5 13879.5 13928.5 13824.5 13825.0 13824.5 13840.0 13840.0 13840.0 (- # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO MERGE TOP 3 3687.5 5 12834.0 MERGE BASE 12834.0 13928.5 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... .-999 Depth Units.................. 1 . . - . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 f}PM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit DEPT FT Min 3687.5 Max 13928.5 Mean Nsam 8808 20483 First Reading 3687.5 Last Reading 13928.5 ("( ("~'" ROP MWD FT/H 0.34 417.3 148.656 20357 3750.5 13928.5 GR MWD API 46.82 208.13 120.274 20371 3687.5 13872.5 RPX MWD OHMM 0.73 1551. 26 5.45301 20319 3720.5 13879.5 RPS MWD OHMM 0.15 1584.44 5.71383 20319 3720.5 13879.5 RPM MWD OHMM 1. 43 2000 12.9859 20319 3720.5 13879.5 RPD MWD OHMM 1. 88 2000 14.2266 20319 3720.5 13879.5 FET MWD HOUR 0.34 135.99 2.14987 20319 3720.5 13879.5 NPHI MWD PU-S 13.26 47.33 29.3082 2184 12733 13824.5 FCNT MWD CNTS 124.42 1278.51 412.098 2185 12733 13825 NCNT MWD CNTS 13713.6 38305.1 24103.8 2185 12732.5 13824.5 RHOB MWD G/CM 2.02 2.75 2.33868 2055 12813 13840 DRHO MWD G/CM -0.13 0.32 0.0495426 2055 12813 13840 PEF MWD BARN 2.92 16.23 4.54283 2185 12748 13840 First Reading For Entire File..........3687.5 Last Reading For Entire File...........13928.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 Fi;:Le Type............... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAWMWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 3687.5 3720.5 3720.5 3720.5 3720.5 3720.5 3750.0 STOP DEPTH 12771. 0 12764.0 12764.0 12764.0 12764.0 12764.0 12834.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 21-SEP-01 Insite 66.16 Memory 12834.0 3750.0 12834.0 72.4 76.3 # TOOL STRING (TOP TO BOTTOM) ("'.( ('''^ VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER 2158HWRGF6 2158HWRGF6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3734.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 9.60 45.0 10.5 550 5.8 2.400 1.471 2.600 2.000 74.0 125.0 74.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet , Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 I 68 28 8 First Last Name Service Unit Min Max M.ean Nsam Reading Reading DEPT FT 3687.5 12834 8260.75 18294 3687.5 12834 ROP MWD030 FT/H 0.34 417.3 156.043 18169 3750 12834 GR MWD030 API 46.82 208.13 119.882 18168 3687.5 12771 RPX MWD030 OHMM 0.73 19.81 4.70006 18088 3720.5 12764 RPS MWD030 OHMM 0.15 22.12 4.83003 18088 3720.5 12764 RPM MWD030 OHMM 2.32 1462.56 5.3739 18088 3720.5 12764 RPD MWD030 OHMM 2.55 2000 7.93988 18088 3720.5 12764 FET MWD030 HOUR 0.34 78.92 1.19451 18088 3720.5 12764 First Reading For Entire File..........3687.5 Last Reading For Entire File...........12834 File Trailer Service name.............STSLIB.002 (''"( Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ 3 (-." header data for each bit run in separate files. 5 .5000 START DEPTH 12732.5 12733.0 12733.0 12748.0 12764.5 12764.5 12764.5 12764.5 12764.5 12771. 5 12813.0 12813.0 12834.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ # STOP DEPTH 13824.5 13824.5 13825.0 13840.0 13879.5 13879.5 13879.5 13879.5 13879.5 13872.5 13840.0 13840.0 13928.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROKÄG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER t S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 28-SEP-01 Insite 66.16 Memory 13929.0 12834.0 13929.0 73.2 76.9 TOOL NUMBER PB02153HAGR4 PB02153HAGR4 PB02153HAGR4 PB02153HAGR4 6.125 12818.0 LSND 9.30 43.0 ("( MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 9.0 1000 4.8 4.500 2.464 5.500 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM. 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 ('- 65.0 124.3 65.0 60.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12732.5 13928.5 13330.5 2393 12732.5 13928.5 ROP MWD040 FT/H 0.56 289.64 87.29 2189 12834.5 13928.5 GR MWD040 API 64.27 166.61 123.505 2203 12771.5 13872.5 RPX MWD040 OHMM 1. 74 1551.26 11.5576 2231 12764.5 13879.5 RPS MWD040 OHMM 1. 79 1584.44 12.8793 2231 12764.5 13879.5 RPM MWD040 OHMM 1.43 2000 74.701 2231 12764.5 13879.5 RPD MWD040 OHMM 1.88 2000 65.1962 2231 12764.5 13879.5 FET MWD040 HOUR 0..39 135.99 9.89549 2231 12764.5 13879.5 NPHI MWD040 PU-S 13.26 47.33 29.3082 2184 12733 13824.5 FCNT l-ffiD040 CNTS 124.42 1278.51 412.098 2185 12733 13825 NCNT MWD040 CNTS 13713.6 38305.1 24103.8 2185 12732.5 13824.5 RHOB MWD040 G/CM 2.02 2.75 2.33868 2Q55 12813 13840 DRHO MWD040 G/CM -0.13 0.32 0.049542.6 2055 12813 13840 PEF MWD040 BARN 2.92 16.23 4.54283 2185 12748 13840 First Reading For Entire File..........12732.5 Last Reading For Entire Fi1e...........13928.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... ('" (~' Version Number...........l.0.0 Date of Generation.......02/02/25 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO4 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/ 02/25 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LTSTPE Date.....................02/02/25 Origin.........._........STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File aOJ-J75 ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 20 09:26:52 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn / Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2N-350 501032038900 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 20-FEB-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-11153 T. MCGUIRE R. ROSS MWDRUN 5 AK-MM-11153 P. SMITH M. THORTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3 T9N R7E 161 1186 MSL 0) 153.50 119.30 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3734.0 6.125 7.000 12818.0 ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). 5. MWD RUN 4 COMPRISED DIRECTIONAL, DGR, EWR4, STABILIZED LITHO- DENSITY (SLD) , AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. CTN DATA WERE REPROCESSED USING A FORMATION WATER SALINITY OF 19149 PPM CHLORIDES; FIELD DATA WERE PROCESSED WITH A FORMATION WATER SALINITY OF 31000 PPM CHLORIDES. 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 1/04/02, QUOTING AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 8. MWD RUNS 3 AND 4 REPRESENT WELL 2N-350 WITH API# 50-029-20389-00. THIS WELL REACHED A TOTAL DEPTH OF 13929' MD / 5018' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLIDE = NON-ROTATED INTERVALS ~, SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 9.3 PPG MUD SALINITY: 600 - 1200 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3687.5 3720.5 3720.5 3720.5 3720.5 3720.5 3750.5 12732.5 12733.0 12733.0 12748.0 12813.0 12813.0 STOP DEPTH 13872.5 13879.5 13879.5 13879.5 13879.5 13879.5 13928.5 13824.5 13825.0 13824.5 13840.0 13840.0 13840.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD MWD $ SOURCE CODE # REMARKS: BIT RUN NO MERGE TOP 3 3687.5 5 12834.0 MERGE BASE 12834.0 13928.5 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O ,~ { Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... .Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 SC02 MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3687.5 13928.5 8808 20483 3687.5 13928.5 ROP MWD FT/H 0.34 417.3 148.656 20357 3750.5 13928.5 GR MWD API 46.82 208.13 120.274 20371 3687.5 13872.5 RPX MWD OHMM 0.73 1551.26 5.45301 20319 3720.5 13879.5 RPS MWD OHMM 0.15 1584.44 5.71383 20319 3720.5 13879.5 RPM MWD OHMM 1.43 2000 12.9859 20319 3720.5 13879.5 RPD MWD OHMM 1.88 2000 14.2266 20319 3720.5 13879.5 FET MWD HOUR 0.34 135.99 2.14987 20319 3720.5 13879.5 NPHI MWD PU-S 13.26 47.33 29.3082 2184 12733 13824.5 FCNT MWD CNTS 124.42 1278.51 412.098 2185 12733 13825 NCNT MWD CNTS 13713.6 38305.1 24103.8 2185 12732.5 13824.5 RHOB MWD G/CM 2.02 2.75 2.33868 2055 12813 13840 SC02 MWD G/CM -0.13 0.32 0.0495426 2055 12813 13840 PEF MWD BARN 2.92 16.23 4.54283 2185 12748 13840 First Reading For Entire File......... .3687.5 Last Reading For Entire File.......... .13928.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 3687.5 3720.5 3720.5 3720.5 3720.5 3720.5 3750.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 12771.0 12764.0 12764.0 12764.0 12764.0 12764.0 12834.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 21-SEP-01 Insite 66.16 Memory 12834.0 3750.0 12834.0 72.4 76.3 TOOL NUMBER 2158HWRGF6 2158HWRGF6 8.500 3734.0 Water 9.60 45.0 10.5 550 5.8 Based 2.400 1.471 2.600 2.000 74.0 125.0 74.0 74.0 HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3687.5 12834 8260.75 18294 3687.5 12834 ROP MWD030 FT/H 0.34 417.3 156.043 18169 3750 12834 GR MWD030 API 46.82 208.13 119.882 18168 3687.5 12771 RPX MWD030 OHMM 0.73 19.81 4.70006 18088 3720.5 12764 RPS MWD030 OHMM 0.15 22.12 4.83003 18088 3720.5 12764 RPM MWD030 OHMM 2.32 1462.56 5.3739 18088 3720.5 12764 RPD MWD030 OHMM 2.55 2000 7.93988 18088 3720.5 12764 FET MWD030 HOUR 0.34 78.92 1.19451 18088 3720.5 12764 First Reading For Entire File......... .3687.5 Last Reading For Entire File.......... .12834 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPD RPX RPM FET RPS GR RHOB DRHO ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 12732.5 12733.0 12733.0 12748.0 12764.5 12764.5 12764.5 12764.5 12764.5 12771.5 12813.0 12813.0 12834.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ # STOP DEPTH 13824.5 13824.5 13825.0 13840.0 13879.5 13879.5 13879.5 13879.5 13879.5 13872.5 13840.0 13840.0 13928.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 28-SEP-01 Insite 66.16 Memory 13929.0 12834.0 13929.0 73.2 76.9 TOOL NUMBER PB02153HAGR4 PB02153HAGR4 PB02153HAGR4 PB02153HAGR4 6.125 12818.0 LSND 9.30 43.0 9.0 1000 4.8 4.500 65.0 ~. MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.464 5.500 3.000 124.3 65.0 60.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical. log depth units.......... .Feet Data Reìerence Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 SC02 MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12732.5 13928.5 13330.5 2393 12732.5 13928.5 ROP MWD040 FT/H 0.56 289.64 87.29 2189 12834.5 13928.5 GR MWD040 API 64.27 166.61 123.505 2203 12771.5 13872.5 RPX MWD040 OHMM 1.74 1551.26 11.5576 2231 12764.5 13879.5 RPS MWD040 OHMM 1.79 1584.44 12.8793 2231 12764.5 13879.5 RPM MWD040 OHMM 1.43 2000 74.701 2231 12764.5 13879.5 RPD MWD040 OHMM 1.88 2000 65.1962 2231 12764.5 13879.5 FET MWD040 HOUR 0.39 135.99 9.89549 2231 12764.5 13879.5 NPHI MWD040 PU-S 13.26 47.33 29.3082 2184 12733 13824.5 FCNT MWD040 CNTS 124.42 1278.51 412.098 2185 12733 13825 NCNT MWD040 CNTS 13713.6 38305.1 24103.8 2185 12732.5 13824.5 RHOB MWD040 G/CM 2.02 2.75 2.33868 2055 12813 13840 SC02 MWD040 G/CM -0.13 0.32 0.0495426 2055 12813 13840 PEF MWD040 BARN 2.92 16.23 4.54283 2185 12748 13840 First Reading For Entire File......... .12732.5 Last Reading For Entire File.......... .13928.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/20 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /02 /20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File