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Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing F±] Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Jet Pump 21 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory El Service ❑ 198-100 3. Address: P. 0. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20061-00-00 7. Property Designation (Lease Number): e. Well Name and Number: KRU 2N-339 ADL 375074 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,239 feet Plugs measured None feet true vertical 5,550 feet Junk measured 7800 feet Effective Depth measured 8,201 feet Packer measured 0 feet true vertical 5,515 feet true vertical 0 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 79 feet 16 108' MD 108' TVD SURFACE 2,934 feet 7 5/8 " 2,963' MD 2306' TVD PRODUCTION 8,201 feet 5 1/2 " 8,228' MD 5542' TVD Perforation depth: Measured depth: 7846-7886, 7846-7866 feet True vertical depth: 5275-5304, 5275-5290 feet Tubing (size, grade, measured and true vertical depth) 27/8 L-80 7,496' MD 5,025' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -NONE N/A N/A SSSV -NONE N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gili Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: SHUT-IN - - - - 14. Attachments (requlnd per 20 AAc 26.070, 25.071, a 26.283) 15. Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319.175 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells Engineer (�c I % I , Contact Phone: (907) 263-4627 Authorizetl Si nature: Date: f Form 10-404 Revised 4/2017 G�Zo �9 / //./ 1 3BDMS 6VJUN 18 2019 Submit Original Only STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑� Reenter Susp Well ❑ Other: Jet Pump 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory ❑ Service ❑ 198-100 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20061-00-00 7. Property Designation (Lease Number): a. Well Name and Number: KRU 2N339 ADL 375074 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,239 feet Plugs measured None feet true vertical 5,550 feet Junk measured 7800 feet Effective Depth measured 8,201 feet Packer measured 0 feet true vertical 5,515 feet true vertical 0 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 79 feet 16 108' MD 108' TVD SURFACE 2,934 feet 7 5/8 " 2,963' MD 2306' TVD PRODUCTION 8,201 feet 5 1/2 " 8,228' MD 5542' TVD Perforation depth: Measured depth: 7846-7886, 7846-7866 feet True Vertical depth: 5275-5304, 5275-5290 feet Tubing (size, grade, measured and true vertical depth) 27/8 L-80 7,496' MD 5,025' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -NONE N/A N/A SSSV -NONE N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (requlreo per 20 MC 25.070, 2&.071, a 2&283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WIND ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-175 contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 263-4627 Authorized Signature: Date: Form 10-404 Revised 4/2017 Submit Original Only KUP PROD WELLNAME 2N-339 WELLBORE 2N-339 Well Akributes Max Angle & MD TD ConoeoPh)ll)ps kkNOme W¢IhereAPNUW We11Wre5 tuz (•I mErou I ACI.1.bukin Alaska. Inc_ TARN PARTICIPATINGAREA 501032026100 PROD 5.25 6.250.00 8,239.0 iWS9..Doxa316<T7. Last Tag V+lertl aRa,wkl ael) AnnotationCapon MKS) EIMDaIe Wetmore Last Mou By Last Tag: FIND (Est 125' Ramote) 6/1012019 IN,rome, ----- — ------ -- Last Rev Reason Na -t= XM'C£X', NJ gnnotatlan Eno Gah We11MLe 1astMW BY REVresson: PUillHEXPlug 'llil limmi Casing Strings caeilq oexnpeon oG prat IG (In1 TOPPI sat Geptnmleel reel dean OVp)... WI/Len n... Gnae Top To.. CONDUCTOR 16 15.06 29.5 108.0 108.0 62.58 HAO WELDED castle 0esmptlon op arm u Qn) n.,ho a) ae ionorn ern set cenam IIV01... Nrn D... Grate Top TM1reaO SURFACE ]59 6.87 29.5 2,963.3 2,306.2 29]0 L30 BTC -MOD Casnq Oaonnaon p011n) Iplln) TopntKIN ant OeplM1 (Niel an Depth nrad WNxn ll...GrWe Top TnrW PRODUCTION 5.5"x35" 512 495 286 8,227.6 5,541.6 1550 L-80 LTC @ 7575' Tubing Strings Tub les Deacnptwo soils Ma... 10IInI TOP hirel SN CePth M Set Geptn ITop)1... WI (Lang s.Ye TOP COnnxMon 2718"INTERNALLY 218 144 7,453.0 4,994.2 850 L-80 MITI AND EXTERNALLY 124A .n/. corvoucToa. n stoeo COATED PLASTIC COMPLETION Completion Details 1, (1131 1, Incl Nominal Top Innen mKel 1') nem Ces core 10 (in) 244 24.3 018 HANGER FMC Gen V Tubing Hanger, 11"X312"EUEM B X P 2.960 7, 5J 419184 4571 SLIDING Weatherford! 3 220'x 23131 BSSD Siding Sleave BTS8 BxP 2.313 SLEEVE (SHIFT DOWN TO OPEN) Open Sliding Sleeve 611012919 7,3944 49526 4523 NIPPLE Carrico 2718(225" D Nipple) STL Bel 2.250 7,438.7 498401 4446 SEALASSY Baker 3026 Locator Seal Assembly STL Box 1.940 Tables Oesaipnan sWlp Ma.. ID lin) TopalKBl set DeptM1 pL sN OepM m'p)1... Nl lelltl Gmde topeonneclion 412"INTERNALLY 412 396 14750 ).496.0 5,0250 1260 L.80 MITI PLASTIC COATED SCAB LINERr Completion Details Top"D1 Topma Nominal Top dem hdan PI nem ons Com ID her 1475.0 1,3783 36.69 MANGER Weatherford 4"x 51aNTP Liner Top Packer W/ WE PER, TKC3350 FJ150 Pin 7,4407 4,9854 4442 SBE Baker30-26Seal Bore Extension Assembly 2.680 6URFACE', S.S3 Ll 1,411.2 S,Ot 15 I 44.35 SEAL ASSv Baker 8040 Locator Seal Assembly EUE Box 3030 Other In Hole (IHireline, retrievable plugs, valves, pumps, fish, etc.) TopmAd Topenol I TNIpion) (KKaI ('1 oes Com Run Ede ED (in) 7,345.7 4,9184 45]11 "XHxxxLwl . 1 lockw/ .5"R jmi-umplI Ratio),Safl el, 61102019 0.000 Jet Pump 8 Single Spreek Gauge (88"OAL) soak. SLEEVE, Taus 2 a1S.k W JY Pent, 7.31 ) 7,..b 5,2430 R.90 Fish Ancherson HEX rru plug that was pulled on 52412019 fi10912gig Perforations & Slots snm Dena Topmol seemed) (sM1duft TOP(rynB) W.UhMiI (head green Unesel Date 1 Type Com 7,8460 7,8860 5,275.5 5,3038 S-3,214339 72&1998 40 IPERF 2.FHC, 1911, deg phasing, 90 deg orient NIPPLE: 23seY 7,846.0 1,8660 5,215.5 5,2893 S-3,214-339 111812005 40 APERF 2.5" HP, 60 deg. phase 7,846.0 ],886.11 5,2]5.5 5,303.8 5-3, 2N-339 5112019 60 1 E:m, SD. ...Phasing, 1,. MAXFORCE HSD guns. Free Summary amilks.proppem0esideeallb) pmppant In Feminism tial Sisk atatl0att T.ID hml TK.I Llnkto HoOsIsteen VolCka pen Volslurrynel 1 11111/2005 ],8460 ],866.0 sea Astax 7xae rNotes: General B Safety Entl Dak Annular. eaE, ].MO.] 6/12019 atic wl Alaska Schematic100 NOTE'. View SCM1em SEAL ASSY. 7,472 FM:7,aD0 FRA0,7,518.0 ANPF: 7.0,1ako RPERF. 7fi1607esk ' PERF: TBI807.BN0 P ....... NssOSe� Operations Summary (with Timelog Depths) 2N-339 Rig: NORDIC 1 Job: RECOMPLETION Time Log Shan Depm Start Time End! Time our (hr) Phase Op Cade Aaivhy Code Time P -T -X Operation (RKB) End Depth (tlKB) 5/5/2019 5/6/2019 3.00 DEMOB MOVE MOB P Moving rig F/ 15 pad T/ 2N 339 21:00 00:00 5/6/2019 5/6/2019 3.00 DEMOB MOVE MOB P Move rig F/ 1 D pad T/ KCS - Y 00:00 03:00 5/6/2019 5/6/2019 4.00 DEMOB MOVE MOB P wait on field crew change. 03:00 07:00 5/6/2019 5/6/2019 3.50 DEMOB MOVE MOB P Move rig F/ KCS Y to CPF2. 07:00 10:30 5/6/2019 5/6/2019 0.50 DEMOB MOVE MOB P Set rig down and check tires and 10:30 11:00 moving system. 5/6/2019 5/6/2019 1.50 DEMOB MOVE MOB P Move F/ CPF 2 T/ 2B pad 11:00 12:30 5/6/2019 5/6/2019 0.50 DEMOB MOVE MOB P Stop rig and perforin equip. check, 12:30 13:00 allow triffic to pass. 5/6/2019 5/6/2019 3.50 DEMOB MOVE MOB P Continue moving rig F/ 2B pad T/ 2M 13:00 16:30 pad 5/6/2019 5/6/2019 0.50 DEMOB MOVE MOB P Set rig down, take measurement of 16:30 17:00 pathway past Doyon 19 and verify clearnce. move rig past Doyon rig. 5/6/2019 5/6/2019 0.50 DEMOB MOVE MOB P Stop F/ Doyon crew change. 17:00 17:30 5/6/2019 5/6/2019 3.00 DEMOB MOVE MOB P Move F/ 2M pad To intersection of 2S 17:30 20:30 pad. 5/6/2019 5/6/2019 2.00 DEMOB MOVE MOB P Check tires, Rear lire on ODS rear, 20:30 22:30 had bubble around bead. 5/6/2019 5/7/2019 1.50 DEMOB MOVE MOB T Wait on tire truck, and tire. Bleed off 22:30 00:00 tire, remove stair well for tire removal, while waiting for tire Irk. 5/7/2019 5/7/2019 6.00 DEMOB MOVE MOB T Wait on Peak lire truck, install new 00:00 06:00 tire, and install stairwell. 5/7/2019 5/7/2019 2.00 DEMOB MOVE MOB P Wait on field crew change. 06:00 08:00 5/7/2019 5/7/2019 2.00 DEMOB MOVE MOB P Continue moving rig. 08:00 10:00 5/7/2019 5/7/2019 2.00 DEMOB MOVE MOB P Hook up dozer to assist rig up hill, 10:00 12:00 move rig up hill. 5/7/2019 5/7/2019 1.50 DEMOB MOVE MOB P continue moving rig to 2L pad. 12:00 13:30 5/7/2019 5/7/2019 3.00 DEMOB MOVE MOB P Check tires, rear tires @ 140 psi, set 13:30 16:30 rig dwn and let tires cool 5/7/2019 5/7/2019 3.00 DEMOB MOVE MOB P Continue moving rig F/ 2L pad to 2N 16:30 19:30 pad 5/7/2019 5/8/2019 4.50 DEMOB MOVE RURD P Set rig malts, And ne X mas tree in 19:30 00:00 cellar, install lower rams on bops, build ramp for malts, set her in cellar for nipple up. 5/8/2019 5/BI2019 1.50 MIRU MOVE MOB P Spot rig over well and level. -Accept 00:00 01:30 Rig @ 01:30 5/8/2019 5/8/2019 5/8/2019 1.00 MIRU MOVE MOB P Berm in cellar. install Handy berm. 01:30 02:30 5/8/2019 5/8/2019 1.50 MIRU MOVE RURD P Go thru mud pumps, check valve 02:30 04:00 seals, Arrange location, set up sign in shack, place Dumpsters. 5/8/2019 5/8/2019 3.00 MIRU WELCTL MPSP P P/u lubricator. Pressure test to 2500 04:00 07:00 PSI. Pull BPV 1000 PSI on tubing, 1500 PSI on IA, 260 PSI on OA. Master and swab valves not holding pressure. 5/8/2019 5/8/2019 2.00 MIRU WELCTL MPSP T Called valve crew, greased master 07:00 09:00 I and swab. Page 116 Report Printed: 5/22/2019 Operations Summary (with Timelog Depths) 2N-339: og: NORDIC 1 Job: RECOMPLETION Time Log star oepm start Time End Tune Dur (hr) Phase Op Code Acavdy Code Time P -T -X Operadon (ftKB) End Depth (MB) 5/8/2019 5/8/2019 3.00 MIRU WELCTL RURD P Rig up circulating equipment to kill 09:00 12:00 well. 5/8/2019 5/8/2019 0.50 MIRU WELCTL SFTY P PJSM with rig crew on pumping 12:00 12:30 heated soapy water. 5/8/2019 5/8/2019 3.50 MIRU WELCTL KLWL P Bleed gas rap off. Stage pumps up to 12:30 16:00 3 BPM 2000 PSI pumping heated sea water with 1 % deep clean in. Total of 290 Bbls pumped. 5/8/2019 5/8/2019 0.50 MIRU WELCTL OWFF P Observed well for flow for 30 Min. No 16:00 16:30 flow. 5/8/2019 5/8/2019 1.00 MIRU WHDBOP MPSP P Set BPV 16:30 17:30 5/8/2019 5/8/2019 1.00 MIRU WHDBOP PRTS P Test BPV from below 1500 PSI for 10 17:30 18:30 Min. 5/8/2019 5/8/2019 4.00 MIRU WHDBOP NUND P N/D Tree.set blanking plug,Set new 18:30 22:30 tree on Xover flange 5/8/2019 5/9/2019 1.50 MIRU WHDBOP NUND P Nipple down rams and mud cross, 22:30 00:00 change position of mud cros. 5/9/2019 5/9/2019 10.00 MIRU WHDBOP NUND P N/D rams and mud cross,to arrange 00:00 10:00 BOP'S, N/U lower rams w/ mud cross on well head, install bop's on top of bottom rams, n/u hCr kill & choke lines, set riser. 5/9/2019 5/9/2019 1.00 MIRU WHDBOP RURD P Fly Weatherford tubing longs onto rig 10:00 11:00 floor with crane. 5/9/2019 5/9/2019 2.00 MIRU WHDBOP RURD P Make up test joint and floor 11:00 13:00 equipment. Fill stack and lines with fresh water. Shell test BOP's. Good test. 5/9/2019 5/9/2019 2.00 MIRU WHDBOP BOPE P Informed AOGCC rep Jeff Jones of 13:00 15:00 successful shell test. Jeff instructed us to wait on him to proceed with test. 5/9/2019 5/9/2019 8.00 MIRU WHDBOP BOPE P Initial BOP test 250/1500 PSI for 5 min 15:00 23:00 each. UVBR's, LVBR's and annular tested with 2 7/8" & 4 1/2" test joints. Gas alarms and PVT alarms test. Test witnessed by AOGCC rep Jeff Jones. 1 F/P on LVBR's. 5/9/2019 5/10/2019 1.00 COMPZN WELLPR THGR P Rig up elevators, install salty valve on 7,492.0 7,487.0 23:00 00:00 landing jt. pull hanger, tubing broke free @ 80K 5/10/2019 5/10/2019 2.00 COMPZN RPCOMP CIRC P Rig up and Circulate 100 bbls 7,487.0 7,487.0 00:00 02:00 5/10/2019 5/10/2019 1.50 COMPZN RPCOMP PULL P Pull hanger to floor and L/D Tubing 7,487.0 7,462.0 02:00 03:30 hnger and landing joint. 5/10/2019 5/10/2019 1.00 COMPZN RPCOMP PULL P UD 3.5" - 9.3# L- 80 EUE completion 7,462.0 6,904.0 03:30 04:30 tubing. Well became out of ballance. Flow from tubing. 5/10/2019 5/10/2019 1.25 COMPZN RPCOMP CIRC P Circulate 100 Bbls at 3 BPM. 6,904.0 6,904.0 04:30 05:45 5/10/2019 5/10/2019 0.25 COMPZN RPCOMP OWFF P Obsereve well for flow. No flow. 6,904.0 6,904.0 05:45 06:00 5/10/2019 5/10/2019 12.00 COMPZN RPCOMP PULL P Cont. UD 3.5" - 9.3# L- 80 EUE 6,904.0 7,474,5- 06:00 18:00 completion tubing. What looks like heavy drag markings on tool joints starting at joint#20. Heavy corrosion on colloars staring at joint #25. Heavy corrosion on tube starting at joint #100. Holes in pipe starting at joint #165 5/10/2019 5/10/2019 3.00 COMPZN WELLPR BHAH P Clem and clear rig floor, load BHA in 7,474.0 7,474.0 18:00 21:00 pipe shed, bring up all slips, elevators, lifting subs, XO's, BHA subs to rig floor Page 216 Report Printed: 5122/2019 Operations Summary (with Timelog Depths) 2N-339 Rig: NORDIC 1 Job: RECOMPLETION Time Log sten Depth Stag Time Eno Time Dur (hr) Phase Op Code Actvlty Code Time P -T -X Operation WS) End Depth (M(B) 5/10/2019 5/11/2019 3.00 COMPZN WELLPR PULD P Load pipe house with 2 7/8 DP and 21:00 00:00 process. 5/11/2019 5111/2019 9.00 COMPZN WELLPR PULD P Load pipe hose with 2 718, S 135 DP 0.0 0.0 00:00 09:00 and process pipe @ 60 its per row. 5/11/2019 5111/2019 1.00 COMPZN WELLPR KURD P Install wear bushing 0.0 0.0 09:00 10:00 5/11/2019 5/11/2019 1.00 COMPZN WELLPR BHAH P MU clean run BHA#1 0.0 135.0 10:00 11:00 5/11/2019 5/12/2019 13.00 COMPZN WELLPR PULD P PU 2 7/8" HT Pac drill pipe and RIH. 135.0 6,570.0 11:00 00:00 Circulate 25 Bbls every 2000'to string in 1% safe lube through system. 5/12/2019 5/12/2019 3.00 COMPZN WELLPR PULD P Continue P/U 2 718" HT Pac drill pipe 6,570.0 7,450.0 00:00 03:00 and RIH. Circulate 25 Bbls every 2000' to string in 1% safe lube through system. 5/12/2019 5/12/2019 2.00 COMPZN WELLPR RURD P M/U circulating hose, wash down to 7,450.0 7,475.0 03:00 05:00 7475', verify where seals enter PBR, with stinger, PSI up T/ 600 psi, shut pump off, seals holding, bleed off. 5/12/2019 5/12/2019 1.00 COMPZN WELLPR CIRC P Pump HI Visc sweep and circulate out 7,475.0 7,518.0 05:00 06:00 @ 3 bpm. Shut down pumps slack off to no-go @ 7475'. Stinger depth 7518' inside 3 1/2" liner. 5/12/2019 511212019 0.50 COMPZN WELLPR RURD P RD circulating equipment. 7,518.0 7,475.0 06:00 06:30 5/12/2019 5/12/2019 4.00 COMPZN WELLPR PULL P POOH and rack back 26 stands in 7,475.0 5,863.0 06:30 10:30 derrick 5/12/2019 5/12/2019 8.50 COMPZN WELLPR PULD P Continue POOH LD/DP. remove BHA 5,863.0 0.0 10:30 19:00 from pipe house and rig floor. clear pipe house of tublars. clean rig floor 5/12/2019 5/12/2019 2.50 COMPZN WELLPR TL -05G P PJSM with Pollard wire line crew, rig 19:00 21:30 up w/line equipment 5/12/2019 5/13/2019 2.50 COMPZN WELLPR ELOG P 21:30 00:00 -wire 5/13/2019 5/13/2019 3.50 COMPZN WELLPR ELOG P TIH with caliper logs on T/ 00:00 03:30 7617'' 5/13/2019 511312019 1.50 COMPZN WELLPR RURD P Rig down wire line equipment. 03:30 05:00 5/13/2019 5113/2019 7.00 COMPZN WELLPR RURD P Load pipe shed with 4 1/2" 12.6# L-80 05:00 12:00 MITI completion. Rabbit, strap and talley. 5/13/2019 5/13/2019 1.00 COMPZN WELLPR RURD P Pull wear bushing 12:00 13:00 5113/2019 5113/2019 7.00 COMPZN WELLPR RURD P Set test plug, grease choke and mud 13:00 20:00 cross. Fill stack and choke with fresh water, test plug not holding. Trouble pulling lest plug. Made up schnozilator and jetted top of test plug to wash sand off of plug. Pull plug, p/u shhnozilator and wash out bop stack. 5/13/2019 5/1312019 1.00 COMPZN WHDBOP BOPE P Replace seal on test plug, check LDS 20:00 21:00 to insure backed all way out. 5/13/2019 5/14/2019 3.00 COMPZN WHDBOP BOPE P Test BOP's Annular, Rams, and choke 21:00 00:00 valves @ 250/1700 psi for 5 min. Floor valves @ 250/1700 psi. with 2 7/8 and 4 112 test joints. 5/14/2019 5114/2019 3.50 COMPZN WHDBOP BOPE P Continue Testing BOP's Annular, 0.0 0.0 00:00 03:30 Rams, and choke valves @ 250/1700 psi for 5 min. Flory valves @ 250/1700 psi. with 2 7/8 and 4 1/2 test joints. Annular element failed on test for 2 7/8 lest jt. Page 316 Report Printed: 5/2212019 - i - Operations Summary (with Timelog Depths) a 2N-339 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T-% Operation MKB) End Depth (WEI) 5/14/2019 5/14/2019 1.50 COMPZN WHDBOP BOPE P Continue Test BOP to 250/1700/All 0.0 0.0 03:30 05:00 Good 5/14/2019 5114/2019 7.00 COMPZN WHDBOP RGRP T C/O 11 "Annular Bag and seals 0.0 0.0 05:00 12:00 5/14/2019 5/14/2019 1.50 COMPZN WHDBOP NUND P NIU BOP Stack and flow riser 0.0 0.0 12:00 13:30 5/14/2019 5114/2019 1.50 COMPZN WHDBOP To -PE -P-- Tested 11"Annular w/ 2 7/8" and 4 0.0 0.0 13:30 15:00 1/2" test joint 250/1700 psi 5/14/2019 5/14/2019 1.00 COMPZN WHDBOP BOPE P RID test equipment and set wear dng 0.0 0.0 15:00 16:00 bushing 5/14/2019 5/14/2019 2.50 COMPZN RPCOMP TRIP P RIH w/ 2 718" Drill pipe T/ 1609' 0.0 1,609.0 16:00 18:30 5/14/2019 5/14/2019 2.00 COMPZN RPCOMP CIRC P Circulate 2 BU All good mud temps @ 1,609.0 1,609.0 18:30 20:30 52 5/14/2019 5/15/2019 3.50 COMPZN RPCOMP PULD P POOH lay down 2 7/8" Pac Drill pipe 1,609.0 0.0 20:30 00:00 1 and RID Tongs 5/15/2019 5115/2019 2.00 COMPZN RPCOMP RURD P R/U Weatherford casing equipment 0.0 0.0 00:00 02:00 w/ MITI thread rep Hold PJSM 5/15/2019 5/15/2019 7.00 COMPZN RPCOMP PUTB P P/U Baker seal assembly w/ locator 0.0 3,022.0 02:00 09:00 and seal bore extension. M/U 4 1/2" 12.6# L-80 MITI liner. M/U Tq 3200 ft/lbs ran with torque tum. 5/1512019 5/15/2019 4.00 COMPZN RPCOMP RURD P Load pipe shed with remaining 74 3,022.0 3,022.0 09:00 13:00 joints of 4 1/2" MITI. Rabbit, strap and N 5/15/2019 5/1512019 7.00 COMPZN RPCOMP PUTB P Cont. RIH W/ 4 1/2" 12.6# L-80 MITI 3,022.0 6,030.6 13:00 20:00 IineLtl 6011' PUW 53k 5/15/2019 5/16/2019 4.00 COMPZN RPCOMP PUTB P Load pipe Shed w/ 2 7!8" 9.3# L-80[7,479.0 0.6 7,479.0 20:00 00:00 EUE tubing rabbit and Strip 50 in shed P/U 46 Joints 2 7/8" EUE tubing and RIH tag up TOL @ 7460' PUW 58k SOW 33K Space out 3' Off no go. PU out of seals and R/U to Circ pies up to 600 PSI Confirm seal are in place P/U out of seals and release pres 5/16/2019 5/1612019 2.50 COMPZN RPCOMP RCST P Continue space out and r/u to Circ 7,479.0 00:00 02:30 1 hold PJSM w/ crew 5/16/2019 5/16/2019 1.00 COMPZN RPCOMP CIRC P R/ll LRS and PT lines 2800 PSI 7,479.0 7,479.0 02:30 03:30 pump reverse circulate 25 bbls 1 % Cl down backside and followed w/ 33 bbls diesel down backside Final pres 125 PSI 5/16/2019 5/16/2019 1.00 COMPZN RPCOMP PRTS P Slack off and String in seal assy it 7,479.0 7,495.0 03:30 04:30 7479' and drop Weatherford 1 3/4" Ball set top liner packer and pressure up to 3800 PSI packer set @ 2650 psi and hole for 10 min all good . 5/16/2019 5/16/2019 1.50 COMPZN RPCOMP PRTS P RID LRS and R/U to test Ann U2500 7,495.0 1,450.0 04:30 06:00 psi f/ 30 min. All good bleed Down to 0 Release packer 16 turns right P/U off packer @ 1450' OKB 5/1612019 5/1612019 1.00 COMPZN RPCOMP CIRC P R/U to Circ diesel out of the Backside 1,450.0 1,450.0 06:00 07:00 t/ flow back tank. 5/16/2019 5/16/2019 0.50 COMPZN RPCOMP RURD P RID circulating equipment. 1,450.0 1,450.0 07:00 07:30 5/16/2019 5/16/2019 2.50 COMPZN RPCOMP PULD P POOH UD 2 718 EUE work string. 1,450.0 0.0 07:30 10:00 5116/2019 5/16/2019 0.50 COMPZN RPCOMP RURD P Pull wear bushing. 0.0 0.0 10:00 10:30 Page 416 Report Printed: 5/22/2019 Operations Summary (with Timelog Depths) 2N-339 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Depth Start7ane End Time Dur(ho Phase Do Code Activity Code Time P -T -X operation W13) End Depth(nKe) 5/16/2019 5/17/2019 13.50 COMPZN RPCOMP RURD P Load pipe shed with 2 7/8", 1 L-80, 0.0 0.0 10:30 00:00 MITI flush joint plastic coated tubing. Rabbit, srap and tally, due to Pups and XO at baker to be made up and ship to rig 5/17/2019 5/17/2019 2.00 COMPZN RPCOMP SFTY P Hold PJSM w/ Weatherford, MITI 0.0 0.0 00:00 02:00 thread rep, R/U tubing equipment Review repair procedures w/ crew on plastic coated tubing. 5/17/2019 5/17/2019 6.00 COMPZN RPCOMP RCST P Make up seal assembly, one joint, D 0.0 2,056.0 02:00 08:00 nipple, one joint sliding sleeve and continue RIH with 2 7/8", 6.5#, L-80 MITI flush plastic coated internally and externally. Torque turned to 1050 ft/lbs. On joint 61 the joint being picked up slid through slips on elevators and pulled free of lifting nubbin and fell from the elevators coming to rest in the pipe shed. 5/17/2019 5/17/2019 9.00 COMPZN RPCOMP WAIT T Identified lifting nubbins would not 2,056.0 2,056.0 08:00 17:00 make up adequately into box end of pipe. Sent thread rep to Baker machine in Deadhorse to modify the nubbins. 5/17/2019 5/17/2019 1.00 COMPZN RPCOMP WAIT T Tested modified lifting nubbins. 2,056.0 2,056.0 17:00 18:00 Threaded in by hand. Picked up joint with flat top elevators to ensure nubbin had integrity to support the joint. 5/17/2019 5/18/2019 6.00 COMPZN RPCOMP RCST P Continue RIH with 2 7/8', 6.5#, L-80 2,056.0 4,365.0 18:00 00:00 MITI flush plastic coated internally and externally. Torque fumed to 1050 ft/lbs. 5/18/2019 5/18/2019 8.50 COMPZN RPCOMP RCST P Continue RIH with 2 7/8", 6.5#, L-80 4,365.0 7,455.0 00:00 08:30 MITI flush plastic mated internally and externally. Torque fumed to 1050 ft/lbs. Tagged NO-GO on seals. Bottom of seal assembly depth while on NO-GO 7455'. 5/18/2019 5/18/2019 2.50 COMPZN RPCOMP HOSO P LD joint# 222 & 221. M/U XO pups 7,455.0 7,423.0 08:30 11:00 from 2 7/8" MITI to 3 1/2" EUE. M/U space out pups, hanger and landing joint. 5/18/2019 5/18/2019 2.00 COMPZN RPCOMP CIRC P Roll pumps at 1 BPM saw pressure 7,423.0 7,423.0 11:00 13:00 increase as seals engaged. Shut down pump bleed pressure off. P/U seals to create circulation path. Close annular and reverse circulate 40 Bbls corrosion inhibited seawater down back side. 5/1812019 5/18/2019 2.50 COMPZN RPCOMP FRZP P R/U LRS and reverse circulate 45 Bbis 7,423.0 7,423.0 13:00 15:30 diesel down back side. Place IA and tubing in communication and let diesel U-tube. Open up annular. 5/18/2019 5/18/2019 1.50 COMPZN RPCOMP HOSO P RIH land hanger. RILDS 7,423.0 7,453.0 15:30 17:00 5/18/2019 5118/2019 3.00 COMPZN RPCOMP PRTS P R/U and test tubing to 1500 PSI for 5 7,453.0 7,453.0 17:00 20:00 min. Test IA to 2500 PSI for 30 Min. RID testing equipment. RID test Equipment 5118/2019 5/18/2019 1.00 COMPZN WHDBOP PRTS P P/U FMC H- BPV and Install and Test 7,453.0 7,453.0 20:00 21:00 T/ 500 f/ 5 mins All good 5/18/2019 5/19/2019 3.00 COMPZN WHDBOP NUND P Blow Down All lines and R/0 Rig floor 7,453.0 7,453.0 21:00 00:00 Equipmenl,Pull out all rams out of BOP stack Page 5/6 Report Printed: 512 212 01 9 A.r"7%1 Operations Summary (with Timelog Depths) qW 2N-339 Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Time End Time Dur Min Phase Op Cotle Activity Cotle Time P -T -X Operation Stan Depth mKa) Entl Depth(XKB) 5/19/2019 5/19/2019 3.00 COMPZN WHDBOP NUND P Continue Pulling out All ram Bodys 7,453.0 7,453.0 00:00 03:00 and N/D choke hose and Kill line, break out all Flange on Stack 5/19/2019 5/19/2019 3.50 COMPZN WHDBOP NUND P Continue N/D choke hose and Kill line, 7,453.0 7,453.0 03:00 06:30 break out all Flange on Stack and Set Back BOP stack 5/19/2019 5/19/2019 3.50 COMPZN WHDBOP NUND P Nipple up tree 7,453.0 7,453.0 06:30 10:00 5/19/2019 5/19/2019 1.00 COMPZN WHDBOP PRTSP Test tubing hanger packoffs and tree 7,453.0 7,453.0 10:00 11:00 250/5000 PSI 5/19/2019 5/19/2019 1.00 COMPZN WHDBOP MPSP P Pull dart and HP BPV. Set H BPV. 7,453.0 7,453.0 11:00 1200 1 I RIG RELEASED AT 12:00 Page 616 ReportPrinted: 5/22/2019 ji S-11. PROAcTivE DIAgNOSTiC SERVICES, INC. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper/ MTT) 199100 30 82 2 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVEDAttn: Diane Williams 130 West International Airport Road MAY 21 2019 Suite C Anchorage, AK 99518 AOGCC PdsanchoraaeO.mem orvloa.com 12 -May -19 2N-339 1 Report /CD 50-103-20261-00 Date (fit 19 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(&MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM D. Achiv--',M stetTemplateFiles\Templetee0isi butlo \Tren -m MShects',ComroPhiU,ps_T,.�,rt td.� L P 0 190100 30 82 2 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2N-339 Log Date: May 12, 2019 Field: Tam Log No.: 20067 State: Alaska Run No.: 1 API No. 50-103-20261-00 Pipe Description: 5.5 inch 17 Ib. L-80 LTC Top Log Interval: Surface Pipe Use: Casing Bottom Log Interval: 7,496 Ft. (MD) Pipe Description: 3.5 inch 9.3 Ib. L-80 8RD EUE Top Log Interval: 7,496 Ft. (MD) Pipe Use: Casing Bottom LoInterval: 7 604 Ft. (MD) Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of the pup joint at 7,464 feet per the Casing Detail dated May 28, 1998. This log was run to assess the condition of the casing with respect to internal corrosive and mechanical damage after pulling the tubing. The caliper recordings indicate the 5.5 inch and 3.5 inch casing logged appear to range from good to poor condition, with a maximum recorded wall penetration of 76% in a line of pits in joint 112 (4,809 ft). Additional wall penetrations ranging from 20% to 71 % wall thickness are recorded in 127 of the 181 joints logged. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the casing logged. The body region analysis and joint tabulation data for the 5.5 inch and 3.5 inch casing are combined. MAXIMUM RECORDED WALL PENETRATIONS: MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. M. Domec C. Waldrop K. Barr & J. Grieco ProActive Diagnostic Ser./ices, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (838; 565-9085 Fax: (261) 431-7125 E-mail: PDSAnalvsis(d)memorvloe com Prudhoe Bay Field Offce Phone: (907) 659-2307 Fax: (907) 659-2314 Line of Pits 76 112 4,809 Ft. (MD) Isolated Pitting 71 69 2,959 Ft. (MD) Line Corrosion 71 60 2,560 Ft. (MD) Line Corrosion 65 95 4,067 Ft. (MD) Line of Pits 60 98 4,194 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. M. Domec C. Waldrop K. Barr & J. Grieco ProActive Diagnostic Ser./ices, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (838; 565-9085 Fax: (261) 431-7125 E-mail: PDSAnalvsis(d)memorvloe com Prudhoe Bay Field Offce Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipe 1 5.5 in (12.3'-7,495.7') Well: 2N-339 Pipe 2 3.5 in (7,495.7' - 7,603.8') Field: Tarn Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 12, 2019 Approx. Tool Deviation Approx. Borehole Profile 24 _7 1• • 50 2,119 75 3,194 11 •• 4,276 125 5,362 J �� 0- N17,506 4 7,599 0 50 00 Damage Profile (% wall) / Tool Deviation (degrees) Bottom Pipe Nom.OD Weight Grade & Thread 5.5 in. 15.5 ppf L-80 LTC 3.5 in. 9.3 ppf L-80 SRD EUE Damage Configuration (body) 150 100 50 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 34 0 104 0 0 Nom.ID PDS Report Overview (PS 4.95 in. Body Region Analysis Well: 2N-339 Survey Date: May 12, 2019 Field: Tarn Tool Type: UW MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc, Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Anal st: Waldro Pipe Nom.OD Weight Grade & Thread 5.5 in. 15.5 ppf L-80 LTC 3.5 in. 9.3 ppf L-80 SRD EUE Damage Configuration (body) 150 100 50 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 34 0 104 0 0 Nom.ID Top Depth Bottom Depth 4.95 in. 12 ft. 7,496 ft. 2.992 in. 7,496 ft. 7,604 ft Damage Profile (%wall) Penetration body Metal loss body 0 50 100 0.1 [ --- 50 100 150 Bottom of Survey = 4 PDS Report Joint Tabulation Sheet ii � Well: 2N-339 Survey Date: May 12, 2019 Field: Tarn Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 5.5 in. 15.5 ppf L-80 LTC Casing 3.5 in. 9.3 ppf L-80 8RD EUE Casing Nom. ID Body Wall Top Depth Bottom Depth 4.95 in. 0.275 in. 12 ft 7,496 ft. 2.992 in. 0.254 in. 7,496 ft. 7,604 ft. Joint No. )t. Depth (Ft.) Pen. Pen. Upset Body (in.) (in.) Pen. Metal % Loss % Min. I.D. (in.) Damage Profile Comments I% wall) 0 50 100 .1 12 0 0.04 15 3 JL91 Pim qhdljpyPit 1 24 0 0.03 10 2 4.88 Lt. Deposits. 4 13 1 4.90 3 109 0 0.04 14 2 4.89 Lt. Deposits. 4 0 0.03 12 2 4.90 5 195 0 0.02 9 1 4.90 6 238 0 0.04 14 3 4.92 282 0 11 2 4 Lt. De its. 324 0 0.07 24 3 4.90 Lin of Pi 9368 0 0.07 25 3 4.91 Line of Pits. to 4110 0.07 24 2 4.9 Line o Piu. 11 54 0.05 0.06 23 2 4.88 i e nf Pitc. Lt. Denosits. 12 496 0 0.06 22 2 4.89 Line of Pits. Lt. Deposits. 13 538 0 0.04 16 3 4.93 all w Pif'nt,. 14 581 0 6 21 3 487 Line of Pits. L. Deposits. 15 623 0 0.02 -d.03 8 2 4.91 16 666 0 = 3 -4.88 Lt. Der,,,its. 17 709 0 0.03 12 2 4. 2 18 753 0 0.02 6 3 4.91 19 796 a 0.07 26 1 4.89 [solatpd Pitting. t. De osit . 20 840 0 0.06 21 3 4.90 Line of Pits. 21 a63 0.06 0.07 27 5 4.92 iLQLatQd Pittin 22 1 926 0 0.05 17 3 4.91 Shall Pitting. 23 1 969 0 0.03 11 4 4.87 Lt. Deposits. 4 1012 007 27 1 4.87 Line of Pits. Lt. Devosits. 25 1056 11 0.0 6 1 4.90 26 1099 0 0.03 11 1 4.90 27 114 6 3 491 8 1186 0 0.08 28 3 4.90 Line of Pits. 29 1230 0 0.08 29 2 4.88 Line of Pits. Lt. Deposits 30 1273 1 0. 19 2 4.11 Shall Line of Pits,Lt. De o it . 31 1317 0 0.07 27 1 4. ine of Pi 32 1360 0 0.03 11 1 2 4.91 33 1401 Q.05 0.09$22 4. IsolatedPitting- 34 1442 0 0.054.8 low Pitting. Lt. osits. 35 1486 0 0.034.91 36 152 0.03 4.90 37 1572 0 0.054.90 Shallow Line of Pits. 38 1615 0 0 39 1658 0.06 4.91 Isolatedfn 40 1701 0 0.08 4.93 Line of Pits. 41 17 4.92 Sh I Pittin . 42 17 4. Line of Pits. Lt. Deposits. 43 1829 0 0.04 13 2 4.89 44 1 0 9 1 4.90 45 191 1 0 0.11 39 4 4 Line f Pits. 46 1954 0 0.07 25 2 4.90 Line of Pits. 47 1 6 0 4 2 4.90 48 2 0.11 3 4 6 Lin its. 49 2076 0 0.09 33 3 1 4.91 1 Line of Pits. Penetration Body Metal Loss Body Page 1 V-6 Well: Field: Company: 2N-339 Tarn ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 12, 2019 Analyst: Waldrop Sheet Pipe Description 5.5 in. 15.5 ppf L80 LTC Casing 3.5 in. 9.3 ppf L-80 8RD EUF Casing Nom. ID Body Wall Top Depth Bottom Depth 4.95 in. 0.275 in. 12 ft 7,496 ft. 2.992 in. 0.254 in. 7,496 ft. 7,604 ft. Joint No. )t. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. °io Metal Loss %(in.) Min. I.D. Comments Damage Profile (%wall) 0 50 100 211 0 .1 42 4.8 Line of Pits, 51 2162 0 0.09 31 3 4.93 Line of Pits. 52 220 0.04 3 4. Line f Pits 53 2249 0 0.09 31 2 4.90 Line of Pits. 54 2 0 23 1 Line f it . 55 1 2336 0.0 1 3 .91 e of Pits. 56 2379 0 0.09 34 3 4.86 Line of Pits. Lt. Deposits. 57 2423 0.1 37 2 in of P' 8 2466 0.04 0.09 2 .91 i of Pits. 59 2510 0.06 0.10 36 4 4.92 Line of Pits. 6 2553 0.19 1 7 4.92 e Corrosion. 61 2592 0.06 0.11 39 3 1 492 Line of Pits. 62 2635 0 0.11 41 3 1 4.91 Line of Pits. 63 26Z9 0 0.15 53 4 4.94 in f Pits. 64 2722 0.04 0.14 51 7 4.91 Line of Pits. 65 2766 0 0.15 56 7 4.90 Line of Pits. 66 2810 0 0.11 41 3 192 Line Qf Pits. 7 2853 0.07 0. 2 42 3 4.92 Line of 68 2897 0.08 0.16 57 5 4.92 Line of Pits. 69 2941 0.04 0 71 4. IsolatedPitting. 70 2985 0 0.14 49 1 4 4.88 Line of Pits. Lt. De osits. 71 1 3025 0 0.10 37 4 Line of pits. 7 3067 0.1 37 4.9 Line of Pits 73 3110 0 0.10 35 3 4.89 Line of Pits. Lt. Deposits 74 31 4 0 0.11 39 3 4.92 Line of Pits. 3194 0 0.12 4 3 4.91 Line of Pits. 76 3235 0 0.15 53 3 4.90 Line Corrosion. 7 3276 0 0.11 40 3 4.92 Line of Pits. 8 3320 0 0.13 45 3 4.88 1 inp of Pits. Lt. Der)osits. 79 3363 0 1 0.13 48 3 4.92 Line of Pits. 0 3406 0.10 0.16 58 4 4.90 Line Corrosion. 1 3449 0 0.13 1 48 4 4.92 Line of Pits 82 3493 0 0.14 51 4 4.91 Isolated Pittin 3 3536 0.16 59 3 4.91 'n of Pi 84 80 0 0.11 41 1 3 492 Line of Pits. 85 3623 0 0.09 33 4 4.93 Isolated Pittin 86 3666 4 0.15 53 3 4.9 e of Pi 87 3710 0 0.15 55 6 4.92 Line of Pits. 88 37 4 0 .1 41 4 4. Line o Pits. 89 3797 0 0.13 4 3 4.9 Line of Pi 90 3841 0 0.14 52 5 4.92 Line of Pits. 91 3885 0 0.1 37 2 4.9 Line of Pits. 92 3928 0.07 0.1 3 6 .9 ine of Pi 93 3972 0 0.12 43 5 4.89 Line of Pits. 94 401 5 0 0 49 4. Line of Pits. 95 4059 .. 5 0.18 6 5 4. in Corr n. 96 4102 0 0.11 40 3 4.92 Line of Pits. 9 414 0 .1 46 Line of Pits. 98 418 0.0 0. 60 4 4. i 'ne of Pi 99 4233 0.04 0.13 48 3 4.91 Line of Pits. Penetration Body Metal Loss Body Page 2 ji4s- Well: 2N-339 Field: Tarn Company: ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 12, 2019 Analyst: Waldrop Sheet Pipe Description 5.5 in. 15.5 ppf LSO LTC Casing 3.5 in. 9.3 ppf L-80 8RD EUE Casing Nom. ID Body Wall Top Depth Bottom Depth 4.95 in. 0.275 in. 12 ft 7,496 ft. 2.992 in. 0.254 in. 7,496 ft. 7,604 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 100 4276 0 10 n.12 4 3 -4.89 Line of Pits. 101 4320 0 0.08 29 3 4.89 Isolated Pitting. 102 4363 0.04 0.10 35 7 4.92 Isolated Pittin 103 4407 0 0.12 44 6 4.91 Line of Pits. 1 44 1 0.0 0.14 0 7 4.92 Isola Pitting, 105 4495 08 0 37 3 4.90 o ate 'ttin 106 4538 0 0.11 41 5 4.91 Line of Pits. 107 4582 0. 7 .14 -51-L 4 4,9Q I Line C rosion. 108 1 4625 1 0 0.10 36 1 3 4.90 1 Line of Pits. 109 1 4669 1 0 0.12 43 5 4.88 1 Line of Pits. Lt. De osits. 110 4713 29 4.89 e f Pi s. 11 4756 0 0.06 23 2 4 QQ Line of Pits. 112 4800 0.08 0.21 76 4 4.92 Line of Pits. 113 844 0.13 46 2 9 Lin of Pit . 14 4888 0 0.07 26 3 4. Isolated Pi in 115 4931 0 1 0.07 26 1 4.89 Line of Pits. Lt. De osits. 116 5.0.09 3 3 4. Line f Pits. 1 7 501 8 0 0 37 3 4.90 ine of Pits. 118 5061 0 1 0.14 52 3 4.91 Line of Pits. 19 5 0 .09 1 3 4.9 Line f Pits. 120 5148 0 0.09 34 3 4.91 Line of Pits. 121 1 0.0 0.14 5 4. Isol ittin 2 5 .1 5 4.9 ine of P' 123 5279 0 0.16 59 4 4.89 Isolated PittingLL De osits. 1 4 53 0 0.0 3 4.8 sola Pitting 1 5362 0 22 3 4.90 1 of ted 'ttin 126 5403 0 0.10 36 4 4.86 Line of Pits. Lt. Deposits. 5444 0 0.12 45 3 4.89 1 ine of P't . 128 5485 1 0 34 3 6 of Pits. Lt. Deposits 129 5524 0.05 0.14 49 4 4.89 Line of Pits. 1 0 55 0 7 2 4.83 Lt. De osi s. 131 5601 1 0 I 0.0 34 4 4.89 i e of Pi 132 5642 0.04 0.13 47 5 4.85 Line of Pits. Lt. Deposits. 1 3 5685 0 8 30 2 4.90 ine of Pi s. 134 1 5728 1 0 1 0.ni 9 2 4.90 135 5772 0.05 0.04 13 2 4.89 6 81 5 0 41 3 .88 e of Pits. Lt. Dpnoqits. 137 5859 0 0.11 40 3 4.89 Line of Pits. 138 54 2 0. 6 1 0.12 44 2 4.89 Line of Pits. 139 0.06 0 39 2 4.89 Line of Pi 140 5989 0.06 0.09 34 4 4.90 Isolated Pitting 14 11 6033 0.05 1 0.16 57 3 4.91 Lingof Eits. 142 6072 0 1 0.05 19 = 4.62 allow Pitting. Lt. Deposits. 143 6111 0 1 0.05 18 1 4.88 Shallow Pitting. Lt. De osiis. 44 6154 32 4 4. Line of Pits. 14 6193 43 1 4.8 Line of Pits. 146 6235 6 2 4.90 147 6279 jM' 2 2 4. Line Pits. 148 3 2 4.90 Line of Pits. 149 6366 12 1 3 4.89 Penetration Body Metal Loss Body Page 3 ii4-s PDS Report Joint Tabulation Sheet Well: 2N-339 Survey Date: May 12, 2019 Field: Tarn Analyst: Waldrop Company: ConocoPhil ips Alaska, Inc. Pipe Description 5.5 in. 15.5 ppf L-80 LTC Casing 3.5 in. 9.3 ppf L-80 8RD EUE Casing Nom. ID Body Wall Top Depth Bottom Depth 4.95 in. 0.275 in. 12 ft 7,496 ft. 2.992 in. 0.254 in. 7,496ft. 7,604ft. Joint No. ft. Depth Pen. Pen. Pen. Metal (Ft.) Upset Body % Loss (in.) (in.) % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 150 64 0 1 0.07 26 1 2 489 Line of Pits. 151 6450 0 0.10 37 3 4.88 Line of Pits. Lt. De osits. 152 6494 0 40 2 4.88 Lin Pits. osits. 153 6537 0 0.06 21 3 4.87 Isolated Pitting, Lt. De osits. 154 6576 0.05 0.11 39 3 4.90 Lioe Qf Pits. 155 6620 0 001 11 3 4.86 Lt. Deposits. 156 6660 0 0.03 9 2 4.88 Lt. De osits. 157 6701 1 0 0. 07 24 4. Isola d nittin 158 6742 0 0.07 1 4.87 I olated Pittiny It. Degosits. 159 6783 0 0.06 20 1 4.88 Isolated Pitting. Lt. De osits. 160 6823 0 0.03 11 2 4.86 It. De o 161 6864 0 0.07 25 2 487 Line of Pits. Lt. Deposits. 162 6903 0 0.04 13 2 4.87 Lt. De osits. 163 6947 0 0.05 20 2 4.90 Isolated Pi i 164 6990 0 0.04 16 3 4.90 Shallow Pitting. 165 7034 0 0.02 7 1 4.87 Lt. Derposits. 166 7077 0 1 0.02 7 1 4.87 osits. 167 7120 0.05 0.06 22 5 4.91 Isolated Pittin . 168 7164 0 0.04 13 3 4.90 169 7207 0.02 8 1 4.90 170 7251 0 0.02 9 1 4.88 Lt. Deposits. 171 7295 0 0.02 7 2 4.89 172 1 7337 0 0.07 27 4.88 Isolated Pitting. Deposits, 173 1 7380 0 0.11 39 2 4.84 Isolated Pitting, Lt. Deposits. 174 1 7423 29 1 4. 1 Isol ed Pittin t. Deo74.1 74 9 1 4 Pu174.2 7475 0 0 0.1 7 9 21 Pu .Deo1 JOQ. 750 8 2 2. 1 t. osis. 2 753711 1 2.91 Lt De osits. 3 7 8 2. i Lt. D si s. 7599 8 2 2.91 Lt. sits. 'Penetration Body Metal Loss Body Page 4 ii� PDS Report Cross Sections Well: 2N-339 Survey Date: May 12, 2019 Field: Tarn Tool Type: UW MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Cross Section for Joint 112 at depth 4,809.130 ft. Tool speed = 53 Nominal ID = 4.95 Nominal OD = 5.5 Remaining wall area = 97% Tool deviation = 48° Finger =5 Penetration = 0.2 11 in. Line of Pits 0.21 in. = 76% Wall Penetration HIGH SIDE = UP iiS. PDS Report Cross Sections Well: 2N-339 Survey Date: May 12, 2019 Field: Tarn Tool Type: UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Cross Section for Joint 69 at depth 2,958.900 ft. Tool speed = 52 Nominal ID = 4.95 Nominal OD = 5.5 Remaining wall area = 95% Tool deviation = 47° Finger = 16 Penetration = 0.196 in. Isolated Pitting 0.20 in. = 71% Wall Penetration HIGH SIDE= UP KUP PROD 2N-339 ConoeoPhillips l{ tnbatea Max Angle & MD TD P1BSKa, In,. Fuld xam. wmlbnm AFwwl waueam srn,m nn (y khhkkal A°leen (RNBI TARN PARTICIPATING AREA 501032026100 PROB 55.25 8,MR0 8,239.0 Lomm°nY N28 (ppm) oN prn,NliM End OM° x6Wa(R) pip R°Iaaea Dab SSSV: NIPPLE Last WO: 34.W 5130/1998 ®Hoa w'ne'sGunds.sent. Last Ta Vmacpl.'—duO(ecwa' AmWafion Ena Dam D.'anaft ) Lsal Moe By Last Tag: RKB(Est 173' M R.IM1de) 5/2812018 8,039.0 zanbae) Last Rev Reason ........ -. HARP, 11.9_. Am°dll°n End Data LaNM°a By Rev Reasen: T8TRapl8cdd0V,85e1C5VIor Leak Deled 6/1/2018 embael Casing $trn a _ Cxiiq Descnplinn .0an) CONDUCTOR 16 ID(in) T°p (M!B) $NDepN(..) SN DapIM1 jND) WGLan(I...Gmlc 15.08 295 108D 108.0 62.58 T°PTAeatl HAD WELDED d .... ..... Pa.. I DD(in) SURFACE 7510 ID Nn) gjansB) S.ID.pM(. 9.MU611 M1(TVU)... 1WILen N... 6.8> 295 2,963.3 2306.2 2970 Ond° Tap TM1r°ad L80 BTGMOO Lasi,g DeaeRFe'" OD Bn) PRODUCTION 55"x3.5" SV2 @ 7575' to (in) T°p (fll(B) S°[DopN (flKB) Sal DeptM1 (No)... WVLcn Q.,, 495 268 8,22]6 5,5416 1650 Grade Top Tbend L-80 LTC Tubing Strings Tubingoncripeon SNns Ma_. m bn) r°v (aKa) Sn! D.p' fl.. Sa DupM lrvD) L.. w! nbltn Gme. TOP c°nn.cmn TUBING 3V2 209 12.6 ],4924 5,022.4 9.30 L80 EUEBRDMOD Completion Details M/ LDNDDCTW:203'lead T^P MDI T^P Incl x.mmal To flKB flk8 Mm Du Com ID lin 12,8 12.8 0.08 HANGER FMC GEN VSMTUBING HANGER 35M 51&3 517.91 &54 NIPPLE CANDO DS NIPPLE 2,875 NIPPL2,51:a 7,359.6 4,928.1 45,45 SLEEVE -C BAKER CMU SLIDING SLEEVE w/2.813" C✓MCO OS PROFILE 2.813 (CLOSED 1 IAV2005) 7,464.8 5,002.6 44.31 NIPPLE CAMCO D NIPPLE 2750 7,4718 5,00]] 44.33 LOCATOR BAKER LOCATOR 2,985 7,4734 5D088 44.30 SEALASSY BAKER W40 CASI NG SEAL ASSEM BLY 3.000 Perforations $ Slots Boal r° nl(B BM rwB TOlpuc(a) Dan. B NtBmi) Lmbaace. DM (ekort cost ],8460 7,8fib0 5,2)5.5 5, 289.7 S-3, 2N-339 11182DD5 4.OAPERF 25" HP, 60 deg. phase 7,846.0 7,886.0 5,2755 5,3038 5-3, 2N-339 ]2611998 4.01PERF 2.WHC,BH,180deg Pbasitg, 9D deg onenl Free Summa Smnoffi Paappanloeagmd(Re PmpPa,R In Fd-.mn go) i 111112005 SIgW abaYDab .FD°pN(Ib(B) 7. sten Link to Fluid Stamm VaI LI.aO (bbg Va131urry(bpg 1 1111112005 ],846.0 ],W6.0 d..E LE 295z.ara-- Mancirel lnsens a3ol SLEEVEL',],95P.s X TO iJ{a Top mD) N(B Make Matl.l OD In S.Iv Valra a Ltd. T • Pons" M Me Run 1 Run ONe Cam 7.410.9 4,964.2 CAMCO NBG-2- i GAS LIFT OV BTM 0.313 O.D fi1V2018 9 Nolen: Generel B Safety '- .. _. End 0. Mnatatian 11/2312D10 NOTE: View Schematic wl Alaska 5chemabc90 CAD LIR: 7A10.8 NIPPLO7.4sig LOGTOR: 1.971 d FFAL: 1.kRD MERF', T.sOs.e-1,9aa.n IFERF', 7.M 41,80:0 %YOOUC110N s,s f5'M_ e". za.:e,zn.a ,l Casing Detail 5.412" X 3-112" Production Casina ARCO Alaska, Inc. Subsidiary of Atlsntie Richfield Company WELL: TARN 2N-339 DATE: 5/28198 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 26.60' TOPS 5 112", LANDING JT, 34A' OVERALL LENGTH 26.60 Jt. 203 Landed on slips and cutoff (31.60) 5 112", 15.5#, L-80 MOD 11.66 26.60 Jts. 29-202 5-112", 15.5#, L-80, MOD (174 joints) 7425.72 38.28 PUP 5-112, 15.59, L-80, MOD 10.75 7464.00 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/2" x 4" 21.35 7 7 . PUP 3-112" 9.3# L-80 8n1 EUE 10.03 7496.10 jts.20-23 3-112" 9.3# L-80 8rd EUE (4 joints) 125.69 7506.13 MARKER 3-112" 9.3# L-80 8rd EUE EST, Lengh 4.13 7631.82 its, 6.19 3-1/2" 9.3# L-80 8rd EUE (14 joints) 433.78 7635.95 Weatherford Gemoco Float Collar 1.17 8009.73 Jts. 1-5 3-1/2" 9.3# L-80 8rd EUE (5 joints) 154.87 8070.90 Weatherford Gemoco Float Shoe 1.80 8225.77 8227.57 (23) 3-112" x 6-112" straight blade centralizers on jts 1-23 (12) 5-112" x 6-314" Gemoco centralizers on Jts. 29- 40 (18) 6.1/2" x 6-1/2" centering guides on Jts #'s 146, 148, 151, 154, 167.160. 163. 166, 169, 172, 175, 176, 181, 184, 187, 190, 193, 198. NOTE: 3.5"JOINTS #24-28 STAY IN PIPE SHED (5 JOINTS) NOTE: 5.112"" JOINTS #204.208 STAY IN SHED (5 JOINTS) Remarks: String Welzlhts with Blocks: 125K # Up, 60K# Dn, 121<01Blooks. Ran 203 Joints 5-112" and 23 Joints 3,61" casing. Drifted 5.5" (4.70')& 3.5.5" (2.867') casing with plastic rabbit Used Arctic Grade API Modified No Lead threw on all connections. Casing is non -coated. Doyon 141 DMAIng Supervisor: D.P. BURLEY THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-339 Permit to Drill Number: 198-100 Sundry Number: 319-175 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. oogc c.a las ka. gov Enclosed is the approved application for the 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, C� Ce Jessie L. Chmielowski Commissioner DATED this 10 day of April, 2019. RBDMS�APR 112019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 95 2An APR 0 4 2019 D7-5 4- // 0 / g AQGC6 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑� Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: - G t mEEr 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑� Stratigraphic Service E]❑ 198-100 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20261-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 2N-339 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0375074 KUPARUK RIVER / TARN OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 222g� 5542 8201 5515 710 none none _ CasingLength Size MD Burst Collapse • • Structural Conductor 78 16" 108 108 Surface 2933 7-5/8" 2963 2306 Intermediate Production 8201 5-1/2"x 3-1/2" 8228 5542 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7846'- 7886 5276'- 5304' 3-1/2" L-80 7492 Packers and SSSV Type: Packer (none) Packers and SSSV MD (ft) and TVD (ft): Packer (none) SSSV (none) SSV (none) Seal Assembly (5.5" x 3.5") Seal Assembly (7475' MD / 5010') 12. Attachments: Proposal Summary ❑� Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development ❑Q * Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2019 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. W IIs Engine r Contact Email: k le.ham ton c0 .cOm (J 2oI Contact Phone: 263-4627 Authorized Signature: Date: t COMMISSION USE ONLY Conditions of approval: Notify Commission that a representative may witness Sundry Number: '✓'1 ,so, Plug Integrity ❑ BOP Test L7 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Bop fCst iv l5'Ua 5 Js f1-/'3Yr Ul4'/' f�rrvlh iY.— /-t 5 _/V/ SG 0 P 5' Post Initial Injection MIT Req'd? Yes ❑ No f RBDMS �(� APR Spacing Exception Required? Yes F1No Subsequent Form Required: /J —`f-0 Lf 1 12019 APPROVED BY by:4/10h ,Approved COMMISSIONER THE COMMISSION Date: V11— 't!!U!! (•- Submit Form and Form 03 Revised 4/2017 Approvetl applicatiogi{ R joG rfia� fprr�the date of approval. �� Attachments in Duplicate UKI'V-I AL [, '�� 74/1•1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 4, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Tarn Producer 2N- 339 (PTD# 198-100). Well 2N-339 was drilled and completed in May 1998 as a Tam producer well. From 1998 to 2005, there have been issues with paraffin buildup, requiring scrapes and hot diesel flushes. In November 2005, the producing interval was -'reperfomted and fraced. In August 2014, conductor was extended and welded. In June 2018, a leak detect log was ran and identified tubing leaks at 7,432', 5,312', and 5,155' RKB. In March 2019, the well passed POT -T, PPPOT- T, POT -IC, and PPPOT-IC. The objective of this rig workover is to pull upper 3-1/2" tubing from seals at 7475' RKB. We will then ran in with a 4-1/2" internally plastic -coated scab liner from 1,400' RKB to the seals at 7,475' RKB. Run new 2-7/8" jet pump i completion that is externally and internally plastic -coated (seal, nipple, sliding sleeve, nipple). If you have any questions or require any further information, please contact me at 263-4627. Sincerely, 4' Kyle ampton Senior Wells Engineer CPAI Drilling and Wells 2N-339 RWO Procedure Tarn Producer PTD #198-100 Current Status: The well is currently shut in. In March 2019, T POT, T PPPOT, IC POT, IC PPPOT passed. Scope of Work: Pull 3-1/2" tubing and ESP from 5,160' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). General Well info: MPSP: 710 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Tarn —1,224 psi / 5,142' TVD (4.6 ppg EMW) 8.5 ppg KWF Wellhead type/pressure rating: FMC Gen V, 3 1/8" SM BOP Config: Annular / Variable Pipe Ram / Blind Ram / Variable Pipe Ram MIT results: CMIT— Passed to 2,500 psig/Opsig on 6/1/2018 Well Type: Producer Estimated Start Date: May 4, 2019 Production Engineers: Adam Childs (263-4690 / Adam.G.Childs@conocophillips.com) Workover Engineer: Kyle Hampton (263-4627 / Kyle.Hampton@conocophillips.com) Remaining Pre -Rig Work 1. New SBHP. 2. Reperforate interval 7,846'— 7,886'. 3. Set IBP in liner top near 7,810'. 4. CMIT to 2,500 psi. 5. Swap to dry hole tree configuration for RU. 6. Install BPV. Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and pump seawater from surface to surface. Record shut-in pressures on the T& IA. If there is pressure, bleed off IA and/or tubing pressure, and weight up fluid as necessary. Complete 30 -minute NFT. Verify well is dead. z 3. Set BPV, ND Tree, NU BOPE and test to 250/ 1,500 psi. Test annular 250/1,500 psi. a. Notify AOGCC of BOP test 24 hours prior to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 4. Pull BPV and MU landing joint. 5. Pull 3-1/2" tubing and lay down the tubing. Clean-out Run / Caliper 6. Pick up 5-1/2" casing scraper and run in hole to top of seals. Pull out of the hole. 7. RU E -line. Perform caliper log from 7,470' RKB to surface. RD E -line. Page 1 of 2 2N-339 RWO Procedure Tarn Producer PTD #198-100 Install in 4-Y2" Scab Liner 8. MU 4'/:" scab liner with seal assembly and liner top packer. RIH and place the stab into the seals at 7,475' RKB. Set packer with running tool. 9. Pressure test tubing to 1,500 psi for 5 minutes. 30. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. Install in 2-N" Tubing 11. MU 2 %" completion with seal assembly, nipple, sliding sleeve, and nipple. RIH and stab into the seals run in previous 4-1/2" string. 12. Pressure test tubing to 1,500 psi for 5 minutes. 13. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Install BPV. 15. ND ROPE. NU dry hole tree. 16. Shift sliding sleeve. Freeze protect well. 17. RDMO. Page 2 of 2 Well 211-339 API 501032026100 PTD 198-100 Rig RKB Nabors 7E5 Max DIS BWA09fi 800 RKB Max Pad H2S 100 ppm Well Category Cat 3 ConocoPhillips PROPOSED RWO Network P (Drilling) MD Network g (Wells) OD AFE Cost Weight AFETime 500' Max Angle 55.3" C 6,2W'RKB Most Recent Well H2S 0 ppm H2S Radius of Exposure (100 ppm) 13 feet Well Spacing Well 2N-341 is 30.2' Well Spacing I Well 2N -3371s 30.3' WELL OBJECTIVE Pull upper 3-1/2" tubing from seals at 7475' RKB. We will then run in with a 4-1/2" Internally -Plastic -Coated scab liner from 1,400' RKB to the seals at 7,475' RKB. Run new 2-7/8" jet pump completion (seal, nipple, sliding sleeve nipple). WELL HISTORY Drilled and completed in May 1998 as a Tarn producer well. From 1998 to 2005, there have been issues with paraffin buildup, requiring scrapes and hot diesel Rushes. In November 2005, the producing interval was reperforated and hated. In August 2014, conductor was extended and welded. In June 2018, a leak detect log was run and identified tubing leaks at 7,432', 5,312', and 5,155' RKB. In March 2019, the well passed POT - T, PPPOT-T, POT -IC, and PPPOT-IC. HSE CONSIDERATIONS Top Perf Bottom Perf PERFORATIONS (RKB) (RKB) S-3 7,846' 7,886' PRESSURE CALCULATIONS SUMP EMW Gas Column MPSP PROPOSED/NEW COMPLETION EQUIPMENT MD TVD OD Nom. ID Weight Thread 500' 2,864' (ft RKB) (ft RKB) (in) (in) (Ib/ft) Grade (tap) Thread(btm) jCASING 108' 108' 16 15.06 62.S8 H-40 WELDED- 1MITIFIush 2-7/8" Sealbore ',:' 2,963' 2,306' 75/8 6.87 29.70 L-80 BTC MOD - Bit" - ntermediate 8,228' 5,542' 51/2 4.95 15.50 L-80 LTC LTC -:; p- 0' 0 0.00 0.00 000 000 0.00 ous) 31/2 0.00 9.30 L-80 EUE8ROMOD EUEBRDMOD:,-j Tubing(Proposed) 7,492' 5,022' 2 7/81 6.41--80 MITI Flush MITI Flush Top Perf Bottom Perf PERFORATIONS (RKB) (RKB) S-3 7,846' 7,886' PRESSURE CALCULATIONS SUMP EMW Gas Column MPSP PROPOSED/NEW COMPLETION EQUIPMENT MD (ft RKB) TVD (1t RKB) OD (in) I ID (in) Thread (top) Thread I (btm) Comments 2-7/8" X Nipple 500' 2,864' 2.875 MITI Flush MITI Flush 2-7/8"Sliding Sleeve 7,360' 3,895' 2.875 MITI Flush MITI Flush Weatherford 2-7/8" X Nipple 7,400' 4,914' 2.8751 IMITIFlush 1MITIFIush 2-7/8" Sealbore 7,475' 5,431'1 2.8751 1 MITI Flush IMITI Flush I Baker FLUIDS Wei ht Comments/Additives Primary Workover Fluid Back-up Workover Fluid n Seawater No back-up fluid needed. Corrosion Inhibitor n/a Inhibited brine w/1%CRW-132 Freeze Protection Diesel .r\ KUP PROD 2N-339 ConOcOPh'"'rs Well Attributes Max An le&MD TO 1" .. Alaska, Inc, Name 'Mlltom PPuuWI We"—smma al'1 MO areAa Ba" ,are Name InNB1 TARNPARTICIPATINGAREA 501032026100 PROD .25 6,25000 8,239.0 Comment X331pgn) pam Anmmtlon Ena DBn naLN IN Rlp RNeaaa DBW SSSV: NIPPLE LmAWO: 34.50 S3W1998 a+a a, arzuzole aso'eeue last Tag ven'ea:ercmnlcmnw) nsionmen Em Dam DapM lnNel IaelMw 6v Last Tag: RM (Est. 173' of Ratbole) 5282018 6039.0 zembeej Last Rev Reason XMICER', 138 Annoemon Era Dam Lea Moa By Rev Reason Tag,Raoacecl OV, B Set CSV for Leah Detect 6/112018 zembaej Casing Strings canna 0eecnpaon OD Qm ID Brat Top (nNel sm Depm lrtNB1 see Depm(rvDl... WYLen (L.. Onae ropimew CONDUCTOR 16 1506 29.5 108.0 108.0 62.58 H40 WELDED Laslna peaOnptlM 00 (Ipl ID (Int TOp InXDI 801DBpNfMle) Set Oepin NO1... VMLen (I... Gmae Top Tnnea SURFACE )SB 6.07 29.5 2,9fi3.3 2,306.2 29.70 L-80 ETCMOD Caalnp"I'leme" OD6nI ID(Ini Top(nKIN Se1Da M-1 SN Cap1n 1N0)... VNLen II...GaJ Top-`- PRODUCTION5.5"x3.5' 512 4.95 26.6 622).6 5.5415 15.50 L-BOn LTC 575' Tubing Strings Tuxnp Dewilpl1- I SDYM Ma...ID1M) iop lnXB) set DepM (2.. Sa DepmfNpl6-OApNn1 Braae Top Lommctlen TUBING 312 2.99 128 ]4924 5022.4 930 L-80 EUEBRDMOO Completion Details Tep DVpl Top lMt xomm.I ' coNoucrog:s3re_O T^plKKel 81881 CI Imm D. cam tD tm) 12.8 12.8 0.09 HANGER EMC GEN V SM TUBING RANGER 3.500 518.3 5179 &M NIPPLE CAMEO DS NIPPLE 2875 MPPLEa183 7,359.6 4,928.1 4545 SLEEVE -C BAI(ER CMU SLI DI NO SLEEVE W 281 J' CAMCO DS PROFILE 2813 (CLOSED n1y2005) 7,11&18 5,002.6 4431 NIPPLE CAMEO D NIPPLE 2.750 7,4719 5.0077 44.33 LOCATOR WER LOCATOR 2985 7,4734 50088 4434 BEALASSY WER00-00CASINGSEALASSEMBLY 3000 Perforations & Slots ana Den Top1TV0) Ban(PA1 ppona1 To KKB BtmIKKBI I IME, (nX81 UnMe43me Dam 1 rifte Com 1,846.0 7,8660 5,275.5 5,289.7 S -3,2N-339 1102WS 46 APERF 2.5"HP, 60 tleg phase ),646.0 ),8860 5,2]5.5 5.303.8 S-3, 2N-339 72&1998 4.O IMER 2, iH ,BR 180mag phasing, 90 deg otleTtl Frac Summary start Dem vroppanmmenM Ile) Prupwrtln lon-son (1b)I V1112005 atpY Dem Top DapT fnnBj etmlMeI ups m Flame snmm valcmMrlMR) wino mm, 1 11/112005 ),84fi.0 7,856.0 17 MOM yJRFACE:1J.sz.968.J— Mandrel Inserts t se tl SME,eC.7£98 N KIN Top OVD) I Np801 I ODDn, 8me Typ Typ PoOaIOe TM%MOn Run Dem Lom 1 ),4109 4,964.2 CAMEO XBG2- 1 GAS LIFT OV BTM 0313 0.0 611/2018 9 Notes: General & Safety ana Dem Annwauon 111212010 NOTE: New Schematic wl Alaska Sctammi.0 GnIs UeE741DB 111 7,18,18- LOCATOR TAIT FMC: 7.BM.G O➢ERE T,BBBDT,�c IPERF;].BI8.6].6980 PRODtICTIONSSS Trs TSTB'; 38.68,YV8 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360S`pNN° OR 3 12015 March 25, 2015 qCommissioner Cathy Foerster Ib0 Alaska Oil& Gas Commission -3-56I 333 West 7th Avenue, Suite 100 )1'\ �_✓ Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion 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 attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043,if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 3-22-2015 2N&2T PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# , PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-315 50103202700000 1981900 _ 6" N/A 13" N/A 4 3/22/2015 2N-339 50103202610000 1981000 8" N/A 25" N/A 8.5 3/22/2015 2T-06 50103200680000 1861070 3` 0.30 25" 8/13/2014 8.5 3/22/2015 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ --/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items o Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~ Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~ildred Daretha Nathan Lowell -- [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si • • /7'; s. THE STATE .klaska Oil and Gas .t �`��', ® Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA. Anchorage, Alaska 99501 -3572 F ALA`,' *� Main: 907.279.1433 Fax: 907.276.7542 Martin Walters SCANNED JUN 2 7 2013 Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 g � Anchorage, AK 99510 g- /0 Re: Kuparuk River Field, Tarn Oil Pool, 2N -339 Sundry Number: 313 -313 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, - 974-4 it — - Cathy P. oerster Chair SP DATED this Zi day of June, 2013. Encl. STATE OF ALASKA 4 .• :, .f-,. z { `. • AL& OIL AND GAS CONSERVATION COMWSION 0 h� 6 5o 113 APPLICATION FOR SUNDRY APPROVALS ((__ 20 AAC 25.280 U� 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Appr Pr raiii r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Sus p. p Well r Stimulate r Alter casing r Other Conductor Extension 1 l✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 198 -100 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20261 -00 . 7. If perforating, What 8. Well Name and Number: 1 Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p 2N - 339 , 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0375074 • 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): 8239 5550 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 108' 108' 1640 630 - SURFACE 2934 7 -5/8 2963' 2305' 6890 4790 PRODUCTION 7546 5 -1/2 7575' 5082' 7000 4990 PRODUCTION 653 3 -1/2 8228' 5541' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7846 -7886, 7846 -7866 . 5275 -5303, 5275 -5289 3.5 L -80 7492 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER 80 -40 SEAL ASSEMBLY • MD = 7473 TVD = 5008 CAMCO DS NIPPLE • MD = 518 TVD = 518 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development , Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WIN J r GINJ r WAG r 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: Martin Walters / MJ Loveland Email: NI878(c�cop.com Printed Name Martin alte Title: Well Integrity Projects Supervisor Signature /7414-9711 Phone: 659 -7043 Date: 06/16/13 Commission Use Only Sundry Number: 313 :3) Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r REIMS JUN 26 201 Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: f d — 4 4 (!1/4g '�-� APPROVED B Approved by: 2-I -' l �QI�QMISSION 1.. TH COMf Date: 4 ' A p 6 pN lication is vd i Oi 2 NEVI ths fro. thnd OT a Form 10 -403 (Reviled 10/2012) Submit Form and Attachments in Duplicate n ��'f `, tar (/L / /f3 ORIGINAL ,,e l • * 1 1.; I :3 2O 3 ConocoPhillips i'-‘‘.00 or Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 16, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N -339, PTD 198 -100 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, /44 U Martin Walters ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -339 (PTD 198 -100) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N -339 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 19 Y2 ". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor IT ,.- KUP • 2N -339 ConocoPhiHips 0`- Well Attributes ___ I Max Angle & MD TD Alaska, ( Wellbore API /UWI Field Name well Status Inc! (1 MD (ftKB) Act Btm (ftKB) canomv'tvlaps 501032026100 TARN PARTICIPATING AREA PRO 55.25 6,250.00 8,239.0 ' "' r Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 55 10/17/2011 Last WO: 34.50 5/30/1998 Well Confi9: - 2N -339, 62312012 9.26 _ 53 AM Last Mod ... End Date Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Tag: SLM 7,947.0 6/22/2012 Rev Reason: TAG I ninam 6/23/2012 Casing Strings . .1/2 III �w Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String .. String Top Thrd IuNOER, 13 CONDUCTOR 16 15.062 29.5 108.0 108.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 29.5 2,963.3 2,305.8 29.70 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 26.6 8,227.6 5,541.6 15.50 L -80 LTC 5.5 "x3.5" @ 7575' Tubing Strings 1 Tubing Description String 0... I String ID .. Top (ftKB) Set Depth (f... !Set Depth (TVD) .. String Wt...'String ... String Top Thrd TUBING 31/2 2.992 12.8 7,492.4 j 5,022.4 9.30 L -80 EUE8RDMOD Completion Details Top Depth (TVD) Top Inc! Noml... Top (M03) (*KB) r) Item Description Comment ID (in) 12.8 12.8 0.69 HANGER FMC GEN V 5M TUBING HANGER 3.500 CONDUCTOR, �. 518.3 517.9 6.54 NIPPLE CAMCO DS NIPPLE 2.875 30.108 7 ,359.6 4,928.5 45.97 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.813" CAMCO DS PROFILE 2.813 lr (CLOSED 11/6/2005) NIPPLE, 518 7,464.8 5,002.7 44.55 NIPPLE CAMCO D NIPPLE 2.750 7,471.9 5,007.8 44.53 LOCATOR BAKER LOCATOR 2.985 IF 7,473.4 5,008.8 44.52 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots - - ..- Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment 7,846 7,886 5,275.5 5,303.8 S -3, 2N -339 7/26/1998 4.0 IPERF 2.5" HC, BH, 180 deg phasing, 90 deg orient 7,846 7,866 5,275.5 5,289.6 S -3, 2N -339 11/8/2005 4.0 APERF 2.5" HP, 60 deg. phase Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) MB) (ftKB) (ftKB) Type Date Comment 7,846.01 7,866.0 5,275.5 5,289.6 FRAC 11/11/2005 FRAC w/185,000# 16/20, 10 ppa ON PERFS Notes: General & Safety End Date Annotation SURFACE. 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 30 -2,963 SLEEVE -C, 7,360 GAS LIFT, 7.411 NIPPLE, 7,465 -- LOCATOR, 7472_ Mandrel Details -- - -- 7,846 Top Depth Top Port APERF. -7866 (TVD) Inc! OD Valve Latch Size TRO Run FRAC, 7,846 - Stn Top (ftKB) (ftKB) (') Make Model (in) Typo Type On) (psi) Run Date Com... IPERF._ 1 7,410.9 4,964.3 44.99 CAMCO KBG - 2 - 9 1 GAS LIFT OV BTM 0.313 0.0 11/132005 7846- 7,886 PRODUCTION 5.5 "x3.5'@ 7575', 27 -8.228 TD, 8,239 -' . . Conoc;pí,illips Alaska Rë.Ct:\VEO SEP 1 2 2007 . sion "\8S\(8 OU & Gas Cons. commlS Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite toO Anchorage, AK 99501 SCANNE.D SEP 12 2007 q<Q~ lo03~ \ ,9..t-\ ~ "3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion 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 corrosion inhibitor/sealant was pumped on September 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ. Loveland at 907-659-7043, if you have any questions. Sincerely, \~/~ ~ ~end 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 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 aal 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5/2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9/5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 Date 9/7/2007 01/20/06 Schlumberger NO. 3663 Schlurnberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth JAN 2 4 2006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~C4&GasCa\S.~ Field: Kuparuk ~ Well Job # Log Description Date BL Color CD -' 1 E-03 11144062 PROD PROFILE W/DEFT 01/14f06 1 - 1 1F-14 11144063 PRODUCTION PROFILE 01/15/06 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 . - - 1 E -06 11154118 PROD PROFILE WIDEFT 01/11/06 1 , - 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILEIWFL 01/13/06 1 3 B -0 5 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 - - 2X-18 11154117 PROD PROFILE WJDEFT 01/10/06 1 2H-09 11154103 PROD PROFILE WIDEFT 12/29/05 1 1 G-11 11154113 '. PROD PROFILE W/DEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z·13 11141242 PROD PROFILE W/DEFT 01/01/06 1 , 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 'PROD PROFILE W/DEFT 01/17/06 1 - 2N-339 '98:(00 ' N/A BHP SURVEY 12/01/05 1 20-04 N/A BHP SURVEY 12103/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1 E -05 11166747 PROD PROFILE W/DEFT 12125/05 1 2 M -0 1 11154119 PROD PROFILE W/DEFT 01/19/06 1 -~ SIGNED: SCANNED JAN 2 5 2005 . . - ~'- DATE:. . 'P V - - - U '\, Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e ConocciP'hillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 5, 2005 ~ECEIVED . £ CIa 2005 Ala'ka Oil & G as Cons Co . AnChorage' mrnlSS10il Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-339 (APD # 198-100) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2N-339. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, JÆJ. Nl~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells ~CAANEC DEC 1 ® 2005 MM/skad · . 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [2] Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory D 198-1001 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20261-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', Pad 121' 2N-339 8. Property Designation: 10. Field/Pool(s): ADL 375074, ALK 4293 Kuparuk River Field 1 Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 8239' feet true vertical 5540' feet Plugs (measured) Effective Depth measured 7984' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 2935' 7-5/8" 2963' 2306' PRODUCTION 7446' 5-1/2" 7474' 5009' PRODUCTION 753' 3-1/2" 8227' 5540' Perforation depth: Measured depth: 7846'-7886' true vertical depth: 5267'-5304' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7474' MD. R8DMS 8Ft DEC 1 :1 2005 Packers & SSSV (type & measured depth) no packer Cameo 'OS' nipple @ 518' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7846'-7866' Treatment descriptions including volumes used and final pressure: 185,000# 16/20,10 ppa on perfs 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 585 622 158 -- 266 Subsequent to operation 661 J 3205 169 247 -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [2] Service D Daily Report of Well Operations _X 16. Well Status after proposed work: 0iI[2] GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Moon~ Title Wells Group Team Lead Signature Jlf I Phone IZ/flIa5 Date 0" ~/l ~ Prenared bv Sharon AlIsu~Drake 263-4612 { I ..~ ~ RECEIVED e STATE OF ALASKA e DEC 1 3 2005 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commi . REPORT OF SUNDRY WELL OPERATIONS sSlon Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only NIP (518-519, OD:3.500) TUBING (0-7474, OD:3.500, ID:2.992) SURFACE (0-2963. OD:7.625, Wt:29.70) 'RODUCTION (0-7474, OD:5.500, Wt:15.50) SLEEVE-C (7360-7361, OD:3.500) Gas Lift I ndrel/Dummy Valve 1 (7411-7412, ODA.OOO) NIP (7465-7466, OD3.500) VALVE (7465-7466, OD:2.750) SEAL (7474-7476. ODA.OOO) 'RODUCTION (7474-8227, OD:3.500. Wt:9.30) FRAC (7846-7866) Perf (7846-7866) Perf (7846-7886) SHOE (8225-8227, OD:3.500) e ConocoPhillips Alaska, Inc. 2N-339 e KRU 2N-339 Ref Lo Date: I ----.ð!:!gle Jfj) TS: I deg @ _... ..._. Angle @..TD: ! 46 deg @. 823~.. Rev Reason: Pull Pump, PERF. FRAC Last U date: 11/12/2005 '-L m API:.5Q10320261.D9_';'. _.m Well Type.JPROD SSSV.:rype:: Nip'p~._ .----.:....Origg9mpletion: ; !:j/]!:J/1998 Annular Fluid: . . Last W/O: Interval 7846 - 7866 7866 - 7886 TVD 5276 - 5290 5290 - 5304 Zone KBG29 62?'Q.._ ....-.-- ..---...-----"------- To Bottom TVD Wt 0 108 108 62.58 0 2963 2306 29.70 0 7474 5009 15.50 7474 8227 5541 9.30 Thread Welded BTC LTC 8RD Status Ft SPF 20 8 20 4 Date 11/8/2005 7/26/1998 Comment Ff3j\C w/185,000#16(20, 10 ppa ON PEf3FS ...---..-..-- V Mfr Vlv Cmnt CAMCO - ---.----.... Cameo 'OS' Ni Ie. Baker CMU Size 2.813" w/Camco OS CAT SV set 11/6/2005 Cameo '0' Ni Ie. Baker 80-40 Seal Ass ID 2.875 2.813 0.000 2.750 2.985 2.992 Date Note 12/20/2002 SUSPECT LOOSE FISHING NECK ON CS LOCK e 2N-339 Well Events Summary e Date Summary 11/06/05 GAUGE TBG TO 7360' RKB W/2.85" GAUGE RING, PULLED 3" RC JET PUMP FROM 7360' RKB, DRIFT & TAGGED FILL W/2.5" X 12' DUMMY GUN @ 7870' RKB, SET CAT SV @ 7465' RKB, LOADED IA WITH 230 BBLS OF DIESEL ;& CLOSTED SLIDING SLEEVE @ 7360'. 11/07/05 PRESSURE TESTED TBG & IA TO 3500 PSI, BOTH HELD SOLID, PULLED 2.75" SV @ 7465' RBK & DRIFTED TBG & TAGGED FILL W/20' - 2.5" DUMMY GUNS, TAGGED @ 7872' RKB, NO PROBLEMS. 11/08/05 PERFORATE FROM 7846'-7866' USING 20' 2.5" HSD 2506 HYPERJET 6 SPF 60 DEG PHASED. FOUND TO AT 7904' 11/11/05 PUMPED RE-FRAC, INCLUDING 1100 BBL BRACKETFRAC STAGE. FRAC DESIGNED WITH 1-7 PPA RAMP STAGE, THEN 9 AND 10 PPA STAGE. PLACED 185,000# 16/20 CARBOLlTE IN FORMATION, 10 PPA ON PERFS, FLUSHED TO COMPLETION. 100% OF DESIGN. 11/12/05 FOLLOWING FRACTURE TREATMENT, CLEANED OUT FILL IN 3.5" LINER TO 8057' CTD. PUMPED DIESEL & DIESEL GEL THROUGH 1.75" JET SWIRL NZL. 11/13/05 TAGGED @ 7830' RKB, EST. 56' FILL. SET 5/16" OV @ 7411' RKB. Re: Jet Pumped Wells Subject: Re: Jet Pumped \Vells From: "NSK Problem Well Supv" <nI617@'conocophillips.com> Date: Sat, 7 Dec 2002 14:07:01 -0900 To: TOTI1 Maunder <tom_maunder@)adn1in.state.ak.us> CC: "n 1617" <n 1617@'conocophillips.con1> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently 51 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2 N - 3 0 3 (PTD 2 0 0 16 9 0 ) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) ~'''...,:~r 2 N - 3 3 9 (PTD 1981 0 0 0 ) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tom maund.er',;'ì,1admin. state. i:tk. us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails f h'l b rom aWl e ack regarding the wells out there on jet pumps. Would you please provide an updated listing of the wells presently on jet pumps in greater KRU?? Thanks in advance. To Well Compliance Report File on Left side of folder ..... i'98'2i0020 ~~'~"UT~ 2N-339 50_ 103_20261_00 MD 08239 f TVD 05540 '/~'~mpletion Date: 5/30/98 '~Completed Status: 1-OIL ARCO Current: T Name ~,lnterval D ~ ............. ~'" ~p'~RRy ~PT/~WR4i~N~iSi~ .... 0H 7/8/98 L DGR/EWR4-MD FINAL. _9~70~8239 OH 7/15/98 .. L DGR/EWR4-TVD FINA~5-5540 OH 7/15/98 R GYRO CONT. MULTI L~CrY~,ODATA TBNG 0-8007. CH · R SRVY DATA ~3T~RRY 0-8239. OH Daily Well Opsff/[q,/c//?---- .~,/k),~/~ Are Dry Ditch Samples Required? yes ~ Was the well cored? yes ~_.. Analysis Description Receive--- Sent Received Comments: 12/7/98 9/1/98 7/8/98 7/15/98 7/15/98 12/7/98 9/2/98 T/C/D A.nfl Received? y~.-no---- Sampie Sei"# .... Monday, May 01, 2000 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 1, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-339 (Permit No. 98-100) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-339. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tam Drilling Team Leader PM/skad RECEIVED oEP 64 Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~-~ GAS [~] SUSPENDED r-] ABANDONED~ SERVICE r-'] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-100 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-103-20261 4 Location of well at surface 9 Unit or Lease Name 124' FNL, 1026' FEL, Sec. 3, T9N, R7E, UM i '-~"~' "~'~'~'E'~ i! Kuparuk River Unit At Top Producing Interval : _~'/~. .i ~~: t 10 Well Number 2264' FNL, 517' FEL, Sec. 4, TON, R7E, UMTotal Depth i h/cr~, :.':..,,-:,~.._~Z~._(_...~ ~'.f '--}..,.. ? ~ .... ~I 11 Field and Pool At 2374' FNL, 948' FEL, Sec. 4, T9N, R7E, UM *'~- ......... ~"~-~>~' Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tam Oil Pool RKB 28', Pad 121' ADL375074 ALK 4293 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp, or Aband. 115 Water Depth, if offshore J 16 No. of Completions 20-Ma¥-98 27-Ma¥-98 30-Ma¥-98I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 18239' MD & 5540' 'I'VD 8069' MD & 5422' TVD YES ~ NO ~ NA feet MD 1258 APPROX 122 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58~ H-40 SURF. 108' 24' 9 cu. yds High Early 7.625' 29.7# L-80 SURF. 2963' 9.875' 44 sx ASIII, 240 sx Class G 5.5' x 15.5# L-80 SURF. 7475' 6.75' 230 sx Class G 3.5' 9.3# L-80 7475' 8228' 6.75' (included above) 24 Perforations open to Production (MD+'I'VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 7492' 7475' (CSR) 7846'-7886' MD 5267'-5295' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7846'-7886' 231,195# proppant in formation with 1459# proppant left in wellbore 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/~/9sI Fiowinc,! Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBl. CHOKE SIZE I GAS-OIL RATIO 8/25/98 6.00 TEST PERIOI: 371 355 0 176I 956 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (coif) Press. 245 0 24-HOUR RATE: 1485 1419 25 39° 28 CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A 1998 00tlS. ' ....... COl'/lml$slo~: ~hor~ge Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , Top Reservoir Ct3) 7633' 5115' Base Reservoir (T2) 7904' 5307' Annulus left open - freeze protected with diesel. 31. LIST OF AI-rACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Date: 7/30/98 ARCO ALASKA INC. Page: 1 WELL SUMMARY REPORT WELL:2N-339 WELL_ID: AK9501 TYPE: AFC: AK9501 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER I/NIT SPUD:05/20/98 START COMP: RIG:RIG # 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20261-00 BLOCK: FINAL:05/30/98 05/19/98 (D1) TD: 80'( 80) SUPV:RWS MW: 0.0 VISC: 0 PV/YP: 0/ 0 Mixing spud mud APIWL: Move rig from 2N-343. N/U diverter system and function test. Accepted rig @ 1400 hrs. 5/19/98. 0.0 05/20/98 (D2) TD: 1350'(1270) SUPV:RWS MW: 10.0 VISC: 66 PV/YP: 23/27 Drilling @ 1980' Drilled from 108' to 1350'. APIWL: 10.6 05/21/98 (D3) TD: 2970'(1620) SUPV:RWS MW: 9.9 VISC: 52 PV/YP: 24/21 Landing csg, preparing to circ APIWL: Drilled from 1350'- 2970'. Downtime, problems with Sperry-Sun readout. Rig up to run casing. Run 7-5/8" casing. 5.6 05/22/98 (D4) TD: 2970'( SUPV:RWS 0) MW: 9.8 VISC: 44 PV/YP: 16/11 APIWL: 5.6 Nippling up BOPE Run 7-5/8" casing. Pump 1st stage cement job. Pump 2nd stage cement job. N/D diverter system. 05/23/98 (D5) TD: 2970'( SUPV:RWS 0) MW: 8.5 VISC: 40 PV/YP: 6/ 8 APIWL: 9.8 Testing Csg N/D diverter system. N/U BOPE and test 300/3500 psi. OK. Attempt to test casing, unable to pressure up. 05/24/98 (D6) TD: 3169'(199) SUPV:RWS MW: 8.5 VISC: 37 PV/YP: 9/ 9 APIWL: 8.4 Drilling Drilling stage collar, wash down to 1721'. Attempt casing test, no test. Set retrievamatic test packer. Drill baffle plate, float collar, shoe and rathole. Drill from 2970'- 2990'. Perform LOT to 15.8 ppg EMW. 05/25/98 (D7) TD: 4987'(1818) SUPV:RWS MW: 9.0 VISC: 43 PV/YP: 13/15 APIWL: 5.6 Drilling 5760' Drilled from 3169' to 5298' Date: 7/30/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/26/98 (DS) TD: 7026'(2039) SUPV:DB MW: 9.2 VISC: 42 PV/YP: 14/15 Drilling 6.75" hole from 7420' Drilled 6.75" hole from 5298' to 7026'. APIWL: 5.2 05/27/98 (D9) TD: 8239' (1213) SUPV: DB MW: 9.7 VISC: 48 PV/YP: 18/22 Slip & cut drilling line Drill 6.75" hole from 7026' to 8239'. APIWL: 4.0 05/28/98 (D10) TD: 8239' ( 0) S UPV: DB MW: 9.8 VISC: 46 PV/YP: 16/20 Conditioning mud for cementing prod. casing Run 3.5" completion tubing APIWL: 4.4 05/29/98 (Dll) TD: 8239'( 0) SUPV:DB MW: 9.7 VISC: 44 PV/YP: 20/15 Running 3.5" completion tubing Continue to runn 3.5" x 5.5" production casing. cement. ND BOPE, NU BOPE. Run 3.5" completion. APIWL: 5.2 Pump 05/30/98 (D12) TD: 8239' ( 0) SUPV: DB MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Moving rig to 2N-337 Run 3.5" tubing. Freeze protect well. Release rig ~ 1800 hrs. 5/30/98 End of WellSummary for Well:AK9501 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-339(W4-6)) ~,VELL JOB SCOPE JOB NUMBER " 2N-339 PERFORATE, PERF SUPPORT 0719981447.4 DATE DAILY WORK UNIT NUMBER 07/26/98 RUN GR/CCL LOG & PERFORATE 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES SWS-ELMORE JONES FIELD AFC,~ CC# Signed ESTIMATE K85115 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 30 PSI 500 PSI 520 PSII 60 PSIJ 250 PSI DAILY SUMMARY SWS RAN A GR/CCL LOG FROM 7290' TO 8050'. PERFED IN 2 RUNS FROM 7846' TO 7886' WITH 2.5" HC, BH, 4 SPF, 180 DEG I PHASED, 90 DEG ORIENT.[Perf] I TIME LOG ENTRY O8:15 SWS MIRU, HELD TGSM. MU TOOLS & PT LUB TO 3000#. 09:30 MIH W/CPLC, WB. RAN GR/CCL JEWERLY LOG FROM 8050' TO 7290' & CORR TO SPERRY SUN LOG 5-28-98. 10:45 POH & LD TOOLS. 11:30 MU GUN & PT LUB TO 3000#. 12:30 MIH W/20' - 2.5" HC, BH, 4 SPF, -180 DEG PHASED, 90 DEG ORIENT, SAFE, MPD, CCL. CORR TO SWS GR/CCL LOG 7-26-98 & PERFED FROM 7866' TO 7886' W/200 PSI WHP. 13:45 POH & LD GUN, ALL SHOTS FIRED. 14:45 MU 20' - 2.5" HC GUN AS ABOVE & MIH. CORR TO ABOVE LOG & PERFED FROM 7846' TO 7866' W/200 PSI WHP. 16:15 POH & LD GUN, ALL SHOTS FIRED. 17:00 RIG DOWN. 17:45 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-339(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-339 FRAC, FRAC SUPPORT 0801982028.5 DATE DAILY WORK UNIT NUMBER 08/02/98 TARN SAND FRACTURE STIMULATION DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-GALLEGOS JORDAN FIELD AFC# CC# Signed ESTIMATE KAWWRK 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 55 PSI 0 PSI 103 PSI 500 PSII 300 PSII 300 PSI DALLY SUMMARY ITARN SAND FRAC PRESSURED OUT DURING FLUSH STAGE. 231,195 LB PROPPPANT PLACED IN FORMATION WITH 1459 LB ~ PROPPANT LEFT IN WELLBORE. MAX, TREATING PRESSURE 7200 PSl.[Frac-Refrac] I 'rIME LOG ENTRY 07:00 MIRU DS FRAC UNIT - GALLAGOS; LRS; APC. TGSM. PT LINES TO 9275 PSI OK. 11:18 PUMP HIGH RATE BREAKDOWN. ISIP 1479 PSI. 12:02 PUMP DATA FRAC. ISIP 1058 PSI. 12:51 PUMP BREAKDOWN AND SCOUR STAGE. ISIP 893 PSI. PUMP PULSES AND SB FOR ENGINEERING ANALYSIS. 14:49 PUMP FRAC ACCORDING TO REDESIGN 7 PPA MAX. BEGIN FLUSH STAGE AND BEGIN PUMPING DIESEL EARLY. 17:13 17:17 19:00 TARN SAND FRAC PRESSURED OUT 6 BBL EARLY DURING FLUSH STAGE. 231,195 LB PROPPPANT PLACED IN FORMATION WITH 1459 LB PROPPANT LEFT IN WELLBORE. MAX TREATING PRESSURE 7200 PSI. WELLBORE FP WITH 7 BBL DIESEL. :RDMO DS FRAC UNIT. RECOVERED ALL TREE SAVER ELEMENTS. SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer .,. ' ARCO Platform ... ' 2N Slot/Well ..' /339 MEASURED ANGLE DIRECTION DEPTH DEG DEG TVD NORTHINGS EASTINGS VERTICAL FEET FEET SECTION DOG LEG 0.00 0,00 0,00 108.00 0.00 0,00 155,16 0.88 83.21 247.13 0.93 90.57 337.55 1.42 162.72 0,00 108.00 155,16 247,12 337,52 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0,00 0.00 0.04 N 0.36 E -0.35 1.87 0.12 N 1,81 E -1.70 0.14 0.96 S 2.87 E -2.25 1,59 429.76 3.80 190.75 518,62 7.09 198.06 607,30 10.83 201.31 698.32 14,69 203.10 790.93 19.48 205.32 429,63 518.08 605.66 694,42 782.92 5.05 S 2.64 E -0.40 2,85 13.16 S 0.39 E 4.91 3.78 26.13 S 4.33 W 14.43 4.25 44,72 S 11.97 W 28.87 4,26 69.49 S 23.19 W 49.07 5.22 880.34 21.05 208.37 866 971.26 23.85 214.62 950 1060.16 28.33 219.51 1030 1151.46 31.79 224.48 1109 1241.87 34.50 227.83 1185 .79 .83 .66 .68 .38 97,10 S 37.20 W 72.96 126,60 S 55.40 W 101.46 157,69 S 79.05 W 135.57 191,58 S 109.70 W 177.22 225.77 S 145.37 W 223.60 2.12 4.04 5.59 4,67 3.62 1330.94 34.45 228.68 1258,80 1420.78 35,92 232,83 1332,24 1515.69 38,54 236.87 1407.81 1610.71 40,77 243,28 1480,99 1706.55 44.46 246.61 1551.52 259.33 S 182.98 W 271.51 292.04 S 223.08 W 321.34 325.03 S 270.04 W 377.58 355,18 S 322.57 W 437.78 382.58 S 381.35 W 502.62 0.54 3,12 3.77 4,90 4.51 1803.20 48.53 249.11 1618 1897.43 52.49 248.91 1677 1991.44 52.57 248.98 1735 2084.94 55.13 248.83 1790 2180.35 54.64 247.55 1845 .05 .96 .15 .30 .19 408.95 S 446.28 W 572.68 434,99 S 514.16 W 645.31 461,80 S 583,79 ~ 719.85 488.97 S 654,22 W 795.27 517,96 S 726,68 W 873.27 4.61 4.21 0.10 2.74 1.21 2274.78 54.25 246.72 1900.10 2369.96 54.86 248.09 1955,29 2463.90 54.30 249.05 2009.74 2556.83 54.17 250.73 2064.06 2662.94 53.99 250.38 2126.31 547.81 S 797.47 W 950.09 577.60 S 869.06 W 1027.61 605.57 S 940.31 W 1104.11 631.50 S 1011.12 W 1179.37 660.10 S 1092.15 W 1265.08 0.83 1.34 1.02 1.47 0.32 2758.74 54.74 248.85 2182.12 2852.62 54.32 248.97 2236.60 2927.02 53.99 248.47 2280.17 3006.07 53.65 247.05 2326.83 3091.09 53.71 247.17 2377.19 687.23 S 1165,13 W t342.81 714,74 S 1236.46 W 1419.19 736.63 S 1292.66 W 1479.45 760.77 S 1351.72 W 1543.24 787.42 S 1414.83 W 1611.74 1.52 0.46 0.70 1.51 0.13 3185.18 54.11 247.18 2432.61 3279.40 54.26 247.35 2487.75 3372.69 54.10 247,86 2542.35 816.91 S 1484.91 W 1687.76 846.44 S 1555.37 W 1764.16 875.26 S 1625.31 W 1839.79 0.43 0.22 0.48 SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer ,,. : ARCO Platform,,. : 2N Slot/Well ,, ' /339 MEASURED ANGLE DIRECTION DEPTH DEG DEG TVD NORTHINGS EASTINGS 'VERTICAL FEET FEET SECTION DOG L~G 3467,23 53.62 247,08 2598.10 3561.22 53,41 247.61 2653.99 3655.59 53.39 247,34 2710,26 3750,09 53,48 247,01 2766.55 3844.17 54.05 247,72 2822.16 904.51 S 933.62 S 962.65 S 992,09 S 1021,29 S 1695.83 W 1916.12 0.84 1765.57 W 1991.68 0.51 1835.55 W 2067.43 0.23 1905.51 W 2143.32 0.30 1975.55 W 2219.19 0.86 3938,16 53.79 248,95 2877 4032.35 54.00 248,21 2933 4126.97 54.26 247,89 2988 4222,46 54.26 248.90 3044 4316.39 54,63 249.49 3098 .52 .02 .46 .24 .86 1049.34 S 1077.13 S 1105.79 S 1134,33 S 1161.47 S 2046.14 W 2295.11 1.09 2116.99 W 2371.15 0,67 2188.10 W 2447,80 0.39 2260.16 W 2525.26 0.86 2331.60 W 2601.58 0,65 4418,84 54.85 249,28 4511.93 55.04 249.85 4604.17 52.81 248,21 4699.01 52.27 248.04 4792,21 52,42 248.81 3158.00 3211.47 3265,79 3323,47 3380,40 1190.92 S 2409.89 W 2685.12 1217.53 S 2481.30 W 2761.21 1244.19 S 2550.91 W 2835.67 1272.24 S 2620.77 W 2910.92 1299.37 S 2689.39 W 2984,66 0.27 O,54 2,81 0.59 0,67 4887.17 52.33 248.32 3438.38 4978.98 52,54 248,52 3494,35 5073.94 52.54 248.51 3552.11 5166.85 52.54 249.11 3608,61 5251.22 52.51 249.33 3659.95 1326.86 S 2759.40 N 3059.82 1353,62 S 2827.07 W 3132.55 1381.23 S 2897.21 W 3207.87 1407.89 S 2965.97 W 3281.56 1431.64 S 3028.58 W 3348.43 0,42 0.29 0.01 0.51 0.21 5346.74 52.86 249,04 3717 5441.07 52.92 249.79 3774 5534,55 52,32 249,87 3831 5629.52 53.43 250.21 3888 5723.57 54,02 249.89 3944 ,85 ,76 .52 .83 .48 1458.64 S 1485.09 S 1510.70 S 1536,55 S 1562.42 S 3099.59 W 3424.31 0,44 3170.01 W 3499.43 0.64 3239,73 W 3573.58 0.65 3310,91 W 3649.15 1.20 3382.18 W 3724.81 0.68 5817.56 54,28 250.21 3999.53 5911.56 54,66 250,81 4054.15 6006.49 55,15 250,55 4108.73 6100.29 54,67 251.03 4162.65 6194.56 55,02 251,75 4216.93 1588.41 S 1613,93 S 1639,63 S 1664,89 S 1689,48 S 3453.79 W 3800.84 0.39 3525,90 W 3877.14 0.66 3599.20 W 3954.60 0.56 3671,68 W 4031.13 0.66 3744.72 W 4107.91 0,73 6298.82 53.93 250.37 6392,38 54,21 248,90 6485.20 52,91 247,39 6580.08 53,18 246.04 6674,38 53,45 246.20 4277,52 4332.42 4387,55 4444.60 4500,93 1717.01 S 3824.98 W 4192.47 1743.38 S 3896.00 N 4268.11 1771.17 S 3965.30 W 4342.74 1801.14 S 4034.94 W 4418.56 1831.75 S 4104,09 W 4494.18 1.50 1,31 1.92 1.17 0,32 6768.35 53,39 247.21 4556.93 6863.30 53,56 246.31 4613.45 6947.88 54.03 247.12 4663.41 1861.59 S 4173.40 W 4569.63 -1891.70 S 4243.51 W 4645.93 1918.68 S 4306,20 W 4714.18 0.87 0.78 0.95 SPERRY-SUN DRILLING SERVICES SURVEY DATA Customer .,, : ARCO Platform .,. : 2N Slot/Well ,, . /339 MEASURED ANGLE DIRECTION TVD NORTHINGS EASTINGS DEPTH DEG DEG FEET FEET VERTICAL SECTION DOG LEG 7040.53 54.32 246.99 4717,63 1947.96 S 4375.38 W 7135.12 53,05 247,57 4773.65 1977.40 S 4445.68 W 7227.49 49.94 247.38 4831.15 2005.09 S 4512.44 W 7323.05 46,42 248.13 4894.86 2032.06 S 4578.34 W 7415,63 44,61 247.17 4959.73 2057.16 S 4639.42 W 4789.30 4865.50 4937.77 5008.95 5074,98 0.33 1.43 3.37 3.73 2.09 7511.40 44.49 247.54 5027.98 2083.03 S 4701,43 W 7606.11 43.89 248.58 5095.89 2107.70 S 4762.66 W 7699.08 44.52 251.25 5162.55 2129.95 S 4823.53 W 7802.80 44.93 250.89 5236.24 2153.63 S 4892.57 W 7897,14 45,52 252.02 5302.68 2174.92 S 4956.06 W 5142.16 5208.14 5272.83 5345.57 5412.28 0.30 0.99 2.11 0.46 1.06 7991.64 46.21 251.83 5368.49 2195,97 S 5020.54 W 8085.37 45,99 251.91 5433.48 2216,98 S 5084.72 W 8161.42 46,06 251.76 5486.29 2234.04 S 5136.73 W 8239.00 46.06 251.76 5540.12 2251.53 S 5189.78 W 5479.79 5547.02 5601.50 5657.12 0.74 0.24 0.17 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET. N/E COORDINATE VALUES GIVEN RELATIVE TO WELL SYSTEM REFERENCE POINT. TVD COORDINATE VALUES GIVEN RELATIVE TO WELL HEAD. THE VERTICAL SECTION ORIGIN IS WELL HEAD, THE VERTICAL SECTION WAS COMPUTED ALONG 246.40 (TRUE). CALCULATION METHOD: MINIMUM CURVATURE. ORiGiNAL ARCO ALASKA INC. DRILLSITE 2N, WELL NO. 2N-339 TARN POOL, ALASKA Gyro Continuous Muitishot Survey Inside 3.5" TUBING Survey date: 06-OCTOBER, 1998 Job number: AK1098GCE500 RECEIVED DEC 07 19c)8 Alaska 0it & Gas Oon~. Conlm~{oll CONTENTS JOB NUMBER · AK1098GCE500 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER: AK1098GCE500 Tool 791 was run in WELL# 2N-339 on SCHLUMBERGER 7/32" wireline inside 3.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: AK1098GCE500 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. .-_ This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1098GCE500 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2N WELL: 2N-339 LATITUDE: 70.25 N LONGITUDE: 150.0 W SURVEY DATE: 06 -OCTOBER, 1998 SURVEY TYPE : GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 147.3 MAX. SURVEY DEPTH: SURVEY TIED ONTO: 8007' N/A SURVEY INTERVAL: 0-8007' APl NUMBER: TARGET DIRECTION: 050-103-20261-00 246.4 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyro da t a D i r e c t i o na i S u rvey for ARCO ALASKA INC. WELL: 2N-339, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA ob Number: AK1098GCE500 un Date: 6-Oct-98 10:45:00 urveyor: TOM STODDARD alcu. lation Method: MINIMUM CURVATURE urvey Latitude: 70.250000 deg. N ,ub-sea Correction from Vertical Reference: 147.3 ft. ~zimuth Correction: Bearings are Relative to True North ~roposed Well Direction: 246.400 deg rertical Section Calculated from Well Head Location :losure Calculated from Well Head Location [orizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i o na i Survey [CO ALASKA INC. ~LL: 2N-339, 3.5" )cation: DRILLSITE 2N, ~b Number~ AK1098GCE500 TARN POOL, ALASKA ~ASURED I N C L AZIMUTH DOGLEG )EPTH SEVERITY feet deg. deg. deg./ ~ 100 ft. 0.0 0.00 0.00 0.00 100.0 .73 89.92 .73 200.0 .77 95.59 .08 300.0 .75 112.55 .22 410.0 2.74 184.83 2.37 500.0 5.82 197.67 3.57 600.0 9.75 198.65 3.93 700.0 14.52 202.31 4.83 750.0 16.].2 204.79 3.45 800.0 19.48 206.04 6.77 850.0 20.40 207.34 2.03 900.0 21.10 208.42 1.60 950.0 23.03 212.40 4.88 1000.0 24.46 215.29 3.69 ].050.0 27.07 218.57 5.94 1100.0 29.59 221.28 5.66 1150.0 31.].3 223.15 3.63 1200.0 32.85 225.35 4.15 ].250.0 34.35 227.20 3.63 1300.0 34.36 227.78 .65 1350.0 34.78 227.97 .87 1400.0 35.66 229.96 2.89 1450.0 35.99 232.42 2.96 1500.0 37.40 234.93 4.11 1550.0 38.90 237.36 4.24 VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 0.0 -147.3 0.0 100.0 -47.3 -.6 200.0 52.7 -1.7 300.0 152.7 -2.8 409.9 262.6 -2.0 499.7 352.4 2.0 598.7 451.4 11.0 696.5 549.2 25.8 744.7 597.4 35.5 792.3 645.0 47.0 839.3 692.0 60.1 886.0 738.7 74.0 932.4 785.1 89.2 97812 830.9 106.2 1023.2 875.9 125.1 1067 . 2 919 · 9 146 . 3 1110.3 963 .0 169.4 ].152.7 1005.4 193.9 1194 . 4 1047 . 1 219 . 9 1235 . '7 1088 · 4 246 . 6 1276.8 1129.5 273.5 1317.7 1170.4 301.0 1358.2 1210.9 329.2 1398.3 1251.0 358.4 1437.6 1290.3 388.8 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 0.0 .6 90.0 1.9 91.9 3.2 96.7 4.9 131.9 10.0 168.0 22.7 185.5 43.4 192.9 56.4 195.4 71.5 197.5 88.4 199.3 105.9 200.7 124.4 202.2 144.2 203.8 165.4 205.5 188.5 207.3 213.0 209.1 238.7 210.7 265.4 212.3 292.8 213.8 320.3 215.0 348.4 216.2 376.7 217.3 405.5 218.5 435.0 219.7 0.0 N 0.0 E .0 N .6 E .1 S 1.9 E .4 S 3.2 E 3.3 S 3.6 E 9.8 S 2.1 E 22.6 S 2.2 W 42.3 S 9.6 W 54.4 S 14.9 W 68.2 S 21.5 W 83.4 S 29.2 W 99.1 S .37.5 W 115.2 S 47.0 W 131.9 S 58.2 W 149.3 S 71.3 W 167.5 S 86.5 W 186.2 S 103.5 W 205.1 S 122.0 W 224.2 S 142.0 W 243.3 S 162.8 W 262.3 S 183.8 W 281.3 S 205.6 W 299.6 S 228.4 W 317.3 S 252.5 W 334.5 S 278.1 W A Gy r o d a t a D i r e c t i o n a i S u rv e y [CO ALASKA INC. ~LL: 2N-339, 3.5" }cation: DRILLSITE 2N, }b Number: AK1098GCES00 ~ASURED }EPTH feet I N C L AZIMUTH deg. deg. 1.600.0 1650.0 1700.0 1750.0 1800.0 40.01 241.13 41.19 243.65 43.67 245.42 45.30 246.55 47.86 247.83 1850.0 1900.0 ].950.0 2000.0 2050.0 49.59 248.04 51.96 248.34 52.81 248.37 52.78 248.39 53.74 248.38 2].00.0 2150.0 2200.0 2250.0 2300.0 54.85 248.29 55.04 248.38 54.74 248.25 54.32 248.18 54.54 247.95 2350.0 2400.0 2450.0 2500.0 2550.0 54.85 248.76 54.86 249.17 54.60 249.23 54.39 249.17 54.56 249.17 2600.0 2650.0 2'700.0 2750.0 2800.0 54.29 248.97 54.36 248.82 54.44 248.28 54.88 246.96 54.83 246.87 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 5.29 1476.2 1328.9 420.3 4.03 1514.2 1366.9 452.7 5.51 1551.1 1403.8 486.5 3.62 1586.8 1439.5 521.5 5.45 1621.1 1473.8 557.8 3.46 1654.1 1506.8 595.4 4.76 1685.7 1538.4 634.1 1.71 1716.3 1569.0 673.7 .07 1746.5 1599.2 713.5 1.92 1776.4 1629.1 753.5 2.22 1805.6 ].658.3 794.1 .41 1834.3 1687.0 835.0 .64 1863.1 1715.8 875.9 .85 189211 1744.8 916.6 .57 1921.2 1773.9 957.2 1.45 1950.1 1802.8 998.0 .68 1978.9 1831.6 1038.8 .54 2007.7 1860.4 1079.6 .44 2036.8 1889.5 1120.3 .35 2065.8 1918.5 1160.9 CLOSURE DIST. AZIMUTH feet deg. Page 465.1 221.1 495.5 222.4 526.9 223.8 559.5 225.2 593.3 226.5 HORIZONTAL COORDINATES feet 628.4 227.7 664.9 228.9 702.3 230.0 740.2 230.9 778.5 231.8 817.5 232.6 857.0 233.4 896.6 234.1 936.1 234.7 975.7 235.2 1015.5 235.7 1055.4 236.2 1095.2 236.7 1135.0 237.2 1174.8 237.6 .63 2094.9 1947.6 1201.5 1214.7 238.0 .29 2124.1 1976.8 1242.1 1254.6 238.3 .90 2153.2 2005.9 1282.7 ].294.6 238.6 2.32 2182.1 2034.8 1323.5 1334.9 238.9 .18 2210.9 2063.6 1364.4 1375.4 239.1 350.7 S 365.8 S 380.3 S 394.5 S 408.6 S 422.7 S 437.1 S 451.7 S 466.4 S 481.2 S 496.1 S 511.3 S 526.4 S 541.5 S 556.7 S 571.7 S 586.4 S 600.9 S 615.3 S 629.8 S 644.3 S 659.0 S 673.8 S 689.4 S 705.4 S 305.4 W 334.3 W 364.7 W 396.7 W 430.2 W 465.0 W 501.0 W 537.8 W 574.8 W 612.1 W 649.8 W 687.8 W 725.8 W 763.6 W 801.4 W 839.3 W 877.5 W 915.6 W 953 . 7 W 991.7 W 1029.7 W 1067.6 W 1105.4 W 1143.1 W 1180.7 W A Gy r o d a t a D i r e c t i o n a i S u rv e y RCO ALASKA INC. ELL: 2N-339, 3.5" ~cation: DRILLSITE 2N, ob Number: AK1098GCE500 EASURED DEPTH feet I N C L AZIMUTH deg. deg. 2850.0 54.37 246.78 2900.0 54.37 246.69 2950.0 54.14 246.71 3000.0 53.24 246.63 3050.0 53.93 246.59 31.00.0 53.74 246.44 3150.0 53.75 246.48 3200.0 54.16 246.44 3250.0 54.30 246.47 3300.0 54.48 246.50 3350.0 54.26 246.65 3400.0 53.87 246.76 3450.0 53.69 246.84 3500.0 53-.35 246.85 3550.0 53.40 246.88 3600.0 3650.0 3700.0 3750.0 38OO.0 53.48 246.94 53.29 246.93 53.36 247.14 53.29 247.00 53.85 246.91 3850.0 53.89 247.09 3900.0 53.92 247.18 3950.0 53.86 248.57 4000.0 53.55 248.79 4050.0 54.16 249.05 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .93 2239.8 2092.5 1405.1 .15 2269.0 2121.7 1445.8 .45 2298.2 2150.9 1486.4 1.81 2327.8 2180.5 1526.7 1.38 2357.5 2210.2 1566.9 .45 2387.0 2239.7 1607.3 .06 2416.5 2269.2 1647.6 .83 2446.0 2298.7 1688.0 .28 2475.2 2327.9 1728.6 .35 2504.3 2357.0 1769.2 .49 2533.4 2386.1 1809.9 .80 2562.8 2415.5 1850.3 .38 2592.3 2445.0 1890.7 .68 2622~0 2474.7 1930.9 .09 2651.9 2504.6 1971.0 .20 2681.7 2534.4 2011.2 .38 271]..5 2564.2 2051.3 .36 2741.3 2594.0 2091.4 .25 2771.2 2623.9 2131.5 1.].3 2800.9 2653.6 2171.7 .30 2830.4 2683.1 2212.1 .16 2859.8 2712.5 2252.5 2.24 2889.3 2742.0 2292.9 .72 2918.9 2771.6 2333.2 1.29 2948.4 2801.1 2373.5 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 1415.8 239.4 1456.1 239.6 1496.4 239.8 1536.4 '239.9 1576.4 240.1 1616.5 240.3 1656.6 240.4 1696.8 240.6 1737.1 240.7 1777.6 240.8 1818.0 241.0 1858.3 241.1 1898.5 241.2 1938.5 241.3 1978.4 241.4 2018.4 241.5 2058.4 241.7 2098.3 241.8 2138.2 241.9 2178.3 241.9 2218.5 242.0 2258.8 242.1 2299.0 242.2 2339.0 242.3 2379.1 242.5 721.4 S 1218.2 W 737.5 S 1255.5 W 753.5 S 1292.8 W 769.5 S 1329.8 W 785.5 S 1366.7 W 801.6 S 1403.8 W 817.7 S 1440.7 W 833.8 S 1477.8 W 850.0 S 1515.0 W 866.2 S 1552.2 W 882.4 S 1589.5 W 898.4 S 1626.7 W 914.3 S 1663.8 W 930.1 S 1700.8 W 945.9 S 1737.7 W 961.6 S 1774.6 W 977.3. S 1811.5 W 993.0 S 1848.5 W 1008.6 S 1885.4 W 1024.4 S 1922.4 W 1040.1 S 1959.6 W 1055.8 S 1996.8 W 1071.1 S 2034.2 W 1085.7 S 2071.8 W 1100.2 S 2109.4 W A Gy r o d a t a D i r e c t i o n a i S u rv e y .CO ALASKA INC. :LL: 2N-339, 3.5" ,cation: DRILLSITE 2N, ~b Number: AK1098GCE500 :ASURED I N C L AZIMUTH )EPTH feet deg. deg. [100.0 54.08 249.06 [150.0 · 54.11 249.14 ~200 . 0 54 . 32 249 . 25 L250 . 0 54 . 22 249 . 31 ~300.0 54.4'7 249.39 t350.0 54.48 249.28 ~400 . 0 54 . 64 249 . 22 t450.0 55.04 249.07 ~500.0 54 . 88 248.85 ~550.0 55.16 248.69 3600.0 53.61 248.11 ~650.0 52.32 247.60 ~700.0 52.34 247.67 3750.0 '52.05 247.88 3800.0 52.55 247.99 4850.0 52.28 248.01 4900.0 52.21 248.08 4950.0 52.42 248.21 5000.0 52.25 248.23 5050.0 52.58 248.29 5100.0 52.46 248.46 5]..50.0 52.27 248.56 5200.0 52.87 248.75 5250.0 52.39 248.62 5300.0 52.23 248.73 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .17 2977.7 2830.4 2414.0 .15 3007.0 2859.7 2454.4 .45 3036.3 2889.0 2494.9 .21 3065.4 2918.1 2535.5 .50 3094.6 2947.3 2576.0 CLOSURE DIST. AZIMUTH feet deg. 2419.4 242.6 2459.6 242.7 2499.9 242.8 2540.3 242.9 2580.6 243.0 .18 3123.6 2976.3 2616.7 2621.1 243.1 .33 3152.6 3005.3 2657.4 2661.6 243.2 .84 3181.4 3034.1 2698.2 2702.2 243.3 .49 3210.1 3062.8 2739.1 2743.0 243.4 .63 3238.8 3091.5 2780.0 2783.8 243.4 3.25 3267.9 3120.6 2820.6 2824.3 243.5 2.69 3298.0 3150.7 2860.5 2864.1 243.6 .11 3328.6 3181.3 2900.1 2903.5 243.6 · 66 3359~'2 3211.9 2939.6 2942.9 243.7 ]..03 3389.8 3242.5 2979.2 2982.4 243.7 Page .55 3420.3 3273.0 3018.8 3021.9 243.8 .18 3450.9 3303.6 3058.3 3061.3 243.8 .46 3481.5 3334.2 3097.8 3100.8 243.9 .34 3512.0 3364.7 3137.4 3140.3 244.0 .67 3542.5 3395.2 3177.0 3179.8 244.0 HORIZONTAL COORDINATES feet .36 3573.0 3425.7 3216.6 32].9.3 244.1 .41 3603.5 3456.2 3256.2 3258.8 244.1 1.22 3633.9 3486.6 3295.9 3298.4 244.2 .98 3664.2 3516.9 3335.6 3338.0 244.2 .36 3694.8 3547.5 3375.1 3377.4 244.3 1114.7 S 2147.3 W 1129.2 S 2185.1 W 1143.6 S 2223.0 W 1157.9 S 2261.0 W 1172.3 S 2299.0 W 1186.6 S 2337.1 W 1201.0 S 2375.2 W 1215.6 S 2413.4 W 1230.3 S 2451.6 W 1245.1 S 2489.8 W 1260.1 S 2527.6 1275.1 S 2564.5 1290.2 S 2601.1 1305.1 S 2637.7 1320.0 S 2674.4 W W W W W 1334.8 S 2711.1 W 1349.6 S 2747.8 W 1364.4 S 2784.5 W 1379.0 S 2821.3 W 1393.7 S 2858.1 W 1408.3 S 2894.9 W 1422.8 S 2931.8 W 1437.3 S 2968.8 W 1451.7 S 3005.8 W 1466.1 S 3042.6 W A G y~r o d a t a D i r e c t i o n a i S u r v e y [CO ALASKA INC. ~LL: 2N-339, 3.5" ~cation: DRILLSITE 2N, ~b Number~: AK1098GCE500 ~ASURED I N C L AZIMUTH )EPTH feet deg. deg. 5350.0 52.86 248.78 3400.0 52.86 248.79 5450 . 0 52 . 97 248 · 94 5500.0 52.58 248.93 5550.0 52.08 249.02 5600.0 52.32 249.19 5650.0 53.63 249.59 5700 · 0 54 . 04 249 . 76 5750.0 53 .95 249.98 5800.0 53.96 249.92 5850.0 54.39 250.15 5900.0 54.52 250.24 5950.0 54.61 250.19 6000.0 55.31 250.42 6050.0 55.31 250.40 6100.0 54.85 250.80 6].50.0 54.7]. 251.04 6200.0 54.82 251.29 6250.0 55.32 251.].2 6300.0 54.].4 249.56 6350.0 53.95 248.58 6400.0 54.43 248.45 6450.0 54.41 248.53 6500.0 52.84 246.65 6550.0 52.98 246.32 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 1.27 3725.2 3577.9 3414.8 .02 3755.4 3608.1 3454.6 .32 3785.6 3638.3 3494.5 .78 3815.8 3668.5 3534.2 1.01 3846.4 3699.1 3573.8 .56 3877.0 3729.7 3613.2 2.70 3907.1 3759.8 3653.1 .86 3936.6 3789.3 3693.4 .40 3966.0 3818.7 3733.8 .11 3995.4 3848.1 3774.1 .95 4024.7 3877.4 3814.6 .30 4053.8 3906.5 3855.2 .20 4082.8 3935.5 3895.8 1.45 411115 3964.2 3936.7 .04 4139.9 3992.6 3977.7 1.13 4168.5 4021.2 4018.6 .48 43.97.4 4050.1 4059.3 .46 4226.2 4078.9 4100.0 1.05 4254.9 4107.6 4140.8 3.48 4283.7 4136.4 4181.5 ]..63 4313.]_ 4165.8 4222.0 .98 4342.3 4195.0 4262.5 .12 4371.4 4224.1 4303.1 4.36 4401.1 4253.8 4343.4 .59 4431.2 4283.9 4383.3 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 3417.0 244.3 3456.8 244.4 3496.5 244.4 3536.2 244.5 3575.7 244.5 3615.1 244.6 3654.8 244.6 3695.0 244.7 3735.3 244.7 3775.6 244.8 3816.0 244.9 3856.5 244.9 3897.0 245.0 3937.8 245.0 3978.7 245.1 4019.5 245.1 4060.2 245.2 4100.8 245.2 4141.6 245.3 4182.2 245.4 4222.6 245.4 4263.1 245.4 4303.7 245.5 4343.9 245.5 4383.8 245.5 1480.5 S 3079.6 W 1494.9 S 3116.8 W 1509.3 S 3154.0 W 1523.6 S 3191.1 W 1537.8 S 3228.1 W 1551.9 S 3265.0 W 1566.0 S 3302.4 W 1580.0 S 3340.2 W 1593.9 S 3378.2 W 1607.8 S 3416.2 W 1621.6 S 3454.3 W 1635.4 S 3492.5 W 1649.2 S 3530.9 W 1663.0 S 3569.4 W 1676.8 S 3608.2 W 1690.4 S 3646.8 W 1703.7 S 3685.4 W 1716.9 S 3724.1 W 1730.1 S 3762.9 W 1743.8 S 3801.3 W 1758.3 S 3839.1W 1773.2 S 3876.9 W 1788.1 S 3914.7 W 1803.4 S 3951.9 W 1819.3 S 3988.5 W A Gyro da t a D i r e c t i o na i S u rve y ~CO ALASKA INC. ~LL: 2N-339, 3.5" ~cation: DRILLSITE 2N, ~b Number: AK1098GCE500 5ASURED DEPTH feet I N C L AZIMUTH deg. deg. 5600.0 53.30 246.30 6650.0 53.64 246.25 6700.0 53.31 246.39 6750.0 53.66 246.43 6800.0 53.36 246.44 6850.0 53.54 246.41 6900.0 53.93 246.12 6950.0 53.75 246.17 7000.0 54.40 246.06 7050.0 54.17 246.19 7100.0 54.51 245.76 7150.0 52.33 245.78 7200.0 51.42 245.83 7250.0 48.93 246.83 7300.0 47.94 247.00 7350.0 45.58 247.17 7400.0 45.27 247.22 7450.0 44.32 246.83 7500.0 44.52 247.02 7550.0 44.37 246.91 7600.0 44.07 247.74 7650.0 43.58 248.79 7700.0 44.].2 249.43 '7750.0 44.57 250.25 7800.0 44.97 250.39 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .64 4461.2 4313.9 4423.3 .68 4491.0 4343.7 4463.4 .69 4520.7 4373.4 4503.6 .71 4550.5 4403.2 4543.8 .62 4580.2 4432.9 4584.0 CLOSURE DIST. AZIMUTH feet deg. Page 4423.8 245.5 4464.0 245.5 4504.2 245.5 4544.4 245.5 4584.6 245.5 HORIZONTAL COORDINATES feet .38 4610.0 4462.7 4624.2 4624.7 245.5 .90 4639.6 4492.3 4664.5 4665.0 245.5 .35 4669.1 4521.8 4704.9 4705.4 245.5 1.3]. 4698.4 4551.1 4745.3 4745.9 245.5 .51 4727.6 4580.3 4785.9 4786.5 245.5 1835.4 S 4025.1 W 1851.6 S 4061.9 W 1867.7 S 4098.7 W 1883.8 S 4135.5 W 1899.9 S 4172.4 W 1915.9 S 4209.2 W 1932.1 S 4246.1 W 1948.5 S 4283.0 W 1964.9 S 4320.0 W 1981.3 S 4357.2 W .98 4756.8 4609.5 4826.6 4827.1 245.6 1997.8 S 4394.3 W 4.35 4786.6 4639.3 4866.7 4867.2 245.6 2014.3 S 4430.9 W 1.83 4817.4 4670.1 4906.0 4906.6 245.6 2030.4 S 4466.7 W 5.21 4849~[4 4702.1 4944.4 4945.0 245.6 2045.9 S 4501.9 W 1.98 4882.6 4735.3 4981.8 4982.4 245.6 2060.5 S 4536.3 W 4.74 4916.9 4769.6 5018.3 5018.8 245.6 .63 4952.0 4804.7 5053.9 5054.4 245.6 1.98 4987.4 4840.1 5089.1 5089.6 245.6 .48 5023.2 4875.9 5124.1 5124.6 245.6 .32 5058.8 4911.5 5159.1 5159.6 245.6 1.3]. 5094.7 4947.4 5194.0 1.75 5130.8 4983.5 5228.6 1.39 5166.8 5019.5 5263.2 1.47 5202.6 5055.3 5298.1 .8]. 5238.1 5090.8 5333.2 5194.4 245.6 5229.0 245.7 5263.6 245.7 5298.5 245.7 5333.6 245.7 2074.7 S 4569.9 W 2088.5 S 4602.7 W 2102.3 S 4635.1 W 2116.0 S 4667.3 W 2129.7 S 4699.6 W 2143.1 S 4731.7 W 2155.9 S 4763.9 W 2168.3 S 4796.2 W 2180.3 S 4829.1 W 2192.2 S 4862.2 W A Gyro da t a D i r e c t i o na i Survey ~CO ALASKA INC. ~LL: 2N-339, 3.5" }cation: DRILLSITE 2N, }b Number: AK1098GCE500 ~ASURED I N C L AZIMUTH , DEPTH feet deg. deg. 7850.0 45.07 250.57 7900.0 45.31 250.62 7950.0 45.72 250.74 8000.0 45.96 250.76 8007.0 46.01 250.81 inal Station Closure: TARN POOL, ALASKA Page DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. .33 5273.4 5126.1 5368.5 5368.8 245.8 .49 5308.6 5161.3 5403.9 5404.2 245.8 .82 5343.7 5196.4 5439.4 5439.7 245.8 .48 5378.5 5231.2 5475.2 5475.4 245.9 .95 5383.4 5236.1 5480.2 5480.4 245.9 Distance: 5480.45 ft Az: 245.86 deg. HORIZONTAL COORDINATES feet 2204.0 S 4895.5 W 2215.8 S 4929.0 W 2227.6 S 4962.7 W 2239.4 S 4996.5 W 2241.1 S 5001.3 W A Gyro d a t a D i r e c t i on a i Survey for ARCO ALASKA INC. WELL: 2N-339, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA ob Number: AK1098GCE500SS Date: 6-Oct-98 10:45:00 urveyor: TOM STODDARD alcu]..ation Method: MINIMUM CURVATURE urvey Latitude: 70.250000 deg. N 'ub-sea Correction from Vertical Reference: 147.3 ft. .zimuth Correction: ~yro: Bearings are Relative to True North 'roposed Well Direction: 246.400 deg ~ertical Section Calculated from Well Head Location llosure Calculated from Well Head Location [orizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t a D i r e c t i o n a i S u r v e y ~CO ALASKA INC. :LL: 2N-339, 3.5" ~cation: DRILLSITE 2N, TARN POOL, lb Number.: AK1098GCE500SS ALASKA ;UBSEA I N C L AZIMUTH DOGLEG VERTICAL )EPTtt SEVERITY DEPTH feet deg. deg. deg./ feet ~ 100 ft. -147.3 0.00 0.00 0.00 0.0 .75 92.60 .42 100.0 .76 103.62 .15 200.0 1.60 143.66 1.15 300.0 4.02 190.18 2.87 0.0 147.3 247.3 347.3 447.3 400.0 7.71 198.14 3.74 500.0 12.].2 200.47 4.38 600.0 16.31 204.86 3.64 700.0 20.52 207.53 1.96 800.0 23.50 213.34 4.49 547.3 647.3 747.3 847.3 947.3 900.0 28.45 220.05 5.79 1000.0 32.63 225.07 4.08 1100.0 34.48 227.83 .71 1200.0 35.90 231.76 2.94 1300.0 39.18 238.30 4.50 1047.3 1147.3 1247.3 1347.3 1447.3 ].400.0 43.41 245.24 5.36 1500.0 49.23 247.99 3.87 1600.0 52.81 248.39 .12 1700.0 54.90 248.32 .51 1800.0 54.82 248.68 1.37 1547.3 1647.3 1747.3 1847.3 1947.3 ].900.0 54.45 249.17 .41 2000.0 54.42 248.39 .77 2100.0 54.37 246.76 .73 2200.0 53.69 246.60 1.53 2300.0 54.17 246.44 .80 2047.3 2147.3 2247.3 2347.3 2447.3 VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. 0.0 0.0 0.0 -1.1 1.9 90.9 -2.2 3.2 94.2 -2.5 4.9 11_]..9 - . 3 10.0 146.9 6.4 22.7 176.4 18.4 43.4 189.1 36.1 71.5 195.5 62.5 105.9 199.5 94.7 144.2 202.7 136.7 188.5 206.5 190.8 238.7 210.5 254.2 320.3 214.1 321.6 376.7 217.0 396.7 465.1 220.1 483.0 526.9 223.7 587.6 628.4 227.5 714.5 778.5 231.0 853.4 896.6 233.7 994.1 1015.5 235.7 1135.0 1174.8 237.3 1274.5 1294.6 238.6 1415.5 1456.1 239.4 1553.1 1576.4 240.1 1689.9 1737.1 240.6 Page HORIZONTAL COORDINATES feet 0.0 N 0.0 E .0 S 1.3 E .2 S 2.5 E 1.6 S 3.4 E 6.0 S 3.0 E 15.9 S 2.1 W 32.4 S 5.9 W 55.1 S 15.3 W 86.1 S 30.6 W 120.7 S 50.6 W 159.2 S 79.6 W 202.7 S 119.6 W 248.7 S 168.7 W 294.7 S 222.3 W 338.5 S 285;0 W 378.8 S 361.6 W 419.8 S 457.8 W 466.8 S 575.8 W 518.1 S 705.0 W 570.3 S 835.7 W 620.6 S 967.5 W 670.8 S 1097.8 W 725.5 S 1227.8 W 780.0 S 1354.1 W 834.5 S 1479.5 W A Gy r o d a t a D i r e c t i o n a I S u rv e y [CO ALASY~ INC. ~LL: 2N-339, 3.5" ~cation: DRILLSITE 2N, TARN POOL, lb Number: AK1098GCE500SS ALAS KA ~UBSEA I N C L AZIMUTH DOGLEG VERTICAL )EPTH SEVERITY DEPTH feet deg. deg. deg./ feet ~ 100 ft. 2400.0 54.08 246.70 .63 2500.0 53.39 246.87 .18 2600.0 53.34 247.11 .34 2700.0 53.91 247.14 .22 2800.0 54.14 249.04 1.27 2547.3 2647.3 2747.3 2847.3 2947.3 2900.0 54.28 249.28 .36 3000.0 54.61 249.23 .30 3100.0 54.71 248.52 1.39 3200.0 52.16 247.80 .45 3300.0 52.22 248.07 .22 3047.3 3147.3 3247.3 3347.3 3447.3 3400.0 52.56 248.32 .62 3500.0 52.65 248.69 1.12 3600.0 52.86 248.79 .36 3700.0 52.08 249.02 .99 3800.0 54.01 249.84 .69 3547.3 3647.3 3747.3 3847.3 3947.3 3900.0 54.49 250.22 .44 4000.0 55.19 250.50 .32 4100.0 55.19 251.17 .89 4200.0 54.42 248.47 .83 4300.0 53.16 246.31 .62 4047.3 4147.3 4247.3 4347.3 4447.3 4400.0 53.63 246.42 .70 4500.0 53.88 246.13 .76 4600.0 54.40 245.90 .83 4700.0 49.09 246.77 4.99 4800.0 45.3]. 247.21 1.17 4547.3 4647.3 4747.3 4847.3 4947.3 VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. 1829.0 1964.9 2099.4 2235.3 2372.0 2510.3 2649.9 2791.9 2924.2 3053.6 3183.2 3313.4 3443.9 3575.0 3708.1 3846.1 3988.2 4130.0 4269.4 4404.7 4539.5 4675.1 4813 .4 4941.9 5049.2 1858.3 241.0 1978.4 241.4 2138.2 241.8 2258.8 242.1 2379.1 242.5 2540.3 242.8 2661.6 243.2 2824.3 243.5 2942.9 243.7 3061.3 243.8 3219.3 244.0 3338.0 244.2 3456.8 244.4 3615.1 244.5 3735.3 244.7 3856.5 244.9 4019.5 245.1 4141.6 245.3 4303.7 245.4 4423.8 245.5 4544 . 4 245 . 5 4705.4 245.5 4827.1 245.6 4945. 0 245 . 6 5054.4 245.6 Page HORIZONTAL COORDINATES feet 890.0 S 1607.1 W 943.5 S 1732.0 W 996.1 S 1855.8 W 1049.2 S 1981.0 W 1099.7 S 2108.1 W 1149.0 S 2237.4 W 1198.4 S 2368.2 W 1249.5 S 2500.8 W 1299.3 S 2623.5 W 1347.9 S 2743.4 W 1396.0 S 2863.8 W 1443.7 S 2985.1 W 1491.1 S 3106.8 W 1538.2 S 3229.2 W 1585.0 S 3354.0 W 1632.3 S 3484.0 W 1680.3 S 3618.1 W 1726.6 S 3752.6 W 1775.7 S 3883.3 W 1827.9 S 4008.1 W 1882.1 S 4131.6 W 1936.4 S 4255.7 W 1992.5 S 4382.2 W 2044.8 S 4499.6 W 2086.7 S 4598.4 W A Gyro d a t a D i r e c t i o n a i Survey {CO ALASKA INC. ~LL: 2N-339, 3.5" >cation: DRILLSITE 2N, TARN POOL, ~b Number: AK1098GCE500SS ALASKA ~UBSEA .I N C L AZIMUTH DOGLEG VERTICAL VERTICAL CLOSURE }EPTH .' SEVERITY DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet deg. . 100 ft. 4900.0 44.42 246.95 .37 5000.0 43.83 249.08 1.58 5100.0 45.00 250.43 .69 5200.0 45.74 250.74 .79 5236.1 46.01 250.81 .95 5047.3 5147.3 5247.3 5347.3 5383.4 inal Station Closure: Distance: 5480.45 Page HORIZONTAL COORDINATES feet 5147.8 5159.6 245.6 5244.4 5263.6 245.7 5342.4 5368.8 245.7 5443.1 5475.4 245.8 5480.2 5480.4 245.9 2125.2 S 4689.1 W 2161.6 S 4778.7 W 2195.3 S 4870.9 W 2228.8 S 4966.2 W 2241.1 S 5001.3 W ft Az: 245.86 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK1098GCE500 TOOL NUMBER: 791 MAXIMUM GYRO TEMPERATURE: 75.88 C MAXIMUM AMBIENT TEMPERATURE: 60.18 C MAXIMUM INCLINATION: 55.32 AVERAGE AZIMUTH: 245.86 WIRELINE REZERO VALUE: O! REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2700 CALIBRATION USED FOR FINAL SURVEY: 2700 PRE JOB MASS BALANCE OFFSET CHECK: -.72 POST JOB MASS BALANCE OFFSET CHECKs: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.60 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS: OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH MWD FINAL SURVEY 8(;;)07 46.01 250.81 'TVD NORTHING EASTING 5383.4 -2241 -5001 FUNCTION TEST JOB NUMBER: AK1098GCE500 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 700 14.52 14.52 14.52 14.52 14.52 AZIMUTH M.D. ft 1 2 3 4 5 700 201.15 201.12 201.06 201.01 200.97 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK1098GCE500 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 791 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 790 GYRO SECTION DATA SECTION POWER SECTION A0150 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0467 A0085 A0079 A0143 A0433 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 7/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING w ECCENTRIC BAR TOTAL LENGTH OF TOOL: 25' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL · 220 POUNDS CHRONOLOGICAL REPORT JOB NUMBER · AK1098GCE500 TUESDAY, 10/06/98 08:00 09:30 10:30 12:00 13:45 14:45 16:00 19:00 TO LOCATION MU TOOL, RU SCHLUMBERGER PICK UP GYRO RIH SURVEY IN TO 8007' SURVEY OUT LD TOOL, RD SCHLUMBERGER. TO ATLAS PROCESS SURVEY, CHECK TOOLS. FINISH PROCESSING. 2N-331 WEDNESDAY, 10/07/98 05:00 TO KUPARUK WITH RESULTS 06:15 RETURN TO ATLAS. 17:30 TO ANCHORAGE I-'IFtlL_I_.INI~ SI=F:tWII--E cl WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 July 15, 1998 MWD Formation Evaluation Logs 2N-339, AK-~MM-80237 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-339: 2" x 5" MD Resistivi~ & Gamma Ray Logs: 50-103-20261-00 2" x 5" TVD Resistivity.. & Gamma Ray Logs: 50-103-20261-00 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, in¢, 0 I::! I I._1_ I I~ CS WELL LOG TRANSMITTAL To: State of Alaska July 8, 1998 3Jaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-339, . AK-~MM-80237 1 LDWG formatted Disc with verification listing. API#: 50-103-20261-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 15. 1998 Paul Mazzolini Tarn Drilling Supv. ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re' Kupark River Unit 2N-339 ARCO Alaska. Inc. Permit No: 98-100 Sur. Loc.: 124'FNL. 1026'FEL. Sec. 3. TgN. R7E. UM Btmholc Loc: 2328'FNL. 864'FEL. Sec. 4. TgN. RTE. UM Dear *lr. Mazolini: Enclosed is thc approved application for permit to drill the above refcrcnced well. Thc bottom- hole location will require a spacing cxccption under 20 AAC 25.055. You are not authorized to open thc well to production until after the commission issues thc spacing cxccption following the protest period for a public hearing. Should an adjacent owner raisc an objection, the commission may rcquire ARCO Alaska. Inc. to plug and abandon thc wcll. Thc permit to drill docs not exempt you from obtaining additional pcrmits rcquircd by law from other governmental agencics, and docs not authorize conducting drilling opcrations until all other requircd permitting determinations arc made. Approval of annular disposal of drilling ,~vastes is contingent on obtaining a well cemcnted surfacc casing confirmcd by a valid Formation Intcgrity Tcst (FIT). Ccmcnting rccords. FIT data. and any CQLs must bc submittcd to thc Commission on form 10-403 to cnsurc thc rcquiremcnts of 20 AAC 25.080 arc tact prior to initiating disposal operations. Blowout prevcntion cquipmcnt (BOPE) must be tcstcd in accordancc with 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE test pcrformcd before drilling below the surfacc casing shoc must bc gix'cn so that a reprcscntativc of thc Commission may witness thc tcst. Notice may b~cting the Commission pctrolcum field inspector on the North ~. ' Chairman BY ORDER OF TIlE COMMISSION dlf/cnclosurcs Department of Fish & Game. t Iabitat Section xv/o encl. Depamnent of l(nvironmcntal Conservation w/o encl. ARCO Alaska, Inc. [lost Of[ice Box 100360 Anci~orage, Alaska 995'iD-0360 )'ele!)ho,~te 907 276 ! May 12, 1998 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 .COMM !COMM RES ENG SR ENG NRO SR GEOL GEOL ASST STAT TF__.CH STAT TECH Re: Permit to Drill KRU 2N-339 (Tarn) Gentlemen: ARCO has submitted a 401 Application for Permit to D 'r~ U~e productive interval of this well lies within 500' of a quarter section line which requires an exception to the general spacing rules. The productive interval lies within the proposed Tarn Oil Pool and is 2259' from the nearest lease line. ARCO and partners own all of the adjacent properties. A request for spacing exception was submitted May 5 and the public notice was posted in the newspaper May 6. With the 14 day public comment period the spacing exception would not be granted until May 22. ARCO requests that the AOGCC proceed ahead with rapid processing and approval of the 401 Application for Permit to Drill prior to the spacing exception being granted. The request is made to allow for continuous drilling rig operations. ARCO's intent would be to drill the 2N-339 well immediately after the KRU 2N-343 which is currently being drilled. Estimated spud date for the KRU 2N-339 well is May 17. This well would not be perforated and produced prior to the spacing exception being granted or approval of the pending Pool Rules. In making this request ARCO assumes the liability of any protest to the spacing exception that might be made. We appreciate your consideration of this request. If you have any questions or require additional information on this matter, please contact me at 265-6206. Mikt~ Zan~g. hi~[.~ Drilling SupelSntendent AS3B 6003-93 242-2603 ~ENI' BY' -5-12-B~ · 1:;321-'~ · AKCO ALASKA~. I~UY Z/O '/.3q2:~ Z~ 2 ARCO Alaska, Inc. post Office Box 100360 Anchorage, Alaska 995'10-[.)360 Telephone 907 276 1215 May 12, L998 Mr. David W. Johnston, Chairman Alaska c)[I and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Permit to Drill KRU 2N-339 (Tarn) Gentlemen: ARC() has submitted a 401 Application rot Permit to Drill KRU 2N-339. The productive interval o1' this well lies within 500' of a quarter sec<kin line which requires an exception m thc general spacing rules. The productive interval lies within the proposed Tarn Oil Pool and is 2259' from the nearest lease line. ARCO and partners own all o1' the adjacent properties. A rcqucst for spacing excuption was submitted May 5 and thc public notice was posted in the newspaper May 6. With the 14 day public comment period thc spacing exception would not he granted until May 22. ARCO rcqucst.,~ that the AOGCC proceed ahead with rapid processing and approval of the 401 Application fi~r Permit m Drill prior to the spacing exception being granted. The request is made to allow for continuous drilling rig opera<imps. ARCO's intent would be to drill the 2N-339 well immcdlately after the KRU 2N-343 which is currently being drilled. Estimatexl spud <late Ibr thc KRU 2N-339 well is May 17. This well would not be perforated and produced prior to thc spacing exception being granted or approval of thc pending Pool Rules. In making this request ARCO assumes the liability of any protest to the spacing exception that might be made. Wc appreciate your consideration of this request. If you have any questions or require additional information on this matter, please contact, me at 265-6206. Mikg Zan'~i{ ~/ Drilling Supelqntcndcnt AIi~II! (;()H:t !t;I ?:.42 SENT BY: 5-12-58 ' l:82PM ' ARCO ALASKA--,- 907 276 7542'# 1/ 2 ARCO Alaska, inc. -- i _ TRANSMIS~ION umber of Pages (Cove~ +): ...... ___ ._ Phone: Location; I ..... iil~i ii Location: ,,'~:2 ~ .... opies To: ~: :- ...... . -..~, III .... __.. Subject: //~"/~ (,/' ~ -J 5 ~ FAX #: Phone #: II II.~IIIIII IllNllwiq! ),II .... IH Il M I qlwll II1 I~.,_,,_,., ~,;! · 'I ~, ~ .". · I.' ,'= ;I 7, 1_.,-_._- ::!,:~,_. Kuparuk Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX# g07 265-6224 AT0-1279 ___ , iiiii ~ __ Comments: 1998 STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Reddll EI lb. TypeofWell Exploratory [% StratigraphicTest F.." Development Oil X Re-Entry E Deepen r-I Service ~' Development Gas r% SingleZone X Multiple Zone ~-' 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4293 ADL 375074 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 124' FNL 1,026' FEL Sec 3 T9N R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2,259' FNL 636' FEL Sec 4 T9N R7E, UM 2N 339 #U-630610 At total depth 9. Approximate spud date Amount 2,328' FNL 864' FEL Sec 4 T9N R7E, UM 5124198 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N 343 MD 8,272' 2,259' @ target feet 2,000' feet 2,560 TVD 5,509' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 63° Maximum surface 1,835 psig At total depth (TVD) 2,425 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx+ Permafrost Cement 9-7/8" 7-5/8" 29.7 ppf L-80 BTC-Mod 3,289' 28' 28' 3,289' 2,300' 1. 70 sxAS3L, 240 sx CIG 2. 260 sx AS3L, 60 sx AS 1 63,4'' 5Y2" 15.5 ppf L-80 BTC-Mod 7,458' 28' 28' 7,458' 4,873' 250 sx CIG 63,4'' 3Y2" 9.3 ppf L-80 8rd EUE 814' 7,458' 4,873' 8,272' 5,509' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: truemeasuredvertical feetfeet Plugs(measured, 0RIGIN, ',aL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented . _ Measured depth True Vertical depth Structural :i~t: !~'~ ;-" ..... . Conductor ;i ~: ~ :~:~ ~. ~ 'f.' .'.,_. Surface Intermediate Production 't:'. i,~!~~? 'i "i ~!;~ !';..':'--!, Liner Perforation depth: measured 20. Attachments Filing fee X Property plat [~ BOP Sketch X DiverterSketch X Ddlling program X Drilling fluid program X Time vs depth plot E Refraction analysis r Seabed report E 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~0~ ,/~~~.~ Title Tarn Drilling Team Supv. Date Commission Use Only I I E,7~Y~ee ISee c°ver letter f°r Permit~.7~,,._ <::~ ~'"jN-umber APIso_ ,//<¢~number,-~ '-'" ~?._ <::~ ~ ,/ Approval date other requirements z "'"/~-ro~al Samples required E~ Yes J~ No Mud logrequired s .[~ No Conditions or app . Hydrogen su,ide measures [] Yes B No Directional survey, required ]2 Yes E' No Required working pressure for BOPE E 2M ,,~ 3M E 5M E 1OM B 15M Other: Original Signed By David W. Johnston by orderof Approved by Commissioner the commission Date ..~ "~ /.-~' '''' /0 .......... -orm 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box'100360 Anchorage, Alaska 995i0-0360 Telephone 907 276 1215 May 8, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-339 Surface Location: 124' FNL 1,026' FEL Sec 3 T9N RTE, UM Target Location: 2,259' FNL, 636' FEL Sec. 4, T9N, RTE, UM Bottom Hole Location: 2,328' FNL, 864' FEL Sec. 4, T9N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tam area, KRU 2N 339, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The drilling order is in a state of flux because we are trying to balance rig moves on the pad with optimum geologic development of the prospect. Moving well to well is challenging under the present circumstances. This well requires a spacing exception. That exception was filed May 5, 1998. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany David W. Johnston Application for Permit to Drill Page 2 KRU 2N-339 The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Fred Johnson at the number above or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tam Development Group Attachments cc: KRU 2N-339 Well File r . ARCO Alaska, Inc. --~ GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 339 1. Move in and rig up Doyon 141. 2. Install divertersystem. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (3,289'_+ MD 2,300' TVD) according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5.Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (7-VD) * 0.25 psi/ft = (2,300' 7-VD) * (0.25 psi/fi) = 575 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (6,450 psi) = 4,515 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 63A'' hole to TD (8,272' MD 5,509' TVD) according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 5Y2" L-80 BTC Csg X 31~'' L-80 8rd EUE Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (5,509' TVD) * (0.25 psi/fi) = 1,377 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (7,000 psi) = 4,900 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (10,160 psi) = 7,112 psi 10. Run 3Y2" L-80 8rd EUD Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Shut in and secure well. 2N 339 mlp, 05/07/98 ARCO Alaska, inc. ,~t 13. Clean location, RD and move to next well on 2N pad. Well will be left ready for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 7-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. 2N 339 mlp, 05/07/98 ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 339 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-4O 5-7 9.5-10 __.10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tam 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. 2N 339 mlp, 05/11/98 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 339 is the 2N 343 about 2,000' to the northwest. Drillinq Area Risks: The primary risk in the 2N 339 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into a nearby annulus or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 339 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 339 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping 2N 339 mlp, 05/11/98 ARCO Alaska, Inc. operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD '(ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 BTC-M 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). iExpected Formation Tops Permafrost West Sak Sub Sea 1,050' 1,094' TVD I 199' I 243' MD 1,258' 1,311' W. Sak Base 1,795' I 944' 2,510' GL Sub 121' 28' 149' C80 (Tabasco/K-10) C50 (K-5) C40 2,323' 3,629' 3,791' 2,472' 3,778' 3,940' 3,666' 6,052' 6,260' T4 (Cairn Interval) 4,881' 5,030' 7,658' T3 (Top Bermuda Interval/top reservoir)_ Target (Midpoint T2 T3) T2 (Base Bermuda Interval/base reservoir) C35 (K-3) 4,982' 5,063' 5,144' 5,210' 5,131' 5,212' 5,293' 5,359' 7,787' 7,891' 7,995' 8,080' TD 5,360' 5,509' 8,272' 2N 339 mlp, 05/11/98 2N 339 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permafrost~.iii!i!i 1,258' MD ......... Stage .:-:.:.: 1,550' MD :.:.:.:. Top of !:i:!:!: West Sak .:-N.: 1,311' MD :::::::: Base of :i:i:i:i West Sak 2,510' MD 7-5/8" Surface Casing at 3,289' MD Top of Cement at 6,900' MD 5-1/2' Production Casing at 7,458' MD 3-1/2" Production Casing at 8,272' MD :i:!:i:i: :.:.:.:.:. · .:.:.:.:.:.: :.:-:-:.:.:. .:.:.:.:-:.: :.:.:-:.:.:. :.:.:.: :-:.:.: :::::::. :.:.:.: .:-:-:-. :i:i:i:i: 9-7/s" :::::::: Hole 6-3/4" Hole Conductor Casing Size / Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 2(7' hole Volume Calculations: (135 If) (0.7854 cf/fi) (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slurr~ Yield 0.93 cf/sx Surface Casing excess 7-5/8" in 9-7/8" hoh Stage 1: Volume (939 If) (0.2148 cfAf) (1.45) = 292 cf Lead (292 cf) /(4.42 cf/sx) = 66 sx Tail (800 If) (0.2148 cf/fi) (1.45) = 249 cf shoe joint vol 21 cf + (249 cf) /(1.15 cf/sx) = 237 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Cl G cmt + 1% S1 (CaCl2) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 292 cf or 70 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 249 cf or 240 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing Stage 2: Vol. Lead Tail (1,258 If) (142 If) (1,125 cf) (o ;f) (15o h3 excess (0.2148 cfAf) (4.00) = 1,081 cf (0.2148cf/fi) (1.45)= 44cf /(4.42 cf/sx) = (0.2148 cf/fi) (4.00) = 0 cf (0.2148 cf/fi) (1.45) = 47 cf 254 sx (47 cf} /(0.93 cf/sx) = 50 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set I cement ) Lead SlurryVolume: 1,125 cf or 260 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size/Hole Size 5-112" and 3-1/2" in 6-3/4" hole Depth: 8,272' Top of 3-1/2' casing 7,458' Top of Cement 6,900' Excess Calculated: 50% BHT (Static): 160~ F 130~ F BHT (Circ): excess Volume around 5-1/2" (558 If) (0.0835 cf/If) (1.50) = 70 cf Volume around 3-1/2' (814 If) (0.1817 cf/if) (1.50) = 222 cf 292 cf shoe joint vol 4 cf + (292 cf) /(1.20 cf/sx) = 246 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% D800 (ret.) Slurry Volume: 292 cf or 250 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickenir~ Time 3.5 - 4.5 hours 5/7/98 Diverter Schematic Doyon 141 Flowline ~ 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 21 iA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" 200 psi WP HYDRAULIC KNIFE VALVE ~/ 16,, OD DiVERTER LiNE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO KRU 2N 339 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS i ! 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe CHOKE LINE ~~0 psi WP OCT ~~ MANUAL GATE VALVE 3-5/8" 5,000 psi WP DRILLING SPOOL L-~ ~ w/two 3" 5,oeo psi WP outlets 15,840' 10,560' 5,280' 0' ! 2N 345 __.....-..~~.,,,- planned 2N3 3 spudded 5~ ~ 4 2~ 33~ ~, ~ 3 "' planned , , ' 2N 337 t lanned ~,' : : ,: : ,, ; ,. , , . ,,,, ~,,,, ~ , , 8 9 10 ,,:, .. , , ., , ,. .~,, , , . , , : , . , ,/ ,. , , i Ill 9 5,280' 10,560' 5/7/98 O,o~e0 ~'~. For: M PRESTRIDGE Dole plotted : f-May-98 I=lot Reference ~s 359 Version ~4. True Vertical De,the are ~elerence RK8 (~ 141). 246.4 AZIMUTH 5336' (TO TARGET) ***Plane of Proposal*** 400 400 800 1 200 600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 400 RK8 ELEVATION: 149' ARCO Inc. Structure : Tarn Drill Site 2N Well : 559 [Field : Tarn Development Field Location : North Slope, Alaska Alaska, <- West (feet) 5500 5000 4500 4000 3500 $000 2500 2000 I I I I [ I I I I I I I I I I I 1500 1000 5O0 0 I I I I I I I KOP T~D=300 TMD=300 DEP=O 4.00 8.00 12.00 16.00 DLS: 4.00 deg per 100 ft 5%%% BEGIN TURN TO TARGET '1'VD=837 TMD=SS0 0EP=72 25.54 28.34 B/ PERMAFROST TVD=1199 TMD=1258 OEP=231 57_ W SAK SNOS TV0=1243 TMD=1311 DEP:259 48.50 55.79 EOC T'VO=1752 TMD=2090 DEP=852 B/ W SAK SNOS 1VD=1944 TMD=2510 0EP=1205 MAXIMUM ANGLE 62.83 DEG l SURFACE LOCATION: J 123' FNL, 1026' gEL I SEC. 3, TgN. RTE J ...... ' ~egm mum 8ese Permafrost~/ Top West Sok Bose West Sok San~ 7 5/8 Casing~.~'/ Begin Angle Drop~ End Angle Dr~ ~..~['~Target - Mid Bermuda 5 1/2 Casing IITARGETLOCATION:I TO LOCATION: 2259' FNL, 636' FEL 2528' FNL, 864' FEL SEC. 4, T9N, R7E SEC. 4, TgN, R7E TARGET TVD=521 2 TMD=7891 0EP=5336 SOUTH 2136 WEST 4890 7 5/8" CSG PT TVO=2300 TMD=5289 0EP=1898 C80 TVD=2472 TMD=5666 DEP=2233 OLS: 3.00 deg per 100 ft BEGIN ANGLE DROP TVD=3081 TMD=5000 DEP=3420 48.02 42.12 END ANGLE DROP TVD=3593 TMO=5815 DEP=4045 C50 TVD=3778 TMD:6052 DEP=4193 C40 TVD=3940 TM0=6260 DEP=¢322 T4 TVD=5030 TMD=7658 DEP=5191 T5 - T/ BERMUDA TVO=5151 TMD=7787 DEP=5271 TARGET - MID BERMUDA TVD=5212 TMD=7891 DEP= __ T2 - B/ BERMUDA 1V0=5293 TMD=7995 OEP:fi400 TARGET ANGLE cJs rvo:5359 TMD=8080 oEP=s453 3 8.7 5 D E G ~'n - CSG PT TVD=5509 TMD=8272 DEP=5572 5600 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Vertical Section(feet) -> Azimuth 246.40 with reference 0.00 1'4, 0.00 E from slot #559 500 ~ 500 500 0 --4-- 1000 ~ 1500 ~ I .v 2000 2500 -- ~x~ For: M PRESTRIDGE Dote p~otted Prat .qete.'a.~ce ;~ 339 Ve~n ~4. Ve~,cal Oept~l ore reference ~KB (~y~ I+1). JAgc0 ^l aska, In Structure : Tarn Drill Site 2N Well : /Field : Tarn Development Field Location : North Slope, Alask <- West (feet) 520 480 440 400 ..360 320 280 240 200 160 120 80 40 0 40 80 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 2OO 1900 1700 1600 1500 14""-' ........ ~' ..............'~" 1000 ................................. uu 1300 1200 11 oo ....... ~ ..... 800 40 ........................................................... 1000 900 .......... 14oo 13oo ~ 200 1 ~ oo , o~- ........ ..... :-.---- ~:-~r~~-O~ ........ t_?. .............. ?_o_ ..................................................................... 0 ...................................... t~ , ~n,~ ,' 600 -' 60~ 4o 800 5o0..,~ ..,~-:- ~'~'o °w6q~oo / / 800 /800 ~ ~oo ..... "," /U.U 1000 ..... - ..... .,,-'" ..." / · ' /700; ' ' 1200 ........... ' [~'~0" 800 700 "" ; / ! ,600 27..°-°- ................ ...-~o..>'~oo.".'~oo / ;'~oo /900 900 ~o ~oo ....... '-- _ ..... ¢ooo..'I'ooo 800/,':/ Z 8oo;' .............. { 1 O0 .-"f'l O0 .-' ,' 1000 ,,' ~' 1000 ~ ~nn / ~-uu -~- ......... 1200 ,~.-" 900 ,/ ,,' ; ,; lOO0 ~ ] UUU 1600 ................. 1300 .../~'~oo'" 1200 .- /-'., .;' 11 oo ///-°°~ /; ~ ~oo.,"'" 1 700 1 20 / 1oo~ ,~oo ~.~..-~'4OOo lOOO....-" ,,5 200 ; , 1 ' ,-' ,' ¢' 1200 , ' ' ' ' './*'~ ,3 0 0 '" / ; ~ eo ..... 'q'~'~} 11 oo .... ' , , i .--- f.~, ~ 1000 ./1~00 1200~ ~ 200 ~oo ......... ............. ., ,, . 1~0 ..""'i500 ,~"~ 1 O0 ,,,' 1400 ,,' i ~oo 240 280 320 50O I V .~o 4OO 440 ..-'/" ..--'%oo 48O 520 . .-"2'~'(~ 0 / 560 /' / 600 ,..,'2300 640 / ./'~6oo .,-'" .-";5oo 1 400 ...-' /- / · .... ~'7oo ..q 200 ,. ./....-' ./" a"i 600 "~ 800 .-//'" '"' ....-' //' /' ..... .."'~3oo /700 .-""~ 900 -/ ..-'" ,-'Goo .. ..'~ 400 · //1900 ..~'1500 ../' ..-'"' ~,'2000 /' ·' ., ..' .· ., / .-¥;oo 400 i ,400 i i ; 1 500 ~ i 500 1600 1600 1700 1700 ~ 18oo 1800 , i 1900 1900 i ! 2000 2000 ! ~ 2100 2100 2200 2300 2200 23001 ~ 2400 2400 ~ ~ 2500 2500 2600 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 <- West (feet) 680 8O F 40 333} ¢o 80 120 L ;50 20O 240 Cf'] o 280 .320 _,,_ I :so V 400 48O 520 560 600 680 IARCO Alaska : I C.ol Structure : Tarn Drill Site 2N II : 33g Field : Tarn Development Field Location : North Slope, Alosk ¢,eo,., ~';n:. For: M PRESTRIDGE Dote p~ottcd : 6-Moy-98 Plot Reference ;s Coard;nates ore ;n leer reference slot M33g. Due Yerticol Oepth$ are reference Ri(i] (Doyo~ 14,1) <- West (feet) 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 600 i i i i ! i i I I i i I [ I i i i i i i i I i i i i I i i i i 400 2OO 2OO 400 600 800 1000 "+- 1200 1400 [ 160C V 1800 20O0 2200 2400 26OO 2800, 3000 3200 600 ~ 2700 2500 ~ .... ..__230~:.2.!.0_0 ~ %..--. ~ ~ 2~00 2100 .............. -"-:::1:~:~-.190'~~0~/ 400 ~ 1900' .... -. ~ 2500 2300 ~ ........ '"'::'~ ~ ......................................................................................... 21 O0 -'-~"--~709'--1. ~ ................... 2500 .... - ................................ ?oo ~ ~o ................................................................. ~_~_%o_ ..... ~~ ...................................... ,_:~_____.,__,~_~_--- ~-t~ 2300 2,00 ~oo ..... _0i5~:- ,_~ '.~ 2~oo ?_o_ ................................................................................... ~ ..................................................... 47an 2o00 379)- ....... ~_~_O_~::_-:::_-~U-~ 5100 _3_7__0_~::::.~76~:::;:-~-0'0' .... 2 ~ _0.0___. ~.--0- -0-'~ ' ~ 9._~. -- ~'~ 200 4900 ...... ~::::=--2~Jcru ............................. .._.--1-5130 -*,~oo 3700 ~...~o~:::--_::::::: ...................... . ...... .,;zoo .... . ..... 4300 ,~ ~ oo ~_? ......... ~ ....~ .......... ' y_V_u. ............ .............................. -. ............. _ ............ .......... _ ...... ..-'" 2500 ..................... ._-~00" .---1%0 .-"' .,'" 2700 ................... _ .......... . ....... ~-:~00 600 3-?- ..... ': ....... ._...-2-~o'o' . ..... Goo ..-'"' ~ ......... . .............. . ......... ....~oo ........ --'- .-" 800 ....2-go 0'-' . ..... 51 oo --' .............. . ...... ..~j" ................ _ ....... ..--" ...,,.-~§o~,~ :5555 ....... .---'-~soo -'"' -- ..... ' .... ' .~-55~0 3700 / ....... ..~o .-¥9oo ..-"" .--'""" ~.- ~'6'6 ,,'~- 1 O0 "" ~,-'~300 ..- ..--'""'~ 900 .-"'" -' ..... _..-~%o ..-.~'6'~' ..-~5oo · -" ~..¢,.'700 ...... 5~oo .--' .... ~ .--" ..~-~' ..- .--"' /';t900 .,--35~o ....... ,.-~oo 1~oo -'"' ...4-'~o .,' .,,-~0 . ~.-'t-~} 0 2000 ...!.--' ,,.~-~ i 5' ~.%~'6'o ~ -'"' 2400 2600 2800 3000 3200 i i i i i i i [ i i i i i i I i i i i i i i i i i i i i i i 3400 3200 .bO00 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 <- West (feet) 1000 0 1200 -'~ 1400 ~6oo I V I KRCO Alaska, Inc[ JStructure : Tarn Drill Site 2N Well : 339 JField : Tarn Development Field Location : North Slope, Alaska WELL PROFILE DATA Te an 0.~ 000 0.00 0.00 0.~ 0.00 O.CO 0.~ ~op ~.~ 0 ~ ~ 3oo.~o.ao 0.~ o.~ 0.~ ~d ~t ~ ~O.~ 22.002~.oa8~6.~8 -98.01-35.67 71.92 ~d el ~wd~ 208g.g*62.83247.58 17~2.~ -~5.53-~4.77 Elgin O~um ~.~ 62 83247.5a 308 I. 14 - t 5~2.88 -~8. I I 3~20.01 ~d cf ~n ~l~.gl ~75 2~.123532.75 -1758.47 -3~.lg 4045.22 3.~ Tatg~ 33~ R~ ~-~ 78~1.~ 38.752~.125212.~ -2135.8~ -4~g.625335.7D o.~ Z.O. a ~O ~ H~a A271.~ 38.752~.125~.~ -2205.~ --5117.6g 5~.4~ O.~ 3OO ,' ". 1900 / ; ' 310 / ! ! ,, ! 35O TRUE NORTH 0 1500 10 2O ~ n.~ For: ,~f PRESTR[DG~ Dale ;~elte~ : 6-May-g8 Plot Relerence ;s 339 Ve~ion ~4. Co~dTnote8 are ;n feet refer~ce V~fcal ~tms are ~Fer~ce 3O 1 900 ..-'" v,, '., 0 290 280 270 i 3 --F 5OO 7O 8O 9O 260 100 25O 1!0 240 120 230 22O 210 200 190 180 Normol Plone Trovelling Cylinder - Fee[ 130 140 150 160 170 All depths shown are Measured depths on Reference W( ARCO Alaska, Inc. Tarn Drill Site 2N 339 slot #339 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDIN~ POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 339 Version #4 Our ref : prop2918 License : Date printed : 6-May-98 Date created : 4-May-98 Last revised : 6-May-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 12.747,w150 19 2.492 Slot Grid coordinates are N 5911885.787, E 460566.915 Slot local coord/nates are 122.76 S 1025.89 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N,339 Tarn Development Field, North Slope, Alaska PROPOSA~ LISTING Page 1 Your ref: 339 Version #4 Last revised : 6-May-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 200.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 200.00 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 200.00 300.00 0.00 N 0.00 E 0.00 0.00 400.00 4.00 200.00 399.92 3.28 S 1.19 W 4.00 2.41 KOP 500.00 8.00 200.00 499.35 13.10 S 4.77 W 4.00 9.61 600.00 12.00 200.00 597.81 29.41 S 10.71 W 4.00 21.58 700.00 16.00 200.00 694.82 52.14 S 18.98 W 4.00 38.26 800.00 20.00 200.00 789.91 81.17 S 29.55 W 4.00 59.57 850.00 22.00 200.00 836.58 98.01 S 35.67 W 4.00 71.92 Begin Turn to Target 900.00 23.07 204.40 882.77 115.74 S 42.93 W 4.00 85.66 1000.00 25.54 212.07 973.92 151.86 S 62.48 W 4.00 118.04 1100.00 28.34 218.39 1063.08 188.74 S 88.67 W 4.00 156.81 1200.00 31.37 223.63 1149.81 226.20 S 121.38 W 4.00 201.78 1258.19 33.23 226.26 1199.00 248.19 S 143.36 W 4.00 230.72 Base Permafrost 1300.00 34.59 228.00 1233.70 264.06 S 160.45 W 4.00 252.74 1311.33 34.96 228.45 1243.00 268.36 S 165.27 W 4.00 258.88 1400.00 37.94 231.70 1314.32 302.12 S 205.69 W 4.00 309.43 1500.00 41.39 234.88 1391.30 340.20 S 256.88 W 4.00 371.58 1600.00 44.91 237.65 1464.25 378.13 S 313.76 W 4.00 438.89 Top West Sak Sands 1700.00 48.50 240.09 1532.82 415.71 S 376.07 W 4.00 511.03 1800.00 52.13 242.27 1596.68 452.76 S 443.49 W 4.00 587.64 1900.00 55.79 244.25 1655.51 489.09 S 515.70 W 4.00 668.36 2000.00 59.49 246.07 1709.02 524.55 S 592.35 W 4.00 752.80 2089.94 62.83 247.58 1752.40 555.53 S 664.77 W 4.00 831.56 EOC 2500.00 62.83 247.58 1939.64 694.66 S 1002.02 W 0.00 1196.31 2509.56 62.83 247.58 1944.00 697.90 S 1009.88 W 0.00 1204.81 3000.00 62.83 247.58 2167.94 864.31 S 1413.24 W 0.00 1641.05 3289.23 62.83 247.58 2300.00 962.44 S 1651.11 W 0.00 1898.31 3500.00 62.83 247.58 2396.24 1033.95 S 1824.45 W 0.00 2085.79 Base West Sak Sands 7 5/8" Casing Pt 3665.93 62.83 247.58 2472.00 1090.25 S 1960.92 W 0.00 2233.38 4000.00 62.83 247.58 2624.54 1203.60 S 2235.67 W 0.00 2530.53 4500.00 62.83 247.58 2852.84 1373.24 S 2646.89 W 0.00 2975.27 5000.00 62.83 247.58 3081.14 1542.88 S 3058.11 W 0.00 3420.01 5100.00 59.86 248.09 3129.08 1575.99 S 3139.36 W 3.00 3507.73 C80 Begin Drop/Turn 5200.00 56.90 248.62 3181.50 1607.41 S 3218.51 W 3.00 3592.83 5300.00 53.94 249.20 3238.25 1637.03 S 3295.31 W 3.00 3675.07 5400.00 50.98 249.82 3299.18 1664.79 S 3369.57 W 3.00 3754.24 5500.00 48.02 250.49 3364.12 1690.61 S 3441.09 W 3.00 3830.11 5600.00 45.07 251.23 3432.89 1714.42 S 3509.66 W 3.00 3902.47 5700.00 42.12 252.05 3505.30 1736.15 S 3575.09 W 3.00 3971.14 5800.00 39.18 252.97 3581.16 1755.74 S 3637.22 W 3.00 4035.91 5814.91 38.75 253.12 3592.75 1758.47 S 3646.19 W 3.00 4045.22 6000.00 38.75 253.12 3737.11 1792.11 S 3757.04 W 0.00 4160.27 6052.43 38.75 253.12 3778.00 1801.64 S 3788.44 W 0.00 &192.86 End Drop/Turn C50 6260.15 38.75 253.12 3940.00 1839.40 S 3912.84 W 0.00 4321.97 C40 6500.00 38.75 253.12 4127.07 1882.99 S 4056.49 W 0.00 4471.07 7000.00 38.75 253.12 4517.03 1973.87 S 4355.94 W 0.00 4781.86 7500.00 38.75 253.12 4906.99 2064.75 S 4655.40 W 0.00 5092.65 7657.73 38.75 253.12 5030.00 2093.42 S 4749.86 W 0.00 5190.69 74 All data is in feet unless otherwise stated. Coordinates from slot #339 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ A~RCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 339 Version #4 Last revised : 6-May-98 Dogleg Vert Deg/100ft Sect 7787.23 38.75 253.12 5131.00 2116.96 S 4827.42 W 0.00 7891.07 38.75 253.12 5211.99 2135.83 S 4889.61 W 0.00 7891.08 38.75 253.12 5212.00 2135.84 S 4889.62 W 0.00 7994.94 38.75 253.12 5293.00 2154.71 S 4951.82 W 0.00 8000.00 38.75 253.12 5296.95 2155.63 S 4954.85 W 0.00 5271.19 T3 - T/ Bermuda 5335.74 Target - Mid Bermuda 5335.75 339 Rvsd 4-May-98 5400.30 T2 - Base Bermuda 5403.45 8079.56 38.75 253.12 5359.00 2170.10 S 5002.50 W 0.00 5452.90 C35 8271.89 38.75 253.12 5509.00 2205.05 S 5117.69 W 0.00 5572.45 TD All data is in feet unless otherwise stated. Coordinates from slot #339 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Calculation usea the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 339 Version #4 Last revised : 6-May-98 Comments in we11path __. MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP 850.00 836.58 98.01 S 35.67 W Begin Turn to Target 1258.19 1199.00 248.19 S 143.36 W Base Permafrost 1311.33 1243.00 268.36 S 165.27 W Top West Sak Sands 2089.94 1752.40 555.53 S 664.77 W EOC 2509.56 1944.00 697.90 S 1009.88 W Base West Sak Sands 3289.23 2300.00 962.44 S 1651.11 W 7 5/8" Casing Pt 3665.93 2472.00 1090.25 S 1960.92 W C80 5000.00 3081.14 1542.88 S 3058.11 W Begin Drop/Turn 5814.91 3592.75 1758.47 S 3646.19 W End Drop/Turn 6052.43 3778.00 1801.6% S 3788.44 W C50 6260.15 3940.00 1839.40 S 3912.84 W C40 7657.73 5030.00 2093.42 S 4749.86 W T4 7787.23 5131.00 2116.96 S 4827.42 W T3 - T/ Bermuda 7891.07 5211.99 2135.83 S 4889.61 W Target - Mid Bermuda 7891.08 5212.00 2135.84 S 4889.62 W 339 Rvsd 4-May-98 7994.94 5293.00 2154.71 S 4951.82 W T2 - Base Bermuda 8079.56 5359.00 2170.10 S 5002.50 W C35 8271.89 5509.00 2205.05 S 5117.69 W TD Casing positions in string 'A' Top MD Top'TVD Rectangular Coords. Sot MD Sot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3289.23 2300.00 962.44S 1651.11W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8271.89 5509.00 2205.05S 5117.69W 5 1/2" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 339 Rvsd 4-May-98 455667.000,5909775.000,-2.000 5212.00 2135.84S 4889.62W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 33g Version #4 Last revised : 6-May-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 122.76 S 1025.89 W 0.00 0.00 100.00 0.00 200.00 100.00 122.76 S 1025.89 W 0.00 0.00 200.00 0.00 200.00 200.00 122.76 S 1025.89 W 0.00 0.00 300.00 0.00 200.00 300.00 122.76 S 1025.89 W 0.00 0.00 KOP 400.00 4.00 200.00 399.92 126.03 S 1027.09 W 4.00 2.41 500.00 8.00 200.00 499.35 135.86 S 1030.66 W 4.00 9.61 600.00 12.00 200.00 597.81 152.17 S 1036.60 W 4-.00 21.58 700.00 16.00 200.00 694.82 174.90 S 1044.87 W 4.00 38.26 800.00 20.00 200.00 789.91 203.93 S 1055.44 W 4.00 59.57 850.00 22.00 200.00 836.58 220.77 S 1061.57 W 4.00 71.92 Begin Turn to Target 900.00 23.07 204.40 882.77 238.49 S 1068.82 W 4.00 85.66 1000.00 25.54 212.07 973.92 274.62 S 1088.37 W 4.00 118.04 1100.00 28.34 218.39 1063.08 311.50 S 1114.56 W 4.00 156.81 1200.00 31.37 223.63 1149.81 348.96 S 1147.28 W 4.00 201.78 1258.19 33.23 226.26 1199.00 370.95 S 1169.25 W 4.00 230.72 Base Permafrost 1300.00 34.59 228.00 1233.70 386.81 S 1186.35 W 4.00 252.74 1311.33 34.96 228.45 1243.00 391.12 S 1191.16 W 4.00 258.88 1400.00 37.94 231.70 1314.32 424.87 S 1231.59 W 4.00 309.43 1500.00 41.39 234.88 1391.30 462.96 S 1282.77 W 4.00 371.58 1600.00 44.91 237.65 1464.25 500.88 S 1339.66 W 4.00 438.89 Top West Sak Sands 1700.00 48.50 240.09 1532.82 538.46 S 1401.96 W 4.00 511.03 1800.00 52.13 242.27 1596.68 575.51 S 1469.38 W 4.00 587.64 1900.00 55.79 244.25 1655.51 611.85 S 1541.60 W 4.00 668.36 2000.00 59.49 246.07 1709.02 647.30 S 1618.25 W 4.00 752.80 2089.94 62.83 247.58 1752.40 678.29 S 1690.66 W 4.00 831.56 EOC 2500.00 62.83 247.58 1939.64 817.42 S 2027.91 W 0.00 1196.31 2509.56 62.83 247.58 1944.00 820.66 S 2035.77 W 0.00 1204.81 3000.00 62.83 247.58 2167.94 987.06 S 2439.13 W 0.00 1641.05 3289.23 62.83 247.58 2300.00 1085.19 S 2677.00 W 0.00 1898.31 3500.00 62.83 247.58 2396.24 1156.71 S 2850.35 W 0.00 2085.79 Base West Sak Sands 7 5/8" Casing Pt 3665.93 62.83 247.58 2472.00 1213.00 S 2986.81 W 0.00 2233.38 4000.00 62.83 247.58 2624.54 1326.35 S 3261.56 W 0.00 2530.53 4500.00 62.83 247.58 2852.84 1496.00 S 3672.78 W 0.00 2975.27 5000.00 62.83 247.58 3081.14 1665.64 S 4084.00 W 0.00 3420.01 5100.00 59.86 248.09 3129.08 1698.75 S 4165.26 W 3.00 3507.73 C80 Begin Angle Drop 5200.00 56.90 248.62 3181.50 1730.16 S 4244.40 W 3.00 3592.83 5300.00 53.94 249.20 3238.25 1759.79 S 4321.20 W 3.00 3675.07 5400.00 50.98 249.82 3299.18 1787.55 S 4395.47 W 3.00 3754.24 5500.00 48.02 250.49 3364.12 1813.37 S 4466.98 W 3.00 3830.11 5600.00 45.07 251.23 3432.89 1837.17 S 4535.55 W 3.00 3902.47 5700.00 42.12 252.05 3505.30 1858.90 S 4600.99 W 3.00 3971.14 5800.00 39.18 252.97 3581.16 1878.49 S 4663.11 W 3.00 4035.91 5814.91 38.75 253.12 3592.75 1881.23 S 4672.08 W 3.00 4045.22 6000.00 38.75 253.12 3737.11 1914.87 S 4782.93 W 0.00 4160.27 6052.43 38.75 253.12 3778.00 1924.40 S 4814.33 W 0.00 4192.86 End A~gle DrOp C50 6260.15 38.75 253.12 3940.00 1962.15 S 4938.73 W 0.00 4321.97 C40 6500.00 38.75 253.12 4127.07 2005.75 S 5082.38 W 0.00 4471.07 7000.00 38.75 253.12 4517.03 2096.63 S 5381.84 W 0.00 4781.86 7500.00 38.75 253.12 4906.99 2187.51 S 5681.29 W 0.00 5092.65 7657.73 38.75 253.12 5030.00 2216.18 S 5775.75 W 0.00 5190.69 T4 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, R7E and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 339 Version #4 Last revised : 6-May-98 Dogleg Vert Deg/100ft Sect 7787.23 38.75 253.12 5131.00 2239.72 S 5853.31 W 0.00 7891.07 38.75 253.12 5211.99 22S8.59 S 5915.50 W 0.00 7891.08 38.75 253.12 5212.00 2258.59 S 5915.51 W 0.00 7994.94 38.75 253.12 5293.00 2277.47 S 5977.71 W 0.00 8000.00 38.75 253.12 5296.95 2278.39 S 5980.74 W 0.00 5271.19 T3 - T/ Bermuda 5335.74 Target - Mid Bermuda 5335.75 339 Rvsd 4-May-98 5400.30 T2 - Base Bermuda 5403.45 8079.56 38.75 253.12 5359.00 2292.85 S 6028.39 W 0.00 5452.90 C35 8271.89 38.75 253.12 5509.00 2327.81 S 6143.58 W 0.00 5572.45 TD All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes I~TEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 339 Version #4 Last revised : 6-May-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 122.76 S 1025.89 W KOP 850.00 836.58 220.77 S 1061.57 W Begin Turn to Target 1258.19 1199.00 370.95 S 1169.25 W Base Permafrost 1311.33 1243.00 391.12 S 1191.16 W Top West Sak Sands 2089.94 1752.40 678.29 S 1690.66 W EOC 2509.56 1944.00 820.66 S 2035.77 W Base West Sak Sands 3289.23 2300.00 1085.19 S 2677.00 W 7 5/8" Casing Pt 3665.93 2472.00 1213.00 S 2986.81 W C80 5000.00 3081.14 1665.64 S 4084.00 W Begin Angle Drop 5814.91 3592.75 1881.23 S 4672.08 W End Angle Drop 6052.43 3778.00 1924.40 S 4814.33 W C50 6260.15 3940.00 1962.15 S 4938.73 W C&0 7657.73 5030.00 2216.18 S 5775.75 W T4 7787.23 5131.00 2239.72 S 5853.31 W T3 - T/ Bermuda 7891.07 5211.99 2258.59 S 5915.50 W Target - Mid Bermuda 7891.08 5212.00 2258.59 S 5915.51 W 339 Rvsd 4-May-98 7994.94 5293.00 2277.47 S 5977.71 W T2 - Base Bermuda 8079.56 5359.00 2292.85 S 6028.39 W C35 8271.89 5509.00 2327.81 S 6143.58 W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 122.76S 1025.89W 3289.23 2300.00 1085.19S 2677.00W 7 5/8" Casing 0.00 0.00 122.76S 1025.89W 8271.89 5509.00 2327.81S 6143.58W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 339 Rvsd 4-May-98 455667.000,5909775.000,-2.000 5212.00 2258.59S 5915.51W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tar~ Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 339 Version Last revised : 6-May-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C T A N G U L A R Vert Ellipse Semi Axes Minor C O O R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 200.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 200.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 200.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 4.00 200.00 399.92 3.28 S 1.19 W 2.41 1.07 1.05 0.60 20.00 500.00 8.00 200.00 499.35 13.10 S 4.77 W 9.61 1.50 1.32 0.75 20.00 600.00 12.00 200.00 597.81 29.41 S 10.71 W 21.58 2.15 1.62 0.91 20.00 700.00 16.00 200.00 694.82 52.14 S 18.98 W 38.26 3.06 1.96 1.07 20.00 800.00 20.00 200.00 789.91 81.17 S 29.55 W 59.57 4.24 2.33 1.26 20.00 850.00 22.00 200.00 836.58 98.01 S 35.67 W 71.92 4.91 2.53 1.36 20.00 900.00 23.07 204.40 882.77 115.74 S 42.93 W 85.66 5.62 2.73 1.46 20.63 1000.00 25.54 212.07 973.92 151.86 S 62.48 W 118.04 7.25 3.16 1.69 23.51 1100.00 28.34 218.39 1063.08 188.74 S 88.67 W 156.81 9.16 3.62 1.95 26.96 1200.00 31.37 223.63 1149.81 226.20 S 121.38 W 201.78 11.39 4.11 2.25 30.63 1258.19 33.23 226.26 1199.00 248.19 S 143.36 W 230.72 12.91 4.41 2.45 32.75 1300.00 34.59 228.00 1233.70 264.06 S 160.45 W 252.74 14.01 4.63 2.59 34.28 · 1311.33 34.96 228.45 1243.00 268.36 S 165.27 W 258.88 14.35 4.69 2.63 34.68 1400.00 37.94 231.70 1314.32 302.12 S 205.69 W 309.43 17.07 5.18 2.99 37.81 1500.00 41.39 234.88 1391.30 340.20 S 256.88 W 371.58 20.63 5.74 3.44 41.12 1600.00 44.91 237.65 1464.25 378.13 S 313.76 W 438.89 24.71 6.32 3.96 44.18 1700.00 48.50 240.09 1532.82 415.71 S 376.07 W 511.03 29.35 6.91 4.55 46.98 1800.00 52.13 242.27 1596.68 452.76 S 443.49 W 587.64 34.54 7.49 5.20 49.52 1900.00 55.79 244.25 1655.51 489.09 S 515.70 W 668.36 40.29 8.06 5.92 51.84 2000.00 59.49 246.07 1709.02 524.55 S 592.35 W 752.80 46.58 8.60 6.70 53.94 2089.94 62.83 247.58 1752.40 555.53 S 664.77 W 831.56 52.66 9.07 7.46 55.65 2500.00 62.83 247.58 1939.64 694.66 S 1002.02 W 1196.31 81.01 11.04 10.95 60.06 2509.56 62.83 247.58 1944.00 697.90 S 1009.88 W 1204.81 81.68 11.09 11.03 60.10 3000.00 62.83 247.58 2167.94 864.31 S 1413.24 W 1641.05 116.12 13.31 15.23 62.42 3289.23 62.83 247.58 2300.00 962.44 S 1651.11 W 1898.31 136.54 14.60 17.72 63.14 3500.00 62.83 247.58 2396.24 1033.95 S 1824.45 W 2085.79 151.43 15.55 19.53 63.66 3665.93 62.83 247.58 2472.00 1090.25 S 1960.92 W 2233.38 163.17 16.29 20.96 63.91 4000.00 62.83 247.58 2624.54 1203.60 S 2235.67 W 2530.53 186.82 17.78 23.84 64.42 4500.00 62.83 247.58 2852.84 1373.24 S 2646.89 W 2975.27 222.25 20.03 28.15 64.94 5000.00 62.83 247.58 3081.14 1542.88 S 3058.11 W 3420.01 257.71 22.29 32.46 65.31 5100.00 59.86 248.09 3129.08 1575.99 S 3139.36 W 3507.73 264.47 22.76 33.28 65.38 5200.00 56.90 248.62 3181.50 1607.41 S 3218.51 W 3592.83 270.87 23.26 34.05 65.46 5300.00 53.94 249.20 3238.25 1637.03 S 3295.31 W 3675.07 276.90 23.78 34.77 65.54 5400.00 50.98 249.82 3299.18 1664.79 S 3369.57 W 3754.24 282.52 24.31 35.45 65.62 5500.00 48.02 250.49 3364.12 1690.61 S 3441.09 W 3830.11 287.74 24.84 36.07 65.71 5600.00 45.07 251.23 3432.89 1714.42 S 3509.66 W 3902.47 292.54 25.38 36.63 65.80 5700.00 42.12 252.05 3505.30 1736.15 S 3575.09 W 3971.14 296.92 25.92 37.15 65.89 5800.00 39.18 252.97 3581.16 1755.74 S 3637.22 W 4035.91 300.88 26.46 37.61 65.98 5814.91 38.75 253.12 3592.75 1758.47 S 3646.19 W 4045.22 301.46 26.54 37.68 66.00 6000.00 38.75 253.12 3737.11 1792.11 S 3757.04 W 4160.27 308.67 27.53 38.52 66.16 6052.43 38.75 253.12 3778.00 1801.64 S 3788.44 W 4192.86 310.71 27.81 38.76 66.21 6260.15 38.75 253.12 3940.00 1839.40 S 3912.84 W 4321.97 318.81 28.93 39.71 66.38 6500.00 38.75 253.12 4127.07 1882.99 S 4056.49 W 4471.07 328.15 30.22 40.80 66.57 7000.00 38.75 253.12 4517.03 1973.87 S 4355.94 W 4781.86 347.67 32.94 43.08 66.94 7500.00 38.75 253.12 4906.99 2064.75 S 4655.40 W 5092.65 367.20 35.66 45.36 67.26 7657.73 38.75 253.12 5030.00 2093.42 S 4749.86 W 5190.69 373.37 36.53 46.08 67.36 All data is in feet unless otherwise stated. Coordinates from slot #339 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Vertical section is from'wellhead on azimuth 246.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth PROPOSAL LISTING Page 2 Your ref : 339 Version Last revised : 6-May-98 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 7787.23 38.75 253.12 5131.00 2116.96 S 4827.42 W 5271.19 378.43 37.24 46.67 67.43 7891.07 38.75 253.12 5211.99 2135.83 S 4889.61 W 5335.74 382.49 37.81 47.15 67.50 7891.08 38.75 253.12 5212.00 2135.84 S 4889.62 W 5335.75 382.%9 37.81 47.15 67.50 7994.94 38.75 253.12 5293.00 2154.71 S 4951.82 W 5400.30 386.55 38.38 47.62 67.55 8000.00 38.75 253.12 5296.95 2155.63 S 4954.85 W 5403.45 386.75 38.40 47.64 67.56 8079.56 38.75 253.12 5359.00 2170.10 S 5002.50 W 5452.90 389.87 38.84 48.01 67.60 8271.89 38.75 253.12 5509.00 2205.05 S 5117.69 W 5572.45 397.39 39.90 48.88 67.70 POSITION UNCERTAINTY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 8272 ARCO (H.A. Mag) User sloecified 397.39 39.90 48.88 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be fo=nd in the Ec*Trakmanual. All data is in feet unless otherwise stated. Coordinates from slot #339 and TVD from RKB (Do¥on 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Vertical section is from wellhead on azimuth 246.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 339 Version Last revised : 6-May-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP 850.00 836.58 98.01 S 35.67 W Begin Turn to Target 1258.19 1199.00 248.19 S 143.36 W Base Permafrost 1311.33 1243.00 268.36 S 165.27 W Top West Sak Sands 2089.94 1752.40 555.53 S 664.77 W EOC 2509.56 1944.00 697.90 S 1009.88 W Base West Sak Sands 3289.23 2300.00 962.44 S 1651.11 W 7 5/8" Casing Pt 3665.93 2472.00 1090.25 S 1960.92 W C80 5000.00 3081.14 1542.88 S 3058.11 W Begin Angle Drop 5814.91 3592.75 1758.47 S 3646.19 W End Angle Drop 6052.43 3778.00 1801.64 S 3788.44 W C50 6260.15 3940.00 1839.40 S 3912.84 W C40 7657.73 5030.00 2093.42 S 4749.86 W T4 7787.23 5131.00 2116.96 S 4827.42 W T3 - T/ Bermuda 7891.07 5211.99 2135.83 S 4889.61 W Target - Mid Bermuda 7891.08 5212.00 2135.84 S 4889.62 W 339 Rvsd 4-Mayo98 7994.94 5293.00 2154.71 S 4951.82 W T2 - Base Bermuda 8079.56 5359.00 2170.10 S 5002.50 W C35 8271.89 5509.00 2205.05 S 5117.69 W TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3289.23 2300.00 962.445 1651.11W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8271.89 5509.00 2205.055 5117.69W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 339 Rvsd 4-May-98 455667.000,5909775.000,-2.000 5212.00 2135.845 4889.62W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 339 Version #4 Last revised : 6-May-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 460566.91 5911885.79 100.00 0.00 200.00 100.00 0.00N 0.00E 0.00 0.00 460566.91 5911885.79 200.00 0.00 200.00 200.00 0.00N 0.00E 0.00 0.00 460566.91 5911885.79 300.00 0.00 200.00 300.00 0.00N 0.00E 0.00 0.00 460566.91 5911885.79 400.00 4.00 200.00 399.92 3.28S 1.19W 4.00 2.41 460565.70 5911882.51 500.00 8.00 200.00 499.35 13.10S 4.77W 4.00 9.61 460562.08 5911872.71 600.00 12.00 200.00 597.81 29.41S 10.71W 4.00 21.58 460556.06 5911856.43 700.00 16.00 200.00 694.82 52.14S 18.98W 4.00 38.26 460547.67 5911833.75 800.00 20.00 200.00 789.91 81.17S 29.55W 4.00 59.57 460536.96 5911804.77 850.00 22.00 200.00 836.58 98.01S 35.67W 4.00 71.92 460530.75 5911787.97 900.00 23.07 204.40 882.77 115.74S 42.93W 4.00 85.66 460523.41 5911770.28 1000.00 25.54 212.07 973.92 151.86S 62.48W 4.00 118.04 460503.68 5911734.26 1100.00 28.34 218.39 1063.08 188.74S 88.67W 4.00 156.81 460477.30 5911697.51 1200.00 31.37 223.63 1149.81 226.20S 121.38W 4.00 201.78 460444.40 5911660.23 1258.19 33.23 226.26 1199.00 248.19S 143.36W 4.00 230.72 460422.31 5911638.35 1300.00 34.59 228.00 1233.70 264.06S 160.45W 4.00 252.74 460405.14 5911622.58 1311.33 34.96 228.45 1243.00 268.36S 165.27W 4.00 258.88 460400.30 5911618.30 1400.00 37.94 231.70 1314.32 302.12S 205.69W 4.00 309.43 460359.71 5911584.75 1500.00 41.39 234.88 1391.30 340.20S 256.88W 4.00 371.58 460308.34 5911546.92 1600.00 44.91 237.65 1464.25 378.13S 313.76W 4.00 438.89 460251.27 5911509.29 1700.00 48.50 240.09 1532.82 415.71S 376.07W 4.00 511.03 460188.78 5911472.04 1800.00 52.13 242.27 1596.68 452.76S 443.49W 4.00 587.64 460121.17 5911435.33 1900.00 55.79 244.25 1655.51 489.09S 515.70W 4.00 668.36 460048.79 5911399.36 2000.00 59.49 246.07 1709.02 524.55S 592.35W 4.00 752.80 459971.97 5911364.31 2089.94 62.83 247.58 1752.40 555.53S 664.77W 4.00 831.56 459899.40 5911333.69 2500.00 62.83 2509.56 62.83 3000.00 62.83 3289.23 62.83 3500.00 62.83 3665.93 62.83 4000.00 62.83 4500.00 62.83 5000.00 62.83 5100.00 59.86 5200.00 56.90 5300.00 53.94 5400.00 50.98 5500.00 48.02 5600.00 45.07 5700.00 42.12 5800.00 39.18 5814.91 38.75 6000.00 38.75 6052.43 38.75 6260.15 38.75 6500.00 38.75 7000.00 38.75 7500.00 38.75 7657.73 38.75 247.58 1939.64 694.66S 1002.02W 0.00 1196.31 459561.48 5911196.29 247.58 1944.00 697.90S 1009.88W 0.00 1204.81 459553.60 5911193.09 247.58 2167.94 864.31S 1413.24W 0.00 1641.05 459149.45 5911028.75 247.58 2300.00 962.44S 1651.11W 0.00 1898.31 458911.10 5910931.83 247.58 2396.24 1033.95S 1824.45W 0.00 2085.79 458737.42 5910861.21 247.58 2472.00 1090.25S 1960.92W 0.00 2233.38 458600.68 5910805.61 247.58 2624.54 1203.60S 2235.67W 0.00 2530.53 458325.38 5910693.67 247.58 2852.84 1373.24S 2646.89W 0.00 2975.27 457913.35 5910526.13 247.58 3081.14 1542.88S 3058.11W 0.00 3420.01 457501.32 5910358.59 248.09 3129.08 1575.99S 3139.36W 3.00 3507.73 457419.90 5910325.90 248.62 3181.50 1607.41S 3218.51W 3.00 3592.83 457340.61 5910294.89 249.20 3238.25 1637.03S 3295.31W 3.00 3675.07 457263.66 5910265.66 249.82 3299.18 1664.79S 3369.57W 3.00 3754.24 457189.27 5910238.28 250.49 3364.12 1690.61S 3441.09W 3.00 3830.11 457117.63 5910212.83 251.23 3432.89 1714.42S 3509.66W 3.00 3902.47 457048.95 5910189.37 252.05 3505.30 1736.15S 3575.09W 3.00 3971.14 456983.41 5910167.98 252.97 3581.16 1755.74S 3637.22W 3.00 4035.91 456921.19 5910148.70 253.12 3592.75 1758.47S 3646.19W 3.00 4045.22 456912.21 5910146.02 253.12 3737.11 1792.11S 3757.04W 0.00 4160.27 456801.20 5910112.94 253.12 3778.00 1801.64S 3788.44W 0.00 4192.86 456769.75 5910103.57 253.12 3940.00 1839.40S 3912.84W 0.00 4321.97 456645.17 5910066.45 253.12 4127.07 1882.99S 4056.49W 0.00 4471.07 456501.32 5910023.59 253.12 4517.03 1973.87S 4355.94W 0.00 4781.86 456201.44 5909934.24 253.12 4906.99 2064.75S 4655.40W 0.00 5092.65 455901.56 5909844.89 253.12 5030.00 2093.42S 4749.86W 0.00 5190.69 455806.96 5909816.70 All data in feet unless otherwise stated. Calculation ~ses minimum cuz-vature method. Coordinates from slot #339 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 339 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 339 Version #4 Last revised : 6-May-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing 7787.23 38.75 253.12 5131.00 2116.96S 4827.42W 0.00 5271.19 455729.29 5909793.56 7891.07 38.75 253.12 5211.99 2135.83S 4889.61W 0.00 5335.74 455667.01 5909775.00 7891.08 38.75 253.12 5212.00 2135.84S 4889.62W 0.00 5335.75 455667.00 5909775.00 7994.94 38.75 253.12 5293.00 2154.71S 4951.82W 0.00 5400.30 455604.71 5909756.44 8000.00 38.75 253.12 5296.95 2155.63S 4954.85W 0.00 5403.45 455601.68 5909755.54 8079.56 38.75 253.12 5359.00 2170.10S 5002.50W 0.00 5452.90 455553.96 5909741.32 8271.89 38.75 253.12 5509.00 2205.05S 5117.69W 0.00 5572.45 455438.61 5909706.95 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #339 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5572.52 on azimuth 246.69 degrees from wellhead. Total Dogleg for wellpath is 96.04 degrees. Vertical section is from wellhead on azimuth 246.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,339 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 339 Version Last revised : 6-May-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00N 0.00E KOP 850.00 836.58 98.01S 35.67W Begin Turn to Target 1258.19 1199.00 248.19S 143.36W Base Permafrost 1311.33 1243.00 268.36S 165.27W Top West Sak S~nds 2089.9% 1752.40 555.53S 664.77W EOC 2509.56 1944.00 697.90S 1009.88W Base West Sak Sands 3289.23 2300.00 962.44S 1651.11W 7 5/8" Casing Pt 3665.93 2472.00 1090.25S 1960.92W C80 5000.00 3081.14 1542.88S 3058.11W Begin Angle Drop 5814.91 3592.75 1758.47S 3646.19W End Angle Drop 6052.43 3778.00 1801.64S 3788.44W C50 6260.15 3940.00 1839.40S 3912.84W C40 7657.73 5030.00 2093.42S 4~49.86W T4 7787.23 5131.00 2116.96S 4827.42W T3 - T/ Bermuda 7891.07 5211.99 2135.83S 4889.61W Target - Mid Bermuda 7891.08 5212.00 2135.84S 4889.62W 339 Rvsd 4-~ay-98 7994.94 5293.00 2154.71S 4951.82W T2 - Base Bermuda 8079.56 5359.00 2170.10S 5002.50W C35 8271.89 5509.00 2205.05S 5117.69W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3289.23 2300.00 962.44S 1651.11W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8271.89 5509.00 2205.05S 5117.69W 5 1/2" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised 339 Rvsd 4-May-98 455667.000,5909775.000,-2.000 5212.00 2135.84S 4889.62W 6-Aug-9? ARCO Alaska, Inc. Tarn Drill Site 2N 339 slot #33~ Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 339 Version Our ref : prop2918 License : Date printed : 6-May-98 Date created : 4-May-98 Last revised : 6-May-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is nT0 10 12.747,w150 19 2.492 Slot Grid coordinates are N 5911885.787, E 460566.915 Slot local coordinates are 122.76 S 1025.89 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.~. 487.4* Object wellpath PMSS <0-9553'>,,323,Tarn Drill Site 2N 345 Version #2,,345,Tarn Drill Site 2N 313 Version #4,,313,Tarn Drill Site 2N 350 Vets. #1,,350,Tarn Drill Site 2N 335 Version #1,,335,Tarn Drill Site 2N 305 Version #2,,305,Tarn Drill Site 2N 303 Version #2,,303,Tarn Drill Site 2N 314 Version #1,,314,Tarn Drill Site 2N 311 Version #1,,311,Tarn Drill Site 2N 315 Version #1,,315,Tarn Drill Site 2N 301 Version #1,,301,Tarn Drill Site 2N 302 Version #1,,302,Tarn Drill Site 2N 304 Version #1,,304,Tarn Drill Site 2N 306 Version #1,,306,Tarn Drill Site 2N 307 Version #1,,307,Tarn Drill Site 2N 308 Version #1,,308,Tarn Drill Site 2N 309 Version #1,,309,Tarn Drill Site 2N 310 Version #1,,310,Tarn Drill Site 2N 320 Version #1,,320,Tarn Drill Site 2N 333 Version #1,,333,Tarn Drill Site 2N 334 Version #1,,334,Tarn Drill Site 2N 347 Version #1,,347,Tarn Drill Site 2N 330 Temp,,330,Tarn Drill Site 2N 327 Version #2,,327,Tarn Drill Site 326 Version #2,,326,Tarn Drill Site 2N 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 24-Apr-98 236.9 400.1 400.1 28-Apr-98 87.8 500.0 5824.2 22-Apr-98 390.2 200.0 200.0 8-Mar-98 162.8 500.0 6820.0 8-Mar-98 60.3 300.0 6900.0 8-Mar-98 510.2 300.0 300.0 8-Mar-98 540.2 300.0 300.0 21-Apr-98 375.2 200.0 200.0 21-Apr-98 420.2 300.0 300.0 8-Mar-98 360.2 300.0 300.0 8-Mar-98 570.2 300.0 300.0 8-Mar-98 555.2 300.0 300.0 8-Mar-98 525.2 300.0 300.0 8-Mar-98 495.2 300.0 300.0 8-Mar-98 480.2 300.0 300.0 8-Mar-98 465.2 300.0 300.0 8-Mar-98 450.2 300.0 300.0 8-Mar-98 435.2 300.0 300.0 8-Mar-98 285.2 300.0 300.0 8-Mar-98 90.3 300.0 300.0 8-Mar-98 75.3 300.0 300.0 8-Mar-98 117.8 500.0 500.0 27-Mar-98 135.2 300.0 300.0 27-Mar-98 180.2 300.0 300.0 27-Mar-98 195.2 300.0 300.0 343 Version #3,,343,Tarn Drii~'$ite 2N 337 Version #2,,337,Tarn Drill Site 2N 341 Version #2,,341,Tar~ Drill Site 2N 331 Temp,,331,Tarn Drill Site 2N 325 Version #3,,325,Tar~ Drill Site 2N 319 Version #l,,319,Tar~ Drill Site 2N 321 Version #3,,321,Tar~ Drill Site 2N 317 Version #1,,317,Tara Drill Site 2N PMSS <O-9690'>,,329,Taz~ Drill Site 2N PMSS < 0 - 6150'>,,TARN#4,TAR~ #4 PMSS < 2250 - 7162'>,,3A, TARN #3 PMSS < 0 - 7650>,,Tarn#2,TAR~ #2 Tarn #1 (Straight Hole),,1,TARN #1 1 - May- 98 28-Apr-98 28-Apr-98 24-Mar-98 12-Apr- 98 8-Mar-98 12-Apr- 98 8-Mar-98 6 -}4ay- 98 12 -Aug- 97 12 -Aug- 97 14-Aug-9? 12 -Aug- 97 60.0 30.4 28.5 116.8 210.2 300.2 269.8 330.2 150.2 6877.0 4296.5 13047.1 12371.7 200.0 300.0 475.0 575.0 200.0 300.0 200.0 300.0 0.0 375.0 300.O 100.0 8271.9 200.0 5575.0 4380.0 575.0 200.0 300.0 200.0 300.0 0,0 375.0 300.0 100.0 8271.9 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Tarn accumulation development wells 2N-341.2N-337.2N-339 and 2N-345. ARCO Alaska, Inc. by letter dated April 30, 1998 and May 5, 1998. has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of four deviated oil wells to an undefined pool adjacent to the ~vestern boundary, of the Kuparuk River Unit. The first exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-341 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 130' from the north line (FNL), 1,055' from the east line (FEL), Section 3. T9N, R7E. Umiat Meridian (UM) to a target location of 2.506' from the south line' (FSL), 624' from the west line (FWL), Section 4. T9N, R7E, UM. and a bottomhole location of 2,161' FSL. 672' FEL. Section 5. T9N, R7E. UM. The second exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-337 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 117' FNL, 997' FEL. Section 3, T9N. R7E. UM to a target location of 1.032' FSL, 2.421' FEL. Section 4, T9N, R7E, UM. and a bottomhole location of 572' FSL, 2.047' FWL, Section 4, T9N. R7E. UM. The third exception xvould allow ARCO Alaska, Inc. to drill the Tarn 2N-339 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The xvell will be drilled as a directional hole from a surface location 123' FNL, 1,026' FEL, Section 3. T9N. R7E. USVl-to a target location of 2.258' FNL, 616' FEL, Section 4. T9N, R7E. UM, and a bottomhole location of 2.462' FNL. 1,144' FEL. Section 4. T9N, R7E. UM. The fourth exception would allow ARCO Alaska, Inc. to drill the Tarn 2N-345 oil well to a bottomhole location that is closer than 500 feet from a quarter section line. The well will be drilled as a directional hole from a surface location 144' FNL. 1,113' FEL. Section 3. T9N. R7E. UM to a target location of 605' FNL. 118' FWL. Section 3. T9N. R7E. UM. and a bottomhole location of 635' FNL. 289' FEL. Section 4. T9N. R7E. UM. A person who may be harmed if the requested order is issued may file a xvritten protest prior to 4:00 PM, Mav 21. 1998, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501~ and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 1:00 PM on June 4, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after May 21. 1998. If no protest is filed, the Commission xvill consider the issuance of the order without a hearing. If you are a person with a disability who may need a s~on in order to comment or to attend the public hearing, . . 998. David W~ohnston Chairman Published May 6. 1998 ADN AO02814046 · WELL PERMIT CHECKLIST COMPANY /f/_._,,~ WELLNAME , ./~..~,~? .2..~ ~.'~ ? PROGRAM:expE]dev_-~redrlll-lservFIwellboreseg[.Tann. disposalparareq,~ FIELD & POOL INIT CLASS .,Z~ ./-,,~ )'./ GEOL AREA ~ ~ UNIT# ON/OFF SHORE ADMINISTRATION A~ D/),.T_.E ,/ . ENGINEERING 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. 4. Well located in a defined pool .................. Y 5. Well located proper distance from drilling unit boundary .... Y 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ Y 12. Permit can be issued without administrative approval ...... (~ N 13. Can permit be approved before 15-day wait ........... ~) N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... REMARKS 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. GEOLOGY 30. 31. 32. 33. p2 DATE ) 34. CMT vol adequate to tie-in long string to surf csg ........ Y CMT will cover all known productive horizons .......... N Casing designs adequate for C, T, B & permafrost ....... N Adequate tankage or reserve pit ................. ~ N /~j If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. _Y) N If diverter required, does it meet regulations .......... ~N ~))/V Drilling fluid program schematic & equip list adequate ..... ,~N BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~~ psig. N Choke manifold complies w/APl RP-53 (May 84) ........ ~'/"" Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y . -' r: - .::.~..::::::::~::~:.-~:..:.~r-_-.-t~:::.m~.:.~::-::.:-~: ::-:~-::---:--r--~:~:-~---:~:.~-:~:-:.~-...:.-..::.....::-: .:-:::~:.:::~..r~:.-:-. ~ ...... ::: -: -::.._:--:::-.~:.. Permit can be issued w/o hydrogen sulfide measures ..... ~~,~ Data preseated on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. .~ Y N Seabed condition survey (if off-shore) .......... .~.. Y N Contact name/phone for weekly~ro~ress repods . . ~.... Y N [ex~/ora'tory only] ENGINEERING: COMMISSION: JDH ~ ' "~RNC/.,,/~ co ,~../~s" Cc, A:\GEN. Misc\FOF~MS\cheklist rev dlf C:\msoffice\wordian\dial~a\chr~(:Mird · ,., Comments/Instructions: . ' ,., Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 01 15:32:35 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Tape Header Service name ............. LISTPE Date ..................... 98/07/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT MWD RUN 3 AK-MM-80237 R. KRELL R. SPRINGER FROM MSL 0) 2N-339 501032026100 ARCO ALASKA, INC. SPERRY-SUN 01-JUL-98 3 09N 07E 124 1026 DRILLING SERVICES KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9. 875 7. 625 2863.0 6.750 8239.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF THE MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DOUG HASTINGS AND ALI TURKER ON 06/25/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTION~tL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). NO FOOTAGE DRILLED DUE TO INITIAL CASING PRESSURE TEST FAILURE. NO DATA IS AVAIIJLBLE TO PRESENT. 5. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY ~HASE-4 (EWR4). 6. ALL MWD RUNS REPRESENT WELL 2N-339 WITH API# 50-103-20261-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8239'MD, 5540'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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH STOP DEPTH 2900.0 8184.0 2900.0 8238.5 2950.5 8191.0 2950.5 8191.0 2950.5 8191.0 2950.5 8191.0 2950.5 8191.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 2970.0 8239.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMS4 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMS4 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max DEPT 2900 8238.5 ROP 7.3245 639.639 GR 30.1396 252.417 RPX 0.0629 84.6519 RPS 0.7089 2000 RPM 0.2853 2000 RPD 0.3349 2000 FET 0.2257 79.5037 Mean Nsam 5569.25 10678 203.833 10678 124.695 10569 4.48603 10482 4.9697 10482 5.50866 10482 8.2176 10482 0.912133 10482 First Reading 2900 2900 2900 2950.5 2950.5 2950.5 2950.5 2950.5 Last Reading 8238.5 8238.5 8184 8191 8191 8191 8191 8191 First Reading For Entire File .......... 2900 Last Reading For Entire File ........... 8238.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/01 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 ....... 98/07/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2900.0 ROP 2900.0 FET 2950.5 RPD 2950.5 RPM 2950.5 RPS 2950.5 RPX 2950.5 STOP DEPTH 8184.0 8238.5 8191.0 8191.0 8191.0 8191.0 8191.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): ~' FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type...~.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 27-MAY-98 5.07 5.46 MEMORY 8239.0 2970.0 8239.0 43.9 55.2 TOOL NUMBER P0959SP4 P0959SP4 6.750 6.8 LSND 9.10 42.0 9.0 500 5.2 2.400 1.696 2.500 2. 600 46.7 .0 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 3 FT/H 4 1 GR MWD 3 API 4 1 RPX MWD 3 OHMM 4 1 RPS MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHMM 4 1 FET MWD 3 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 2900 8238.5 ROP 7.3245 639.639 GR 30.1396 252.417 RPX 0.0629 84.6519 RPS 0.7089 2000 RPM 0.2853 2000 RPD 0.3349 2000 FET 0.2257 79.5037 Mean Nsam 5569.25 10678 203.833 10678 124.695 10569 4.48603 10482 4.9697 10482 5.50866 10482 8.2176 10482 0.912133 10482 First Reading 2900 2900 2900 2950.5 2950.5 2950.5 2950.5 2950.5 Last Reading 8238.5 8238.5 8184 8191 8191 8191 8191 8191 First Reading For Entire File .......... 2900 Last Reading For Entire File...i ....... 8238.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Reel Trailer Service name ............. LISTPE Date ..................... 98/07/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Scientific Technical Physical EOF Physical EOF End Of LIS File