The URL can be used to link to this page

Home My WebLink About203-017STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 01 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E] AQGG w ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ID Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: ConoCoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 1 203-017 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20449-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 i<fiu 2T-218 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,360 feet Plugs measured None feet true vertical 3,076 feet Junk measured None feet Effective Depth measured 7,325 feet Packer measured 2891 5284 feet true vertical 3,075 feet true vertical 2056, 2994 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 feet 16 109' MD 109' TVD SURFACE 5,443 feet 10 3/4 5,480' MD 3023' TVD GRAVEL PACK LINER 2,066 feet 5 1/2 " 7,350' MD 3075' TVD Perforation depth: Measured depth: 5547-7350 feet True Vertical depth: 3033-3075 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,110' MD 2,967' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - WEATHERFORD PACKER 2,891' MD 2,056' TVD PACKER - SCA R PACKER 5,284' MD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation: 287 83 7714 489 1 222 Subsequent to operatiowl 884 160 9494 679 1 286 14. Attachments (required Per 20 AAC 25.070, 28.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil EI 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: 318-559 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells Engineer Authorized Si nature: L 1 q Contact Phone: (907)263-4627 Date: 1 "1� "� �'rt- 413/19 ,111 RBD APR 0 21019 KUP PROD WELLNANE 2T•218 WELLBORE 2T-218 ConocoPhillips aa6kE, b1c. zaz+e. arzzrzma++ao'.1a AM Last Tag varo-alxtenotic pcemll A..,.., pePtb(fll(B)End Desk We11Wn tsstMWBy Las(Tag: 5,048.0 95200) 21-218 ........_.._..........._................_._...._....._... IWVoj Conversion Last Rev Reason Annotatbn End Date 1 vlellbon IaarMMay +Ja�e.r as i_ Rev Reason'. Pulled Plug & Set OV ...... 1,T-218 JzEsrrmeyl Casing Strings casing oeantlopen (in) to (is) Top(M1NB) set D. (me) Bet Dopa, lrvD)_. WaLen ll...onde trip Tbrcad 100 CONDUCTOR ib 15.06 370 109.0 109.0 6250 H-/0 WELDED I Call, pescrlppartOD tin) ID lin) TOPIM1KB) SN DepIh IS.,sN Dykm IIvol- per. (L.. Grade Top Tnrwd SURFACE 10314 9.97 3,S 5,4]9.6 3,0230 45.50 L-80 BTC Galva Daaeinse OD (in) IDlin) Topumato BMMpM@KB) ossesM1 I1V01... WbLen 11._GrYe Top Tbwd wn coxpa(i0al s]0tw.o GRAVEL PACK LINER 512 4.95 5283.9 ],350.0 3,0]5.3 Liner Details Nampato T,IMe) 11 MD) DKED Top mc119 arum Prue con DID 5,283.9 2,993.9 8144 PACKER MODEL SC -1R PACKER 6000 5,2890 2.994) 8144 EXTENSION UPPER EXTENSION 6.]]0 5,2927 2.995.3 81.44 SLEEVE SLIDING SLEEVE wSEAL BORE 6.00 5,2964 2,995.8 8144 EXTENSION LOWER EXTENSION 6300 mndar Ekdd-pM.M; Iso 5.326.6 3,0003 8144 KOIV KNOCK OUT ISOLATION VALVE 6310 2>6oppeav rzoa EBPcaw:Smy 5,54].5 3,0328 82.22 SCREEN EXCLUDER SCREEN 4.950 7,324.6 3,0]46 88.52 0 -RING 0 -RING SEAL SUB 2.8]5 mbnpxO; 2AW7 Tubing Strings MagM'. 2.e)36 Tubing Description sang Ma_. +p (In) Top (al(e) last Deep (IT 1.1 Depth (rvp) 6.. intpna9 Oracle Top c*nnmSon TUBING 4112 396 0.0 5,199.4 2,9812 1260 L-80 .BTM Tun,x028107 Completion Details Pcpx P89Ia Top (WO) Top Incl Nonlnal Top DIKED mMp) f) Ikn ours com to (in) 34.2 34.2 0.18 Haagen EMC 11" x 4 2" ESP,1 1 bn x Acme Top w.4" Type 3.958 H" BPV SIBS 517.3 866 Nipple -UB 45"x 3 812"Camm'DB' Nipple, 9Cr(SIN: T031216) BEA 3.812 McM'el];e(3.a 2890.5 2056.3 66.51 Packer WeaNerkrd D&L Oil tools Packer (16314 x 4-12) 3.920 5,021.6 2,951.8 79.56 Nipple -DB 4.5'x 3]S Des. DB'Nlpple 9Cr (SIN. 3656-3) 3750 ser""D's -c°"°`I°" Mnnnd a.lD; 6 5,111.5 2967.0 8051 DischaraSu Summit dischara pressure sub ACE 312"SS SN: 0016 1.000 (ESP)9 9 ( ) 5,112.8 7967.2 80.51 ESP Pumps Summit 513 Series 042 stage Pump (SIN -SP18316J3J2) 1.000 5,145.5 2972.6 80.61 ESP Intake Summit lmakelseparstpr 1,000 / 5,146.8 2,972.8 8062 Seal Assembly Summit Seal Section PBSL513sEhes(S1N:5S17D105485) 1.000 5,164.6 2,9751 80.76 & Summit 562 Sell. KM 5 HP 5V. 2,ESP &I SIN'. 1.000 JEEPMotors Cables EM18E146613) 5,195.52,980 .8 81.03 P awns Summit Sensor(SM: SSDHV033) 1.000 Cables 5,197.6 2,980.9 81.114 Centralizer Summit Centralizer Motor Guide S 62- CD) 1.000 xomMm):s.up+ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, Inc.) GxMpe Sub lESP): 5,111.5 raplrvDD TOP 1flKE) (RME) pop Incl (°) Des core Pun Date Ip lin) ESP Pieces : 5.112,6 34.2 34.2 0.18 ESP Cable 22N2019 perforations & Slots ESP InYM', S, less shot Den setlFwctio, s.1a6.T Tappee) BtntM1Ke) TSeKel) Bt(DM61) unxMzone w@ an) Type Coll BSPMoe ."assNs18(.6 5,547.0 ],350.0 3, ,l 30]5.3 - 218 41&2003 1 50.0 SLOTS GRAVEL PACK SCREEN E&P Nolas a cede4 &Ia85 laandral Inserts cella 'S,taiB St as ber Top phDn Valor tech PortStre TRO Run K Top 11IX8) MB) Mese MMeI OO en1 Besv Type Type Kiri) 1psp Rnn pOk Com 2,8]3.8 2,0495 CAMCO KBMG 1 DMY BK 0.000 0.0 3/1412019 11 2,943.9 2,0]].3 CAMCO IKBMU 11 JUMY BK I Ums)l JV I2262019 Notes: General & Safety EndDak I Anncnlmn 1 27 3 512010 NOTE: View Schematic wl Alaska Schemanc90 sumosca as"..>9e- BLOT&: GSoV1s1.X IJXEE; S,ffi16 I.P00� Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth StartTime End Time Our(hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(ftKa) 2/20/2019 2/21/2019 4.00 DEMOB MOVE MOB P RD off 2T-22. 20:00 0000 2/21/2019 2/22/2019 24.00 MIRU MOVE MOB P Move rig and pits, back in and spot rig 0000 0000 over well center and verify center over well. Install herculite liners, move outside tanks, hardline. Rig up all auxilary equpiment Replace choke hose. Replace rotary table. Button up pits to rig. 2/22/2019 2/22/2019 2.50 MIRU WELCTL NUND P Rig accepted at 00:00. Prepare cellar 00:00 02:30 and install secondary annulus valve. Install gauges on tubing - Opsi, IA - 200psi. Bleed liquid and some gas from IA to zero pressure in two minutes, bleed pressure off adapter flange per FMC wellhead rep. 2/22/2019 2/22/2019 5.50 MIRU WELCTL NUND P Break bolts on tree, NO tree. Install 02:30 0800 adapter spool 11" 5k x 13 5/8" 5k. NU BOP. 2/22/2019 2/22/2019 2.50 MIRU WELCTL NUND P Install riser and flowline to riser 0800 10:30 adapter to annular. TO bolts on choke hose to BOP. 2/22/2019 2/22/2019 2.00 MIRU WELCTL CLEN P PU test tools, grease choke 10:30 12:30 manifold/HCR valves prep 4.5" test joint, xovers. 2/22/2019 2/22/2019 0.50 MIRU WELCTL SVRG P Service rig. Fill surface equipment. 12:30 13:00 2/22/2019 2/22/2019 6.00 MIRU WELCTL BOPE P Test BOPS to 250 low/ 1500psi high 5 13:00 19:00 min each with 4 1/2" test joint. CMV 1 -16, super & manual choke, choke and kill HCR, upper and lower 2.875" x 5" VBR, blind ram, annular, TO IBOP and lower valve, dart valve, floor valve. 2/22/2019 2/22/2019 2.00 MIRU WELCTL MPSP P Pull blanking plug. Pull BPV with dry 19:00 21:00 rod, turning 1/4 turn and observing well at each turn. 2/22/2019 2/23/2019 3.00 MIRU WELCTL NUND P MU dutch riser. PU and stab into 21:00 0000 annular. RU slickline. 2/23/2019 2/23/2019 7.00 MIRU WELCTL MPSP P RU Halliburton full pressure slickline 00:00 0700 lubricator to dutch riser. Pressure test to 750psi. RIF, pressure wellbore to 800psi, release prong, pressure fell to 130psi. Allow pressure to equalize, POOH. Bleed and break off lubricator, swap to retrieval tool. RIF, latch on to plug at 481', POOH, LD RBP. RD slickline. RD dutch riser. 2/23/2019 2/23/2019 1.00 MIRU WELCTL KLWL P Tubing pressure increased from 130 07:00 0800 psi to 196 psi. Line up tubing to gas buster. Attempt to bleed off pressure. Bleed pressure down from 196 psi to 172 psi, observed 6.8 ppg diesel back to surface. No gas to surface. Shut well in to monitor pressure. Observed pressure increase from 172 psi to 190 psi. Pressure build due to U-tube differential pressure. Page 117 Report Printed: 3/612019 Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log SOO Depen Start Time Ed Time Dur (Inn Phase Op Coce Activity Coce Time P -T -X operahan (m<B) End Dept,(ftKB) 2/23/2019 2/23/2019 3.50 MIRU WELCTL KLWL P Line up to tubing and bull head tubing 08:00 11:30 volume of 80 bbls with 8.8 ppg KWF. Pump at 2 bpm at 220 psi initial circulating pressure, final circulating pressure 80 psi. Shut down pump and monitor well for flow. Observed flow. Pump an additional 70 bbls of 8.8 ppg KWF down tubing at 2 bpm. ICP= 110 psi and FCP = 80 psi. Observe well for flow. No flow observed. 2/23/2019 2/23/2019 0.50 MIRU WELCTL OTHR P Pick up 4 1/2" IBT landing joint and 11:30 12:00 make up to tubing hanger. Close annular in preparation for packer gas. Set approximately 10k down on hanger and BOLDS. Unseat hanger and release packer with 170 string weight. 2/23/2019 2/23/2019 2.50 MIRU WELCTL KLWL P Observed 190 psi on IA. Line up to 12:00 14:30 pump down 4 1/2" tubing in preparation to kill well. Line up to take returns out IA to tiger tank. Pump 395 MIS of 8.8 ppg KWF at 2 BPM. Pump pressure 13 psi. Well taking fluid. Received a total of 250 bbls back to surface, mainly diesel and diesel cut brine 7.1 -7.5 ppg. Shut pump down and shut in IA to build volume. IA pressure 55 psi. 2/23/2019 2/23/2019 0.50 MIRU WELCTL OTHR P Build volume. Build an additional 100 14:30 15:00 bbls of 8.8 ppg KWF. 2/23/2019 2/23/2019 3.00 MIRU WELCTL KLWL P Observed 55 psi on IA. Line up to 15:00 18:00 pump down 4 1/2" tubing in preparation to kill well. Line up to take returns out IA to tiger tank. Pump an additional 90 MIS of 8.8 ppg KWF at 2 BPM. Pump pressure 13 psi. Well taking fluid. Received a total of 60 bbls back to surface, mainly diesel and diesel cut brine 7.1 -7.5 ppg. Shut pump down and shut in IA to build volume. IA pressure 25 psi. Pump an additional 98 bbls of 8.8 ppg of KWF received 35bbl back to surface. Shut down pump and shut in well. IA pressure =9 psi. SI and observe well. Pump an additional 20bbl of 8.8ppg, at 2bpm, received I Obbl diesel back to surface. Shut down pump and shut in well. No pressure on IA. 80bbl of KWF remain in pits. 2/23/2019 2/23/2019 2.50 COMPZN RPCOMP RURD P RU ESP spooling unit, elephant trunk. 18:00 20:30 Take on truckload of fresh water, blend with 8.8ppg and dust up for total in pits of 350bbl of 8.5ppg. 2/23/2019 2/24/2019 3.50 COMPZN RPCOMP PULL P Observe well, discuss with town 20:30 00:00 engineer swap to seawater. Open IA, no flow. Open annular, pull hanger to floor, cut ESP cable. Summit diagnostics on ESP cable indicate problem is down hole, wire is grounded. Break off, LD tubing hanger. Page 217 Report Printed: 3/6/2019 Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time Eno Time Dur (h,)Phase Op Code Activity Cade Time P -T -x Operation (ftKB) End Depth (ftKB) 2/24/2019 2/24/2019 1.50 COMPZN RPCOMP KLWL P Bullhead 200bbl 8.5ppg at 61bpm, 00:00 01:30 500psi down the annulus. Caught fluid/pressure at 3bbl away. Shut down pump, open well. Static loss rate 10bbl per hour. 2/24/2019 2/24/2019 2.00 COMPZN RPCOMP PULL P Lay down tubing from 5164'to 5040' 01:30 0330 filling back side with 5bbl from trip tank every 30min. 2/24/2019 2/24/2019 2.50 COMPZN RPCOMP KLWL P Observe diesel flowing (u -tubing) f/ 03:30 0600 tubing, stab TIW valve. RU to circ tubing volume through cml line cont to fill back side every 30min w/ 5bb f/ trip tank. SD wait on fluids. 2/24/2019 2/24/2019 3.00 COMPZN RPCOMP WAIT T Wait on Sea water truck. Fill pits up 06:00 09:00 with sea water when truck arrived. Tubing had u -tube pressure of 15 psi. While waiting on trucks for volume, concurrently bleed off tubing pressure. Well out of balance, bleed back approximately 15 bbls of diesel via tubing. Monitor well for flow for 30 mins. No flow observed. 2/24/2019 2/25/2019 15.00 COMPZN RPCOMP PULD P PJSM with all personnel involved in 09:00 0000 pulling 4 1/2" ESP Completion string. POOH with 4 1/2" completion string from 5040'to surface, laying down all and inspecting all 1/2" tubing for damage. Test ESP cable, good test at packer. Lay down completion jewelry as well. Clean, drift and strap all 4 1/2" tubing laid down, to be re -ran on new 4 1/2" ESP completion. Filling backside w/ 5bbl 8.6ppg seawater every 10joints. At 18:00 Total Brine losses = 450 bbl 2/25/2019 2/25/2019 1.00 COMPZN RPCOMP PULL P LD remaining tandem seal section and 00:00 01:00 ESP motor. Motor was corroded on the outside, bits of metal shavings and rubber on inside. Clean and clear rig floor of 156 CC clamps, 3 equip clamps and 2 pro clamps, stage new CC clamps on floor. Pump 5bbl SW into well every 30mm. 2/25/2019 2/25/2019 2.50 COMPZN WELLPR RURD P Spool up remaining ESP cable, RD 01:00 03:30 elephant trunk, swap ESP reels. Pump 5bbl SW into well every 30min. Load pipe shed with jewelry, pumps, packer. 2/25/2019 2/25/2019 8.50 COMPZN RPCOMP PUTB P PU Summit ESP motor and seal 03:30 12:00 section, allow air to work out of cold oil. Install motor guide on sensor, make up to seal assembly and two pumps. Pull new cable to rig floor. Install 5 motor clamps, 6 seal clamps, 8 pump clamps, 1 splice clamp and motor lead extension. Test motor/sensor/ESP cable, all test good. Test discharge line to 5000 psi, test good. Cycle pump. Continue to pump 5bbl SW every 30min, fluid staying at about wellhead level. Page 3/7 Report Printed: 3/6/2019 , Operations Summary (with Timelog Depths) 4 1 qW 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur(hr) Phase Op Cotle Activity Cotle Time P-T-X Operation Stan Depth (ftKB) End Depth(0(B) 2/25/2019 2/25/2019 5.00 COMPZN RPCOMP PUTB P PJSM with rig crew and Summit 12:00 1700 personnel on picking up 4 1/2" IBT tubing. Pick up used tubing and run in hole 4 1/2" IBT completion string replacing seal rings in box, make up torque average 3650 ft lbs with Jet Lube dope. Test ESP cable every 100011. ESP spooling unit generator faled, order out replacement. Filling IAwith 5bbl 8.6ppg seawater every 30min 2/25/2019 2/25/2019 0.50 COMPZN RPCOMP SVRG P Service rig. Grease draw works, 17:00 1730 adjust brakes, grease topdrive. 2/25/2019 2/25/2019 0.50 COMPZN RPCOMP WAIT T Waiting on Summit replacement 17:30 1800 generator for ESP spooling unit. at 18:00 Daily Brine losses = 217 bbl Total Brine losses = 667 bbl 2/25/2019 2/25/2019 3.00 COMPZN RPCOMP PUTB P Continue picking up used tubing and 18:00 21:00 run in hole 4 1/2" IBT completion string replacing seal rings, make up torque average 3650 ft lbs with Jet Lube dope. Test ESP cable every 100011. PU Weatherford 10 3/4" x 4 1/2" feed through packer. Filling IAwith 5bbl 8.6ppg seawater every 30min 2/25/2019 2/26/2019 3.00 COMPZN RPCOMP PULD P PJSM for splicing cable. Splice ESP 21:00 00:00 cable into feed through packer. Filling IAwith 5bbl 8.6ppg seawater every 30min, 2/26/2019 2/26/2019 2.00 COMPZN RPCOMP PUTB P Complete Splice ESP cable through 00:00 0200 packer. Verify cable, good. 2/26/2019 2/26/2019 8.00 COMPZN RPCOMP PUTB P Continue picking up used tubing and 02:00 1000 run in hole 4 1/2" IBT completion string replacing seal rings, make up torque average 3650 ft lbs with Jet Lube dope. Cannon clamps on every joint. Test ESP cable every 1000ft. Up weight 83k and down weight 59k. Filling IAwith 5bbl 8.6ppg seawater every 30min 161 Cannon Clamps, 4 mid joint GLM, 2 on upper GLM, 2 on lower GLM, 2 half, and 4 single clamps ran in hole. 2/26/2019 2/26/2019 4.00 COMPZN RPCOMP PULD P Make up landing joint to hanger. 10:00 1400 Orientate hanger to line up with well head profile. Test ESP cable, test good. Remove sheave from derrick. Land tubing hanger in well head profile. Run in LDS. Test ESP cable, test good. 2/26/2019 2/26/2019 4.50 COMPZN RPCOMP CIRC P Displace well bore fluid with 8.6 ppg 1400 1830 Cl Seawater. Pump 500 bbls at 2 bpm down tubing at 80 psi, packer limitation, taking returns up the IA to bleed trailer. Minimal returns observed at surface. Page 417 Report Printed: 3/6/2019 Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time our rv) Phase Op Cotle Activity Cotle Time P -T -X Operation (ftKB) End Depth(ftKB) 2/26/2019 2/26/2019 2.50 COMPZN RPCOMP PACK P Drop ball and rod. Line up to pump 18:30 21:00 down tubing, IA open to bleeder, attempt to pump ball/rod on seat to set packer, RHC seat at 80deg inclination. Adjust pump rate f/ lbpm to 6bpm, 30- 800psi slight returns noted from IA. No set. Order more seawater, discuss with town engineer pumping viscous pill or using slickline. Slickline unit already on 2T pad, will move over. 2/26/2019 2/27/2019 3.00 COMPZN RPCOMP RURD P Clean and clear floor, remove pump in 21:00 0000 sum, rig down cement line, blow down lines. Spot slickline unit, bring tools and shives to floor. Hot shot crossover sub to location. PJSM for rig up. Remove elevators, make up crossovers to slickline Otis connection on grease head; bring wire to floor and thread through. Assemble and pick up tools, make up to 4 1/2" landing joint. Daily losses 594bbi Cumulative losses 1261bbl 2/27/2019 2/27/2019 2.00 COMPZN RPCOMP SLKL P RIH with 2.70 bell guide on slick line 00:00 0200 from surface to 5007'. Pump down tubing at 2bpm. Pump ball on seat pressure up to 1800 psi, set packer and hold 1800 psi for 30 minutes. Test good. POOH with slick line. 2/27/2019 2/27/2019 1.50 COMPZN RPCOMP RURD P Rig down slick line equipment and 02:00 03:30 tools. Summit performed electrical test on ESP. Test good. 2/27/2019 2/27/2019 2.50 COMPZN RPCOMP PRTS P Pressure test tubing to 3000 psi for 15 03:30 06:00 minutes. Test good. Bleed tubing pressure down to 1500 psi. Pressure up IA to 2500 psi. Maintain both tubing pressure and IA pressure for 30 mins and chart. Test good. Bleed tubing pressure down from 1500 psi to 0 psi, while maintaining 2500 psi on IA in attempt to shear out SOV. Attempt failed. Pressure up IA from 2500 psi to 3000 psi four times, unable to shear out valve. Pressure up tubing to 1500 psi and IA to 3500 psi. Bleed off tubing pressure quickly to 0 psi. SOV successfully sheared open. Pump to verify communication between IA and tubing. 2/27/2019 2/27/2019 1.00 COMPZN RPCOMP OTHR P Blow down equipment. Lay down 06:00 07:00 landing joint and 4 1/2" handling equipment. 2/27/2019 2/27/2019 0.50 COMPZN WELCTL MPSP P Install BPV and pressure test to 1000 07:00 07:30 psi for 5 mins. Test good. 2/27/2019 2/27/2019 1.50 COMPZN WELCTL NUND P Remove riser. Nipple down BOP 07:30 09:00 stack and remove adapter. Set BOP stack back on trolley and secure. 2/27/2019 2/27/2019 2.00 COMPZN WELCTL NUND P Clean hanger profile. Change out 09:00 11:00 1 production valve on wellhead. Page 517 Report Printed: 316/2019 Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan DapN Steri Time End Time Dur (m) Phase Op Code AcbAy Code Time P -T -X Opereeon (/IKB) End Depth (ftKa) 2/27/2019 2127/2019 7.00 COMPZN WELCTL NUND T Attempt to nipple up tree as per FMC. 11:00 18:00 Tubing adapter would not fit over the penetrators on hanger. Change penetrators, still no fit. Try old adapter, no fit, try new penetrators and old adapter, no fit. The I -wire bore is 1/4" off. Confer with town engineer, FMC engineer. Decision made to NU BOP and set RBP, set dry hole tree and RDMO. Order out equipment Check adapter fit without blanking plugs on i - wire or heat trace. 2/27/2019 2/27/2019 4.00 COMPZN WELCTL NUND X Wait on and set blanking plug in well 18:00 22:00 head, install adaptor flange and torque up. NU BOP and torque up. Install riser. 2/27/2019 2/27/2019 0.50 COMPZN WELCTL BOPE X Function test BOPs, RU test 22:00 2230 weuipmn,flood lines, purge air. 2/27/2019 2/28/2019 1.50 COMPZN WELCTL BOPE X Attempt to shell test BOP, blanking 22:30 00:00 plug leaking fluid coming out. 2128/2019 2/28/2019 3.50 COMPZN WELCTL BOPE X Continue to attempt to pressure test 00:00 03:30 BOP. Remove blanking plug and pull to surface and inspect. Re -dress blanking plug and re -install in wellhead profile. Close blinds to test, blanking plug still leaking. Remove blanking plug and inspect. Re -dress blanking plug again, file off a very small burr and re -install firmly. 2/28/2019 2128/2019 0.50 COMPZN WELCTL BOPE X Perform BOP shell test and blind rams 03:30 04:00 to 250 psi low for 5 mins and 1500 psi high for 10 mins. Test Good. Note: State, Austin McLeod waived witness. 2/28/2019 2/28/2019 0.50 COMPZN WELCTL MPSP X Remove blanking plug. Drain stack 04:00 04:30 and dry rod remove BPV. 2/28/2019 2128/2019 0.50 COMPZN WELLPR RURD X Rig up slick line equipment. 04:30 05:00 2/28/2019 2/28/2019 2.50 COMPZN WELLPR SLKL X RIH with slick line from surface to 05:00 07:30 5007'. Latch on ball and rod, rig pump pressure up to 500psi, POOH slickline retrieving tool, saw pressure fall off. POOH with ball and rod to surface. Lay down ball and rod. Lay down landing joint. Re -head slick line. 2/28/2019 2/28/2019 2.50 COMPZN WELLPR SLKL X RIH with slick line kick over tool. 07:30 10:00 Perform flagging run to correlate RBP setting depth. RIH from surface to 2869' slick line measurement. POCH 2/28/2019 2/28/2019 2.00 COMPZN WELLPR SLKL X Pick up RBP and setting tools. RIH 10:00 12:00 with slick line. Set RBP elements mid joint at 2917' slick line measurement. POOH and set slick line tools aside in preparation to test RBP. 2/28/2019 2/28/2019 0.50 COMPZN WELLPR PRTS X Confirm line up and close blind rams. 12:00 12:30 Circulate down kill line down tubing through IA to tiger tank until returns established. Hole fill. Pressure test RBP to 1500 psi for 15 mins. Test good. 2/28/2019 2/2812019 1.00 COMPZN WELLPR RURD X Rig down slick line equipment. 1230 13:30 Page 617 Report Printed: 3/612019 Operations Summary (with Timelog Depths) 2T-218 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Dec. Activity Ccde Time P-T-X Operation Stan Depth (flKB) End Depth(fiKB) 2/28/2019 2/28/2019 5.50 COMPZN WELLPR FRZP X Pick up landing joint and screw into 13:30 19:00 hanger Rig up circulating iron to tubing and rig up little red services to IA. Freeze protect well pumping 266 bbls of diesel at 3 bpm at 800 psi. Circulating down IA taking returns up tubing to the tiger tank. Allow equalize IA and tubing to allow to U-tube. 2/28/2019 2/28/2019 1.00 COMPZN WELLPR MPSP X Pull landing joint. Set BPV Test BPV 19:00 2000 to 1500psi with Little Red for 5min. Good test. Bleed off pressure, suck back with Little Red to drain stack. 2/28/2019 2/28/2019 1.50 COMPZN WELLPR NUND X ND BOP stack, remove riser, ND 20:00 21:30 adapter flange. 2/28/2019 2/28/2019 1.50 COMPZN WELLPR OWFF X Put tubing adapter in cellar. Clean 21:30 23:00 hanger profile, prep dummy stubs and adapter. Install tree test dart. Bleed IA to bleed trailer, RU trash pump and suck on IA, just a trickle. SD pump, RD. IA on a vac. 2/28/2019 3/1/2019 1.00 COMPZN WELLPR NUND X With IA open. Change dummy 23:00 00:00 penetrators, one at a time, to the cut off flush version. Install adapter with machined dummy stubs in place. PU and install flange on adapter, torque up. 3/1/2019 3/1/2019 3.00 COMPZN WELLPR NUND P Pressure test tubing hanger packoffs, 00:00 0300 adapter void, machined blank seals. Low - 250psi 5min passed, High - leaking at 3000psi. I-wire blank leaking. Unbolt adapter flange, replace o-ring seal on I-wire blank. Re install adapter and torque up. Pressure test low - 250psi 5min, High - 5000psi 10min. Good lest. 3/1/2019 3/1/2019 1.00 COMPZN WELLPR NUND P NU master and swab. Attempt to test, 03:00 0400 new wing valve flange leaking, not tightened. Tighten newwing valve flange to wellhead. 3/1/2019 3/1/2019 1.50 COMPZN WELLPR PRTS P Pressure test tree. Low 250psi-5min, 04:00 05:30 High 5000psi 10 min good test. IA open to bleed trailer 3/1/2019 3/1/2019 1.50 COMPZN WELLPR MPSP P Monitor well, IA open to bleed trailer. 05:30 07:00 Dry rod out test plugs, dry rod set BPV -H. Install tree cap. Rig released at 07:O0hrs Page 717 ReportPrinted: 3/6/2019 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2T-218 Run Date: 1/19/2019 203017 30377 February 13, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-218 Digital Data in LAS format Digital Lo file RECEIVED g � g g 1 CD Rom 50-103-20449-00 FEB 19 2019 A®GCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q3 - 0 1 7- Well History File Identifier Organizing (done) o Two-sided III" 11111"" 11111 ~an Needed r . OVERSIZED (Scannable) RESCAN ~Olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No.3 o Other, No/Type: o Maps: o Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: Scanning Preparation BY: Helen~ ~ x 30 = /0 () o Other:: I Date:S It, ~ Isl In J I Date: 6 I b ~~ Isl »1!J + -1J,_ = TOTAL PAGES \ Count doe:s I)Ot "tlCIU. de cover sheet) VIA 'J Date: S" J 61._ ñs- 151 , r I . NOTES: BY: Helen ~ Project Proofing BY: Helen ~~ . Production Scanning I Stage 1 Page Count from Scanned File: 77 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¡/ YES NO " 0 HelenCMaria) Date: S 16 ø Isl m· If NO in stage 1, page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: 151 III ., I II III Date: Isl Quality Checked 111111111111" 1111I Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: RECEIVED STATE OF ALASKA ' AL1A OIL AND GAS CONSERVATION CO4SION 1 0 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell P' Plug Perforations r Perforate r 4Q49Qc /cep jaCC Alter Casing r Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension r 675 P Change Approved A ogram r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r _ - 203 - 017 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service -` 50- 103- 20449 -00 — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 " 2T - 218 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): CCL Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 7360 feet Plugs (measured) None true vertical 3076 feet Junk (measured) None Effective Depth measured 7360 feet Packer (measured) 2922 true vertical 3076 feet (true vertucal) 2069 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 114 114 SURFACE 5443 10.75 5480 3023 GRAVEL PACK L 2066 5.5 7352 3075 SCANNED MAR 0 12013 Perforation depth: Measured depth: 5547' - 7325' True Vertical Depth: 3031' - 3075' Tubing (size, grade, MD, and TVD) 4.5, L - 80, 5164 MD, 2976 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD HYDROW II PACKER (10 -3/4 X 4 -1/2) (S/N:45045309 -1) @ 2922 MD and 2069 TVD PACKER - MODEL SC -1 R PACKER @ 5284 MD and 2994 TVD SSSV - CAMCO D NIPPLE @ 510 MD and 509 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 506 106 6478 -- 238 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ • Service r Stratigraphic r 16. Well Status after work: - Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson • 263 -4693 Printed Name EriAg" / Title Sr. Wells Engineer Signature C Phone: 263 -4693 Date 1 *--d,, /_ 'Affit2- Form 10-404 Revised 1112U'I' SEP 1 010 ;� G NA L / v Sub Original Only � KUP • 2T -218 Conoc i hIIIips KW**** Well Attributes Max Angle 8, MD TD Alaska Inc Wellbore APIIUWI Field Name Well Status !nci (°) MD (ftKB) Act Btm (ftKB) 501032044900 TABASCO PROD 92.93 6,447.51 7,360.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date wanconeg - 2r 216,ar2v2o126:23so AM . SSSV:NONE 10 10/28/2011 Last WO: 8/10 /2012 43.19 4/10/2003 Schemalk - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 5,048.0 9/5/2007 Rev Reason. GLV C /0, PULL PLUG ninam 8/21/2012 Casing Strings .,. Casing Description String 0... String ID ... Top (ftK8) Set Depth (0... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 34 " CONDUCTOR 16 15.062 37.0 109.0 109.0 62.50 H 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (G.. Set Depth (TVD) ... String Wt... String ... String Top Thrd ' SURFACE 103/4 9.974 36.6 5,479.6 3,022.9 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (9... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 51/2 4.950 5,283.9 7,350.0 3,075.3 LINER CONDUCTOR. 37 -109 Liner Details , Top Depth (ND) Top Inc! Nomi... Top (ftKB) (RKB) (°) Item Description Comment ID (in) NIPPLE, 510 5283.9 2,993.9 81.40 PACKER MODEL SC -1R PACKER 6.000 5,289.0 2,994.7 81.41 EXTENSION UPPER EXTENSION 6.770 5,292.7 2,995.2 81.41 SLEEVE SLIDING SLEEVE w /SEAL BORE 6.000 ) 5,296.5 2,995.8 81.41 EXTENSION LOWER EXTENSION 6.300 5,326.6 3,000.3 81.43 KOIV KNOCK OUT ISOLATION VALVE 6.310 ESP Cable. 34 5,547.5 3,031.1 81.42 SCREEN EXCLUDER SCREEN 4.950 ESP 7,324.6 3,074.6 88.52 0-RING 0 -RING SEAL SUB 2.875 MANDREL, 2,798 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) I Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 34.2 5,164.2 2,976.1 12.60 L -80 IBTM Completion Details PACKER, 2,922 Top Depth (ND) TO Intl Nomi... Top (ftKB) (MR) ( "1 Item Description Comment ID (in) 34.2 34.2 0.70 HANGER FMC 11 "x4.5 ESP TUBING HANGER 3.958 510.0 508.5 8.49 NIPPLE CAMCO D NIPPLE (S/N: T031215) 3.812 ESP 2,922.5 2,069.4 67.91 PACKER WEATHERFORD HYDROW I I PACKER (10-3/4 x 4 -1/2) 3.920 MANDREL 3,033 (SIN:45045309 -1) 4,817.1 2,905.1 74.15 NIPPLE CAMCO DB NIPPLE w/ RHC -M PLUG INSTALLED (S /N: T031022) 3.562 5,078.3 2,961.5 80.41 GAUGE WELL LIFT DISCHARGE GAUGE UNIT (S/N: 12129835) 3.958 5,086.8 2,962.9 80.44 X0 Reducing CROSSOVER 4 1/2' 8rd EUE x 3 1/2" 8rd EUE 3.500 5,097.8 2,964.7 80.47 DISCHARGE CENTRILIFT DISCHARGE SUB (PM: C50557) ESP 5,098.3 2,964.8 80.47 PUMP CENTRILIFT 61 P100 PUMP (S/N: 12352484) MANDREL, 5,120.3 2,968.5 80.54 INTAKE CENTRILIFT INTAKE (S/N: 12034903) 4.763 5,121.3 2,968.6 80.54 SEAL CENTRILIFT TANDEM SEAL SECTION (S/N: 12064508) ' 5,128.2 2,969.8 80.56 SEAL CENTRILIFT TANDEM SEAL SECTION (S/N: 12064705) 5,135.1 2,970.9 80.55 MOTOR CENTRILIFT 562MSP1 336/2650/77 ESP MOTOR (S/N: 12347568) NIPPLE, 4,817 5,160.5 2,975.6 81.44 GAUGE WELL LIFT MOTOR GAUGE UNIT (S/N: DN45R90701 -85) 5,162.3 2,975.8 81.44 Centralizer MOTOR CENTRALIZER (8' OD) Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! GAUGE, 5,078 Top (ftKB) (968) (°) Description Comment Run Date ID (in) 34 34.2 0.70 ESP Cable 8/10/2012 0.000 Perforations & Slots Shot Top (ND) Btm (TVD) Dens DISCHARGE. Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date leh- Type Comment 5,098 " 5 ,547 7,325 3,031.0 3,074.6 TABASCO, 4/8/2003 50.0 SLOTS GRAVEL PACK SCREEN PUMP, 5,098 � x_218 INTAKE. 5.120 Notes: General & Safety SEAL, 5,121 J End Date Annotation SEAL, 5,126 12/15/2010 NOTE: View Schematic w/ Alaska Schematic9. MOTOR, 5,135 Ill I 1 GAUGE. 5,180 Centralizer, I 5,162 1 .1 Mandrel Details L Top Depth Top Port (ND) Intl OD Volvo Latch Size T (p Run S tn Top (ftKB) (ftKB) ( °) Make Model (in) son, Typ Type (in) (Psi) Run Date Com... 1 2,797.5 2,019.2 66.74 CAMCO KBMG 1 ESP DMY BK 0.000 0.0 8/19/2012 SURFACE. 2 3,033.5 2,113.1 65.55 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 8/10/2012 37 - 5,480 3 4,7631 2,890.8 73.31 CAMCO KBMG 1 ESP DMY BK - 5 0.000 0.0 8/10/2012 SLOTS, �% 5,547 -7,325 1∎( ___ - - GRAVEL PACK LINER, 5,284 -7,350 N TO, 7,360 • • • ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 2T - 218 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/31/2012 4:00:00 PM Rig Release: 8/11 /2012 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/31/2012 24 hr Summary MIRU Nordic Rig 3. Pull BPV.. Kill Well _ 15:00 16:00 1.00 0 0 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -207 to 2T -218. Nordic Rig 3 Accepted at 16:00 on 07/31/2012. 16:00 17:30 1.50 0 0 MIRU MOVE RURD P Spot Cuttings Box, Hook up Hardline, Spot Auxiliary Equipment and Load pits w/ Filtered 8.5 ppg 3 % KCL Brine. Load lubricator. 17:30 18:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM and Pre Spud meeting with FMC, Nordic and CPAI. 18:00 19:00 1.00 0 0 COMPZ WELCTL MPSP P Lubricate out CIW 4" Type "H" BPV. 19:00 00:00 5.00 0 0 COMPZ WELCTL KLWL P PJSM, PT lines, Open Well, 270 psi on Tbg (diesel) 170 psi on Csg (gas) Notify DSO and security of bleeding gas. Bleed gas cap off IA. Pump down Annulus with 8.5 ppg 130 degf 3% KCL Brine. 3 bpm at 240 psi, 4 bpm at 300 psi. 170 bbls returned to kill tank. Swap over to pump the long way down Tbg at 3 bpm, 400 psi ICP. Pump total 290 bbls off truck at 130 degf. 150 psi FCP. 08/01/2012 Condioning Well L Dummy off Open GLM at 4276', Prepare to Circulate IA to Diesel 00:00 01:30 1.50 0 0 COMPZ WELCTL KLWL P Continue pumping down Tbg at 3 bpm with 8.5 ppg 3% KCL Brine, Returns up IA- 150 psi FCP. Pump addional 100 bbls from Pits at 3 bpm at 150 psi. Returns 325 bbls. Pump additional 75 bbls from pits at 5 bpm at 300 psi. 345 bbls total returns total. 01:30 03:30 2.00 0 0 COMPZ WELCTL OTHR P Shut down Pumps and Vac out Returns from Kill Tank (715 bbls pumped and 345 bbls returned), Move DP in Derrick 03:30 06:00 2.50 0 0 COMPZ WELCTL KLWL P Continue Pumping Down Tbg at 3 bpm at 140 psi. Pump 200 bbls away, Shut Down Pumps and check Kill Tank Strap- 40 bbls Returns. Bullhead 80 bbls down TBG at 8 bpm at 560 psi, continue to circulate 92 bbls at 3 bpm at 140 psi w/ 8 bbl return. Page 1 of 9 • • Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 06:00 08:30 2.50 0 0 COMPZ WELCTL OWFF P Monitor well for 30 minutes, 40 psi TBG pressure / 90 psi IA pressure. Callout slick line to set DV in stage 1 @ 4,258 -ft and DHD to shoot fluid level - found fluid level at surface, confirm with 2nd shot. 08:30 12:00 3.50 0 0 COMPZ RPCOM SLKL P Held PJSM w/ HES slick line crew, ASRC pumping crew, and rig crew. RU slick line and ASRC kill truck for pumping diesel and PT kill lines at 3,500 psi. - good test. 12:00 00:00 12.00 0 0 COMPZ RPCOM SLKL P MU slick line tools and PT lubricator at 500 psi. RIH and attempt to set 1.5" DV in lower mandrel at 4,258 -ft - unsuccessful. POOH. Make 3.78" guage ring run to 4270 -ft POOH. Make 2.5" bailer run to 4400 -ft. Stop due to deviation- POOH. RIH w/ 1.5" DV and attempt to latchup at 4,258 -ft - unsuccessful. Second attempt successful. DV set in GLM #1 at 4267'. RIH with CMU Shifting Tool with Pump assist. 4 bpm at 850 psi, total pumped 122 bbls SW. Unable to engage and shift CMU. Prepare to RD SL. 08/02/2012 RD Slick line and Reverse 40 bbls diesel SI TBG and bull head 350 bbls of diesel. SWI and monitor well. discuss weighting up to 9.0 ppg w/ Town engr - recieve go ahead, Load pits w/ 9.0 ppg and circulate w/ 986 bbls w/ 45% returns recovering 9.0 ppg at surface. 00:00 01':30 1.50 0 0 COMPZ RPCOM SLKL P PJSM. Rig Down SlickLine 01:30 04:00 2.50 0 0 COMPZ WELCTI CIRC P PJSM with ASRC Pump Crew. PT Lines to 3500 psi. OK. Rev Circulate down la at 3 bpm at 2600 psi ICP. After 40 bbls Away, Clean SW Retuns from Tbg. Shut in Tbg and Bullhead additonal 310 bbls down IA at 425 psi FCP. 04:00 05:00 1.00 0 0 COMPZ WELCTL OWFF P Monitor Well. IA 330 psi, Tbg 50 psi. Rig Down ASRC Pumpers. 05:00 07:00 2.00 0 0 COMPZ WELCTL CIRC P Circulate down Tbg with 8.5 ppg SW at 2 bpm - 240 psi, 3 bpm - 460 psi, 4 bpm - 800 psi. FCP 830 psi. Pumped 360 bbls down Tbg with 379 bbl returns up IA to Kill Tank. 07:00 15:00 8.00 0 0 COMPZ WELCTL OWFF P Monitor Well. 40 psi on Tbg and 90 psi on IA. Offload Kill Tank. Bleed 21 bbls to Kill Tank simulateously from Tbg and IA. Shut in and Monitor- 40 psi Tbg and 40 psi on IA. Load pits with 9.0 ppg KWF. 15:00 15:30 0.50 0 0 COMPZ WELCTL OTHR P Check block valves for obstructions or small ID's due to high back pressure on kill line. PT line at 250 / 3,500 psi. Page 2 of 9 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 19:30 4.00 0 0 COMPZ WELCTL CIRC P Circulate 350 bbls of Filtered 8.9 ppg Brine at 3 bpm at 460 psi and recovered 192 bbls in kill tank - 54% returns. Empty kill tank and top of pits w/ Filtered 8.9 ppg Brine. 19:30 00:00 4.50 0 0 COMPZ WELCTL CIRC P Pump 32 bbl 3 ppb hi visc sweep and chase with 636 bbls of Filtered 8.9 ppg Brine at 3 bpm at 500 psi and recovered 250 bbls in kill tank - 39% returns - recovering 9.0 ppg brine as of midnight. 08/03/2012 C_ontinue_to circ. 8.9 pppg in attempt to recover sweep. Monitor well for flow SetBPV. ND Tree / NU BOPS - test ROPE. Upland hancer and POOH laying down 4 1/2" TC -ESP de- completion to 4,200 -ft. 00:00 01:00 1.00 0 0 COMPZ WELCTL CIRC P Continue to circulate w/ 184 bbls of 8.9+ ppg brine at 3 bpm at 520 psi and recovered 55 additional bbls at 30% return rate. - shut down pumping operations due increase in losses - 3 ppb sweep was never recovered, even though 9.0 ppg brine was being recovered. 01:00 02:00 1.00 0 0 COMPZ WELCTL OWFF P Monitor well for flow - well on vac - RD circ hoses. 02:00 02:30 0.50 0 0 COMPZ WHDBO MPSP P Dry rod in w/ 4" CIW Type "H" BPV 02:30 04:30 2.00 0 0 COMPZ WHDBO NUND P ND FMC Tabasco Horizontal Production tree, clean and inspect threads in hanger. Install Blanking plug w/ 10 RH rotations. 04:30 04:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM w/ crew on NU of Class III 11" 5M BOPE. 04:45 08:15 3.50 0 0 COMPZ WHDBO NUND P NU Class III 11" 5M BOPE and install Dutch flow riser. Connect Kill and Choke lines. Shot Fluid level in IA at 72' 08:15 16:45 8.50 0 0 COMPZ WHDBO BOPE P PJSM. Obtain Shell Test On Stack, 250/3500 psi. Start BOP Test 250/3500 psi w/ 3 1/2" & 4 1%2" Test Joint. Perform Annular test and Draw down test. 24 hr notice was given at 06:00 hrs on 7 -31 -12 and Test was witnessed by Chuck Scheve. System pressure = 3,100 psi After closure = 1,950 psi 200 psi build = 15 seconds Full system pressure = 90 seconds 4 bottles N2 = 1,950 psi Ave psi 16:45 18:00 1.25 0 0 COMPZ WHDBO BOPE P RD Test Joint and Test Hoses. Pull . Blanking Plug and BPV. 18:00 18:30 0.50 0 0 COMPZ RPCOM OTHR P ,Blanking BOLDS 18:30 19:00 0.50 5,144 5,139 COMPZ RPCOM PULL P Un -land TBG hanger at 89k up wt 19:00 19:30 0.50 5,139 5,139 COMPZ RPCOM OWFF P Monitor well on trip tank - loosing 77 bph Page 3 of 9 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:30 2.00 5,139 5,100 COMPZ RPCOM PULL P POOH to hanger, disconnect from penetrator, remove penetrators from FMC TBG Hanger and break out and lay down hanger. 21:30 00:00 2.50 5,100 4,200 COMPZ RPCOM PULL P POOH from f/ 5,100 -ft to 5,000 -ft. String ESP cable I -wire over sheaves. Continue to POOH laying down 4 1/2, 12.6#, L -80, NSCT TBG and jewelry from 5,100 -ft to 4,200 -ft triple displacing with 8.9 ppg Filtered brine. 38/04/2012 Continue to POOH laying 4 1/2 de- completion to ES P equipment. De- complete ESP equipment and load in boxes for shipping. Clean and clear floor and pipe shed of de- completion. Load Baker C/O BHA in pipe shed. Hold man down drill with both crews and service contractors. PU and RIH w/ RCJB C/O BHA on 3 1/2 DP to 3802 -ft. 00:00 06:30 6.50 4,200 226 COMPZ RPCOM PULL P Continue to POOH lay down 4 1/2 TC -ESP de- completion from 4,200 -ft to 226'. 79k# and 59k# dwn. 3x displacement. Stop for man down Drill. 06:30 08:00 1.50 226 226 COMPZ RPCOM SFTY P Hold Rig Evac H2S Man Down Drill with both crews and service contractors and Kuparuk Fire and Rescue. 08:00 11:00 3.00 226 0 COMPZ RPCOM PULL P Continue to POOH laying down 4 1/2 TC -ESP de- completion from 226' to ESP components at 75 -ft. Decommission esp components and load in shipping boxes. 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR P PJSM with Contract Crane Operators Brandon & Tom. Swap out ESP Spools. 12:00 15:00 3.00 0 0 COMPZ RPCOM OTHR P PJSM. Offload ESP Equipment, count clamps, tec wire spool, spooler and TBG. Clean and Clear Floor. Changeout Floor Equipment. 15:00 16:00 1.00 0 0 COMPZ WELLPF OTHR P Load Drill Collars to Pipe Shed, Load BHA #1 16:00 20:00 4.00 0 0 COMPZ WELLPF SLPC P PJSM, Slip and Cut 84 -ft. 20:00 20:24 0.40 0 0 COMPZ WELLPF SFTY T Held PJSM w/ rig crew and Baker fishing hand on PU, MU and RIH w/ Fishing BHA - discussed options as there is a Tam Port Collar at 976 -ft at 28° that shifts open in downward motion. Discussed rotating past at 10 rpm's. 20:24 22:00 1.60 0 241 COMPZ WELLPF PULD T PU and MU BHA #1. RCJB, boot basket, jars and string magnet and 6- 4.75" OD DC's to 241 -ft. 22:00 00:00 2.00 241 3,802 COMPZ WELLPF TRIP T RIH w/ BHA #1 from 241 -ft to 3802 -ft 08/05/2012 Cont to RIH to SC -1 Packer and function RCJB, POOH and RIH w/ CSG Scraper assy to 5,130 -ft 00:00 00:30 0.50 3,802 4,510 COMPZ WELLPF TRIP T Continue to RIH w/ BHA #1 from 3,802 -ft to 4,510 -ft Page 4 of 9 • . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 00:30 03:30 3.00 4,510 5,278 COMPZ WELLPF PULD T Begin picking up 3 1/2 DP and RIH from 4,510 -ft to 5,278 -ft (28 -ft in jt #156 while pumping - functiong RCJB) seen torque on top drive. Dry tag is 29 -ft in = 5,280 -ft and SC -1 is supposed to be at 5,283 -ft. 03:30 05:30 2.00 5,278 241 COMPZ WELLPF TRIP T POOH w/ 52 stands of 3 1/2 DP to 241 -ft 05:30 08:30 3.00 241 0 COMPZ WELLPF TRIP T POOH standing back DC's and breaking down BHA #1 - Recovered a 2' piece of flat guard cable protector wedged in the bottom of RCJB. Missing approx 4' of guard and 2 SS Bands. 08:30 10:45 2.25 0 5,250 COMPZ WELLPF TRIP T Run Back in hole with RCJB- BHA #2, boot basket, jars and string magnet and 6- 4.75" OD DC's to 10:45 11:45 1.00 5,250 5,282 COMPZ WELLPF TRIP T Get parameters, pumped ball on seat. RIH down at 10 RPM, pumping 8 bpm. Tag at 5282'. Reverse on top of Packer. Pull up full joint and repeat. Pumped total of 282 bbls and 180 bbls returned. 11:45 15:00 3.25 5,282 241 COMPZ WELLPF TRIP T Blow Down TD, Monitor Well- static, POOH w/ 52 stands of 3 1/2 DP to 241 -ft 15:00 16:00 1.00 241 0 COMPZ WELLPF TRIP T POOH standing back DC's and breaking down BHA #2 - Nothing recovered 16:00 17:00 1.00 0 0 COMPZ WELLPF OTHR P Off load tools and reload scraper tools. 17:00 17:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM w/ rig and Baker Fishing rep on PU and MU of CSG Scraper bha. 17:15 18:45 1.50 0 246 COMPZ WELLPF PULD P PU and RIH w/ BHA #3 to 246 -ft. 18:45 20:00 1.25 246 1,012 COMPZ WELLPF TRIP P RIH to 1,012 -ft w/ bull nose and CSG scraper set down at 972 -ft (TAM Port Collar) 20:00 21:30 1.50 1,012 0 COMPZ WELLPF TRIP T POOH and remove CSG scraper from BHA 21:30 00:00 2.50 0 5,130 COMPZ WELLPF TRIP P RIH w/ BHA #4 to 5130 -ft. 86k up wt, 75k do wt. 08/06/2012 Continue to RIH to 5,289-ft Wash SC-1 packer, POOH. PU and RIH w/ IBP to 5,250 -ft ±, set and Release off. 00:00 01:00 1.00 5,130 5,290 COMPZ WELLPF TRIP P Continue to RIH f/ 5,130 -ft to 5,268 -ft. Begin waashing down to SC -1 packer at 5 bpm at 700 psi and No -Go at 5,282 -ft w/ jetted bull nose at 5,290 -ft. Increase pump rate to 8 bpm at 1,720 psi and wash packer. 01:00 01:15 0.25 5,290 5,290 COMPZ WELLPF SFTY P Held PJSM with rig crew and Baker Fishing rep on POOH 01:15 04:00 2.75 5,290 234 COMPZ WELLPF TRIP P POOH f/ 5,290 -ft to 234 -ft. 04:00 05:30 1.50 234 0 COMPZ WELLPF PULD P POOH laying down BHA #4 from 234 -ft, cleaning magnets 05:30 07:00 1.50 0 0 COMPZ WELLPF OTHR P Off load BHA #4 from pipe shed and re -load with IBP Page 5 of 9 • • • Time Logs 9 Date From To Dur S. Depth E. Depth Phase Code Subcode -T Comment 07:00 12:00 5.00 0 5,275 COMPZ WELLPF TRIP P MU BHA #5. RIH to 5275 -ft (81.4° hole angle) Up 80k# and Down 70k #. 12:00 16:30 4.50 5,275 5,275 COMPZ WELLPF OTHR P Drop 1/2" Ball, Pump down to seat, 1 bpm at 50 psi. Pump 5 bbl viscosified sweep and chase with 45 bbls and ball won't seat. 16:30 20:00 3.50 5,275 1,772 COMPZ WELLPF TRIP T PJSM. POOH with BHA #5 to 1,772 -ft (54° hole angle) and ball fell on seat. 20:00 22:00 2.00 1,772 5,275 COMPZ WELLPF TRIP T RIH f/ 1,772 -ft to 5,275 -ft 22:00 00:00 2.00 5,275 5,275 COMPZ WELLPF PACK P RU test hoses and set IBP at 5,275 -ft at 1,820 psi. 08/07/2012 Release off IBP at 1,820 psi. PT 10.75" csjat 1,500 psi for 30 minutes. POOH. RU E -line and run 40 arm caliper and Gyro. Run 9.625" OD drift - set down at 380 -ft. POOH. PU and RIH w/ Test packer to 5,225 -ft and PT IA @ 1,500 psi - passed. Release Packer. 00:00 01:30 1.50 5,275 5,275 COMPZ WELLPF PRTS P Pressure up to 1,500 psi (visual on guage) - bled of 100 psi over 30 minutes. Bump back up to 1,500 psi - lost 800 psi over 30 minutes. RD test equipment. 01:30 05:30 4.00 5,275 0 COMPZ WELLPFTRIP P TOOH racking back DP, lay down BHA #5 IBP setting tool. 05:30 06:00 0.50 0 0 COMPZ WELLPF OTHR P Pull wear bushing 06:00 07:00 1.00 0 9 COMPZ WELLPF OTHR P Load E -line tools & Dutch Riser. 07:00 07:30 0.50 0 0 COMPZ EVALWE SFTY P PJSM with Halliburton and Nordic 3 crews 07:30 12:00 4.50 0 0 COMPZ EVALWE ELOG P Install Dutch Riser and RU E -line equipment, P/T equipment 500 psi and RIH w/ CCL, GR, Pressure, Temp, Spinner, capacitance and 40 arm Caliper to 5,010 -ft, Log up at 50 fpm to surface, lay down Caliper assembly. Send caliper data off for interpretation. 12:00 17:30 5.50 0 0 COMPZ EVALWE ELOG P PU MU GYRO assembly, P/T equipment 500 psi and RIH w/ CCL, GR and GYRO tool to 5,250 -ft, Log up to surface, lay down GYRO tool assembly. 17:30 18:30 1.00 0 0 COMPZ WELLPF RURD P RD E -line equipment and Dutch Riser, off load E -line equipment. 18:30 20:00 1.50 0 380 COMPZ WELLPFTRIP P RIH w/ 9 5/8 Drift bha and set down at 380 -ft. POOH and lay down drift BHA. 20:00 21:30 1.50 0 1,050 COMPZ WELLPFTRIP P PU and RIH w/ Baker 10 3/4" Retievamatic test packer and rotate thru Tam port collar at 976 -ft - seen 7k slack off wt. Continue to rih to 1,050 -ft. Set packer and test IA at 1,500 psi for 10 minutes - good test. 21:30 23:00 1.50 1,050 5,225 COMPZ WELLPF TRIP P Release Packer and continue to RIH to 5,225 -ft and set. Page 6 of 9 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 5,225 5,225 COMPZ WELLPF PRTS P RU pressure testing equipment - PT IA at 1,500 psi for 30 minutes on chart - Passed. Bleed off pressure and RD test equipment. 08/08/2012 POOH and LD PKR. RU E -line a n d Run CA ST -I log RD E -line. 00:00 02:30 2.50 5,225 0 COMPZ WELLPF TRIP P POOH from 5225 -ft. laving down 10 3/4" Retrievamatic Packer. 02:30 04:30 2.00 0 0 COMPZ WELLPF PULD P Clean and clear floors, off Toad tools. 04:30 06:00 1.50 0 0 COMPZ WELLPF RURD P RU Dutch Riser with extra 3 -ft of 9 -5/8" lubricator pup. 06:00 09:30 3.50 0 0 COMPZ WELLPF OTHR T Monitor well, while Waiting for HES E -Line crew to arrive due to Halliburton crew held up at BP guard shack. 09:30 11:15 1.75 0 0 COMPZ WELLPF RURD P Halliburton E -line crew onsite, rig orientation with crew. Spot equipment and ready / load tools to rig floor. 11:15 11:30 0.25 0 0 COMPZ WELLPF SFTY P PJSM w/ Halliburton E -line and Nordic 3 crews, discussed hazards of E -line rip up and job procedures. 11:30 13:30 2.00 0 0 COMPZ WELLPF RURD P RU E -line equipment, MU E -line tools. 13:30 20:00 6.50 0 4,952 COMPZ EVALWE ELOG P RIH w/ CAST -F tool assembly to 4,952 -ft, log up at 20 fpm to surface. 20:00 22:00 2.00 0 0 COMPZ WELLPF RURD P RD E -line and and dutch riser. 22:00 00:00 2.00 0 0 COMPZ WELLPF OTHR P Clean and organize rig while waiting for tools to arrive from Dead horse. load in pipe shed upon arrival. 08/09/2012 PU and MU BHA #8 RIH and Retrieve IBP. POOH, laying down 3 1/2 DP. Change over equipment. RIH w/ Completion by design to packer. Conduct esp cable splice. 00:00 01:00 1.00 0 2,237 COMPZ WELLPFTRIP P PU, MU and RIH w/ IBP retrieving BHA to 2,237 -ft 01:00 03:30 2.50 2,237 5,275 COMPZ WELLPFTRIP P PU 9.5" OD string mill and install in string. Continue to RIH to 5,264 -ft and Engage IBP, slack off 4k to equalize, PU and release IBP. 03:30 04:00 0.50 5,275 5,275 COMPZ WELLPF OWFF P Monitor well for flow - well taking fluid 04:00 10:30 6.50 5,275 0 COMPZ WELLPF PULL P POOH, laying down 3 1/2 DP from 5,275 -ft, lay down IBP and retrieving tool, wrap for transport. 10:30 13:00 2.50 0 0 COMPZ WELLPF OTHR P Clean and clear floors / pipe shed. Off Toad tools. Load Baker ESP pump, motor, seals and clamps. Prep to run completion. 13:00 13:30 0.50 0 0 COMPZ WELLPF SFTY P PJSM w/ Centrilift, Weatherford and Nordic 3 crews, discussed hazards associated with running completion, running order and job procedures. 13:30 16:30 3.00 0 0 COMPZ RPCOM PULD P PU MU and service Motor Gauge Unit / Motor / Tandam Seals / Intake and Pump. Pick up and connect I -wire and MLE. Page 7 of 9 • Time Logs • Date From To Dur - S. Depth E. Depth Phase Code Subcode T Comment 16:30 22:00 5.50 0 2,236 COMPZ RPCOM RCST P RIH 2 23671,with 4 -1/2" TC -ESP competion adding clamps were needed to DGU, connect I -wire to DGU and check cable electrical integrity. Continue RIH with completion adding clamps to every collar and checking cable electrical integrity every 1,000 -ft to Packer. 22:00 00:00 2.00 2,236 2,236 COMPZ RPCOM OTHR P Conduct Packer feed thru splice 08/10/2012 Con't to RIH to desired depth_ PU hanger, make fianl splice. Land hanger, spot CI b rine on IA. Pressure set pucker, Integrity test TBG and IA. bleed off pressure. ND BOP niti Tree. 00:00 00:30 0.50 2,236 2,236 COMPZ RPCOM OTHR — P Finish packer splice. 00:30 05:00 4.50 2,236 34 COMPZ RPCOM RCST P Continue to PU and RIH w/ 4 1/2 ESP completion from 2,236 -ft, Up wt 85k, Dn wt 70k to 34 -ft. 05:00 05:30 0.50 34 34 COMPZ RPCOM THGR P MU tubing hanger and landing joint with side port isolation sleeve, install penetrators. 05:30 07:30 2.00 34 34 COMPZ RPCOM OTHR P Make final splice thru FMC tbg hanger, MEG cable, good. 07:30 08:45 1.25 34 0 COMPZ RPCOM THGR P RIH and land completion, Up wt 88k, Dn wt 70k. RILDS. Cannon Clamps ran on Completion: 2 ea. Protectolizers 2 ea. 5150- AF -12P Cannon Clamps 1 ea. 3150- 35 -AO -5 Cannon Clamp 1 ea. 4500 -AO -5P Cannon Clamp 164 ea. 4500 -AO -5 Cannon Clamps 08:45 10:00 1.25 0 0 COMPZ RPCOM PRTS P Pressure test tubing hanger pack -offs 250/5000 psi. 10:00 11:00 1.00 0 0 COMPZ RPCOM RURD P RU circulating hoses and testing equipment and pressure test to 4000 psi. 11:00 11:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with Weatherford and Nordic crews, discussed hazards circulateing and of high pressure testing. 11:15 13:00 1.75 0 0 COMPZ RPCOM CIRC P Reverse circulate 290 bbls of Corrosion Inhibited KWF 3 bpm ICP 60 psi, FCP 60 psi with no returns. 13:00 13:30 0.50 0 0 COMPZ RPCOM RURD P RU test hoses and drop roller stem Ball & Rod (1.375" external fishneck) and wait 30 minutes for ball and rod to seat. 13:30 15:00 1.50 0 0 COMPZ RPCOM PACK P Line up pumps and start Weatherford 10 -3/4" x 4 -1/2" Hydrow -II Feedthru Packer setting sequence to 3750 psi on chart 10 minutes as per WFT Rep. bleed tubing to 2000 psi. Page 8 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:15 1.25 0 0 COMPZ RPCOM PRTS P Line up pumps and pressure test IA to 2500 psi on chart 30 minutes, good. Bleed tubing down to 200 psi to shear SOV, Tubing and IA equilize out at 1800 psi. 16:15 19:30 3.25 0 0 COMPZ RPCOM OTHR P Begin Centrilift De- compression Schedule from 1800 psi. 19:30 20:00 0.50 0 0 COMPZ RPCOM OWFF P Observe well for flow - no flow 20:00 20:30 0.50 0 0 COMPZ RPCOM MPSP P Set Two Way Check 20:30 22:00 1.50 0 0 COMPZ RPCOM NUND P ND BOPE 22:00 00:00 2.00 0 0 COMPZ RPCOM NUND P NU tree - add new 4 1/16" 5M master valve to tree design due to having to have riser in order to remove BPV to get clearance to close master valve. 08/11/2012 Finish NU Tree, PT tree at 250 / 5,000 psi. RU LRS and freeze •rotect well Lubricate BPV. Secure well / Back rig off well and clean cellar. Release Nordic rig _ 00:00 00:30 0.50 0 0 COMPZ WHDBO NUND P Finish Nippling up tree. 00:30 02:00 1.50 0 0 COMPZ WHDBO PRTS P Pressure test tree to 250 / 5,000 psi - had to bleed off and tighten flanges twice. Resulted in passing test. 02:00 02:30 0.50 0 0 COMPZ WHDBO MPSP P Pull Two way check 02:30 02:45 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with LRS and rig crew on pt lines, pumping freeze protect and taking returns to kill tank. 02:45 05:00 2.25 0 0 COMPZ RPCOM FRZP P RU LRS. PT lines at 2,500 psi, Freeze protect well through SOV at 2,797 -ft with 50 bbls neat diesel followed by 200 bbls of Gelled Diesel and cleared lines with 10 bbls of neat diesel. SWI w/ 450 psi. RD LRS 05:00 05:45 0.75 0 0 COMPZ WHDBO MPSP P Lubricate in BPV 05:45 06:30 0.75 0 0 COMPZ RPCOM OTHR P Secure well, Blow down circ manifold, and RD circ hoses. 06:30 09:00 2.50 0 0 COMPZ RPCOM RURD P RD auxilary equipment and prep to move rig off well. Pull rig off well, clean cellar with super sucker. Release Nordic rig 3 at 09:00 on 08/10/2012 Page 9 of 9 • \ 7z0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 10, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool/Circumferential Acoustic Scanning Tool: 2T -218 Run Date: 08/07/2012 - 08/08/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -218 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50 -103- 20449 -00 CASE Log (Processed Print) 1 Color Log 50- 103 - 20449 -00 SCANNED MAR 2 8 ZU 3 CAST -F (Field Print) 1 Color Log 50- 103 - 20449 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: O "/ Signed: ) v��l -, • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~~~ August 1, 2010 ~ : , , _ as ~ ~ i ~~ d~ Commissioner Dan Seamount ~~~~~[~ Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~ ~ Z~~~~~i Anchorage, AK 99501 Alaska ~~ ~ Gstl Ce~"-s. C~lmission Commissioner Dan Seamount: 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 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 cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30~', 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland 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 8/01/10 ~n ~~r ~-r own l ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date . _, Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7!21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • ~sd« ~ ...ti-- R{.. N _~ _ MICROFfLMED 03/01 /2008 DO NOT PLACE ANY .NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc . . WELL LOG TRANSMITTAL ~~~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13,2006 RE: MWD Formation Evaluation Logs: S-106_PB1, S-112, S-205, C-01A, 2T-218, P2-57A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 S-106_PB1: :do I-Old.. tt /¿/39-S Digital Log Images: 50-029-22999-00, 70 1 CD Rom S-112: U::t:c.,. QO;;) -13S- /:Þ J~/~/ Digital Log Images: 50-029-23099-00 5 .9ISí' 41o¿(edwr()V\.~- S 2G5! Ù.::I::.C.-Ó)Od- 1551 It /t../3'9-d Digital Log Images: 50-029-23107-00 C-01A: <963 -bl 0 :{4 ¡LInt:> SCAHMED JAN S 0 2007 Digital Log Images: 50-029-20121-01 1 CD Rom 1 CD Rom 1 CD Rom 2T-218: Qo3 -Ol-::f IZ-}LI3--:J.\ Digital Log Images: 50-029-20449-00 1 CD Rom P2-57A: dOd -dlL.( '# lL./3(ð1 Digital Log Images: 50-029-22183-01 1 CD Rom e e WELL LOG TRANSMITTAL I 354-4-- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 10,2004 RE: MWD Formation Evaluation Logs 2T-218, AK-MM-2323381 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 995] 8 2T-218: Digital Log Images: 50-103-20449-00 ~O~~-{)/'l 1 CD Rom ~ ./7 ðÞ:¡./d" (~ fVt') À U ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030170 Well Name/No. KUPARUK RIV U TABS 2T-218 Operator CONOCOPHILLlPS ALASKA INC MD 7360'-' TVD 3075·/ Completion Date 4/10/2003- Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Fnnt Number Name .5f7utcL 2} ~~ J> API No. 50-103-20449-00-00 UIC N ..-,....'"") --".',.- J Directional Survey çYes_,...~,_ (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH ED D LrRPt '-Rpt ~Pt v-- Rpt ~ D 11712 J,.IS Vorifiea1.ivlI' \o~ l w~~( ~ùV' 61 7317 Open Directional Survey 353 7360 Open Directional Survey 353 7360 Open LIS Verification 61 7317 Open Directional Survey 0 353 Open t.ðîrectional Survey 353 7360 Open ~ D ...sr- D bírectional Survey ~ctional Survey Well Cores/Samples Infonnation: Name Interval Start Stop ..~ Received Comments A Directional Survey Log is I required to be submitted. ! This record automatically created from Permit to Drill Module on: 2/6/2003. 5/13/2003 4/29/2003 4/29/2003 5/13/2003 4/29/2003 4/29/2003 MWD GYRO MWD A Mud Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/6/2003. -- 353 7360 Open 4/29/2003 0 353 Open 4/29/2003 GYRO Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030170 Well Name/No. KUPARUK RIV U TABS 2T-218 Operator CONOCOPHILLlPS ALASKA INC MD 7360 TVD 3075 Completion Date 4/10/2003 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION ~. Well Cored? VU!J Daily History Received? (J)/ N l~/N Formation Tops LY Chips Received? i( / N .. Analysis Received? -~- Comments: Compliance Reviewed By: 'L Date: API No. 50-103-20449-00-00 UIC N '- I G fv~ .~ j;-- --,' ) ) Jim Ennis Wells Group Engineer Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 May 26, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2T-218 (APD #203-017/304-155) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations to replace the submersible pump on the Kuparuk well 2T-218. If you have any questions regarding this matter, please contact me at 265-1544. Sincerely, ~ \\ k--- -~ J. Ennis Wells G rJup Engineer CPAI Drilling and Wells JJE/skad RECEIVED MAY 2 7 2004 Alaska Oil & Gas Cons. Commission Anchorage ORiGiNAL ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 36' 8. Property Designation: ADL 25569 I ALK 2667 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE SURFACE GRAVEL PACK E CSG WINDOW Length 106' 4461' 982' 1803' Perforation depth: Repair Well [2] Pull Tubing D Operat. ShutdownD 7360' 3076' Size 16" 10-3/4" 10-3/4" 5-1/2" Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development _ [2] Stratigraphic D Stimulate D Waiver D Time Extension Other D D D Re-enter Suspended Well 5. Permit to Drill Number: 203-017/304-155 6. API Number: 50-1 03-20449-00 Exploratory Service D D 9. Well Name and Number: 2T-218 10. Field/Pool(s): Kuparuk River Field I Tabasco Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 106' 4498' 5480' 7350' 106' 2801' 3023' 3075' Measured depth: gravel pack screen 5547'-7350' true vertical depth: 3032'-3075' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5071' MD. RECEIVED MAY 2 7 2004 Packers & SSSV (type & measured depth) model SC-1 R pkr pkr @ 5284' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) (t~t n/a Treatment descriptions including volumes used and final pressure: n/a 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation SI Subsequent to operation 1013 91 498 291 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [2] Service D Abandoned D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil [2] GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature \ Form 10-404 Rev\ed 04/2004 Wells Group Engineer Date 5ha::L::L34612 Title Phone n01h1t\LA1.. RBDMS BfL ) ) : .... :. :",,: .. ....: :",.:..' '.' ...: . .:. . ...¡.mmIlR~~~Þii!)iR~~{~$k~.. . ,0... :.:.:.P. ' ,@~ªt:i:g~~¡:s:llIrnm¡lry .:~epørt.... . ...... .... ... ..... . ...... ........ ..... ... .... .. .. ... . ... ........ ·""0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-218 2T-218 WORKOVER/RECOMP Þrom -TôHÒùrSÒÒdeSUb: ph~š~ .::q§¢J~ .. 4/28/2004 06:00 - 08:30 2.50 MOVE DMOB MOVE 08:30 - 21 :30 13.00 MOVE MOVE MOVE 21 :30 - 00:00 2.50 MOVE RGRP MOVE 4/29/2004 00:00 - 00:00 24.00 MOVE RGRP MOVE 4/30/2004 00:00 - 03:00 3.00 MOVE MOVE MOVE 03:00 - 09:00 6.00 MOVE RURD MOVE 09:00 - 09:30 0.50 WELCTL NUND DECOMP 09:30 - 10:00 0.50 CMPL TN RURD DECOMP 10:00 - 12:00 2.00 CMPL TN CIRC DECOMP 12:00 - 19:00 7.00 CMPLTN CIRC DECOMP 19:00 - 22:30 3.50 CMPL TN OTHR DECOMP 22:30 - 23:00 0.50 CMPL TN NUND DECOMP 23:00 - 00:00 1.00 CMPL TN NUND DECOMP 5/1/2004 00:00 - 00:30 0.50 WELCTL NUND DECOMP 00:30 - 06:30 6.00 WELCTL NUND DECOMP 06:30 - 09:30 3.00 WELCTL BOPE DECOMP 09:30 - 10:00 0.50 CMPLTN RURD DECOMP 10:00 - 12:00 2.00 WELCTL NUND DECOMP 12:00 - 14:30 2.50 CMPL TN PULD DECaMP 14:30 - 15:00 0.50 CMPL TN RURD DECOMP 15:00 - 18:30 3.50 CMPLTN PULL DECaMP 18:30 - 18:45 0.25 CMPL TN SFTY DECOMP 18:45 - 21 :45 3.00 CMPL TN PULD DECOMP Start: 4/28/2004 Rig Release: Rig Number: Spud Date: End: Group: Rig released from 2P-406 @ 0600 hours 4/28/2004. Moved camp to 2T pad. RID cuttings boxes and secure tarps. Prep rig for move Moved rig from 2P pad. Blew #7 tire in front of rig module after turning north at the 4-corners. Spare tire coming from Dead Horse, Ak. Prep steering cylinder and tire for removal. REmove tarps and tarp hangers from front O.D.S. tire area. Install pad eyes and remove steering tie bar and steering cylinder. Use roll-a-gone to move spare tire to front of rig and unload. Remove hose clamps and manifolds. Turn tire set 7 & 8 around for access to tire #7. Remove tire. Remove tire from rim and change tire. Mount tire on hub and torque lug nuts. Spin tires and lineup and install steering cylinder and tie bar. Mount hydraulic manifold blocks and secure hoses. Air up tire #8 and secure all tools Move rig from 4-corners to 2T pad. Well 2T-218. Spot rig over well. Accept rig @ 03:00 hours 4/29/2004. Spot M-I filter van and Little Red hot oiler. Spot rig equipment and cuttings boxes. Unload equipment R/U lubricator and pull BPV. RID lubricator. R/U hot oiler to pump down annulus. Pump down annulus wI 60 bbl 160 deg. diesel followed hot-filtered seawater. Bring in ESP cable spooler and I-wire spooler wI crane. Pump total of 600 bbl 160 deg seawater down annulus and 120 bbl 160 deg seawater down tubing. Rig up spoolers and load ESP into pipe shed. Prep handling tools for pulling 4-1/2" tubing. RID Little Red and shoot fluid levels. Pressure and fluid level in annulus 450 psi and 825' respectively. Pressure and fluid level in tubing 0 psi and 26' respectively Spot bleed tank and bleed off gas pressure in annulus to 0 psi. Had no liquids in returns. Reshoot fluid levels. Fluid level in annulus @ 336' and in tubing @ 550'. Set Cameron type HP Back pressure valve N/D FMC Xmas tree N/D FMC tree and set Cameron type HP BPV N/U 11" 5k x 11" 5k spool and N/U BOPE and riser. Change air boot in riser M/U test joint Test BOPE to 250/3500 psi. UD test equipment. John Spaulding wI AOGCC waived witnessing BOPE test M/U FMC retrieving tool on landing jt. Attempt to pull Cameron BPV wlo success. Drain stack. Attempt to pull BPV wlo success. RIH wI landing jt and circulate to clean off hanger. Drain stack and pull BPV. Screw into tubing hanger and back out LDS's. Pull hanger free wI 80k (60k string wt.) Pull hanger to floor and megger ESP cable. UD hanger Thread ESP cable and i-wire over sheaves and onto spoolers POOH and stand back 4-1/2" tubing. SLM Safety meeting on handling ESP and disconnecting cables Detach cables from y-block and inspect. One small dent in by-pass side of y-block approximately 1/32" to 1/16" deep by 1/2" long. Y-block appears bent. Skid mark on by pass side tubing swivel from riding on low side of casing. Motor lead clamp on seal section torn loose. More scraping on motor sections. Appears that connection of motor lead to top motor is burnt causing electrical failure. Pumps, seal sections and Printed: 5/26/2004 2:25:13 PM ) ) . . ,".. '" ..". .' ... .... .... . . . .. QphqcqÞhillllp$ÄI#skél.· . .. .... . .. ..... . . . ... . .'. ..... . .... . "." ..... . . ... . . ... . ". . . . ..... .. ........ .. .............. ...... ...... . .... . ....... .......... ......... . .·······.···QpØt~tiq...~i;~¡~m.r1í~r'a~þ()rt .'. . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5/1/2004 5/2/2004 5/3/2004 2T-218 2T-218 WORKOVER/RECOMP Spud Date: End: Group: Start: 4/28/2004 Rig Release: Rig Number: FrQmFTb . Houts ···CÓdè . ê~g~' Phãš~ .. .. ..." ,"". . . . "' .. ..",.. . .. .. .. ... 0""·..·.·.. ...... ·Déscr!p~iqnQfqþer~tiÒris 18:45 - 21 :45 3.00 CMPL TN PULD DECOMP bottom motor check out okay. 21 :45 - 00:00 2.25 CMPL TN PULD DECOMP Remove i-wire and clamps. Disassemble bypass tubing and laydown. 00:00 - 02:00 2.00 WELLSR PULD DECOMP UD ESP assembly 02:00 - 03:00 1.00 WELLSR RURD DECOMP Change out ESP cable spool on rig floor 03:00 - 05:00 2.00 WELLSR PULD DECOMP Finish laying down ESP assembly. Y-block assembly damaged. 05:00 - 10:30 5.50 WELLSR PULD DECOMP P/U new ESP assembly and service. M/U sliding sleeve assembly. Install Baker i-wire (23' above pump discharge) 10:30 - 18:00 7.50 WELLSR PULD DECOMP RIH wI completion assembly on tubing from derrick. Drift tubing. Check ESP electrical hookup every 10 stands. 18:00 - 18:30 0.50 WELLSR OTHR DECOMP M/U tubing hanger and space out. P/U = 80k, S/O=50k 18:30 - 22:00 3.50 WELLSR OTHR DECOMP Make terminations wI ESP cable and i-wire 22:00 - 23:00 1.00 WELLSR NUND DECOMP Land hanger. RILDS. UD landing jt. 23:00 - 23: 15 0.25 WELLSR NUND DECOMP SetBPV 23:15 - 00:00 0.75 WELLSR NUND DECOMP N/D riser 00:00 - 02:00 2.00 WELLSR NUND WRKOVR N/D riser and BOPE 02:00 - 03:30 1.50 WELLSR NUND WRKOVR N/U tree 03:30 - 04:00 0.50 WELLSR OTHR WRKOVR Test compression ring sea and tree to 250/5000 psi. 04:00 - 05:30 1.50 WELLSR FRZP WRKOVR R/U hot oiler and pressure test lines to 2500 psi. Pump 90 bbl diesel down annulus and 15 bbl diesel down tubing @ 2.5 bpm 05:30 - 05:45 0.25 WELLSR OTHR WRKOVR Set BPV 05:45 - 07:30 1.75 WELLSR DEQT WRKOVR Megger ESP cable and secure well. Release rig @ 07:30 hrs 5-3-2004. Printed: 5/26/2004 2:25: 13 PM ) ) KRU ,:~Q*,'Ø'P'hi'I:liil'''A'.é'~.~ .1:~þÌ! 2T;'21e TUBING (70-5071, OD:4.500, ID:3.958) SURFACE (37-4498, OD:10.750, Wt:45.50) Gas Lift !ndrellDummy Valve 2 (4258-4259. OD:7.031) SURFACE (4498-5480, OD:10.750, Wt:55.50) PUP (5029-5072, OD:4.500) PUMP (5072-5097, OD:4.725) SEAL (5097-5111, OD:4.500) MOTOR (5111-5144, OD:4.000) PACKER (5284-5285, OD:9.420) PUP (5285-7348, OD:6.010) SLEEVE (5293-5294, OD:8.120) Perf (5547-7350) .r- , 1111 -lrl,11 I . . - ... 1.. III f i . -i ·~W iii ....~~!. r ./~: _I. ..jj I - orj'·' .' f I.\t¡"'l r~ 1~¡ I API: 501032044900 SSSV Type: NONE Angle @ TS: deg @ Angle @ TD: 89 deg @ 7360 Well Type: PROD Orig 4/10/2003 Completion: Last W/O: 5/3/2004 Ref Log Date: TD: 7360 ftKB Max Hole Angle: 93 deg @ 6448 Rev Reason: WORKOVER Last Update: 5/9/2004 Annular Fluid: Reference LOQ: 36' RKB Last Tag: Last Tag Date: Casing String - AL,. STRINGS DescrIptIon CONDUCTOR SURFACE SURFACE GRAVEL PACK SCREENS TubIng String. TUBING Size Top 4.500 32 4.500 70 Perforations Summary Interval I TVD 5547 - 7350 3032 - 3075 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V aD Latch Port Mfr 2750 2000 CAMCO MMG-2 2 4258 2701 CAMCO MMG-2 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 34 34 HANGER 5028 2953 SLEEVE BAKER CMU SLIDING SLEEVE set 5/3/2004 5029 2953 PUP 5072 2960 PUMP CENTRILlFT GPMTAR 1:1 PUMP ASSEMBLY set 5/3/2004 5097 2965 SEAL CENTRILlFT SEAL SECTION 5111 2967 MOTOR CENTRILlFT KMH/418 MOTOR 5144 2972 Centralizer CENTRILlFT bthêr:,(pIiJgš;¡:eQÚlp.:;etd~):';HORiz()NTAL:GRÄVetpACK··.:.,. . Depth TVD Type DescrIption 5284 2994 PACKER MODEL SC-1 R PACKER 5285 2994 PUP 5293 2995 SLEEVE SLIDING SLEEVE W/SEAL BORE 5327 3000 KOIV 7326 3075 Flapper SUB 2T-218 Size 16.000 10.750 10.750 5.500 Wt 62.50 45.50 55.50 0.00 Grade Thread H-40 WELDED L-80 BTC 13Cr80 V AM-ACE Top o 37 4498 5547 Bottom 109 4498 5480 7350 TVD 109 2801 3023 3075 Bottom 70 5071 Grade L-80 L-80 Thread IBTM NSCT TVD 70 2960 Wt 12.60 12.60 Zone I Status 1Ft I SPF I Date I Type I Comment 1803 50 4/8/2003 IPERF GRAVEL PACK SCREEN TRO o o Date Run 5/3/2004 5/3/2004 DMY DMY 1.0 1.0 0.000 0.000 BK-5 BK-5 DescrIption TREE: FMC 4-1/16" 5K TREE CAP CONNECTION: 7" OTIS Vlv Cmnt ID 3.500 3.810 3.958 0.000 0.000 0.000 0.000 ID 6.000 4.880 6.000 6.310 2.980 0.000 RE: 2T-218 Subject: RE: 2T-218 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Thu, 29 Apr 2004 13 :23 :45 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Tom: Here is a copy of the email from us to you on 1/22/04: Reported ESP Failure to State Tom, ConocoPhillips has completed diagnostics on the electric submersible pumps (ESP) on Tabasco wells 2T-218 (PTD #203-017) & 2T-220 (PTD #198-253) and has determined that the ESP's have failed and will require a rig workover to repair. These are Tabasco wells and can not flow to surface unassisted. At this time ConocoPhillips is not pursuing gas lift as an alternative lifting method and the wells will remain shut in until further notice. Since Tabasco wells are not flow to surface, they will not be reported on the Weekly SCP report, however will be carried on the Quarterly Troubled Well report. Please let me know if you have any questions. MJ Loveland .--" The well has been shut-in since this notice was sent to you. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 èJDs- O~l -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, April 29, 2004 12:03 PM To: NSK Problem Well Supv Subject: 2T-218 ~/ Jerry, How long has the pump been down on 2T-218?? This wasn't one of the gas lifted wells was it?? Tom 1 of 1 4/29/2004 3 :26 PM 2T-218 ".) ( . \ Subject: 2T-218 ~O~ -0 \ \ From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 29 Apr 2004 16:43 :05 -0800 To: Sharon Allsup-Drake <sallsup@ppco.com>, NSK Problem Well Supv <N 161 7 @conocophillips.com> CC: John Spaulding <john_spaulding@admin.state.ak.us> ') Please be advised that the sundry for the subject well has been verbally approved. Please contact the North Slope Inspector for the BOP test. Tom Maunder, PE AOGCC 1 of 1 5/4/2004 10:57 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ') k'"\l ~"\ [)Þ) '94/9- Alter casing Abandon 0 o o APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 Stimulate Perforate 0 o Variance o o o Annular Disp. 0 Other 0 " '1- .'tI Repair well Suspend 0 o o Time Extension 1. Type of Request: Change approved program Pull Tubing Re-enter Suspended Well 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36' 8. Property Designation: ADL 25569 I ALK 2667 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7360' 30761 Casing Length Size 5. Permit to Drill Number: 203-017 V 6. API Number: 50-1 03-20449-00 9. Well Name and Number: 2T-218 10. Field/Pool(s): Kuparuk River Field I Tabasco Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 CONDUCTOR 106' SURFACE 4461' SURFACE 982' GRAVEL PACK SCREENS 18031 16" MD TVD Burst Collapse 106' 106' 4498' 2801' 5480' 30231 7350' 3075' 10-3/4" 10-3/4" 5-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): gravel pack screen 5547'-7350' 3032'-3075' Packers and SSSV Type: Packers and SSSV MD (ft) Model SC-1 R pkr pkr @ 5284' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 29, 2004 Oil 0 Gas 0 16. ~2:w,ro:~ ~a;~~,~~ WAG D GINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name{\ ~.. Ennis Title: Signature ~ Phone Commission Use Only Tubing Size: 4.5" / 2-7/8" Tubing Grade: Tubing MD (ft): L-80 / 13CR80 5075' / 51781 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Engineer Jim Ennis @ 265-1544 0~ 'ði Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(.>-).i.1- / s-S- Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: 3>5aa Ç'Š\ ""\\~\~0\, ~Ç> ~<,\- RECEIVED ~bnu~,' .' afl.. APQ 3 0 200\ APR 2 9 2004 .' ~ A'aska Oil & Gas Cons. Commission COMMISSIONER ~~~~g~~~~ION A~~~:rag~r If o RIG I N A L SUBMIT IN DUPLllTE ' ) ) KRU CanøcoPhillipsA.I¡u¡ka, Inc. 2T·218 TUBING (32-5075, 00:4.500, 10:3.548) SURFACE (37-4498, 00:10.750, Wt:45.50) 1111,1' "..;'..' .' ~ ,:: ~ ~ . '" r:il:'\ ,. ': :!: -5 SURFACE (4498-5480, 00:10.750, Wt:55.50) GAUGE (5060-5061, 00:5.000) (5075-50~~ It ,I 00:4.500) Connector i ~I~" . (5074-5080, .', 00:9.600) I I I ~ ,'J" '¡ (5;¡;~~~ 1 . ·1'· ,r 00:4.500) PUMP I (5080-5088, 00:5.620) PUMP (5088-5113, 00:5.620) I PACKER (5284-5285, 00:9.420) _1. · '.~. i~ '~i, PUP (5285-7348, 00:6.010) SLEEVE (5293-5294, 00:8.120) Perf (5547-7350) API: 501032044900 SSSV Type: NONE Well Type: PROD Orig 4/10/2003 Completion: Last W/O: Ref Log Date: TD: 7360 ftKB Max Hole Angle: 93 deg @ 6448 Annular Fluid: Reference Log: 36' RKB Last Tag: Last Tag Date: Casing String· ALL STRINGS Description CONDUCTOR SURFACE SURFACE GRAVEL PACK SCREENS Tubing String· ALL STRINGS Size Top 4.500 32 2.875 5075 Perforations Summary Interval I TVD 5547 - 7350 3032 - 3075 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V aD Latch Mfr 2750 2000 CAMCO MMG 2 4258 2701 CAMCO MMG Other (plugs, equip., etc.) - JEWELRY MAIN LEG Depth TVD Type 34 34 HANGER 5027 2952 SLEEVE-O BAKER CMU SLIDING SLEEVE 5060 2958 GAUGE GUARDIAN GAUGE 5075 2961 XO 5075 2961 V-BLOCK 5078 2961 NIP HES 'X' NIPPLE 5178 2978 WLEG BAKER WIRELlNE GUIDE Other (plugs, equip., etc.) - MOTOR LEG Depth TVD Type 5074 2961 Connector 5080 2962 PUMP 5088 2963 PUMP 5113 2967 SEAL 5127 2970 MOTOR 5150 2973 MOTOR 5175 2977 Centralizer Other (plugs, equip., etc.) - HORIZONAL GRAVEL PACK Depth TVD Type Description 5284 2994 PACKER MODEL SC-1 R PACKER 5285 2994 PUP 5293 2995 SLEEVE SLIDING SLEEVE W/SEAL BORE 5327 3000 KOIV 7326 3075 Flapper SUB SHOE Size 16.000 10.750 10.750 5.500 Bottom 106 4498 5480 7350 Top o 37 4498 5547 Bottom 5075 5178 TVD 2961 2978 Wt 12.60 6.40 2T-218 Angle (â) TS: deg @ Angle @ TD: 89 deg @ 7360 Rev Reason: Pull plug Last Update: 3/20/2004 TVD 106 2801 3023 3075 Grade L-80 13Cr80 Wt 62.50 45.50 55.50 0.00 Grade Thread H-40 WELDED L-80 BTC 13Cr80 VAM-ACE Thread IBTM SLT Zone I Status 1Ft I SPF I Date I Type I Comment 1803 50 4/8/2003 IPERF GRAVEL PACK SCREEN DMY DMY 1.5 1.5 Description Description CENTRLlFT PUMP 19KC12000 MT CENTRILlFT PUMP 44KC12000 L T GST3 4B HL PFS TANDEM SEAL TANDEM ESP MOTOR TANDEM ESP MOTOR 7348 3075 RK RK Port 0.000 0.000 TRO Date Run 4/8/2003 4/8/2003 o o Vlv Cmnt ID 4.500 3.810 4.500 2.875 3.958 2.313 2.441 ID 5.620 0.000 0.000 0.000 0.000 0.000 0.000 ID 6.000 4.880 6.000 6.310 2.980 0.000 ) Randy Thomas ) Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips. P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 13, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2T-218 (APD # 203-017) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2T-218. If you have any questions regarding this matter, please contact me at 265-6830 or Shane Cloninger at 265-6829. Sincerely, \<-~ \ ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVED JUN 1 8 2003 Alaska Oil & Gas Cons. Commission Anchorag2 ORIGINAL ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 Plugged 0 Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 7fi8' F~L, 556' FWL, Sec. 1, T11 N, R8E, UM At Top Productive ,.- Horizon: 2638' FNL, 1664' FEL, Sec. 2, T11 N, R8E, UM Total Depth: 1322' FNL, 1021' FEL, Sec. 2, T11N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-498945 y- TPI: x- 496724 y- Total Depth: x- 497366 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 10.75" 45.5#/55.5# L-80 I 13Cr80 5.5" 17# 13Cr CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 5480' 5284' 7352' 5970748 5972623 5973938 Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): gravel pack screen from 5547' - 7350' MD, 3032' - 3074' TVD j._.._."~"-,.'".- ,~,~...,..",~..",\ ."\:. G(¡¡I:,1 :)iEn 0iI\! ~ j ~,"2Jf. d ~ \{:~~;:~ ~F; i~:::-:¡ r ! _.__-!,{þ. 1 t....,....___.,.."".,~~=:~··· ..~~ " Suspended 0 WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: April 10, 2003 6. Date Spudded: I March 23, 2003 7. Date TD Reached: / April 2, 2003 8. KB Elevation (ft): RKB 36' 9. Plug Back Depth (MD + TVD): 7360' MD I 3075' TVD 10. Total Depth (MD + TVD): 7360' MD I 3075' TVD 11. Depth where SSSV set: N/A 19. Water Depth, if Offshore: NI A feet MSL 1 b. Well Class: Development 0 Exploratory D Service 0 Stratigraphic Test 0 12. Permit to Drill Number: ,¡ 203-0171 13. API Number: 50-103-20449-00 14. Well Name and Number: 2T-218 15. Field/Pool(s): Kuparuk River Field Tabasco Oil Pool 16. Property Designation: ADL 25569 17. Land Use Permit: ALK 2667 20. Thickness of Permafrost: 1675' MD 24" CEMENTING RECORD AMOUNT PULLED HOLE SIZE 13.5" 8.75" 9 cu yds High Early 661 sx AS Lite & 636 sx LiteCrete gravel packed TUBING RECORD DEPTH SET (MD) 5075' 5075' - 5178' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5435' - 5352' 75 bbls caustic wash and 500 gals HCI wi inhibitor 24. SIZE 4.5" 2.875" 25. PACKER SET (MD) 5284' 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 8,2003 GAS LIFT OIL Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 6/12/2003 13 hours Test Period --> 853 55 44 176 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 374 psi not available 24-Hour Rate -> 1530 145 80 not available 27. CORE DATA n Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necesJa\)E C t: tv ED Submit core chips; if none, state "none". . JUN 1 g 2003 Alaska Oil & Gas C . ons. Commission Anchorage Form 10-407 Revised 2/2003 fØ)MS Bt'- Gr NONE CONTINUE!j l'iREVE~E r)~E. A l jUL V t lWjj J ~ GAS-OIL RATIO 95 Submit in duplicate 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2T-218 Tabasco Sand S~ h·-'H~'e'L-.:· .-:) 11 ' Ic.-ì-,·"·· t"O.I....',·· ",..t /,,1 f.\ (, 5895' 3056' NIA RlEClE/1/J .' JUN t:. A 182 laska 011. 003 & Ga,~ C. fms. C . . A/~"'8. On~¡·!.,."r.o .. B"'U1orage li/iliV,;;s"fGf1 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Shane Cloninger 265-6829 Printed Name R. Thomas Title: Kuparuk Drilling Team Leader <- Signature \ ~ ~ P'tlune U<)6i?~ò Date 6 I ()(o :$ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". OR\G\N' Form 1 0-407 Revised 2/2003 ) ) ., ... : ....... . ....... : .':' :.. ". .' . . ..". . '. .' ..... "".. . ... .. ........... . ..... .. ...... "... . ".. . '". .. .. ..... .. .. ... ..."... . ,.. . ...... ... ... ..... ..... ....... ... ......... ..... '... .. ..... .... ........ .... ........."... .... ... . . . ... .... ". . . .. . '." ...... . ... "... ... ... .." ..... ...... ........ .. . .......... .... .. .... .... ". .... ..... ..........",... ....... . , .... . ... . . . . ...... .. . . . ...." .. .... ... .:.. ..... :.... :.. ." . ..... .. ... . .' . . ..... .: ...... .... . .... .. .. . . . ... ... . .. . ..... ·i··i......r·····~~~t;1~~:~~~~~~~~~þØJl······ 9.50 MOVE MOB MOVE Rig released and underway from Rig Modifications to Tabasco 2T -218 at 1430 hrs. 3/19/2003. At 0000 hrs., rig floor/derrick carrier 2 miles past Colville River, 13 miles travelled of 39 miles total. Rig substructure at Colville River crossing, 11 miles travelled of 39 miles total. Continued moving rig from Alpine CD2 to Tabasco 2T-218. Continued moving rig from Alpine CD2 to Tabasco 2T-218. Moved pipe module and mud/pwer module. Elevated rig floor/derrick carrier and skidded rig floor and derrick to substructure. Began moving camp Positioned rig over 2T -218 well. Positioned rig over 2T -218 well and skidded rig floor and derrick to drilling position. Moved pipe module into position. Moved mudlpower module into position. Hooked up service lines between modules. Accepted rig for drilling operations at 0630 hrs. on 3/22/2003. Took on spud mud into pits. Removed snow under production flowline for diverter line. Welded extension onto conductor pipe to accommodate sliplock casing head. 8.00 MOVE RURD RIGUP Finished welding extension onto conductor pipe. Installed landing ring and sliplock casing head. Tested to 400 psi. N/U diverter (20" hydril), and diverter line knife valve. R/U diverter line under production flowline. Modified and installed drilling riser. Loaded DP and HWDP into pipe module. Finished R/U drilling riser, flowline, and auxilliary lines. P/U drill pipe and stood back in derrick. Function tested diverter as per and witnessed by AOGC. Continued P/U drill pipe (49 stands total) and stood back. P/U HWDP and stood back in derick. P/U BHA. Uploaded MWD. Adjusted motor housing to 1.83 degrees. Oriented UBHO. Filled hole and riser with mud - knife valve leaked. Dismantled knife valve and repaired same. Tested mud lines to 2500 psi. Conducted pre-spud meeting. Drilled 13-1/2" hole from 114' to 183'. Stood back stand HWDP. P/U 3 x NM Flex collars. Drilled 13-1/2" surface hole from 183' MD (183' TVD) to 503' MD (502' TVD). Sliding +1- 30' per stand. Ran gyro single shot survey after each of first four stands until 468' TMD. 1030 psi @ 111 SPM = 475 GPM. 80/115 RPM. WOB 10-20 klbs. P/U wt. 100 klbs., S/O wt. 95 klbs., Rot. wt. 95 klbs. Rotary torque onloff bottom 7500/4500 kft-Ibs. ADT: 3.64 hrs. = ART: 1.85 hrs. + AST: 1.79 hrs. 12.00 DRILL DRLG SURFAC Drilled 13-1/2" surface hole from 503' MD (502' TVD) to 1481' MD (1359' TVD). 1350 psi @ 106 spm 1454 gpm. 75-110 RPM. WOB 30-45 klbs. P/U wt. 120 klbs., S/O wt. 120 klbs., Rot wt. 120 klbs. Rotary torque onloff bottom 5500 / 4500 kft-Ibs. ADT: 9.32 hrs. = ART: 2.59 hrs. + AST: 6.73 hrs. 12.00 DRILL DRLG SURFAC Drilled 13-1/2" surface hole from 1481' MD (1359' TVD) to 2530' MD (1912' TVD). 2340 psi @ 150 spm (643 gpm). 100-150 rpm. WOB 10-45 klbs. P/U wt. 130 klbs., S/O wt. 110 klbs., Rot. wt. 120 klbs. Rotary torque on/off bottom: 12000 I 8500 kft-Ibs. ADT: 6.35 hrs. = ART: 3.72 hrs. + AST: 2.63 hrs. Total ADT: 19.31 hrs. = ART: 8.16 hrs. + AST: 11.15 hrs. Legal Well Name: 2T-218 Common Well Name: 2T-218 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Fròm'HTø tHòÙrs· ..COp~.·ð6dbe ···phéÌs~ 3/19/2003 14:30 - 00:00 3/20/2003 00:00 - 00:00 24.00 MOVE MOVE MOVE 3/21/2003 00:00 - 22:00 22.00 MOVE MOVE MOVE 22:00 - 00:00 2.00 MOVE POSN MOVE 3/22/2003 00:00 - 06:30 6.50 MOVE POSN MOVE 06:30 - 12:00 5.50 MOVE RURD RIGUP 12:00 - 20:00 3/23/2003 00:00 - 01 :30 1.50 MOVE RURD RIGUP 01 :30 - 07:00 5.50 DRILL PULD SURFAC 07:00 - 08:00 1.00 CEMENT SEaT SURFAC 08:00 - 09:00 1.00 DRILL PULD SURFAC 09:00 - 10:30 1.50 DRILL PULD SURFAC 10:30 - 13:30 3.00 DRILL PULD SURFAC 13:30 - 16:00 2.50 DRILL OTHR SURFAC 16:00 - 16:30 0.50 DRILL SFTY SURFAC 16:30 - 17:00 0.50 DRILL DRLG SURFAC 17:00 - 18:00 1.00 DRILL PULD SURFAC 18:00 - 00:00 6.00 DRILL DRLG SURFAC 3/24/2003 00:00 - 12:00 12:00 - 00:00 Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: . .,. .' ." .. ..:..... :..:" :":......": :.': :..:..:..:.....: '.': ....... ":. . . . .. ."., .,"....... .". '.. .···l:)e$brjpti()r)()fØþer~ti()ns·· .... .... ................. ........ ... Printed: 5/16/2003 3: 13: 15 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) .. .. ...... . . . .." ... ..:.... :". "..."; . . '. ... .... . ... .. .. .. ..". . . ." .... . .. ..... . . ".' '. .. ":"".... .".... . . :.. :.... .... .' : . .. ... . .. . , . . . . . . . . . .. . :1. . .. .:...... ... .... :·l¡~Þcn~~QF!hilìp!)~I~!)~<t·.. ............ ..¡ ..... · ... .·.·ºPE!~élti()I1~>SLJrn:l11~ryF1~p<?rJ·· 2T-218 2T-218 ROT - DRILLING doyon1 @ppco.com Doyon 19 ... > Dåte ...... Ftom..To Hdurs:QødeS.l.Jb Pht4s~ Code.· 3/24/2003 3/25/2003 12:00 - 00:00 00:00 - 12:00 12:00 - 17:00 17:00 - 18:30 18:30 - 00:00 Spud Date: End: Group: Start: 3/19/2003 Rig Release: Rig Number: Land Pe~criptiori 9fÖpåråtiÓJ1s·. 12.00 DRILL DRLG SURFAC 27 total circulating hours at 2400 hrs., estimated 155k bit revolutions. 12.00 DRILL DRLG SURFAC Drill 13 1/2" hole f/2530' to 3672' MD 2389' TVD ADT - 8.75 hrs. = ART - 5.16 hrs AST - 3.59 hrs. RPM - 50 WOB - 10/45 K GPM - 630 @ 2300 psi String wt. PU 135 SO 115 ROT - 125 Torque onloff 10,000/9,000 kftllbs 5.00 DRILL DRLG SURFAC Drilled 131/2" hole f/3672' MD (2384' TVD) to 3958' MD (2527' TVD). ADT: 4.93 hrs. = ART: 1.6 hrs. + AST: 3.33 hrs. 103 rpm (motor) + 50 rpm (TDS); 20-35 klbs. WOB; 2420 psi @ 643 gpm. P/U wt. 145 klbs., S/O wt. 120 klbs., Rot wt. 133 klbs. Torque on/off bottom: 12/10 kft-Ibs. Total ADT: bit #1: 32.99 hrs. = ART: 14.92 hrs. + 18.07 hrs. Bit #1 total circulating hrs. = 44.29; estimated max bit revolutions = 310k. 1.50 DRILL CIRC SURFAC Pumped hivis sweep and circulated and conditioned hole. 5.50 DRILL TRIP SURFAC POOH with pump (235 gpm) and TDS (30 RPM) from 3958' to 2911' with no resistance. Continued POOH on trip tank to 1728' - tight (60k o'pull). POOH with pump and TDS as above from 1728' to 1386'. Continued POOH on trip tank to 911' with no further resistance. Other resistance (25-50K) noted over short intervals (+1- 1') at 2370', 2340', and 2324'. POOH wI HWDP Handle BHA - change bit - adjust AKO to 1.5 on motor - Remove pressure drop sub & read MWD RIH to 1470' - took wt. Work through tight hole f/1470' to 1600' - Orient tool face & wash down & back ream Continue RIH f/1600' to 3862' - no problem Establish circulation - safety wash & ream f/3862' to 3958' - Pump hi vis sweep & circulate hole clean - 15 BPM @ 1850 psi wI 50 RPM Drill f/3958' to 4148' MD 2654' TVD ADT - 2.51 hrs. = ART - .28 hrs. AST - 2.23 WOB - 35 K RPM - 0 to 50 GPm 546 @ 1850 psi St. wt. PU 150 SO 125 ROT 135 Torque onl off 10,000 I 9,000 ftIlbs 12.00 DRILL DRLG SURFAC Drill f/4148' to 4850' MD 22913' TVD ADT - 8.66 hrs. = ART - 1.70 hrs. AST - 6.96 hrs. WOB - 35 K RPM - 0 to 50 GPM 630 @ 1980 psi St. wt. PU 155 SO 120 ROT 135 Torque onl off 13,000/11,500 ftIlbs 8.00 DRILL DRLG SURFAC Drill 13 1/2" hole f/4850' to 5370' MD 3/26/2003 00:00 - 01 :00 1.00 DRILL TRIP SURFAC 01 :00 - 03:00 2.00 DRILL PULD SURFAC 03:00 - 04:00 1.00 DRILL TRIP SURFAC 04:00 - 05:30 1.50 DRILL REAM SURFAC 05:30 - 07:00 1.50 DRILL TRIP SURFAC 07:00 - 08:30 1.50 DRILL REAM SURFAC 08:30 - 12:00 3.50 DRILL DRLG SURFAC 12:00 - 00:00 3/27/2003 00:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 16:00 0.50 DRILL CIRC SURFAC Circulate for Geologist - 15 BPM @ 2150 psi 1.00 DRILL DRLG SURFAC Drill 13 1/2" hole f/5370' to 5490' MD - 3024' TVD ADT - 6.21 = ART - 4.2 hrs AST - 2.01 hrs WOB - 35 - 40 K RPM - 50 - 60 GPM - 630 @ 2150 psi String wt. - PU 155 SO 115 ROT 135 Torque on I off btm - 13,500 19500 ftIlbs. 2.50 DRILL CIRC SURFAC Pump sweep & circulate hole clean for wiper trip -70 RPM -700 GPM 4.00 DRILL WIPR SURFAC Flow check (static) - POOH wI pump & back reaming (6 BPM wI 40 RPM) fl 5490' to 4527' - Switch over to trip tank - continue to POOH fl Printed: 5/16/2003 3:13:15 PM ') ') .. .. .. ... . . .. ...... . .. .. . . ·n·' .. .'.,.... .".Þ.~~~R?P~ili~S~laskà>. . . .'.., .'.. ,.CPpE)råtic~~I)$.~urpmClry·.R~p().r~ 4527' to 2427'. Tight spot and unable to work through. RIH to 2432'. Work through tight spot wI pump and rotation. Hole packing off. CBU @ 546 gpm - 60 rpm - 1380 psi. Finish wiper trip to 1288' while continuing to pump and rotate. Pull last stand without pump or rotation with normal drag. Flow check. RIH (work through one tight spot @ 1460') with normal drag of 5 to 10 down. Wash/Ream last stand to bottom @ 5490'. Circulating and Conditioning hole while pumping Hi-Vis sweep. 630 gpm - 70 rpm - 1930 psi. Pump hi vis sweep & circulate hole clean for casing -700 gpm @ 2140 psi - std back 1 std. POOH f/ 5395' to 4522' - tight hole - work tight hole up to 4485' POOH wI pump & rotary fl 4522' to 3550' - switch back to trip tank & POOH fl 3550' to 2670' - tight spot - POOH wI pump & rotary fl 2670' to 2200' - switch back to trip tank & POOH fl 2200' to 1600' - tight spot - POOH wI pump & rotary f/1600' to 1400' - switch back to trip tank & POOH on trip tank f/1400' to 1006' (BHA) - flow check - well static Handle BHA - std. back HWDP & jars - LD (3) 8" DC's - stab - UBHO - MPT - MWD (down load MWD) - motor & bit - Clear rig floor of BHA tools Rig up to run 10 3/4" casing Held Pre-job safety meeting on running 10 3/4" Chrome casing and reg. buttress Run 103/4" casing - Float shoe - 2 jts. 103/4" 55.5# L-80 13 Chrome V AM-ACE casing - Float collar - 1 jt. 10 3/4" 55.5# L-80 13 Chrome csg - Baker Loc first 4 connections - 23 jts. 10 3/4" 55.5# L-80 13 Chrome V AM-ACE casing - 1 jt. 10 3/4" 55.5# L-80 13 Chrome Vam- Ace P x BTC B - Run 60 jts. 10 3/4" 45.5# L-80 BTC casing (Total joints run 84 of 132). * Note took wt. @ 1517' - washed down f/1517' to 1739' - took wt @ 3345' - washed down fl 3345' to 3384' 4.00 CASE RUNC SURFAC Continue running 10 3/4" 45.5# L-80 BTC casing - f/3399.52' to 3526.09' (washed down) ran into 4500.68' (110 jts. total) Install Tam port collar top of jt # 110 - Continue running 10 3/4" 45.5# L-80 BTC casing to 5441.41' (132 jts. total ran) PU hanger & Landing Jt. Land casing wI shoe @ 5479.63' - FC @ 5400.41' - Tam PC @ 976.16' 0.50 CASE OTHR SURFAC LD fill up tool & blow down TD - RU cement head 3.00 CEMENTCIRC SURFAC Circulate & condition mud & hole for cement job - 5 BPM @ 260 psi- Held pre-job meeting 4.50 CEMENT PUMP SURFAC Cement 10 3/4" casing: Pumped 40 bbls Biozan water wlnut plug & dye - Test lines to 3500 psi - Drop bottom plug - Mix & pump 50 bbls Mudpush XL spacer @ 10.5 ppg - Mix & pump 504 bbls Lead slurry ASlite @ 10.7 ppg - 6 bpm - Mix & pump 254 bbls tail slurry LiteCrete @ 12.0 ppg - Drop top plug wI 20 bbls water fl Dowell- switch to rig pumps & displace wI 496 bbls 9.8 ppg mud @ 6.6 bpm - Bumped plug w/ 1500 psi - CIP @ 1152 hrs. - full returns through out job wI 326 bbls cement returns to suriace Legal Well Name: 2T-218 Common Well Name: 2T-218 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 . [)ate From;;, To +:löurSCödé SUb·. . Phase COdè 3/27/2003 12:00 - 16:00 4.00 DRILL WIPR SURFAC 16:00 - 17:00 1.00 DRILL CIRC SURFAC 17:00 - 19:00 2.00 DRILL WIPR SURFAC 19:00 - 22:00 3.00 DRILL WIPR SURFAC 22:00 - 00:00 2.00 DRILL CIRC SURFAC 3/28/2003 00:00 - 02:15 2.25 DRILL CIRC SURFAC 02:15 - 03:15 1.00 DRILL TRIP SURFAC 03:15 - 09:15 6.00 DRILL TRIP SURFAC 09:15 - 13:00 3.75 DRILL PULD SURFAC 13:00 - 14:45 1.75 CASE RURD SURFAC 14:45 - 15:00 0.25 CASE SFTY SURFAC 15:00 - 00:00 9.00 CASE RUNC SURFAC 3/29/2003 00:00 - 04:00 04:00 - 04:30 04:30 - 07:30 07:30 - 12:00 12:00 - 14:00 2.00 CEMENT PULD SURFAC 14:00 -18:30 4.50 DRILL RIRD SURFAC 18:30 - 20:30 2.00 DRILL RIRD SURFAC Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: . . .. .. '. "', . .. . ... ..... . ....... ..... ... ",. ... . .. . DescriptiÓr1·.·~f·Øperatioris UD cement head - elevators - slips - bales - fill up tool - landing joint - power tong unit and flush riser. N/D diverter system - riser - flowline - mousehole - turn buckles. Remove diverter line and clear cellar. N/U casing head - adaptor flange - wing valves - install annulus valves Printed: 5/16/2003 3:13:15 PM ) ., ) "'i ,':'r9:~~~?~t1nHff~~la~ka.:'.,": i¡'n. ,',' ..···Qp~t~tiºI"Ì~§uml1'1ê:},rYFf~P9~J .... .... . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-218 2T-218 ROT - DRILLING doyon1 @ppco.com Doyon 19 ····[jate> ·SÙb··· Frörit";TÔ Hòl.lrsCod$ Gode' Phase· 3/29/2003 18:30 - 20:30 20:30 - 00:00 2.00 DRILL RIRD SURFAC 3.50 DRILL RIRD SURFAC 3/30/2003 00:00 - 01 :30 01 :30 - 03:00 03:00 - 09:30 1.50 WELCTL NUND SURFAC 1.50 WELCTL NUND SURFAC 6.50 WELCTL BOPE SURFAC 09:30 - 10:00 0.50 DRILL PULD SURFAC 10:00 - 14:00 4.00 DRILL PULD SURFAC 14:00 - 18:00 4.00 DRILL TRIP SURFAC 18:00 - 19:00 1.00 RIGMNT RSRV SURFAC 19:00 - 21 :00 2.00 DRILL TRIP SURFAC 21 :00 - 21 :30 0.50 DRILL CIRC SURFAC 21 :30 - 23:00 1.50 DRILL OTHR SURFAC 23:00 - 00:00 1.00 CEMENTCOUT SURFAC 3/31/2003 00:00 - 00:45 0.75 DRILL DRLG SURFAC 00:45 - 01 :15 0.50 DRILL CIRC SURFAC 01:15-02:00 0.75 DRILL FIT SURFAC 02:00 - 02:30 0.50 DRILL DRLH PROD 02:30 - 04:00 1.50 DRILL CIRC PROD 04:00 - 07: 15 3.25 DRILL DRLG PROD 07:15 - 08:15 08:15 - 14:00 1.00 DRILL 5.75 DRILL CIRC PROD CIRC PROD 14:00 - 00:00 10.00 DRILL DRLG PROD 4/1/2003 0.50 DRILL DRLH PROD 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 10:00 1.00 DRILL 0.50 DRILL 8.00 DRILL WIPR PROD TRI P PROD DRLH PROD Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: ... . . . .".. . . . .. . . .".. . . ..." ... .. ..... . .". .. .", péscriptiorio.f 9pe~~tiOrJs·· and test metal to metal seal to 1000 psi wI FMC for 10 minutes. Begin N/U of BOP equipment including chokeline & kill line. Tighten stud on adaptor flange - M/U drain lines - mouse hole & modify bell nipple for length. Modify bell nipple - Service rig - Service & inspect TD PU bell nipple - RU to test BOPE Test BOPE : pipe rams, blind rams, kill & choke ine valves, choke manifold TD IBOP - TIW & dart valves to 250 psi low & 5000 psi high- Hydril to 250 psi low & 3500 psi high - Accumulator closure test - Test witnessed & approved by Jeff Jones AOGCC Pull test plug - install wear bushing - blow down choke & kill lines PU short bails - elevators - Prep to PU DC's & HWDP for Hybrid string PU 10 stds Hybrid string for liner job - 2 - 6 1/4" DC's & 1 HWDP (10 stds total) - Pulll out & std back M/U 8 3/4" BHA including motor, MWD and PWD. Motor set @ 1.22 degrees. Orient. Continue RIH picking up necessary 5" DP to 1881'. Cut & Slip 60' of drill line. Continue to RIH to 5,376'. Test MWD. Circulate BU to perform casing test. R/U and test casing to 3000 psi for 30 minutes. Good test. RID test equipment. Drill cement, FE, float collar, shoe track, shoe and rathole to 5491'. Drill 83/4" hole f/5490' to 5510' MD 3027' TVD Circulate hole clean for FIT Blow down TD - RU for FIT - Perform FIT to 11.5 ppg EMW 300 psi wI 9.6 ppg mud - RD test equip. Drill 8 3/4" hole f/5510' to 5544' MD Circulate & lower mud wt. to 9.3 ppg Drill 83/4" hole f/5544' to 5670' MD 3074' TVD WOB 10/12 RPM 65 GPM 546 @ 1400 psi String Wt. PU 190 SO 110 ROT 135 Torque on I off btm 12500 K ADT - 2.76 hrs. = ART - 2.1 hrs. AST - .66 hrs Circulate hole clean PJSM - Change well over to 9.0 ppg FloPro - Flow ck (static) - Clean surface equip. & pit #6 to take on reseve Flo Pro for loss circulation Drilling 8 3/4" hole from 5,670' to 6,154' (3070' TVD). ADT= 5.77 ART: 1.80 AST= 3.97 GPM= 546 PSI= 1550 RPM= 60170 WOB= 3/12 String Weights: PU= 235 SO= 85 ROT= 145 Torque on/off= 14000/13500 Drill 8 3/4" horizontal section fl 6154' to 6220' MD WOB 4 k RPM 50 GPM 437 @ 1140 psi String wt. - PU 245 SO 85 ROT 145 Torque on I off btm 14000/13500 Wiper trip - Back ream & pump out fl 6220' to 5940' - 13 BPM - 90 RPM RIH f/5940' to 6220' - taking wt. -pump @ 8 BPM wI 50 RPM Drill 8 3/4" horizontal section f/ 6220' to 6602' MD 3072' TVD - ADT- 8.54 = ART - 1.44 hrs AST - 7.1 hrs. WOB - 4 k RPM 50 GPM 437 @ 1140 String wt. PU 245 SO 85 ROT 145 Torque on / off btm - 14000/13500 Having trouble sliding Printed: 5/16/2003 3: 13: 15 PM ) ) .... .... ..:.... .. .. ......... ."": ". .. . ....... .'.. . :..... .':. '..' .... ... ...., . ... . .. . .... .. . .. . . ... . ... . . .. . . .". ,". ..... .... . ........ .. .... .. ... .... . .. '... .. ".' . ....... . .... ..... . .... ...... ..... ... .... . . ... ..... .. ............ .. . . ... .. . .. .. '". ......... . . . . . . . . .. ....... ... . ... ..... . ..... ... .. ".. . . .. ...... :.. . ...' ......... ." . ",." .. ...... ...... .. ..""0··· .. . . .. ."". .' ,". . . .. . ..... .... ,.. .. .. ....... .. .. ... ... ....... ........ ........ . . "." . .. .... .. ... ... . .... ... ,. ...... ....,...'.... < .. ...·...Ðoijc)êþehilliR~~Ia.~kCl'... ...i:.:!'." , <~ip~râtiål1~.¡$!U:r11rTIªtY!å~pørf .... ' .' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-218 2T -218 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: ··pate.... From Htp<· HoÜrsC()d~.' · Sub . Code 4/1/2003 WIPR PROD CIRC PROD 10:00 - 13:00 13:00 - 15:30 3.00 DRILL 2.50 DRILL 15:30 - 16:30 16:30 - 17:00 17:00 - 00:00 1.00 DRILL 0.50 DRILL 7.00 DRILL WIPR PROD REAM PROD DRLH PROD 4/2/2003 DRLH PROD 00:00 - 06:00 6.00 DRILL 06:00 - 08:00 08:00 - 08:30 08:30 - 10:00 2.00 DRILL 0.50 DRILL 1.50 DRILL WIPR PROD TRIP PROD DRLH PROD 10:00 - 12:00 2.00 DRILL CIRC PROD 12:00 - 16:30 4.50 DRILL TRIP PROD 16:30 - 18:00 1.50 DRILL CIRC PROD 18:00 - 20:30 2.50 DRILL TRIP PROD 20:30 - 21 :00 0.50 DRILL CIRC PROD 21 :00 - 00:00 3.00 DRILL TRIP PROD 4/3/2003 00:00 - 01 :00 1.00 DRILL PULD PROD 01 :00 - 02:00 1.00 DRILL PULD PROD 02:00 - 06:00 4.00 DRILL TRIP PROD 06:00 - 07:00 1.00 DRILL CIRC PROD 07:00 - 10:00 3.00 DRILL TRIP PROD 10:00 - 13:00 3.00 DRILL CIRC PROD 13:00 - 13:30 0.50 CMPL TN CMPL TN 13:30 - 15:30 2.00 CMPL TN CMPL TN 4/4/2003 15:30 - 19:00 19:00 - 00:00 00:00 - 03:30 3.50 CMPL TN CMPL TN 5.00 CMPL TN CMPL TN 3.50 CMPL TN AWSH CMPL TN 03:30 - 04:00 0.50 CMPL TN CI RC CMPL TN 3.50 CMPL TN AWSH CMPL TN RU for Acid pickle job - PJSM - Pump acid wI Dowell @ .5 BPM - 500 04:00 - 07:30 . .' .".. '. . ... .. .. .... .. ..... '.' ........ ........", ...... . .. . . . '.' 0"" ...... ..... ............... . .. '. D~scriptiqrl ()f9þ~ra~iÓns ... Wiper Trip fl 6602' to 5480' - Pump out wI 12 BPM - 80 RPM Pump sweep & circulate clean - Pump @ 16.5 BPM & 90 RPM - massive amount of cutting @ shakers RIH w/4 stands of HWDP & 8 stands of hybrid assembly to 6492'. Wash & Ream to 6602'. Drill 83/4" horizontal section f/6602' to 7005' MD 3070' TVD- ADT -1.92 = ART -1.77 hrs AST - .15 hrs. Having trouble sliding - much time spent orienting and reaming. WOB= 4 RPM= 100 GPM= 546 @ 1590 psi. String Weight: PU= 275 SO= 85 ROT= 170 Torque on/off= 16000/15500 Drill 8 3/4" horizontal hole f/7005' to 7276' MD - 3069' TVD - WOB 0/4 k RPM 0/90 GPM 546 @ 1500 psi St. wt - PU 285 SO 85 ROT 170 Torque on I off btm 17000 116500 Having trouble sliding Flow check (static) Back ream f/7276' to 6950' - 15 BPM 80 SPM RIH wI pump f/6950' to 7276' - 15 BPM 80 RPM Drill 8 3/4" horizontal hole f/7276' to 7360' MD TD 3079' TVD WOB - 0/4 RPM 0/90 GPM 546 @ 1500 St. wt. - PU 285 SO 85 ROT 170 Torque on I off btm - 17000/16500 Circ hole for trip out - 13 BPM 100 RPM - std. back 1 std @ first bottom up Flow check (static) POOH wI pump 12 BPM 80 RPM f/7332' to 5480' - Hi torque slight pack off @2 5754' - hi torque @ 5586' to 5642' Circ @ 10 3/4" casing shoe POOH wI pump and rotary to 5021'. POOH on trip tank to 4409. POOH wI pump and rotary to 4069'. POOH to 4038' on trip tank. Drag increasing. CBU x 2 using 18 bpm - 30 rpm @ 1550 psi. Large amounts of cutting from hole over shaker. POOH on trip tank to 76' laying down necessary BHA components. Continue LD BHA Flow check (static) PJSM - PU clean out assembly - bit IBSI stabl 2 HWDPI jars 13 HWDP RIH wI CO assembly f/195' to 5450' (fill string every 2000') Circulate bottoms up 20 BPM 150 RPM - Observed cutting @ shakers - Flow check (static) RIH f/5450' to 7360' wI pump 6 BPM - 40 RPM Circulate hole clean for brine change over - 14 BPM - 110 SPM PJSM - Displacement procedures for brine. Displace well- Pump 40 bbls. push pill and displace with 9.2 ppg brine at 12 bpm - 110 rpm - 1090 psi. Spot 140 bbls of viscosified brine in open hole. POOH to 5435'. Monitor losses @ shoe wI ·0" static losses. Circulate hole wI unfiltered brine while cleaning pits. PJSM - Caustic wash - Perform caustic wash - Pumped 75 bbls Caustic SL wash @ 7.5 BPM wI 100 RPM Circulate & condition filtered brine @ 7.5 BPM - until returns of 14 NTU Printed: 5/16/2003 3: 13: 15 PM ) ') . .. . . ... . . .. . .. . ..,. . .. .... ..: ':.: ':': .... . ...:' ... .:......". ':'.:" .". ':":" :" :".' .'..." ".: .... .. ..... : .... ......'.. :. .' : :- ....., . . . . "' .. ..... ......... ..···.ø~t!tZ1~~~~~:~~~[~~~ðrt· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .. ··pä.te 2T-218 2T-218 ROT - DRILLING doyon1 @ppco.com Doyon 19 From-To; ··Hou rs .ciodê > ..;.~LlÞ!. : ...; ......<) ··Code Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: .....:.. ..... . :.' . ....:. ":.".":": .:".':: . .... <. < De$criptio·nÇ)(Qper~tions.· .... 4/4/2003 04:00 - 07:30 3.50 CMPL TN AWSH CMPL TN gals 15% HCL wI inhibitor & 7# citric acid Displaced acid wI Dowell @ .5 BPM to 5352' 8.00 CMPL TN AWSH CMPL TN Reverse circulate acid pickle @ 2 BPM wI 230 psi - taking returns to tank - hole taking fluid while reversing - Discovered that float valve was mistakingly ran in clean out string - Contacted Kup. Drilling team leader - Continued to reverse out acid to ph of 6.5 - switched and circulated out long way - took 350 bbls brine 8.3 ph to pits & sent 150 bbls to acid return tank - lose rate of 12 BPH while circulating out long way - Lost 380 bbls to formation while reversing - 07:30 - 15:30 15:30 - 19:00 3.50 CMPLTN CIRC CMPL TN Circulate and condition brine to achieve < 20 NTUs. Initial NTU reading of 99.9 - Last reading 66.9. 19:00 - 23:00 4.00 CMPLTN CIRC CMPL TN Circulate over top hole and monitor well while building additional clean brine (600 bbls.). Hole taking 10 to 14 bbl/hr. 23:00 - 00:00 1.00 CMPL TN CI RC CMPL TN Pump viscosified spacer. Displace with clean brine to clean well bore to approximately 20 NTU. 4/5/2003 00:00 - 02:30 2.50 CMPLTN CIRC CMPL TN Continue cirulate & filter brine to <20 NT Us - 9.1 ppg Hole taking fluid @ 10 bbl/hr. 02:30 - 07:00 4.50 CMPLTN TRIP CMPL TN RD circulating equipment - flow check - POOH wI clean out assembly - hole taking @ 14 bbls/hr 07:00 - 08:00 1.00 CMPL TN PULD CMPL TN LD BHA - - losses @ 10 bbls/hr 08:00 - 08:30 0.50 CMPL TN OBSV CMPL TN Pull wear bushing 08:30 - 11 :00 2.50 CMPL TN RURD CMPL TN RU to run 5 1/2" gravel pack screens 11 :00 - 11 :30 0.50 CMPL TN SFTY CMPL TN Held PJSM wI crew - running 51/2" chrome GP screens 11 :30 - 12:00 0.50 CMPL TN OTHR CMPL TN House keeping rig floor 12:00 - 12:30 0.50 CMPL TN SFTY CMPL TN Held PJSM wI PM crew - running 5 1/2" GP liner 12:30 - 17:00 4.50 CMPL TN SCRN CMPL TN Begin running 5 1/2" GP screens - PU shoe jt. - V-set shoe - pup jt. - flapper valve - flapper valve - 0 ring sub - 51/2" 17#SLHT 13CR - 45 jts 51/2" 17# 13CR base pipe wI 8251 Excluder 2000 Screen Medium Mesh - 6 jts. 5 1/2" 17# SLHT CR13 blank pipe - 17:00 - 18:30 1.50 CMPL TN RURD CMPL TN RID 51/2" screen running handling equipment. R/U handling equipment to run 4" inner string. 18:30 - 22:30 4.00 CMPL TN SCRN CMPL TN Run 4" inner sting. 22:30 - 00:00 1.50 CMPL TN SCRN CMPL TN Space out inner sting as per Baker. P/U gravel pack assembly complete with packer. 4/6/2003 00:00 - 01 :30 1.50 CMPL TN SCRN CMPL TN MU Baker Model SC-1 R packer - RD liner running equipment 01 :30 - 02:00 0.50 CMPL TN SCRN CMPL TN PU 1 std. drill pipe - fill pipe 1 BPM - Attempt to rotate @ 10 RPM Torque - 5500 ftllbs @ 2155' 02:00 - 08:30 6.50 CMPL TN SCRN CMPL TN RIH w/5 1/2" GP assembly f/2155' to 5463' (16" above 103/4" shoe) - 13 stds. 5" DP - 8 stds 5" HWDP - 14 stds. 5" DP 08:30 - 09:00 0.50 CMPL TN OTHR CMPL TN Break circ - fill string wI 75 bbls viscofied brine - Obtain PU wt 205 K SO wt. 115 K @ 5463' 09:00 - 14:00 5.00 CMPL TN SCRN CMPL TN Continue RIH wI GP assembly f/5463' to 6055' - took wt. attempt to work liner down - Screw in wI TD - Wash & work GP liner down f/6055' to 7351.57' - pumping @ 3.2 BPM @ 2290 to 330 psi - didn't rotate Final PU wt. 300 K SO wt. 85 K 5 1/2" liner shoe @ 7351.57' Top of liner @ 5274.38' 14:00 - 17:30 3.50 CMPLTN CIRC CMPL TN Circulate hole volume (581 bbls.) filtered brine @ 3 bbls/min @330 psi start wI final pressure 11 0 psi 17:30 - 20:00 2.50 CMPL TN PCKR CMPL TN Drop setting ball - pump down wI 41 bbls @ 1.5 BPM @ 30 psi - Set Printed: 5/16/2003 3:13:15 PM .) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-218 2T-218 ROT - DRILLING doyon1 @ppco.com Doyon 19 [)at~ Sub 'Fron1-"To' HoÜrs >Code Code 4/6/2003 17:30 - 20:00 20:00 - 00:00 4/7/2003 00:00 - 03:30 03:30 - 04:00 04:00 - 08:30 08:30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 17:00 4/8/2003 17:00 - 20:00 20:00 - 20:30 20:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 08:30 08:30 - 09:00 4/9/2003 09:00 - 09:30 09:30 - 14:30 14:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 00:00 00:00 - 07:30 07:30 - 17:00 17:00 - 20:30 4/10/2003 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 05:30 Spud Date: End: Group: Start: 3/19/2003 Rig Release: Rig Number: Land Description..olqpetatiöns 2.50 CMPL TN PCKR CMPL TN 4.00 CMPL TN OTHR CMPL TN 3.50 CMPL TN OTHR CMPL TN 0.50 CMPLTN SFTY CMPLTN 4.50 CMPL TN OTHR CMPL TN 5.00 CMPL TN GRVL CMPL TN 1.00 CMPL TN GRVL CMPL TN 0.50 CMPL TN RURD CMPL TN 2.00 CMPL TN TRI P CMPL TN 3.00 CMPL TN TRIP 0.50 CMPL TN TRIP 2.50 CMPL TN TRIP 0.50 CMPL TN OTHR 0.50 CMPL TN TRI P 8.50 CMPL TN TRIP 0.50 CMPL TN OTHR 0.50 CMPL TN RURD 5.00 CMPL TN PULD 2.00 CMPL TN TRIP 0.50 CMPL TN OTHR 1.00 CMPLTN OTHR 6.00 CMPL TN RUNT 7.50 CMPLTN RUNT CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 9.50 CMPL TN RUNT CMPL TN 3.50 CMPL TN RUNT CMPL TN 0.50 CMPL TN RUNT CMPL TN 0.50 CMPL TN RURD CMPL TN 1.50 CMPL TN NUND CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN RURD CMPL TN 1.00 CMPLTN FRZP CMPLTN 2.00 CMPL TN FRZP CMPL TN 1.00 CMPLTN FRZP CMPLTN 0,50 CMPL TN FRZP CMPL TN packer - pull & slack test - test back side to 1500 psi - pressure up to 4400 psi to release GP tool - Obtain space out marks for circ & reversing RU & check reverse pumping OK - Set @ circulating position & check to circulate long way OK - Blow down TD RU Dowell GP lines - Circ on trip tank - monitor well - loss rate 4 bblslhr - building GP fluid * Note: all GP fluid @ 5 NTU Continue monitor well on trip tank - while building GP fluid - losses @ 4 B/H Held Pre job safety meeting on Gravel pack job Establish circulation rates @ 2, 4, 6, & 8 B/M - Anchorage office formulating GP pump schedule - work on Dowell flow out meter Pump Gravel Pack as per instructions from Anchorage - Rate= 7 bpm @ 500 psi Gravel Concentration= 1/2 ppg. Gravel Pack screened out early with 1319 psi. Estimated product usage: 1788 bbls of brine & 36049 Ibs. of sand. (Initial job planned to use 66,000 Ibs. of sand) P/U to reverse position and reverse 400 bbls of brine @ 8 bpm wI 870 psi. -Observed sand @ shakers RID casing bales & circulating head. R/U short drilling bales to POOH. POOH and stand back 10 stands of DC's and 13 stands of DP to close KOIV valve. Monitor well - no static losses. Continue to POOH laying down 25 stands of DP & 8 stands of HWDP. UD gravel pack tool. R/U to UD 4" inner string. UD 48 joints and pups. Clear rig floor of Baker tools - handling tools & R/U to RIH wI DP. RIH wI DC's to UD same. Finish UD drilling tubulars including drill collars, HWDP and 5" drill pipe. Run wear bushing to pick up 41/2" completion tubing and stand in derrick. R/U to pick up 41/2" tubing and stand in derrick. P/U & RIH wI 53 stands of 41/2" tubing. POOH and stand in derrick 53 stands of 4 1/2" tubing. Pull wear bushing. Cut drilling line. R/U to run ESP and completion. RIH wI Baker ESP. Finish making up Baker ESP including "I" Tube and power control cable. RIH wI ESP on completion tubing as per program. M/U hanger. Prepare ESP power connector and gauge connector. Mate both to hanger penetrators. Test as per program. Land hanger. UD landing joint. N/D BOP's. N/U FMC tree as per program. Finish N/U tree and test to 5000 psi-OK. Pull 2-way check and RlU to freeze protect Safety meeting. Test lines to 1100 psi. Freeze protect wI 180 bbl diesel Put tubing an annulus in communication and let diesel u-tube. Suck out lines and RID freeze protect lines and manifold Printed: 5/16/2003 3:13:15 PM ) ) .. . . ..... .. ... , ...¡ .,. ...... . .. ...... ,. ...9pnqp()PHiW~~·þ.t~~l<a, '.. ,....... .. ... ......, '... :'.··.Øþ~rCltiC)f'$.. §ûlt)l'11C1ry .·fI.~pórt..·.. Legal Well Name: 2T-218 Common Well Name: 2T-218 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Pate ¡::röm~To < H.·. ·.o.ü.rs ..c.o..·.·.d. è..·.··......·.··Csu.·.d·b.. Phâse ....<.. .....··.··:.·0 e· Start: 3/19/2003 Rig Release: Rig Number: Land Spud Date: End: Group: . - . . . .. . . De~øripti6fl!()f ()PE!rati()h~· 4/1 0/2003 05:30 - 06:00 0.50 CMPL TN SEaT CMPL TN Check ESP electrical hook-up and downhole gauge-(1320 psi & 61 deg. F) 1.00 CMPLTN RURD CMPLTN Install BPV and release rig at 07:00 hrs 4-10-03 CMPL TN CMPL TN 06:00 - 07:00 07:00 - Printed: 5/16/2003 3:13:15 PM Date 05/09/03 05/12/03 05/14/03 05/15/03 05/18/03 ) ) 2T -218 Event History Comment OBTAINED SBHP @ 4625' AND 5025'RKB, SET 2.3111 XX PLUG IN IIDII NIPPLE @ 5078'RKB [PRESSURE DATA] PULL 2.31311XX PLUG @ 50781 VERY BAD ACTION [OTHER STIM] CERAMIC FLAPPER BROKEN AT 5328' USING 2-1/811 HIPPTRIPPER. UNABLE TO DRIFT KOIV WI HIPPTRIPPER BHA DUE TO TRASH FROM FLAPPER. RIH WI 2.2511 MHA, 211 STINGER, 211 JETSWIRL NOZZLE AND WASHED THROUGH TO 5330' CTM WI DIESEL. WILL RTN IN A.M. FOR ENZYME TREATMENT. LOADED TBG WI DIESEL TO ATIEMPT TO GET WELL TO FLOW; NOT ENOUGH BHP. ATIEMPTED TREATMENT WI BAKER MHA/DOWELL JET-BLASTER TS , BUT WERE UNABLE TO PASS 5056'; APPEARED HUNG AT Y-BLOCK. RECONFIGURED TS WI 211 STINGER AND 2.2511 CENT ABLE TO MAKE WASH PASSES WI ENZYME MIX FROM 5900' TO 7300', SET 2.31311 XX PLUG @ 5078' RKB. [ESP WORK] Page 1 of 1 6/9/2003 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T -218 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,360.00' MD (if applicable) ) a08-0/7 22-Apr-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 29 2003 Alaska (X: & Gas Cens. Commissron Anchorage Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 2T 2T-218 - Job No. AKZZ2323381, Surveyed: 2 April, 2003 Survey Report 21 April, 2003 Your Ref: 501032044900 Surface Coordinates: 5970747.74 N, 498944.97 E (70019' 52.7219" N, 150000' 30.8073" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -- Surface Coordinates relative to Project H Reference: 970747.74 N, 1055.03 W (Grid) Surface Coordinates relative to Structure: 365.31 N, 0.01 W (True) Kelly Bushing: 117.40ft above Mean Sea Level Elevation relative to Project V Reference: 117.40ft Elevation relative to Structure: 117.40ft Spe!I'r'Y-!5Ufl DRILLING SERVIc:es A Halliburton Company Survey Ref: 5vy2005 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 Your Ref: 501032044900 Job No. AKZZ2323381, Surveyed: 2 April, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 353.00 5.500 270.000 235.29 352.69 1.01 S 8.70W 5970746.73 N 498936.27 E -1.01 AK-6 BP IFR-AK 498.45 8.270 265.430 379.67 497.07 1.85 S 26.10 W 5970745.90 N 498918.87 E 1.940 -1.85 594.24 10.110 269.800 474.23 591.63 2.43 S 41.38 W 5970745.32 N 498903.59 E 2.053 -2.43 683.81 13.840 269.510 561.84 679.24 2.54 S 59.96 W 5970745.20 N 498885.01 E 4.165 -2.54 773.93 18.050 270.590 648.4 7 765.87 2.49 S 84.71 W 5970745.26 N 498860.26 E 4.683 -2.49 862.62 23.150 271.450 731.46 848.86 1.91 S 115.90 W 5970745.85 N 498829.07 E 5.760 -1.91 _. 961.95 27.770 269.350 821.12 938.52 1.68 S 158.58 W 5970746.08 N 498786.39 E 4.738 -1.68 1053.91 29.140 269.160 901.97 1019.37 2.25 S 202.39 W 5970745.52 N 498742.58 E 1 .493 -2.25 1148.43 32.000 268.790 983.35 1100.75 3.12 S 250.45 W 5970744.66 N 498694.52 E 3.032 -3.12 1244.73 34.590 267.720 1063.83 1181.23 4.74 S 303.28 W 5970743.04 N 498641.69 E 2.758 -4.74 1340.39 39.530 265.920 1140.15 1257.55 7.99 S 360.82 W 5970739.80 N 498584.15 E 5.287 -7.99 1435.27 44.700 265.960 1210.51 1327.91 12.49 S 424.27 W 5970735.31 N 498520.70 E 5.449 -12.49 1530.73 49.310 265.340 1275.59 1392.99 17.80 S 493.86 W 5970730.01 N 498451.10 E 4.853 -17.80 1625.91 52.960 269.090 1335.31 1452.71 21.34 S 567.85 W 5970726.48 N 498377.11 E 4.910 -21.34 1721.83 54.100 264.880 1392.34 1509.74 25.41 S 644.85 W 5970722.42 N 498300.12 E 3.724 -25.41 1817.24 53.340 265.430 1448.80 1566.20 31.91 S 721.49 W 5970715.93 N 498223.48 E 0.922 -31.91 1912.79 54.730 265.080 1504.92 1622.32 38.31 S 798.56 W 5970709.54 N 498146.41 E 1.485 -38.31 2008.97 55.790 265.930 1559.72 1677.12 44.50 S 877.35 W 5970703.36 N 498067.62 E 1.320 -44.50 2102.82 59.950 268.830 1609.63 1727.03 48.09 S 956.71 W 5970699.79 N 497988.25 E 5.147 -48.09 2198.17 60.450 269.500 1657.02 1774.42 49.29 S 1039.44 W 5970698.59 N 497905,52 E 0.804 -49.29 2293.60 64.280 267.280 1701.28 1818.68 51.70 S 1123.93W 5970696.20 N 497821.03 E 4.511 -51.70 2388.39 67.500 266.560 1740.00 1857.40 56.35 S 1210.31 W 5970691.56 N 497734.65 E 3.467 -56.35 2484.26 67.100 266.170 1776.99 1894.39 61.96 S 1298.58 W 5970685.96 N 497646.38 E 0.561 -61.96 2580.19 66.810 263.850 1814.55 1931.95 69.63 S 1386.51 W 5970678.30 N 497558.45 E 2.246 -69.63 2675.37 65.680 264.600 1852.89 1970.29 78.40 S 1473.18W 5970669.55 N 497471.78 E 1.389 -78.40 2771 .16 66.930 265.640 1891.39 2008.79 85.86 S 1560.58 W 5970662.10 N 497384.38 E 1.640 -85.86 2865.96 66.250 266.160 1929.05 2046.45 92.08 S 1647.35 W 5970655.89 N 497297.61 E 0.876 -92.08 2956.20 67.190 267.700 1964.72 2082.12 96.52 S 1730.12 W 5970651.47 N 497214.84 E 1.882 -96.52 3049.56 65.210 270.810 2002.40 2119.80 97.64 S 1815.51 W 5970650.35 N 497129.44 E 3.713 -97.64 3149.82 64.040 272.550 2045.37 2162.77 94.99 S 1906.06 W 5970653.01 N 497038.90 E 1.955 -94.99 3246.56 63.530 277.350 2088.12 2205.52 87.52 S 1992.49 W 5970660.50 N 496952.47 E 4.482 -87.52 3341.59 63.620 283.180 2130.44 2247.84 72.36 S 2076.17 W 5970675.67 N 496868.79 E 5.494 -72.36 3436.93 62.680 290.000 2173.54 2290.94 48.11 S 2157.63 W 5970699.93 N 496787.33 E 6.457 -48.11 3532.78 60.410 293.330 2219.22 2336.62 17.03 S 2235.94 W 5970731.02 N 496709.03 E 3.865 -17.03 3626.45 58.880 300.780 2266.60 2384.00 19.65 N 2307.86 W 5970767.72 N 496637.11 E 7.053 19.65 21 April, 2003 - 10:08 Page 20f5 DríJIQtJest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 Your Ref: 501032044900 Job No. AKZZ2323381, Surveyed: 2 April, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3721.85 60.210 304.150 2314.97 2432.37 63.80 N 2377.22 W 5970811.87 N 496567.76 E 3.349 63.80 3816.63 59.920 309.880 2362.29 2479.69 113.21 N 2442.77 W 5970861.30 N 496502.22 E 5.247 113.21 3912.13 59.330 315.280 2410.61 2528.01 168.92 N 2503.41 W 5970917.01 N 496441.58 E 4.917 168.92 4007.50 57.790 318.080 2460.36 2577.76 228.10 N 2559.24 W 5970976.20 N 496385.77 E 2.980 228.10 4102.17 59.710 327.000 2509.54 2626.94 292.28 N 2608.33 W 5971040.38 N 496336.68 E 8.304 292.28 4197.98 62.450 332.430 2555.90 2673.30 364.67 N 2650.55 W 5971112.79 N 496294.47 E 5.725 364.67 ---' 4293.01 63.480 339.550 2599.14 2716.54 441.93 N 2684.94 W 5971190.05 N 496260.09 E 6.760 441.93 4388.50 65.090 347.240 2640.62 2758.02 524.30 N 2709.46 W 5971272.42 N 496235.58 E 7.448 524.30 4483.14 67.730 353.980 2678.53 2795.93 609.81 N 2723.55 W 5971357.93 N 496221.51 E 7.096 609.81 4578.12 69.450 0.000 2713.22 2830.62 698.06 N 2728.16 W 5971446.18 N 496216.91 E 6.172 698.06 4673.54 70.740 6.750 2745.74 2863.14 787.55 N 2722.86 W 5971535.68 N 496222.22 E 6.787 787.55 4769.19 73.490 13.380 2775.14 2892.54 877.10 N 2706.93 W 5971625.23 N 496238.17 E 7.195 877.1 0 4864.54 75.470 19.620 2800.68 2918.08 965.13 N 2680.82 W 5971713.25 N 496264.28 E 6.638 965.13 4960.04 78.120 25.080 2822.51 2939.91 1051.07 N 2645.47 W 5971799.18 N 496299.65 E 6.219 1051.07 5054.96 80.340 28.320 2840.25 2957.65 1134.36 N 2603.57 W 5971882.46 N 496341.56 E 4.088 1134.36 5148.30 80.620 28.590 2855.69 2973.09 1215.29 N 2559.71 W 5971963.39 N 496385.43 E 0.414 1215.29 5243.54 81 .440 28.580 2870.54 2987.94 1297.90 N 2514.70 W 5972045.99 N 496430.46 E 0.861 1297.90 5340.78 81.440 27.990 2885.01 3002.41 1382.57 N 2469.13 W 5972130.66 N 496476.03 E 0.600 1382.57 5435.39 81.500 28.910 2899.04 3016.44 1464.83 N 2424.56 W 5972212.92 N 496520.62 E 0.964 1464.83 5523.32 81.600 28.450 2911.97 3029.37 1541.14 N 2382.82 W 5972289.21 N 496562.37 E 0.530 1541.14 5609.60 83.800 26.460 2922.93 3040.33 1617.07 N 2343.37 W 5972365.14 N 496601.83 E 3.426 1617.07 5702.26 87.350 26.330 2930.08 3047.48 1699.81 N 2302.31 W 5972447.88 N 496642.90 E 3.834 1699.81 5791.26 88.430 24.720 2933.35 3050.75 1780,07 N 2263.98 W 5972528.13 N 496681.24 E 2.177 1780.07 -~ 5881.50 85.780 24.240 2937.91 3055.31 1862.08 N 2226.64 W 5972610.14 N 496718.59 E 2.984 1862.08 5970.76 87.170 24.840 2943.40 3060.80 1943.13 N 2189.64 W 5972691.17 N 496755.60 E 1.696 1943.13 6065.37 85.260 25.690 2949.64 3067.04 2028.49 N 2149.35 W 5972776.54 N 496795.91 E 2.209 2028.49 6161.49 87.070 27.480 2956.07 3073.47 2114.25 N 2106.43 W 5972862.29 N 496838.84 E 2.645 2114.25 6257.12 88.560 26.800 2959.72 3077.12 2199.29 N 2062.84 W 5972947.32 N 496882.44 E 1.712 2199.29 6352.17 89.260 26.940 2961.53 3078.93 2284.06 N 2019.89 W 5973032.08 N 496925.40 E 0.751 2284.06 6447.52 92.930 25.950 2959.71 3077.11 2369.40 N 1977.44 W 5973117.42 N 496967.86 E 3.986 2369.40 6541.47 91.930 26.530 2955.72 3073.12 2453.59 N 1935.94 W 5973201.60 N 497009.37 E 1.230 2453.59 6608.78 92.500 25.910 2953.12 3070.52 2513.93 N 1906.23 W 5973261.94 N 497039.10 E 1 .251 2513.93 6697.62 89.930 26.070 2951.24 3068.64 2593.76 N 1867.31 W 5973341.76 N 497078.03 E 2.898 2593.76 6790.21 89.660 24.740 2951.57 3068.97 2677.40 N 1827.59 W 5973425.39 N 497117.76 E 1 .466 2677.40 6884.52 88.710 25.970 2952.91 3070.31 2762.61 N 1787.21 W 5973510.60 N 497158.15 E 1.648 2762.61 21 April, 2003 - 10:08 Page 3 of5 Dril/Quest 3.03.02.005 Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 6983.29 88.980 25.940 2954.90 3072.30 7078.59 92.290 24.630 2953.84 3071.24 7173.29 89.670 25.980 2952.23 3069.63 7269.21 86.670 26.140 2955.29 3072.69 7299.44 88.520 27.260 2956.56 3073.96 7360.00 88.520 27.260 2958.12 3075.52 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 Your Ref: 501032044900 Job No. AKZZ2323381, Surveyed: 2 April, 2003 ConocoPhillips Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (01100ft) 2851.40 N 1743.99 W 5973599.38 N 497201.38 E 0.275 2851.40 2937.55 N 1703.29 W 5973685.53 N 497242.09 E 3.735 2937.55 3023.14 N 1662.82 W 5973771.11 N 497282.57 E 3.112 3023.14 3109.26 N 1620.71 W 5973857.22 N 497324.70 E 3.132 3109.26 3136.24 N 1607.14 W 5973884.20 N 497338.27 E 7.152 3136.24 3190.05 N 1579.41 .W 5973938.01 N 497366.01 E 0.000 3190.05 Projected Survey ~d All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 117.4' MSL. Northings and Eastings are relative to 768' FSL & 556· FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 768' FSL & 556' FWL and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.218°(22-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 7360.00ft., The Bottom Hole Displacement is 3559.63ft., in the Direction of 333.660° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 7360.00 3190.05 N 1579.41 W Projected Survey ,__1 3075.52 21 April, 2003 - 10:08 Page 4 0'5 Dril/Quest 3.03.02.005 Western North Slope Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 Your Ref: 501032044900 Job No. AKZZ2323381, Surveyed: 2 April, 2003 ConocoPhí//ips Survey tool program for 2T-218 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 353.00 0.00 352.69 21 April, 2003 - 10:08 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 353.00 7360.00 352.69 Tolerable Gyro (2T-218 GYRO) 3075.52 AK-6 BP _IFR-AK (2T-218) '~ '- Page 5 0'5 Dril/Quest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ") c?]o 3 ~OJ7 22 -Ap r -03 Re: Distribution of Survey Data for Well 2T-218 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0,00' MD 0,00' MD 7,360,00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECE\VED APR 29 2003 A\as\(a æ¡ & Gas Cons. Commission AnchOtage \'< " (J ì lYJ () rcr Sperry-Sun Drilling Services ,.- Western North Slope ConocoPhillips Kuparuk 2T 2T-218 MWD Job No. AKMW2323381, Surveyed: 2 April, 2003 Survey Report 21 April, 2003 /~ Your Ref: 501032044900 Surface Coordinates: 5970747.74 N, 498944.97 E (70019' 52.7219" N, 150000' 30.8073" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ' Surface Coordinates relative to Project H Reference: 970747.74 N, 1055.03 W (Grid) Surface Coordinates relative to Structure: 365.31 N, 0.01 W (True) Kelly Bushing: 117.40ft above Mean Sea Level Elevation relative to Project V Reference: 117.40ft Elevation relative to Structure: 117.40ft sper"r"Y-sul'l DRILLING seRVIc:es A Halliburton Company Survey Ref: svy2004 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 MWD Your Ref: 501032044900 Job No. AKMW2323381, Surveyed: 2 April, 2003 ConocoPhi/lips Western Norlh Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 353.00 5.500 270.000 235.29 352.69 1.01 S 8.70W 5970746.73 N 498936.27 E -1.01 MWD Magnetic 498.45 8.270 265.600 379.67 497.07 1.82 S 26.11 W 5970745.93 N 498918.86 E 1.937 -1.82 594.24 10.110 270.870 474.23 591.63 2.22 S 41.38 W 5970745.53 N 498903.59 E 2.110 -2.22 683.81 13.840 269.590 561.84 679.24 2.17 S 59.96 W 5970745.57 N 498885.01 E 4.175 -2.17 ,..- 773.93 18.050 270.560 648.4 7 765.87 2.12 S 84.71 W 5970745.64 N 498860.26 E 4.681 -2.12 862.62 23.150 271.280 731.46 848.86 1.59 S 115.90 W 5970746.17 N 498829.07 E 5.757 -1.59 961.95 27.770 269.230 821.12 938.52 1.47 S 158.59 W 5970746.30 N 498786.38 E 4.734 -1.47 1053.91 29.140 269.100 901.97 1019.37 2.11 S 202.40 W 5970745.66 N 498742.57 E 1.491 -2.11 1148.43 32.000 268.650 983.35 1100.75 3.06S 250.45 W 5970744.72 N 498694.52 E 3.035 -3.06 1244.73 34.590 267.480 1063.83 1181.23 4.86S 303.28 W 5970742.92 N 498641.69 E 2.771 -4.86 1340.39 39.530 266.020 1140.15 1257.55 8.17 S 360.81 W 5970739.62 N 498584.16 E 5.245 -8.17 1435.27 44.700 265.870 1210.51 1327.91 12.67 S 424.26 W 5970735.13 N 498520.71 E 5.450 -12.67 1530.73 49.310 265.500 1275.59 1392.99 17.93 S 493.86 W 5970729.88 N 498451.10 E 4.838 -17.93 1625.91 52.960 269.280 1335.31 1452.71 21.24 S 567.86 W 5970726.58 N 498377.10 E 4.925 -21.24 1721.83 54.100 265.160 1392.34 1509.74 25.00 S 644.88 W 5970722.83 N 498300.09 E 3.652 -25.00 1817.24 53.340 265.670 1448.80 1566.20 31.15S 721.54 W 5970716.69 N 498223.42 E 0.906 -31.15 1912.79 54.730 265.340 1504.92 1622.32 37.21 S 798.64 W 5970710.64 N 498146.33 E 1.481 -37.21 2008.97 55.790 266.360 1559.72 1677.12 42.93 S 877.46 W 5970704.93 N 498067.50 E 1 .405 -42.93 2102.82 59.950 268.950 1609.63 1727.03 46.14 S 956.85 W 5970701.74 N 497988.12 E 5.010 -46.14 2198.17 60.450 269.880 1657.02 1774.42 46.98 S 1039.58 W 5970700.90 N 497905.38 E 0.996 -46.98 2293.60 64.280 267.440 1701.28 1818.68 48.99 S 1124.08 W 5970698.91 N 497820.89 E 4.608 -48.99 -- 2388.39 67.500 266.660 1740.00 1857.40 53.45 S 1210.47 W 5970694.46 N 497734.49 E 3.479 -53.45 2484.26 67.100 266.480 1776.99 1894.39 58.74 S 1298.76 W 5970689.18 N 497646.21 E 0.452 -58.74 2580.19 66.810 263.710 1814.55 1931.95 66.29 S 1386.70 W 5970681.65 N 497558.26 E 2.674 -66.29 2675.37 65.680 264.690 1852.89 1970.29 75.09 S 1473.36 W 5970672.85 N 497471.60 E 1.516 -75.09 2771.16 66.930 265.390 1891.39 2008.79 82.67 S 1560.75 W 5970665.29 N 497384.21 E 1 .466 -82.67 2865.96 66.250 266.030 1929.05 2046.45 89.18 S 1647.50 W 5970658.79 N 497297.46 E 0.948 -89.18 2956.20 67.190 267.530 1964.72 2082.12 93.83 S 1730.26 W 5970654.15 N 497214.70 E 1.848 -93.83 3049.56 65.210 270.360 2002.40 2119.80 95.42 S 1815.65 W 5970652.57 N 497129.31 E 3.491 -95.42 3149.82 64.040 272.260 2045.37 2162.77 93.36 S 1906.20 W 5970654.65 N 497038.75 E 2.072 -93.36 3246.56 63.530 276.390 2088.12 2205.52 86.82 S 1992.72 W 5970661.20 N 496952.24 E 3.866 -86.82 3341.59 63.620 282.910 2130.44 2247.84 72.57 S 2076.55 W 5970675.47 N 496868.41 E 6.144 -72.57 3436.93 62.680 290.450 2173.55 2290.95 48.20 S 2157.96 W 5970699.84 N 496787.00 E 7.123 -48.20 3532.78 60.410 293.630 2219.23 2336.63 16.61 S 2236.06 W 5970731.45 N 496708.91 E 3.757 -16.61 3626.45 58.880 301.050 2266.61 2384.01 20.44 N 2307.80 W 5970768.50 N 496637.17 E 7.026 20.44 ---"-------..------ 21 April, 2003 - 10:09 Page 20f5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 MWD Your Ref: 501032044900 Job No. AKMW2323381, Surveyed: 2 April, 2003 ConocoPhiflips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3721.85 60.210 303.840 2314.97 2432.37 64.56 N 2377.18 W 5970812.64 N 496567.80 E 2.881 64.56 3816.63 59.920 310.780 2362.31 2479.71 114.29 N 2442.46 W 5970862.38 N 496502.53 E 6.352 114.29 3912.13 59.330 314.880 2410.62 2528.02 170.28 N 2502.87 W 5970918.37 N 496442.13 E 3.755 170.28 4007.50 57.790 318.460 2460.37 2577.77 229.44 N 2558.70 W 5970977.54 N 496386.30 E 3.586 229.44 ~ 4102.17 59.710 327.530 2509.56 2626.96 294.00 N 2607.28 W 5971042.11 N 496337.73 E 8.435 294.00 4197.98 62.450 332.740 2555.91 2673.31 366.71 N 2648.97 W 5971114.82 N 496296.05 E 5.552 366.71 4293.01 63.480 339.520 2599.15 2716.55 444.06 N 2683.18 W 5971192.18 N 496261.86 E 6.446 444.06 4388.50 65.090 347.560 2640.63 2758.03 526.48 N 2707.48 W 5971274.60 N 496237.56 E 7.769 526.48 4483.14 67.730 354.480 2678.54 2795.94 612.08 N 2720.96 W 5971360.21 N 496224.10 E 7.257 612.08 4578.12 69.450 0.660 2713.24 2830.64 700.37 N 2724.68 W 5971448.50 N 496220.39 E 6.322 700.37 4673.54 70.740 7.630 2745.76 2863.16 789.79 N 2718.17 W 5971537.91 N 496226.91 E 6.999 789.79 4769.19 73.490 14.100 2775.16 2892.56 879.11 N 2700.99 W 5971627.23 N 496244.10 E 7.049 879.11 4864.54 75.470 20.680 2800.70 2918.10 966.72 N 2673.53 W 5971714.83 N 496271.58 E 6.965 966.72 4960.04 78.120 25.620 2822.53 2939.93 1052.16 N 2636.97 W 5971800.27 N 496308.15 E 5.749 1052.16 5054.96 80.340 28.290 2840.27 2957.67 1135.26 N 2594.70 W 5971883.37 N 496350.43 E 3.620 1135.26 5148.30 80.620 28.380 2855.70 2973.10 1216.29 N 2551.01 W 5971964.39 N 496394.13 E 0.315 1216.29 5243.54 81 .440 29.270 2870.55 2987.95 1298.70 N 2505.65 W 5972046.80 N 496439.50 E 1.262 1298.70 5340.78 81.440 28.950 2885.03 3002.43 1382.71 N 2458.87 W 5972130.80 N 496486.29 E 0.325 1382.71 5435.39 81.500 28.010 2899.06 3016.46 1464.95 N 2414.26 W 5972213.03 N 496530.92 E 0.985 1464.95 5523.32 81.600 28.450 2911 .98 3029.38 1541.58 N 2373.12 W 5972289.66 N 496572.07 E 0.508 1 541 .58 5609.60 83.800 25.280 2922.95 3040.35 1617.92 N 2334.46 W 5972365.98 N 496610.74 E 4.448 1617.92 ~-. 5702.26 87.350 26.100 2930.10 3047.50 1701.15N 2294.41 W 5972449.22 N 496650.80 E 3.931 1701.15 5791.26 88.430 24.920 2933.37 3050.77 1781.42 N 2256.11 W 5972529.48 N 496689.11 E 1.797 1781.42 5881.50 85.780 24.600 2937.93 3055.33 1863.25 N 2218.37 W 5972611.30 N 496726.86 E 2.958 1863.25 5970.76 87.170 25.190 2943.42 3060.82 1944.06 N 2180.87 W 5972692.11 N 496764.38 E 1.691 1944.06 6065.37 85.260 25.970 2949.66 3067.06 2029.21 N 2140.11W 5972777.25 N 496805.15 E 2.180 2029.21 6161.49 87.070 27.950 2956.09 3073.49 2114.68 N 2096.63 W 5972862.72 N 496848.64 E 2.787 2114.68 6257.12 88.560 27.030 2959.74 3077.14 2199.45 N 2052.52 W 5972947.48 N 496892.76 E 1.831 2199.45 6352.17 89.260 27.000 2961.55 3078.95 2284.11 N 2009.36 W 5973032.14 N 496935.93 E 0.737 2284.11 6447.52 92.930 26.070 2959.73 3077.13 2369.39 N 1966.77 W 5973117.40 N 496978.53 E 3.971 2369.39 6541.47 91.930 26.550 2955.74 3073.14 2453.53 N 1925.17 W 5973201.54 N 497020.14 E 1.180 2453.53 6608.78 92.500 26.420 2953.14 3070.54 2513.73 N 1895.18 W 5973261.74 N 497050.15 E 0.869 2513.73 6697.62 89.930 26.550 2951.26 3068.66 2593.22 N 1855.57 W 5973341.22 N 497089.77 E 2.897 2593.22 6790.21 89.660 25.290 2951.59 3068.99 2676.49 N 1815.10W 5973424.49 N 497130.25 E 1.392 2676.49 6884.52 88.710 26.810 2952.93 3070.33 2761.21 N 1773.69 W 5973509.20 N 497171.67 E 1.900 2761.21 --- ----~----------- 21 April, 2003 - 10:09 Page 30f5 DriflQlIest 3.03.02.005 Western North Slope Measured Sub-Sea Vertical Depth Inct. Azim. Depth Depth (ft) (ft) (ft) 6983.29 88.980 26.590 2954.92 3072.32 7078.59 92.290 25.150 2953.86 3071.26 7173.29 89.670 26.550 2952.24 3069.64 7269.21 86.670 25.740 2955.31 3072.71 ~ 7299.44 88.520 26.590 2956.58 3073.98 7360.00 88.520 26.590 2958.14 3075.54 Sperry-Sun Drilling Services Survey Report for Kuparuk 2T . 2T-218 MWD Your Ref: 501032044900 Job No. AKMW2323381, Surveyed: 2 April, 2003 ConocoPhí1lips Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 2849.43 N 1729.32 W 5973597.41 N 497216.05 E 0.353 2849.43 2935.16 N 1687.74 W 5973683.14 N 497257.64 E 3.788 2935.16 3020.36 N 1646.46 W 5973768.34 N 497298.93 E 3.137 3020.36 3106.41 N 1604.22 W 5973854.38 N 497341 .18 E 3.239 3106.41 3133.52 N 1590.90 W 5973881.49 N 497354.51 E 6.734 3133.52 3187.66 N 1563.81 W 5973935.62 N 497381.61 E 0.000 3187.66 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 117.4' MSL. Northings and Eastings are relative to 768' FSL & 556' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 768' FSL & 556' FWL and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.218°(22-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 7360.00ft., The Bottom Hole Displacement is 3550.59ft., in the Direction of 333.868° (True). Comments .-. Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7360.00 3075.54 3187.66 N 1563.81 W Projected Survey 21 April, 2003 - 10:09 Comment ------- Page 4 0'5 Dri/lQuest 3.03.02,005 ,..> Western North Slope Sperry-Sun Drilling Services Survey Report for Kuparuk 2T - 2T-218 MWD Your Ref: 501032044900 Job No. AKMW2323381, Surveyed: 2 April, 2003 ConocoPhillips Survey tool program for 2T-218 MWD f~--' From Measured Vertical Depth Depth (ft) (ft) 0.00 353.00 0.00 352.69 ~, 21 April, 2003 - 10:09 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 353.00 7360.00 352.69 Tolerable Gyro (2T-218 GYRO) 3075.54 MWD Magnetic (2T-218 MWD) Page 5 of5 o riff Quest 3.03.02.005 ) WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2T-218, > aÔ3-ù/-¡ I/II~ MayO?, 2003 AK-MW -2323381 1 LDWG forrnattedDisc with verification listing. ~I#: 50-103-20449-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-SunDrilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~.{~~ RECEIVED MAY 13 2003 Alasita Q¡.¡ & Gas Cons. CommiMn Anctunge ~li ® ~ L liD J fro J J: (~ ) Í !Æ'~!Æ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR i ~ AI¡ASIiA. OIL AlVD GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 333 W. "f"! AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 2T-218 ConocoPhillips Alaska, Inc. Permit No: 203-017 Surface Location: 768' FSL, 556' FWL, SEC. 1, TIIN, R8E, UM Bottomhole Location: 1325' FNL, 1087' FEL, SEC. 2, T11N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals· required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was. erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~r~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ~ day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill 0 Redrill 0 Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 768' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM At top of productive interval 2495' FSL, 1752' FWL, Sec. 2, T11 N, R8E, UM At total depth 1325' FNL, 1087' FEL, Sec. 2, T11 N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 1325' @ TD feet 2T -217 10' @ 350' ,// 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size 1 b. Type of well. Service Maximum hole angle 89.7° Hole Casing Weight 24" 16" 62.5# 13.5" 10.75" 45.5# 13.5" 10.75" 55.5# 8.75" 5.5" 17# Specifications Grade Coupling H-40 Weld L-80 BTCM 13Cr-80 V AM-Ace 13Cr SHL T Length 77' 4476' 1000' 1969' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: feet feet measured true vertical Casing Conductor Surface Production Length Size Cemented Liner Perforation depth: measured true vertical 6. Property Designation ADL 25569 ALK 2667 7. Unit or property Name Kuparuk River Unit 8. Well numb~' 2T -218 9. Approximate spud daty"" March 1, 2003 14. Number of acres in property 2560 17. Anticipated pressur;..-(see 20 AAC 25.035 (e)(2)) Maximum surface 738" At total depth (TVD) 1063 psig Setting Depth Exploratory D Stratigraphic Test Development Gas D Single Zone 5. Datum elevation (DF or KB) RKB 36.5' 1116.8' AMSL feet iI,-it; A- Z·''il01 Measured depth D o Development Oil 0 Multiple Zone D 10. Field and Pool Kuparuk River Field ,.... Tabasco Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Prop~d depth (MD and TVD) 7295 ' MD I 3070 ' TVD Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 0 0 77' 77' 225 cf AS I 0 0 4476' 2782' 690 sx AS lite, 820 sx Class G ./ 4476' 2782' 5476' 3022' see above 5326' 2996' 7295' 3070' gravel packed Plugs (measured) Junk (measured) True Vertical depth R.. ..\1'1\11(, >.\J \.T'" IY ¡J"". 11- ,,: , Ø"",. .:.... g,~, .~ E JþJ\ 2: J 2003 '~\~as~'aûij & Commissioner by order of the commission 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Shane Cloninger 265-6829 Signed~·J~ ~andY r:::ì Title: Kuparuk Drilling Team Leader Date l/"Gl/ô3 Prepared by Sharon Allsup-Drake Commission Use Only Permit Number I API number ..... "J. I Approval date f] ( Ofl-. Isee cover letter :2 0 ~ -' 0 i '7 50- / CJ _ '? - ¿ CJ <t 7' '7 7\ \ ) , I for other requirements Conditions of approval Samples required DYes ¡x No Mud log required' U Yes ~ No Hydrogen sulfide measures IX! Yes 0 No Directional survey required ~ Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D " €- ~ f- i!1 PE to 5'" OL~ 0 Other: Approved by ORIGINAL SIGNED BY MLSm Form 10-401 Rev. 12/1/85· ., j, t' : :1\" A' WI II U ¡ Ii i"! .. , p.it, Date ~/0/0J Submit in triplicate ) Application for Pøm1 )rill, We1l2T-218 Tabasco Horizontal Revision No.O Saved: 21-Jan-03 n~lmm~I~11 Permit It - 2T-218 Tabasco Horizontal Application for Permit to Drill Document M~ximizE Well Vghu ~m!~i~mllllmll Table of Contents 1. Well Name....................................................................... '" '" '"""""....................................... 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Location Sum mary ........................................................."" ""..........................................2 Requirements of 20 AAC 25.005(c)(2) ... ........ .... ........... .............. ........,.. ......... ....... .... ....... ....... ........... 2 Requirements of 20 AA C 25.050(b) .................................................................................................... 3 3. Blowout Prevention Equipment Information .............................................................3 Requirements of 20 AAC 25.005(c)(3) ....................................................... .......................................... 3 4. Dri IIi ng Hazards Information ........ .............. ..... .... .... ....."""."""" .... ................. ........... ....... 3 Requirements of 20 AAC 25.005 (c)(4) .... ...... ............... .... ............. ........ ................... .... ...................... 3 5. Procedure for Conducting Formation Integrity Tests """."........................................5 Requirements of 20 AAC 25.005 (c)(5) ...............................................................................................5 6. Casing and Cementing Program .................................."""""" ........................................ 5 Requirements of 20 AAC 25.005(c)(6) .......................................... ...................................................... 5 7. Diverter System Information ..... ............ ........... ..... ........."""." ......... ........ ...... ...... ..... .....5 Requirements of 20 AA C 25.005(c)(7) ................................................................................................ 5 8. Dri II i ng Flu id Prog ram................................................................................................. 6 Requirements of 20 AA C 25.005(c)(B) ................................................................................................ 6 9. Abnormally Pressured Formation Information ........................................................6 Requirements of 20 AAC 25.005 (c)(9) ............................................................................................... 6 1 O. Seis m ic Analysis.......................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) .... ... ... .... .... ... ...... ............ ............ ... ................ ............. .......... 6 11. Seabed Condition Analysis ......... ............. ......... ...... ................. ...... .......... .............. ....6 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 6 12. Evide nce of Bon ding ................................................................................................... 7 Requirements of 20 AAC 25.005 (c)(12) ...... ............ ...... .... ..... ........ ....... ... ......... ... ... ... ....... ..... ..... ....... 7 ~. [? ~,f'\ , !"JA w rt I u ¡ 1: .~ ~ Permitlt.doc Page 1 of 8 Printed: 21-Jan-03 ) Application for P·erm )rill, Well 2T-218 Tabasco Horizontal Revision No.O Saved: 21-Jan-03 13. Proposed Dri IIi ng Program... ...... ........ ........ ..... .... .......... """""" ........ .......... ............. .... .... 7 Requirements of 20 AAC 25.005 (c)(13) .................. ........ ......... ...... ....... ....... .......... ........ ............ ........ 7 14. Discussion of Mud and Cuttings Disposal and Annu~a~r Disposal........................8 Requirements of 20 AAC 25.005 (c)(14) .............................................................................................8 15. Attach ments. ..... ........... ..... ........ ........ ......... ...... ............. ....."""". .... ....... ........... ................8 Attachment 1 Directional Plan................................................................;. "..~·;,::·~z7............... ................. 8 Attachment 2 Drilling Hazards Summary............................................/II~;~Op/'Bookmark not defined. l'~' Attachment 3 Cement Loads and CemCADE Summary. ..................u."............................................ 8 Attachment 4 Well Schematic............................................................................................................. 8 IllWlilmlll1 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches/ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as ,::IJ!:"r -218 Tabasco Horizontal 2. Location Summary Requirements of 20 AAC 25. 005 (c)(2) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and Identified in the application: (2) a plat Identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface/ at the top of each objective formation/ and at total depth referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface/ referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUNey in the National Oceanic and Atmospheric Administration/ (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Su rface NGS Coordinates Northings: 5,970,747.74 1768' FSL, 556' FWL, Sec 1, T11N, R8E, UM RKB Elevation Eastings: 498.944.97 Pad Elevation 116.9' AMSL 80.4' AMSL Location at Top of Productive Interval (Tabasco) NGS Coordinates Northings: 5,972,476.31 2,495' FSL, 1,752' FWL, Section 2, T11N, R8E, UM // Eastings: 496,636.33 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 5,962 3,052 2,935 Location at Total Depth 1,325' FNL, NGS Coordinates Northings: 5,973,935 Eastings: 497,300 1087' FEL, Section 2, T11N, R8E, UM Measured Depth, RKB: 7,295 Total Vertical Depth, RKB: 3,070 Total Vertical Depth, 55: 2,953 and C.. n'G/~' 1\ 1 i .. i ~v ¡..;~ ... Permitlt.doc Page 2 of 8 Printed: 21-Jan-03 ) Application for Perm )rill, Well 2T-218 Tabasco Horizontal Revision No.O Saved: 21-Jan-03 (D) other information required by 20 MC 25. 050(b); Requirements of 20 AA C 25. 050(b) If a well is to be intentionally deviated,. the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25. 005(c) (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 MC 25.035, 20 AAC 25.036, or 20 MC 25.037, as applicable; ^ Please see "Diagram and Description of the Blowout Prevention Equliprnent for Doy~'n 19. Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered,. criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Tabasco sands in the 2T pad area vary from 0.36 psi/ft, or 6.7 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby 2T-209 well. The maximum potential surface pressue (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Tabasco formation is 738 psi, calculated thusly: MPSP =(2953 ft)(0.36 - 0.11 psi/ft) =738 psi / (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; 2T-218 Tabasco Horizontal - Drilling Hazards Summary: O~'G~~'A I .. ' fl~ > '. )11 \~¡g\~l~- Permitlt.doc Page 3 of 8 Printed: 21-Jan-03 ) Application for Perm' )rill, We1l2T-218 Tabasco Horizontal Revision No.O Saved: 21-Jan-03 Potential Hazards Hydrogen Sulfide- H2S: 200 ppm has been measured on 1this drill pad. Hydrates- This is considered a hydrate potential area. Lost Circulation - Reservoir pressure equals 6.7ppg equivalent mud weight. Stuck Pipe, hole packing off. SAFETY CONCERNS 1. Hold pre-Spud Safety meetings with all crews. · Hydrogen (HzS) precautions, air-packs, alarms, buddy system. · Scott-Air Packs are available, and strategically 10catE~d. · Have Evacu-8 canisters available in secondary arøas., · Make sure all camp personnel have had Air-Pack and HzS training. · Have an adequate number of windsocks on the rig to ble noticeable from the rig, camp, shop and any other pertinent areas. · Post the current wind direction at the start of each tour at the rig floor. 2. Hold Simultaneous Operations meetings with Pad workers, wireline operators and any construction workers that have plans to be working on the 2T Pad. 3. Always use the "Buddy System" when working away from the I"ig floor. 4. Have a Well Control "Kill Sheet" updated and filled out by the! Company man as well as on the Kill Sheet board updated daily by the rig crews. 5. Spotters should make tourly inspections around the rig looking for any spills or possible gas broaching the ground surface. 6. Safety Drills are to be carried out daily by each rig crew. rv~.ake sure everyone knows where their positions and location assignments will be for both well controll and H2S emergencies. Record drills on IADC sheets. 7. Short, Pre-Job safety meeting are to be held prior to starting any new operation. Include any pertinent Service company representatives. 8. All personnel not regularly assigned to the Rig are to be signed in, accounted for, and made sure to have proper rig orientation prior to commencing work. 9. The STOP program, Technical Limits, as well as Safety Audits are to be used for this operation. ]R~l';""~L ;',¡ ,1t'.1 ,~ \,' .;~ .~ :\ L 1iI-.'I t, .' ',', ' ( . I !~ ~~,..1 ;f k' ~! .1- J ' Permitlt.doc Page 4 of 8 Printed: 21-Jan-03 ) Application for Perm }rill, Well 2T-218 Tabasco Horizontal . Revision No.O Saved: 21-Jan-03 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f); The Frac Gradient for the Tabasco is 11.9 ppg EMW, and an FIT (formation integrity test) of 11.5 ppg EMW is planned. The FIT will be performed in accordance with the LOT / FIT procedure, that Conoco- Phillips Alaska has on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted liner, pre- perforated liner, or screen to be Ji1stalled; Casing and Cementing Program Hole / Top Btm Csg/Tbg Size Weight Length MD/TVD (F¿K,s) MD/TVD (RKB) 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 77 0/0 77 / 77 Cemented to / surface with 225 cf ArcticSet 1 10-3/4" 13-'12" 45.5 L-80 BTC,AB 4476 0/0 4476/2782 Cemented to Modified Surface with 10-3/4" 13- V2" 55.5 13Cr- YAM-Ace 1000 4476/ 2782 5476/3022 690 sx ASLite 80 Lead, 820 sx Class G Tail 5-'12" 8-3/4" 17 13Cr SHLT 1969 5326 / 2996 7295/3070 Gravel Packed 4- '12" 10-3/4" 12.6 L-80 NSCT 5192 0/0 5027 / 2944 csg See also Attachment 3: Cement Loads and CemCADE Summary. 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commissIon and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2)¡ Please see "Diagram And Description of the Diverter System For Doyan Rig 19", placed on file with the Commission. J R,; I, I': l@fVA·,1 U ".. Permitlt.doc Page 5 of 8 Printed: 21-Jan-03 ) Application for Pørm' )rill, Well 2T-218 Tabasco Horizontal i Revision No.O Saved: 21-Jan-03 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description ofthe drilling fluid system, as required by 20 MC 25.033; Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Spud to Base of Permafrost Base of Permalf¡'"O!s to TD Base of Permafros to TD Initial Value Final Value Initial Value Final Val/ Initial Value Final Value Density (ppg) 8.5 9.5 9.5 9.6 9.1 9.3 Funnel Viscosity +150 +150 65 100 47 50 (seconds) Yield Point 30 50 25 30 30 30 (cP) Plastic Viscostiy 8 15 8 15 10 10 (lb1100 sf) 10 second Gel 10 30 10 24 9 12 Strength (lb1100 sf) 10 minute Gel 21 53 21 ' 53 12 14 Strength (lb1100 sf) pH 8 9 8 9 9.0 9.5 API Filtrate(cc) 8 15 5.5 8 4 6 Solids (%) 5 8 5 8 Tr tr *9.8 ppg if hydrates are encountered Please see "Diagram of Mud System, Doyan 19", placed on file with the Commission with the Application for Permit to Drill for well 2G-17, dated --- This drilling fluid system of Doyon 19 consists of: (2) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1,005 barrel capacity, Pill Pits 20 + 40 bbl, Trip Tank - 100 bbl, (3) Derrick High G Shakers, Brandt 2 Cone Desander (1000 gpm), Derrick Model 20 cone Mud Cleaner, Derrick high speed Centrifuge, Degassers, Derrick Flow Line Cleaner, Burgess vaccum degasser. p\rr System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: C.. ,J"~ G ¡ 1'\1 /, ; > 1 . '114_ Permitlt.doc Page 6 of 8 Printed: 21-Jan-03 ) Application for Perm, )rill, Well 2T-218 Tabasco Horizontal / Revision No.O Saved: 21-Jan-03 (11) for a well drilled from an offstlore platform/ mobile bottom-founded structure/ jack-up rig/ or floating drilling vesse¿ an analysis of seabed conditions as required by 20 AAC 25.061(b)/ Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been me~' Evidence of bonding for Conoco-Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items/ except for an Item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Move In / Rig Up Doyon Rig 19 /~ 2. Nipple Up and function/pressure test the Diverter System. Test remaining BOPE to 250/5,000 psi. /" 3. Pick Up 9-%" Bit, 8" Motor/MWD, and BHA. 4. Drill Build Section of Surface hole to ±1 ,500', or the base of the permafrost. ~ 5. Circulate Bottoms Up, Short trip to check BHA and bit. 6. RIH, orient, drill ahead to the ± 5,476' casing point, sweep hole, CBU, short trip to ,/' 1,500', RIH, rotate and circulate hole clean. Condition mud for casing job. POOH. 7. RU, Run 10-%" casing,Žirculate and cement the same. /' 8. Wait on cement while, NU casing-head and BOPs. Tlest BOPE. 9. PU 8-%" PDC bit, Motor, MWD/LWD, BHA, and R:IH,. / 10. Drill out Float Collar and all but 10' of shoe track. Prøssure test casing to 3,000 psi. ,-/" 11. Drill out Float Shoe and ±20' of new formation. Perform Leak Off Test. 12. Drill Horizontal production hole to 7,295' md. /' 13. Spot liner running pill, POOH and LD excess driUpip1e. 14. PU, RIH with 5-%" liner and screen. Displace hole to brine. /' 15. Set packer. Pump gravel pack. 16. POOH, lay down workstring and drillpipe. 17. Run pump and completion assembly, circulate and spot corrosion inhibitor. 18. Land tubing and run in lock down screws on hanger, Pressure test packer and tubing/casing annulus to 3,000 psi. Shear out RP valve. / 19. ND/NU, freeze protect, RD, Release rig. OD"~Jr\~~L "" . . /,' '1$( :; : , ~ ~ .J , ... " , . ... \.1 :(r," " § i j ~."ll , ~ !. ~ t!._ Permitlt.doc Page 7 of 8 Printed: 21-Jan-03 ') Application fO!" Perm:¡ } ill , We1l2T-218 Tabasco Horizontal I Revision No.O Saved: 21-Jan-03 13. Discussion of Mud and Cuttings Disposal and Annu~q:U' IDisposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how tl7e operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Conoco-Phillips Alaska does not intend to request authorization for the use of this well for annular /' disposal operations. 14. Attach ments Attachment 1 Directional Plan (12 pages) Attachment 2 Cement Loads and CemCADE Summary (1 page) Attachment 3 Well Schematic. (1 page) O'-""·~ .;~ ~~~ '''L rJ , . .:: ,j! t\ ,.,' "-à j \¡A ~ ~ I.J,¡I"":\ Permitlt.doc Page 8 of 8 Printed: 21-Jan-03 Q ::0 --.,,- ~ ~-"= :::::~::: L~ r-- Sperry-Sun Drilling Services ConocoPhi//ips A/ask North S/ope,/ß}-:^, Kuparl!.k. ""B.,~\ ;"ør.,V,.."· init' (2T - Télþ~S~Q,~flor¡ionta/) 2T~~18 (wp01) _c/ . Proposal Report 19 January, 2003 Your Ref: 2T Tabasco Horizontal from 2T-218 Slot Surface Coordinates: 5970747.74 N, 498944.97 E (70019'52.7219/1 N, 150000'30.8073" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~--- Kelly Bushing: 116.80ft above Mean Sea Level =1--=1 ., .~ .., Ø:B:I:¡;:g:ø1l~Il]:r:D IÜI{oì:ì~ Oœë1J"ád¥ Proposal Ref: pro 10012 DrillQuest 3.03.02.002 Page 2 of7 19 January, 2003 - 12:57 Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 - 2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg . Vertical , Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section C'omment (ft) (ft) (ft) (ft) (ft) (ft) (ft) '("110Oft) 0.00 0.000 0.000 -116.80 0.00 O.OON 0.00 E 5970747.74 Nx( 498!lAlt.9'1iÈ 0.00 8HL (768' F8L & 556' FWL, See 1· T11 N-R8E) 100.00 0.000 0.000 -16.80 100.00 0.00 N 0.00 E ;~;g;:;:;: ~"'i)t\.:~~BI~~;;j~; "{¡if} .000 0.00 200.00 0.000 0.000 83.20 200.00 O.OON 0.00 E 0.000 0.00 300.00 0.000 0.000 183.20 300.00 O.OON 0.00 E 597fì~'llù7 4 N \¡glt498944.97 E 0.000 0.00 Begin Dir @ 3.000/100ft in 13-11')11 Hole: 300.00ft MD, 300.00ft T 400.00 3.000 266.780 283.15 399.95 0.158 2.61 W 59707 4 7:~~iN 498942.36 E 3.000 -0.15 ",,.,,./ 500.00 6.000 266.780 382.83 499.63 0.598 10.45 W 5970747.15 N 498934.52 E 3.000 -0.59 600.00 9.000 266.780 481.97 598.77 1.328 23.48 W 5970746.42 N 498921.49 E 3.000 -1.32 633.33 10.000 266.780 514.84 631 .64 ,,1.638 28.97 W 5970746.11 N 498916.00 E 3.000 -1.63 Increase in Dir Rate @ 5.00/100ft : 633.33ft MD, 631.64ft TVD 700.00 13.333 266.780 580.12 696.92 42.43 W 5970745.36 N 498902.54 E 5.000 -2.39 800.00 18.333 266.780 676.30 793.10 69.66 W 5970743.83 N 498875.31 E 5.000 -3.92 a 900.00 23.333 266.780 769.73 886.53 8 105.16 W 5970741.84 N 498839.81 E 5.000 -5.92 =a 1000.00 28.333 266.780 859.71 976.51 8.368 148.65 W 5970739.40 N 498796.32 E 5.000 -8.36 ~----.-"'G:!I 1100.00 33.333 266.780 1062.35 11 .24 8 199.81 W 5970736.53 N 498745.16 E 5.000 -11.24 '7:;"'0) 1200.00 38.333 266.780 r'~'9 14.53 8 258.24 W 5970733.25 N 498686.73 E 5.000 -14.53 1300.00 43.333 266.780 12Hr:03 18.20 8 323.50 W 5970729.59 N 498621 .47 E 5.000 -18.20 "~r..!..~ -'';:i:J 1400.00 48.333 266)180 1288.69 22.23 8 395.10 W 5970725.57 N 498549.87 E 5.000 -22.23 1453.33 51.000 266.780 1323.20 24.51 S 435.68 W 5970723.29 N 498509.28 E 5.000 -24.51 End Dir, 8tart 8ail @ 51.0° : ":~~ -r" '. 1453.33ft MD, 1323.20ft TVD ,-' ....-, ~-- 1500.00. 51.oøO c·:2e6/Zßø 1235.77 1352.57 26.55 8 471.89 W 5970721.26 N 498473.07 E 0.000 -26.55 1600.00,' 51 .000 ?e6.7&Q, 1298.70 1415.50 30.91 8 549.49 W 5970716.90 N 498395.48 E 0.000 -30.91 1649.73. ~1.000 266.780 1330.00 1446.80 33.08 8 588.08 W 5970714.74 N 498356.89 E 0.000 -33.08 Base Pennafrost 1700.ocf· 51.000 266.780 1361.63 1478.43 35.28 8 627.08 W 5970712.55 N 498317.89 E 0.000 -35.28 ~/ 1800.00 51.000 266.780 1424.57 1541.37 39.64 8 704.67 W 5970708.20 N 498240.29 E 0.000 -39.64 1900.00 51 .000 266.780 1487.50 1604.30 44.01 8 782.26 W 5970703.84 N 498162.70 E 0.000 -44.01 2000.00 51 .000 266.780 1550.43 1667.23 48.37 S 859.85 W 5970699.49 N 498085.11 E 0.000 -48.37 Resume Dir @ 5.00/100ft : 2000.00 MD, 1667.23ft TVD 2015.33 51.767 266.780 1560.00 1676.80 49.05 8 871 .82 W 5970698.82 N 498073.15 E 5.000 -49.05 Top Ugnu C 2100.00 56.000 266.780 1609.89 1726.69 52.89 8 940.09 W 5970694.98 N 498004.88 E 5.000 -52.89 2200.00 61.000 266.780 1662.13 1778.93 57.68 S 1025.19 W 5970690.21 N 497919.77 E 5.000 -57.68 2300.00 66.000 266.780 1706.73 1823.53 62.708 1114.51 W 5970685.20 N 497830.45 E 5.000 -62.70 2324.40 67.220 266.780 1716.42 1833.22 63.96 8 1136.87 W 5970683.94 N 497808.09 E 5.000 -63.96 End Dir, 8tart Sail @ 67.2° : 2324.40ft MD, 1833.22ft TVD 2400.00 67.220 266.780 1745.69 1862.49 67.87 S 1206.47 W 5970680.04 N 497738.50 E 0.000 -67.87 Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 - 2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical , Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section COmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (oI10Oft) 2500.00 67.220 266.780 1784.41 1901.21 73.05 S 1298.52 W 5970674.87 N ".. 4;~76~~4",J¡: \~;¡I~g:~~~ -73.05 2600.00 67.220 266.780 1823.13 1939.93 78.23 8 1390.57 W 5970669.70 NIII; "'k5íl¡~II, -78.23 2700.00 67.220 266.780 1861 .85 1978.65 83.41 8 1482.63 W 5970664.54 N jilti, 49'''.;33ir <;7;'0.000 -83.41 2800.00 67.220 266.780 1900.57 2017.37 88.59 8 1574.68 W 5970659.37 N \¡¡rœ~t4973(t}:28 E 0.000 -88.59 2900.00 67.220 266.780 1939.29 2056.09 93.77 8 1666.74 W 5970654.21 N<%';~'!~7278.22 E 0.000 -93.77 3000.00 67.220 266.780 1978.01 2094.81 98.95 8 17§ª..79 W 5970649.04 N 497186.17 E 0.000 -98.95 ~ 3005.1 5 67.220 266.780 1980.00 2096.80 99.21 8 1763':53 W 5970648.77 N 497181.43 E 0.000 -99.21 K-13 3077.86 67.220 266.780 2008.15 2124.95 102.98 S 1830.46 W 5970645.02 N 497114.49 E 0.000 -102.98 Resume Oir @ 5.68°/100ft : 3077.86ft MO, 2124.95ft TVO 3100.00 66.772 268.057 2016.81 2133.61 "....1850.82'1/1I 5970644.10 N 497094.13 E 5.680 -103.90 3200.00 64.881 273.928 2057.78 2174.58 \;1111;,.1941 .98 W 5970645.66 N 497002.97 E 5.680 -102.35 C~) 3300.00 63.229 279.973 2101.57 2218.37 2031 .19 W 5970656.51 N 496913.77 E 5.680 -91.51 3351.35 62.481 283.141 2125.00 2241 .80 2075.95 W 5970665.67 N 496869.01 E 5.680 -82.36 Top West 8a!< 0 ":="'\0 3400.00 61.840 286.181 2147.72 2264.52 8 2117.56 W 5970676.56 N 496827.40 E 5.680 -71 .48 ¡:~~~~ ·--or"..:..:;" 3500.00 60.737 292.535 2195.80 2312.60 42.46 8 2200.25 W 5970705.59 N 496744.71 E 5.680 -42.46 ._,..:._--",,:~ ,'~ 3600.00 59.941 299.008 2245.32 2362.12 4.728 2278.45 W 5970743.34 N 496666.52 E 5.680 -4.72 "'-------- -;:'-.i ~-~-n 3700.00 59.466 305.564 2295.81 41.35 N 2351.39 W 5970789.42 N 496593.58 E 5.680 41.35 3800.00 59.322 312.162 2346.77 2463.57 95.30 N 2418.36 W 5970843.39 N 496526.63 E 5.680 95.30 - -"-_4-_","-ç..,¡: 3900.00 59.511 318i7'þ7E.. <g397.69 2514.49 156.62 N 2478.68 W 5970904.71 N 496466.31 E 5.680 156.62 ~~ 4000.00 60.030 3~5~305{ '2~8.07 2564.87 224.68 N 2531.79 W 5970972.78 N 496413.21 E 5.680 224.68 ~ 4100.00 60.868 331.763 2497.43 2614.23 298.83 N 2577.14 W 5971046.94 N 496367.87 E 5.680 298.83 4200.00 ·..62.011 338.099 2545.28 2662.08 378.34 N 2614.31 W 5971126.45 N 496330.72 E 5.680 378.34 4300.00, ~A37.., 344.286 2591.14 2707.94 462.43 N 2642.91 W 5971210.54 N 496302.12 E 5.680 462.43 4331 .26 83.937 . 346.187 2605.00 2721.80 489.52 N 2650.05 W 5971237.64 N 496294.99 E 5.680 489.52 Base West 8a!< --~ 4400.00 65.123 ' ·350.307 2634.57 2751.37 550.26 N 2662.68 W 5971298.38 N 496282.37 E 5.680 550.26 4500.00 67.043 356.156 2675.14 2791 .94 640.99 N 2673.41 W 5971389.10 N 496271 .65 E 5.680 640.99 4600.00 69.172 1.832 2712.45 2829.25 733.71 N 2675.00 W 5971481.82 N 496270.07 E 5.680 733.71 4700.00 71.482 7.343 2746.14 2862.94 827.52 N 2667.44 W 5971575.63 N 496277.64 E 5.680 827.52 4800.00 73.947 12.703 2775.87 2892.67 921.49 N 2650.80 W 5971669.60 N 496294.30 E 5.680 921.49 4900.00 76.542 17.929 2801 .35 2918.15 1014.71 N 2625.25 W 5971762.81 N 496319.87 E 5.680 1014.71 5000.00 79.243 23.040 2822.34 2939.14 1106.25 N 2591 .02 W 5971854.35 N 496354.10 E 5.680 1106.25 5027.47 80.000 24.427 2827.29 2944.09 1130.98 N 2580.15 W 5971879.09 N 496364.98 E 5.680 1130.98 End Oir, 8tart 8ail @ 80.0° : 5027.47ft MO, 2944.000 TVO 5100.00 80.000 24.427 2839.88 2956.68 1196.02 N 2550.61 W 5971944.12 N 496394.53 E 0.000 1196.02 5200.00 80.000 24.427 2857.25 2974.05 1285.68 N 2509.88 W 5972033.78 N 496435.27 E 0.000 1285.68 5300.00 80.000 24.427 2874.61 2991.41 1375.35 N 2469.16 W 5972123.44 N 496476.00 E 0.000 1375.35 5400.00 80.000 24.427 2891 .97 3008.77 1465.01 N 2428.43 W 5972213.10 N 496516.74 E 0.000 1465.01 19 January, 2003 -12:57 Page 3 of7 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 Page 4 of 7 19 January, 2003 - 12:57 Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 -2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg VerticaJ Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section COmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5476.50 80.000 24.427 2905.26 3022.06 1533.61 N 2397.28 W 5972281.69 Nit: 496d~~Ø'¡IE nO.OOO 1533.61 10-3/4" Csg Pt; Begin 8-3/4" Hole: 5476.50' MD, 3022.06' TVD (2301' FSL, 1840' FEL Sec 2-T11 N-R8E) 10 3/4" Casing 5500.00 80.000 24.427 2909.34 3026.14 1554.68 N 2387.71 W 5972302.76 N \¡ftl¡'~6557.48 E 0.000 1554.68 5519.41 80.000 24.427 2912.71 3029.51 1572.08 N 2379.80 W 5972320.16 N '1JQ§p65.39 E 0.000 1572.08 Begin Dir @ 3.00/100ft : 551 F MD, 3029.51ft TVD ~ ,--' 5564.40 81 .350 24.427 2920.00 3036.80 1612.51 N 2361.45 W 5972360.58 N 496583.75 E 3.000 1612.51 C-80 5600.00 82.418 24.427 2925.03 3041 .83 1644.59 N 2346.87 W 5972392.66 N 496598.33 E 3.000 1644.59 5692.42 85.190 24.427 2935.00 3051.80 1728.24 N 2308.88 W 5972476.31 N 496636.33 E 3.000 1728.24 T ABASCD Intersect: 5692.42ft MC 3051.80ft TVD (2495' FSL & 1752' FWL, Sec. 2-T11 N-R8E) Top Tabasco Sand 5692.74 85.200 24.427 2935.03 2308.75 W 5972476.60 N 496636.47 E 3.000 1728.53 Decrease in Dir Rate @ 2.0001100ft a 5692.74ft MD, 3051.83ft TVD Target - Tabasco Horz (Heel) ::Q 5700.00 85.345 24.427 2935.62 1735.12 N 2305.76 W 5972483.18 N 496639.46 E 2.000 1735.12 ~:-;-~-:'-~ 5800.00 87.345 24.427 2942.00 1825.98 N 2264.49 W 5972574.04 N 496680.74 E 2.000 1825.98 c~~-~.~ 5900.00 89.345 24.427 2944.89 3061.69 1916.98 N 2223.16 W 5972665.04 N 496722.08 E 2.000 1916.98 ~~ ~}, ~~=- - --Da 5900.54 89.356 24.427' "2944.89'" 3061.69 1917.48 N 2222.93 W 5972665.53 N 496722.31 E 2.000 1917.48 Continue Dir @ 2.00/100ft : 5900.5¿ ~~~~: MD, 3061.69tt TVD ~....r.;_._ 5916.27 89.669.24;46.1 2945.03 3061.83 1931.80N 2216.42 W 5972679.85 N 496728.82 E 2.000 1931.80 End Dir, Start Sail @ 89.70 : ,~~ 5916.27ft MD, 3061.83ft TVD ~"""""'- 6000.00 : 89.669 3g4.4Q't 2945.51 3062.31 2008.01 N 2181.75 W 5972756.06 N 496763.50 E 0.000 2008.01 ~ 6100.00 89.669 '24.461 2946.09 3062.89 2099.03 N 2140.35 W 5972847.07 N 496804.92 E 0.000 2099.03 6200.00 -89.669 24.461 2946.67 3063.47 2190.06 N 2098.94 W 5972938.09 N 496846.34 E 0.000 2190.06 -~ 6300.00 89.669 24.461 2947.25 3064.05 2281.08 N 2057.53 W 5973029.11 N 496887.76 E 0.000 2281.08 6400.00 89.669 24.461 2947.82 3064.62 2372.10 N 2016.13W 5973120.12 N 496929.18 E 0.000 2372.10 6500.00 89.669 24.461 2948.40 3065.20 2463.12 N 1974.72 W 5973211 .14 N 496970.59 E 0.000 2463.12 6600.00 89.669 24.461 2948.98 3065.78 2554.15 N 1933.32 W 5973302.16 N 497012.01 E 0.000 2554.15 6700.00 89.669 24.461 2949.56 3066.36 2645.17 N 1891.91 W 5973393.18 N 497053.43 E 0.000 2645.17 6800.00 89.669 24.461 2950.14 3066.94 2736.19 N 1850.50 W 5973484.19 N 497094.85 E 0.000 2736.19 6900.00 89.669 24.461 2950.71 3067.51 2827.22 N 1809.10 W 5973575.21 N 497136.27 E 0.000 2827.22 7000.00 89.669 24.461 2951 .29 3068.09 2918.24 N 1767.69 W 5973666.23 N 497177.69 E 0.000 2918.24 7100.00 89.669 24.461 2951 .87 3068.67 3009.26 N 1726.28 W 5973757.24 N 497219.11 E 0.000 3009.26 7200.00 89.669 24.461 2952.45 3069.25 3100.29 N 1684.88 W 5973848.26 N 497260.53 E 0.000 3100.29 DrillQuest 3.03.02.002 Page 50f7 End Dir, Start Sail @ 67.2° : 2324.40ft MD, 1833.22ft TVD Resume Dir @ 5.68°/100ft: 3077.86ft MD, 2124.95ftTVD End Dir, Start Sail @ 80.0° : 5027.47ft MD, 2944.09ft TVD 10-3/4" Csg Pt; Begin 8-314" Hole: 5476.50' MD, 3022.06' TVD (2301' FSL, 1840' FEL Sec 2- T11 N-R8E) Begin Dir @ 3.00/100ft: 5519.41ft MD, 3029.51ftTVD ~~/ 0.000 3187.03 Total Depth: 7295.30ft MD, 3069.80ft TVD (1325' FNL & 1087' FEL, Sec. 2- T11 N-R8E) 7" Casing Target - Tabasco Horz (Toe) Comment Dogleg Vertical Rate Section (0/1 OOft) ConocoPhillips SHL (768' FSL & 556' FWL, Sec 1-T11 N-R8E) Begin Dir @ 3.000/100ft in 13-1/2" Hole: 300.00ft MD, 300.00ftTVD Increase in Dir Rate @ 5.00/100ft : 633.33ft MD, 631.64ft TVD End Dir, Start Sail @ 51.0° : 1453.33ft MD, 1323.20ft TVD Resume Dir @ 5.0°/1 OOft: 2000.00ft MD, 1667.23ft TVD Comment 1136.87 W 1830.46 W 2580.15 W 2397.28 W 2379.80 W 63.96 S 102.98 S 1130.98 N 1533.61 N 1572.08 N 1 833.22 2124.95 2944.09 3022.06 3029.51 19 January, 2003 - 12:57 2324.40 3077.86 5027.47 5476.50 5519.41 Measured Depth >(ft) 0.00 300.00 633.33 1453.33 2000.00 Comments Based upon Minimum Curvature type calculations, at a Measured Depth of 7295:'30ft., The Bottom Hole Displacement is 3586.72ft., in the Direction of 332.693° (True). 0.00 E 0.00 E 28.97 W 435.68 W 859.85 W 0.00 N O.OON 1.63 S 24.51 S 48.37 S ·0.00 300.00 631 .64 1323.20 1667.23 Magnetic Declination at Surface is 25.283°(17-Jan-03) Station Coordinates WD Northings Eastings (ft). (ft) (ft) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 768' FSL & 556' FWL and calculated along an Azim All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True N Vertical depths are relative to RKB = 116..8' MSL. Northings and Eastings are relative to T~' Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Global Coordinates Northings Eastings (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) 5973935.00 1645.42 W 3187.03 N Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 7295.30 89.669 24.461 2953.00 3069.80 Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 -2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot [j--- -'-;:~---... '... ~~'- ":-~ ~;-,- f~ .j ~:'=:'-''''~ a ::rj DrillQuest 3.03.02.002 .~ Dip Up-Dip Formation Name Angle Dim. 588.08 W 0.000 359.992 Base Permafrost 871.82 W 0.000 359.992 Top Ugnu C 1763.53 W 0.000 359.992 K-13 2075.95 W 0.000 359.992 Top West Sak D 2650.05 W 0.000 359.992 Base West Sak 2361.45 W 0.000 359.992 C-80 2308.88 W 0.000 359.992 Top Tabasco Sand Page 60i7 1612.51 N 1728.24 N ~08 .~05 S 9.21 S 82.36 S 489.52 N Northings eft) TABASCO Intersect: 5692.42tt,;MíJ;~1~1.80ft 1WEIt;{f495' FSL & 1752' FWL, Sec. 2-T11 N-R8E) Decrease in Dir Rate @ 2.0Qo/100ft : 5~2.74ft MD';'8051.83ft TVD Continue Dir @2.00/1 00ft : 5900.54ft rv1tr;'3061.69ft TVD End Dir, Start Saif @ 89.7°: 5916.27ft MD, 3061.83ft TVD Total Depth: 7295.30ft fv1º~~9.80ft TVD (1325' FNL & 1087' FEL, Sec. 2-T11N-R8E) -- ConocoPhillips 1330.00. 1560.00 . ,1~JJº~D() ?125:Qo . "\?f?O§.tQº 2~?º.00 2935.00 Sub-Sea Depth (ft) 19 January, 2003 - 12:57 5564.4-0 ., 30qß.{!0 5692-42~' . 'fß051.80';/' -.......~"---.-..-.r-¡ ~ 1446.80 1676.80 2096.80 2241 ,80 2721;80 1649.73 2015.33 3005.1 5 3351.35 4331.26 f'......,. _, ~.:...~.-., Vertical Depth eft) Measured Depth (ft) <:::> :1:) Formation Toos Measured Station Coordinates Depth TVD Northings Eastings (ft) eft) Cft) eft) 5692.42 3051.80 1728.24 N 2308.88 W 5692.74 3051.83 1728.53 N 2308.75 W 5900.54 3061.69 1917.48 N 2222.93 W 5916.27 3061.83 1931.80N 2216.42 W 7295.30 3069.80 3187.03 N 1645.42 W Comment Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 - 2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot Comments (Continued) Western North Slope <:::> ::t:J ~-o-J-.":_...:r.. r~=·· 'ic -'». .o~.:. .J ~-l.k-o-::<;._~ ~.- ~- -~ :i~ ¡--- Sperry-Sun Drilling Services Proposal Report for Kuparuk 2T - Plan: 2T-218 - 2T-218 (wp01) Your Ref: 2T Tabasco Horizontal from 2T-218 Slot Western North Slope Casino details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 5476.50 3022.06 <Surface> <Surface> <Run-TO> <Run-TO> Taroets associated with this welllJath Target Name Tabasco Horz (Heel) Tabasco Horz (Toe) 19 January, 2003 - 12:57 Casing Detail 10 3/4" Casing 7" Casing Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Page 70f7 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape 3051.83 1728.53 N 2308.75 W 2935.03 5972476.60 N 496636.47 E 700 20' 09.7201" N 1500 01' 38.2393" W Point 3069.80 3187.03 N 1645.42 W 2953.00 5973935.00 N 497300.00 E 70020'24.0674" N 150001'18.8747" W Point ConocoPhillips ,,-j Target Type ~..... DrillQuest 3.03.02.002 ~ ~ ;\~ün~·~_- -·--:r.~,--r:nn~··,: /\z~rnu~: ~: I 4000 I 3500 I 3000 I 2500 I 2000 I 1500 TalJ{l~((> H(>!7. ([v;> j 3fl69.Nf) ITD, J187.fJ3 X, 16-15.42 IV Tabascû llar.z. {lieelJ 3(JSUH TVD. 172853 X, ZJMU5 w '. ~ APPROVED Plan 5970747.74 N, 498944.97 E 365.31 N, 0.01 W 70° 19' 52.7219" N, 209° 59' 29.1927" E 768' FSL & 556' FW L, See 1- T11 N-R8E 116.800 above Mean Sea Level True North Feet (US) RKB Elevation: North Reference : Units: Hoñzontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates: Current Well Properties 2T-218 Well: .~ Reference is True North ConocoPhil I ips ConocoPhillips Alaska, Inc. North Slope, Alaska Kuparuk (2T Pad) 2T -218 (wp01) Scale: 1 inch = 500ft Drill Quest 3.03.02.005 I 1000 I 500 o I -500 ~ ~o .....\0 \J?i '\~ n~·. _~ # 7.::> ~e' '\~ (' 6.... ~o' "~O ~~ ';,...~ .>_{::~V '?,I;j ~O ~O b.1~ :!J\þ;. ~~ ~7,9' <)~\' ~O' 'ò9~ 'è'?,~ V' 'b ,"ì. ~ -\." 1b.~ fõ...· fõ.... ';,I;j oÙ~Q '1:'\ ~O' -~()>;),·0 a.. '?,I;j '?,Çj ,I) 0°" Q<~\ ~ '\ See. b....~ _ ~9\.:,..,'0() . ';,IõÇj ~O' ~O' ,,-\,,-'0l,£><2\ @ ,p' ", ....".~'" 6'·'., d'"-':<--;'· cØ' ",," .¡;." ." ~:,'i>.",. # ~ ~ '!J,¡JI; ,~ . ~ -{w'" ~\\ ~O· ,,'ô' n<,)'J -< . ~S "Gs~,Q',':¡i~ ...oo~·, ~J'>-0j!Y' 7,9 .~J?J .';,9 \\:)<':>0.1:' S....'2J: ~þ;. ~\. '\'" tf. 0'" ,,0']><:'/ @ ~~. 1° . C\~ ~ 00 <"Î\1" ..a- <:.~ ¿""'" @'?,. ,.f" <i '( F O..'(>....e rf\...1;j @'ò9' ;~'?f-:~'v' ... v , :\'U' ,"" ,\" ~0'" "V" " ". vv '(;.-(\v 4c '!Ja" ç)\~ -cP '",- ... ;.. . ç)\1, @ '2-' s# /¡"'::"'i" . \~ ;..\-(\ Q';,:::~.c-_\.. ~ e \-(\ ç)\1, >'ò-?- p~ '>-.."'_ <òe~ -c þ'v /' <./ 'ò-S e S\; Vv\~\._ _ ~ '~t;.,'0') r:Je ~-(\~ ç)\1" ".j:.". Ý' :1ß<j.rP ;. . 0° cP-(\ <'.-(\ò '<:. v <">;&'.) 7. Csg Pt. ~<S" df> .. v 0"': MD. 7295.300 .p><j. rP . rØ ' TVD: 3069.800 ~""~18 ",Q ß' ~. <:Ø: ~rP .,Ð-rP </>rj>-rØ .1'# _ _ _ ==;;:: =;;::::: ~ f ~ ~ ~ ~_~=~=~.=~___ ~ ",Q,-:;:::;;;:::::=::::¡=~ - r . "'''\. ÿ;:·,~"F ==;;:: =;;:: 1o-314.~S9Pt. -. "- MD: 5476.5011 ' TVD: 3022.06ft I I 3000 - -. :¡:¡\~:,.:;; =t= = --t-',. . . I I 2500 - ¡ rØ J ",Q"# End Dir, Start Sail @ 51.0° : V 1453.33ftMD,1323.20ftTVD ,¡F<;Ø ~..' . ". .' .;,: ... .....·..r'·F. ";:,[~'g¡ ':r'" -. ................ .....__..·__·u ... ------- .... ..-.--..-"-. .... I .cØ ______ Resume Dir @ 5.00/100ft : ~ _.. 2000.00ftMD,1667.23ftTVD ----;-~'.-, =+----------- .. ., ^, I End Dir, Start Sail @ 67,2° : ~ 2324.40ft MD, 1833.22ft TVD I ",J'..p>. I Resume Dir @ 5.68°/1000: ______ 3077.86ft MD, 2124.95ftTVD ,,"j,";70iT;"OO ~~. ...._...___00-. moo '00'0'000_'_' .... 0000...__'_ .-- ..--.---- ,," ,;ç;:;':::\ '-;-':\'Ti-'::"T::'(:;ooloooo .... ....... ....... -. .--_.---- ..0 __00__...·_ -- ....._._00 I 2000 - 1500 - 1000 - : .,,,,<ji>1fl'" . ",v' ______ Increase in Dir Rate @ 5.00/100ft: 633.33ft MD, 631 ,64ft TVD ,¡f>~<F- ",<S' 500- ç,<F- ~<S'# ___ Begin Dir @ 3.00°/1000 in 13-1/2" Hole: 300.00ft MD, 300.00ft TVD SpBn-'Y-SUIl Q'¡rffL'~JN-~'-~~~ 1(,rf5tt ç:;: -i$-:~ A HáU~wtn(W C(¡ntþdny 0-'---'--' / SHL (768' FSL & [iS6' FWL.. See 1-T11N-R8E) Qj ~ Cf) .+: o o It) II .c u .ç r-- II IX) ~ ~ .c: ã. <1> o ëti u '€ <1> > .. . ..~--...=.~..:-~ 1:~~ ~---....,.-,~~- -" r ~<~~ ~~---""'" """"/-.. ¡ ~ '-.,...: :::J (/) ~ éx! cò T"" T"" a ..:.1::J ~';"-:::J,-~ f"~ ~':> ~,."~~~ "" ,~ ~'C.__ -3000 -2400 J 7~!bu.ù. 0 /-{¡j¡";' [TtJi:·~ .>(j{,9.8U IYD. .iJS:UJ3 ,\C. 1(,45...2 H" ~?::'!-~~~_"'_"'- -r~~~~~)F':~t~ ;~~E;·:Ji~t:¡j~;2°;~f;~_~~~) rr 3000 - 2400 - lì¡/¡asm I {or: ! {fe"l, .>()5 ¡.S.! '/\'1). U::/i.S.! .Y. ::3U8. /5 >Ii 1800 - en C> c :c t o Z 10·314· Csg PI. MD: 5476.5011 TVD: 3022.0611 -1800 I o -1200 I -600 I 7" Csg PI. MD: 7295.3011 TVD: 3069.8011 - 3000 - 2400 End Dir, Start Sail @ 89.7": 5916.27ft MD, 3061.83ft TVD Continue Dir @ 2.0°/1000 : 5900.54ft MD, 3061.69ft TVD Decrease in Dir Rate @ 2.000/100ft : 5692.74ft MD, 3051.83ft TVD - 1800 TABASC:() ¡nh?::"sect: E/:392.42tt f\-H): 3ü51.8Dh TVD ¿:49S: FSL (£ 1752: FEL, S{-;D. 2-T1~N-RBE} Begin Dir @ 3.00/10Oft: 5519.41ft MD, 3029.51ft TVD 10-314" Csg Pt.n Drill out 8-3/4" Hole: 5476.50ft MD, 3022.06ft TVD (2301' FSL & 1840' FEL, See 2-T11N-R8E) End Dir, Start Sail @ 80.0° : 5027.47ft MD, 2944.09ft TVD I Ç)Ç)~~<:).. I Ç)~" <J) \" b~ <t ;.\<:) ~~ ~<:) 0 '. ç$\" ~'!3r¡}'ß @ ~1~,,~ ç$\"r¡,.'!>~ ~,,~<:) <i!J~<:) <p" Q"<' ~.r¡,.'\ C:JiÞ ~,!>rp; . @ \Ç;¡~1' ~ @r¡,.ç}' <?-'l>-,e1 ~@' ~e....~ ~'l>-~ ,,'ò <:)~~. ~'5n.r¡,.'!>' Ä"<' ~,\. -('II> ~-s !õ"- '5 _,,<:). e ~ ~'è> "... .~ v 6 <?-e(\1~~ Q~~~~' ~~~Ç)Ç)~ .~.Çj~<:). ~e"~<:)' ,!>Ç) ~<:-ò b,þI <?-~~(). Ò Q '!>'!>~ fj<.e'lj '!>'!>" I O-----~<:::-- .-~A-~~-'i~:..~· ~~.. . ---- 0 .~ .~ . . ,/1 B,g;n 0;, @ 3.00·/100fUn ':>'12' Hoe, :/ I 300.000 MD, 300.000 TVD / ¡ 1200 - <1''' ~.,ø' . 600 - .t: o o <0 II L: o .f: iJj (ij o (f) -3000 J -2400 Scale: 1 inch = 600ft DrillQuest 3.03.02.005 - 1200 - 600 SHL (76~r FSL.& 556: FV1L~ SeG 1-T1iN~R3E) I -1800 I -600 o I -1200 Eastings ConocoPhillips ConocoPhillips Alaska, Inc. North Slope, Alaska Kuparuk (2T Pad) 2T -218 (wp01) ~' N .~. ~~~,~ Reference is True North Well: Current Well Properties 2T-218 Horizontal Coordinates: Ref. Global Coordinates: 5970747.74 N, 498944.97 E Ref. Structure: 365.31 N, 0.01 W Ref. Geographical Coordinates: 70019' 52.7219" N, 209° 59' 29.1927" E 768' FSL & 556' FWL, See 1-T11 N-R8E RKB Elevation: North Reference : Units: 116.800 above Mean Sea Level True North Feet (US) APPROVED Plan --" !Eipe"""-'Yiiisull fjRTL__CT..., G-·~.~wj!-~VrE·ë!~ A HølfitïwrtQfJ C(J~Dr'fY WELL DETAILS ANTI COLLISION MD SETTINGS COMPANY DETAILS WELLPATH DLTAIIS +N/ -S ♦F/ -W NoMvg Fasting Lal89de Wngtlude S Pi Alaska Inc. 2T - 216 (Tabasco Hon) ■ Interpolation M Interval: 50.00 F,�� g Plan for 1st Tabasco Hon Well from Zr -218 2T -218 (Tabasco Horz) 365.35 -0.01 5970747.74 498944.97 70°1652.72271 15071030.807W ethod: Depth Range From: 36.40 To 7295.05 ^ °P Maximum Range: 925.86 Reference: Plan: 2T -218 (wp01) Ri Doyon 19 116.80 Calculation Method IS Curvature. .ef Deeun: D]B@2T- 218= I16.8'MSL H Fnor S IS W SA Scan Swface Tr er North V.S Angk O�n7m 01197 Fr0mT Error Sw[ace'. ESipncal +Casing Angk +147 -S +r9 -W FromTVD SURVEY PROGRAM Wammg Method: Rules Based 0 0.00 0.00 0.00 Depth Fm Depth To Survey/Plan Tool From 0 Colour 30 M From Colour MD 0 3 300 0 300 500 300 500 36.40 700.00 Planned: 2T -218 (wp01) VII CB- GYRO -SS 500 700 500 700 700.00 7295.05 Planned: 2T -218 (wp01) V11 MWD 700 900 700 900 900 1100 900 1100 1100 --- 1300 1100 1300 1300 1500 1300 1500 1500 ..,- . °:.'.° 2000 2000 2500 2T -2 zu -P Bur) 0 2000 2500 2500 -- 3000 2500 3000 0 . 2T-220 3000 3500 � 3000 3500 - 105 7 !J`1 3500 4000 � 3500 4000 - 100 1� 4000 4500 40 33� 4 • 0 4000 4500 �� Pi 400 5000 �, .�V� / 4500 5000 33 �� Sp.4 ' 0 5000 6000 L•a , 5000 6000 r6000 7000 - + 6000 7000 Aa 800 0 9000 30 / `�.��` 0 1 :: ' � &ES / , e Wit , , \ .10 301 / ‘ 41.W " \ .0 2T - 32 ■tL*6.. --KI \ / / ..,,4141k ..,,::::_-' \ ,,:- ,, \ t . N� / . 2T -217 (2T -21 -25 10 / 1 _ � l N % � � 1�� 4 - 0 270 �� • � � - - I /� 0 27' ,� 011111w 90 • 0 1'111 • r, ' ' ■ 10 rte! ::; �. \ k ._ \ __ ,,,,1114,1" IIIIII 1 �` 2 (I 1 4n \ _ / 1 0 24 \ _ -4 1 2T -29 \ lhOki ' � -75 _ �� 30 o �„ ® � ,. \ �, I „T 21 (2T -215) • ; 4141111111 %. 41 1101 10 !"..... .-.410. 5° ----,,,,,.. , -.4,1 011 -100 , ir''''1,0b - _ 0 (TT-210) 40 - 105 SECI'14.1l AILS , . ► Sec MD Inc Azi TVD +141 -8 +E/ -W DLeg TFace VSec Target 180 1 36.40 0.00 0.00 36.40 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 266.78 300.00 0.00 0.00 0.00 266.78 0.00 3 633.33 10.00 266.78 631.64 -1.63 -35.68 3.00 266.78 -1.63 2T -218 (wp0l ) 4 1453.33 51.00 266.78 1323.20 -24.51 - 435.68 5.00 0.00 -24.51 5 1500.00 51.00 266.78 1352.57 -26.55 - 471.90 0.00 0.00 -26.55 6 2000.00 51.00 266.78 1667.23 -48.37 - 859.86 0.00 0.00 -48.37 7 2324.32 67.22 266.78 1833.18 -63.96 - 1136.81 5.00 0.00 -63.96 ' Tabasco Horizontal' 8 3077.86 67.22 266.78 2124.94 - 102.98 - 1830.47 X0.00 0.00 - 102.98 9 5026.66 80.00 24.42 2943.69 1130.47 - 2579.96 5.68 111.12 1130.47 10 5520.88 80.00 24.42 3029.51 1573.64 - 2378.74 0.00 0.00 1573.64 '''' Approved Plan --® 11 5694.25 85.20 24.42 3051.83 1730.13 - 2307.69 3.00 360.00 1730.13 12 5917.44 89.67 24.42 3061.81 1933.10 - 2215.53 2.00 360.00 1933.10 13 7295.05 89.67 24.42 3069.75 3187.45 - 1646.01 0.00 0.00 3187.45 Travelling Cylinder Azimuth (TFO +AZI) [deg] vs Centre to Centre Separation [50ft/in] Travelling Cylinder Azimuth (TFO +AZI) [deg] vs Centre to Centre Separation [2Oft/in] CQ~p$ri~: F1iè~(li . · . · .Øfijr~Qçe Sitß: Reference Well: Reference Well path: ') ) SPERRY_SUN RES Anticollision Report Philliþ$Alä$kålh¢. . Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-218 (Tabasco Horz) 2T-218 (Tabasco Horz) NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 36.40 to 7295.05 ft Maximum Radius: 925.86 ft Survey Program for Definitive Wellpath Date: 1/11/2003 Validated: No Planned From To Survey ft ft 36.40 700.00 700.00 7295.05 Casing Points MD ff 5476.50 7295.05 Tv» ft . 3021.80 3069.75 Planned: 2T-218 (wp01) V11 Planned: 2T -218 (wp01) V11 Di~~t~r in 10.750 7.000 · Ii~.e Size :in 13.500 9.875 . Náß1e 10 3/4" 7" Sununary <-~-~-~-~-~----.;--;~-:: .·Oft'set WcUpath .--.;~-.;~-;.--~---~---.;--> Site . Well . W¢llpáth Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad Kuparuk 2T Pad 2T-02 2T-202 2T -204 2T-207 2T -209 2T-21 0 2T-215 2T-217 2T-217 2T-220 2T-220 2T-22 2T-23 2T-27 2T-28 2T-29 2T -30 2T-31 2T -32 2T -39 2T-02 V2 2T -202 V2 2T -204 VO 2T-207 V1 2T-209 V1 2T-21 0 VO 2T-215 VO 2T-217 VO 2T-217A VO 2T-220 VO 2T-220PB1 V2 2T -22 VO 2T -23 VO 2T -27 VO 2T -28 VO 2T-29 VO 2T -30 VO 2T-31 VO 2T-32 VO 2T -39 V9 D~tß:1/19i2003 " , "" "'" " . Ttme:... 09:44;22 1 Pagë: .Ço-o..din~t~Ò~E)·Ref~rßnc~: Vertical (TVD) Reference: '"". . " ,., . .' " . ·wåu: Plah:2P218, r"abaseo Hór:i) D19@2T-218=116.8' MSL 116.8 Db: Oracle Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 3 Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MWD - Standard R.cfel'ence Offset Ctr~Ctr. . . No-Go Allowable MD MD Distance· . Area ))eviátion Warnin~ . ft ft ft ft ft 1276.24 1350.00 257.27 32.42 228.39 Pass: Major Risk 1343.19 1450.00 94.45 40.48 66.34 Pass: Major Risk 396.70 400.00 170.09 7.97 162.15 Pass: Major Risk 557.42 550.00 130.38 10.23 120.19 Pass: Major Risk 455.55 450.00 112.78 7.63 1 05. 18 Pass: Major Risk 930.15 950.00 96.96 16.51 82.00 Pass: Major Risk 456.03 450.00 37.00 7.88 29.14 Pass: Major Risk 351 .40 350.00 9.80 6.46 3.34 Pass: Major Risk 351 .45 350.00 9.80 6.46 3.34 Pass: Major Risk 305.88 300.00 24.88 5.43 19.46 Pass: Major Risk 299.37 300.00 24.75 5.33 19.43 Pass: Major Risk 1026.41 1050.00 337.45 19.67 318,02 Pass: Major Risk 7209.69 5550.00 333.88 252.00 128.40 Pass: Major Risk 913.96 950.00 264.70 15.70 249.19 Pass: Major Risk 863.22 900.00 245.72 15.00 230.74 Pass: Major Risk 6368.85 5050.00 243.39 188.10 75.70 Pass: Major Risk 864.55 900.00 196.85 15.09 181.77 Pass: Major Risk 631.34 650.00 196.85 11.50 185.39 Pass: Major Risk 6241.00 4950.00 194.84 179.23 49.13 Pass: Major Risk 3217.66 3250.00 276.98 No Offset Errors OR' .~(ì J ..~ ,~ 11 L ~; .\ ,~I ~ .. t:t"j .¡1I':l~ <,. I I \i) 8 : J ,l~'~ . ~ ) ) MOVING SYSTEM All the· rig modules are self-moving on the well pad, using a Columbia - type system that has hydraulically dri ven wheel assemblies. The substructure is capable of 2.5 mph on level ground, and all the other modules are rated at 1.5 mph on level ground. The moving generators are 1 ea. Cat 3114 for the pipe shed, 1 ea. Cat 399 for the substructure, 1 ea. Cat 3406 for the mud pits, and 1 ea. Cat 398 for the utility module. The personnel camp, shop and support units are moved with oilfield trucks. MUD SYSTEM I The rig mud system consists of nine compartments, totaling 1165 barrels in usable volume. The active system comprises six agitated compartments which hold 1,005 barrels. All active pits are connected with a mud ditch for fluid transfer from pit to pit, and sub mud guns provide solids agitation and fluid relocation. Additional tankage consists of two pill pits at 60 barrels and one trip tank at 100 barrels. The centrifugal pump suction and discharge manifold is interconnected with butterfly valves to allow for pump red,undancy. Drill solids and gravel are removed by a drag chain system which feeds into an external cuttings containment unit. A mud lab area is provided for the mud engineer adjacent to the pits. Mud Pit Volumes · pit 1 - 161 barrels @ 2.24 bbls / inch · pit 2 - 155 barrels @ 2.15 bbls / inch · pit 3 - 180 barrels @ 2.20 bbls / inch · pit 4 - 172 barrels @ 2.10 bbls / inch · pit 5 - 165 barrels @ 2.01 bbls / inch · pit 6 - 172 barrels @ 2.10 bbls / inch · trip - 100 barrels @ 1.22 bbls / inch · pill 1 - 20 barrels @ 0.24 bbls / inch · pill 2 - 40 barrels @ 0.49 bbls / inch Solids Control Equipment · 3 ea. - Derrick, four panel Hi G shakers with common possum belly · 1 ea. -Derrick high speed centrifuge with adjustable pulleys for G force selection · 1 ea. - Derrick, 20 cone mud cleaner cluster, 1000 gpm, over a Derrick Flow Line Cleaner OR' I ~,,~., ~ f 'I I .. i ,,; ,i ;'\,ih , . .Il:lj J ,~ \J ,/"J !~ ) ) · 1 ea. - Brandt 2 cone desander,' 1000 gpm , discharging to the drag chain · 1 ea. - Burgess vacuum degasser · 2 ea. - Sidewinder mud hoppers with bulk mud feed capability · 8 ea. - Brandt, right angle, slow speed, 10 hp agitators for active mud pits. Mud System Centrifugal Pumps · 1 ea. - 3 x 4 x 30 hp., trip tank pump · 1 ea. - 2 x 3 x 20 hp., centrifuge charge pump · 2 ea. - 5 x 6 x 60 hp., Galligher, mixing pumps · 2 ea. - 5 x 6 x 60 hp., Galligher charge pumps · 2 ea. - 5 x 6 x 60 hp., Galligher mud cleaner pumps · 1 ea. - 2 x 3 x 20 hp., drill water pump INSTRUMENTATION Drilling · 1 ea. - Martin Decker, 8 pin recorder · 1 ea. - Automatic driller per contractual agreement Totco Drillers Console · 1 ea. - rotary torque indicator · 1 ea. - mud pump strokes per minute · 1 ea. - PVT display and flow show indicator · 1 ea. - stand pipe pressure · 2 ea. - mud pump pressures transmitted through transducer digital system · 1 ea. - weight indicator capable of 1,000,000 # read out · 1 ea. - Iron Roughneck torque indicator · 1 ea. - tong line pull torque indicator · 1 ea. - top drive control console indicating motor rpm and and torque output Mud :. 1 ea. - Martin Decker, Pit Volume Totalizer system with a read out at the drillers console · 1 ea. - methane detector at the shaker possum belly, cellar, rig floor, and drillers console o. hF~~. ;J~.."" ,.~ ~. ø .j1.[ 5 J 1;1;; ^.: \,' ':1' I,! ~1 , ~ t,il I d t, p,: .=t' ) ) GEOLOGIC SUMMARY: 2T-218 (wp01)...Tabasco Horz Target 1 : Tabasco Sand Resp: Mike Werner ~ 6191 ø ÇQI'riPI~~Ø ,. preterred Tar. Angle Formation Heel Toe X 496,638 497,300 V 5,972,478 5,973,935 Z (TVD.SS) Porosity Perm 2,9351 2,943' Net Pay 90 50 S Plan may differ from target at heel by +/-100' E/w- '~'/ Target hape: Approx 1600' Stepout: horizontal Remarks: Target depths are provided at the top of the Tabasco"Sand. The objective is to stay within the upper 1 0 feet of the interval. 1IIr ." Target 2 : ~nmmp-nt~: .~ 'U .. ø Not Applicable !L; Geological Prognosis: .. Formation X v " . Responsible: Mike Wern(:H' - 6191 Z (TVD.SS) MD Gross 'Thickness EJ Net Pay . Iriqqmþlßl$ , . Net to Gross Base Permafrost Top Ugnu G Top Ugnu B Top Ugnu A k13 Top West Sak D Top West Sak B Top West Sak A2 Base West Sak G80 Top Tabasco Sand 1,330' 1,560' 1,980' 2,125' 2,605' 2,920' 2,935' Remarks: Estimated tops for initial directional planning. These will be replaced once directional plan is com p leted. Geological Discussion: Responsible: Mike Werner - 6191 0 Complete The 2T-218 is planned as 1600 foot long horizontal Tabasco Sand producer along the western margin of the channel fill. Gross formation thickness should vary from 90 feet at the heel to about 50 feet at the toe. In this portion of the channel facies the net-to-gross should be 0.90 or greater. Lithologies are expected to be medium to coarse, pebbly unconsolidated sandstones with conglomeratic stringers. The well path is virtually flat, " dropping only 7 feet structurally from heel to toe. Due to risk of loss circulation, surface casing should be set 30"'" feet tvd above the Tabasco Sand. 0', ;,Cl i~r /: :1:' _' N.~ ~ \",,) d 'j I "cø • 2T -218 Tabasco - Horizontal Doyon 19 RKB = 36.5' 7F 6' @ 77' GL Ground Level Elevation (2'18 slot) = 80.4' 62 - 58 lb /ft (ID= 15.25 ") - - - - -- - TAM Collar at +/ 2,160' - -_ 10 - 45.5 lb /ft E--- -- 13 - 1/2" Hole ID= 9.95" Cap. = 0.1123 bbl /ft Displ.= 0.0161 bbl /ft 10 -3/4" - 45.5 lb /ft, L -80, BTC -M Yield= 3,580 psi Collapse = 2,090 psi 10 - 3/4" - 55.5 lb /ft 10 -3/4" - 45.5 lb /ft, CR80, VAM -ACE at +/- 4,476' ID= 9.76" Cap. = 0.0925 bbl /ft Displ.= 0.01973 bbl /ft Liner top at +/- 5,326' Yield= 6,450 psi Collapse = 4,020 psi 10 -3/4" shoe at 5,476' md, 3,022' TVD -RKB 5 -1/2" - 17 lb /ft, 13CR -80, SHLT slotted liner with screens Open hole Gravel Pack 8 -3/4" Hole E--- 5 -1/2" shoe at 7,295' md, 3,070' TVD -RKB SURFACE LOCATION: 768' FSL, 556' FWL, SEC -1 -T1 1 N -R8E, Umiat Meridian ) ) ConocriP'hillips Conoco/Phillips, Inc. Post Office Box 100360 Anchorage, Alaska 99510 January 21,2003 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill: 2T -218 Surface Location: Target Location: Bottom Hole Location: 768' FSL, 556' F'NIL., Sec 1 T11 N, R8E, UM 2495' FSL, 1752' IF~'uIVIL., Sec 2, T11 N, R8E, UM 1325' FNL, 1087' FElL, Sec 2, T11 N, R8E, UM Dear Commissioner: " t· ~Ir dellte~p J1;\M- Conoco/Phillips Alaska, Inc. hereby applies for a "Permit to Drill" to (:lr~111 theJnjee1."ðf well 2T -218. The well will be drilled and completed using Doyon #19. Please uŒize documents on file for this rig. The following logs are to be run on this well: GR/Res. Subject to AOGCC approval, fluids and cuttings generated from drillin!~ the well will be pumped down an approved and existing annulus on Drillsite 1 C, or hauled to an appn]ved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25,070) Sharon Allsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20AAC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Shane Cloninger at (907) 265- 6829. Sincerely, \~\~ R. Thomas Kuparuk Drilling Superintendent R, E'. ''''' ( r'" g '. "II' iF...· ~t ~ V t¡"~ .., Q¡:,.r ~ ~'" ~\ I.~,-.:o J ' 1\' ,', L\II\1 ,/ " ¡ ï _. ')!ìO " LVJJ Alaska DB & Gas Cons. GOJ¡Hìjssion J~ r·~I"~·~lii¡J·· In., co J-¡~H..~ti:h,l' ai.J~. L", .~ " J i , . j~-'~ 1'¡;¡:¡¡;~IWtit'''''''''I'''~~Willl&liJo'. ...' . ",~iMtIIm~",_,~~~"·-~,p""'n·'ftw¡, t I!! ¡í ~ ¡} ~ I i~ 0 CHASE :::::::.::""'::,:~", Val~l5000 Dollars · M: -~_~gá~ .~ ¡ . : 0 :ì ~ ~ 0 0 ~ I. 1.': 2 ~ 8 0 0 0 0 I. 2 ? 2 5 ? III ~ 0 2 ~ I ~;¡:"W'~t~i,'."::,¡:rcf!,!'I1j¡,,!''f:':',:.1:I:''T'!,!n:,~.¡w.\¡¡~~·~1!;:,,1'!~'I'!)':'~~I~~ì":·I,ii¡~\II::!k'm"~j!~~~/"R~~~\·"IIJ'I'~mr,":'1:f./>f'Jf¡'.'I':,{iI'f.I~~I.,"'mr,<iì~~·i'"~I!w,~·Ø,~lfI;.M~.'¡'~~,,~~~'Ir,m"..':I.:¡"1¡Y"","'!:r"",!!.",.,,"~'''''!'I'Jlè·~,.'''_'''JI'''~~i~;;~';:'~'~~!'I~. S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 700G ST. ATO 1530 ç~ ANCHORAGE AK 99501 DATei--·t<:.}1.I1..xzff2qfj'~62_14/311 :;~1~~ó'iJ; 5TrlT60F/fÙ'fjrA / A-e~c I $ {C-:O.OcJ .___'2~ /Lu'1A-l-£-eJ clól&Zr<; ~'- /;..-e.<-O ~ðd "".;: Do ,,"",,,,,.,,,",,,, L /;i e['/ I (~ UOLLARS W ~;::::~"ß",k 1021 I) E· ( i~ R v' 'r.'" r'" 1\,... C ~ I' C l) ! 1\ i\! I) ,') 2003'" ,)-\, t....., Alaska Oil & Gas Glms. CommiSSIOI 1ô.l1chorag8 ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. . WELL PERMIT CHECKLIST C'oMPANý ^",-,,,"fitfl~~ WELL NAME J:.R (I .2.!- 2/<{ PROGRAM:Exp _ Dev X- Redrll _ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL '~ ~ c> I he:> INIT CLASS (J ~~ / / -.....,,! GEOL AREA ? .,......) UNIT# /1/ C ð ON/OFF SHORE QA.) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ç- N 2. Lease number appropriate. . . ~ . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. .. '. . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N p[)~_ )~~ ¿2 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~rr - ~c....:7 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force.. . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . \ '!. N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Welll?cate? ~(in ~rea & strata ~uth?rize? by injection order #___ Y ft A.J,A ~ (Service Well Only) 14. All wells wlln ~ mile area of review Identified. . . . . . . . . '. ~ N ENGINEERING 15. Conductor string provided. . .. . . . . . . . ~ N 16. Surface casing protects all known USDWs. . . . . . . . . Y N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . . Y N .A' 19. CMT will cover all known prod.uctive horizons. .. . .' . . . .. . ~ s.1r; TT~J 20. Casing designs adequate for C, T, B& permafrost. . . . . . . . N f.\ 10 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N V 19-11) OV\.... 7, 22. If a re-drill, has a 10-403 fo~ abandonment been approved. . . ~ AI/Æ-I 23. Adequate wellbore separation proposed.. .'.' . . . . . .. . . é:fi.. N 24. If diverter required, does "it meet regulations. .' . . . . . ,. . ft/... N ,/J/l. 25; Drilling fluid program schematic & equip list adequate. . . . . j. N f v¿A.-'V f'J'J /IJ C¡. IF. P P. ~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~j N . '3 ~ fI, ~7.. BOPE press rating appropriate; test to 5" 000 psig. /' N fVlS. P 1 ð yJ~ t . I / 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ,N IJJ6k z.,. tf 05- 29. Work will occur without operation shutdown. . . . . . . . . . . ~ N . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . U" N IlL . (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N- Ai", GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . . y Q;i/ APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . ~. L) ß/} /1. ) 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /J · r¡ \. 'o/?"'... ~2<7k?~ 35. Seabed condition survey (if,off-shore). . . . . .. ...... Y. N ' (Exploratory OnlY) 36. Contact name/phone for weekly progress reports. ...... N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING . UIC ENGINEER RP#,: APPR DATE COMMISSIONER: TEM JDH JBR COT l . DTS 0 è/~1-( c 3 MLB 0 '/ DJ""./oJ SFD WGA / MJW Rev: 10/15/02 G:\geology\permits\checklist.doc ( ( Commentsllnstructiol"ls: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify 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. ') ') 6103'"017 I/-¡/~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 02 08:S4:48 2003 Reel Header Service name... . . . . . . . . . .LISTPE Date.................... .03/0S/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/0 S / 02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River (Tabasco) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2T-218 S01032044900 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 02-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002323381 M. HANIK G. WHITLOCK MWD RUN 2 MW0002323381 M. HANIK D. MICKEY MWD RUN 3 MW0002323381 M. HANIK D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1 11N 8E 768 SS6 .00 117.40 80.40 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.S00 16.000 114.0 8.7S0 10.7S0 S480.0 ) ) 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE DISCUSSION BETWEEN MIKE WERNER (CPAI) AND BUSTER BRYANT (SSDS) ON 29 APRIL 2003. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1 - 3 REPRESENT WELL 2T-218 WITH API#: 50-103-20449-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7360'MD/3075'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service'name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM 1 and clipped curves; all bit runs merged. .5000 START DEPTH 61.0 100.0 100.0 100.0 STOP DEPTH 7317.0 7327.0 7327.0 7327.0 ) ) RPS RPX ROP $ 100.0 100.0 114.5 7327.0 7327.0 7359.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 61.0 3958.0 5490.0 MERGE BASE 3958.0 5490.0 7359.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 61 7359.5 3710.25 14598 61 7359.5 ROP MWD FT/H 0.27 1482.2 137.52 14491 114.5 7359.5 GR MWD API 11.84 147.2 74.7474 14513 61 7317 RPX MWD OHMM 1.9 2000 102.981 14376 100 7327 RPS MWD OHMM 0.85 2000 140.985 14376 100 7327 RPM MWD OHMM 0.12 2000 222.257 14376 100 7327 RPD MWD OHMM 0.28 2000 332.29 14376 100 7327 FET MWD HOUR 0.14 89.31 1.28603 14376 100 7327 First Reading For Entire File......... .61 Last Reading For Entire File.......... .7359.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 ) Date of Generation...... .03/05/02 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...... .03/05/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 61.0 100.0 100.0 100.0 100.0 100.0 114.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 3903.5 3896.0 3896.0 3896.0 3896.0 3896.0 3958.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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): 25-MAR-03 Insite 66.37 Memory 3958.0 60.0 3958.0 .3 67.5 TOOL NUMBER 142827 67981 13.500 114.0 Spud Mud 9.50 200.0 ) ') MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.0 200 5.6 9.000 7.310 4.000 8.000 70.0 87.8 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 61 3958 2009.5 7795 61 3958 ROP MWD010 FT/H 0.27 1482.2 154.655 7688 114.5 3958 GR MWD010 API 11.84 128.17 68.8463 7686 61 3903.5 RPX MWD010 OHMM 1.9 2000 184.857 7593 100 3896 RPS MWD010 OHMM 0.85 2000 199.824 7593 100 3896 RPM MWD010 OHMM 0.12 2000 240.442 7593 100 3896 RPD MWD010 OHMM 0.28 2000 353.395 7593 100 3896 FET MWD010 HOUR 0.2 2.1 0.775909 7593 100 3896 First Reading For Entire File......... .61 Last Reading For Entire File.......... .3958 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/02 ) Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 '-" ) header data for each bit run in separate files. 2 .5000 START DEPTH 3896.5 3896.5 3896.5 3896.5 3896.5 3904.0 3958.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 5430.0 5430.0 5430.0 5430.0 5430.0 5437.5 5490.0 27-MAR-03 Insite 66.37 Memory 5490.0 3958.0 5490.0 57.8 81.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 142827 67981 # 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: 13.500 114.0 Spud Mud 9.90 100.0 9.6 ') 'ì J 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: 350 4.4 5.000 4.440 2.000 4.750 74.0 84.2 74.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3896.5 5490 4693.25 3188 3896.5 5490 ROP MWD020 FT/H 1.67 316.27 102.266 3064 3958.5 5490 GR MWD020 API 61.61 147.2 103.351 3068 3904 5437.5 RPX MWD020 OHMM 2.82 22.63 6.79829 3068 3896.5 5430 RPS MWD020 OHMM 3.24 25.01 7.01064 3068 3896.5 5430 RPM MWD020 OHMM 3.59 27.46 7.29109 3068 3896.5 5430 RPD MWD020 OHMM 3.32 31.31 8.02061 3068 3896.5 5430 FET MWD020 HOUR 0.44 17.01 1.63699 3068 3896.5 5430 First Reading For Entire File......... .3896.5 Last Reading For Entire File.......... .5490 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/02 Maximum Physical Record. .65535 ) File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/05/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 , , header data for each bit run in separate files. 3 .5000 START DEPTH 5438.0 5470.0 5470.0 5470.0 5470.0 5470.0 5490.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 7317.0 7327.0 7327.0 7327.0 7327.0 7327.0 7359.5 02-APR-03 Insite 66.37 Memory 7360.0 5490.0 7360.0 81.6 92.9 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 164580 145654 # 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): 8.750 5480.0 Flo Pro 9.10 59.0 8.6 28000 \ ¡ ) 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: 4.0 .180 .130 .160 .240 67.0 98.6 67.0 67.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5438 7359.5 6398.75 3844 5438 7359.5 ROP MWD030 FT/H 8.32 680 131.179 3739 5490.5 7359.5 GR MWD030 API 31.35 135.92 63.4677 3759 5438 7317 RPX MWD030 OHMM 2.16 2000 15.0667 3715 5470 7327 RPS MWD030 OHMM 2.36 2000 131.367 3715 5470 7327 RPM MWD030 OHMM 2.25 2000 362.618 3715 5470 7327 RPD MWD030 OHMM 0.62 2000 556.947 3715 5470 7327 FET MWD030 HOUR 0.14 89.31 2.03883 3715 5470 7327 First Reading For Entire File......... .5438 Last Reading For Entire File.......... .7359.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/02 Maximum Physical Record. .65535 F i 1 e Type................ LO ) ) Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/02 origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File