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STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION C ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing F Operations Shutdown Performed: Suspend 1', Perforate 1- Other Stimulate 1 Ater Casing F Change Approved Program Plug for Redrill f Perforate New Pool 1- Repair Well F Re-enter Susp Well 1- Other: Stacked Packer iv- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 198-218 3.Address: 6.API Number: Stratigraphic I Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20276-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380051 KRU 2L-315 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 8236 feet Plugs(measured) None true vertical 5627 feet Junk(measured) None Effective Depth measured 8061 feet Packer(measured) 4923,7419 true vertical 5536 feet (true vertical) 3774,5182 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 2372 7 5/8 2400 2291 PRODUCTION 8201 51/2 8228 5623 NNE� APR 1 n7 RECEIVED Perforation depth: Measured depth: 7765-7805,7900-7920 �U True Vertical Depth: 5377-5399,5450-5461 FEB 22 20117► AOGCC Tubing(size,grade,MD,and TVD) 2 7/8, L-80,7490 MD,5222 TVD Packers&SSSV(type,MD,and TVD) PACKER-HALLIBURTON PHL RETRIEVABLE PACKER @ 4923 MD and 3774 TVD PACKER-HALLIBURTON"PHL"13-17K RETRIEVABLE PACKER @ 7419 MD and 5182 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 180 206 115 513 280 Subsequent to operation 292 405 760 850 263 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic 1 Copies of Logs and Surveys Run r` 16.Well Status after work: Oil F Gas I WDSPL 1"- Printed Printed and Electronic Fracture Stimulation Data 1— GSTOR E WINJ E WAG E GINJ r SUSP E 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: 316-627 Contact Sara Heskin a 265-1027 Email Sara.E.Heskinaconocophillips.com Printed Name Sara Heskin Title Assoc. Wells Engineer Signature C /��j n j Q� Phone:265-1027 Date /,f / 14 ,V\v+/�I✓�'.J��} / am Q'L Form 10-404 Revised 5/2015 Ti- 3/24/IrRDD1911S vFE3 7 2p17 Submit Original Only • • 0 Operations Summary (with Timelog Depths) 2L-315 Conoco Phillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End,Depth(ftKB) 1/10/2017 1/10/2017 0.50 MIRU MOVE RURD P Latch up to Pit Complex and separate 09:30 10:00 from rig structure. 1/10/2017 1/10/2017 1.00 MIRU MOVE RURD P Skid Rig floor back to transit setting on 10:00 11:00 Sub Base,Road the following Pit, Pump,Motor room and Pipe Shed Complex's to 2A Pad 1/10/2017 1/10/2017 1.00 MIRU MOVE RURD P Install Tow tongue to Sub Base 11:00 12:00 Complex and raise stompers in preparation for towing. 1/10/2017 1/10/2017 3.00 MIRU MOVE MOB P Pull Doyon 142 away from 2T-201 and 12:00 15:00 transport the sub base to 2A Pad. 1/10/2017 1/10/2017 3.00 MIRU MOVE MOB P Road Doyon 142 complex's and sub 15:00 18:00 base from 2A Pad to 2L Pad access, utilizing 3 blades ahead of caravan scratching the road base. 1/10/2017 1/10/2017 2.00 MIRU MOVE WAIT X Pre-rig operations still being 18:00 20:00 preformed on 2L-315 via E-line services.KDTH pad prep along with setting of rig mats which is normally conducted by Sim Ops operations while rig is being moved or prior to moving the rig,but was unable to initialize do to other equipment on well. Pre spot sub base and remove hand rails from on top of well houses 314 and 316. 1/10/2017 1/10/2017 1.50 MIRU MOVE MOB P Spot Doyon 142 over well 2L-315 20:00 21:30 1/10/2017 1/10/2017 1.00 MIRU MOVE RURD P Set stompers and spot mud pits next 21:30 22:30 to sub base. 1/10/2017 1/11/2017 1.50 MIRU MOVE RURD P Skid rig floor forward on cantilever 22:30 00:00 1/11/2017 1/11/2017 1.25 MIRU MOVE RURD P Spot Pit Modules,work on sub 00:00 01:15 interconnects 1/11/2017 1/11/2017 1.00 MIRU MOVE RURD P Spot and Shim Pump Complex 01:15 02:15 1/11/2017 1/11/2017 0.50 MIRU MOVE RURD P Spot Motor Modules,work on sub 02:15 02:45 interconnects 1/11/2017 1/11/2017 1.25 MIRU MOVE RURD P Spot Pipe shed Modules,work on sub 02:45 04:00 interconnects. 1/11/2017 1/11/2017 0.50 MIRU MOVE RURD P Spot Rock Washer,work on sub 04:00 04:30 interconnects ' 1/11/2017 1/11/2017 2.25 MIRU MOVE RURD P Spot cuttings tank and Hand-Y-Berm, 04:30 06:45 work on sub interconnects,Tie in steam,air and water lines. Swap over power from Transit Gen sets to 3512 Main Power. 1/11/2017 1/11/2017 1.25 MIRU MOVE RURD P Prep and Raise Pipe skate rail,Test 06:45 08:00 run skate trough. Prep and raise Beaver slide,continue to work MU of serevice lines along with completion of acceptance list. Accept Doyon 142 @ 08:00 hrs on 1-11-17 1/11/2017 1/11/2017 2.50 MIRU WELCTL RURD P Rigged up lines and manifold for well 08:00 10:30 kill to Flow Back Tank.Loaded SW in Pits. 1/11/2017 1/11/2017 0.50 MIRU MOVE SFTY P Held Preworkover meeting with Crew. 10:30 11:00 Page 1/12 Report Printed: 1/25/2017 . • 0i~ Operations Summary (with Timelog Depths) r 2L-315 Cono nips , Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code TimeP-T-X Operation (ftKB) End Depth(ftKB) 1/11/2017 1/11/2017 4.50 MIRU WELCTL KLWL P Verfied Pressure on Well.Tubing 250 11:00 15:30 psi, IA 820 psi,OA 300 psi.Checked gauges to insure readings were good, OK.Bled IA to Flowback tank to 50 psi.Opened Tubing on vac. Pumped 177 Bbls SW staging pump to 4 BPM. FCP 1510 psi. 1/11/2017 1/11/2017 0.25 MIRU WELCTL OWFF P OWFF Slight flow from IA to Flowback 15:30 15:45 tank. 1/11/2017 1/11/2017 0.75 MIRU WELCTL CIRC P CBU @ 2.5 BPM 324 psi. 15:45 16:30 1/11/2017 1/11/2017 0.50 MIRU WELCTL OWFF P OWFF slight flow from IA.Tubing on 16:30 17:00 Vac. 1/11/2017 1/11/2017 1.00 MIRU WELCTL CLEN P Empty Diesel Returns from pits and 17:00 18:00 take on SW. 1/11/2017 1/11/2017 1.00 MIRU WELCTL CIRC P Pumped 10 Bbls down Tubing to 18:00 19:00 remove any remaining Diesel from IA. Reversed @ 2 BPM taking returns out Tubing to Pitts.Observed clean SW after 200 Stks. 1/11/2017 1/11/2017 1.00 MIRU WELCTL OWFF P OWFF Well Static after 30 Min. 19:00 20:00 Observed for 30 Min more to confirm. Well Static. 1/11/2017 1/11/2017 0.50 MIRU WELCTL KLWL P Rigged down Kill Lines. 20:00 20:30 1/11/2017 1/11/2017 0.25 MIRU MOVE THGR P Installed Type H BPV. 20:30 20:45 1/11/2017 1/11/2017 0.75 MIRU MOVE NUND P Nippled down Tree and Adapter 20:45 21:30 Flange. 1/11/2017 1/11/2017 0.50 MIRU MOVE MPSP P Installed Blanking Plug. 21:30 22:00 1/11/2017 1/12/2017 2.00 MIRU MOVE NUND P Nippled up Spacer Spool. 22:00 00:00 1/12/2017 1/12/2017 3.75 MIRU WHDBOP NUND P NU BOPE equipment,MU choke and 00:00 03:45 kill lines. Install Bell Nipple and riser. Perform Bi-Well BWM,set mouse hole Sim-Ops-Continue to change out savor sub. 1/12/2017 1/12/2017 1.25 MIRU WHDBOP RURD P RU test equipment,MU X-O to Test 03:45 05:00 joint. MU Safety Valves,Perform shell test to 3,000 psi. Page 2/12 Report Printed: 1/25/2017 • Operations Summary (with Timelog Depths) 2L-315 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/12/2017 1/12/2017 5.00 MIRU WHDBOP BOPE P Conduct Initial BOP test at 250/3,000 05:00 10:00 psi with 3-1/2 test joint. (Note-Sundry called for 250/2,500 psi,but Casing test is 3,000 psi) 24 hr Notification was sent @ 17:04 hrs on 1-10-17 and was witnessed by Matthew Herrera. Test 1 Annular,CM Valves 1, 12, 13, 14,4" Kill line and XT-39 Dart Valve with F/P on Annular Test 2 3-1/2"x 6"VBR UPR,CM Valves 9 and 11,Mezz.Kill line and XT-39 Floor Valve Test 3 3-1/2"x 6"VBR UPR,CM Valves 8 and 10,HCR Kill Test 4 3-1/2"x 6"VBR UPR,CM Valves 6 and 7 Test 5 3-1/2"x 6"VBR UPR and Manual Operated Choke at 1,800 psi Test 6 3-1/2"x 6"VBR UPR and Super Choke at 1,800 psi Test 7 3-1/2"x 6"VBR UPR,CM Valves 2 and 5,Man.Kill,UPR IBOP Test 8 3-1/2"x 6"VBR UPR,HCR Choke, LWR IBOP with F/P on LWR IBOP Test 9 3-1/2"x 6"VBR UPR and Man.Choke Test 10 3-1/2"x 6"VBR LPR and 3-1/2 EUE FOSV Test 11 Blinds and CM Valves 3 and 4 Accumulator System- System pressure=3,050 psi PSI after closure=1,750 psi 200 PSI Attained=9 seconds Full PSI attained=52 seconds 6-N2 Bottles @ 2,525 psi AVG 1/12/2017 1/12/2017 0.50 MIRU WHDBOP RURD P Pull 3-1/2 test joint and blanking plug, 10:00 10:30 Blow down and Rig down test equipment. Break apart FOSV's and Dart Valve Page 3/12 Report Printed: 1/25/2017 • • Operations Summary (with Timelog Depths) qk> 2L-315 Ci nocoPhitlips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase.. Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/12/2017 1/12/2017 1.00 MIRU WHDBOP THGR P RIH w/Dry rod and tap BPV,no 10:30 11:30 pressure,release BPV and pull same. MU XT-39 crossover to landing joint, screw into TBG hanger,BOLDS 1/12/2017 1/12/2017 0.50 COMPZN RPCOMP PULL P Un Land hanger,attempt to pull 11:30 12:00 hanger to floor. Pull to max of 200k, 95K OSW. lower back to landing position,not able to land back with out stacking block wt. Bring pump on at 4 BPM at 1,700 psi w/5%F/O. Working TBG from calculated string wt of 105K to 200K,not able to pull seals or cut (TBG was cut pre-rig @ 7,448-ft). Call out for E-line for Chem cut @ 12:00 hrs 1/12/2017 1/12/2017 3.50 COMPZN RPCOMP PULL P Pull to150k,45K OSW.Continuing to 12:00 15:30 circulate at 4 BPM at 1,300 psi ICP w/ 5%F/O.and FCP 1,246 psi©5% F/O.Attempt to pull up to 175K,70K OSW and something pulled free at 172K. Observe free travel and hook load loss of 92K. Pull hanger to rig floor. Remove landing joint. Call and release E-line for Chem cut @ 15:00 hrs 1/12/2017 1/12/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow -No Flow,well 15:30 16:00 static. 1/12/2017 1/12/2017 1.25 COMPZN RPCOMP PULL P POOH laying down w/3-1/2,9.3#, L- 7,413.0 6,993.0 16:00 17:15 80 EUE 8rd De-Completion tubing and Jewelry. From 7,413'to 6,993'. 1/12/2017 1/12/2017 0.25 COMPZN RPCOMP OWFF P Observed flow out of Tubing. 6,993.0 6,993.0 17:15 17:30 1/12/2017 1/12/2017 0.75 COMPZN RPCOMP CIRC P Reverse circulated @ 2.5 BPM 480 6,993.0 6,993.0 17:30 18:15 psi volume of tubing. 1/12/2017 1/12/2017 0.25 COMPZN RPCOMP OWFF P OWFF Well Static. 6,993.0 6,993.0 18:15 18:30 1/12/2017 1/13/2017 5.50 COMPZN RPCOMP PULL P POOH Laying down w/3-1/2,9.3#, L- 6,993.0 3,047.0 18:30 00:00 80 EUE 8rd De-Completion tubing and Jewelry. from 6,993'to 3,047'. 1/13/2017 1/13/2017 4.50 COMPZN RPCOMP PULL P Continue to POOH w/3-1/2"EUE 9.3# 3,047.0 0.0 00:00 04:30 L-80 Completion string from 3,047-ft, Monitoring displacement via Trip tank. Mark and document all corrosion/ holes on de completion tally starting with joint numbers in relation to original tally 78,72,71,69,65,64,59, 53,52,47,44,42,39,37,32,29,28, 27,25,23, 19,2 and GLM#1. There was large amounts of scale build up on GLM#1. Recovered 15.18-ft of jt #1 leaving 16.48-ft of stub, 1-Camco 2.75"D Nipple,6-ft x 3-1/2 Pup joint, and a Baker 80-40 seal assembly x 15 -ft. Page 4/12 Report Printed: 1/25/2017 • • "' v `,s Operations Summary (with Timelog Depths) k.,,; ,Vitri,-*t 4,„ 2L-315 i111ps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/13/2017 1/13/2017 3.75 COMPZN RPCOMP BHAH P Clear and clean work area,set wear 0.0 0.0 04:30 08:15 ring ID=9-1/16"x 10-3/4"OD x 1.0 Ft long. Continue to rack and tally Weatherford Rental 3-1/2 PH-6 12.95# P-110 Work string. Load,rack and Tally 6-2 3/8 IF x 3-1/2"OD Drill Collars. MU proper cross over for FOSV on rig floor and change elevators. Perform MP2's. 1/13/2017 1/13/2017 1.75 COMPZN RPCOMP BHAH P PJSM,PU,MU and RIH with BHA#1 0.0 195.0 08:15 10:00 (4-11/16"OS w/3-1/2 spiral grapple) to 195-ft. 1/13/2017 1/13/2017 2.00 COMPZN RPCOMP PULD P RIH w/BHA#1 from195-ft while 195.0 1,818.0 10:00 12:00 picking up 3-1/2 PH-6 12.95#,P-110 Work string from Pipe shed tot 818-ft. Torque conn.to 7k ft/lbs.,Drifting to 2.625". Monitoring displacement via TT. Circulate 2 drill pipe volumes every 60 joints picked up to flush scale from inside work string. PU wt=70K, SO wt=69K. 1/13/2017 1/13/2017 4.00 COMPZN RPCOMP PULD P Continue to RIH w/BHA#1 while 1,818.0 3,948.0 12:00 16:00 picking up 3-1/2 PH-6 12.95#,P-110 Work string from Pipe shed from1,818 -ft to 3,948-ft. Torque conn.to 7k ft/lbs., Drifting to 2.625". Monitoring displacement via TT. CBU until clean at 10 bpm @ 2,916 psi due to signs of schmoo and scale at the shakers. PU wt=85K,SO wt=76K. 1/13/2017 1/13/2017 1.50 COMPZN RPCOMP PULD P Continue to RIH w/BHA#1 while 3,948.0 5,100.0 16:00 17:30 picking up 3-1/2 PH-6 12.95#,P-110 Work string from Pipe shed from3,948 -ft to 5,100-ft. Torque conn.to 7k ft/lbs.,Drifting to 2.625". Monitoring displacement via TT. Circulate 2 drill pipe volumes every 60 joints picked up to flush scale from inside work string PU wt=85K,SO wt=76K. 1/13/2017 1/13/2017 1.00 COMPZN RPCOMP SVRG P Serviced Rig and Topdrive. 5,100.0 5,100.0 17:30 18:30 1/13/2017 1/13/2017 0.50 COMPZN RPCOMP RGRP T Repair to Buggy on Pipe Skate. 5,100.0 5,100.0 18:30 19:00 1/13/2017 1/13/2017 1.00 COMPZN RPCOMP PULD P Continue to RIH w/BHA#1 while 5,100.0 5,819.0 19:00 20:00 picking up 3-1/2 PH-6 12.95#,P-110 Work string from Pipe shed from5,100 -ft to 5,819-ft. Torque conn.to 7k ft/lbs., Drifting to 2.625". Monitoring displacement via TT. Circulate 2 drill pipe volumes every 60 joints picked up to flush scale from inside work string 1/13/2017 1/13/2017 0.25 COMPZN RPCOMP CIRC P Circulated 2 X String volune to flush 5,819.0 5,819.0 20:00 20:15 string.9 BPM 3290 psi. Page 5/12 Report Printed: 1/25/2017 • • Operations Summary (with Timelog Depths) -414 2L-315 ConocoP°hillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/13/2017 1/13/2017 2.25 COMPZN RPCOMP PULD P Continue to RIH w/BHA#1 while 5,819.0 7,378.0 20:15 22:30 picking up 3-1/2 PH-6 12.95#,P-110 Work string from Pipe shed from5,819 -ft to 7,378-ft. Torque conn.to 7k ft/lbs.,Drifting to 2.625". Monitoring displacement via TT. Circulate 2 drill pipe volumes every 60 joints picked up to flush scale from inside work string 1/13/2017 1/14/2017 1.50 COMPZN RPCOMP WASH P Washed down from 7,378'to 7,428' 7,378.0 7,450.0 22:30 00:00 Pump 6BPM 1880 psi.Slowed pupm to 3 BPM 500 psi and washed from 7,428'to 7,450'. 1/14/2017 1/14/2017 8.00 COMPZN RPCOMP JAR P Gather Parameters:UP wt=130K, 7,450.0 7,460.0 00:00 08:00 DN wt=86K, ROT=100K at 10 rpm's,5.5k free torque with Pumps off; UP wt=124K,DN wt=86K,ROT= 98K at 15 rpm's,5.5k free torque with Pumps on at 3 bpm at 500 psi. Continue to wash down from 7,450-ft MD to 7,458-ft MD at 3 bpm at 510 psi. Set down 3K at 7,458-f,PU and rotate over fish,then slide and engage and swallow fish to 7,460-ft. w/18-ft in on jt#233.Pull 10k over string wt, Slack off to release trapped Tq from string. Begin jarring with max hit of 60K OSW and straight pulls up to 160k OSW. Release off fish with out difficulties. 1/14/2017 1/14/2017 1.50 COMPZN RPCOMP CIRC P While conducting Post jarring 7,460.0 7,440.0 08:00 09:30 inspection,CBU at 6 BPM @ 2,000 psi,8%F/O,total stks pumped= 1,240.and recovered small amount of sand, Pump 30 bbl sweep and chase surface to surface,pulll joint and blow down Top Drive. Pump 25 bbl high visc sweep at 8 bpm at 3,270 psi w/ 11%F/O Total stks pumped=2,032 1/14/2017 1/14/2017 0.25 COMPZN RPCOMP OWFF P Lay down jt#232 and monitor well for 7,440.0 7,410.0 09:30 09:45 10 minutes-Static. Blow down Top drive 1/14/2017 1/14/2017 2.00 COMPZN RPCOMP TRIP P POOH from 7,410-ft to 3,658-ft MD. 7,410.0 3,658.0 09:45 11:45 Monitoring displacement via TT 1/14/2017 1/14/2017 0.25 COMPZN RPCOMP SFTY T Held Stand up with all on location due 3,658.0 3,658.0 11:45 12:00 3 in field incidents in 3 days. Discussed being on the right page by having good thorough change outs with alternates. Also making good decisions before acting(3 second rule) 1/14/2017 1/14/2017 2.25 COMPZN RPCOMP TRIP P Contninue to POOH to BHA#1 from 3,658.0 194.0 12:00 14:15 3,658-ft to 194-ft 1/14/2017 1/14/2017 0.25 COMPZN RPCOMP OWFF P Monitor well-Static 194.0 194.0 14:15 14:30 1/14/2017 1/14/2017 1.50 COMPZN RPCOMP BHAH P Laid down Fishing BHA. 194.0 0.0 14:30 16:00 1/14/2017 1/14/2017 0.50 COMPZN RPCOMP BHAH P Cleared Rig Floor. 0.0 0.0 16:00 16:30 Page 6/12 Report Printed: 1/25/2017 • • Operations Summary (with Timelog Depths) _',f 2L-315 ccoPhitlips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/14/2017 1/14/2017 0.50 COMPZN WELLPR BHAH P Made up Test Packer. 0.0 0.0 16:30 17:00 1/14/2017 1/14/2017 0.75 COMPZN WELLPR TRIP P RIH to 1,014'. 0.0 1,014.0 17:00 17:45 1/14/2017 1/14/2017 0.50 COMPZN WELLPR MPSP P Set Packer. 1,014.0 1,014.0 17:45 18:15 1/14/2017 1/14/2017 1.00 COMPZN WELLPR PRTS T Rrigged up lines to Test At.Line was 1,014.0 1,014.0 18:15 19:15 obstructed.Trouble shoot Line Obstruction. 1/14/2017 1/14/2017 1.00 COMPZN WELLPR PRTS T Rigged up MPD line to test IA. 1,014.0 1,014.0 19:15 20:15 1/14/2017 1/14/2017 0.25 COMPZN WELLPR PRTS P Tested IA 3000 psi for 10 Min.Good 1,014.0 1,014.0 20:15 20:30 test. 1/14/2017 1/14/2017 0.50 COMPZN WELLPR MPSP P Unseated Packer and Rig down lines. 1,014.0 1,014.0 20:30 21:00 1/14/2017 1/15/2017 3.00 COMPZN WELLPR TRIP P RIH with Test Packer from 1,014'to 1,014.0 3,950.0 21:00 00:00 3,950'. 1/15/2017 1/15/2017 1.75 COMPZN WELLPR TRIP P Continue RIH with Test Packer from 3,950.0 6,004.0 00:00 01:45 3,950'to 6,004'. 1/15/2017 1/15/2017 0.50 COMPZN WELLPR PRTS P Set Packer @ 6,009'and tested 6,004.0 6,009.0 01:45 02:15 Casing bled from 2500 psi to 1500 psi Test failed. 1/15/2017 1/15/2017 0.25 COMPZN WELLPR TRIP P POOH from 6,009'to 5,530'. 6,009.0 5,530.0 02:15 02:30 1/15/2017 1/15/2017 2.50 COMPZN RPCOMP PRTS P Tested Casing @ 5,540' to 3000 psi 5,530.0 5,915.0 02:30 05:00 for 10 Min Passed.Tested Casing @ 5,635' to 3000 psi for 10 Min Passed. Tested Casing @ 5,730' to 3000 psi for 10 Min Passed.Tested Casing @ 5,821' to 3000 psi for 10 Min Passed. Tested Casing @ 5,915' to 2500 psi Bled to 1500 psi Failed. Hole in Casing between 5,821'and 5,915'. 1/15/2017 1/15/2017 0.25 COMPZN WELLPR RURD P Rigged down and blew down lines. 5,915.0 5,915.0 05:00 05:15 1/15/2017 1/15/2017 0.50 COMPZN WELLPR CIRC P CBU 5 BPM 710 psi. 5,915.0 5,915.0 05:15 05:45 1/15/2017 1/15/2017 0.25 COMPZN WELLPR OWFF P OWFF Static. 5,915.0 5,915.0 05:45 06:00 1/15/2017 1/15/2017 3.50 COMPZN WELLPR TRIP P POOH From 5,915'to Surface. 5,915.0 0.0 06:00 09:30 1/15/2017 1/15/2017 0.50 COMPZN WELLPR BHAH P Laid down Test Packer and cleared 0.0 0.0 09:30 10:00 Rig Floor. 1/15/2017 1/15/2017 2.50 COMPZN RPCOMP BHAH P Picked up and Made up Cleanout BHA 0.0 249.0 10:00 12:30 per Baker Rep. 1/15/2017 1/15/2017 6.00 COMPZN RPCOMP TRIP P RIH from 249'to 7,431'. 249.0 7,431.0 12:30 18:30 1/15/2017 1/15/2017 1.00 COMPZN RPCOMP REAM P Washed out Fill over Seal Stub from 7,431.0 7,474.0 18:30 19:30 7,431'to 7,474'.Took weight 5K from 7,462'to 7,474'.20 RPM 3BPM 555 psi.Tq 6.5K. 1/15/2017 1/15/2017 1.00 COMPZN RPCOMP CIRC P Pumped 25 Bbl Hi Vis and Circulated 7,474.0 7,470.0 19:30 20:30 it out of the hole.5 to 6 BPM 1,360 to 2,000 psi.Observed Frac Sand and Scale on BU with Sweep. 1/15/2017 1/15/2017 0.50 COMPZN RPCOMP PULD P Laid down 2 Singles. 7,470.0 7,408.0 20:30 21:00 Page 7/12 Report Printed: 1/25/2017 • •.„„,v,,,. :._. , . xr ,{ . ,.- -,- ,. .,,, -,,,,..„, Operations Summary (with Timelog Depths) , ff 2L-315 coPhft!ps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time: End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/15/2017 1/15/2017 0.50 COMPZN RPCOMP OWFF P OWFF Static. 7,408.0 7,408.0 21:00 21:30 1/15/2017 1/15/2017 1.00 COMPZN RPCOMP SVRG P Serviced Rig and Topdrive. 7,408.0 7,408.0 21:30 22:30 1/15/2017 1/16/2017 1.50 COMPZN RPCOMP TRIP P POOH from 7,408'to 4,936'.UW 97K 7,408.0 4,936.0 22:30 00:00 DW 81K. 1/16/2017 1/16/2017 2.75 COMPZN RPCOMP TRIP P Continue to POOH f/4,936-ft to 249-ft 4,936.0 249.0 00:00 02:45 1/16/2017 1/16/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow-static 249.0 249.0 02:45 03:00 1/16/2017 1/16/2017 2.75 COMPZN RPCOMP BHAH P POOH laying down BHA#2 as per 249.0 0.0 03:00 05:45 BOT Fishing Rep. Calculated Displ=35.88/Actual Displ.=35.5 bbls 1/16/2017 1/16/2017 2.75 COMPZN RPCOMP BHAH T PU,MU Fishing BHA#3 and over 0.0 0.0 05:45 08:30 torqued 4,000 ft/lb.connection @ Lubricated Bumper Sub and Over shot drive with GBR power tongs. Break apart and lay down components. Service Top Drive and Continue to conduct MP2's while waiting for replacement tools to arrive from Dead Horse. 1/16/2017 1/16/2017 1.25 COMPZN RPCOMP BHAH P PU,MU and RIH with Fishing BHA#3 0.0 202.0 08:30 09:45 (4-11/16"Overshot w/3-1/2 Grapple) to 202-ft. 1/16/2017 1/16/2017 5.25 COMPZN RPCOMP TRIP P Continue to RIH from 202-ft to TOF @ 202.0 7,455.0 09:45 15:00 7,455-ft 1/16/2017 1/16/2017 0.50 COMPZN RPCOMP FISH P Engage Fish with Overshot. 7,455.0 7,458.0 15:00 15:30 1/16/2017 1/16/2017 7.75 COMPZN RPCOMP JAR P Attempt to Jar Fish free.219 Hits @ 7,458.0 7,458.0 15:30 23:15 60K over pulling up to 160K over after each hit.Varied Pump from 1 BPM 380 psi to 3.5 BPM 3,200 psi.No Success.Released Overshot. 1/16/2017 1/17/2017 0.75 COMPZN RPCOMP 'CIRC P CBU while inspecting Derrick.5 BPM 7,458.0 7,455.0 23:15 00:00 1,188 psi. 1/17/2017 1/17/2017 4.00 COMPZN RPCOMP TRIP P Derrick inspection post jarring 7,455.0 0.0 00:00 04:00 operations. TRIP OOH from 7,448'to 202'monitor well for flow prior to Laying down BHA+HWDP. 1/17/2017 1/17/2017 1.50 COMPZN RPCOMP BHAH P LD BHA#three. 0.0 04:00 05:30 1/17/2017 1/17/2017 1.00 COMPZN RPCOMP BHAH X PU BHA#four. 05:30 06:30 1/17/2017 1/17/2017 4.50 COMPZN RPCOMP TRIP X RIH prep to wash over stump. 0.0 7,451.0 06:30 11:00 1/17/2017 1/17/2017 1.50 COMPZN RPCOMP WASH X Wash over tubing stub at 7,451'MD. 7,451.0 7,451.0 11:00 12:30 Circulate sweep prep to POOH. 1/17/2017 1/17/2017 3.50 COMPZN RPCOMP TRIP X POOH to 296'MDmonitoring well. 7,451.0 296.0 12:30 16:00 1/17/2017 1/17/2017 0.50 COMPZN RPCOMP OWFF X @ 300'monitor well for flow while 296.0 296.0 16:00 16:30 service top drive and blocks. 1/17/2017 1/17/2017 2.50 COMPZN RPCOMP BHAH X POOH with BHA#four 296.0 0.0 16:30 19:00 Page 8/12 Report Printed: 1/25/2017 III III Operations Summary (with Timelog Depths) tz 2L-315 ConocoP'taifilps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/17/2017 1/17/2017 4.50 COMPZN RPCOMP WAIT X Waiting for completion equipment out 19:00 23:30 of Deadhorse. Clean rig/ maintenance while STBY. 1/17/2017 1/18/2017 0.50 COMPZN RPCOMP PUTB X PU, MU and RIH w/Poor boy 0.0 26.0 23:30 00:00 overshot,2-6-ft x 2-7/8 Pup joints,2- 7/8 XN Nipple w/2.313"x 2.205"No- Go., 1-2 7/8"x 6-ft pup joint, 1/18/2017 1/18/2017 1.00 COMPZN RPCOMP PUTB X Continue toPU,MU and RIH w/2-7/8 26.0 62.0 00:00 01:00 Completion Packer and PBR from 26- ft and RIH to 62-ft. 1/18/2017 1/18/2017 4.00 COMPZN RPCOMP RCST X Change over and RIH with 2-7/8 lower 62.0 7,448.0 01:00 05:00 completion from 62-ft to 7,448-ft on 3- 1/2, 12.95#,P110 PH-6 work string. 1/18/2017 1/18/2017 0.50 COMPZN RPCOMP RURD X Rig up bail extensions and prepare for 7,448.0 7,448.0 05:00 05:30 CI circulation placement. 1/18/2017 1/18/2017 2.50 COMPZN RPCOMP PACK X Tag top of tubing stub at 7,458'. 7,448.0 7,458.0 05:30 08:00 Circulate 100 BBLs 1%BV of CI at 4 BPM. Shear out shear pins and drop B&R. Pressure uo to 2,500 PSI to ser PKR. Pressure up to 2,750 PSI and shear out of PBR. PBR top at 7,341' MD. 1/18/2017 1/18/2017 2.00 COMPZN RPCOMP PRTS X Lay down two singles and set test pkr 7,458.0 7,252.0 08:00 10:00 for test proceeudres. set at 7,252'MD PT to 2,500 PSI(FAILED) PU sngl and re-set test pkr. Test to 2,500 PSI (FAILED). 1/18/2017 1/18/2017 2.00 COMPZN RPCOMP PRTS XT After monitoring well PUH to 5,360 7,252.0 5,630.0 10:00 12:00 close upper VBR's and test IA to 2,500 PSI(GOOD TEST). 1/18/2017 1/18/2017 3.50 COMPZN RPCOMP TRIP XT BD lines and POOH from 5,360'MD. 5,630.0 0.0 12:00 15:30 Lay down seal jt and pup below PKR. 1/18/2017 1/18/2017 6.50 COMPZN RPCOMP TRIP XT Pick up test PKR and RIH with same. 0.0 7,339.0 15:30 22:00 1/18/2017 1/18/2017 1.00 COMPZN RPCOMP PRTS XT Set test PKR at 7,339'test to 2,500 7,339.0 7,336.0 22:00 23:00 PSI. 8 min test pressure fell to 1,850 PSI. (FAIL). PUH 3'set back down for retest. 2,500 PSI 8 mn test pressure fell to 1,900 PSI.(Fail). Checked IA for any pressure--- Pressure=0 PSI. Call town engineer. Bleed off and POOH. 1/18/2017 1/19/2017 1.00 COMPZN RPCOMP TRIP XT LD singles 120 up WT. 87K DWN. 7,336.0 5,924.0 23:00 00:00 Continue to POOH standing back. 1/19/2017 1/19/2017 2.50 COMPZN RPCOMP TRIP XT Continue to POOH standing back PH6 5,924.0 0.0 00:00 02:30 P110. Prepare for drill collar arrival for fishing string. 1/19/2017 1/19/2017 2.00 COMPZN RPCOMP WAIT XT Waiting on drill collars to arrive from 02:30 04:30 Deadhorse Baker shop. Load pipe shed strap and drift. 1/19/2017 1/19/2017 0.50 COMPZN RPCOMP BHAH XT Pick up fishing BHA. Baker fishing 0.0 300.0 04:30 05:00 jars,accelerator,six drill collars,and PBR retrieving tool. 1/19/2017 1/19/2017 5.00 COMPZN RPCOMP TRIP XT RIH with PH6 P110 work string to 300.0 7,430.0 05:00 10:00 retrieve lower completion. 1/19/2017 1/19/2017 1.00 COMPZN RPCOMP FISH XT Engage fish at 7,340'MD. Sheared at 7,430.0 7,400.0 10:00 11:00 40k over. 120K up,90K Dwn. lay down single.prep to reverse CI sea water to surface. Page 9/12 Report Printed: 1/25/2017 ! • Operations Summary (with Timelog Depths) • 2L-315 Con000Phillips Rig: DOYON 142 Job: RECOMPLETION Time Log stat Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/19/2017 1/19/2017 3.00 COMPZN RPCOMP CIRC XT Reverse circulate sea water to rock 7,400.0 6,690.0 11:00 14:00 washer.Start to POOH pulling wet so Drop circ ball in prep to POOH. Shear circ sub at 2,700 PSI. 1/19/2017 1/19/2017 4.50 COMPZN RPCOMP PULL XT POOH.lay down fish and fishing tools. 6,690.0 300.0 14:00 18:30 1/19/2017 1/19/2017 0.50 COMPZN RPCOMP CLEN XT Clean and clear rig floor of fishing 18:30 19:00 equiment. Prep to RBIH with test PKR asym. 1/19/2017 1/19/2017 1.50 COMPZN RPCOMP RGRP XT Change out Saver Sub on top drive. 19:00 20:30 1/19/2017 1/19/2017 0.50 COMPZN RPCOMP BHAH XT Make up BHA of baker bridge plug 20:30 21:00 and test plug for casing leak identification process. 1/19/2017 1/20/2017 3.00 COMPZN RPCOMP TRIP XT RIH 0.0 4,990.0 21:00 00:00 1/20/2017 1/20/2017 2.00 COMPZN RPCOMP TRIP XT Continue to RIH with test packer-"G" 4,990.0 7,448.0 00:00 02:00 Bridge plug assembly from 4,990-ft to 7,453-ft MD. PU 117K,DN 86K 1/20/2017 1/20/2017 1.00 COMPZN RPCOMP PACK XT MU Top Drive, tag up on tubing 7,448.0 7,458.0 02:00 03:00 stump at 7,458'MD. Set bridge plug and release off. Set test PKR at 7,438'COE. R/U for testing proceedures. 1/20/2017 1/20/2017 3.00 COMPZN RPCOMP PRTS XT Begin presure testing of casing 7,458.0 7,420.0 03:00 06:00 looking for holes. Tested center element at 7,438',7,430',7,420' Passed. {{7,410',7,415',{FAILED}}. Retested at 7,420'twice more and ((FAILED)). lowest hole appears to be in this proximity. 1/20/2017 1/20/2017 1.00 COMPZN RPCOMP FISH XT Fish Bridge plug and rig down testing 7,420.0 7,420.0 06:00 07:00 equipment in preparation to POOH. 1/20/2017 1/20/2017 3.00 COMPZN RPCOMP PULL XT POOH standing back PH-6 to lay 7,420.0 0.0 07:00 10:00 down plug testing BHA. 1/20/2017 1/20/2017 1.00 COMPZN RPCOMP BHAH XT Lay down plug testing BHA.Monitor 10:00 11:00 well for flow. 1/20/2017 1/20/2017 1.50 COMPZN RPCOMP BHAH P Clean rig floor. Check tally's and 11:00 12:30 begin picking up lower completion eqiupment as per tally. 4 1/4"PBOS, 2.875"Camco XN nip,PHL Halliburton 13-17K retrievable packer,Baker 80- 32 20'Polish Bore Receptacle. 1/20/2017 1/20/2017 6.50 COMPZN RPCOMP RCST P RIH with completion. 0.0 7,440.0 12:30 19:00 1/20/2017 1/20/2017 2.00 COMPZN RPCOMP RCST P Spot 1%CI ,Wash over tubing stub, 7,440.0 7,464.0 19:00 21:00 drop B&R to set PKR at 7,431'mid element of PKR. Pull 10k over to confirm PKR set. Shear PBR 5K over pull to shear. 1/20/2017 1/21/2017 3.00 COMPZN RPCOMP PULD P POOH laying PH-6 P110 sideways. 7,464.0 4,944.0 21:00 00:00 1/21/2017 1/21/2017 5.00 COMPZN RPCOMP PULD P Continue to POOH laying down 3-1/2 4,944.0 0.0 00:00 05:00 PH-6 work string. 1/21/2017 1/21/2017 1.50 COMPZN RPCOMP BHAH P Clean rig floor. Pull wear ring. 0.0 05:00 06:30 Arrange 2-7/8 lower completion and upper 3-1/2 as per run order. Page 10/12 Report Printed: 1/25/2017 e 4z • Operations Summary (with Timelog Depths) 2L-315 CoriocoPhilltps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time. Dur(hr)_i Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/21/2017 1/21/2017 11.00 COMPZN RPCOMP RCST P Pickup Baker 80-32 seal assembly. 0.0 7,392.0 06:30 17:30 RIH with 2 7/8"production tubing, upper jewelry and 3 1/2"production tubing as per run order. bring pump on and circ down to confirm on depth with PBR. Pressure bump indicating proper insert. PUH to pump Cl. 1/21/2017 1/21/2017 2.00 COMPZN RPCOMP CIRC P Circulate corrision inhibited sea water 7,392.0 7,392.0 17:30 19:30 around as per program @ 2BPM. 240 PSI with 200 BBLS pumped. 1/21/2017 1/21/2017 1.00 COMPZN RPCOMP PACK P Sting in and space out with mule shoe 7,392.0 7,410.0 19:30 20:30 @ 7,410-ft and set HES Perma Latch PHL Packer @ 4,923-FT MD(positive pressure bump),Pressure up to 3,500 PSI as per Halliburton procedures. PT all systems and check set PKR prior to shear out of PBR @ 3,000 psi with 10K over pull. 1/21/2017 1/21/2017 1.00 COMPZN RPCOMP HOSO P Space out lay down 4 singles pick up 7,410.0 7,410.0 20:30 21:30 space out pups 10.26'and 8.13'. pick joint 151 back up for true count. 1/21/2017 1/21/2017 2.00 COMPZN RPCOMP HOSO P Make up hanger Assembly and 7,410.0 0.0 21:30 23:30 landing joint w/pup. DBL check space out with pumps running. Space out confirmed. drain stack,blow down lines and land hanger. RILDS. 1/21/2017 1/22/2017 0.50 COMPZN RPCOMP THGR P Pressure test tubing to 3K. test 23:30 00:00 passed. Prep for IA test then shear out SOV. 1/22/2017 1/22/2017 1.00 COMPZN RPCOMP THGR P Pressure test tubing/IA to 2,500 PSI 00:00 01:00 (PASSES) Shear out SOV. Confirm SO with circulating both directions at 1.5 BPM @ 420 psi. 1/22/2017 1/22/2017 1.00 COMPZN RPCOMP THGR P Install BPV.PT same/blow down all 01:00 02:00 lines. 1/22/2017 1/22/2017 1.50 COMPZN RPCOMP CLEN P Clear rig floor and prep for 13-5/8 5M 02:00 03:30 Annular element change out. 1/22/2017 1/22/2017 2.00 COMPZN WHDBOP NUND P Remove flow nipple,air boot on top 03:30 05:30 annular,remove choke and kill lines. 1/22/2017 1/22/2017 3.00 COMPZN WHDBOP RGRP P NU Potato Masher(Annular Cap 05:30 08:30 removal Tool) to Annular cap and remove cap. Pull element and replace with new element. Install Cap and remove Potato masher. 1/22/2017 1/22/2017 2.00 COMPZN WHDBOP NUND P Remove studs from bottom of BOP 08:30 10:30 Stack. Set back stack and secure. RD skate from sub base and load in pipe shed. Clean pits. 1/22/2017 1/22/2017 1.00 COMPZN WHDBOP NUND P Break apart and set back 11"5M x 13- 10:30 11:30 5/8"Adapter/spacer spool assembly. Hang tree in preparation for nipple up. 1/22/2017 1/22/2017 1.50 COMPZN WHDBOP NUND P Re-install FMC Adapter on wellhead 11:30 13:00 and Nipple up. 1/22/2017 1/22/2017 0.25 COMPZN WHDBOP DHEQ P Pressure test void at 250/5,000 psi 13:00 13:15 for 10 minutes.-Good Test 1/22/2017 1/22/2017 2.00 COMPZN WHDBOP NUND P Nipple up tree and confirm orientation 13:15 15:15 with DSO Page 11/12 Report Printed: 1/25/2017 • • 0. ii0 Operations Summary (with Timelog Depths) 0 2L-315 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time, Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB),. .... End Depth(ftKB) 1/22/2017 1/22/2017 0.50 COMPZN WHDBOP MPSP P Pull BPV and install test plug. 15:15 15:45 1/22/2017 1/22/2017 1.00 COMPZN WHDBOP DHEQ P Pressure test tree at 250/5,000 psi- 15:45 16:45 good test. 1/22/2017 1/22/2017 2.00 COMPZN RPCOMP FRZP P RU Little Red Service and pressure 16:45 18:45 test lines to 2,500 psi. Freeze Protect well with 45 bbls at 2 bpm @ 1,400 ICP and 1800 FCP. Allow well to swap and RD LRS 1/22/2017 1/22/2017 0.75 COMPZN WHDBOP MPSP P Open Tree and bleed off Pressure. 18:45 19:30 Set BPV via Dry Rod. 1/22/2017 1/22/2017 0.50 COMPZN RPCOMP OTHR P Dress tree and Install gauges, 19:30 20:00 Gather Shut in pressures TBG=0, IA =0,and OA=460 Release Doyon 142 @ 20:00 on 1-22- 17 Page 12/12 Report Printed: 1/25/2017 e'I , KU PROD 2L-315 ConocoPhillips ; Well Alliirutes Max e&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status incl 0) MD(ftKB) Act Btm(ftKB) con000`Pteips 501032027600 TARN PARTICIPATING AREA PROD 58.90 8,163.85 8,236.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-315,2/22/20171.48:58 PM SSSV:None 95 11/23/2015 Last WO: 1/22/2017 37.31 12/15/1998 Verpr:l schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,528.0 1/28/2017 Rev Reason:PULL RHC,BALL 8 ROD,GLV pproven 2/3/2017 HANGER,25.0 LI (J C/O&TAG Casing Strings � ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I CONDUCTOR 16 15.062 30.0 108.0 108.0 62.58 H-40 WELDED Casing Description SOD(in) ID(in) Top(ftKB) set Depth(ftKB) Set Depth(TVD).. Wt/Len(I...Grade Top Thread 1 . . r . r' SURFACE 7 5/8 6.875 28.4 2,400.3 2,290 7 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 27.0 8,228.0 5,623.0 15.50 L-80 LTC MOD �� rµ;.,Tubing Strings Js.n.CONDUCTOR;30.0-108.0- .f 'f Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER 27/8 2.441 25.0 7,410.4 5,177.3 6.50 L-80 EUE 8rd w/Gas Lift Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inoi(°) Item Des Com (in) ..!, 25.0 25.0 0.10 HANGER FMC Gen V TC-1A-EMS,3-1/2 x 11 x 3-1/2 EUE 8rd Top 2.920 • / and Bottom 4,778.5 3,692.1 55.49 SLIDING SLV Baker CMU Sliding Sleeve w/2.812"BX Profile Ran in 2.810 Closed Postion PN:H810-79-4439 2,687 MD/2,500 GAS LIFT,2,356.6 I.: TVD 4,890.0 3,755.5 55.23 LOCATOR 2-7/8 EUE 8rd Locator Sub 2.420 4,890.5 3,755.8 55.23 SEAL ASSY Baker GBH-22 Seal Assembly 2.400 • 4,893.5 3,757.5' 55.21 PBR Baker 80-32 20-ft Polish Bore Receptacle w/5 pins= 3.250 SURFACE;28.4-2,400.3 33,150#shear 4,922.6 3,774.1 ' 55.06 PACKER Halliburton PHL Retrievable packer w/62,000 shear 2.380 release 4,975.8 3,804.7 54.89 NIPPLE Halliburton 2.875"x 2.313"X-Nipple SN:3093991 2.313 7,387.7 5,164.5 55.71 LOCATOR 3-1/2 EUE 8rd Locator Sub 2.990 SLIDING SLv;4,778.5 7,388.8 5,165.1 ' 55.70 SEAL ASSY Baker GBH-22 3.98"OD Seal Assembly 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-LOWER 4.8 2.400 7,392.0 7,454.0 5,201.9 GAS LIFT,4,834.1 ® w/Stacked Pkr Completion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl T) Item Des Com (in) 7,392.0 5,166.9 55.69 PBR Baker 80-32 20-ft Polish Bore Receptacle w/5 pins= 2.400 • 33,150#shear LOCATOR;4,890.0it 7,419.1 5,182.2 55.61 PACKER Halliburton"PHL"13-17K Retrievable Packer w/54,600# 2.360 SEAL ASSY;4,890.5-. - _ shear PBR,4,893.5 7,434.2 5,190.8 55.63 NIPPLE Halliburton 2.875"x 2.205"XN-Nipple 2.313 (w/RHC Plug Body Installed SN:G3059426 I -RHC,BALL 8 ROD PULLED 1-27-2017) PACKER;4,922s '" . 7,448.3 5,198.7 55.64 OVERSHOT 4-1/2"OD x 3-3/4"ID x6-ft Baker Machined Poor Boy 3.730 Overshot w/15K Shear pins installed w/5.7-ft of swallow NIPPLE;4,975.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. N Set Depth( D)(...Wt(lb/ft) Grade Top Connection TUBING-Original 3 1/2 2.992 7,448.0 7,490.4 5,222.5 9.30 L-80 EUE8rdMOD 1998 Completion Details LOCATOR;7,387.7 AM Nominal ID Tap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Das Com (in) `,.. " 7,465.5 5,208.4 55.66 NIPPLE CAMCO'D'NIPPLE 2.750 SEAL ASSY;7,388.8 s 7,473.1 5,212.7 55.67 LOCATOR BAKER LOCATOR 2.985' PBR;7,392.0 1 7,473.8 5,213.1 55.67 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY w/15' 2.985 EFFECTIVE SEAL STROKE Perforations&Slots shot Dens Top(ND) Bbn(ND) (shots/ PACKER;7,419.0 - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,765.0 7,805.0 5,376.7 5,398.8 S-3,2L-315 1/23/1999 4.0 IPERF 2 1/2"DP 180 DEG PH • 7,900.0 7,920.0 5,450.1 5,460.8 S-3,2L-315 4/23/2016 6.0 APERF PERFORATE 7900'- NIPPLE;7,434.2 7920'WITH 2.5"6 SPF 60 DEG PHA ii Mandrel Inserts OVERSHOT;7,448.3 tj St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;7,465.5 1 2,356.6 2,255.4 Camco KBG-2- 1 GAS LIFT GLV BTM 0.188 1,654.0 1/27/2017 9 2 4,834.1 3,723.7 Camco KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 1/27/2017 LOCATOR;7,473.1II 9 Notes:General&Safety SEAL ASSY;7,473.8 End Date Annotation 6/15/2009 NOTE:View Schematic w/Alaska Schematic9.0 IF IPERF;7,765.0-7.805.0 APERF;7,900.0-7,920.0 PRODUCTION 5.5553.5";27.0- 0,228.0_ • • SOF Tjt sA THE STATE Alaska Oil and Gas ti1- � 7, f Conservation Commission o ALASKA. 333 West Seventh Avenue ' '' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 °FA "_'g8Q` Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat Sr. Wells Engineer �� � L ,, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-315 Permit to Drill Number: 198-218 Sundry Number: 316-627 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED thisy of January, 2017. RBDIVI3 IL Jr: L;t% 0 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 6 2016 APPLICATION FOR SUNDRY APPROVALSOzrS 4(` 7 20 AAC 25.280 (� 1.Type of Request: Abandon LJ Plug Perforations El Fracture Stimulate LJ Repair Well U pera ions shutdownH Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Programs Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing H Other: Stacked Pkr n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑✓ ' 198-218 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20276-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a , Will plannedperforations require a spacing exception? YesKRU 2L 315 " q P 9 p ❑ No❑� 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL380051 ` Kuparuk River Field/Tarn Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8236' 5627' < 8228' . 5623' 1673 7520' none Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 2367' 7.625" 2399' 2289' Intermediate Production 8196' 5.5"x 3.5" 8226' 5622' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7765'-7805' • 5377'-5399' 3.5" L-80 7490' 7900'-7920' 5450'-5460' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SSSV:none PACKER-none 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/28/2016 OIL ❑✓ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown H Abandoned H 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew Beat 265-6341 Title Sr.Wells Engineer P one 7U-- Signature Date 12/15/Ikj COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test e Mechanical Integrity Test ❑ Location Clearance ❑ ` Other: pop fit.1 to 05-0 0 /7 5 1 J E 1(4 11= Bop 1— 1 �i5-00 51_I Post Initial Injection MIT Req'd? Yes ❑ No e RSDt S Spacing Exception Required? Yes H Nod Subsequent Form Required: /0—40Z-)- L ,,,,,, t APPROVED BY Approved by: (,,Wtti COMMISSIONER THE COMMISSION Date: /— L—/7 Submit Form and Form 10-403 Revised 11/20150 R1PG1 awpI�C81 nLvalid for 12 months f /����e of approval. Attachments in Duplicate • • Illy- RECEIVED ConocoPhillips Alaska DEC 16 2016 P.O. BOX 100360 AGC ANCHORAGE,ALASKA 99510-0360 December 15,2016 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby submits an Application for Sundry Approval to work over Tarn Producer 2L-315 (PTD# 198-218). 2L-315 was originally drilled and completed in 1998 as a Tarn producer.The well continued to produce until TxIA communication was observed during routine well work in May 2016.After a failing MIT-T and a failing CMIT- TxIA,additional diagnostics were run and multiple small tubing leaks were discovered as well as a casing leak around 7,413' KB.2L-315 has remained shut-in waiting on a workover. The proposed workover scope for 2L-315 is to remove the existing production tubing,perform a test packer run to confirm casing leak depth,and install new production tubing with a stacked packer to isolate casing leak. / This Sundry is intended to document the proposed well work,including the modifications to the production casing, and request approval to work over the well. If you have any questions or require any further information,please contact me at 265-6341. Sincerely, . s` ,r7L Andrew Beat Wells Engineer CPAI Drilling and Wells • • 2L-315 Rig Workover P&R Tubing w/Stacked Packer (PTD#: 198-218) Current Status: This well was shut in on June 8,2016 and is currently waiting to be worked over to isolate a casing leak. Scope of Work: Pull the existing 3-1/2"tubing,perform test packer run,install new 3-1/2"tubing with stacked packer. / General Well info: Well Type: Producer MPSP: 1,673 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,201 psi/5,289' TVD(8.1 ppg EMW)measured on 06/30/2016 Wellhead/Pressure Rating: FMC Gen V, 11"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TxIA failed-07/01/2016(Prod. Csg. leak at—7,413') Earliest Estimated Start Date: December 28,2016 Production Engineer: David Neville Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work **Plug already set in liner below SBE at 7,520' KB.** 1. Inspect pad and work area for hazards. Complete the PJSM. 2. RU Slickline. 3. RIH and pull OV from GLM#2 and leave open. 4. RD Slickine. 5. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV.Reverse circulate seawater. Obtain SITP&SICP,if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/2,500 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe, rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3 V2"tubing. a. If tubing does not pull free from seals,call out E-Line and cut tubing in the middle of the first full joint above the nipple at 7,465' KB. 6. MU 5.5"test packer assembly and RIH 7,350'KB. Set packer and test casing to 2,500 psi. a. If pressure test passes,RIH 100' and repeat casing test. Continue RIH until leak is found. b. If pressure test fails,POOH 100' and repeat casing test.Continue POOH until leak is found. 7. POOH laying down DP and test packer assembly. 8. MU&RIH with new 3-1/2"upper completion and stacked packer to SBE. ' a. Space out packer to be set—50-100' above highest passing casing test. / 9. Slowly cycle the charge pump and look for pressure increases or lack of returns as the seals engage. Shut down charge pump. Space out,mark the pipe,and pull out of the SBE. 10. Pump corrosion inhibited fluid down tubing and up IA to fill IA from the SBE to PBR. 1 • • 2L-315 Rig Workover P&R Tubing w/Stacked Packer (PTD#: 198-218) 11. Re-engage SBE and set stacked packer by pressuring up against plug set below SBE.,✓' 12. With tubing engaged,pressure test IA to 2,500 psi to confirm packer set and casing integrity. Shear out of PBR. 13. Install space out pups below the hanger,MU hanger.Load the IA with corrosion inhibited fluid.Land the hanger,RILDS. 14. PT the tubing to 3,Q00 psi,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 15. Pull the landing joint, install BPV. 16. ND BOPE. 17. NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 18. Freeze protect well with diesel. Set BPV. 19. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline: a. Pull SOV and run GL design. b. Pull catcher and plug. 3. RD Slickline. 4. Reset well house(s)and flowlines of adjacent wells. 5. Turn well over to operations. 2 • KUP PROD 111 2L-315 ConocoPhillips 1, Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crno<aarvatlx 501032027600 TARN PARTICIPATING AREA PROD 58.90 8,163.85 8,236.0 -°- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-315,7/13/20163:24:50 PM SSSV:Nipple 95 11/23/2015 Last WO: 37.31 12/15/1998 VerEcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,048.0 3/30/2016 Rev Reason:PULL CSV,SET PLUG& pproven 7/13/2016 ...... _.. _...__..... CATCHER s -1 z �' �, Casing Strings tl� Casing Descr ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WllLen(I..Grade Top Thread HANGER;25.9 CONDUCTOR 16 15.062 30.0 108.0 1080 62.58 H-40 WELDED 111 w a Casing Description OD(in) ID(in) Top(MB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread �. SURFACE 7 5/8 6.875 28.4 2,400.3 2,290.7 29.70 L-80 BTC-MOD . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)... Wt/Len(I...Grade 'Top Thread PRODUCTION 5.5'5,3.5" 5 1/2 4.950 27.0 8,228.0 5,623.0 15.50 L-80 LTC MOD Tubing Strings il Tubing Descr pbon String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection ` �`j TUBING 31/2 2.992 25.9 7,490.4 5,222.5 9.30 L-80 EUE8rdMOD Completion Details Nominal ID IIIITap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) -p,A/CONDUCTOR;30.0-108.0 - 25.9 25.9 0.11 HANGER FMC GEN V TUBING HANGER 3.500 501.0 500.9 1.04 NIPPLE CAMCO'DS'NIPPLE 2.875 NIPPLE;501.0 i 7,362.8 5,150.5 55.80 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"CAMCO 2.813 • PROFILE(CLOSED 12/13/2008) 7,465.5 5,208.4 55.66 NIPPLE CAMCO'D'NIPPLE 2.750 ' 7,473.1 5,212.7 55.67 LOCATOR 'BAKER LOCATOR 2.985 7,473.8 5,213.1 55.67 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY w/15' 2.985 'EFFECTIVE SEAL STROKE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) f Top(ND) Top Incl 7 Top(ftKB) (ftKB) (°) Des Com Date ID(in) 7,517.6 5,237.8 55.68 CATCHER 3.5"GS W/2.71"X 29"FLAT BTM AVA CATCHER 6/30 0.000 7,520.0 5,239.2' 55.68 PLUG 2.72 RBP 6/30/2016 0.000 SURFACE;28.4-2,400.3 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,765.0 7,805.0 5,376.7' 5,398.8 S-3,2L-315 1/23/1999 4.0 )PERF 2 1/2"DP 180 DEG PH GAS LIFT;4,440.8 7,900.0 7,920.0 5,450.1 5,460.8 S-3,2L-315 4/23/2016 6.0 APERF PERFORATE 7900'- 7920'WITH 2.5"6 SPF 60 DEG PHA Mandrel Inserts Sti SLEEVE-C;7,362.8 I 1 a i N Top(ND) Valve Latch Port Sloe TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 4,440.8 3,503.8 CAMCO KBG-2- 1 GAS LIFT -DMY BTM 0,000' 0.0 10/16/1999 9 2 7,413.0 5,178.8 CAMCO KBG-2- 1 GAS LIFT OV BTM ' 0.250 0.0 5/26/2016 GAS LIFT;7,413.0 _ 9 Notes:General&Safety End Date Annotation 6/15/2009 NOTE View Schematic w/Alaska Schematic9.0 NIPPLE;7,465.5 IOW LOCATOR;7,473.0 SEAL ASSY;7,473.8 -fs a CATCHER;7,517.6 l I' PLUG;7,520.0 vi IPERF;7,785.0-7,805.0 - APERF;7,900.0-7,920.0 - PRODUCTION 5.5'x3.5';27.0- 8,228.0 0 - k 5 - - 0 `ConocoPhillips 2L-315 s Tarn Producer P&R Tubing k 5 4 k s k a w/ Stacked Packer ' PROPOSED k k k , COMPLETION k 1 k , a Well Details: API: 50-103-20276-00 k ' k o PTD: 198-218 t ` s Wellhead: FMC Gen V 5M ; Tree: FMC 3-1/8" 5M ='. , Casing/Tubing Details: 16"62.58#H-40 Conductor to 108' MD I , 7-5/8"29.7# L-80 Surface to 2,400' MD 'l 5-1/2" 15.5# L-80 Liner to 7,475' MD 1 , 3-1/2" 9.3# L-80 Liner to 8,228' MD 1 '". 3-1/2" 9.3# L-80 Tubing to 7,490' MD I ; Misc Details: 14 KBG 2-9 GLM's Max Inclination: 58.9° k Max Dogleg: 6.2°/100' Last Tagged Fill: 8,048' MD Total Depth: 8,236' MD k I k r Perforation Details: i i 7,765'-7,805' MD—S3 Sand 1 ii i a Camco 2.813" DS Nipple 7,900'-7,920' MD—S3 Sand S 4 Stacked Packer w/ PBR Assy (depth dependent on test packer run) k , k 7,413'- Production Casing Leak I ` I k k y 5-'/z" to 3-W XO and SBE Ist- TE I Date: December 15,2016 Drawn By: Andrew Beat \P -2 g • • 21(2c WELL LOG TRANSMITTAL#903411916 To: Alaska Oil and Gas Conservation Comm. I V /September 9, 2016 Attn.: Makana Bender OCT 0 4 Z016 333 West 7th Avenue, Suite 100 DATA LOGGED 1O/5/2016 Anchorage, Alaska 99501 AOGOC K BENDER RE: Leak Detect Log with ACX: 2L-315 Run Date: 7/20/2016 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 2L-315 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20276-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-103-20276-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari ` ' �+ NOV 6900 Arctic Blvd. 31016 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / /4 , ,/ N um 4: raw V:r, P :°,-1*-- Nw v v O n J CD N a) L t C Y ca G r _ U d. 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F- a aQ STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r-- Performed: Performed: SuS end r Perforate F Other Stimulate Suspend r Alter Casing r Change Approved Program r-- Plug Plug for Redrill rPerforate New Pool r Repair Well r Re-enter Susp Well IT r- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 198-218 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20276-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380051 KRU 2L-315 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 8236 feet Plugs(measured) None true vertical 5627 feet Junk(measured) None Effective Depth measured 8099 feet Packer(measured) 0 true vertical 5556 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 2372 7 5/8 2400 2291 PRODUCTION 8201 51/2 8228 5623 sCANNED DEC a 82016 Pig`: lkU Perforation depth: Measured depth: 7765-7805, 7900-7920 True Vertical Depth: 5377-5399, 5450-5461 Tubing(size,grade,MD,and ND) 3.5, L-80, 7490 MD, 5222 ND 1,`, r i-1 Packers&SSSV(type,MD,and ND) NONE SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): None 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 214 177 177 1400 1400 Subsequent to operation 270 329 157 1400 200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL I- P ri n te d Printed and Electronic Fracture Stimulation Data r 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: N/A Contact Elan Manoppo @ 263-4323 Email Elan.R.Manoppo(a'�.conocophillips.com Printed Name Elan Mao'•o Title Tarn Dev. Team Lead Signature , IPhone:263-4323 Date tP f / Ii i0 4OP le �� ® I v�rL 7/ l 7/01(- 1(- Form 10-404 Revised 5/2015 A7/1/4.0 RBDMS 7/1/4.0RBDMS LV R:..! 1 9 2016 Submit Original Only • 2L-315 • DTTMS.JOBTYP SUMMARYOPS 3/25/16 PUMPING HOT DIESEL FLUSH 10 DOWN F/L, 30 DIWN TBG. JOB COMPLETE TRACKING ONLY 3/26/16 ASPH / PARAFFIN GAUGED TBG. TO 2.85"TO 5000' SLM. LIGHT PARAFFIN ENCOUNTERED. JOB COMPLETE. 3/29/16 PERFORATIONS- PERFORM WEEKLY BOP TEST, COMPLETED NITRIFIED FILL CLEANOUT FROM 7700' CTMD TO HARD TAG AT 8060' CTMD USING SLICK DIESEL AND DIESEL GEL SWEEPS AT 2.2 BPM EQUIVALENT, MAINTAINED 1;1 RETURNS THROUGHOUT CLEANOUT, LIGHT SAND CONCENTRATIONS OBSERVED, EST TOTAL SOLIDS VOLUME AT 8 BBLS, F/P TBG TO 8000' CTMD, READY FOR SLICKLINE DRIFT AND E-LINE PERF, JOB IN PROGRESS. 3/30/16 PERFORATIONS - DRIFT W/DMY PERF GUN ASSEMBLY&TAG TD @ 8048' SLM. READY FOR E- LINE PERFS (7900-7920' MD) 4/23/16 PERFORATIONS- PERFORATE 7900' -7920'WITH 2.5"6 SPF 60 DEG PHASED CCL TO TOP SHOT 7.7' CCL STOP AT 7892.3'AFTER SHOOTING PULLED UP HOLE 100'AND TOOLS BECAME STUCK AT 7814'. WORKED TOOLS AND PUMPED AT 5 BPM ON TUBING WITH NO LUCK. FISH IN HOLE 45' 350 LBS MAX OD 2.5"AT GUN 1 7/16" FISHING NECK. DIAGRAM GIVEN TO CPAI REP. 4/25/16 PERFORATIONS- RECOVERED E-LINE FISH @ 7994' SLM AFTER CHASING FISH DOWN FROM 7780' SLM. COMPLETE. Lp��}��1e��►►gg KUP D 2L-315 Co SocoPhi[ips .J erWClta Well Attribu Max Angle D TD • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl I) MD(ftKB) Act Btm(ftKB) cxroc,,,phdllps `0 501032027600 TARN PARTICIPATING AREA PROD 58.90 8,163.85 8236.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-315,6/27/20,6646.53 AM SSSV:Nipple 95 11/23/2015 Last WO: 37.31 12/15/1998 Vertical schemaso(actua0.:::......._... _ - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,048.0 3/30/2016 Rev Reason:PERFS ON 4/23/2016 pproven 6/26/2016 r Casing rings � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(0KB) Set Depth(TVD)...WtlLen(I...Grade Top Thread HANGER;25.9 sil CONDUCTOR 16 15.062 30.0 108.0 108.0 62.58 H-40 WELDED won Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen p...Grade Top Thread SURFACE 75/8 6.875 28.4 2,400.3 2,290.7_ 29.70 L-80 BTC-MOD � ���� Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I.. Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 27.0 8,228.0 5.623.0 15.50 L-80 LTC MOD i rl Tubing Strings 1` Tubing Description String Ma... ID(in) Top(ftKB( Set Depth(ft..I Set Depth(TVD)(...Wt(I5/t) Grade Top Connection TUBING Completion Details 74 31/2 2.992 25.9 90.4 5,222.5 9.30 L-80 EUE8rdMOD i uLL Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) _,•,,A`CONDUCTOR;30.0-106.0 _ 25.9 25.9 0.11 HANGER FMC GEN V TUBING HANGER 3.500 501.0 500.9 1.04 NIPPLE CAMCO'DS'NIPPLE 2.875 NIPPLE;501.0 7,362.8 5,150.5 55.80 SLEEVE-C •BAKER CMU SLIDING SLEEVE w/2.813"CAMCO 2.813 PROFILE(CLOSED 12/13/2008) 7,465.5 5,208.4 55.66 NIPPLE CAMCO'D'NIPPLE 2.750 7,473.1 5,212.7 55.67 LOCATOR BAKER LOCATOR 2.985 7,473.8 5,213.1 55.67 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY w/15' 2.985' EFFECTIVE SEAL STROKE • • • • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (') Des Com Run Date ID(in) • 7,465.0 5,208.2 55.66 VALVE 2.75"D-CAT STANDING VALVE(2.78"NOGG/ 5/25/2016 0.000 • • 43"OAL) Perforations&Slots SURFACE,28 4-2,400.3-. Shot Dens Top(TVD) Blm(TVD) (shots/ iii IF Top(ftKB) Btrn(60KB) (ftKB) (ftKB) Zone Date ft) Type Com 7,765.0 7,805.0 5,376.7 5,398.8 S-3,2L-315 1/23/1999 4.0 (PERF 2 1/2"DP 180 DEG PH GAS LIFT,4 44 a 7,900.0 7,920.0 5,450.1 5,460.8 S-3,2L-315 4/23/2016 6.0 APERF PERFORATE 7900'- 7920'WITH 2.5"6 SPF 60 DEG PHA Mandrel Inserts St 0-i SLEEVE C,7,362.8 1 on Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,440.8 3,503.8 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 10/16/1999 9 2 7,413.0 5,178.8 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 5/26/2016 •• 9 GAS LIFT;7,4130 - Notes:General&Safety End Date Annotation 6/15/2009 NOTE.View Schematic w/Alaska Schematic9 0 1's NIPPLE;7,465.5 irit t- VALVE;7,485.0 gg .�7 .lam' LOCATOR;7,473.0 00 SEAL ASSY;7,473.6 :; I I (PERF;7,765.0-7,605.0 APERF;7,900.0-7,920.0 PRODUCTION S.5'3.5";27.0-_ 6,228.0 AtetiNitt • • z---i -, 3 MAY - 211116 �` WELL LOG TRANSMITTAL#903266695 To: Alaska Oil and Gas Conservation Comm. May 12, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Sid/201Q, Anchorage, Alaska 99501 M.K BENDER RE: Perforation Record: 2L-315 Run Date: 4/23/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-315 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20276-00 Perforation Record (Field Print) 1 color log 50-103-20276-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RE TJ NTNG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & PerforatingSCANNE Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ vaLadid.A., / ..E;+ka'`'"C Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~'~/~ile Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other COMMENTS: Scanned b~ildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Dareth~["Lowell Date: ~'~""~:~'e~. /si i WELL LOG TRANSMITTAL To: State of Alaska July 20, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 2L -315 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2L -315 Digital Data in LAS format: 1 CD Rom 50 -103- 20276 -00 LiLMNED `J, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. 1 96...a4 Anchorage, Alaska 99518 Office: 907 273 -3527 S Fax: 907 273 -3535 rafael.barreto @halliburton.com DAP/ 0 5 2009 Signed: low Alaska Oil Gas Cons t'or mis$_ nr' Anchorage S E P 1 0 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION G$~I~[t~~ll~t~i CBS ~C" }. ~t31??f;;;~SlOI~ REPORT OF SUNDRY WELL OPERAT~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other 0 SPJP to Gaslift -Alter Casing ^ Pult Tubing ^ PerForate New Poot ^ Waiver ^ Time,Extension ^ Conversion Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConoCOPhillips AIBSka, InC. Development ~ Exploratory ^ 198-218 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20276-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' - 2L-315 ` 8. Property Designation: 10. Field/Pool(s): ADL 380051, ALK 4599 Kuparuk River / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 8236' feet true vertical 5627 ' feet Plugs (measured) Effective Depth measured 8099 feet Junk (measured) true vertical 5556 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 16" Boa' 108' SURFACE 2254' 7-5/8" 2400' `"'2~90''~ PRODUCTION 7329" 5-1/2" 7475' 5214' PRODUCTION 753' 3-1/2" 8228' 5623' e.~ ;A- v ~ ~ ~ f~ {~ ~~~ > Perforation depth: Measured depth: 7765 -7805 true vertical depth: 5377-5399 • Tubing (size, grade, and measured depth) 3-1/2", L-80, 7475' M D. Packers &SSSV (type & measured depth) Packer =Baker 80-40 Csg Seal Asssy. Packer = 7473' SSSV =Nipple SSSV = 501 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf .Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 524 1238 426 2164 212 Subsequent to operation 775 1391 84 841 227 14. Attachments ~. 15. Well Class after proposed work:: Copies of Logs and Surveys. run _X Exploratory ^ Development 0 Service ^ Daily Report of Well Operations 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correcfto the best of my knowledge. Sundry Number or WA if C.O. Exempt , NIA contact Bob ChristensenNacant ~ Printed Name `Robe D. Chri tensen Title Production Engineering Technician ~ (t ~ Signature ~~ ~~.,_ '.~ Phone: 659-7535. Dafe qr / ~ ~ ~ ' ~' ~ ~ I I N A L ~~.~~ ~ ~ ~o~~ ~,~,~~ ~ ~ 9•,Q-~s Facet 10„404 Revised 04/2004 ~ Submit Original On{v 2L-315 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/17/08 08/18/08 PULLED 3" RC JET PUMP (S/N: PH-114) @ 7363' RKB. TAGGED @ 7780' SLM. MEASURED BHP @ 7785' RKB: 1574 PSI. IN PROGRESS. :,LOBED CMU @ 7363' RKB. SET 2.75 CAT SV@ 7465' RKB. MITIA 3500 PSI, PASSED. 'ULLED DV @ 7413' RKB, SET OV. PULLED 2.75 CAT @ 7465' RKB. COMPLETE. 08/21/08 Open Well -Returned to Service . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AcœC Christine Mahnken 333 West 71t1 Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to 1t1e attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 a Fax: (907) 245-8952 1 Report/ EDE 2L-315 MTT / Caliper Report 18-Aug-07 1) 2J 3J 4) 5J 6J 7J SCANNED SEP 0 7 2007 lqr- dl'?f . J:¡S-'3tL( Signed: ~jjÆ _ RECE\VE\.) Date: SEP e 11 7001 Print Name: ~ j¡ ( >A-' ~ {l f/;ll\ ~'li~&.OI <1 ' ,.\~"';LJr' ,'\Iaska Oil &. Gas Cons '. ,\ 111", . . .. Anchm'l'." PRoAcTIVE DIAONOSl1C SERVICES, INC., 130 W.INTERNA110NAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D;\Masre.- _copy _ 00 YDSANC-2OxxIZ _ WordIDislnlmtion\TI8I1SIt1Íttat Shecb;\1\"ansmiC Original.do<: I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: . . Memory Multi-Finger Caliper & Magnetic Thickness Tool Log Results Summary ConocoPhlllips Alaska, Inc. August 18,2007 9507 1 3.S" 9.3 lb. L-80 Tubing 5.S" 1S.Slb BTCM Tubing 2l-315 Kuparuk Alaska SO-103-20276-00 Surface 7,492 Ft. (MO) 2,397 Ft. (MO) (MTT only) 7.492 Ft. (MO) (MTT only) Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Top Log Intvl1.: Bot. Log Intvl1.: Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This CaliperlllTT data is tied into the '0' Nipple @ 7,465 ft. (Drillers Depth). This is the first log of this well with the 24-Arm Multj..finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 3.S" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.S" production casing within the logged interval. The MTT portion ofthis log covers 2,397' to 7,492'. The additional metal volume added by the 7.625" surface casing above this interval exceeds the MTT's capability to record accurately. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. Generally, intermittent high-frequency metal loss indications are attribUted to metal loss of the tubing or inner-most string, and metal loss to outer concentric strings will be denoted by lower frequency shifts in the average metal loss of all twelVe sensors combined. In this log, the MTT was calibrated down hole (6732'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point. which include influences from the 3.5" tubing and 5.5" production casing. INTERPRETATION OF CALIPER LOG RESULTS FOR 3.5" TUBING: This log was run to assess the condition of the 3.S" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.S" tubing interval logged appears in good condition with respect to internal corrosive damage, with only shallow corrosion and pitting of less than 18% wall thickness recorded throughout the logged interval. No areas of significant cross-sectional metal loss or 1.0. restrictions are recorded throughout the interval logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18%) are recorded. RECEIVED ProActive Diagnostic Services, Inc. I P.O. Box 1369{ Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 SEP 0 4 Z007 Alaska Oil & Gas Coos. eonunission Anchorage '-f I I I I I I I I I I I I I I . . 3.5" Tubing - MAXIMUM RECORDED CROSS-SEC110NAL METAL LOSS: No areas of significant cross-sectional wall loss (:> 11 %) are recorded. 3.5" Tubing - MAXIMUM RECORDED 10 RESTRICTIONS: No significant I.D. restrictions are recorded throughout the interval logged. INTERPRETATION OF MTT LOG RESULTS: A graph of the average metal loss assessed from the MTT data on a joint-by-joint basis is Included in this report. The MTT log results indicate no intervals of significant overall metal loss (:>S%) throughout the interval logged below the 7.625" surface casing. Short intervals of some very minor metal loss are indicated over the intervals 3,802' - 3,925' and 4,82S' - S,OSO'. A detail of the MTT recordings over the interval3,76S' to 7,90S' are included in this report. There are no recordings that point to significant metal loss to either the tubing or production casing throughout the interval befow the surface casing. Increased metal volume is indicated at the GLM's and the Jewelry at the bottom of the tubing interval. I Field Engineer: S. Carpenter Analyst: J. Burton / M. Lawrence I B. Qi Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P,O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565·9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I Correlation of Recorded to Borehole Profiie I Pipe 1 3.5 in - 7472.0') Well: 2l-315 Field: Kuparuk I ConocoPh¡lIips Alaska, Inc. Country: USA Survey Date: August 18, 2007 I I Approx. Too! Deviation Borehole Profile 11 I 25 764 I 50 1531 I 75 2311 I 3088 100 I .... (!) ...., ...0 E u.. ::;¡ 125 3859 .S; z I E GlM 1 150 4669 I 175 5448 I 200 6233 I 225 7017 I GlM2 237.3 7472 0 50 100 I Profile wall) / Tool Deviation (degrees) I Bottom of '= 237.3 I I I I Well; 21.-315 Survey Dat(i;: HI,2007 Field: Kuparuk Too! Type: MFC 24 No. 40665 Inc. Tool Size: 1.69 USA No. of 24 Anal t: B. , Tubing: Nom.OD Grade & Thread Nom.iD Nom. Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins I I I I Penetration and Metall.oss wall) Pl"OfiJ~ _ penetraliòn metal loss body I I o I 10 to 20 to 40 to over 20% 40% 85% 85% o o I I Configuration (body) 40 20 GLM 1 I 30 I 10 o I isolated general line ring pitting corrosion corrosion cúrroskm I GlM2 o Bottom of = 237.3 I I Analysis Overview page 2 I I metal loss 50 100 I I I I I I I I I I I I I I I I I I JOINT LA TION Wall: Upset Wall: Nominal LD.: 3.5 În 9.3 ppf 1.-80 0254 in 0.254 in 2.992 in USA August 2007 Well; Field: 2l-315 Ine. Join t Jt ~~fth Pen. Pen. I Metal Min, .~. ' Profile No. ;t 1.0. Comments wall) (Ins) (Ins.) (Ins.) 0 50 100 1 11 o I g.O] I 11 I 2.90 2 42 2 2.89 3 74 ') Yi 4 106 . ±± 137 2 16Q i 2.89 Shallow oittioo. 201 13 I 2.89 Shallow nittiml. 8 232 14 2.90 Shallowoittioll, 9 264 10 296 ! 0.D3 Shallow pittinll. Lt.Dennsits. 11 325 1 12 356 s/ì;¡l!ow nittinq. ¡ t Denosits. ~388 2.89 S/ì;¡liow oiliiml. 14 419 2.88 15 450 1: . 2.88 15 1 481 2.88 OS NiDole 16 48l O. 1 2.88 17 515 0.0 ~ 18 546 0.04 Sh;¡lIow nittioo. 19 577 0.02 20 607 ¡ ~*~ 21 639 22 670 23 701 '4 7.n 0.02 J =±±289 25 764 0.02 C 2.89 26 795 0.03 2.90 27 825 i 2.90 28 857 2.90 29 888 =~~i 30 919 31 950 32 981 33 1011 I 2.90 34 1042 i 35 1073 36 1103 1 37 1131 38 1163 .03 ? 2.90 39 1194 0.02 2.91 40 1224 0.03 2.90 41 1253 0.03 2.90 42 1284 0_01 =i Sh;dlow nittin2. 43 1316 I 44 1346 0 45 1376 0 t 46 140 2.89 47 143 :.91 48 146 0 IJJ7 49 1500 C I 0.02 q ') 89 I I I I I I I I I I I REPORT NT TABULATION SH Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: 2L-315 field: ConocoPhillips Alaska, Inc. USA August 18, 2007 I I I I I I Joint Jt. Depth Pen. Pen_ Pen. ¡\Aetal Min, Profile No. (Ft) \~~:~';t (Ins.) 1.0. Comments (% wall) 0 50 100 50 1531 I:~ I in *,now n;ttina, 51 1563 52 1594 53 1625 -3-91 54 1 ;')7 0.02 I B ! 55 1 :;88 0.02 ¡ 56 1 19 57 1751 89 ,)FI 17111 . 1 ')q 1814 11 2.91 60 1845 a ,92 61 1877 I Ft .89 1907 ~ .1'10 63 1937 t 0.03 .91 64 1968 ( 2.87 65 2000 t 1 2.91 66 2031 t ¡ 2.92 67 1063 t ¡ 2.94 68 2094 3 2 2.91 69 212,1 t±& ~ 70 154 v 3 71 186 n 0.02 2.94 72 1217 t 0.01 11 73 2248 C 0.03 74 2280 0.02 75 2311 76 2341 77 2373 'J 2.90 78 2405 2.93 79 2436 2.93 80 2467 2.93 81 2499 t 2.94 82 2519 0.02 2.91 83 2560 0.02 R4 2592 I I 85 2622 I 2.94 86 2653 ( 2.91 87 2hflil. t 2.90 88 2716 2.91 Shallow oittimz. 89 2747 1 +:t 2.91 Shallow oittinu. 90 2778 ( 3 2.90 Shallow oittimz. It. Deoosits. 91 2809 ( 2.93 92 2840 ([02 2.93 93 2871 ±§]i j 2.91 q4 2900 291 95 2932 0.02 2.93 96 2962 0.02 2.92 97 2993 0.02 2.94 9R 10/') 0.03 12 4 2.94 99 3056 0.03 n 5 2.89 Shallow Dittin¡¡. 2 I I I I I I I I I I I I I I I I I I I REPORT JOINT TABULATION SH 3.5 in 9.3 1.-80 Wen: 21.-315 Wail: 0.254 in field: Upset Wall: 0.254 in Inc. Nominal 1.0.: 2.992 in USA Survey 18, 2007 Joint Jt. Depth F'en. Pen. Pen. ¡'-lIeFal Min. Profile No. 'F W. Comments (% wall) (Ins.) (Ins.) '7<, (Ins.) 0 50 100 100 3088 0.04 2.91 Shallow oiltina 0.02 2.94 7 0.02 3178 0.03 me 3209 0.02 1240 0.03 II 1272 0.02 q Is 3302 Iim 2.89 Shallow oittin2. l1 0.02 2.91 109 3366 2.90 110 3396 2.90 Shallow oiWmz. 111 3428 112 3459 Om -¡; ~ 113 3488 0.02·C; .94 114 3519 In 2.97 115 3549 i 2.90 116 3'i81 I 2.92 117 3611 .91 118 3642 .93 119 3673 0 93 120 3704 l1 0.03 2 2.91 Sh"UmAl Ditlinli!'. 121 373" II 291 12? 3765 4 ~ 93 123 3797 0.02 2.90 124 3828 O. 2'<ß 125 3859 0.03 2.89 Shallow oittinQ, 126 3890 0.02 2.89 127 3922 ±t! 92 PA iil950 \ .89 Shallow oiWn12. 129 3982 I 2.92 130 4012 i 2.93 131 4044 o 0.03 ? 2.89 132 4075 0 ~ ~.02 2.90 133 4107 ( 134 4138 ( 135 4170 0.02 136 4201 I 0.02 137 4231 0.02 138 4262 Î 0.0 2.90 139 4294 0 Ii 2.93 140 4325 2.91 141 4356 2.91 142 4388 . 2.90 142.1 4420 0 2.93 PUP 14:>,/ 4433 ( o (] ~":.~ @ 9,30\ 142.3 4442 0.00 143 ~ OJ)) 1 144 0.02 I¡ 145 4515 0.03 1 2.89 146 4546 0 0,03 1) í 2.89 I 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Wall: Upset Wail: Nominal I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in 1.-80 Well: field: 21.-315 Kuparuk Alaska, loe. Country: Survey Date: USA August 18, 2007 Joint Jt. Depih Pen. Pen. Pen. i 1\,1r'1al Min. Profile No. \~ ~::r; t LD. Comments 10/ -'" \ '" vva,,! (Ins.) (Ins.) 0 50 100 147 I 4578 () 1 0.02 R }±tlH 148 ! 4607 ±m !2 149 ¡ 4616 10 ~ 0.02 7 2.9i ~I] q 2.91 Shallow nittimI, 1 4730 11 2.89 153 4761 fi . 2.92 154 4791 2.90 155 4823 I: 0.02 q 2.aQ nittina. 1 "6 ::>.91 1 "7 4887 n 0.03 ) 2.89 1 "8 4918 () 0.r¡2 ) 2.91 m n 003 ì r; 2,<:¡0 160 ~ ) .94 161 5012 M~ 162 5042 .90 1(;3 5074 .~; 164 5105 { 0.02 165 0.02 .90 166 5168 ( 0.02 ) J.rÙ 167 5198 { 002 'Ö 2.89 168 5230 { 0.02 289 169 .5260 ( I 0.02 2.89 170 5292 () 0.02 2.92 171 "3)7 () 0.0"1 ::>.89 172 5354 0 0.02 { 2.93 173 002 ~ 2.94 174 I 5416 0.03 1 2.88 Shallow nittimI. 175 5448 002 11 2.94 176 5479 0.02 fJ ~ 177 5510 0.02 -t--ï-t--'-- 178 5542 0.02 2.94 179 5574 0.03 13 2.89 Shallow niUina, 180 5605 0.04 14- +fa9 Shallow nittina. 181 5638 œ 5 90 Shallow niWm;,. 182 5669 2.94 183 5700 V~(j Shallow oittirIQI. 184 5732 ( 2.92 185 5764 ( 2,90 Shallow ""ittin<Y. 186 5796 0 0.02 2.93 187 <;RJ7 0 0.02 2.93 188 58')7 0 it ili 189 5889 i 190 1 += 2.93 191 5952 289 192 5984 0.02 2.93 191 6016 J 0.02 ; =1 2.R9 194 6047 n 0.02 19<; 6077 n 0.03 10 196 6108 0 0.02 ¡:. :¡ 2.89 4 I I I I I I I I I I PDS REPORT JOINT TABULATION 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: field: Company: Wali: Upset Wall: NominaII.D.: Joint Jt Depth Pen. Pen. Pen. ~ Min. No. (ft) I Loss 1.0. (Ins.) (Ins.) ''l<, (Ins.) 197 6140 0_. Shallownil:tíno. 19R 6171 0 Ii 199 6203 0 . 200 6233 2 201 6266 202 6297 0.07 203 ~7 0.02 'í'¡·!tiI2.92 204 ~9 0.02i1 205 6390 0.04 11', r Shallow nil:tína. 206 _420 0.02 'RT 207 2.90 Shallow "'itUn"'. 208 6483 2.8. 9 209 651" 2.9) 210 6546 2.89 ~6578 I ¡ 2.94 6609 """i\02 ¡ ¡ ) q", 213 0.02 2 V:¡1 214 6672. 0.02 ~ 215 ! 6703 n 0.0) 21h ! 6734 0 .90 Shallow....iíiîn<>. 217 6766 0.02 2.92 218 6797 2(/1 219 6828 2.91 ¡ t DPnos¡ts. 220 6858 2.90 2'/1 6890 ) 92 222 6921 2.93 2/3 "Q"3 ).94 224 6984 0.03 2.88 shallow....il:tín<l. 225 7017 0.03ÜJ 2.94 226 7048 0.02 13 =Rft 227 7080 0.04 1 Shallow nittino-. 228 7110 0.02 2. 229 7142 fI 0) 2.93 I 230 7174 nO) 2.93 231 7205 0.031 ? Jl£. 232 7236 0.07 (: ?,,2!l 233 7268 002 ( 2.94 234 7299 ( 2.94 23" 7331í! 2.95 235.1 7363!J I 2.Bl 236 73651 2 94 236.1 7396 ,I P 2.91 2362 7410 0 n t N/A 236.3 7422 0.03 ffi VB 237 7413 0.04 2'<H 237.1 7465 0 2.75 237.2 7A.hR I 0113 n ¡ 7.94 2"7.3 7472 0 0 () I 2.75 I I I I I I I I 51idino- Sleeve Shallow nittino. PUP GLM iiL"tch @ 6:30\ PUP Shallow nil:tínO". D Nínnle PUP Sea! 5 2l·315 Kuparuk ConocoPhíllips Alaska, Ine. USA August 18, 2007 Comrnents ¡Hine. -;-. U. Denosits. Damage Profile (% wall) o 50 100 II ¡¡ Body Metal Loss Body I Recorded Calibration I 3.5 in (2404.7' - Well: 2L-315 Fie!d: I ConocoPhillips Alaska, inc. USA August 18, 2007 I I Decrease Increase I I 100 3088 I 125 3859 I GLM 1 I ... 150 4669 (II ..0 ~ E ;:¡ .5 z I ..... !:: '5 ~ 175 5448 I 200 6233 I I I I I I 225 7017 GLM2 237.3 -50"/0 o in Metal Thickness 7472 50"/" Bottom of '" 237.3 I I I I I I I I I cIrk MTT 10 - .. ---. ~ onc;' ~ S"IWIe""", iNC:. . """ ,tÖ:') to _,___ Database File: ~.n "'" 5\21-315. db Data$et Pathname: 1/1¡1/MIT ~ .. Format mtl:-", Dataset Creation: 15:55:102007 Charted in Feet scaled 1 :100 ~ MPCMN (~%) 100 "I MITP01 (rad) Une Speed (ftlmin) -200 -45.2 !VI I W1L (rad) 3.4 fing02 (in) 1.41 I 1 \ I 1-1- µt ~¡T ef02~ ..~ ~ '-- Jt 122 .'"" - -~.- - - - <; 3780 ha 1-1;.- ... K! f-- ¡-'S -Une f-- :;.. ¡¡. ~ - ."" Collar <- - - ""¿ I IUI J!ng Collar 3800 II -- -- --- - ~ JOint 123 1--- ~- I L- ----- -..... srern i uamaœ 0::: - - i:. 3820 , , I :tt= Metal, Los~ A entT Tü bing Coilar ' II I 1--- ---4-- I I I I I I I I I I I I I I I I I I I I I I I I I I I I i~.. I Œ I.... I ng Collar í ~I-' arent r ì J \ r- --~ ~-r- r ~7 3840 , ;: t, Tubin Joint 124 '" iÞ of Relative tvetal' L~~ß4- .. (Minor) - '--- A arent Da ¡.UD!!!9 Dam II' f---- -.- --1-- i UDlO¡;; Co¡¡a~ 3860 - - - --- - -- _. - - ~ '- '" - Joint 125 ....... ;.. - ~ng Collar - - 1. LL 3880 l MIT ::ln~!er 02~ "' ¡ Dam I. -r I ' I-- ;;;:;; T, ,;~ 1- -" Collar "2 T --~ I Joint 126 ~, -, . i 3900 I ~ ¡;;-Une S ad ---- I I ¡ ~¡ ¡ -100 MPCMN (%) 100 1 MTTP01 (rad) 51 0 Une Speed (ftlmin) -200 -45,2 IV! J ¡ r'lL (rad) 4.8 3.4 fil"l.-.!ì'J ¡i.... ì 1.4 ""'::JV- "/ I I I I I I I I I I I I I I I I I !I I KRU 2L~316 NIP - (7766-7005) . . Conoc~Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \ 0... C6' 'J..\ 'b 5{;Ã!'~NED SEP 0 6 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Each of these wells was found to have a void in the còÍ1d1Îêtor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. Aß per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 12-13, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. 4¥~¿ MJ. Eoveland 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 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2l-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A N/A N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 Date 8/13/2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): o o 2004/1st o o 2004 / 2nd 11303 100 2004 / 3rd o o 2004 / 4th o o 2005/1st o o Total Ending Volume (bbls): 11303 100 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-071 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/5/2004 Volume (bbls): Number of days disposal occurred 37* 37* 0 0 0 0 0 11403 12 0 0 0 0 0 0 0 0 0 37 11440 12 Pressure vs. Time 0 Step Ra~è]\N~D Þ.PR 1 8 20G5 freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. r\ ~ \~ 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 98-218 2L-315 50-103-20276-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 4/9/2004 4/24/2004 2 L -311 ~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. lfill-fQT Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 304-071 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/5/2004 Volume (bbls): Number of days disposal occurred Previous 0 0 37* 37* 0 totals (bbls): 2004/ 1st 0 0 0 0 0 2004 / 2nd 11303 100 0 11403 12 2004 / 3rd 0 0 0 0 0 2004/4th 0 0 0 0 0 Total Ending Volume 11303 100 37 11440 12 (bbls): 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D Other (Explain) 0 12. Remarks and Approved Substances Description(s): freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. 0--'~ \~~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 98-218 2L-315 8. API Number: 50-1 03-20276-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: -" 4/9/2004 4/24/2004 2L-311 ~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNED JAN 1 4 2005 l (, fO.>- Phone Number: (907) 265-6830 Submit in Duplicate /,"""'" Previous totals (bbls): 20041 1st 2004 1 2nd 20041 3rd 2004 14th ,-.., Total Ending Volume (bbls): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 304-071 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/5/2004 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 98-218 2L-315 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 8. API Number: 50-103-20276-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 0 37* 37* 0 0 0 0 0 0 11303 100 0 11403 12 4/9/2004 4/24/2004 2L-311 0 0 0 0 0 11303 100 37 11440 Pressure vs. Time D Step Rate Test D 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): freeze protect volumes only I hereby certify that the fore~e and correct to the best of my knowledge. Signature: ' \ '-~ t ~, - Printed Name: Randy Thomas Title: Form 10-423 RAv- 2/2004 Date: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 12 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNED NOV () 4 2004 \.'é ((oz (Oy Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 0 37* 37* 0 0 0 0 0 0 11303 100 0 11403 12 4/9/2004 4/24/2004 2L-311 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004/1st 2004 / 2nd 2004 / 3rd 2004/4th Total Ending Volume (bbls): 11303 100 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 304-071 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/5/2004 Volume (bbls): Number of days disposal occurred 37 11440 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): Step Rate Test D freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ,~. Printed Name: Randy Thomas Title: ...- .II.^^ 1"""'\-.. n/nnl'\.A Date: Kuparuk Drilling Team Leader 1fl.I~T~IIr.TI()N~ ()N RFVFRSE SIDE 6. Permit to Drill Number: 7. Well Name: 98-218 2L -315 8. API Number: 50-103-20276-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~~ 12 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ? (ð (0 .,.- Phone Number: (907) 265-6830 Submit in Duplicate Re: 2L-315 Repeat LOT f , Subject: Re: 2L-315 Repeat LOT From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 16 Apr 200409:55:02 -0800 To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> \<;.<6- )\1) Philip, Thanks for performing and sending in the new information. It appears that pump in is at a steady 15.0 ppg. This is less than the original leakoff of 16.1. Submission of this information satisfies the requirement ofthe sundry. By copy of this message, you have approval to initiate annular disposal into 2L-315. I will place a copy of this information in the well file. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, Attached please find a record of a repeat LOT carried out on the annulus of well 2L-315 on 04-15-2004. This was carried out as per the AOGCC's requirements to approve this well for annular disposal- Sundry Permit No. 304-071. FYI: The mud weight used in the calculation was 8 ppg - based on having previously displaced the annulus to diesel for freeze protection 09-04-2004. Regards Philip 1 of 1 4/16/20049:55 A PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I 2L-3í5 I Ri9: Doyon 141 Date: I 4/15/2004 J Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Gn:mVmf'.. Rizei<. Pump used: I #1 Mud Pump \... St ~ I ~ ::i~:jlii Bbl/Strkl ~ :::::::::::::::::):1::'1 St k/ . I... Type of Test: I Annulus Leak Off Test for Disposal Adequacy 1"'1 Pumping down I USE UST I... ro es casiJ:r~;::~f s pJ:~~j;!j~~te~ri:nTest Hole Size: 16-3/4" ,..., Casing Shoe Depth I I Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 28.01Ft 2,400 1Ft-MOl 22921Ft-TVo! 2AOOIFt-MO I 2,292IFt-TVO Strks psi Min psi Strks psi Min psi 1 0 ::;@:¡::;i:l:lf.i 1000 - w 0::: ::I UJ UJ w 0::: Q. II ¡:¡:¡:¡:¡:¡:¡Ijij¡ :¡:¡:i:j:i:¡:¡:¡:~~~: IÎIId 1111 lrr~$l: ::l/{:¡:laø: Volume Pumped 6.9 Bbls 500 . iJJJJJJJJjjjjUWiii@tUiWtit . t: 0 0 - @j:Nf:¡:tij@):r:w:iji::::::i::i 5 6 7 8 0 '5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 2 3 4 Barrels 30 Volume Pumped 0.0 Bbls Volume Bled Back :::ftfiiJ:fIBbls ""-CASING TEST ~LEA~OFFTEST Comments: .. Volume Bled Back :Wt:fHitifU Bbls STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): freeze protect volumes only I hereby certify that the foregoin. ue and correct to the best of my knowledge. \ ~ ~--~~~--J 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation D or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 0 0 2004/1st 0 0 2004/2nd 2004/3rd 2004/4th Total Ending Volume (bbls): 0 0 Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-071 (h)(3) Other Commission approved substances (include descriptions in block 12) 3/5/2004 Volume (bbls): Number of days disposal occurred 37* 37* 0 0 0 0 37 37 Step Rate Test D Date: Title: ~:s- \5 ~'...- Lc..,J INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 98-218 2L-315 8. API Number: 50-103-20276-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, Ju/y 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. Phone Number: Lt Irb ID'f '2-6 ç 6'-t 30 Submit in Duplicate Note to File 2L-315 (198-218...304-071) Kuparuk River Unit (Tarn) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. Approximately 70 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 167% XS of the calculated hole volume. Placement of such cement volume should provide adequate isolation. --The initial leak off test did not break at 16.1 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole and the tapered 5-1/2" x 3- 1/2" production casing was run and cemented as planned. --An injectivity test down 9-5/8" x 5-1/2" annulus was conducted. Pressure steadily increases with the exposed formations accepting fluid at 12.5 EMW. During the observation period, the pressure declined to 11.8 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within 'X mile of 2L-315. There are a total of 6 wells within 'X mile of the shoe. There are 3 wells within 650' with 2 of the wells having been approved for AD. The remaining wells are over 1000' distant. An examination of the files did not reveal any problem that would preclude granting CPA's request for 2L-315. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Since the information CPAI has available for this well is over 5 years old, prior to initiating disposal CPAI should conduct a new :¡:t~J t: results to the Commission. Tom Maunder, PE .~( Sr. Petroleum Engineer March 5, 2004 .. . .~... - , . SCA¡¡~NE[) MA~ 1 2 2004 ConocJP'hillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: philip.hayden@conocophillips.com R (::' (,.., E ~ V E' ri"'~ s li.."",-4'" ~ L) MAR 0 3 2004 March 3, 2004 Ala~~ka (l! & Gas COI1~. Commi~~ion AllrÞnp:~g(? Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilline Waste on we1l2L-315 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that 2L-315 be repermitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. This well was permitted for annular injection in November 1998 (Permit to Inject Number 398-298). Th", e, pe,rmit, eX~'red in Novem, ber 1999 without any fluid being disposed of in the annulus of this well. ~."'t"i\ ~ "" . \;" ~ . f"' \.. , . . D . . , ",~,<¿C?v 'l ~~ ~ \--G C. T'Ö.~G.- ~l C\.. ''/ \~ Please find attached form 10-403 and other pertinent information as follows: ~~,\,)\O~S\ ,', '. '\\,\~ ~ ap~~~ " 1. Annular Disposal Transmittal Fonn ~ \o..e-.-1I'-0\.~~,> 'SA.. \. 2. Pressure Calculations for Annular Disposal D'~~~ö ' \ 3. Surface Casing Description ~~ílLf 4. Surface Casing Cementing Report & Daily Drilling Report during cement job "3~ .-d1 5. Casing and Formation Integrity Test Report (LOT at surface casing shoe) with Daily Drilling Report. .5 6. Production Casing Description 7. Production Casing Cementing Report & Daily Drilling Report during cement job. 8. Formation LOT in 6 %" hole @ 4571' MD, 3577' TVD. 9. Plan View of Existing Adjacent Wells 10. Details on all wells within 1A mile of 2L-315 at the surface casing shoe (2L-305, 2L-307, 2L-313, 2L-321, 2L-323, 2L-325). With reference to point (8) above, this deeper LOT occurred at a lower equivalent mud weight than the casing shoe test. Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FITILOT. If you have any questions or require further information, please contact Philip Hayden at 265-6481, or Randy Thomas at 265-6830. s2er~L I ß- . Philip ~ Drilling Engineer Cc: 2L315 Well File Randy Thomas Sharon Allsup-Drake ATO-1576 ATO-1530 ORIGINAL STATE OF ALASKA ~ Á--3' ALASKA OIL AND GAS CONSERVATION COMMISSI~r.:: f"'. E ~'VE D ~/ Is- APPLICATION FOR SUNDRY APPROVALv ' ".' I'~ 20 AAC 25.280 MAR 3 2004 Operational shutdown D Perforate D Variance D. Annular Dispos,0 D . \I~(I, iH? G,as Cons: CIl~WìSlon D Plug Perforations Stimulate -U Tlm~ Extension U Other ,Af!!'I1i1f3gP D Re-enter S~spended Well D Liner Perforation Depth MD (ft): 7765 - 7805 Packers and SSSV Type: Baker GBH-22 seal assembly, Cameo OS nipple for SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation Depth TVD (ft): 5377 - 5399 Packers and SSSV MD (ft): Seal bore receptacle @ 7475', Nipple @ 501' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend D Repair well D Pull Tubing D P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' RKB, 143' AMSL 8. Property Designation: ADL 380051 / L 4599 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8236 5627 8099 Casing Length Size Structural Conductor 80' 1611 Surface 2372 7 5/8 Intermediate Production 8200 5 1/211 x 3 1/211 4/2/2004 Date: Printed Name Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic D 5. Permit to Drill Number: Exploratory D Service D 98-218 6. API Number: 50-1 03-20276 9. Well Name and Number: 2L-315 10. Field/Pools(s): Ku aruk River Field / Tarn Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 5556 MD TVD Burst Collapse 108 2400 108 2290 6890 4790 8228 5623 7000 / 10160 4990 / 10530 Tubing Size: 3.5 Tubing Grade: L-80 Tubing MD (ft): 7490 Service 0 Plugged D WINJ D Abandoned D WDSPL D Contact Philic Havden @ 265-6481 R. Thomas \~ :-ñ-0---- Title Kuparuk Team Leader Phone 265-6830 .~--~ COMMISSION USE ONLY Date '5 I "3 I () ~ Signature Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Sundry Number: ~-?Ð1-07/ Location Clearance D .' '", , \ Other: ?..-'\o...-\.v \~A\ "-~\"'S>~ ';,~'ðs.C>.\ \ C\' f-I..I: 1J\~~fJ C!)~ù& û. "'-Lv,) ~;\~~\ \\"\j, +(c~\ ~, t;. ,.' ç\ ,""- '-\. \,"'\ <!: \) Il t.) - ~ ~ '\ ~-\ D \ t'--'\-c...\:\ ~ ,"\. t' 'T ~ ~\ S"'~~ \ ~ ~ ~ c; .~ \>~, Subsequent F " equi . )7 .~ ~G CC ~GÄ~~ED MAH 'u tíþ 20nA "-, f..v s '66MMISSIONER .".', <. . . BY ORDER OF THE COMMISSION ORIGINAL NAi10 ,I ~' L\!.' ¡;;:!' I¡~V~~I~!~; g~~i.>t" SUBMIT IN DUPLICATE Annulus Disposal Transmittal Form - We1l2L-315 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: 2L- 315 2 The depth to the base of freshwater aquifers and permafrost, if No Aquifers I Base Permafrost = +1- 1193' TVD RKB present. 3 A stratigraphic description of the interval exposed to the open From the 7 5/8" shoe to the cement top all that is open is annulus and other information sufficient to support a interbedded claystone, siltstone and shale with occasional commission finding that the waste will be confined and will minor non-hydrocarbon bearing sands. not come to the surface or contaminate freshwater. 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin!! waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate waste under (h)(3) of this section. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1917 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT I FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT /FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or 2L-311 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Well Date 2L-315 3/3/2004 "'" ~ ~ bJ) ¡::; = .¡;'¡ = U : = = lO Ir) Pressure Calculations for Annular Disposal "'" ~ ~ ¡::; 2,290 TVD TOC Est. @ 6,~94' MD 4,938' TVD 3 1/2"Tbg 5,214 TVD Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure 1,500 psi 12 ppg 0.4525 psi/ft 0.11 psi/ft 0 psi Maximum Fluid Densitv to Burst Surface Casine Pburst85% = PHydrostatic + P Applied - PFonnation MW max 5,857 = ( 2,290 * 0.052 * MW max ) + 1500 - (0.4525 * 2,290) = 45.3 ppg Surface Casine Strine Size Weight Grade PburstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure 7.625 in 29.7 ppf L 80 6,890 psi 5,857 psi 2,290 ft 16.1 ppg 12.5 ppg 1,500 psi or 1,917 psi Maximum Fluid Densitv to Collapse 2nd Casine Strine P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader MW max 4,242 = ( 4,938 * 0.052 * MWmax ) + 1,500 - ( 0.1100 * 4,938) - 0 Maximum Allowable Pressure at Surface Casine Shoe P max allowable = P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = ( 2,290 * .052 * 16.1 ) 1,917 psi 12.8 ppg 2nd Casine Strine Size Weight Grade P collapse 1 00% P collapse85% Top of Cement Gas Gradient Max Surf. Pressu Header Press 5.5 15.5 L 80 4,990 4,242 4,938 0.11 1,500 0 in ppf psi psi ft psi/ft psi psi ~PHILLIPS Alaska, Inc. ~ .å. Subsidiary of PHilLIPS PETROLEUM COlv1PANY 2L-315 NIP (501-502. 00:4.620) TUBING (0-7475, 00:3.500, 10:2,992) PRODUCTION (0-7475, 00:5.500, Wt:15,50) Gas Lift landrel/Dummy Valve 1 (4441-4442, 00:4.725) SLEEVE (7363-7364. 00:4,500) PUMP (7363-7364. 00:2,813) Gas Lift landrel/Dummy Valve 2 (7413-7414, 00:4,725) NIP- (7465-7466, 00:4,470) SEAL (74B0-74B1, 00:4.000) PRODUCTION (7475-8228, 00:3.500, Wt:9.30) Perf (7765-7805) ---------.--.----.---- --....---- ---. -.- - KRU 2L-315 Bottom 108 2400 7475- 8228 TVD 108 2290 '5214 5623 Wt Grade Thread 62.58 H-4Q WELDED 29.70 L-BO BTC-MOD 15.50 - L.:sO ' - EUË-:'S'RD 9.30 L-BO EUE-8RD Th read - tUE~8¡:fö- - V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BTM 0.000 0 10/16/1999 -,Q_flŒÍ_-, _tQ--, ,J?IM" _9.QQQ ---Q,--- 1Jl1J1?.991,___,_-- .__,~es~ri,p.t!Q~,- ID --- ---213yÇ 2.813 0.000 0""'-_. _._.",-_._-----"--,-- , '" .-- ,-.-.-.- - :2 ~ 750.-- 2.985 Re: Jet Pumped Wells Subject: Re: Jet Pumped Wells From: "NSK Problem Well SUpV" <nI617@~eonoeophil1ips.eom> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tom :tvlaunder <tom_maunder@adnlin.state.ak.us> CC: "n 161 7" <n 161 7@eonocophillips.com> Tom: I requested a list of surface powered jet pump wells from our PEls. Th~ following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently SI for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) .--~2L-315 (PTD 1982180) .' 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2 N - 3 0 3 (PTD 2 0 0 16 9 0 ) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <cc.m mal1nd.er'~\:idrnin.state.ak.us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails f1 h'l b -om aWl e ack regarding the wells ouc chere on jet pumps. Would 'iou please provide an updated listing of ch~ wells presently on jet pumps ln greater KRU?? Thanks in advance. To ( ( ~ ' , '. Casing Detail 7.625" Surface Casino WELL: TARN 2L-315 DATE: 12/08/98 1 OF 1 PAGES ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.50' TOPS Above RKB 7 5/8" Landing Joint 28.50 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 3.24 28.50 jts. 33-56 7 5/8",29.7#, L-80 BTC-mod(23 jts) 1007.57 31.74 TAM 7 5/8" Port Collar 2.41 1039.31 jts. 3-32 7 5/8", 29.7#, L-80 BTC-mod (37 jts) 1269.53 1 041 .72 Gemeco Float Collar 1.30 2311.25 jts 1-2 7 5/8", 29.7#, L-80 BTC-mod(2 jts) 86.37 2312.55 Gemeco Float Shoe 1.50 2398.92 Casing shoe @ 2400.42 T.D. @ 2412' leaving 9.25' of rathole 28 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, 32, 33, over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17, 20, 23, 26, 29, 36, 39,42,45,48,51,54 Joints 57 - 63 (7 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 75K Up, 65K On, 12k Blocks. Ran 56 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: DA VE BURLEY ( ~~ ~" ARCa Alaska, Inc. Cementing Details ( I Well Name: 2L-315 Report Date: 12/08198 Report Number: 3 Rig Name: DOYON 141 AFC No.: AK9725 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout 7-518" 9-718" 2400' 2311' Centralizers State type used, intervals covered and spacing Comments: Detailed on casing tally. Mud Weight PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.4110.2 30 28 26 16 Gels before: Gels after: Total Volume Circulated: 11126 8114 980 bbls Wash 0 Type: Volume: Weight: Comments: ARCO 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 " 10.5 '\ I Lead Cement 0 Type: Mix wtr temp: N6. of sacks:) I Weight: Yield: Comments: ASIIILW 60 330 10.7 4.43 Additives: ..~ Standard blend ."...... Tall Cement 0 Type: Mix wtr temp: Norof sac): I Weight: Yield: Comments: G 60 l 235 15.8 1.17 Additives: V 1 % S1, 0.2% 046, 0.3% D65. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7 bpm 7 bpm 75 Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 10 fpm 65 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 106 bbls 106.2 bbls Calculated top of cement: CP: Bumped plug: I Floats held: Cement returns to suñace. Date: 12-8-98 yes yes .~e:1240 hrs. Re"'''',Oo".,Io"ed m.. @ 7 bpm. p.mped 2D bbIS~:'" bbls of spa,e,. 255 bbls of 10.7 ppg lea. aM 49 bbls of 15.. ppo tail oeme'" Dls~aoe. oem.'" with 20 bbls of wash up water and 86.2 bbls of mud. d 70 bbl of 10.7 ppg cement returns to suñace,bumped plugs to 1200 psi, floats held. Reciprocated pipe untilllead cement back to surface. Cement Company: I Rig Contractor: I Approved By: DS DOYON D.BURLEY ( ( ~~ ~~ ARCO Alaska, Inc. Daily Drilling Report ( AFC No. I Date RptNo I Rig Accept - hrs Days Since Accept/Est: 2.341 Rig Relase - hrs: AK9725 12/08/98 3 12/06/9804:00:00 PM Well: 2L-315 Depth (MDfTVD) 2412/2302 Prev Depth MD: 2412 Progress: 0 Contractor: DOYON Daily Cost $ 234717 Cum Cost $ 444878 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5/8' @ 2400' Next Csg: 5-1/2" @ 8372' Shoe Test: Operation At 0600: Perform LOT. Upcoming Operations: Drill 6-3/4" Production hole. MUD DATA DRILLING DATA BIT DATA .' EH&S .' ,,', DRillS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL lSND 1 2R1 N TST 12/01/98 12/06/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 9.875 6.75 12/02198 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 58sqc HTC HTC N SPACE 12/08/98 PVIYP SOWT TYPE TYPE TYPE .',..., .,.'... .,','. "'.," ii<' ...i .' .iii... 20 / 21 MX1 STR554 iT. ..'..<,i it .'. GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1600 5/7/ Y02YV 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1475 7.2 2412 12/08/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN '.. POTABLE WATER 116 ml/30 min 113 2412 ,INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ",' .., ', WEA Tt:IER& 4% 2299 0 2L-329 ',"'. PERSONNEL,DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -9 92bbl III 9.01 3.5 1 2L-315 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 7.5 11211 45- 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 25° 8.0 61611 90- 550 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -22.42 2.2% III 0.518 Water Base Muds 1342 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 400 III 101151151151 I 131131131131 I 55 Diesel 60 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $8249 III 8246 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $32757 III 111 WTIA III 1457 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 10 BAROID III E 11/161 NO I TD III 28297 PERSONNEL TOTAL 43 '.TINlE :,ENP <, HOURS .. r OPS CODe I HOLES,ECT ,,!PHASEQP$ ,'.. ,.,"J.. ",'., ,', " QPERATIONS FROMOOOP"oooo '",' , ,'.i.""" 12:00 AM 01 :00 AM 1.00 CIRC SURF Making Hole Pumped sweeps and circ hole clean, monitor well, pump dry job. 01:00 AM 02:30 AM 1.50 TRIP_OUT SURF Making Hole POH, no problems. 02:30 AM 04:00 AM 1.50 BHA SURF Making Hole Laid down dc's, mwd and motor. 04:00 AM 08:00 AM 4.00 RUN_CSG SURF Casing and PJSM. RIU GBR casers and run 7.5/8" casing. Cementing 08:00 AM 11:00AM 3.00 CIRC SURF Casing and Circ and cond mud @ 7 bpm, full returns. Cementing 11 :00 AM 01 :00 PM 2.00 CMT_CSG SURF Casing and Cement casing as per program, had 70 bbls of 10.7 ppg Cementing cement returns to surface, plugs bumped, floats held, CIP @ 1240 hrs. 01 :00 PM 02:30 PM 1.50 OTHER SURF Casing and Flush surface equipment and lines, removed cement head Cementing and landing joint. 02:30 PM 08:00 PM 5.50 NU_ND SURF Casing and ND Divertor system, Installed casing and tubing heads, NU Cementing BOPE. 08:00 PM 11:00 PM 3.00 BOPE SURF Casing and Tested BOPE 250/3500 psi Cementing Installed wear bushIng. 11:00 PM 12:00 AM 1.00 BHA PROD Making Hole MU BHA #2. 24.00 Supervisor: D.P.BURLEY ( Daily Drilling Report: 2L-315 12/08/98 Page 3 ~ CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-315 Date: 12/9/98 Supervisor: D.P.BURLEY Casing Size and Description: 75/8",29.7 ppf, L-80, STC Casing Setting Depth: 2400 TMD 2,292' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,316' TVD 840 psi + 9.1 ppg EMW LOT= (0.052 x 2,316') = 16.1 ppg Fluid Pumped = 1.1 BBL Pump output = 0.101 BBUSTK TIME LINE 2,300 psi - ONE MINUTE 2,200 psi . . 2,100 psi 0---- 2,000 psi 1,900 psi IT 1,800 psi 1,700 psi J 1,600 psi -, 1,500 psi ,. W 1,400 psi a:: 1,300 psi ~ 1,200 psi 4 13 1,100 psi ~LEAK-OFF TEST e-e-- a:: 1,000 psi Q. 900 psi ""CASING TEST >-- >-- - 800 psi . Ie>, -- LOT SHUT IN TIME >-- >-- - ,. j -'-0_--,_".. -k- CASING TEST SHUT IN TIME 700 psi I -+- TIME LINE --- 600 psi j 500 psi 400 psi j j 300 psi ,r 200 psi 100 psi A 0 psi 02468wuMffifflwn~.Dm~~y.gG"ag~~~gæ~aM~~mnNRR~~Mæ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above -----, LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE C~~~~~~~~~~~~~~~I~~~~~~~~~~~~~~~~~r~~~~~~~~~~~~~~] ¡ ! 0 stks ! 0 psi ! rnm_m___--n-T---Tstkš---¡----"2õ--ps¡----1 F~~~~~~~~~~~~~r~~~¡Hi~~~~Fii~i~¡~~j C~~~~~~~~~~~~~~~~í~~~~~~~~f.~!~~~~l~~~~~~~~P.~!~~~~ : : 7 stks : 495 psi: r------______n_n-rm--sstks----T---ä1"õ-¡;š¡---1 [~~~~~~~~~~~~~~~J~~~~~:~!~!::::r::!.~:~)~L:] : : 10 stks : 790 psi: F~::~~:~::~::::~r~~I~~~!~~:~~:F::!!~~p.~C::i r-"'- ------..--..----- r- --.............. --....... -- --1---------- -- -- -- --1 f.~~~~~~~~~~~~~~~r~~~~~~~~~~~~~~~l~~~~~~~~~~~~~~~~j t:: :::::::::::=:::1::::::::::::::::::1::::::::: :::::::::1 t----------______ntnnn______------in_----__nn_----i r------------------t------------------1------------------1 ¡ SHUT IN TIME r SHUT IN PRESSURE [~~~~~êg~~~~E~~~~~~~~~~~~~~~~E~~;j~~~E] L--_?.:.q_!!1J!!_-j-----__------__n.J-___!~_~_E~L__j ! 3.0 min ! ¡ 800 psi ¡ t~~~~~~~~i~~~~~t~~~~~~~~=~~~~~~~~i~~~~~;~~~~~¡~~~j ! 6.0 min ¡ ! 790 psi! t~~~ì~~~g~~~~t~~~=~~~~~~~=~~~~l~~~~~~~~~~¡~~~j ! 9.0 min ¡ ! 770 psi! CJg~QË]lli:~~C~::~:~:::::::~:~C~:!.f~~p.~~~] --" CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE f ----------- --- ----,---- ------ - -- ----- T ------ - ------ -- ---, r::~~~~~~~~~~~~~~~1:~~~~~~~~~~~~~t~~~~~~p.~r~~:J ! ¡ 1 stks ! 40 psi ¡ C:~:~~~:~~~~~~~~~~r~~~~~~~!~~~~:r~~~1!~~p-~r~~1 I : 3 stks : 280 psi: E:::::::::::::::r:::H~E:r:J.~H;E::¡ : : 6 stks : 980 psi: t - ---- - - - - - ____nn -1-- --------- n- -- - -+-- -- - _n__---_n--I t_--------____--mL___!.._!!~~~_---L_~_t~~!!_p.!!L.! l------___----_n_-L----!_!!!~~----L-!t~-~!!_P.~L_¡ ~ - - - - - -- --- -. - - ---- ~- - - -- ~ _!!~~~-- -- ¡ - _!t~ ~!! - p.~)_n¡ ~__---_n_____-----~----~-~-_!!~-~~---+--~_t?_~!!_P.~L_¡ Lm_m_------_-L--!L!!~_~~--_L_!t~-~~_p.~l_-J r-------_._-----___~__n~_~__~~~~---+--~t~~~_P.~J_--! I::::::: ::::::: ::: :1:::::::::::::::::l ::::::: ::::::::::1 r - - --- - - - - - - - - -- -- - i- - - - - ---- -- -- - -- - - t- - -- - - - -.. ---------! t-- -. - - - -- _n -- -- - - in_---- -------- ---f - -- -- ----- -- - - - ---I ¡ SHUT IN TIME ¡ SHUT IN PRESSURE C~~Q~g~~~~~~~~]~~~~~~~~~~:::~:~~]::~~~g:~]:~] ~---~~OïO ~~~----~_____--m______--+--~tõO_~~_P.~L-i : ¿. mln ; : 2,10 psi: L~~~~g:~~~~~~~L~::~:::::~::~~~~I~~~~~~~:P.~r~] ~____~'<l!!!~~_--_~_____m--_____---¡--~t~_~~_p.~L_¡ L_?.:.g_!!!~~--__L__--_--____m__J.._!t~-~~-p'~_I__.! r~~~~~~~:ill~~:~~J:~::::::::~~:~~:j~~;:~~~~:~~;~~~1 : 8.0 mln : : 1,990 psi: t----~rõï1irñ----1------------------t--;f;ifšõ-pšr.! l~iÌ~¡~f~~~~~~~~~~~~lt[ii~I~~~~1 ! 25.0 min ¡ ! 1,980 psi ¡ [~:~9.~~:!!!§::]~~::::::~:::::::~~r:!~~~~~:p.~:] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~~ ...." ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I ;i9 Accept - hrs Days Since AccepUEst: 3.34/ Rig Relase - hrs: AK9725 12/09/98 4 12/06/98 04:00:00 PM Well: 2L.315 Depth (MDnvD) 4571/3577 Prev Depth MD: 2412 Progress: 2159 Contractor: DOYON Daily Cost $ 115590 Cum Cost $ 560468 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5/8' @ 2400' Next Csg: 5-1/2" @ 8372' Shoe Test: 16.0 Operation At 0600: Drilling Production hole from 4870'. Upcoming Operations: Drill Production hole, wiper trip @ +/- 7000'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO, INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 4571 2R1 N TST 12/09/98 12/06/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 70 6.75 12/02198 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 47sqc 85 HTC N SPACE 12/08/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 14/16 65 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1700 4/5/ 15 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1680 6.8 20 12/09/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 102 ml130 min 3000 2412 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER& 6.5% 2600 2159 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF .7 176bbl 2450 III 9.1/1.9 / 2L-315 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 10 11211 10 - 20 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 180. 9 61611 90 - 285 550 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -16.31 6.5% 170 II 0.518 Water Base Muds 1525 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 600 129411 131131131131 I I1III 135 Diesel 120 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $18780 20140 II 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $51538 420 11050 I I III III 1780 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID 9.1111 III III 30077 PERSONNEL TOTAL 46 "TIME "'I"END" " HQURS ' 1 '. opsCoDi:I, HQLi:SECT' " ., pHAS~QP$' '..1/, :' OPEHATIONSFRO.M.oOOO~OOOO,' :', '.'.',,' "..' ',':,'" ',", 12:00 AM 01 :30 AM 1.50 BHA PROD Making Hole PJSM. Initialize MWD, load sources and MU BHA. 01:30 AM 02:00 AM 0.50 TRIP_IN PROD Making Hole RIH, tagged cement @ 2268'. 02:00 AM 03:00 AM 1.00 CIRC SURF Casing and Circulate out and condition cement contaminated mud. Cementing 03:00 AM 03:30 AM 0.50 TEST_CSG SURF Casing and Tested casing to 2000 psi for 30 min. Cementing 03:30 AM 05:00 AM 1.50 CLN_OUT SURF Casing and Cleaned out cement and float equipment, drilled 20' of new Cementing hole to 2432'. 05:00 AM 05:30 AM 0.50 CIRC SURF Casing and Changed well over to 9.1 ppg LSND mud. Cementing 05:30 AM 06:00 AM 0.50 TEST SURF Casing and Peñorm FITto EMW of 16.0 ppg. Cementing 06:00 AM 07:00 AM 1.00 CIRC PROD Making Hole Circ and cond mud untill shakers would handle drilling flow rate. 07:00 AM 12:00 PM 5.00 DRIL PROD Making Hole Drill from 2432' to 2908'. ART=2.2 hrs AST=1.4 hrs. 12:00 PM 11:00 PM 11.00 DRIL PROD Making Hole PJSM. Drill from 2908' to 4571' recognized slight loss to hole (20 bbls). ART=5 hrs. AST=0.5 hrs. 11:00 PM 12:00 AM 1.00 CIRC PROD Making Hole Pumped sweep around and clrc hole clean. 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-315 12/09/98 Page 5 Casing Detail 5-1/2" X 3-1/2" Production Casino WELL: TARN 2L-315 DATE: 12/13/98 1 OF 1 PAGES ( ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company ( # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 25.25 TOPS 5 1/2", LANDING JT. 34.0' OVERALL LENGTH 27.00 5-1/2" GEN V CASING HANGER 2.92 27.00 Jts. 1-174 5-1/2",15.5# L-80, LTC MOD (174 joints) 7433.65 29.92 PUP 5-1/2", 15.5# L-80, LTC MOD 11.75 7463.57 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/2" x 4" 19.35 7475.32 XO 3-1/2" 9.3# L-80 8rd EUE X 5 1/2" EUE 8rd (XO) .65 7494.67 pup 3-1/2" 9.3# L-80 8rd EUE 10.14 7495.32 Jts.199-203 3-1/2" 9.3# L-80 8rd EUE ( 5 joints) 154.88 7505.46 pup 3-1/2" 9.3# L-80 8rd EUE (marker) 4.02 7660.34 Jts.184-198 3-1/2" 9.3# L-80 8rd EUE (15 joints) 466.28 7664.36 Weatherford Gemoco Float Collar 1.14 8130.64 Jts.181-183 3-1/2" 9.3# L-80 8rd EUE (3 joints) 94.42 8131.78 Weatherford Gemoco Float Shoe 1.83 8226.20 Bottom of Shoe @ 8228.03 ACTUAL TD= (8236') 8' RA THOLE. Bypass plug latch in receptical @ 8099.47'. (top of jt. #184) (23) 3-1/2" x 6-1/2" straight blade centralizers(Jts.181- 203) (12) 5 1/2'~ x 6 3/4" bow spring centralizers (Jts.1-12 ) (15) 5-1/2" x 6-1/2" centering guidess on jts 124, 127, 130, 133, 136,139,142,145,148,151,154,157,160,165,170. Remarks: String Weîghtswith Blocks: 120k Up, 60K On, 12K Blocks. Ran 23 Joints 3;.112" and 17'4 Joints of 5-1/2" casing.. Drifted 5.5" (4.75")& 3.5" (2.867") casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. ( Doyon 141 Drilling Supervisor: D. P. BURLEY ( .1118~ ~" ARCO Alaska, Inc. Cementing Details ( I Well Name: 2L-315 Report Date: 12/15198 Report Number: 10 Rig Name: DOYON 141 AFC No.: AK9725 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 3-112" x 5-112" 6-314" 8228' 8099 Centralizers State type used, intervals covered and spacing Comments: Detailed on casing talley. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.1 19.8 24 17 20 14 Gels before: Gels after: Total Volume Circulated: 9/13 41S SOO Wash 0 Type: Volume: Weight: Comments: ARCO 20 bbls a.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: Additives: Tail Cement 0 Type: Mix wtr temp: No, of Sacks: I Weight: Yield: Comments: G 60 285 15.8 1.2 Additives: 2 gps DSOO, 0.1 gps D135, 0.1 gps D47, 3% D53, 0.8% DS5, 0.12% D800. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt Up: Comments: 4.0 4.0 120 Reciprocation length: Reciprocation speed: Str. Wt Down: 20 5fpm SO Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 183.7 184 Calculated top of cement: CP: Bumped plug: I Floats held: 6994 Date: 12-15-98 yes yes Time:0440 hrs. Remarks:Circulated first BU @ 2.2 bpm with 75% returns. Staged pumps up to 4.0 bpm with full returns prior to cementing. Pumped 20 bbls of wash, 40 bbls of spacer and 50 bbls of cement. Displaced with 10 bbls of fresh water and 174 bbls of seawater, had full returns throughout. Reciprocated pipe untlllpreflush at shoe, bumped plugs to 2000 psi. ,---- ,....-....,. ,.~ Cement Company: Rig Contractor: I Approved By: DS DOYON D.BURLEY ( ( ~~ ~" ARCa Alaska, Inc. AFC No. AK9725 Well: 2l-315 I Date 112/14/98 RptNo 9 IRi9 Accept - hrs 12/06/98 04:00:00 PM 8236/5627 Prev Depth MD: 8236 Days Since AccepUEst: 8.34/ 8.5 Rig Relase - hrs: Depth (MDfTVD) Contractor: DOYON Daily Cost $165159 Rig Name: DOYON 141 Last Csg: 3-1/2" x 5-1/2" @ 8228' Operation At 0600: Installing 5-1/2" packott. Upcoming Operations: Run 3-1/2" Completion, ND/NU, move rig. MUD DATA MUD TYPE lSND WEIGHT 9.8ppg VISCOSITY 46sqc PVfYP 17/14 GELS 4/6/ APIWL 6.2 HTHP WL mll30 min SOLIDS 7.5% HOLE VOLUME 157bbl MBT 10 ph 8.5 LGS 3.9% ( PIT VOL 450 DAIL Y MUD $5221 TOTAL MUD $99439 COMPANY BAROID ,TIME 'lEND, 12:00 AM 12:30 AM 12:30 AM 02:30 AM 02:30 AM 07:00 AM 07:00 AM 08:30 AM 08:30 AM 12:00 PM 12:00 PM 03:00 PM 03:00 PM 07:30 PM 07:30 PM 08:00 PM 08:00 PM 09:15 PM 09:15 PM 10:00 PM 10:00 PM 12:00 AM ( Cum Cost $ 1181417 Next Csg: DRILLING DATA DEPTH 8236 BIT DATA BIT NO. EH&S INCIDENT N BIT NO. 4R1 ROT wr 90 puwr 127 SIZE 6.75 MAKE STC SIZE EMPLOYER MAKE SPILL N sowr 80 AVG DRAG 40 MAX DRAG 45 TRQ BTM TYPE FDS SERIAL NO lP9142 DEPTH OUT TYPE TYPE SERIAL NO VOLUME DEPTH OUT LAST SAFETY MTG 12/14/98 DEPTH IN 8236 FOOTAGE 0 ADT/AST / WOB2 DEPTH IN .", "",.I',", ". c. TRQ OFF 4000 PUMP PRES 1600 III PUMP NO 1121 I LINER SZ 61611 SPM 1 170 II FOOTAGE ADT/AST / WOB2 2l-329 SOURCE WELL 2l-315 RATE (bpm) 2.3 PRESSURE (psi) 700 INJECTION FLUIDS RPM 1 RPM 1 TFA TFA Water Base Muds 263 Fresh Water 45 Diesel 70 GPM2 129411 JETS JETS open 1111I 11111 BIT COST BIT COST DULL DULL 2121WTIA III GRADE GRADE E 11 I NO I TD III 0 TOTAL VOL (bbl) 378 TOT FOR WELL (bbl) 32920 SPS 1 20140 II 0 SPP 1 200150011 MUD wr 9.811 I ,HOURS. :I>OPSCODE' :I" HOLESECTIPHASEOPS ' 0.50 TRIP_IN PROD Making Hole 2.00 CIRC PROD Making Hole 4.50 WIPERTRP PROD Making Hole 1.50 CIRC PROD Making Hole 3.50 TRIP_OUT PROD Making Hole 3.00 TRIP_OUT PROD Making Hole 4.50 RUN_CSG PROD Casing and Cementing 0.50 CIRC PROD Casing and Cementing 1.25 RUN_CSG PROD Casing and Cementing 0.75 CIRC PROD Casing and Cementing 2.00 RUN_CSG PROD Casing and Cementing 24.00 Daily Drilling Report: 2L-315 12/14/98 Daily Drilling Report Progress: 0 Est Cost To Date $1250000 Shoe Test: 16.0 ,', DRillS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 12/13/98 12/08/98 LAST H2S DRILL 12/02/98 LAST CONFINED SPACE LAST FIRE DRILL 12/05/98 LAST SPILL DRILL 12/11/98 "",: ,""" ,," .:ii.. '. ,"'"", ,.:' '..' :' '" ': ,,'.'.iir.'., ,,:,,':"':'" ""'.' ".,... ,.,:,. .,,: ,: .'. FUEL USED :' """ ,.",:",,',':'. 2280 , DRILL WATER USED- BBLS ,. POTABLE WATER USED - BBLS ',.'.;: '." " TEMP of -28 400 114 WELL WEATHER & " PERSoNNEL DATA , WIND SPEED 8 WIND DIRECTION 15° CHILL FACTOR of .48.13 ARCO PERSONNEL 1 CONTRACTOR PERSONNEL 26 MISC PERSONNEL 6 SERVICE PERSONNEL 12 TOTAL T" "."" """OHERATIQNSFROMOOOO~OOOO PJSM. RIH to 8236'. Pump low/high vis sweeps and circ clean. Moniter well and pump dry job. 45 ,,' :'.. Wiped hole to shoe, tight spot @ 3263', no other problems. Pumped sweeps and circ clean. Monitor well, static, pump dry job. POH, laid down drill pipe. PJSM. lay down drill pipe, hwdp and collars. pulled wear bushing. Held safety meeting with GBR Casers and rig crew, RU and run 3-1/2" & 5.1/2" casing to 2365'. Circ BU @ 4 bpm, 420 psi with full returns. Run casing to 5410'. Circ BU . 4 bpm @ 490 psi lost 25 bbls. Run casing MU landing joint and cement head. Supervisor: D.P.BURLEY Page 11 ( 4lØ1II... ~" ARCO Alaska, Inc. Daily Drilling Report ( AFC No, I Date Rpt No IRi9 Accept - hrs Days Since AccepUEst: 9.34/10 Rig Relase - hrs: AK9725 12/15/98 10 12/06/98 04:00:00 PM Well: 2L-315 Depth (MDfTVD) 8236/5627 Prey Depth MD: 8236 Progress: 0 Contractor: DOYON Daily Cost $ 207844 Cum Cost $ 1389262 Est Cost To Date $ 1850000 Rig Name: DOYON 141 Last Csg: 3-1/2" x 5-1/2" @ 8228' Next Csg: Shoe Test: 16.0 Operation At 0600: Released Rig @ 2000 hrs. Upcoming Operations: MUD DATA DRILLING DATA " BIT DATA EH&S DRILLS/BOPDATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL SW 4R1 N TST 12/13/98 12/08/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.5ppg 6.75 12/02/98 12/05/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc STC N SPACE 12/11/98 PVIYP SOWT TYPE TYPE TYPE ""FlJEL \AI^TCD '..'.'iii .." 1 FDS ..:.<.,.. ... ".'." ",'".. 'Z',;,'7. ,'...'. ,..{ GELS AVG DRAG SERIAL NO SERIAL NO VOLUME . FUEL USED 1 1 LP9142 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 0 8236 12/15/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ' POTABLE WATER 0 mll30 min 8236 ',:' iNJECTION USED « BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ' WEATHE~& % 0 2L-329 I... ." ,/.' " " PERSONNELQATA' , "' HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -22 Obbl III 1 1 2L-315 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 1 121 I - 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 15° 61611 625 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -37.16 % III Water Base Muds 819 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 III open IIIII 11111 190 Diesel 185 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 31 $1500 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $100939 III 2121WTIA III 1194 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 12 BAROID III E 11 I NO I TD III 34114 PERSONNEL TOTAL 50 TIME I ' ,END " ,i, ' HOURS i I OPSCODE I ' .HOLE SECT ,', 'IPHASEOPS I, .: .'" 'OPERATIONSFROM.oQQP,-OQOO, ,'" ,,;. 12:00 AM 03:00 AM 3.00 CIRC PROD Casing and PJSM. Circulate and condition mud for cementing, final Cementing rate 4 bpm 550 psi with full returns. 03:00 AM 05:00 AM 2.00 CMT_CSG PROD Casing and Cement casing as per program, displaced with seawater, Cementing full returns throughout. Bumped plugs to 2000 psi, fioats held. 05:00 AM 06:00 AM 1.00 OTHER PROD Casing and Install and test packoff to 5000 psi. Cementing 06:00 AM 06:30 AM 0.50 RIGS PROD Other Slip and cut drilling line. 06:30 AM 01 :30 PM 7.00 RUN_CaMP CaMP Completion RU and run 3-1/2" completion. 01 :30 PM 03:00 PM 1.50 RUN_CaMP CaMP Completion Space out tubing and MU hanger. Displaced well with 175 bbls of clean seawater. 03:00 PM 03:30 PM 0.50 TEST_CSG CaMP Completion Test casing to 3500 psi for 30 min. 03:30 PM 05:30 PM 2.00 OTHER CaMP Completion Freeze protect tubing and 3.1/2" x 5.1/2" annulus to 2000' TVD with 45 bbls of diesel. Land hanger, tested tubing to 3500 psi, 10 min. & tested backside to 3500,10 min. Remove landing Joint and installed TWC. 05:30 PM 08:00 PM 2.50 NU_ND CaMP Completion ND BOPE Install adaptor flange and master valve. Tested tubing hanger and packoff to 5000 psi. Released rig @ 2000 hrs. 20.00 Supervisor: D.P.BURLEY ( Daily Drilling Report: 2L-315 12/15/98 Page 13 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-315 Date: 12/10/1998 Supervisor: D.P.BURLEY Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2400 TMD 2,292' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 3,577' TVD 41 0 psi + 9.1 ppg EMW LOT= (0.052 x 2,292') = 12.5 ppg Fluid Pumped = 4.5 BBL Pump output = 0.100 BBUSTK -1 TIME LINE 2,300 psi I I' I I I ! ONE MINUTE 2.200 psi I! I I.. ] . 2,100 ps~ I I ¡ þ-I_~ -> ,l~ I I I 2,000 psi J " l' 1900psi ,: 1:800 psi iT I I I I 1,700 psi ! I 1,600 psi I J, I I I 1500psi J. I I I I , , I W 1,400 ps~ 1 I a: 1,300 psi j ~ 1,200 ps~ 4 I I I I fa 1,100 psi r ' a: 1,000 psi -- LEAK-OFF TEST - - f- D. 900 psi I ~CASING TEST - -f- . JI I I "..', ...LOT SHUT IN TIME 800700 ps~ ,. i -A:- CASING TEST SHUT IN TIME ¡- ¡- ~ ps~ I . I I I -+- TIME LINE r- f-+- 800~ J I I I 800~ ~I I 400 ps~ i,Jr-, I )!;*J,g ,I . I, I,,,,, I :::: I 'l.Jr I I I I I TTl 100 psi J 1.Jr' I I 1 ¡ I I I 0 psi .&ill!""' I I I ¡ I I I 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 60 82 84 86 88 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r---T--------T----------' 1-----------1-----1-----------; ! ! 0 stks ! 0 psi I [===-~-=~=~=f st.@=r~~~P_~L~~~ L-------__~_~tks -i--~!»_.P!!...-i ! ! 3 stks ! 50'p'si ! '-------------1--------------------- ----, ! ! 4 stks ! 60 psi I r-------I-s-Siks--¡-gO psi--' I------i------+-----------I ! ! 6 stks ! 140 psi! r-- T- 7 stks-T1-9Õ"j>"š-f--' 1o---------4----~---------J ! ! 8 stks ! 240 psi! t----------i-----+----------f I I 9 stks I 300 psi' I--------I----~----------i L-------L--1Q stks --L--!~~s~.l ! i 11 stks ! 400 psi! ì--- i 12 stks ---r-41 0 -psr-1 .--------i--------+------I L-------L-~tks _~2°..p.!L_j i I 14 stks _L_- 43Q..P.si --~ ~------J-.!~!!~!._-!--_~~..p~L__~ ! ! 20 stks ! 420 psi! 1----1--25 stkS1----410-pšT--l r----------l-3"Õstks --r---41Õ-pŠ-r--, ----------i--------+-------------f !-------J-__~5 s~~-.i---~-~_!_--~ L---------.l-_~.!tks -L---~tQ.£~!_j ~------------1---~!.~~~t-- 41 Q..Esi i I I , I i i ! i SHI!!" IN TIMÉ1-------~'il}_!.!!'!.PRES~~~E L__~CLI!1.!!1__j_--______l__~_Q..!?21___j ! 1.0 min ! ! 330 psi! t--------f----+---------- L-~;Q. mil'!_J------l-- 33Q.'p'si -j L_~Q..rn!~-.J---___L-E~__p-~!_-j ! 4.0 min ! ! 320 psi! t---;----i---------+---------------f !-2:Q.!!1~-J-----------l---~-~..p~-~---i ! 6.0 min ! ! 320 psi! [- 7;Q~~ .c=====I=-_~i~_i!L-~ ! 8.0 min ! ! 320 psi I .-----------i------+-------------I L 9.0 m~ .l--_~?.Q..esL_.J i__!.Q;O mi~____-_-L_!!C!£~L.J CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ¡===~~ì=:~cj L_-----------1---~~~f- --~~"p_~_i___~ ~--------f----~-~~~---- J1.~_£~L~ L----------------!---~-~!~~--- _.-?~.C!P.2L__~ L______------+--_'! st~~- --~-~-~_'p~_.J ~----------i---É-~~~-- 260 ..p.2~i L---------i---~_stk~----r-!f!C?J?.~L_~ L___-__-____-L__.! stk~____J_JJ~QJ!~-H ~---------------~----_!!!~~--J-_!!33~_R~-h !---------------t----~.!!~---H?~Q..~J-4 L_--_-_-_L---~~.!!~~----t-+~.Q-~.J L_-----------l--_-"!l stk~___-t-~.QQ-R~J_j t-----------+---~~-~~~---+-~!~~Q-R~Y f:=~~=~~f=-===t-==~ r-=~~~~~===~~~~I~~===---===r==~~~~~=~=~~~~ ¡I! I !~~-l}-~_!~_!-'-~E I --------~1 UT_~~_~ESSU..RE ! 0.0 min I 2,040 psi! .-----------t-------------"'------------:;-1 L___!;.q-~!~--+-----------t-~!~~Q-~-!-J L---~~O mi ~--t-------------+_~~!~ESi -4 L_-~Q.!!1J~--t-------------f--;QQQ_R~i L_-~;Q.!!!!~___l______------- --~!~.QQ.p_sJ_-1 L---§;.~~!~---t-------------- _~~~~_R~J__~ L__6 .0- mi~___~_--------_--r-M'!!Q_R~_Ll L__LQ.~~-J----------------L-~!~~Q_R~~.J ~---~;Q..rn!~---!---------------J-_.1!~~j)-R~i !--__~;Q_min ---t------------~_t~~Q_P~J_-.. L_'!Q;Q-~!~--t---------------l' _!!~80 _R~J_~ L__'!§;Q-~!~---t-._----------- -_!!~~~..R~J_J ~___3Q;Q.~!~_-r---------- __!!~80 R~~~ ~-_3§;Q.!!1~~-T-----------__+_t~80 ps~~ L_~Q;Q.!!!~~__L_---____--___",--~!980 _R!!...J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Created by hrNrtiuk Dato ploltod : 3O-Jun-200J Plot Rbfðranoa I.J, 315 PI.ISS <D-B236'> . Coon:tina~ orð in feet nrf«enc:'ð slot #31S. True VortJcol 0cptM ore refemnt::e RKB (Doyon 1" I). - ~ ConocoPhillips Alaska, Inc. Structure: Tarn Drill Site 2L Well: 315 Field: Tarn Development Field Location: North Slope, Alaska 1Pm<Q Scale 1 inch ~ 100 ft East (feet) -> (§E¡ ~~~~~ 1000 1100 1200 1300 1400 1500 1ðOO 17QO 1800 19QO t400 g i> ~ 1200 II 0 1100 D ;:, 500 1320 ft 100 U1 0 c: 200 :;: ,....... (I) 300 ~ I 100 V 700 ConocoPhillips Alaska, Inc. Tarn Drill Site 2L 315 slot #315 Tarn Development Field North Slope, Alaska H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 315 PMSS <0-8236'> Our ref: svy5895 License: Date printed: 30-Jun-2003 Date created: 8-Dec-1998 Last revised: 29-Dec-1998 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 47.932,w150 18 54.286 Slot Grid coordinates are N 5927661.303, E 460931.771 Slot local coordinates are 184.00 S 718.97 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS <0-9727'>,,307,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 2888.5 2290.4 194.7S 1544.0E 84.9 1095.fJ 686.9 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS <0-11140'>,,313,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 2591. 2 2290.5 404.8S 811 . 7E 107.3 375.13 232.6 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference we11path Object we11path : PMSS <0-14161'>,,317,Tarn Dri 11 Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 3395.0 2290.5 1141.9S 1659.2E 125.1 1475,1 557.8 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 4 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS 9455'-12655'MD,,317A,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 3395.0 2290.5 1141. 9S 1659.2E 125.1 1475.1 557.8 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : MWD <0-11316'>,,3,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2.1,00.0 2290.5 292. 9S 453.0E 2799.2 2290.5 1076.9N 904.9E 18.3 1.142.tJ 953.8 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,3l5 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS <0-9210'>,,305,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400,0 2290.5 292.98 453.0E 2666.0 2290.5 562.8N 999.5E 32.6 1015.3 798.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 7 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS <0-9200'>,,325,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292. 9S 453.0E 2754.5 2290.5 936.7S 452.9E 180.0 643.9 464.0 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska M.D. T.V.D. Rect Coordinates M.D. T.V.D. CLEARANCE LISTING Page 8 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 PMSS <0-6864'>,~:ete'T~rn Drill Site 2L \ ./ \,'1!oriz Rect Coordinates-'''~/ Bearing Horiz Dist Min'm Dist Reference wellpath Object wellpath : 2400.0 2290.5 292.9S 453.0E 2613.0 2290.5 155.5N 1181.9W 285.3 1695.3 1268.7 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,3l5 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 9 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 2607.2 2290.5 150. ON 1174.1W 285.2 :1686.3 1268.7 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,3l5 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 10 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : PMSS <0-12403'>,,32l,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.98 453.0E 3304.9 2290.5 1203.78 l250.8E 138.8 1210.9 493.4 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). ConocoPhillips Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 11 Your ref: 315 PMSS <0-8236'> Last revised: 29-Dec-1998 Reference wellpath Object wellpath : 323 PMSS <0-10400'>,,323,Tarn Drill Site 2L Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2400.0 2290.5 292.9S 453.0E 2601.5 2290.5 597.0S 559.4E 160.7 322,2 228.1 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). 198-218-0 KUPARUK RIV U TARN 2L-315 50- 103-20276-00 PHILLIPS ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD 08236 TVD 05627 Completion Date: 12/15/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D ~D 9199 2,3 SPERRY MPT/GR/EWR4 OH 6/3/99 6/3/99 ~e/L DGR/CNP/SLD-MD FINAL 2412-8236 OH 6/8/99 6/8/99 ~ DGR/CNP/SLD-TVD FINAL 2300-5627 OH 6/8/99 6/8/99 ~'L DGR/EWR4-MD FINAL 2412-8236 OH 6/8/99 6/8/99 ~' L DGR/EWR4-TVD FINAL 2300-5627 OH 6/8/99 6/8/99 b,,,'L RFT FINAL 7500-7913 CH 5 1/6/99 1/15/99 ~4//58/d/~ L TEMSRVY-TEM/ FINAL PRES 100-7770 9/10/99 CH 5 9/17/99 9/22/99 ~/'R SRVY CALC BH 0-8236 OH 3/12/99 3/15/99 u/l( SRVY RPT SPERRY 0-8236 OH 12/19/98 12/23/98 Thursday, January 18, 2001 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation CommiSsion TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp?/~,~ C,, SUBJECT: Petroleum I~pector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep' John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 .......................... Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2N-307 1990170 2N-308 1990100: 94 70 65 P P OIL 2N-309 !990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70~ 70 P P OIL 2N~319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710 94 70 70 P P OIL 2N-325 1981630 2N-329 1980670! 94 70 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P oIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70i 65: P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% ~ 90 Day Remarks: Page 1 of 1 SVS Tam KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Barndt AOGCC Rep' John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE i2L-305 1982400 94 70! 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL ~i~':'5i ,:: ~1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [] 90 my Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc.xls Scblmberger NO. 12800 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print I C-26 99339 SCMT 990820 1 2A-02 Lt.t (--- INJECTION PROFILE 990822 I 1 2A-09 ;LEAK DETECTION LOG 990826 I 1 2A-10 PRODUCTION PROFILE 990830 I 1 2L-315 TEMPERATURE SURVEY 990910 I 1 2M-01 PRODUCTION PROFILE 990830 I 1 2N-325 {~. t e,_ RST WATER FLOW LOG 990829 I 1 2N-325 ~,..- WARM BACK TEMP LOG 990908 1 1 2N-343 L~ ~ RST WATER FLOW LOG 990827 I 1 2N-343 ~ WARM BACK TEMP LOG 990909 I 1 2V-08A ~t ~ INJECTION PROFILE 990821 I 1 3G-17 PRODUCTION PROFILE 990826 I 1 3M-02 L~i ~.. INJECTION PROFILE 9.90825 I 1 3M-10 IA.~ ~ INJECTION PROFILE 990906 I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. TI~'~I~. 9/17/99 r"l/R I 11.. I IM I:~ Si=R~JI ~--E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. June 8, 1999 MWDFommtionEvaluationLogs 2L-315, AK-MM-90035 The technical data listed below is being suhnitted herewith. Please address any problems or concerns to the attex~tion o~ J'ma Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~3, Anchorage, AK 99518 2L-315: 2"x 5" MD Resisti'"'""~y & Gamma Ray Logs: 50-103-20276-00 2" x 5" TVD Re~ & Cranmm Ray Logs: 50-103-20276-00 2"x 5" MD Neutron & Density Logs: 50-103-20276-00 2" x 5" TVD Neutron & Density Logs: 50-103-20276-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia REG , 0 $1999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG'TRANSMITTAL To: State of Alaska Alaska Off and Gas Conservation Corem Attn.: Loft Taylor 3001 Porcupim Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June3, 1999 2L.315, AK-MM-90035 1 LDWG formamxl Disc with vcrifx:ation listing. API#: 50-103-202764)0 PLEASE ACKNOWLEllGE RECT$'~ ttt(-8IG~ ,~!~IG~A~I~ RE'~...,~r!~.., ~. ~ ~ ATFACHF~D COPY OF THE TRANSMt'I~ LETI'Fti TO-TitF~ ATI'g/~fION OF:. Speny-Sun Drilling Service Attn: Jun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED JUN 03 1999 Date: ~aska Oil & Gas C~s. Commission ,~cttom~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. · --- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 12, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-315 (Permit No. 98-218/398-298) Well Completion Report Dear Mr. Commissioner: Enclosed is a well completion report for the completion on Tarn 2L-315. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [-~ GAS r-~ SUSPENDED E~ ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-218/398-298 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20276 4 Location of well at surface . 9 Unit or Lease Name 185' FNL, 719' FEL, Sec. 22, T10N, R7E, UM 7 ......... i,~ Kuparuk River Unit At Top Producing Interval.! '?'"!'~.~.,,__.-" ~!~:~i, ~--- .~~ ,i._=~.~ ~ 10 Well Number 2073' F SL, 2236' F EL, Sec. 23, T10N, R7E, U M /.~/~ ; I~~ 2L-315 .~.,~ ,~:,"'~ ..... ~. [ ~,, ~~ 11 Field and Pool At Total Depth ~ ~ ~,.~, ,: :. 1759'FSL, 1870'FEL, Sec. 23, T10N, R7E, UM ~. ~'"'¥-.~ KUPARUKRIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 117'I ADL 380051 ALK 4599 12 Date07.Dec_98Spudded 13 1Date2-Dec-98T'D' Reached 14 1Dates-Dec-98C°mp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 NO.lOf Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost - 8236' MD & 5627' TVD 8099' MD & 5556' TVD YES ~ NO ~ NA feet MD 1201 APPROX 22 Type Electric or Other Logs Run GR/Res/Neu/Dens, G~CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5~ H-40 SURF. 108' 24" 9 cu yds High Early 7.625" 29.7¢ L-80 SURF. 2400' 9.875" 330 sx AS III LW & 235 sx Class G 5.5" x 15.5¢ L-80 SURF. 7495' 6.75" 285 sx Class G 3.5" 9.3~ L-80 7495' 8228' 6.75" (included above) 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) 3.5" 7490' 7475' (CSR) 7765'-7805' MD 5377'-5399' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ~C 4 spf ~".~ ~: ~'* ~; ~ ~ ~ ~ ~PTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED -- 7765'-7805' pumped 67998~ of up to 4.5 ppa 1~18 proppant in peds Date First Production Method of Op~b~.~Flowing, gas lift, etc.) N23/99 Flowing Date of Test Hours Tested PRODUCTION FO: OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO 2~28~99 8 TEST PERIOI: 267 332 8 0[ 1241 Flow Tubing Casing Pressure CALOU~TED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVIS-APl (corr) Press. 260 0 24-HOUR RATE: 802 995 24 36.7° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 7664' 5320' T-2 7920' 5461' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~j"~~ ~/~~ Title "~t~,LItI. IGT~i~i'~I LE'~E'i~, DATE '3/'~/~14:~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/2/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-315 WELL ID: AK9725 TYPE: -- AFC: AK9725 API NUMBER: 50-103-20276-00 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/07/98 START COMP: RIG:RIG # 141 STATE:ALASKA BLOCK: FINAL: WI: 0% SECURITY:0 12/06/98 (D1) TD: 108' (108) SUPV:R.W. SPRINGER 12/07/98 (D2) TD: 2412' (2304) SUPV:R.W. SPRINGER 12/08/98 (D3) TD: 2412' ( 0) SUPV:D.P.BURLEY 12/09/98 (D4) TD: 4571' (2159) SUPV:D.P.BURLEY 12/10/98 (D5) TD: 5768'(1197) SUPV:D.P.BURLEY 12/11/98 (D6) TD: 7946' (2178) SUPV:D.P.BURLEY 12/12/98 (D7) TD: 8236'(290) SUPV:D.P.BURLEY MW: 10.0 VISC: 97 PV/YP: 22/26 APIWL: 8.4 DRILLING 9-7/8" SURFACE @ 330' (8 HR. FIELD POWER USAGE) Move rig from 2L-305 to 2L-315. Accept rig @ 1600 hrs. 12/6/98. NU diverter system. MW: 10.2 VISC: 64 PV/YP: 28/25 RUNNING 7-5/8" CASING APIWL: 6.6 Function test diverter. Drilled from 113' to 2412' MW: 9.1 VISC: 58 PV/YP: 20/21 PERFORM LOT. APIWL: 7.2 Run 7-5/8" casing. Pump cement. ND diverter, NU BOPE and test to 250/3500 psi. MW: 9.1 VISC: 47 PV/YP: 14/16 DRILLING PRODUCTION HOLE FROM 4870' APIWL: 6.8 Clean out cement and float equipment, drilled 20' of new hole to 2432'. Perform FIT to 16.0ppg EMW. Drill from 2432' to 4571' MW: 9.1 VISC: 45 PV/YP: 16/14 DRILLING PRODUCTION HOLE FROM 6195' APIWL: 6.8 Perform LOT, EMW = 11.3 ppg. Drill from 4571' to 5768' ROP dropped to 40 fph last 80' drilled, unable to improve rate. CBU, monitor well and pump dry job. MW: 9.8 VISC: 46 PV/YP: 16/17 SHORT TRIP TO 7200' APIWL: 4.2 Hit tight spot @ 5580'. Ream from 5580' to 5768'. Drill from 5768' to 7946' MW: 9.8 VISC: 45 PV/YP: 15/17 DRILL PIPE CONVEYED RFT LOGS. APIWL: 4.4 Drill from 7946' to 8236'. Run RFT log. Date: 2/2/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/13/98 (D8) TD: 8236' ( 0) SUPV:D.P.BURLEY 12/14/98 (D9) TD: 8236' ( 0) SUPV:D.P.BURLEY 12/15/98 (D10) TD: 8236' ( 0) SUPV:D.P.BURLEY MW: 9.8 VISC: 46 PV/YP: 16/16 APIWL: 5.0 MAKING WIPER TRIP, RIH @ 5000' RIH w/drill pipe conveyed RFT log to 7440' MW: 9.8 VISC: 46 PV/YP: 17/14 APIWL: 6.2 INSTALLING 5-1/2" PACKOFF. Run 3.5" and 5.5" casing. MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASED RIG @ 2000 HRS. Cement casing. Run 3.5" completion. Freeze protect well. ND BOPE. Install master valve and test packoff to 5000 psi. Release rig @ 2000 hrs. 12/15/98. Date 01/23/99 Well Name 2L-315 Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor FITZPATRICK Complete [~ Accident E~ Injury E~ Spill E~] Summary Ul~r~bming Job Num 0120990757.3 Unit 2128 Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 PERFORATE F/7765' TO 7805' RKB WITH 4 SPF HSD-DP 2-1/2" GUNS. [Per'f] SWS-ELMORE AFC AK9725 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 180KNU2 Uploaded to S Date printed: 02102199 at: 15:51:24 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT '~, Kl(2L-315(W4-6)) WELL JOB SCOPE JOB NUMBER 2L-315 DRILLING SUPPORT-CAPITAL 0105991631.4 DATE DAILY WORK UNIT NUMBER 02/07/99 PUMP FRAC JOB DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-YOAKUM JOHNS FIELD AFC# CC# Signed ESTIMATE AK9725 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 67 PSI 0 PSI 0 PSI 500 PSII 0 PSII 0 PSI DALLY SUMMARY I LEAVING 12,547 # IN PIPE.[Frac-Refrac] PUMPED FRAC WITH 67998# OF UP TO 4.5 PPA 12/18 PROPPANT IN PERFS. PRESSURED OUT TO 7000 PSI, SHUT DOWN, TIME LOG ENTRY 16:00 MIRU DOWELL FRAC, LITTLE RED PUMP AND APC VACUUM TRUCKS 17:00 HELD SAFETY MEETING, DISCUSSED. COLD WEATHER AND ASSIGNED MUSTER AREA. 18:05 PUMP BREAKDOWN WI100 BBLS WATER 26 BPM 4666 PSI. 18:25 PUMP BREAKDOWN & SCOUR SAND STAGE WITH 475 BBLS FLUIDS AND 9000~ 20/40 PROPPANT, 15 BPM AND 4211 PSI. 19:34 PUMP DATA FRAC AND FLUSH WITH 180 BBLS FLUIDS, 5 TO 15 BPM AND4729 PSI. 20:58 PUMP 500 BBLS PAD W/15 BPM AND 2399 PSI. 21:30 PUMP 2PPA STAGE OF 20/40 PROPPANT, 50 # GEL AT 15 BPM AND 3736 PSI. 21:41 PUMP RAMP UP TO 4.5 PPA AT 15 BPM AND 3172 PSI. 22:13 PRESSURED UP FRAC TO 7000 PSI, SHUTDOWN, WITH 67998 # TO 4.5 PPA AT PERFS. LEFT 12547 # PROPPANT IN TUBING. " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02513 Sidetrack No. Page ! of 4 ~g [~[~.]~1 =~! Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/315 Survey Section Name SPERRY SUN BHI Rep. i~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -184.00 Grid Correction 0.000 Depths Measured From:RKI~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -718.97 Magn. Declination 26.780 Calculation Mct hod MINIMUM CURVATU! Target Direction (DD) Build\Walk\DL p~0ft[~ 30m[~ 10m~ Vert. Sec. Azim. 128.87 Magn. to Map Corr. 26.780 Map North to: OTHER I II SURVEY DATA Survey Survey . Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~g~h TVD Section N(+)/ S(-)! E(+~)F/T~V(-' DL Build (+) Right (+) Comment Type (FT) (D-D) (DD) .~. (FT) (FT)---- (Per 10~ F~E~rop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 07-DEC-9~ MWD! 161.43 0.67 283.07 161.43 161.43 -0.85 0.21 -0.92 0.42 0.42 8" MIC SET @ 1.4 AKO ~' 07-DEC-9~ MWD 245.33 0.55 279.05 83.90 245.32 -1.64 0.39 -1.79 0.15 -0.14 07-DEC-9~ MWD 339.83 1.16 259.01 94.50 339.81 -2.65 0.28 -3.18 0.71 0.65 07-DEC-9~ MWD 428.41 0.59 286.93 88.58 428.38 -3.65 0.24 -4.50 0.79 -0.64 30' 07-DEC-9~ MWD 524.94 1.19 134.84 96.53 524.90 -3.12 -0.32 -4.26 1.80 0.62 30' 07-DEC-9~ MWD 614.76 1.88 134.71 89.82 614.69 -0.72 -2.02 -2.55 0.77 0.77 07-DEC-9~ MWD 707.34 3.26 126.81 92.58 707.18 3.42 -4.66 0.63 1.54 1.49 30' 07-DEC-9~ MWD 797.12 4.18 ~15.87 89.78 796.77 9.16 -7.62 5.62 1.29 1.02 30' 07-DEC~9~ MWD 887.72 6.32 119.74 90.60 886.98 17.30 -11.54 12.92 2.39 2.36 4.27 30' 07-DEc-91 MWD 978.83 7.84 123.17 91.11 977.40 28.44 -17.42 22.48 1.73 1.67 3.76 30' 07-DEC-91 MWD 1072.04 11.08 124.43 93.21 1069.33 43.69 -25.97 35.19 3.48 3.48 1.35 45' ,, 07-DEC-91 MWD 1162.53 13.20 122.96 90.49 1157.79 62.64 -36.51 51.03 2.37 2.34 -1.62 31' 07-DEC-9f MWD 1251.10 15.20 119.82 88.57 · 1243.65 84.17 -47.78 69.59 2.42 2.26 -3.55 31' [.~ 07-DEC-91 MWD 1344.47 15.35 118.37 93.37 1333.72 108.41 -59.74 91.09 0.44 0.16 -1.55 07-DEC-91 MWD . ~436.04 i5.24 120.04 91.57 1422.05 132.22 -71.53 112.17 0.50 -0.12 1.82 07-DEC-91 MWD 1530.07 17.93 121.05 94.03 ~512.16 158.78 -85.18 135.27 2.88 2.86 1.07 45' 07-DEC-91 MWD ~625.29 20.33 '118.92 95.22 1602.11 189.59 -100.74 162.31 2.62 2.52 -2.24 30' 07-DEC-9~ MWD 1718.89 21.51 118.20 93160 1689.54 222.47 -116.71 191.67 1.29 1.26 -0.77 15' 07-DEC-9~ , MWD 1815.06 23.38 119.95 96.17 1778.42 258.65 I -134.57 223.74 2.06 1.94 1.82 30' 07-DEC-91~ MWD 1906.26 22.64 118.03 91~20 1862.37 293.77 ~151.86 254.92 1.16 ~0.81 -2.11 30' 07-DEC-91~ MWD 2002.25 25.35 '121.80 95.99 1950.06 332.32 -171.37 288.70 3.24 2.82 3.93 45' 07-DEC.9~ MWD 2096.75 27.80 126.46 94.50 2034.58 374.42 ~195.13 323.62 3.40 2.59 4.93 40' 07-DEC-9~ MWD 2190~57 30.57 126.94 93.82 , 2116.48 420.14 -222.48 360.30 2.96 2.95 0.51 40' II r SURVEY CALCULATION AND FIELD WORKSHEET o4s -o s __ "~~r~ Sidetrack No. Page 2 of 4 · l [~[~-' I::~'~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/315 Survey Section Name SPERRY SUN BHI Rep. IN't'l ,, WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -184.00 Grid Correction 0.000 Depths Measured From:RKB~ MSL~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -718.97 Magn. Declination 26.780 Calculation Met hod MINIMUM CURVATU~ Target Direction (DD) Build\Walk\DL p6fl0ft[~ 30m[--] 10m~ Vert. Sec. Azim. 128.87 Magn. to Map Corr. 26.780 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~l[~h TVD Section N(+t~T/~S(-) E(+t)g/Ty(~' DL Build (+) Right (+) Comment Type (FT) (D-D) (DD),_~ (FT),~ ~._~ (Per 100 F~l~rop (-) Left (-) 07-DEC-9[ MWD! 2285.93 33.61 126.68 95.36 2197.26 470.76 -252.83 400.85 3.19 3.19 -0.27 45' 07-DEC-9~ MWDI 2366.41 35.99 127.95 80.48 2263.34 516.67 -280.68 437.37 3.09' 2.96 1.58 45' 09-DEC-9~ MWD 2433.46 36.68 127.77 67.05 2317.36 556.39 -305.06 468.74 1.04 1.03 -0.27 4 3/4" M1XL SET @ 1.2 AKO 09-DEC-9~ MWD 2524.62 41.52 132.32 91.16 2388.09 613.81 -342.11 512.63 6.17 5.31 4.99 50' 09-DEC-9~ MWD 2618.52 44.47 132.21 93.90 2456.77 677.73 -385.17 560.02 3.14 3.14 -0.12 31' 09-DEC-9~ MWD 2711.69 47.58 132.31 93.17 2521.45 744.65 -430.25 609.63 3.34 3.34 0.11 31' 09-DEC-9~ MWD 2804.12 50.52 130.06 92.43 2582.03 814.39 -476.19 662.18 3.67 3.18 -2.43 31' 09-DEc-9[ MWD 2899.88 53.84 131.08 95.76 2640.74 889.99 ~525.39 719.62 3.57 3.47 1.07 31' 09-DEC-9~ MWD 2992.45 55.58 130.16 92.57 2694.22 965.51 -574.58 776.98 2.05 1.88 -0.99 15' 09-DEC-9[ MWD 3086.42 55.59 i 129.38 93.97 2747.33 1043.02 -624.17 836.56 0.68 0.01 -0.83 09-DEC-9~ MWD 3178.94 55.57 129.58 92.52 2799.62 1119.34 -672.69 895.47 0.18 -0.02 0.22 09-DEC-9[ MWD 3274.43 55.60 129.82 95.49 2853.59 1198.10 -723.01 956.08 0.21 0.03 0.25 09-DEC-9t~ MWD 3368.81 55.53 130.81 94.38 2906.96 1275.92 -773.37 1015.43 0.87 -0.07 1.05 09-DEc-9~ MWD 3463.50 55.69 130.82 94.69 2960.45 1354.01 -824.45 1074.57 0.17 0.17 0.01 . 09-DEC-91~ . MWD 3557.84 55.83 130.30 94.34 3013.53 1431.97 -875.16 1133.82 0.48 0.15 -0.55 09-DEc-9~ MWD 3652.67 55.63 130.75 94.83 3066.93 1510.30 -926.08 1193.39 0.45 -0.21 0.47 09-DEC-9[ MWD 3747.09 55.44 131.02 94.42 3120.36 1588.10 -977.03 1252.24 0.31 -0.20 0.29 09'DEC-9~ MWD 3843.68 55.23 131.18 96.59 3175.30 1667.49 -1029.26 1312111 0.26 20.22 0.17 " 09-DEC-9~ MWD 3933.48 56.65 129.75 89.80 3225.59 1741.85 -1077.53 1368.71 2.06 1.58 -1.59 20' 09-DEC29~ MWD 4030.45 56.66 130.39 96.97 3278.89 1822.84 -1129.67 1430.70 0.55 0.01 0.66 09-DEC~9~ MWD 4122.67 56.53 130.70 92.22 3329.67 1899.79 -1179.72 1489.20 0.31 -0.14 0.34 09-DEC-98 MWD 4214.92 57.16 128.40 92.25 3380.12 1977.00 -1228.88 1548.75 2'.20 0.68 -2.49 20' 09-DEc-9~ MWD 4309.31 56.99 129.58 94.39 3431.43 2056.23 -1278.73 1610.33 1.06 -0.18 1.25 09-DEC-98 MWD 4403.29 56.43 130.18 93.98 3483.01 2134.78 -1329.10 1670.61 0.80 -0.60 0.64 i 1~'[~" ~;[JR~/I--~lt' {,,~AL{~IJLJ~TIO[~[ J]k[~]i~} [Zll~Ll~} WORKSHEI--T Job No. 0451_02513 Sidetrack No.__ Page 3 of 4 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/315 Survey Section Name SPERRY SUN BHI Rep. i~Ii~"~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -184.00 Grid Correction 0.000 Depths Measured From:RKI~ MSL~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -718.97 Magn. Declination 26.780 Calculation Method MINIMUM CURVATUt Target Direction (DD) Build\Walk\DL pd.~00ft[~ 30m[--] 10m~ Vert. Sec. Azim. 128.87 Magn. to Map Corr. 26.780 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~gl~l TVD Section N(-~T/~S(-) E(+0F/T~,V(- DL Build (+) Right (+) Comment Type (FT) (DD) (DD) ., , (FT), -- -- -- (Per 100 F~Ejrop (-) Left (-) 10-DEC-9~ MWD 4495.79 56.22 129.66 92.50 3534.30 2211.74 -1378.50 1729.65 0.52 -0.23 -0.56 10-DEC-9~ MWD 4592.20 56.31 130.15 96.41 3587.84 2291.90 -1429.93 1791.15 0.43 0.09 0.51 -- 10-DEC-9~ MWD 4685.79 56.01 130.33 93.59 3639.96 2369.62 -1480.15 1850.49 0.36 -0.32 0.19 , 10-DEC-9~ MWD 4781.12 55.48 127.58 95.33 3693.63 2448.40 -1529.69 1911.75 2.45 -0.56 -2.88 20' 10-DEC-9~ MWD 4872.59 55.32 127.87 91.47 3745.57 2523.68 -1575.75 1971.30 0.31 -0.17 0.32 10-DEC-9~ MWD 4970.21 54.81 126.87 97.62 3801:47 2603.68 -1624.33 2034.90 0.99 -0.52 -1.02 10-DEC-9~ MWD 5060.92 56.16 126.75 90.71 3852.87 2678.37 -1669.11 2094.74 1.49 1.49 -0.13 15' 10-DEC-9~ MWD 5159.99 55.79 127.19 99.07 3908.30 2760.43 -1718.49 2160.34 0.52 -0.37 0.44 10-DEC-9~ MWD 5250.18 55.22 127.83 90.19 3959.38 2834.74 -1763.75 2219.31 0.86 -0.63 0.71 10-DEC'98 MWD 5345.76 56.96 127.44 95.58 4012.70 2914.04 -1812.18 2282.12 1.85 i.82 -0.41 20' i0-DEC-9~ MWD 5440.16 56.41 128.56 94.40 4064.55 2992.92 -1860.75 2344.29 1.15 -0.58 1.19 10-DEC-9~ MWD 5531.61 56.69 128.33 91.45 4114.96 3069.22 -1908.19 2404.05 0.37 0.31 -0.25 10-DEC-9~ MWD 5627.35 55.74 128.94 95.74 4168.20 3148.79 -1957.87 2466.21 1.12 -0.99 0.64 ll-DEC-9~ MWD 5721.53 56.31 127.63 94.18 4220.83 3226.88 -2006.25 2527.51 1.30 0.61 -1.39 ./' 11-DEC-9~ MWD 5815.52 56.91 128.30 93.99 4272.56 3305.35 -2054.53 2589.38 0.87 0.64 0.71 ll-DEC-9~ MWD 5909.09 57.90 128.04 93.57 4322.96 3384.17 -2103.25 2651.36 1.08 1.06 -0.28 ll-DEC-9~ MWD 6003.02 55.71 127.30 93~93 4374.38 3462.75 -2151.28 2713.56 2.42 -2.33 -0.79 30' ll-DEC-9~ MWD 6097.43 55.85 126.94 94.41' 4427.48 3540.78 -2198.39 2775.81 0.35 0.15 -0.38 Il-DEC-9[ MWD 6190.49 56.31 127.16 93.06 4479.41 3617.97 -2244.92 2837.44 0.53 0.49 0.24 Il-DEC-9[ .MWD 6285.53 57.12 126.72 95.04 4531.57 3697.37 -2292.67 2900.94 0.94 0.85 -0.46 ll-DEC-9~ MWD 6379.'15 55.49 129.01 93.'62 4583.51 3775.24 -2340.46 2962.44 2.68 -1.74 2.45 30' ll-DEC-9~ MWD 6472.50 55.91 .130.93. 93.35 4636.12 3852.33 -2390.00 3021.53 1.76 0.45 2.06 ll-DEC-9~ MWD 6566.81 56.59 129.51 94.31 4688.51 3930.72 -2440.63 3081.41 1.44 0'.72 -1.51 ll-DEC-9~ MWD 6659.48 54.70 129.58 92.67 4740.81 4007.22 -2489.33 3140.40 2.04 -2.04 0.08 30' ~[ ~[JRVl::Y CA/C;[Jt"l~TION AND Fll"-lD WORKSHI--ET J°bN°' °451-°2513 SidetrackN°'-- Page 4 °f 4 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/315 Survey Section Name SPERRY SUN BHI Rep. I~"~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -184.00 Grid Correction 0.000 Depths Measured From:RKB~ MSL[~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -718.97 Magn. Declination 26.780 Calculation Method MINIMUM CURVATUt Target Direction (DD) Build\Walk\DL p6fl0ft[~ 30m~ 10m[~ Vert. Sec. Azim. 128.87 Magn. to Map Corr. 26.780 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction L~ TVD Section N(+)/S(-) DL Type (FT) (DD) (DD). . (FT) (FT) E(+~/T~Ar(- (Per 100 F~l~rop (-) Left (-) Il-DEC-91 MWD 6751.82 53.55 130.19 92.34 4794.92 4082.03 -2537.31 3197.81 1.36 -1.25 0.66 Il-DEC-91 MWD 6847.04 52.98 130.29 95.22 4851.87 4158.32 -2586.60 3256.06 0.60 -0.60 0.11 - · Il-DEC-91 MWD 6941.77 '54.72 129.37 94.73 4907.75 4234.79 -2635.59 3314.81 2.00 1.84 -0.97 20' Il-DEC-91 MWD 7039.96 54.28 130.24 98.19 4964.77 4314.72 -2686.76 3376.22 0.85 -0.45 0.89 Il-DEC-91 MWD 7131.94 54.64 129.96 91.98 5018.24 4389.55 -2734..97 3433.47 0.46 0.39 -0.30 Il-DEC-91 MWD 7223.11 54.36 129.81 91,17 5071.18 4463.76 -2782.57 3490.42 0.34 -0.31 -0.16 Il-DEC-91 MWD 7317.48 55.96 129.38 94.37 5125.09 4541.20 -2831.93 3550.11 1.74 1.70 -0.46 20' Il-DEC-91 MWD 7414.63 55.61 130.02 97.15 5179.72 4621.53 -2883.24 3611.92 0.65 -0.36 0.66 Il-DEC-91 MWD 7508.92 55.70 131.32 94.29 5232.92 4699.34 -2933.98 3670.96 1.14 0.10 1.38 Il-DEC-91 MWD 7599.52 55.51 131.67 90.60 5284.10 4774.02 -2983.51 3726.96 0.38 -0.21 0.39 Il-DEC-91 MWD 7694.49 56.01 130.90 94.97 5337.53 4852.46 -3035.31 3785.95 0.85 0.53 -0.81 Il-DEC-91 MWD 7785.12 56.56 132.66 90.63 5387.84 4927.75 -3085.54 3842.16 ! 1.73 0.61 1.94 12-DEC-91 MWD 7879.84 57,63 129.85 94.72 5439.30 5007.19 -3137.96 3901.95 2.73 1.13 -2.97 12-DEc-91 MWD 7974.43 57.91 130.41 94.59 5489.75 5087.18 -3189.53 3963.12 0.58 0.30 0.59 12.DEC_9~, . MWD 8068.55 57.77 130.84 94A2 5539.85 5166.83 -3241.41 4023.60 0.41 -0.15 0.46 ',, i2-DEC-9 'MWD 8163.86 58.90 129.18 95.31 5589.88 5247.92 -3293.56 4085.73 1.90 1.19 -1.74 12-DEC-98 MWD 8236.00 58.90 129.18 72.14 5627.15 5309.70 -3332.58' 4133.62 0.00 0.00 0.00 NO SURVEY EXTRAPOLATE TO TD 3/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12408 Company: Alaska Oil & Gas Cons Comm (i Attn: Lori Taylor I~ 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Color Floppy LIS Well Job # Log Description Date Print Sepia Disk Tape WGI-03 Lkl C_~ 99108 USIT 971112 1 D.S. 9-13 99111 USIT CEMENT IMAGE 971228 1 D.S. 9-13 99111 USIT CORROSION IMAGE 971228 1 D.S.13-06A L~.! ~ 99110 USIT CEMENT LOG 980117 D.S. 14-08A 99107 USIT CEMENT LOG 981010 1 D.S. 14-08A 99107 USlT CEMENT LOG/CBT 981010 1 .. .. , . ..... ,, SIGN~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Th~l~' ~. 1/11/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATi'N: Sherrie NO. 12216 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL Sepia LIS Tape 2L-315 RFT 981213 1 1 dAi,,,l 'I 5 1999 DATE: Alaska Oil & Gas G~'as. uol~'l~i~i~ A~ot~orag~ Please sign and return or~ copy of this transmittal to Sherrie at the above address. Thank you. Arco Alaska Inc. North Slope Alaska ASP Zone 4 Kuparuk 2L,~ Slot 2L-315 2L-3~5 Job No. AKMMgO035, Surveyed: 7 December, 1998 ORIGINAL SURVEY REPORT 18 December, ~ 998 Your Reft API-501032027600 KBE- 146.10' MWD Survey Instrument Surface Coordinates: 5927661.35 N, 460931.78 E (70° 12'47.9325" N, 150° 18' 54.2857" W) Survey Ref: svy121 Sperry-Sun Drilling Services Survey Report for 2L-315 Your Ref: API-501032027600 Job No. AKMMgO035, Surveyed: 7 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -146.10 0.00 161.43 0.670 283.070 15.33 161.43 245.33 0,550 279.050 99.22 245.32 339.83 1.160 259.010 193.71 339.81 428.41 0.590 286.930 282.28 428.38 524.94 1.190 134.840 378.80 524.90 614.76 1.880 134.710 468.59 614.69 707.34 3.260 126.810 561.08 707.18 797.12 4.180 115.870 650.67 796.77 887.72 6. 320 119.740 740.88 886.98 978.83 7.840 123.170 831.30 977.40 1072.04 11.080 124.430 923.23 1069.33 1162.53 13.200 122.960 1011.69 1157.79 1251.10 15.200 119.820 1097.55 1243.65 1344.47 15.350 118.370 1187.62 1333.72 1436.04 15.240 120.040 1275.95 1422.05 1530.07 17.930 121.050 1366.06 1512.16 1625.29 20.330 118.920 1456.01 1602.11 1718.89 21.510 118.200 1543.44 1689.54 1815.06 23.380 119.950 1632.32 1778.42 1906.26 22.640 118.030 1716.27 1862.37 2002.25 25.350 121.800 1803.96 1950.06 2096.75 27.800 126.460 1888.48 2034.58 2190.57 30.570 126.940 1970.38 2116.48 2285.93 33.610 126.680 2051.16 2197.26 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5927661.35 N 460931.78 E 0.21 N 0.92 W 5927661.57 N 460930.86 E 0.39 N 1.79 W 5927661.75 N 460929.99 E 0.28 N 3.18 W 5927661,64 N 460928.60 E 0.24 N 4.50 W 5927661.61 N 460927.28 E 0,32 S 4.26 W 5927661.05 N 460927.52 E 2.02 S 2.55 W 5927659.35 N 460929.22 E 4.66 S 0.63 E 5927656.68 N 460932.39 E 7.62 S 5.62 E 5927653.70 N 460937.36 E 11.54 S 12.92 E 5927649.75 N 460944.64 E 17.42 S 22.48 E 5927643.81 N 460954.17 E 25.97 S 35.19 E 5927635.20 N 460966.84 E 36.51 S 51.03 E 5927624.58 N 460982.62 E 47.78 S 69.59 E 5927613.21 N 461001.13 E 59.74 S 91.09 E 5927601.14 N 461022.56 E 71.53 S 112.17 E 5927589.24 N 461043.58 E 85.18 $ 135.27 E 5927575.47 N 461066.61 E 100.74 S 162.31 E 5927559.77 N 461093.57 E 116.71 S 191.67 E 5927543.64 N 461122.84 E 134.57 S 223.74 E 5927525.62 N 461154.82 E 151.86 S 254.92 E 5927508.18 N 461185.91 E 171.37 $ 288.70 E 5927488.49 N 461219.59 E 195.14 S 323.62 E 5927464.54 N 461254.39 E 222.48 S 360.30 E 5927437.01 N 461290.92 E 252.83 S 400.85 E 5927406.45 N 461331.32 E Dogleg Rate (o/,tooft) 0.415 0.152 0.709 0.786 1.796 0.768 1.535 1.290 2.393 1.731 3.483 2.367 2.419 0.440 0.496 2.877 2.625 1.290 2.065 1.156 3.242 3.402 2.963 3.191 Vertical Section (ft) 0.00 -0.85 -1.64 -2.65 -3.65 -3.12 -0.72 3.42 9.16 17.30 28.44 43.69 62,64 84.17 108.41 132.22 158.78 189.59 222.47 258.65 293.77 332.32 374.42 420,14 470.76 ASP Zone 4 Kuparuk 2L Comment Continued... 18 December, 1998 - 8:28 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-315 Your Ref: API-50'1032027600 Job No. AKMMgO03$, Surveyed: 7 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2366.41 35.990 127.950 2117.24 2263.34 2433.46 36.680 127.770 2171.26 2317.36 2524.62 41.520 132.320 2241.99 2388.09 2618.52 44.470 132.210 2310.67 2456.77 2711.69 47.580 132.310 2375.35 2521.45 2804.12 50.520 130.060 2435.93 2582.03 2899.88 53.840 131.080 2494.64 2640.74 2992.45 55.580 130.160 2548.12 2694.22 3086.42 55.590 129.380 2601.23 2747.33 3178.94 55.570 129.580 2653.52 2799.62 3274.43 55.600 129.820 2707.49 2853.59 3368.81 55.530 130.810 2760.86 2906.96 3463.50 55.690 130.820 2814.35 2960.45 3557.84 55.830 130.300 2867.43 3013.53 3652.67 55.630 130.750 2920.83 3066.93 3747.09 55.440 131.020 2974.26 3120.36 3843.68 55.230 131.180 3029.20 3175.30 3933.48 56.650 129.750 3079.49 3225.59 4030.45 56.660 130.390 3132.79 3278.89 4122.67 56.530 130.700 3183.57 3329.67 4214.92 57.160 128.400 3234.02 3380.12 4309.31 56.990 129.580 3285.33 3431.43 4403.29 56.430 130.180 3336.91 3483.01 4495.79 56.220 129.660 3388.20 3534.30 4592.20 56.310 130.150 3441.74 3587.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 280.68 S 437.37 E 5927378.41N 461367.69 E 305.06 S 468.74 E 5927353.87 N 461398.93 E 342.11S 512.63 E 5927316.59 N 461442.64E 385.17 S 560.02 E 5927273.29 N 461489.80 E 430.25 S 609.63 E 5927227.95 N 461539.18 E 476.19 S 662.18 E 5927181.74 N 461591.49 E 525.39 S 719.62 E 5927132.24 N 461648.67 E 574.58 S 776.98 E 5927082.76 N 461705.77 E 624.17 S 836.56 E 5927032.86 N 461765.10 E 672.69 S 895.47 E 5926984.03 N 461823.75 E 723.01S 956.08 E 5926933.40 N 461884.10 E 773.37 S 1015.43 E 5926882.73 N 461943.20 E 824.45 S 1074.57 E 5926831.35 N 462002.07 E 875.16 S 1133.82 E 5926780.34 N 462061.06 E 926.08 S 1193.39 E 5926729.11N 462120.36 E 977.03 S 1252.24 E 5926677.85 N 462178.95 E 1029.26 S 1312.11E 5926625.32 N 462238.54E 1077.53 $ 1368.71E 5926576.75 N 462294.90 E 1129.67 S 1430.70 E 5926524.29 N 462356.61E 1179.72 S 1489.20 E 5926473.94 N 462414.86 E 1228.89 $ 1548.75 E 5926424.47 N 462474.15 E 1278.73 S 1610.33 E 5926374.30 N 462535.47 E 1329.10 S 1670.61E 5926323.62 N 462595.49 E 1378.50 S 1729.65 E 5926273.92 N 462654.27 E 1429.93 S 1791.15 E 5926222.17 N 462715.51E Dogleg Rate (°/'tOOf~) 3.091 1.041 6.169 3.143 3.339 3.674 3.568 2.047 0.685 0.180 0.210 0.868 0.169 0.479 0.445 0.310 0.257 2.059 0.551 0.314 2.196 1.065 0.800 0.520 0.433 Vertical Section (ft) 516.67 556.39 613.81 677.73 744.65 814.39 889.99 965.51 1043.02 1119.34 1198.11 1275.92 1354.01 1431.97 1510.30 1588.10 1667.49 1741.85 1822.84 1899.79 1977.01 2056.23 2134.78 2211.74 2291.90 ASP Zone 4 Kuparuk 2L Comment Continued... 18 December, 1998.8:28 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-315 Your Ref: API-501032027600 Job No. AKMMgO035, Surveyed: 7 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. AzJm. Sub-Sea Depth (ft) Vertical Depth (ft) 4685.79 56.010 130.330 3493.86 3639.96 4781.12 55.480 127.580 3547.53 3693.63 4872.59 55.320 127.870 3599.47 3745.57 4970.21 54.810 126.870 3655.37 3801.47 5060.92 56.160 126.750 3706.77 3852.87 5159.99 55.790 127.190 3762.20 3908.30 5250.18 55.220 127.830 3813.28 3959.38 5345.76 56.960 127.440 3866.60 4012.70 5440.16 56.410 128.560 3918.45 4064.55 5531.61 56.690 128.330 3968.86 4114.96 5627.35 55.740 128.940 4022.10 4168.20 5721.53 56.310 127.630 4074.73 4220.83 5815.52 56.910 128.300 4126.46 4272,56 5909.09 57.900 128.040 4176.86 4322.96 6003.02 55.710 127.300 4228.29 4374.39 6097.43 55.850 126.940 4281.38 4427.48 6190.49 56.310 127.160 4333.31 4479.41 6285.53 57.120 126.720 4385.47 4531.57 6379.15 55.490 129.010 4437.41 4583.51 6472.50 55.910 130.930 4490.02 4636.12 6566.81 56.590 129.510 4542.41 4688,51 6659.48 54.700 129.580 4594.71 4740.81 6751.82 53.550 130.190 4648.82 4794.92 6847.04 52.980 130.290 4705.77 4851.87 6941.77 54.720 129.370 4761.65 4907.75 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1480.15 S 1850.49 E 5926171.64N 1529.69 S 1911.75 E 5926121.79 N 1575.75 S 1971,30 E 5926075.42 N 1624,33 S 2034.90 E 5926026.51N 1669.11S 2094.74 E 5925981.42 N 1718.49 S 2160.34 E 5925931.70 N 1763.75 S 2219.31E 5925886.14 N 1812.18 S 2282.13 E 5925837.38 N 1860.75 S 2344.29 E 5925788.50 N 1908.19 S 2404.05 E 5925740.75 N 1957.87 S 2466.21E 5925690.75 N 2006.25 S 2527.51E 5925642.04 N 2054.53 S 2589.38 E 5925593.45 N 2103.25 S 2651.36 E 5925544.41N 2151.28 S 2713.56 E 5925496.05 N 2198.40 S 2775.81E 5925448.62 N 2244.92 S 2837.44 E 5925401.77 N 2292.67 $ 2900.94E 5925353.70 N 2340.46 S 2962.44E 5925305.59 N 2390.00 S 3021.53 E 5925255.75 N 2440.63 S 3081.41E 5925204.81N 2489.33 S 3140.40 E 5925155.80 N 2537.31S 3197.81E 5925107.53 N 2586.61S 3256.06 E 5925057.93 N 2635.59 $ 3314.81E 5925008.64N 462774.59 E 462835.59 E 462894.90 E 462958.25 E 463017.86 E 463083.20 E 463141.93 E 463204.50 E 463266.41E 463325.92 E 463387.82 E 463448.88 E 463510.49 E 463572.22 E 463634.18 E 463696.18 E 463757.57 E 463820.82 E 463882.07 E 463940.90 E 464000.52 E 464059.26 E 464116.42 E 464 174.42 E 464232.91 E Dogleg Rate (°/'~OOft) 0.358 2.448 0.314 0.989 1.492 0.524 0.861 1.852 1.150 0.371 1.125 1.303 0.873 1.084 2.423 0.348 0.532 0.936 2.678 1.758 1.445 2.040 1.356 0.605 1.997 Vertical Section (ft) 2369.62 2448.40 2523.68 2603.68 2678.37 2760.43 2834.74 2914.04 2992.92 3069.22 3148.79 3226.88 3305.35 3384.18 3462.75 3540.78 3617.97 3697.37 3775.24 3852.34 3930.73 4007.22 4082.03 4158.32 4234.80 ASP Zone 4 Kuparuk 2L Comment Continued... 18 December, 1998 - 8:28 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-315 Your Ref: API,501032027600 Job No. AKMMgO035, Surveyed: 7 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7039.96 54.280 130.240 4818.67 4964.77 2686.76 S 3376.22 E 5924957.15 N 464294.05 E 7131.94 54.640 129.960 4872.14 5018.24 2734.97 S 3433.47 E 5924908.65 N 464351.05 E 7223.11 54.360 129.810 4925.08 5071.18 2782.57 S 3490.42 E 5924860.76 N 464407.76 E 7317.48 55.960 129.380 4978.99 5125.09 2831.93 S 3550.11 E 5924811.09 N 464467.18 E 7414.63 55.610 130.020 5033.62 5179.72 2883.25 S 3611.92 E 5924759.45 N 464528.73 E 7508.92 55.700 131.320 5086.82 5232.92 2933.98 S 3670.96 E 5924708.41 N 464587.51 E 7599.52 55.510 131.670 5138.00 5284.10 2983.51 S 3726.96 E 5924658.59 N 464643.25 E 7694.49 56.010 130.900 5191.43 5337.53 3035.31 S 3785.95 E 5924606.49 N 464701.98 E 7785.12 56.560 132.660 5241.74 5387.84 3085.54 $ 3842.16 E 5924555.97 N 464757.93 E 7879.64 57.630 129.850 5293.20 5439.30 3137.96 S 3901.95 E 5924503.24 N 464817.44 E 7974.43 57.910 130.410 5343.65 5489.75 3189.53 S 3963.12 E 5924451.35 N 464878.35 E 8068.55 57.770 130.840 5393.75 5539.85 3241.41 S 4023.60 E 5924399.16 N 464938.55 E 8163.86 58.900 129.180 5443.78 5589.88 3293.56 S 4085.73 E 5924346.70 N 465000.42 E 8236.00 58.900 129.180 5481.05 5627.15 3332.58 S 4133.62 E 5924307.42 N 465048.10 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. ~fertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.783° (04-Dec-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 128.870° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8236.00ft., The Bottom Hole Displacement is 5309.70ft., in the Direction of 128.876° (True). Dogleg Rate (°~OOft) 0.849 0.463 0.335 1.736 0.653 1.142 0.382 0.852 1.726 2.735 0.582 0.414 1.898 0.000 Vertical Section (ft) 4314.72 4389.55 4463.76 4541.21 4621.53 4699.34 4774.02 4852.46 4927.75 5007.19 5087.19 5166.83 5247.93 5309.70 ASP Zone 4 Kuparuk 2L Comment Projected Survey Continued... 18 December, 1998 - 8:28 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-315 Your Ref: AP1-501032027600 Job No. AKMMgO035, Surveyed: 7 December, 1998 Arco Alaska Inc. North Slope Alaska ASP. Zone 4 Kuparuk 2L Comments Measured Depth (ft) 0.00 8236.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5627.15 3332.58 S 4133.62 E Comment Tie-on Survey Projected Survey 18 December, 1998 - 8:28 - 6 - DrillQuest ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-315 Sundry Application ORIGINAL Dear Mr. Commissioner: Enclosed is a sundry to change the bottomhole location for KRU 2L-315. In order to provide our Operations personnel additional rathole on completed Tarn wells, AAI will be drilling an additional 100' (normally 200' below the C35 marker- now 300' below the C35) on all Tarn wells. Future Permits to Drill will reflect these changes in the proposed BHL. This additional rathole should prevent the requirement of a coiled tubing clean out below the float collar which has been necessary on several wells. Sincerely, P. Mazzolini Tarn Drilling Team Leader Tarn Development PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well __ Plugging __ Time extension _ Stimulate __ Pull tubing__ Variance__ Perforate__ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service -- 4. Location of well at surface 184' FNL, 719' FEL, Sec. 22, T10N, R7F, UM At top of productive interval 2197' FSL, 1260' FEL, Sec. 23, T10N, R7E, UM At effective depth At total depth 1937' FSL, 845' FEL, Sec.23, T10N, R7E, UM 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2L-315 9. Permit number 10. APl number 50- 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical As proposed on Permit to Drill 8898' feet Plugs (measured) 5741' feet 8898' feet Junk (measured) 5741' feet None Casing Length Size Structural Conductor 90' 16" Surface 2414' 7.625" Intermediate Production 7924' 5.5" x Liner 946' 3.5" Cemented Measured depth 9 Cu High Early 118' 260 sx ASilILW & 2442' 240 sx Class G & 60 sx AS I True vertical depth 118' 23OO' 260 sx Class G 7952' 5198' 8898' 5741' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", L-80 Packers and SSSV (type and measured depth) N/A N/A ORiGI .!AL 13. Attachments Description summary of proposal __ Contact Paul Mazzolini at 265-4603 with any questions. Detailed operation program BOP sketch __ 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Service Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢~'~~ ,~,,~~ Title Tarn Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10- ~¢~' Approved by the order of the Commission ~,-,,,~a W :!nhnston Form 10-403 Rev 06/15/88 ~. ?'~.2j~.~"~- ~~C o m m i s s i o n e r IApproval NO. ~ Date ///./.?//.~_ SUBMIT IN"TRIPLI'OATE TONY KNOWLE$, GOVERNOR ALASKA OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 1998 Paul Mazzolini Drilling Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2L-315 Revised ARCO Alaska. Inc. Permit No: 98-218 Sur. Loc. 184'FNL. 719'FEL, SEC 22, T10N. R07E. UM Btmholc Loc. 1753'FSL, 1836'FEL. SEC 23, T10N, R07E. UM Dcar Mr. Mazzolini: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a changc in bottom-hole location. The provisions of the original approved permit dated November 20, 1998. are in effect for this revision. -) dlffEnclosures Department of Fish & Game. Habitat Section W/o encl Department of Environmental Conservation w/o encl ARCO Alaska, Inc. Post Office Box' i ~0360 Anchorage, Alaska 99510-0360 November 27, 1998 B ob Crandall/Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: 2L 315 Permit To Drill Application Bob/Blair, per my discussion with Blair on Friday 11 27/98; AAI is submitting a second PTD request for the Tarn well 2L 315 due to a BHL change by the Geologists. We will send over the filing fee on Monday when our administrative personnel return to work. In the meantime, if there are any questions, please feel free to call me at 345-4590 or page me at 275-7352 (digital only). Staff Engineer tC0v 2 ? ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA'SY,,A OIL AND GAS CONSERVATION COMM~%SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen! Service X Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 184' FNL, 719' FEL, Sec. 22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1996' FSL, 2153' FEL, Sec. 23, T10N, R7E, UM 2L-315 #U-630610 At total depth 9. Approximate spud date Amount 1753' FSL, 1836' FEL, Sec. 23, T10N, R7E, UM 11/30/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2L-313 8272' MD 1753' @ TD feet 31' @ 600' feet 2560 5664' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 800' feet Maximum hole angle 59.07o Maximum surface 1 357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 2414' 28' 28' 2442' 2300' 1) 310 Sx Arcticset III L & 235 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 7415' 28' 28' 7443' 5190" 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 829' 7443' 5190' 8272' 5664' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural _ Conductor ISF~!°erfradumC~idcante 0 R ! G I, N k L ~1~ ~4b=~ ~Iv ~ D Liner NOV 2 7 Perforation depth: measured true vertical 0{1 & Co s. 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch X D~!~ X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed(' '~,~,4,,,./'~.,~ .,, ..,~i~r ~ ,~ ,~,~' ?¢.~ ~t' Title Drilling Team Leader. Date //~ .... //~ ~.,-. C°mmisii°n Use Only ~"~ I Permit Number APl num6er Approval date See cover letter for 98-218 0- //4::3' ~ ,~ O ~ ~;~ ~' //--" ~ O-"" other.._.equirements Conditions of approval Samples~ed Yes /~NE~ Mud log required Yes Hydrogen sulfide measures Yes ~~..--., Directional survey required ("Yes-') No Required working for BOPE 2M ~"~M,,~ 5M 1 OM 15M pressure Other: Original S;gr;:;~ Approved by David W, Johnston byorder of //,~) Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate .... ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L-315 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +!000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. o , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. ~"" ARCO Alaska, Inc. Secure well. Rig down and move out. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-315 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~l point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-6O 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2L-315 is 2L-313. The wells are 31' from each other at a depth of 600'. Drillinq Area Risks: The primary risk in the 2L-315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations' Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure - 2,935 psi ..... ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3½" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Created by Dob~ plott~d: 2~-N~-S8 / Plot ~f~ b 315 Ve~an ~ m ~d~ne~ ore In f~t r~eren~ 400 8O0 1200 1600 2000 2400 2800 5200 ~ 3500 4000 4400 4800 520O 5600 6000 AI CO Alaska, Structure : Tarn Drill Site 2L Well: 315 Field : Torn Development Field Location : NoAh Slope, Alaska East (feet) -> 0 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4~00 I I I I I I I I I I I I I I I I I I I I I I I I SURFACE LOCATION: I )st: 0 184' FNL, 719'FEL I of West Sok SEC 22, TION, R7E 7 5/8 Casing Pt C80 400 800 0.00 1200 (23 0 C50 1600 3.00 C¢0 fl) 6.00 2000 9.00 DLS: 3.00 deg per 100 ft 2.00 .I, Base of Permafrost Top of West Sak 2400 V 23.87 DLS: 3.00 deg per 100 ft 26.85 n .... ~ tu~+ ~,,u Top of Bermuda 29.83 .............. Target - Mid Bermuda 32.81 3200 35.80 I TARGET LOCATION: J 1.78 7 5/8 Casing Pt 1996' FSL, 2155' FEL -iD - Cosng Pt 1'4'7-76 C80 [ 5EC23' TION' R7E I 5600 %x~53'75 128.87 AZIMUTH I TD LOCATION: 1755' FSL, 1836' FEL 4940' (TO TARGET) ***Plane of Proposal*** , MAXIMUM ANGLE c5o 4 12 C35 TD - Casing Pt I I I I I I I I I I I I I I I I I I I I II I I I I I I I I 0 400 800 1200 1600 2000 2400 2800 5200 3600 4000 4400 4800 5200 5600 Vertical Section (feet) -> Azimuth 128,87 with reference 0.00 N, 0.00 E from slot #515 Creoted by rixse Dote ~otted: 25-Nov-98 Plot Reference is 315 Version ~.5. Cocrdlnotes ore in feet reference slot ti'315. 'rTrue Ve~,[col Oepths cre reference RKB (Doyon 14-1). ARCO Alaska Inc Structure : Tarn Drill Site 2L Well : ,515 Field : Tarn Development Field Location : North Slope, Alaska 80 6O 4O 2O 4O ~ 6O 0 ~oo I V ~2o 140 160 180 8O 6O 40 2O 0 i East (feet) -> 20 40 60 80 100 120 140 160 180 200 220 240 [ [ I I ~ [ ~ ~ [ 80 /_oo , 1700 e ~o ~,. 40 e e~ .... ._500 1 i O0 e eann ^ ........... ~.-$-~ .......... ::.z.7.~i-I ............................ ,~_, =o ,.k __F e.,..~. 500 ............... 900 -~ DUU .. -~-,~- e $ oo e ~ 500 '""-.... ~ 1 oo ""-.. "-~. 700 '"'-.~ 11 O0 '~. ""- '"'-~.?00 """""'""'--.... ~ "' % oo '.. '"-. '"-,~ 1300 "--.. 1 O0 1 120 V %. 1300 "-~. 1300 "'-. '"'~."-.. 1500 ""'""- '-./~ ~ 40 200 220 240 260 , ~ ' ' 2'0 ~ 80 6~0 40 '.% 1500 '".. lo ' lo '~oo' ' East (feet) -> 16O 18O 200 220 240 26O I I / I I I I I I I I I I I I I 0 20 120 140 160 180 200 220 240 1 Creoted by rlxse Dote p~otted: 23-Nov-9~ J Plot Reference is 315 Version ~5 | Ccar~nates ore in feet. reference slot ~'315. iTrue Vort[ccl Depths ore reference RKB (Doyon 141),1 ARCO A aska Inc Sfrucfure : Tarn Drill Sire 2L Well : 315 Field : Torn Developmenf Field Locafion : Norfh Slope, Alaska 50 100 150 200 250 .300 350 -4.- Q) 400 -+- 450 0 500 I V 550 600 650 700 75O 80O 85O Eosf (feet) -> 150 200 250 ,:300 350 400 450 500 550 600 650 700 750 800 850 go0 I I I I I I I I I I I I I I I I I I I I I I I I 1 I I t I ~ 1500 ,C;J 1 O0 '-.. 700 "-,~ 1700 '"--.... ! oo "".,~.1500 ""-,,. 1 I0 ~ ",., "-.. 2100 , 1500 ~ """'-.. 1900 '"'"'.. '"'"-. '"'""'"- '"' '""- '""-~. 1700 '"" 2100 '"'-.... '"'-,...2300 '""..... '"'-.... , '""., 1900 "".. '"-... "-.. ~ '"'-.... '"".... "'"-... '"'-~.2700 "'"'--......,....,. '"'",..,,....,..... ............ .~,,, ~ , ~ , .~ ........ - , , 150 200 250 500 .350 400 4 O 500 5 0 6 0 6 0 700 750 800 850 900 Easf {feel) -> 50 100 150 200 250 300 550 o 400 450 500 I 550 6OO 65O 700 75O 800 850 i Cre~ted by rixse ! Dote p~otted : 25-Nov-g8 i Plot Reference is 315 Version j Cooro~not .... in feet rd .......lot tl315. True Ve~'Jco[ Depths ore reference RKB (Doyon 141). ARC 0 Alaska Structure : Tarn Drill Site 2L Well : 515 Field : Tarn Development Field Location : North Slope, Alaska 400 500 600 700 800 900 1000 ..4-- ~ 1i00 · 4- 12o0 1300 I V 1400 1500 1600 1700 1800 1900 2000 East (feet) ' > 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 I I I I I f I I f I I I I ~ I t I I I I ~ I I I ! I I f I t ............ ............. ~h]][[[[[[[[[[.......,.~7o~ o 2~oo~.._ "' .................... ?oo 6oo L,.,.,..,,. %.". .... .... ~ 900 ..,~) 700 % '"-..'.::..,,, .... "",'::::. 8oo -,-%,,? · ' ' '" ' *" ~' ~'0 g 0 0 %'"'"%,. '"'"...,,. '%""" . ~.~1 0 '"'"'--.,,i"'"---,,,. ..%0.. ooo "',, '",, '"-',"-~, 21 O0 ~'~ '"--.. '"',2700 "'-.'."-.. ~ 1100 ""-... '"-... '"'-.'¥~o 12oo 2300",. "-. "-. "-.. 13oo "'"-. '"'.. '"".~ 3~B, N 900 '-.... "-..... ".....".%..2 1400 N~O0 '".. '"-.. '"'.. '"'-, 2300 1500 ~ "-.."-... '"-.. 37o~;"--.. k '"'::::::-..? 1 O0 '"'"'" '""% 1700 2900 '"-~"- "". ".::::... "-,..3.900 . 270{~'":,',,:,,,, 1900 t,.~ 2000 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 East (feet) -> Creote~ by rixse Dote plotted: 25-Nov-g8 ! · Plot Reference is ..7,15 Version ~5 CocrO~notes ore in feet reference slot ~'315. iTrue Vertical Depth ...... f ...... RKB (Doyon ARCO Alaska, Structure : Tarn Drill SHe 2L Well : ,515 Field : Tarn Development Field Location : North Slope, Alaska East (feet) ' 2000 2200 2400 2600 2800 3000 3200 :3400 3600 3800 4000 4200 4400 4600 4800 5000 1200 I~'""- ./ '"'"~ ....... 1600 d "" '"" " "~ 3500 '"' / %. '"--.. /' 27oo"~ " ' ....... ~ 4~oo ,., ....... ~soo ~. '"'.. '"~ 2~00 "~~700 ....... ,~00 ~00'% '~ ~0~.. 2~o~'~ ..... ' % 3300/' ",, "-.. "-~ '"--~ ~ooo x~ -. -. "'~ ~ "~ 4300~.., "-~ ~ '- '-,_ 31 O0 "~ 2200 %z~2900 "-,. x,, '~N' '" 4 "' '" 5500 '~, 1 O0 '~. 24oo 'K'C~,,, "',,,, '"-,., ~3oo '"-.~ "%.. --,,.,,.. . ~7o6'q'-. '".. '"-. 2600 "~'-, ",, "-~ 2900 ,.,,~... '-x, 4900 '-,,, ~soo ~8'~"- ~oo'".., ~oo "'-. 5000 5900 '"']"'- '""~ 5500 "'-~,3100 ~o¢'.. "'-, ~od"-.. - ""-.. 3200 "',,, ",,. "-~ 5500 "'-.,, 4100 ",.. '",,, ~ '",,, ~ "-,,, ~,oo ¢~ .. '-.... -,.poo "-, "-~ 3700 "-,, 4300 '"'~ 1 O0 '"'-, If,~l ~4300 ", 3600 ~,~'-,~ 5go0 "-, -....--..... ~~O%o° '-~ ~oo-..~... ~oo "-... "'-%~900 ~ 2900 S~O0 v 3800 4..500 4000 4200 4400 4600 4700 4900 % I I I I I I J I I I I I I I I I t I I I I t I I I I I I I I I 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 Easf (fee'f) -> 1200 1400 1600 1800 200O 2200 2400 2600 2800 3000 I 3200 V 3400 3600 4000 4200 4400 4600 ARCO Alaska, Inc. Structure : Torn Drill Site 2L Well : 515 Field : Tarn Development Field Location : North Slope, Alaska WELL PROFILE ; ..... V(~nt ..... UD in<: i'-', on, 0.00 0.~0 -:..~- of Turn 700.00 0.00 ~.~e~in Turn to Tcrget 15~0.00 [.,-~ cf 5~,'ld/Tum 2e47.15 ,~5.1~ i?¢r~et 2L-315 ~ternet ?772.9955.16 .~t-~ ~ ~.d 81~5.5555.16 DATA Dir TVD NOPJ~ Fo~t V. ~ De~/10~ O.O~ 0.00 O.CX3 0.00 0.~ 0.~ 120.~7~.000.~ 0.00 0.00 0.~ 120.~1194~1 -52.~ ~.36 ~.30 3.~ 1~.~ 1~4.~-71~5 1~.~ 141.Q20.~ 1~.4g256~.73 -52g~ 725.428S7.693.~ 1~.49~79.~-51~.11~4~.~ 49~.190.01 129.49 555g.~ -~27~.~~057.0~ 5213.11 0.~ T.C. & En~ ar H(=td E272.2~. 55.1~ 12g.49 5664.25 -5360.71 4t52.~5 5349.95 0.00 % ',,,510 ',,1700 X~ 520 300 ,,, 530 540 35O TRUE NORTH 0 210 10 2O 290 30 4O Created by rlxse Dote I~crtted: Plot Reference ;s 315 Vets;on ~5. Coorc~nates ore in feet reference slot ~515. True Ver'Ecol Depths ore reference RKB (Doyen 141 . 1oo o 5O '700 28O 270 5O ~oo q- 8O go 26 250 lO0 240 120 2~ 0 t ~7°°220 210 2OO 190 180 170 160 150 " 1700 "'"-1.40 '% Normol Plone Trovelting Cylinder - Feet All depths shown ore Meosured depths on Reference Well ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21~,4" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L ~J 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / h F- DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP I I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple 3" 5,000 psi WP Shaffer GATE VALVE {m~l~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL ~"~ w/two 3" 5M Dsi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom ARCO Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska Reference wellpath CLEARANCE LISTING Page 37 Your ref : 315 Version #5 Last revised .. 25-Nov-98 Object wellpath ~ PMSS <0-11140>,,313,Tarn Drill Site 2L Horiz Min'm E11ipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100.0 0.0N 200.0 200.0 0.0N 300.0 300.0 0.0N 400.0 400.0 0.0N 500.0 500.0 0.0N 600.0 600.0 0.0N 700.0 700.0 0.0N 711.1 711.1 0.08 722.2 722.2 0.18 733.3 733.3 0.18 744.4 744.4 0.38 755.6 755.5 0.48 766.7 766.7 0.68 777.8 777.8 0.88 788.9 788.9 1.08 800.0 800.0 1.38 811.1 811.0 1.68 822.2 822.1 2.08 833.3 833.2 2.38 844.4 844.3 2.78 855.6 855.4 3.28 866.7 866.5 3.68 877.8 877.5 4.18 888.9 888.6 4.78 0.0E 0.0 0.0 0.0E 100.0 100.0 0.0E 200.0 200.0 0.0E 300.0 300.0 0.0E 399.9 399.9 0.0E 499.9 499.9 0.0E 599.8 599.8 0.0E 698.9 698.9 0.0E 709.5 709.5 0.1E 720.6 720.6 0.3E 731.3 731.2 0.4E 742.4 742.3 0.7E 753.0 752.9 1.0E 764.1 763.9 1.4E 774.8 774.6 1.8E 785.9 785.7 2.3E 797.0 796.7 2.8E 808.0 807.6 3.4E 819.1 818.7 4.0E 830.2 829.7 4.7E 841.1 840.6 5.5E 852.2 851.6 7.0N 29.5E 76.6 30.3 N/A 7.0N 29.5E 76.6 30.3 )29.8( 6.9N 29.5E 76.8 30.3 )29.3( 6.6N 29.5E 77.3 30.2* )28.7( 6.5N 29.7E 77.6 30.4 )28.3( 6.5N 30.0E 77.8 30.7 )28.1( 6.6N 30.3E 77.7 31.0 )27.9( 6.2N 32.3E 79.2 32.9 )29.2( 6.1N 32.8E 79.5 33.3 )29.6( 5.9N 33.3E 79.8 33.8 )30.0( 5.8N 33.9E 80.0 34.3 )30.5( 5.6N 34.7E 80.2 34.8 )30.9( 5.5N 35.4E 80.4 35.3 )31.4( 5.3N 36.3E 80.5 35.9 )31.9( 5.1N 37.2E 80.7 36.4 )32.4( 4.9N 38.2E 80.8 37.0 )32.9( 4.6N 39.2E 80.9 37.5 )33.4( 4.3N 40.2E 81.0 38.0 )33.8( 4.0N 41.3E 81.1 38.5 )34.2( 3.6N 42.3E 81.2 38.9 )34.6( 3.2N 43.4E 81.3 39.3 )34.9( 2.8N 44.6E 81.3 39.7 )35.2( 6.3E 863.1 862.5 2.3N 45.7E 81.4 40.0 )35.5( 7.2E 874.2 873.5 1.8N 46.9E 81.5 40.3 )35.9( 8.1E 885.3 884.5 1.2N 48.1E 81.6 40.6 )35.9( 900.0 899.6 5.28 9.1E 896.2 895.3 0.TN 49.3E 81.6 40.9 )36.1( 911.1 910.7 5.8S 10.1E 907.3 906.4 0.1N 50.5E 81.7 41.1 )36.3( 922.2 921.7 6.58 11.2E 918.5 917.4 0.6S 51.8~ 81.8 41.3 )36.4( 933.3 932.8 7.18 12.3E 929.3 928.2 1.38 53.1E 81.8 41.4 )36.5( 944.4 943.8 7.SS 13.5E 940.5 939.2 2.08 54.4E 81.9 41.6 )36.5( 955.6 954.8 8.58 14.8E 951.2 949.9 2.7S 5517E 81.9 41.7 }36.5( 966.7 965.8 9.38 16.1E 962.3 960.8 3.58 57.1E 82.0 41.7 )36.5( 977.8 976.8 10.18 17.5E 973.5 971.8 4.38 58.6E 82.0 41.8 )36.5( 988.9 987.8 10.98 18.9E 984.1 982.4 5.18 60.0Z 82.0 41.9 )36.5( 1000.0 998.8 11.88 20.4E 995.2 993.4 6.08 61.5E 82.0 41.9 }36.5( 1011.1 1009.7 12.68 21.9E 1006.4 1004.3 6.88 63.1Z 82~0 42.0 )36.5( 1022.2 1020.7 13.68 23.5E 1017.0 1014.8 7.78 64.7E 81.9 42.0 )36.4( 1033.3 1031.6 14.58 25.1E 1028.1 1025.8 8.68 66.4B 81.8 42.1 )36.4( 1044.4 1042.6 15.58 26.8E 1039.3 1036.7 9.58 68.1Z 81.7 42.1 )36.3( 1055.6 1053.5 16.58 28.6E 1049.9 1047.2 10.48 69 7E 81.5 42.1 )36.2( 1066.7 1064.4 17.58 30.4E 1061.0 1058.1 11.38 71.6E 81.4 42.1 )36.2( 1077.8 1075.3 18.68 32.3E 1071.5 1068.4 12.38 73.4E 81.2 42.2 )36.2( 1088.9 1086.2 19.78 34.2E 1082.6 1079.3 13.38 75.4E 81.1 42.3 )36.1( 1100.0 1097.1 20.98 36.1E 1093.1 1089.6 14.38 77.3E 80.9 42.4 )36.2( 1111.1 1107.9 22.08 38.2E 1104.2 1100.4 15.48 79.5E 80.8 42.5 )36.2( 1122.2 1118.8 23.28 40.3E 1114.8 1110.7 16.48 81.6E 80.6 42.7 )36.2( 1133.3 1129.6 24.58 42.4E 1125.9 1121.5 17.58 83.9E 80.5 42.8 )36.3( 1144.4 1140.4 25.78 44.6E 1136.5 1131.9 18.6S 86.1E 80.3 43.0 )36.3( 1155.6 1151.2 27.0S 46.8E 1147.6 1142.6 19.88 88.5E 80.2 43.2 )36.4( 1166.7 1162.0 28.48 49.1E 1158.7 1153.4 21.08 91.0E 80.0 43.4 )36.4( 1177.8 1172.8 29.78 51.5E 1169.5 1163.8 22.28 93.4E 79.9 43.5 )36.5( All data is in feet unless otherwise stated[ CasinG dimensions are not included. Coordinates from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean sea le~81). Vertical section is from wellhead on azimuth 128.87 degrees. Calculation uses the minimum curvature method. Presented by Baker HuGhes INTEQ ARCO Alaska, Inc. ~ .... Post Office Box 100360 Anchorage, Alaska 99510-0360 November 27, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-315 Surface Location: 184' FNL 719' FEI_ Sec 22 T10N R7E, UM Target Location: 1996' FSL, 2153' FEL Sec. 23, T10N, RTE, UM Bottom Hole Location: 1735' FSL, 1836' FEL Sec. 23, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-315, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. Due to new data from drilling 2L 325 & 2L 313, the Geologists have moved the bottom hole location on this well. A previous permit (98-218) was issued by AOGCC with the same surface location but a different BHL. Aisc, please note that we will be using a TAM port collar on this well for the surface casing cement job. Your prompt approval is being requested by 11130198. Doyon 141 could be moving off the existing 2L 305 location to 2L 315 (pending approval) late Monday (11/30/98) evening. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There w,II be no reserve pit for this well. Waste mud will be disposec~'r'¢~.¢ down the annulus of an existing well on Drillsite 2L (subject to AOGCC~. · . ~-. approval), or hauled to a KRU Class II d~sposal well. All cutbngs gener~;lj~,~¢"~.,. will be either stored temporarily onsite or hauled to the Prudhoe Bay FielE{"~¢*'~,, for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. ARCO Alaska, Inc. is a Subsidiary of AtlandcRichfieldCompany David W. Johnsto~-~ Application for Permit to Drill Page 2 KRU 2L-305 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzol~i Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-315 Well File ~- ..... ARCO Alaska, Inc. ~ GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER KRU 2L-315 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +_]000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time .required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). , Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. '~-~ ARCO Alaska, Inc. Secure well. Rig down and move out. ]3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. ~ J DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-315 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 +10% 2-6 4-8 ~,-6 through Arete & Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank . Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.O33. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2L-315 is 2L-313. The wells are 31' from each other at a depth of 600'. Drillinq Area Risks: The primary risk in the 2L-315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Puml3in~l Operations' Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vedical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ..... ARCO Alaska, Inc. --- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2'' 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ~aOl'~no~ll Qrl ~1 tnt nl~IrencI Ito~ t31~. I 0 400 8O0 1200 1600 2000 2400 2800 3200 5600 4000 4400, 4800 5200 5800 6000 AR'CO Alaska, inc. Structure : Tarn Drill Site 2L Well : 515 Field : Tarn Development Field Location : North Slope, Alaska SURFACE LOCATION: J 184' FNL, 719'FEL SEC 22, TI ON, R7E East (feet) -> 0 400 BO0 1200 1600 2000 2400 2800 3200 I I I I I I I I I I I I I I I I I 3f Permafrost ~ of West Sok ]se of West Sok '7 5/8 Casing C80 3600 I I 0.00 3.00 6.00 9.00 DLS: 3.00 deg per 100 ft 12,00 Bose of Permafrost Top of West Sok 17.94 20.90 23.87 DLS: 5.00 deg per 100 ft 26.85 Bose of West Sok 29.83 32.81 35.80 41,78 7 5/8 Cosln9 Pt 47.76 C80 53.75 C50 C40 Top of Bermuda Target - Mid Bermuda TARGET LOCATION: 1996' FSL, 2153' FEL SEC 23, T1ON, R7E TD - Casing Pt 128.87 AZIMUTH 4940' (TO TARGET) ***Plane of Proposal-** MAXIMUM ANGLE 55.16 DEG C50 Top of Be. rrnuda ~ T4 Target- Mii_Bermud¢ ~. TD - Casing Pt ~ i i 400 i i i i i i i i i i i i i i i i i i i i i 800 1200 1600 2000 2400 2800 3200 5600 4000 4400 4800 Vertical Section (feet) -> Azimuth 128.87 with reference 0.00 N, 0.00 E from slot #515 4000 4400 I I I T2 C35 i i i i 5200 5600 400 800 1200 1600 2000 2400 2800 3200 5600 I V TD LOCATION: [ 1735' FSI_, 1836' FEL SEC 23, T1ON, R7E Dele p"otted: 25-Nov-98 Ptot Reference ie ,.~1-~ Yerslon iJS. Cocr~note$ ore in feet reference elot ~315. True Ve.'t;col Depths~ce RKB (Doyon 141). · ARCO Alaska, Inc. Structure : Tarn Drill SHe 2L Well : 315 Field : Tarn Development Field Location : North Slope, Alaska 80 6O 40 20 20 4O ~ 6O 0 1 aa I V 140 160 180 200 220 240 260 , , , , , 80 6'0 40 2~0 East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 I 1 I I I I I I I I I ! I I I I I I I I I ~ ~ .... 500 ~ ~ O0 900 ~soo ~oo '-... "-~ 900 '"- o ~oo ..... ~ ....? - ~ ~oo "-...._ ~ ~ oo "-... ~ "'"'"x, ~ 1100 '" -....~oo ---..?o~ ~---... --...~ --...... ~;~. ",~ 13~ ""'"-........._ ""'"-.,......... ",,,,,, ' '"'"-. '""-x 1700 "~:~ ~ 300 '"'-x ~ 300 ":(".~ ~ soo '""'- '"' "' 200 '"" "~ 1700 '".. '""~,, '"'" ',~ 1500 '"',.. '-,.% ' ~ ' ; ' ~'o ' ~o ............... ~o ~ 2 0 100 120 140 160 180 200 220 240 E~st (feet)'-> 8O 6O 20 2O 4O 60 0 --4- BO 1 O0 .-~ I 120 V 140 16o 180 Creoled by Dote I~otted: 25-Nov-gR Plot Referencfs Ifs 315 Verelon Ccor'd;r, otes ere in feet reference slot ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well: 315 Field : Tarn Development Field Location : North Slope, Alaska 50. 100 150 200 250 300 350 (~ ~00 -+- 450 0 500 I 550 600 650 700 750 800 850 East (feet) -> 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 I I I I I I I I I I I I I I I I I I ! I I I I 1 I I '-.. 1500 )q 1 O0 21 O0 "',~ 1700 ~, '"'.. 1900 1300 '-~ 1500 '-,,,, '"' "-. 2100 <:~ '""'-~ 1900 '.. '"-., ',. 1700 ',, '-.. 1700 "- "",. 2100 '",, 1500 1700 2500 " " " 2500 · "",,. "'"~ 2300 ' '"'"" "'""x ' '"~ 1900 '"',. '""-.. "'t,. '"-,, '"., '"'-, '"'-~ 2700 21oo '"--.., '"',...'"'--... '"'-,,....,..,...... '""-,,,.,..,.,.... -% -% 150 200 250 300 350 400 450 5 0 550 600 650 700 750 8 0 850 900 East (feet) -> 5O 1 O0 150 200 250 300 350 0 400 450 ,...h .-i- 500 I 550 6OO 650 700 750 800 850 Crecled I~y rSxse Dct¢ plotted: 25-Nov-98 I Plot Reference is 515 Version ~5. Ccord;n~te$ om in f~et f~renc~ slot ~15. ~ ARCO Alaska, S]rucfure : Torn Drill Site 2L Well: 315 Field : Torn Development Field Location : North Slope, Alaska 400 500 600 7OO 800 900 1000 -I-- ~ 1100 1200 0 1300 I 1400 1500 1600 1700 1800 1900 200O East (feet)' > 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 I I I I I I I I I I I 1 I I I I I I I I t I ! I I I I I I I I 1700 '"',."'". 2700 "".~"..1900 ~ '""-. 2500 "'~:t~t~ 2900 21o~"-., '",... "'-.~ 2700 '"'"'""'...2900 1900 '"'~ 2100 400 5OO 600 700 800 900 1aa0 '" "',.2700 '" '" '" "-. ¥~0 "-..... -..... ..~.. ..... 1200 X 2300'"-.. "..- '"' '"" 1300 '"'.. '"'., '"'~ "....,"..,2,900 ",.,. '"-.... 1400 " 2700 '"""i""', ""'., "'".. 2300 1500 ,~ 2500'-.. '-., '"'-""- 1600 · ' '"'::::'-.. 3~oo '""-,. '"':~b t '"-::',, '-'-, F ~ 2700';:~'.,. 1900 ~ 2000 i i i i i i i i i i i i i i i i i i i i i I i i i i i t i i I 0 1100 (- 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 East (feet)'-> Create~ b.v rix~e Dote ~otted: 25-Nov-gO Plot Reference ia -~15 Version Coord;no[es ore ~n teet reference slot True Vert;cel Depths ore reference RKB (Doyen 141). , ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well : ,315 Field : Tarn Development FTeld Location : North Slope, Alaska East (feet) '-> 2000 2200 2400 2600 2800 3000 3200 5400 3600 3800 4000 4200 4400 4600 4800 5000 I I I I I I I I I I I I I I I I I I I I I I I I I I '""" '": ..... O0 O0 2200 ' '~' '" 4 "' 3500 '~. O0 ":~-.. '"... '"... 33o0 ....... 2400 .,...., 3700 ..'.. -. 2~00 "C'. "-. '-~ 2~00 2800 3~0~x~',.3300 "%. 51 O0 '"-... 3000 3~00 '. '~ 5300 '-~ 4100 '-,, '~ 3500 -,, . '-, 3200 ",, "-, ".~ 5500 '"-. 4100 "","", '"-. '""-.....] 3400 4300~..'",., T'~ 5300 ",, ",~ 3700 '"',.,, 4300 '"- "~4300 "' m~..._ ~9oo "'-.,. 3600 '",,.-'~. --"'"'"--~3500 '~] 4500 ~,,~ "-,,. -'"--...~00 "",~ -"',~.5900 ~'~2900 3800 4500 '"..,_ "~.., 5~ 4000 4700 ",, '"., 4700 "'".. '"'-. 4100 4400 4600 I I I I ] I I I I I i I I f I I I I I I 2000 2200 2400 2600 2800 3000 3200 3400 5600 3800 4000 4200 4400 4600 4800 5000 East (feet) -> 1200 1400 1600 1800 2000 2200 2400 2600 0 --,i- 2800 3000 .-~ I 320o V 3400 3600 3800 4000 4200 4400 4600 ARCO Alaska, Strucfure : Tarn Drill Site 2L Well : 315 Field : Tarn Development Field Location : Norih Slope, Alaska WELL PROFILE DATA ?0~3.O0 1200.00 1500.00 7772.99 0.00 "1.00 0.00 .5~.35~,.,30 123.E~141.~2 '72~.42 8~','.8~1 ~84B.4~ 494~.1g I~: Dit TVD Nodh Eelt V. ~ De~/lO0 0,00 0.00 0,0(3 O.O0 0.00 O.00 120.0~ ?00.00O.OO 0.00 ~5.00120.00 1194.31 -32.~ 3.00 5~..16 12~.4g -~5,16 12~.4g ~37g.O0 -3100.11 O.Ol ,55.16 12~,49 -~5.16 12_=.4g 5E64.~.E % """,,51 0 ',,1700 300" 320 330 340 35O TRUE NORTH 0 210 10 20 290 280 27O 30 500 + 3O Creoted by rh~e Dote ~ted: 25--Ncrv--g8 Plot Reference ie .315 Verslon C~ord;notes are iA feet reference slot True Veri;col Depths ore reference RK~ (Doyon 141 . 40 lO0 ,0 5O '700 80 25O 100 ~no 240 120 2,50 7°°220 210 2OO 190 180 130 ""-.. 1700 "-1.40 -. '% 160 170 Normol Plone Trovelling Cylinder - Feet All depths shown ore Meosured depths on Reference Well ~-~ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 ~,4" 2,000 psi WP DRILLING SPOOL w/16" Outlet i, Flowline ~ _ 21IA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80, (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L1 b 3" 5,000 psi WP OCT MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / DSA 13-5/8" 5,000 psi WP "'~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple J F- L_ I 3" 5,000 psi WP Shaffer GATE VALVE i~~~raulic actuator 13-5/8" 5,000 psi WP I~ DRILLING SPOOL w/two 3" 5M psi WP outlets I SINGLE 13-5/8" 5,000 psi WP, / HYDRIL MPL BOP w/pipe rams / DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom ARCO Alaska, Inc. Tarn Drill Site 2L,318 Tarn Development Field,North Slope, Alaska Your reft 315 Version Last revised t 25-Nov-98 Object we11path : PNSS <0-11140>,,313,Tarn Dr~11 Site 2L Reference wellpath M.D. T.V.D. Rect Coordinates M.D. 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 500.0 600.0 700.0 711.1 722.2 T.V.D. Rect Coordinates 500.0 600.0 700.0 711.1 722.2 0.0N 0.0B 0.0 0.0 0.'0N 0.0E 100.0' 100.0 0.0N 0.0E 200.0 200.0 0.0N 0.0~ 300.0 300.0 0.0N 0.0~ 399.9 399.9 0.0N 0.0E 499.9 499.9 0.0N 0.0B 599.8 599.8 0.0N 0.0E 698.9 698.9 0.0S 0.0E 709.5 709.5 0.18 0.1B 720.6 720.6 7. ON 7. ON 6.9N 6.6N 6.5N 6.5N 6.6N 6.2N 6.1N 5.9N 29.53 29.53 29 29 29.73 30.0~ 30.38 32.3~ 32.83 33.3~ Horiz M~n'm Bearing D~st 76.6 30.3 76.6 30.3 76.8 30.3 77.3 30.2* 77.6 30.4 77.8 30.7 77~7 31.0 79.2 32.9 79.8 33.8 ./A )29.8( )29.3( )28.7( )28.3( )28.1( )27.9( )29.2(. )29.6( )30.0( 733.3 744.4 755.6 766.7 777.8 733.3 744,4 755.5 766.7 777.8 0.18 0.33 731.3 731.2 0.38 0.43 742.4 742.3 0.48 0.7~ 753.0 752.9 0.6S 1.0~ 764.1 763.9 0.88 1.4~ 774.8 774.6 5 · 8N 5.6N 5 · 5N 5.3N 5.1N 33.9B 80.0 34.3 34.73 80.2 34.8 35.4Z 80.4 35.3 36.3~ 80.5 35.9 37.2~ 80.7 36.4 )30.$( )30.9( )31.4( )31.9( )32.4( 788.9 788.9 800.0 800.0 811.1 811.0 822.2 822.1 833.3 833.2 1.08 1.83 785.9 785.7 1.3S 2.33 797.0 796.7 1.63 2.8Z 808.0 807.6 2.0S 3.43 819.1 818.7 2.38 4.08 830.2 829.7 4 .gN 4.6N 4.3N 4.0N 3.6N 38.2B 39.2~ 40 41.33 42.3B 80.8 80.9 81.0 81.1 81.2 37.0 37.5 38.0 38.5 38.9 )32.9( )33.4( )33.8( )34.2( )34.6( 844.4 844.3 855.6 855.4 866.7 866.5 877.8 877.5 888.9 888.6 900.0 899.6 911.1__. 910.7 922.2 921.7 933.3 932.8 944.4 943.8 955.6 954.8 966.7 965.8 977.8 976.8 988.9 987.8 1000.0 998.8 1011.1 1009.7 1022.2 1020.7 1033.3 1031.6 1044.4 1042.6 1055.6 1053.5 1066.7 1064.4 1077.8 1075.3 1088.9 1086.2 1100.0 1097.1 1111.1 1107.9 1122.2 1118.8 1133.3 1129.6 1144.4 1140.4 1155.6 1151.2 1166.7 1162.0 1177.8 1172.8 2.78 3.28 3.6S 4.18 4.7S 5.28 5.8S 6.58 7.18 7.88 8,58 9.38 10.1S 10.98 11.88 12.68 13.68 14.58 15.58 16.58 17.53 18.68 19.78 20.98 22.08 23.28 24.58 25.78 27.08 28.48' 29.78 4.73 841.1 840.6 5.53 852.2 851.6 6.3E 863.1 862.5 7.2~ 874.2 873.5 8.1~ 885.3 884.5 9.13 896.2 895.3 10.1~ 907.3 906.4 11.2~ 918.5 917.4 12.3~ 929.3 928.2 13.53 940.5 939.2 14.83 951.2 949.9 16.13 962.3 960.8 17.53 973.5 971.8 18.93 984.1 982.4 20.4~ 995.2 993.4 21.93 1006.4 1004.3 23.53 1017.0 1014.8 25.13 1028.1 1025.8 26.83 1039.3 1036.7 28.63 1049.9 1047.2 30.43 1061.0 1058.1 32.33 1071.5 1068.4 34.23 1082.6 1079.3 36.13 1093.1 1089.6 38.23 1104.2 1100.4 40.33 1114.8 1110.7 42.43 1125.9 1121.5 44.6~ 1136.5 1131.9 46.83 1147.6 1142.6 49.13 1158.7 1153.4 51.5E 1169.5 1163.8 3.2N 2.8N 2.3N 1.8N 1.2N 0.TN 0.1N 0.68 1.38 2.78 3.58 4.38 5.18 6.0S 6.88 7.78 8.6S 9.58 10.48 11.38 12.38 13.38 14.38 15,48 16.48 17.58 18.68 19.8S 21.08 22.28 43.43 44.63 45.73 46.93 48.13 49.33 50.53 51.83 53.13 54.48 5s~71 58.63 60.03 61.53 63.13 64.73 66.43 68.13 69~73 71.63 73.43 75.43 77.33 79.53 81.63 83.93 86.13 88.53 91.03 93,43 All data is in feet unless otherwise stated~ Casing d~menaions are not included. 81.3 81.3 81.4 81.5 81.6 81.6 81.7 81.8 81.8 81.9 81.9 82.0 82.0 82,0 82.0 ~2,o 81.9 81.8 81.7 81.5 81.4 81.2 81.1 80.9 80.8 39.3 39.7 40.0 40.3 40.6 40.9 41.1 41.3 41.4 41.6 41.7 41.7 41.8 41.9 41.9 42.0 42.0 42.1 42.1 42.1 42.1 42,2 42.3 42.4 42.5 80.6 42,7 80.5 42.8 80.3 43.0 80,2 43.2 80.0 43.4 79.9 43.5 )34.9( )35.2( )35.5( )35.9( )35.9( )36.1( )38.3( )36.4( )36.5( )36.5( )36.5( )36.5( )36.5( )36.5( )36.$( )36.5( )36.4( )36.4( )36.3( )36.2( )3~.2( )36.2( )3~.1( )3~.2( )36.2( )36.2( }36.3( )36.3( )38.4( )3e.4( Coordfnates from slot ~315 and TVD from RKB (Doyon 141) (145.00 Ft above mea~ sea le~81) Vertical section fs from wellhead on az~nuth 128.87 de~rees. Calculation uses the m~n~um curvature ~ethod. Presented by ~aker Hughes INTE~ . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 November 27, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-315 Surface Location: 184' FNL 719' FEL Sec 22 T10N R7E, UM Target Location' 1996' FSL, 2153' FEL Sec. 23, T10N, R7E, UM Bottom Hole Location: 1735' FSL, 1836' FEL Sec. 23, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-315, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. Due to new data from drilling 2L 325 & 2L 313, the Geologists have moved the bottom hole location on this well. A previous permit (98-218) was issued by AOGCC with the same surface location but a different BHL. Also, please note that we will be using a TAM port collar on this well for the surface casing cement job. Your prompt approval is being requested by 11/30/98, Doyon 141 could be moving off the existing 2L 305 location to 2L 315 (pending approval)late Monday (11/30/98)evening. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption ARCO Alaska, In~ is a Subsidiary of AflanficRichfieldCompany David W. Johnsto~...~ Application for Permit to Drill Page 2 KRU 2L-305 However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for repoding responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzol, i, fli Drilling Team Leader Exploration / Tarn Development GrOup Attachments cc: KRU 2L-315 Well File .. OF:IICI_lNG S E I:!~/I I: Ec: 19-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-315 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,236.00' MD (if applicable) Please call me at 563-3256 if you have any questk Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS ~oYem~er ~o~ ~NSERVATION COMMISSION James Tmnthum Drilling Team Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kupamk River Uuit 2L-315 ARCO Alaska. Inc. Permit No: 98-218 Sur. Loc. 184'FNL 719'FEL. SEC 22. T10N. R07E. UM Btmholc Loc. 1981'FSL. 915'FEL SEC 23. T10N. R07E. UM Dear Mr. Tranthmn: Enclosed is thc approved application for pcnnit to drill thc above referenced well. Annular disposal of drilling wastes will not be approvcd for this well until sufficient data is submitted to ensure that thc rcquiremcnts of 20 AAC 25.080 are met. Annular disposal of drilling waste ,,,,,ill be contingent on obtaining a well cemented surface casing confirmcd by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and an,,' CQLs must be submitted to the Commission on form 10-403 prior to thc start of disposal operations· Please note that an5' disposal of fluids generated from this drilling operation which are pumped down lhe surface/production casing annulus of a well approved for annular disposal on Drill Site 2L must comply with the requirements and limitations of 20 AAC 25·080· Approval of tiffs pcnnit to drill does not authorize disposal of drilling xvasle in a volmne greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one ','car. Thc permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting deterlninations are made. Thc blov~'out prcvcntion equipn]cnt (BOPE) must be tested in accordance with 20 AAC 25.035: and thc mechamcal integrity (MB of thc injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI test before operation, and of thc BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of thc Commissiou may witness thc tests· Notice may be given by contacting the Commission petroleum field · Clminnan "~~ BY ORDER OF THE COMMISSION dl£F. ncl~sure cc' Department offish & (.lame. Habitat Section w,(~ encl. Department (~I' Envir,~nmental Conservation w,o encl. STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Re-Entry Deepen Service X Development Gas Single Zone X MiJltiPle'Zon~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 184' FNL, 719' FEL, Sec. 22, T10N, RTE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2197' FSL, 1260' FEL, Sec. 23, T10N, R7E, UM 2L-315 #U-630610 At total depth 9. Approximate spud date Amount 1981' FSL, 915' FEL, Sec. 23, T10N, RTE, UM 11/22/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2L-313 8798' MD 915' @ TD feet 27' @ 1246' feet 2560 5684' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 59.07° MaxJmurn surface 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 2414' 28' 28' 2442' 2300' 1) 20 Sx Arcticset I11 L & 240 Sx Class G 2) 240 sx AS III L & 60 sx AS I 6.75" 5.5" 15.5# L-80 LTC-M 7924' 28' 28' 7952' 5198' 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 846' 7952' 5198' 8798' 5684' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: true measured vertical 0 20. Attachments Filing fee X Property plat ~,1 BOP Sketch X ketch X Drilling program X Drilling fluid program X Timevs depth plot F,~ Refraction analysis E~ Seabed report [~ 20AAC 25.050 requirements X 21. I hereby certify ~regoing is true and correct to the best of my knowledge Signed ,,~~~ [ ~~¢~.~ '~"~T~ Title Drilling Team Leader. Date Commission Use Only ~b,,e.~___ APl number I Approval date / - o ~ I See cover letter for Permit /) ~' 50- r/'~O ~ -- .2... O ~-. ,'~ ~ I~'~(~- }~'-'~other requirements Conditions of approval Samples required [~ Yes ~ No Mud togrequired r-] Yes ~ No Hydrogen sulfidemeasures BI Yes ]~ No Directional surveyrequired '~ Yes [~ No Required working pressure for BOPE ~1 2M r-~(/~-M~)[~ 5M ~ 10M r-~ 15M Other: 0riginai Approved by Commissioner the commission Date .... Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA 0£~% , ALAS~,A OIL AND GAS CONSERVATION COMIVr~'SION ~ ,-:.~, ~5' i~9~8- PERMIT TO DRILL 20 AAC 25.005 '~taska 0ii & ~asCo~. ~missior~ la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test I~}gl~r¢~ Oil Re-Entry DeepenJ Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 184' FNL, 719' FEL, Sec. 22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2197' FSL, 1260' FEL, Sec. 23, T10N, R7E, UM 2L-315 #U-630610 At total depth 9. Approximate spud date Amount 1981' FSL, 915' FEL, Sec. 23, T10N, R7E, UM 11/22/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2L-313 8798' MD 915' @ TD feet 27' @ 1246' feet 2560 5684' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 59.07° Maximum surface 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOD 2414' 28' 28' 2442' 2300' 1) 20 Sx Arcticset III L & 240 Sx Class G 2) 240 sx AS III L & 60 sx AS I 6.75" 5.5" 15.5# L-80 LTC-M 7924' 28' 28' 7952' 5198' 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 846' 7952' 5198' 8798' 5684' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Sudace Intermediate Production Liner Perforation depth: t r%eea Sv~ rd~cdal DUPLICATE 20. Attachments Filing fee X Property plat E~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E~ Refraction analysis E~ Seabed report Et 20 AAC 25.050 requirements X 21. I hereby certify ~regoing is true and correct to the best of my knowledge Signed J~~ [ /'~¢~~-,~ -~T~k,. Title Drilling Team Leader. Date 16~)(..T' Commission Use Only r/,~,~ I APl number IAppr°val date "~ Pe u m.~/~ ~ 50-/~0 ,,,~ ..~... (~ 2--, 7~ / 1~.~ ~ c~ See cover letter for - - -' , other requirements Conditions of approval Samples required FI Yes ~1 No Mud logrequired r'~ Yes '~ No Hydrogen sulfide measures r~ Yes 'J~ No Directional survey required [~ Yes E~ No Required working pressure for BOPE F! 2M E] QE~ 5M r'~ 1OM E] 15M Other: by order of David W, Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 - Submit in triplid,~te ..... ARCO Alaska, Inc. -~ GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L-315 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ...... ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-315 Drillinq Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 _+10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: ITriple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2L-315 is 2L-313. The wells are 27' from each other at a depth of 1246'. Drillinq Area Risks' The primary risk in the 2L-315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the head of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi '~. ~ ARCO Alaska, Inc. ~-- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ~,,~ FOR: BRASSFIELD Cote p~otted : 8-Cct-98 I~EQ aDO SURFACE LOCATION: 184' FNL. 719' FEL SEC 22, T10N. RTE Ax C0 Alaska, !nc-7 t Structure : Torn Drill Site 2L Well : 315 Field : Tarn Develcpmenf Field Locafien : North Slope, Alaska East (feet) -> 400 800 1200 1600 2000 2400 2800 3200 3800 I V 4oo 800 1200 1600 2000 2400 2800 3200 3600 4000 End Initiot Build Section Bose Permafrost ~d% Son~s to Tar°et Bose West S(~k Sands 7 5/8 Casing 121.45 AZIMUTH 5555' (TO TARGET) *-=Plane of Proposals,= 4000 : 4400 4800 5200 t RKB ELEVATION 1 C50 I KOP TVD=700 TMD=700 DEP=O la.OD 16.DO 9.00 ~'12 O0 END INITIAL BUILD TV0=1194 TMD=1200 DEP=64 t Bi PERMAFROST TVD=1195 TVD=1201 OEP=64 T / W SAK SNDS TVD=1239 TMD=1246 DEP=76 BEGIN TURN / CONTINUE BUILD TVD=1484 TMD=15OO DEP=141 C40 TARGET LOCATION: 2197' FSL, 12B0 FEL SEC 23, T1ON, R7E TARGET TVD=5398 TMD=8300 OEP=5555 SOUTH 2899 EAST 4738 Begin Anale Drop 4O0 r- 0 - 400 i800 , ! ? 1200 1600 i k2000 2400 17.94 End Angle Drop 74 ~- 2800 20.90 T3 - Top '~ ~ ~.784 TARGET Mid Bermuda Tz - Bose .uermucc .C..~ % 29.82 B / w SAK SNDS ~D=1897 TM0=1945 OEP=303 ~ ~ . . 4 TO LOCATION- J ~.76 7 5/8" CSG PT ~D=2300 TMD=2442 BEP=592 198" FO' cl:"F~, ~ ~7.75 C80 ~D=2470 TMD=2690 DEP=772 ~ L 3600 36 TMD=2979 0EP=1007 MAXI~M ANGLE 59.0? DEG =37~4 IMD=521 2 ~897 DEP=351i 4400 4800 5200 ~ 55 DgO 6000 ~ I ] ] I I I I I J I i I I I i I J I I I tI i I I I i 400 0 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4~00 4800 5200 5600 6000 Vertical Secfion {feel} -> Azimuth 121.45 with reference 0.00 N, 0.00 E from slot #315 I V 6400 ICrcote. d by Michoclson For: IlIIA.C;SF[I']I,I} Dote plotted : B-Oct-g8 1,rue Vert~col D~Dlhs ore ref~renc~ ~KEI H~flES 60 20 ~ 4O 0 80 I V lOO 120 140 160 180 200 - Eosf (feet) -> O0 80 60 40 20 0 20 40 6('1 80 1 O0 120 "140 160 180 200 220 240 260 280 500 ,320 ,340 I I t J.I I I I I L..~t t J, I ..... J I ..... I ! t I I .I. I I I L__ I I I I I I I I I I ! I I I_~ I I I 60 : ¢g6~ ..... 7oo ; 4O i1700 0 (~'500 900 i1600 ~)~500e ...... '~-~::---~-:-::--'-ii'?_-'...~'9.UQ ....................... 12.00 ................... : 2O t ¢' '"'h%if .......°'J" soo ~o~":-:~'-'-i~'6t~ ........ f~'~:'c;'::::::::::'::-: ..... laOO ........... ' ' ) 9~ .... '"' ' .... "' ..... 1300 i 1 -(~- (~50C ............ 905 ........ 1200 '~"-'--~- t 57~. ~ "-,.900 1000 .......... ' ...... ... 1000 ';'~'~:::t: ........ 1400 : -- 50(]"'", '"-.. 1000 ......... ' ....... ' ....... ':: .......... O t~t'.5000 (~). 500 ~1'..5.00'500 gOO ..... ' .... 1..0. ~ .... ' ...... ' ....... 1100 .......... ""'-....8. 00'"'"'6'?.0... 700 1000 ......... 110~' ........... "'""'1' '--,.. 1200 ,, .u .............. - ........................ " ~' 120~""---. ......... 1200 ""-.. 900 '%. 900 '.. 120~'"--. -.. -- ' ..... "'"'-.,. 1000 '""... "'"--. 800 '""--.... '"'-- "'""-- ......... ".. '.. 1000 ".. 1 .'~00 '-..,,. 1.300 "-- "-- -.. -... '-,. ~ oo ~ ~' ...... '"-,,,, ' ........ 13oo '"~ ',, 1500 '.. 1 400 · '~, 1500 ',,. ",. ', ~ 500 ...... '-.. - ..... '-,, ~20o "'- '"', "--L' .... - ..... '""" '"'"'., 12~'(~"'" 1000 160'~""":::-. ~. 1500 ...... ...... ' .... '-.... '- :.-..::.. "%. 1500 -... .... , -.:~:.. 80 · "-. ' "-. 1700 '""-.'-.. "".. '"".. 1.300 '"".. 11 O0 '"':"z~. 1600 ".... "..... "..... 18 ~........ "..~ 1400 ".. "-.. "".. '"'.. '"',,.. 1199,99 1900 "%. 1500 '".. "-.. '" -...z~. " '"'. " '"'.~' " '"". '"' ---- 160 ,. / '" ',, ',,. 16oo ',.. t- "' 'X 150('1 '.. '-.. '"'-.. 1 }00 ' , '. "'- 180 · " ' '" "" 1600 '"".. 1 I I - I I I T--'"'-I ...... T ......... I' ...... ~'-----~F------'r-'---T ...... "l------T- I ---r .... "T .... f ......... ! ...... T ......... I ......... ? ....... i ........ 1-----1' i i i i -1'-- i i -'~F- .... I-'--T--"! ....... F ....... 1 ........ I ........ r-- ~O0 O0 80 60 40 '20 (] 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 .300 320 540 East (feet) -> 40 0 C' ..+., 100 V 12o 14o Created by Michaelson For: III~A$SI,'IELD J Dote plotted : O-Oct-gO J Plot Reference ;s 315 Version jJ/'~. Coord;nates ore ;n feet reference slot J315. J [rue Verticol 0epths ore reference RKB (Doyon 141),m I 120 16O 20O ARCO Alaska, Inc. Structure : Torn Drill Site 2L Well : 515 Jrield : Tarn Development Field Localion : North Slope, Alaska East (feet) -> 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1050 t i i i i i i i J ___._l ..... 1 I I I I l .... J I I [ [__ L I ...... I. l ..... J I I L__ I I I I I I k__l__ I L.--J I i i I -- ........ "''-..., soo - ......... ~'L:'.:'.-: ."--- 2ooo ........ ~. 2000 °%-... "-., -'"-- .... 1 600 ',-,-...,,%, , ......... -'-'-'.'.:.-,~ ......... ' ......... 21 (~'";:'.'.,.:..1900 '" .... 21 O0 ......... ' ............. ' ............. "--.. "'-... .......... ' ......... 2200 240 2~0 Q) 320 360 4O0 440 480 520 560 6O0 17~"-,, 1400 220~'::::'-,, 2000 "-,.1600 . '" "' ~.2~ ...... ' ..... ,700 ---4 .... ' ..... ' ...... '"~-~ "",180~'".. '"":'.::"'-. ....... . ' ....... '"'"'""'"'"'"'i . '-,2100 " ... '"'... ",, 1500 '" '"' "- '"-,, 1900 ,, '",,, ', "'"'- '" "~ '",,,,, '"-., ~90~"', 240~"-. "'"-., 2200 '"'"" '"',,,,, ""-,, "'",. "'",, ""-,., '""-.. 1700 ',, ,,,. .ooo '-,,.,, ' ........ "'"'"',,, '"',. '"'-,,1600 ""',, '""-. "'",,, '",, 2100 '"',. '"',, '"',, '""-, '"",, " '" 21 O0 "" ",, 2600 "-, "-. ',,,, "-,,. "... ",. "-,, 2 O0 "'-, 2200 "'"., '""-, '"'"-, "'"'"', "' '"' 2200 ""- "'., 2700 '"-., ',,,, '--,:::.,,,,, "'-..,,,,,,,, '"-,,,,,.,.., 2100 · · ',. 22OO ,, ',, ,, ',,. 1 700 . -----r-----T--- I I [ I I I I I I 1 F--"--'T .... -1- ....... '1- .......... T~'- I [ i i I i i i I ) I '--T'-'- ~ ..... 1 I I I [ [ I I i ' i - l i ...... T--'- - 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1 Eas! (feet) -> 120 16O 2OO 240 280 o 32O --i- 360 '-~ ..-i- 400 I V 440 480 520 56O 6OO I greated by Michoelson For: BRA$SFIEI,D Dote plotted : 8-Oct-ge Plot Reference is ",15 Version ~3.J Coordinates ore in ~c~t reference slot ~315. J True Vertical Deplhs ore re~erence RKB (Doyon 141)J JARCO Alaska, ino. J JStructure : Torn Drill Site 2L Well : 315 rinld : Tarn Development Field Locotion · North .Cilopa ~,lasko ~ 900 Q] v 1000 East (feet) -> go0 1000 1100 1200 1300 1400 1500 1500 1700 1800 1900 2000 2100 2200 2.300 2400 2500 2600 2700 2800 2900 .3000 '" ...... 2500 .......... 1900 '" .... ..2500 26002000 .......... ~i ............ 2100 3tO0... 600 %... '"'-... 28;'~---... ' .... :-.. ' ....... -. ~'~ ...... ~ ................ ",. '..,... -..... '-,..... '-..... "--.... ' .......... ' ............2200 700 '""-. "",.. '"",,. 2900'""-2-?® ..... ',.. 2000 .......... 2800 .............. ' ................ .~ "-.. "., "-. "-.. '"-. "--. 2600 '"' ..... ' .... '-..... '--.,.jsoo '-..... '" ...... ' ...... .. ' ......... 800 "-,, "-., "-., .3000 '"-- 2700 '"'-. "'-. -4--" ' " ~' ' " "' - ~" ~ oo -.. '--. '-.. '-.. '-.. ~_,oo '.. , , ~ '"'"'"'"" "'"" ' ..... "- '" ..... ' ...... xC-4 ",, "-, ",... 5100 "-, "-., '" '"' 2700 ' ' ' ".,.7o ""'.....:,,oo .... , , !oo ....... ...... . ..... / ', 2500 '- ', '-. '" 900 "' "' ' " "'- '",, "", .3300 '"- '"' "" " ,~ ",, ',,, -,, -,,' "-., "-,. 2300 "--. 2800 ,' 0 1100 J ",,,, ",.,2600 '"",. '"",. 20°0 '"",. 3400 '"'-,.,3000 '"--,. '"'-... ," V 1200 '",, ~7nn '"', 260~"', ""', '"", """, '""-.. 2400 ," "'"'-, ""' '~ ";'"'~ "% "%, '"% "", '"", ''"- /' ",, ", ",, "-, "-...3500 "-.. "-,. ,,' ", ",, "-, '"., "-. "-...3100 "--. ,,' 1.300 '"", '"', 2700 "'". '"". .... '"'-. ,3600 '"'".. '"'"40.500 ".. 2800 ",. ".. ".... 2, uu ".. '-.. ,,' "-.. ,,,,, ',,,, ~;'~.,,, "-,.,.. '---.,,.. "-,....,~oo ,,,, ........... ,,oo ,,,,,,,, ,,,,,,,, ,.,.,..,., ,..,,,,,,, ......CoO .../,.,.. ...... 1500 ~, '"',. 2900 '"',,, """,, "'"'-,, "'"'-~. 5800 // "'"",i5300 ", ",, ',. 2800 '"' '"' 2200 '"' '"' '""' '"'.., ~.8oo ".. ". ~;ii-.... "'--... ""-.-..."' ""~:~ % '"% ,% ,% ,% 1700 i i T-- i i i i i-----'I----'I~--'T----'I .... i i - i T i T ..... 'T~-i I .... 1 ........ q ........ 1 ...... q ........ 1'-I I I I I I F~'-*"T'--'I I I---I ....... I ...... r ....... 1 ..... 'l i 900 1000 1100 1200 1,300 1400 1500 1600 1700 1800 1900 2000 21(10 2200 2300 2400 2500 2600 2700 2800 2900 ,3000 East (feet) -> 4O0 500 600 700 800 900 fJ') 0 000 100 ~ I 12oo V 1500 1400 150O 1600 17O0 Creoted by Michoelson I"or: IlRASSI"IEI,I) J Dote plotted : 8-Oct-g8 J Plot Reference is 515 Version ~3, Coordino~es ate in feet reference slot ~315. True Verdcol Depths ore reference R'KB (Doyon 14t)[ INTEO ARCO Alaska, Iz c. .................. Slructure : Torn Drill Site 2L Well : 315 IField : Torn Davelopmenl Field Iocntlon : North Slope. AlosI<o East (feet) -> 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 ]200 I I I I I I I I I I I I I I I I I. J. .I I .1___1 .... l ..... I I I I I I I I I I I I I ,I I L I. I I I I 140oq,~,. '""-. 3700 '--,??0 ....... ' ....... 3000 ........... 3700 ............ ~100 r.<.zeh x.. )... "-..2600 ---. "' ..... ' ........ _~'-~'-.. "-..~3800/ "'-.. 3300'"-.. '"-.. '"---.. 3800 ........ :.200 *~'x'""..2200 "-...." '""-.. '"'--, 2700 "'"--. ,1~ ' .......... _ 3900 ............. ~3Qo~ 1600- 2800"... "-.. .?.x.3900 "-...3400 '--.. -x.~ uu ........ 4000 '"3oL~ '"'-..""-.? "'--~ 4000 '""-.. '""-.. 2800 '""--. ..... ' .... "'.~"'"-. 2300"-. '-...3500'-... '"'" 3200 ........ 4100 , oo,%.,............. .?oo ............. ,oo ..." "-.... "-.... '"-...4200 " .~.. "--.... '"--.... ," '"- '"x 2400 '"-. 430n '"'-. z~n~'". 3000 '"-. 3300 ., 3000 ', -. '-. .' '-. -. 2000~ r~ ',.,.,, "-....., '..,!.~oo~ ~ ' ....... ..~8o~ ...... ,~o ........... 34.00 ' ".. "-~ 25 O '"..4.000 "-. "-. "-.. ". 3100 ". '-. ".. '"'- 3900 '"-~ 3200 '"-. 2200 ".. ".. '"-: '".. 4600 "'..~ '-.. '"-.. '"' "" ""' '"' '"" 4 '"" '"-. 3500 ,+- ~ "x 3200 '" ""~ 2600 '"'- 4700 ".. 000 "-., 3300 "-.~ "-" 2400 ",,,,3500',,,, 32Q0 %,,, "'..., "-.,?800 '"",..4100'""-.. 3400 '"'"" ~ '". '"~ 3300 '"'. '"'- 2700 "x. 900 '-.... 4~^".... '-.... ~ "x 3600 '. '.. '% '... =~ '.~..zuu '"-~ 3500 "'--. 0 2600 '.... "... 3300'.... '...... '.~.~uuu "'"-. '"'-.. '""-.. 3700 (-/') "...._~>.. '".. '"... '"-, 5100 "-,..~300 ....-.. 3600 ....... I ..,~'°° ,2400 ..,,. -..,~800'"--, ~00 ..... ,.. ~ ....... '""-.. v 2800 ".,., ~.. 3400',.. ""--. ""... ~300 "<~7 .... "-2700 ..... ~00 3000 "'-~ 5906".. '". 3500 "-.... "-x.~500 '""-..4600 '""-.. ".. "'. %'.. '".. "'.. 5600 "-... "-...3900 '.. '-x 5600 ".. '".. 5000 '"-. "'-.x 4700 '"'-.. ".. 4000". "... '-...... 13D-~ ..... '.. ",. 3~oo ',., 3200 ~.. 4100 "~ 410¢'x 3700 "'.. "'-~ 3100 ", ', 5400 " 4200", ',. 3700 '"""" 3600 'x 4200 '",, 4 300 ' 3800 , ,, ,~ 4,m~', ",, · , ",, .3800 oo '% ., oo .% '-., 3200 ... 3800 1200 1400 1600 1800 2000 2200 2400 2600 I 2800 V 3000 3200 3400 3600 --'-'-~-"-----'I I I I I [ ~ I [ [ [ -----I ! ...... '-'] ........ 1" ' I '-I I '-'T--'I ~-- I I I I ] I -"-T"'-~- I --T'-'-'""I f I If f [ [ f ~----T ..... ~ 2200 24(30 2600 2800 3(}00 3200 3400 .% (ii't(1 ,~(~f')4000 4200 4400 4600 4800 ',~000 5200 .5400 5600 5800 6000 6200 6400 East (feet) -> A;{CO Alas ka !n ct' Structure : Tarn Drill Site 2L Well: 315 Field : Tarn Develcpment Field Location : North Slope, Alaska WELL ..... Point .....~O mc er, O.CO O.CC i KOP ~OC.CC O.O0 En¢ Initicl 8u;tC: 2~.CC I 5.CC [~eg,n Turn ~o T~r~et 15CO.OO 15.CC ~6[e O,c~ 77~8.15 5g.07 IEnc cf O~cp/lur~ 7~51.84 55.0C ITcrget 2L-F (I) Rvsc ~ 8300.03 55.00 Eno el Ho~c Esg6.16 55.0C PRO Oir 112.0C 112.~0 122.08 122.08 122.07 122.07 122.07 122.07 FILE DATA T~C Na~n Ecst 0 CC 0.C0 0.C0 7CO.OCO.CO 0.00 11S4.31 -24.3~ 6C.34 1484.09 -53.'6 t32.33 2636.20 -48~.60 855.05 5087.45 -2665.J74352.01 51§5.2B -2747.10¢496.79 5395.00 -25S8.56~738.48 5569.00 -3025.244945.41 55~3.71 --3115.24 5084.24 V. SectCe§/lO0 C.CO 0.00 O.CC O.O0 6~.19 3.00 140.78 0.00[ 1007.353.00 5098.65O. OOI 5554.71 0.00[ 5798.91 0.00I 5962.73 0.00) 320 330 340 35O TRUE NORTH I ~ 0 210 / / % 3OO 3i0 ~$o ~ 1~0 10 2O t ~°°i 40 , .~, c,,c:e¢ =~ ..... FOR: BRASSFIELD Octe ¢:ctte~ : 5-0cl-98 ~1c1 Re~ere~ce 15 315 Versian Ccorcinctes cra :n leal relerence ~ot ~315. 1 ~TEQ / 280 / , ! ; i 26~ ...... ~ ~oo 3O 5nc 500 -k 1300 ',, · ~1100 9i0 '1 / i ,0 210, ....... i. / ..... ¢ .... '% / ! 250 / [ 1500 249 ~230 , :~oo 220 ! , , , 6 200 190 180 Normal Plane Travelling Cylinder- Feet 900 2O 170 '%..21 O0 160 "--.. 130 140 '-.. ~scc . All depths shown ore Measured depths on Reference Wel ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 21 iA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21iA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L J 1 F 3" 5,000 psi WP OCT Fj MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator E~ / / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE [~~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL ~--~ w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. -~_~ Tarn Drill Site 2L,315 Tarn Development Field,~orth Slope, Alaska CLEAILA-NCB LI'~_~NG Page 3 Your ref : 315 Version Last revised : 1-Oct-98 Reference wellpath Object wellpath : 313 Version #4,,313,Tarn Drill Site 2L M.D. T.V.D. Rect Coordinates M.D. T.V.D. ~oriz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 0.0 0.0 7.0N 100.0 100.0 0.0N 0.0E 100.0 100.0 7.0N 200.0 200.0 0.0N 0.0E 200.0 200.0 7.0N 300.0 300.0 0.0N 0.0E 300.0 300.0 7.0N 400.0 400.0 0.0N 0.0E 400.0 400.0 7.0N 29.5E 76.6 30.3 N/A 29.5E 76.6 30.3 )29.8( 29.5E 76.6 30.3 )29.2( 29.5E 76.6 30.3 )28.7( 29.5E 76.6 30.3 )28.2( 500.0 500.0 0.0N 0.0E 500.0 500.0 7.0N 600.0 600.0 0.0N 0.0~ 600.0 600.0 7.0N 700.0 700.0 0.0N 0.0E 699.9 699.9 800.0 800.0 1.0S 2.4E 798.9 798.9 5.8N 900.4 900.0 3.9S 9.7E 898.0 897.7 2.2N 29.5E 76.6 30.3 )27.7( 29.5E 76.6 30.3 )27.1( 29.5E 76.6 30.3 )26.6( 31.7E 76.9 30.1' )25.9( 38.5~ 77.9 29.5* )24.8( 1001.2 1000.0 8.9S 22.0E 997.7 996.5 3.8S 1103.0 llO0.O 15.9S 39.3E 1098.3 3095.4 12.2S 1205.9 1200.0 24.9S 61.8E 1200.0 1194.3 23.3S 1309.4 1300.0 35.0S 86.6~ 1302.1 1292.1 36.8S 3412.9 1400.0 45.0S 111.4E 1403.7 1387.8 52.6S 50.0E 79.6 28,6* )23.3( 66.1E 82.3 27.4* )21.3( 87.0E 86.2 26,0* )19.1( 112.7E 93.9 27.4 )19.9( 142.9E 103.6 34.6 )26.7( 1516.5 1500.0 55.1S 136.3E 1504.1 1480.6 70.6S 1621.1 1600.0 67.3S 364.4E 1604.6 1571.2 90.8S 1727.6 1700.0 83.0S 197.6E 1706.2 1660.3 113.5S 3836.5 5800.0 102.3S 236.2E 1809.4 1748.1 138.8S 5948.4 1900.0 125.5S 280.6E 1914.2 1834.0 166.6S 177.1E 110.8 47.7 )39.3( 215.6E 114.7 63.2 )54.1( 258.7E 116.6 79.0 )69.0( 306.7E 117.4 94.9 )84.0( 359.7E 117.5 110.9 )99.0( 2063.9 2000.0 153.0S 331.3E 2022.3 1919.2 197.6S 2183.9 2~00.0 585.3S 389.2E 2133.3 2002.5 231.8S 2309.4 2200.0 223.0S 455.0~ 2248.0 2084.0 269.3S 2442.0 2300.0 266.9S 530.1E 2368.7 2164.4 311.2S 2583.8 2400.0 318.4S 616.5E 2497.5 2243.7 358.5S 418.7E 117.1 127.1 )124.0( 483.6E 116.2 143.4 )129.2( 555.0E 114.9 160.0 )144.3( 634.7E 113.0 176.9 )159.6( 724.5~ 110.4 194.2 )175.0( 2738.0 2500.0 379.3S 716.8E 2635.3 2320.7 411.6S 2930.1 2600.0 452.8S 835.8E 2789.5 2396.9 474.05 3302.7 2700.0 540.2S 975.3~ 2958.4 2467.7 545.3S 3297.2 2800.0 628.8S 1116.7E 3149.5 2539.4 627.7S 3491.8 2900.0 717.4S 1258.2~ 3341.3 2611.5 710.4S 825.6E 106.5 212.2 )190.7( 944.2E 101.0 231.2 )206.5( 1079.8E 92.8 254.8 )226.5( 1236.6~ 89.5 286.8 )253.2( 1393.9E 87.1 318.9 )280.0( 3686.4 3000.0 806.1S 1399.6E 3533.1 2683.5 793.2S 1551.3E 85.1 351.2 )306.V( 3881.0 3~00.0 894.7S 1541.0E 3724.9 2755.6 875.9S 1708,6~ 83.6 383.5 )333.4( 4075.5 3200.0 983.3S 1682.5~ 3916.7 2827.6 958.6S 1866,0E 82.3 415.9 )360.1( 4270.1 3300.0 3072.0S 1823.9E 4108.5 2899.6 1041.4S 2023,3E 81.3 448.3 )386.9( 4464.7 3400,0 1360.6S 1965.3E 4300.3 2971.7 1124.1S 2180.6~ 80.4 480.8 )413.6( 4659.3 3500.0 1249.3S 2106.8E 4492.1 3043.7 1206.8S 2338.0E 79.6 513.3 )440.3( 4853.8 3600.0 1337.9S 2248.2E 4683.9 3115.7 1289.6S 2495.3~ 78.9 545.8 )467.0( 5048.4 3700.0 1426.5S 2389.6E 4~75.7 3187.8 1372.3S 2652.7~ 78.3 578.4 )493.7( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~315 and TVD from RKB (Doyon 141) (145.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 121.45 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. ...- Post Office Box 100360 Anchorage, Alaska 99510-0360 October 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-315 Surface Location: 184' FNL 7'19' FEI. Sec 22 T10N R7£, tim Target Location: 2197' FSL, 1260' FEL Sec. 23, T10N, R?E, UM Bottom Hole Location: 1981' FSL, 915' FEL Sec. 23, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-315, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany DUPLICATE David W. Johnstor,.~.t Application for Permit to Drill Page 2 KRU 2L-315 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-315 Well File ARCO Alaska, Inc. - Post Office Box 100360 Anchorage, Alaska 99510-0360 October 15, 1998 REC~'~VED David W. Johnston, Chairman 0~T ~ 'j~t8 Alaska Oil and Gas Conservation CommissicA~bOii&SasC0r~s, C0111~i0ri 3001 Porcupine Drive /~orage Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-315 Surface Location: 184' FNL 719' FEL Sec 22 T10N R7E, UM Target Location: 2197' FSL, 1260' FEL Sec. 23, T10N, R7E, UM Bottom Hole Location: 1981' FSL, 915' FEL Sec. 23, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-315, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnsto~- Application for Permit to Drill Page 2 KRU 2L-315 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-315 Well File "~ ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L-315 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). , Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-315 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-6O 10-25 15-40 5-7 9.5-10 +10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be .-2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks' ARCO Alaska, Inc. The nearest well to 2L-315 is 2L-313. The wells are 27' from each other at a depth of 1246'. Drillinq Area Risks' The primary risk in the 2L-315 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-315 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-315 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ..... ARCO Alaska, Inc. ~-- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,638 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). w~ FOR: BRASSFIELD Plot Reference Fs ~l~ ','e's;o~ ~J Alaska, !nc':1 Structure : Torn Drill Site 2L Well: 315 Field : Tarn Development Field Location : North Slope, Alaska East (feet) -> 4CO 0 400 800 1200 1600 2000 2400 2800 5200 3600 SURFACE LOCATION:I 184' FNL, 719' FEL SEC 22, T10N, R7E 400 400 -~ 800 ~ 1200 1600 2000 2400 2800 3200 3600 4000 End Initial Build Section Bose Permafrost TSuak Sonds rn i:o Target West Sak Sands 75/8 Cosing Pt 4000 4400 48C0 5200 ~ I ~ I ' ' i 121.45 AZIMUTH 5555' (TO TARGET) · -,Plone of Proposai-*,* RKB ELEVATION 145' C50 ~KOP TVD=?00 TMD=?00 DEP=O i5006'.00 9.00 12.00 END INITIAL BUILD TV0=1194- TMD=1200 DEP=64 ~ B/ PERMAFROST TVD=1195 TVD=1201 OEP=64 T / W SAK SNDS TVD=1239 TMD=124-6 DEP=76 BEGIN TURN / CONTINUE BUILD TVD=1484- TMD=1500 DEP=141 C¢0 TARGET LOCATION: 2197' FSL,!260 FEL SEC 25, T10N, R7E TARGET -FVD=5598 TMD=8300 DEP=5555 SOUTH 2899 EAST ¢758 Begin Angle 0rop 400 ? ? ~00 h 800 ! O h ]200 C i :~- ~ ] 600 '-~ _ · ---4- - 2000 I V - 2400 4400 4800 5200 58°0 AN G LE 8000 I L I J I t I t I I J i J I J J I J J J I I II I I ' i J I I I i 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 8000 Vertical Section (feet) -> 21 End Anqle Drop T4 20.~07'9~ T3 - ~op L 2800 3.87 TARGET - Mid Bermuda 26.84 T2 - Base Bermuda %29.82 B / W SAK SNDS TVD=1897 TM0=1945 DEP=303 ~_~ . ~/./3 C80 W0=2470 TMD=2690 DEP=772 j ~ 23, TI~N~7E j L3600 ~7~WD=2636~ TMD=29790EP=i007 MAXIMUM ANGLE 5~.07 DEG ' _ ........... ~ ~~.~ : Azimuth 121.45 with reference 0.00 N, 0.00 E from slot #515 IARCO Alaska, Ir~.e.] Structure : Torn Drill Site 2L Well : ,515 Field : Torn Development Field Location : North Slope. Alaska 40 Q) 60 O 80 I lOO 120 1'10 -Created by Michaelson leer: IIItASSI:II,]I,D 1 Dote plotted : 8-0ct-98 Plot Reterencc is 515 Verulon ~/5. Coordlnotes ore in leer reference slot #515. True Vertical Depths ere reference RKB (Doyen 14,1).I Fost (*eet) -> 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 300 320 340 I I I ~°1~o ....................... ;/,'"'~ ,~oo o~~,~"~ ~ , ~oo~°°' ~oo' '~' '~oo e~a ~ooo'~'"~"~ ~ ...... o~ ~ ,oo ~' ', ~ ........ : : .... ~500~ .......~-~: :: %:~:: :L:~;~LtL~LT.' ................l~® .................... t-z ........ 800 ..... 1 ~ .............. ~t:tttttt~t .......1500 ....... 20- t ,,ou O' 80(~ ....... ?'~ 800 ..... I ~00 ' ' ............ ~ 1,300 i1590~ e' ~' 900 900 10;6 ........... 900 .......... . 1000 1200 %'"~'~.,::::. 1400 o ~ ~=~' 50(~ .... '"'-. 1000 .......... ......... ~500~."==~uuu 900'"'-. '"- 1100 ......... ' ........ 1100 ........... ~0~ "- "600 ~uuu '-. . .... "- .... . ......... - ""..,,~oo -...... '..,... ~soo ...... ~::. .... - ........ ~ "..... '..... ~o?...?ooo ,6oo .... %:.. ~soo .... -- -. '. '- '-.'- v '"., 1200 "%] 300 '"".. "'".. ' 1 " '",, '"",, 1300"'".. 1100 '==' -~=~.1~600 '%, ,,% '" ""x 14.00 '.,, '"-. 1800 ' "',, 1300 '.,,.,,,,, '",, ""- , '"-~ ~400 '"',.. 700 '-%, -.. ",, '"',. '"",~ 1199.99 1900 "',, ",% 1500 ',. 14.00 ,,,,,,,, ",,, ',, '"'-~ 1500 "'",. ~ 60 '~ 1500 '"' '", '"'., 1 600 '"'" """-~ 1`300 ", "~ 1500 % % "% 180 '"' ,x 1 ~00'"'"" 200 .... 1 ...... ~ 1 .... ~'[ ...... 1 ........... i ..... 1 i ...... t ......... i i ..... F--~ ..... ~ ....... T--~ [ ...... [ ...... i ........ 1 ........ 1 ...... i ........... i ........... i ....... 1 ...... 1 ...... ~-~~-" i ...... i-~ .... ~ ...... 1 ...... ] ..... 1 ........ i ....... ~ ...... i ...... [ ..... 1 O0 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 320 340 Eest (feet) -> 40 20 20 40 U3 0 C" 6O 80 ~ I 100 V 120 200 180 160 140 Created by Michoelson For: I}I{ASSFIELD Dote plotted : O-Oct-§§ Ptot Reference ~s .315 Version J Coord~notcs ore in fc=J rc~cr~nce slot J T~ue Ver([col Oep(hs or~ ~clerenc~ RKB (Doyon 141 280 320 360 ~00 East {feet) -> 240 280 520 560 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 120 _~ I I I I I I I l ..... J I I I I I I I I I I L .1. I L I I I .LI I I I I I__l I I I__1 .L ./_____l L 120 '-... 1700 ....... '"--.. 2000 ......... 1900 '"-., "-.. 1500 '" ' ...... ::::::"" ....... -- .... 16oo ..................... 2-!.° '"* 800 '"'"' 0 "-%%..%%%%..... " _ ...... .. '... ....... . _..... 16o- 2oo~'~"-',-! ...... '-...... -,.::-.. ...- .... .,.- 17 "... 1400 220~'[::.''-.. 2000 .... ......1600 ..... ..... ' ...... --..... "- ' ............... 1~oo ;:; '- 22C~ ...... 240 -..."-, '-. . -,..,:.,., "'-,.1800'".. "- "- .... .. . .. "-.. 2100 "-.. ".. 4.40 480 520 56(] 600 "'-,, 1900 2100 · · 2200 · '.. ""-.. ' ""-. '""-. 2200 '""-.. '"'",. "'"'.. '"'"',.'""'-., '""--.1700 ', 2000 '""-, '""-. '""', '"'".. '"'"-- %"... "".,.200~)'"-... "-.,..2.500 .... '"-. . ' ......... '"', '"'-. '"'-,. 1600 '"'., '"-... "-..... "'%, 2100 '"',.'"'.. '"'-., '""-.. '"'-,, ""..... '"'---.... ' ...... "% 2200 ""... '"'... ""-... '""-... '". '". 2200 '"- '-.. 2700 "-.. '"'"'"' '"'"'"" '"'"'"'"1 100 '"'"'"'" '"'"~ ,% ,% ,.% --,% ,% ---'--IF .... I I I I I I I I I I------] T-- "--'] ......... T .......... ~' .... --I I I I I I I I I ----l--T- -'l ........... T ...... l ..... -r-----]1--1 i---r-"~-T---f I -T ...... ] ....... T ........... 240 280 320 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1 I20 East (feel) -> 120 160 2O0 240 280 0 320 (- -.-t-- 360 "~ ~00 I 520 560 600 480 440 Created by Michoelson For: BRASSFIELD J Date platted : 8-Oct-g8 J Plot Reference is 515 Version ~/5. ICoordinotcs arc in feet reference slot ~fl15. ITrue V~rficol Depths ere re~crcnce RKB (Doyen 14~).~ East (feet) -> 900 1000 1 t00 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 400 ~- ,~ ~ ~ ~ ~ ~ ~ ~ ~ ~ --~ ~ ~ ' ~ ' ~ ~ ~ ~ ~ ~ ~ ~ ~ J ' ~ ~----~ .... -~-- ' ~ ~ ' ~ ~ ~ ~ ~ L---~--~T~-----l- 400 -~'" 40 ' '" :: .... '" ........ ........ ... '--::'-'--.---.-...??; .... ................ ;, / '"-.. 27~0'... ' ...... ' ....... 2600 ........ ~'. ........... ' ......3-tO~. -I --.... -. .... ....... .... .~,~oo .......... - .......... ~oo 6°0lh__~,~.~ ....... . .... 2~00... -.......1900 ' ........ 2;'~ ....... ' .............. I;".1~I.. 600 ~.... '..,?8°0 -- ..... ' ...... ' ..... ' ........ ' ......... -~ '...T~,... '..... -...... -....... --..... '--..... ........ ' ........ 2200 I- - 700-~ ""-.. '"".. '""-. 2900'""'--2.600 ........ 2000 ......... 2800 ............. ' .............. .~t-700 -t -..,...--..... '-..,... ' ........ - ........ --.....~.~oo ............. [ ',.,. "-,,.1800 ",,. "-... "-.., "-.... 2900 ........... '~] 8oo -~ "-- "-, "'-. 3000 '"'- 2700 '"'- ""- "--bi 8oo 2400 '-. "-. ".. "-. "-. 2100 '".. , 9o0 1~.. "...... '--.... ".,.~100 ........ . ......... ' ......... 27o0 ~200/ ! 900 / '"'.., -.... '--... ..... ' .... ?800 .... .. ' ..... :'/ o .-.i ',. zSO0 '"' '"' 1900 '"' '"'" '"- 2200 '"-. ,' ] C ; '... '-,.'... '... 5200 '-... "... , '-... ,, ~ -'+- 1000 -, '. "-. ". "-. "-. "-. "-. ,' / 1000 _ ....... 2~oo ..,................ '"'""-. ~oo '---.....?00 .......... . ............. ,," / "... "'... "-.. "".. '"-. '"'.. 2300 '"--. 2800 / 11oo 11oo _ "... "..,,26 '"'-. "".. 2000 '"'.. 34-00 '"'-...3000 '"--... '"'"" '"' I 1200- '"" 2700 '"" 260~"-. ""-.. '"'-.. ' ....... ' ....... 2400 ,"' ......... %; 1200 V .... 0',,,, '",. 2700 "-. ",, "-. '-. ~'~-. ".. 2800 ". '... 'x.z~uu -... '-.... ,,' '..... '", '"'. 2-/0(~'""- '"'-. ""-. "-...3200 .," ".... 1400 '"'.... "'..,. ""'..... '"'-..... '"'..%.3.700 .... ?~'.'.... '-.....% 1400 1500 ~ '"'" '"'" '"'"' """ ""'. ,'" '""- 3300 1500 · "'.. 2900 ",,. '".. "-.. ".,.. 5800 ,,' ".;. ", "... '... 2800 ""-. '"'-. 2200 '"'- ,'" '""-. '"",, ~a~o "',,, '"',, 2 ~ oii",,. '":-,. '""-.,'" '~----~ 1600 ', ", ".. "-. ,'"".. 3900 1600 "% ,% -% --% ,,% ¢ '% 1700 I I V- ....[ I I---I .... --I ...... '~ ........ T ....... r------I ..... T"---'[ i i--T--'-'] .......~- ..... f r-----1--'--[ .......... 1 ....... i ........ l-"---'-I ..... T-"----~ i i--T'--'I ....... 1 '1 .......T ..... r ....I ......... i ..... r ....¥ ...... 1 T--- 1700 900 1000 1 1 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 24.00 2500 2600 2700 2800 2900 5000 East (feel') 'Created by Michaelson For: III{ASSI"[ELI) I Dote plotted: B-Oct-es [ Plot Rut ...... i'.l 315 Version lime Vertical aepth 1200 1400 1600 1800 200O '"'"" 2200 ~ 2400 0 2600 2800 3000 3200 3400 3600 38O0 Slruciure : Torn Drill Site 2L Well : Field : Torn Development Field I. ocolian : Nodh Slope, Alaska East (feet) -> 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 I I I t I I I I I I I I I I I I I I I I J____L__ I I I I I I I ~ I I I I I I L I__2.____L~ I ! I 1200 ~ -...~o0 ~¢o..~,:... ' .... ..~oo -...~0", '- '--, '--. ~"'-, "'-~ 3800,"' "-..,3300"-... '--.. ' ........ . ". 2200 '-. ,' "-. "-. .... ~ '"-. ' ..... x, ',. -.,, -.. -~ ~uu --.. - ' ....... .3900 .......... 3300 '"- .... 1600 '"".."'"./" ""-~ 4000 '""-. ""'-. 2~00 '""--. ' ....... ~000..... ;..~'-.....~oo--...,. 290 ,' ,. ,. x -.. .. -.. ....... ' " " " " 00" 2900 '. ........ 4200 18o0 ,' '- ". '-, "-x 36 ~-. '-- '--..~ ,,' '-.. '-.. '-. 4200 .. '--. "--, ,," '"'.. "',,.2~o"",.. ,3o~ ....... , ~;;'--,. 3ooo ...... . ~,' 3000 ',,,, --.., '-,..~, '-.:,.. ' ....... "'-.. " "-,. ',.. ~.~oo '- ' ....... ', "-' ..... ,3~.oo "',, '"'x 2500 "-.. 4.500 '"'- '"'- ",,,,,,,, 3100",,., '"'" ~600 '""-., 3900'""-~ 3200 '"'"'-.. '" '",. ", '-. "-.. 3500 ",%3200 "' ""- 4000 "-.. 3300 "' 'x 2600 "-...4700 ,.... "-.... ,, '-... ' -.... '",, 350~",, 3200'"-, '-, "", 4.800 "- 4100 ""'- - '"'"'- ,., ,,. ,,.. '-,,. '-... -.... -....34.00 '"--. 3600 "... ~&,~oo '".. '"'-. ~oo'''--"~°° ..... .-..~o; ....... ' ....... "x ', '" "" '"' ~000 ' -' '"x 3500 "--. ', ", 3300"- "- "x ~ ", '- "- ', ', ', ". '- "-. "'- "-. 3700 '" '" "" '"'. '"'-. 5100 · "-~ 4300 '""- 3600 '""- '",,3700",~ 3400 '"'. '"', 2800 '"- '""- '"'-, "'"- ", ", '", '";. '"x.5200 ""-. 4400 '"'- ""-- 380~ "..... ~;;... ~,~',.... '-...... "-....~oo ..... .... - ...... ~:oo .......... '-..... "'.,.~ '-..... "......~o~ '-.-..,?~o ..... .~o~ ....... ..~o~ "~ '",~ 390~",, '""x 3500 "",.. '"x.~500 '""-...4600 '""-.. ", ",, ",, '",. '",. 5600 "-,.. "-...3900 3000 '", "x 3600 "-, '"-. 3000 '"-.. _ '",x 4700 "-.... ~ ",,,,4000',,,, "',, '"-,, ~ ..... . 4oo~.~ ~ ',,,, ",,,, ",.,.3600 ",,.,. ""-~.4800 ~ 3200 ,, 4100 ",~ 410~'~ 3700 '"', '"',x 3100 "'". ",,, '-,,, ',,,,, ",,., ,.,.,, , 'N, 4200 '"',. 420~", '",., 3700 "',,,, 3400 ", ", "x 3800 '"', "',,, 3200 '"~ 4300 "',, "', ",, '--. ', "x 430~',, ",, ",.. ", ',, ", '-,, 3800 '-,. 3600 ..... I ........ 1 ........ I .... I I I I I I [ .... ~ ~ ...... l ....... I .......... I ......... 1 .... ~ ....... ~'~ ........ T ..... 1~ I IC--~I .... ~-~ ....... ~ ...... ~ ..... 1 ....... 1 ......... l ...... T'~ ...... F ....... ~-T---I'--~I~-~ .......~ 3~00 2200 2400 2600 2800 3000 3200 5400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 East (feet) -> 2200 (./) 0 ,-+. 24OO 2600 _.~ I 2800 V [ARco Alaska Structure : Tarn Drill Site 2L Inc. Well : 315 Field : Tarn Develcpment Field Location : North Slope, Alaska WELL PROFILE DATA I ..... p~inl ..... ~O I.c Oir 'I%'0 Ner:n EcsI V. Sect. Ceg/1OO ;~e on O.CO O.CO 0.00 OCO O.O0 O.CO O.CO O.GO -~nc 'nit;cl 9ui:~ ~200.C0 15.C0 112.00: 194.]1-24.~8 60.54 6~.19 iEC~ 2978.50 59.07 122.082635.20 -~85.50 885.35 IG07.55 ' O. O0 End ~f Orcp/Turn 7951.~ 55.C0 122.0751~8.2B -2747.104495.795269.50 Tcr~et 2L-F (I] R~sO I 8300.0~ 55.00 122.075~98.00 -2898.564738.z8555z.71 0.00 Eno ot ~olo 8598.18 55.00 122.07555g.00 -~028.244945.415798.91 0.O0 T.D. ~ ~o ~ Hole 8798.!6 55.00 122.07568~.71 -~115.245084.245982.?~ 0.00~ TRUE NORTH 350 0 10 340 20 330 2i0 310 320 ~ '~1 lOO 26~ ..... ,boo 500 i23© 'i ~7oo 220 i , ~210 2OO 190 100 29~5 ---i I 0 180 2O 170 ",,.. 21 O0 160 '--. IXQ 14,0 % ~scc Normal Plane Travelling Cylinder - Feet All depths shown ore Measured depths on Reference Well ..... ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 21 lA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L L I 3" 5,000 psi WP OCT MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / BSA 13-5/8" 5,000 psi WP -"~L x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom L I 3" 5,000 psi WP Shaffer GATE VALVE ~ F~T~r~raulic actuator ,v 13-5/8" 5,000 psi WP DRILLING SPOOL bl'~'~ w/two 3" 5M psi WP outlets ] SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. Tarn Drill Site 2L,315 Tarn Development Field,North Slope, Alaska CLEARANCE Li~ING Page 3 Your ref : 315 Version #3 Last revised : 1-Oct-98 Reference wellpath Object wellpath : 313 Version #4,,313,Taz-n Drill Site 2L M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 0.0N 0.0E 0.0 0.0 7.0N 0.0N 0.0E 100.0 100.0 7.0N 0.0N 0.0E 200.0 200.0 7.0N 0.0N 0.0E 300.0 300.0 7.0N 0.0N 0.0E 400.0 400.0 7.0N 29.5E 76.6 30.3 N/A 29.5E 76.6 30.3 )29.8( 29.5E 76.6 30.3 )29.2( 29.5E 76.6 30.3 )28.7( 29.5E 76.6 30.3 )28.2( 500.0 500.0 600.0 600.0 700.0 700.0 800.0 800.0 900.4 900.0 0.0N 0.0E 500.0 500.0 7.0N 0.0N 0.0E 600.0 600.0 7.0N 0.0N 0.0E 699.9 699.9 7.0N 1.0S 2.4E 798.9 798.9 5.8N 3.9S 9.7E 898.0 897.7 2.2N 29.5E 76.6 30.3 )27.7( 29.5E 76.6 30.3 )27.1( 29.5E 76.6 30.3 )26.6( 31.7E 76.9 30.1' )25.9( 38.5E 77.9 29.5* )24.8( 1001.2 1000.0 1103.0 1100.0 1205.9 1200.0 1309.4 1300.0 1412.9 1400.0 8.9S 22.0E 997.7 996.5 15.9S 39.3E 1098.3 1095.4 24.9S 61.8E 1200.0 1194.3 35.0S 86.6E 1302.1 1292.1 45.0S 111.4E 1403.7 1387.8 3.8S 50.0E 79.6 28.6* )23.3( 12.2S 66.1E 82.3 27.4* )21.3( 23.3S 87.0E 86.2 26.0* )19.1( 36.8S 112.7E 93.9 27.4 )19.9( 52.6S 142.9E 103.6 34.6 )26.7( 1516.5 1500.0 55.1S 136.3E 1504.1 1480.6 70.6S 177.1E 110.8 47.7 )39.3( 1621.1 1600.0 67.3S 164.4E 1604.6 1571.2 90.8S 215.6E 114.7 63.2 )54.1( 1727.6 1700.0 83.0S 197.6E 1706.2 1660.3 113.5S 258.7E 116.6 79.0 )69.0( 1836.5 1800.0 102.3S 236.2E 1809.4 1748.1 138.8S 306.7E 117.4 94.9 )84.0( 1948.4 1900.0 125.5S 280.6E 1914.2 1834.0 166.6S 359.7E 117.5 110.9 )99.0( 2063.9 2000.0 153.0S 331.3E 2022.3 1919.2 197.6S 418.7E 117.1 127.1 )114.0( 2183.9 2100.0 185.3S 389.2E 2133.3 2002.5 231.8S 483.6E 116.2 143.4 )129.2( 2309.4 2200.0 223.0S 455.0E 2248.0 2084.0 269.3S 555.0E 114.9 160.0 )144.3( 2442.0 2300.0 266.9S 530.1E 2368.7 2164.4 311.2S 634.7E 113.0 176.9 )159.6( 2583.8 2400.0 318.4S 616.5E 2497.5 2243.7 358.5S 724.5E 110.4 194.2 )175.0( 2738.0 2500.0 379.3S 716.8E 2635.3 2320.7 411.6S 825.6E 106.5 212.2 )190.7( 2910.1 2600.0 452.8S 835.8E 2789.5 2396.9 474.0S 944.2E 101.0 231.2 )206.5( 3102.7 2700.0 540.2S 975.3E 2958.4 2467.7 545.3S 1079.8E 92.8 254.8 )226.5( 3297.2 2800.0 628.8S 1116.7E 3149.5 2539.4 627.7S 1236.6E 89.5 286.8 )253.2( 3491.8 2900.0 717.4S 1258.2E 3341.3 2611.5 710.4S 1393.9E 87.1 318.9 )280.0( 3686.4 3000.0 806.1S 1399.6E 3533.1 2683.5 793.2S 1551.3E 85.1 351.2 )306.7( 3881.0 3100.0 894.7S 1541.0E 3724.9 2755.6 875.9S 1708.6E 83.6 383.5 )333.4( 4075.5 3200.0 983.3S 1682.5E 3916.7 2827.6 958.6S 1866.0E 82.3 415.9 )360.1{ 4270.1 3300.0 1072.0S 1823.9E 4108.5 2899.6 1041.4S 2023.3E 81.3 448.3 )386.9( 4464.7 3400.0 1160.6S 1965.3E 4300.3 2971.7 1124.1S 2180.6E 80.4 480.8 )413.6( 4659.3 3500.0 1249.3S 2106.8E 4492.1 3043.7 1206.8S 2338.0E 79.6 513.3 )440.3( 4853.8 3600.0 1337.9S 2248.2E 4683.9 3115.7 1289.6S 2495.3E 78.9 545.8 )467.0( 5048.4 3700.0 1426.5S 2389.6E 4875.7 3187.8 1372.3S 2652.7E 78.3 578.4 )493.7( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #315 and TVD from RKB (Doyon 141) (145.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 121.45 degrees. Calculation uses the minlmLun curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. AAI PAYABLES · P.O. BoX >102776 · ' :. Anchorage, AK 99510'2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 2O5O8559O 73-426 839 SEPTEMBER 28, 1998 099?579 VOiD AFTER 90 DAYS ExAcTLY , The First National Bank of Chidago40710 Chicago, Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 205085590 ' 1:00 DOLZARS AND O0 CENTS $*********** 100.00 . WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION INIT CLASS ENGINEERING WELL NAME GEOL ////.~" K~ ON/OFF SHORE Y ~ Y N NY N Y N Y N _~,~'~ .Z- ~'J" ~//,~ ' I~°GRAk~: exp [] dev Fi redrll [] serv~wellbore seg.l ann. disposal para req~' AREA ~ ~ UNIT" ~ ~_ GEOLOGY 20. Adequate tankage or reserve pit .................. 21. If a re-drill, has a ~0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (.~ N 23. If diverter required, does it meet regulations ..... ...... ~ N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ............... ,. ~ N 26. BOPE press rating appropriate; test to ~OoQ:) . psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ..... . . . ~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. Y~) 30. Permit can be issued w/o hYdrogen sulfide measure~i * . i 31. Data presented on Potential overpressUre zones ....... Y/N 32, Seismic analysis of shallow gas zones ..... ' ........ /Y~ N ./r 33. Seabed condition survey (if off-shore) ........... i . / Y N ' 34. Con. tact.nam, elphonp.for weekly Progress reports ..... '..// Y N . lexp~orazory onlyj . ' . ANNULAR DISPOSAL 35. APpR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N 1o surface; (C) wi'Il n'~"oti~ai~.~chanical integrity of the well used for disposal; (D) will not damage Producing formation or impair recovery from a pool; and (E) wil! not circumv.ent _.20. A~_C_ 25.~2.52 or 20 AAC 25:412. GEOI,,~GY: M:cheklisl rev 05129198 r;llf C ~rtlsof fi(:¢~wor di,qntdinr in~, Y N Y N Y N ENGINEERING: UIC/Annular COMMISSION: DWJ BEW(~ ta[z.9 WM V~ t~l~q:~ RNc , : ~ J DH ~-.-..--~ co ~ Comments/InStructions: 2./-- 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CMl- vol adequate to tie-in long string to surf csg ........ 18. CMl' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well Iocaled in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the hiStory file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Jun 02 11:33:06 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/06/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER': LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: PJkNGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-90035 G. GRIFFIN D. BURLEY RECEIVED JUN 05 1999 AJaska Oil & Gas Cons. Commission ~.-r, - 3 ~_ 5 A~ ~orage 50103202'7600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02 - JI/N- 99 MWD RUN 3 AK-MM-90035 G. GRIFFIN D. BURLEY 22 I0N 007 184 719 146.10 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 144.60 117.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2400.0 6.750 8236.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED ON LOG. 3. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA P~AY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 12/30/98. MWD DATA IS PDC. 5. MWD RUNS 1-3 REPRESENT WELL 2L-315 WITH API#: 50-103-20276-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8236'MD, 5627'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY' COMBINED. SEXP = SMOOTHED PPLASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR PEF DRHO RHOB NCNT FCNT NPHI FET RPD RPM RPS RPX ROP $ .5000 ST2LRT DEPTH 2386 0 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2412 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 8181 0 8159 5 8159 5 8159 5 8143 5 8144 0 8144 0 8188 0 8188 0 8188 0 8188 0 8188 0 8235 5 EQUIVALENT UNSHIFTED DEPTH .... BIT RUN NO MERGE TOP MERGE BASE 2 2412.0 5768.0 3 5768.0 8236.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD RHOB MWD DRHO MWD PEF MWD CNTS 4 1 68 G/CM 4 1 68 G/CM 4 1 68 BARN 4 1 68 40 44 48 52 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Min 2386 0.2 28 77 0 91 0 99 1 07 1 16 0 O7 8 69 75 93 13606.9 0.9 -1.46 0.08 Max Mean Nsam 8235.5 5310.75 11700 1599.32 284.04 11647 252.96 123.46 11591 1337.5 4.75751 11580 1332.65 4.89391 11580 2000 6.62889 11580 1898.79 5.29169 11580 11.1 0.595138 11580 74.52 38.6057 11492 1123.44 233.727 11492 38144.9 20698.2 11491 4.11 2.3449 11523 1.8 0.119386 11523 12.09 2.32111 11523 First Reading 2386 2412.5 2386 2398.5 2398.5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398.5 Last Reading 8235.5 8235.5 8181 8188 8188 8188 8188 8188 8144 8144 8143.5 8159.5 8159.5 8159.5 First Reading For Entire File .......... 2386 Last Reading For Entire File ........... 8235.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/02 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 ....... 99/06/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 PJIW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR PEF DRHO RHOB NCNT FCNT NPHI FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2386 0 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2398 5 2412 5 10.87 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 5712.0 5690.5 5690.5 5690.5 5675.5 5675.5 5675.5 5719 0 5719 0 5719 0 5719 0 5719 0 5766 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEtLATURE: MUD FILTRATE AT MT: 10-DEC-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD MEMORY 5768.0 2412.0 5768.0 -36.7 57.2 TOOL NUMBER Pl177NL4 Pl177NL4 Pl177NL4 Pl177NL4 6.750 6.8 LSND 9.10 47.0 9.0 450 6.8 4.500 4.500 5.500 32.8 MUD CAKE AT MT: NEUTRON TOOL M3~TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.000 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 NPHI MWD 2 PU-S 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CM 4 1 68 DRHO MWD 2 G/CM 4 1 68 PEF MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB Min 2386 0.2 28.77 0 91 0 99 1 12 1 24 0 07 8 69 75 93 13606.9 0.9 Max Mean Nsam 5766.5 4076.25 6762 1599.32 299.683 6709 224.43 117.954 6653 1337.5 4.62535 6642 1332.65 4.80973 6642 2000 7.89293 6642 1898.79 5.45113 6642 4.82 0.501819 6642 74.52 41.5425 6555 1123.44 202.01 6555 38144.9 19667.2 6555 2.98 2.28586 6585 First Reading 2386 2412.5 2386 2398.5 2398.5 2398.5 2398.5 2398.5 2398.5 2398.5 2398.5 2398.5 Last Reading 5766.5 5766.5 5712 5719 5719 5719 5719 5719 5675.5 5675.5 5675.5 5690.5 DRHO -1.46 0.69 0.13564 6585 PEF 0.08 12.09 2.34785 6585 2398.5 2398.5 5690.5 5690.5 First Reading For Entire File .......... 2386 Last Reading For Entire File ........... 5766.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/02 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 ....... 99/06/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: 3 .5O0O START DEPTH 5676 0 5676 0 5676 0 5691 0 5691 0 5691 0 5712 5 5719 5 5719 5 5719 5 5719 5 5719 5 5767 0 STOP DEPTH 8143.5 8144 0 8144 0 8159 5 8159 5 8159 5 8181 0 8188 0 8188 0 8188 0 8188 0 8188 0 8235 5 12 -DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: 10.87 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL FLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD MEMORY 8236.0 5768.0 8236.0 52.9 58.9 TOOL NUMBER Pl177NL4 Pl177NL4 Pl177NL4 Pl177NL4 6.750 6.8 LSND 9.80 45.0 9.0 450 5.4 4.500 2.600 4.900 2.900 44.5 .6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 3 FT/H 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 PU-S 4 1 68 FCNT MWD 3 CNTS 4 1 68 NCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CM 4 1 68 DRHO MWD 3 G/CM 4 1 68 PEF MWD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 5676 8235.5 6955.75 5120 ROP 1.12 1400.34 262.786 4938 GR 59.75 252.96 130.878 4938 RPX 1.02 27.47 4.93528 4938 RPS 1.06 24.76 5.00715 4938 RPM 1.07 22.53 4.92865 4938 RPD 1.16 18.9 5.07722 4938 FET 0.16 11.1 0.72066 4938 NPHI 13 66.48 34.7064 4937 FCNT 131.4 918.48 275.839 4937 NCNT 16837.4 34713.2 22067.3 4936 RHOB 1.96 4.11 2.42364 4938 DRHO -0.12 1.8 0.0977116 4938 PEF 0.39 7.32 2.28544 4938 First Reading 5676 5767 5712.5 5719.5 5719.5 5719.5 5719.5 5719.5 5676 5676 5676 5691 5691 5691 Last Reading 8235.5 8235.5 8181 8188 8188 8188 8188 8188 8144 8144 8143.5 8159.5 8159.5 8159.5 First Reading For Entire File .......... 5676 Last Reading For Entire File ........... 8235.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/06/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
