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Home My WebLink About200-076Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~- _~ ~7~' Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. m""'"~Grayscale items: D Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGE~:~ NOTES: ORGANIZED BY~ BEVERLY BR~"~I~INCE_E_E_E_E_E_E_E_E~HERYL MARIA LOWELL Project Proofing PROOFED BY: BEVERLY BRE~HERYL MARIA D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: Scanned (done) PAGES: SCANNED BY'. (at the time of scanning) BEVERLY BREN VINCENT~~MARIA LOWELL DATE: Is/ RESCANNEDBY: BEVERLY BREN ~)SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES: ,~// Quality Checked (done) STATE OF ALASKA r ALASKA CND GAS CONSERVATION COMMISSI® REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well 1 Plug Fbrforations r Stimulate r' Other jj ESP to Jet Pump Alter Casing Pull Tubing f Perforate New Rool r Waiver — Time Extension E Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well j- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development jam" Exploratory r - 200 - 076 3. Address: 6. API Number: Stratigraphic j `- Service I- P. O. Box 100360, Anchorage, Alaska 99510 ` 50 029 - 22960 - 60 `00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 " L 1D-102L1 9. Field /Pool(s): . Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 7407 feet Plugs (measured) None true vertical 3647 feet Junk (measured) None Effective Depth measured 7354 feet Packer (measured) none true vertical 3651 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 13.375 110 110 SURFACE 4145 7.625 4175 3439 SURFACE 754 7 4929 3752 LINER 3025 4.5" / 4" 7393 3648 RECEIVE. lk Perforation depth: Measured depth: 4999' - 7293' . °1iN„„4s' S ! ,8 uv (I : SEP ° 9 M9 True Vertical Depth: 369S COCA 02#50 Oil & Gas Goas• Tubing (size, grade, MD, and TVD) 2.875, L -80, 3961 MD, 3302 TVD Packers & SSSV (type, MD, and ND) no packers CAMCO 'DS' landing nipple @ 518' MD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development l; r Service r Stratigraphic r 15. Well Status after work: Oil 1' • Gas r WDSPL j - Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 16. 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: 311 -235 Contact Brett Packer 265 -6845 Printed Name Brett ;?: Packer Title Wells Engineer Signature , "' �- Phone: 265 -6845 Date ?/90/ RBDMS SEP 0 9 20 4 /-Z2- - 0 Form 10 -404 Revised 10/2010 Submit Original Only vi • KUP • 1D- 102L1 . 1 Well Attributes Max Angle & MD TD a, Inc. . I Wellbore API/UWI Field Name Well Status Inc!() IMD (en)) Act elm (RKB) 500292296060 WEST SAK PROD 93.76 7,294.51 7,407 0 corocertrips 'Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV NIPPLE 0 8/7/2009 Last WO: 5/3/2009 We 39.60 6/22/2000 t Congo 1 t,3ZI2E. 4,3753 PM C: '.it. Aaayl Annotation Depth (Eke) End Date Annotation Last Mod ... End Dale Casing 5,5 Last Tag: I Rev Reason: WORKOVER ninam 9/7/2011 w NGER.sa 5 Casing Strings . /r .. _ M. Casing Description String 0... String ID Top (MB) Set Depth (f . Set Depth (ND) ... String Wt... String ...'String Top Thrd '. ..,„r . D -SAND LINER 41/2 3.958 4,3693 7,393.0 36 L 476 1260 L-80 BTC MOD , '; 45x4 _, CONDUCTOR, I Liner Details 4TOR, Li .'. Top Depth NIPPLE, 518 osier (TVD) Top Incl AMOK It Top (RKB) (RKB) (n) Item D..viption Comment (in) 4,645.9 3,663.9 78.03 CMT VLV BAKER HMCV CEMENTING VALVE ID ( n GAS LIFT, IMP 3,667.9 78.74 ECP BAKER CTC ISOZONE ECP 3.958 2,671 M ging 4,850.4 3,690.5 87.19 ECP BAKER CTC PAYZONE ECP 3.958 GAS s�ni" VINIM. 4,907.7 3,692.7 89.62 KOIV VLV BAKER KOIV KNOCK OUT ISOLATION VALVE 3.958 WIREG3,830 1 4 3,692.9 89.72 SLEEVE BAKER CMD SLIDING SLEEVE 3437 3 SLEEVE-C, 31 3,831 M P rforations & Slots WIREG 3,835 3,835 Lalw' hot Top (rtD) Btm (r1D) Dens GAUGE, 3,889 - -- Top (R Btm (R K B ) (RKB) (ftKB) Zone Date (sh- Type Comment 5,028 7,292 3 693.6 3,653.9 WS D, 1D -102L1 7/12/2000 50.0 SLOTS Perfs thru screens Notr "' SEAL ASS /. __End Date - Annotatbn - •. a. it 3s42� - 3/6/2001 NOTE: MULTI - LATERAL WELL: B-SAND (1D -102), D -SAND (1D- 102L1) SBE, 3,951 - - - - -- 6/1712008 NOTE: VIEW WITH Alaska Schematic9.0 GAS LIFT, ,�a.._ 4,018 SEAL ASSY, 4,074 PBR, 4,082 PACKER, 4,105 PACKER, 4,250 SOS, 4,295 WINDOW, 4,3681,3831 SURFACE 31879 314,930 Ili +Y+ir So Y 4 l * g m 1. '., —, . `: ' ^ SLOTS, 5,028 - 7,292_ wluy F Mandrel Details Top Depth Top Port ^ ^- (ND) Inc! OD Valve Latch Size TRO Run Stn Top (.RKB) (RKB) (1 Make Motel (in)_ Seen Type Type (in) (psi) Run Date Com... ,:_: 1 2,670.9 2,507.6 51.11 CAMCO KBMG 1 GAS UFT SOV BEK 0.000 0.0 8/20/2011 2 3,771.1 3,188.6 52.96 CAMCO KBMG 1 GAS UFT DMY BK -S 0.000 0.0 8/20/2011 3 4,017.5 3,339.3 49.71 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/19/2011 5-SAND LINER iS 4.504. 4,369 -7,393 TO (1D- 102L1), 7,407 1 D -102 Well Work Summary DATE, SUMMARY 8/7/11 PULLED 4 1/2 SLIP STOP @ 3588,M, SET 4 1/2 D &D TEST TOOL W/ BAIT B AS CATCHER, ATTEMPTED TO PULL 1" SOV @ 3509' RKB, SOV POSS. OUT OF POCKET, IMPRESSION BLOCK INDICATES SAME. DRIFT TBG TO BAIT SUB CATCHER W/ 3.69" IMPRESSION BLOCK TBG OPEN, SWEEP GLM'S W/ 2.62" IMPRESSION BLOCK UNABLE TO FIND MISSING VLV, ATTEMPT TO SET 1" BTM LATCH DMY @ 3509' RKB. IN PROGRESS. 8/8/11 RAN 1.22" LIB ON KOT LIB SHOWS 1/2 MOON OF POCKET, RAN KOT & RUNNING TOOL MARKS ON TOOL INDICATE VLV PARTLY OUT OF POCKET, WORKED 1" SOV BACK INTO POCKET. MIT TBG TO 1500 PSI GOOD TEST, PULLED 4 1/2 D &D TEST TOOL @ 3605' RKB, DRIFTED TBG OPEN TO 3.845" DOWN TO 3605' RKB, MADE SEVERAL ATTEMPTS TO PULL 4 1/2 PACKOFF ASSEMBLY @ 3605' RKB. IN PROGRESS. 8/9/11 MADE SEVERAL ATTEMPTS TO PULL 4 -1/2" PACKOFF @ 3605' RKB, NO SUCCESS. PULLED SOV @ 3509' RKB, LEFT GLM OPEN. CALLED FOR BPV. 8/10/11 PRE RWO, VIOD -PPPOT (PASSED), UPPER T -PPPOT (PASSED), LOWER -PPPOT (PASSED), GRAYLOC- PPPOT (PASSED) FT -LDS ALL NORMAL. • • i ConocoPhiilips Time Log & Summary Weliview Web Reporting Report • Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/12/2011 3:30:00 PM Rig Release: 8/21/2011 2:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/10/2011 24 hr Summary Disconnect from Shore Power. Clean location and button up misc small projects. Prep and stage Rig at pad entrance in preparation for move to 1D-102 15:00 22:30 7.50 DEMOB MOVE DMOB P Prep for Move to 1D-102. Disconnect from Shore Power. Pick up plywood, secure tools, breakdown containment and button up misc small projects while waiting on Rig Mat delivery f/ Nabors in Prudhoe. 22:30 00:00 1.50 DEMOB MOVE DMOB P Rig Mats on location. Jack up Rig, Move off mats, clean area and spot Rig at pad entrance in preparation for Rig move. 08/11/2011 Continue Rig Move 1C pad to 1D -102 00:00 01:30 1.50 DEMOB MOVE SFTY P PJSM- Rig Move 1C pad to 1D-102. Continue laying down mats. Pre trip inspection of rig. 01:30 00:00 22.50 DEMOB MOVE TRNS P Security notified and announced. Move off 1C pad. Destination 1D-102. 38/12/2011 Continue Rig Move 1C pad to 1D -102. Build 11" 5M BOPE. Spot Rig over well. Accept Rig @ 15:30 hrs. MIRU all support equipment. Pull BPV. Pressure Test hard line, manifold and hoses 250/3500. 00:00 05:00 5.00 DEMOB MOVE TRNS P Continue Rig Move 1C pad to 1D -102 05:00 07:00 2.00 DEMOB MOVE TRNS P Standby at KIC for field wide change out. 07:00 08:00 1.00 DEMOB MOVE TRNS P Continue with Rig move towards 1D-pad. 08:00 09:00 1.00 DEMOB MOVE TRNS P Shuffle Mats to Culvert and stage. 09:00 12:00 3.00 DEMOB MOVE TRNS P Continue with Rig move towards 1D-pad. 12:00 14:30 2.50 MIRU MOVE PULD P PJSM. Load 11" BOPE back inside Cellar. Hang Tree and Casing Head. Spot Rig. 14:30 15:30 1.00 MIRU MOVE OTHR P Move Rig over 1D-102, spot and level Rig. Accept Rig at 15:30 P.M. 15:30 23:00 7.50 MIRU WELCTL RURD P Set up berm around cellar, Spot Cuttings Box, Boiler Blow Down Box, Used oil tank and Kill tank. RU hard line to Kill Tank and hoses in cellar. Bring in BPV lubricator and equipment and Test Joints. 23:00 23:30 0.50 MIRU WHDBO KLWL P Lubricate and pull BPV. 23:30 00:00 0.50 MIRU WELCTL KLWL P Pressure test hard line and manifold 250/3500. Page 1 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/13/2011 24 hr Summary Circulate surface to surface 8.6 ppg 60° filtered Seawater with 3% KCI. Set BPV. ND Tree. NU BOPE and begin test. 00:00 00:30 0.50 COMPZ WELCTL SFTY P PJSM- Circulating out well. 00:30 02:00 1.50 COMPZ WELCTL KLWL P Start circulating 8.6 ppg- 160° filtered seawater @ 3 bpm, clean, hot 8.43 ppg returns at 180 bbls. ICP 140 psi, FCP 120 psi with 1:1 returns. 02:00 02:30 0.50 COMPZ WELCTL KLWL P Shut in and monitor well, initial SITP 10 psi, slight pressure increase to 20 psi in 30 min. 02:30 04:00 1.50 COMPZ WELCTL KLWL P Circulate last 100 bbls hot filtered 8.6 ppg seawater. ICP 140 psi, FCP 180 psi. 1:1 returns. 04:00 05:00 1.00 COMPZ WELCTL KLWL P Shut in and Monitor well, SITP 0 psi, IA 0 psi, returns hot and clean. no pressure increase in 30 minutes but still have flow. off load 60° 8.6 ppg seawater to pits. 05:00 07:00 2.00 COMPZ WELCTL KLWL P Circulate 150 bbls 8.6 ppg 60° seawater, 1:1 returns to outside tank. ICP 170 psi, FCP 140 psi. Monitor well for 30 mins. 07:00 07:30 0.50 COMPZ WELCTL KLWL P Install Type "H" BPV. 07:30 09:30 2.00 COMPZ WELLPF NUND P PJSM. N/D Tree and remove from cellar. Inspect Lifting threads. All Good. 09:30 19:00 9.50 COMPZ WELLPF NUND P PJSM. N/U BOPE. Install 2 7/8" x 5" VPR's in lower set and 3 1/2" Fixed in upper set. 19:00 21:30 2.50 COMPZ WELLPF BOPE T Attempt Shell test BOPE, found leak at kill line grayloc at mezzanine. replace seal in grayloc. 21:30 22:00 0.50 COMPZ WELLPF BOPE T Attempt Shell test failed, trace leak to block valve at manifold, change out block valve and get passing Shell test. 22:00 00:00 2.00 COMPZ WELLPF BOPE P Begin BOPE test 250/3500. Annular 250/3000. 08/14/2011 Continue BOPE test. Pull Blanking Plug and BPV. Pull Hanger to floor, LD same. POOH laying down 4.5" Tubing Spooling back ESP cable / TEC wire / Heat Trace. PU MU Clean Out and Casing Drift assembly. 00:00 03:00 3.00 COMPZ WELLPF BOPE P BOPE test 250/3500. Annular 250/3000. 03:00 04:00 1.00 COMPZ WELLPF OTHR P Pull Blanking Plug and BPV. Install Side Isolation Sleeve. 04:00 05:30 1.50 COMPZ WELLPF OWFF P Monitor well for flow. Bring in small spooler and empty spool and Centalift equipment. Prep floors for 4 1/2 equipment. Well Static. 05:30 06:15 0.75 COMPZ RPCOM SFTY P PJSM w/ Centralift Reps. Pulling ESP Completion, Non Standard Procedure. 06:15 07:15 1.00 COMPZ RPCOM OTHR P Hang ESP and Heat Trace Sheave for Both. Check For Flow and Psi on Well. Check All Audio Alarms on Rig. Page 2of9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 09:00 1.75 COMPZ RPCOM PULL P Un -seat Hanger at 210k, free weight at 98k. Continue up hole with hanger and measure distance from mark on rotary table to landing joint. ( 27.4 "). Pull one full stand and rig up heat trace and ESP cable to spoolers. Remove Penetrator, L/D hanger and landing joint. 09:00 15:00 6.00 3,694 107 COMPZ RPCOM TRIP P PJSM. POOH standing back 4 1/2" De- Completion while removing ESP clamps. Up Wt 98k 15:00 15:15 0.25 107 107 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of Removing ESP from 4.5" Completion. 15:15 16:00 0.75 ,107 0 COMPZ RPCOM PULL P Able to remove 4 1/2" Completion. Pack -off assembly was stuck inside tubing. 16:00 21:30 5.50 0 0 COMPZ RPCOM PULL P Pulled and dis- assemble lower section of ESP. Take samples, Box ESP equipment and Kick out. No clamps or bands missing. 5' mid -joint dual - channel HT clamps= 454 4' mid -joint dual - channel HT clamps= 11 3' mid joint dual - channel HT clamps= 10 2' mid joint dual - channel HT clamps = 7 Dual- channel cross - coupling clamps= 98 Single- channel cross - coupling clamps= 20 Stainless -steel flat bands= 22 Flat gaurds= 4 Protectolizers= 3 21:30 22:00 0.50 0 0 COMPZ WELLPF OTHR P Change over Floors 22:00 00:00 2.00 0 0 COMPZ WELLPF PULD P Bring in Baker Clean Out tools. Set Wear Ring. PU MU BHA #1 as per Baker Rep. 38/15/2011 RIH w/ Clean Out - Casing Drift assembly to 4,224 -ft, Clean out to 4,353 -ft. POOH standing back DP, LD & KO BHA #1. PU MU and RIH w/ Surface Casing Pressure Test assembly and set Top of RBP at 4,247 -ft. Test 7" RBP to Test Packer at 4,036 -ft to 1500 psi, failed, 60 psi loss in 15 minutes. Test Backside to Test Packer at 4,036 -ft to 1500 psi, failed, 60 psi loss in 15 minutes. Move Test Packer down to 4,046 -ft, test same. Release Test Packer and Test Casing to RBP. Appears to be surface leak. 00:00 01:30 1.50 0 0 COMPZ RPCOM PULD P PU MU BHA #1 as per Baker Rep. 01:30 03:00 1.50 0 209 COMPZ RPCOM PULD P Bring in 4 3/4 Drill Collars, strap and continue PU MU of Clean Out assembly. 6" OD smooth body concave mill, 1 jt. DP, 6" OD string mill, magnet, oil jar, 4 ea. DC's, 7 5/8" casing scraper, dual boot baskets and pump out sub. 03:00 06:30 3.50 209 4,224 COMPZ RPCOM TRIP P RIH w/ BHA #1 on 3 1/2" Drill Pipe (Single In) Page 3 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:30 2.00 4,224 4,261 COMPZ RPCOM CIRC P Set Down with Drift assembly at 4,224 -ft. Start Circulating and Rotating thru fill. Clean to 4,261 -ft. PUH 1 joint and CBU at 6 bpm, 760 psi,until return are clean and good 8.6 ppg fluid is seen at surface. 08:30 09:30 1.00 4,261 4,353 COMPZ RPCOM CIRC P Continue to Circulate down to 4,353 -ft at 6 bpm, 740 psi, 09:30 12:00 2.50 4,353 4,353 COMPZ RPCOM CIRC P Clean down to target depth at 4,353 -ft, circulate a 25 bbl High -Vis sweep and CBU until returns are clean. Pump rate 8 bpm, 950 psi. Return Not cleaning up very well. CBU again. Load Baker Testing Equipment to rig floor. 12:00 15:00 3.00 4,353 200 COMPZ RPCOM TRIP P Seen good clean 8.6 ppg fluid at surface. Start POOH standing back DP while keeping hole full. Up Wt 108k, Down Wt 72k. 15:00 16:30 1.50 200 0 COMPZ RPCOM PULD P BHA at surface. PJSM. Lay down Clean Out Assembly. 16:30 17:30 1.00 0 128 COMPZ RPCOM PULD P PJSM. PU MU Surface Casing Test Assembly. 7" Model 'G' RBP, Model 'L' Retrieving Head, 3 joints DP, 7 5/8" Retrievamatic Test Packer. BHA #2 17:30 22:00 4.50 128 4,247 COMPZ RPCOM TRIP P RIH with BHA #2 on DP and set Top of RBP at 4,247 -ft (Top of Test Packer at 4,132 -ft) Up wt 98k, Dn wt 70k. 22:00 00:00 2.00 4,247 4,161 COMPZ RPCOM PRTS P PUH 1 stand, Circulate down DP 31 bbls 3 bpm at 110 psi. Set Top of Test Packer at 4,036 -ft. Attempt test RBP 1500 pi, failed, lost 100 psi in 15 minutes, appears to be linier. Attempt Test Backside to 1500 psi, same results 100 psi in 15 minutes. Release Test Packer, RIH and Set @ 4,046 -ft, Attempt tests both sides with samr results. Release test Packer and test Backside to RBP to 1500 psi. 38/16/2011 Reset RBP up hole at 4,237 -ft. Test Backside from Top of Test Packer at 4,107 -ft to 1500 psi, Passed. Unable to obtain Test from Test Packer @ 4,107 -ft to RBP at 4,237 -ft, Leak off rate 60 psi every 15 minutes. Dump Sand on RBP. POOH Standing back 10 joints DP, Single out remainder of DP. LD KO BHA #2. Run Micro- Vertilog from 4,180 -ft to surface. ND Riser. NU shooting Flange. Run Caliper /MTT /GR /CCL log from 4,228 -ft to surface. 00:00 00:30 0.50 4,161 4,161 COMPZ RPCOM PRTS P Release test Packer and test Backside to RBP to 1500 psi. steady leak off rate 120 psi in 30 min. Confer w/ Town Rep. Page 4 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 4,161 4,237 COMPZ RPCOM PRTS P RBIH to 4,247 -ft, release RBP and reset RBP Top at 4,237 -ft. PUH 15' with Test Packer 4,127 -ft to 4,107 -ft and set. Attempt test between plugs, failed, same leak off rate. Pressure test Backside 1,450 psi good, Flat line 25 minutes, All tests Charted. 02:00 04:00 2.00 4,237 4,219 COMPZ RPCOM PRTS P PUH and reset Test Packer @ 4,103 -ft, set in slips, Kelly down and hook up direct to DP. Attempt Pressure Test between Plugs, same 60 psi in 15 minutes, 120 psi in 30 minutes leak off rate. 04:00 04:30 0.50 4,219 4,193 COMPZ RPCOM OTHR P Unseat Test Packer PUH 1 Joint and dump 300 lb sand on RBP at 4,237 -ft. 04:30 05:30 1.00 4,193 4,193 COMPZ RPCOM OTHR Allow sand to drop. BD Top Drive 05:30 06:00 0.50 4,193 4,228 COMPZ RPCOM TRIP P RIH and Tag Top of Sand at 4,228 -ft 06:00 10:00 4.00 4,231 0 COMPZ RPCOM TRIP P POOH standing back first 10 stands DP, Single out remainder of DP, LD and KO BHA #2 and DP. 10:00 12:00 2.00 0 0 COMPZ EVALWE SFTY P PJSM- Bring in Wireline tools and equipment. RU Wireline. 12:00 13:00 1.00 0 4,180 COMPZ EVALWE ELOG P RIH w/ Micro Vertilog / GR /CCL. Log up from 4,180 -ft to surface. 13:00 14:00 1.00 4,180 0 COMPZ EVALWE OTHR P LD and off load Micro Vertilog tools 14:00 17:00 3.00 0 0 COMPZ WELCT[ NUND P PJSM- ND riser and NU Shooting Flange 17:00 18:00 1.00 0 0 COMPZ EVALWE NUND P Bring in and RU Wireline Lubricator and stripper head. 18:00 00:00 6.00 0 4,228 COMPZ EVALWE ELOG P MU and RIH with Caliper / MTTX / GR / CCL, Log up from 4,228 -ft to surface. Repeat MTTX Log from 270 -ft to surface. 38/17/2011 Run GYRO /GR /CCL log from 4,228 -ft to surface. Run HES CAST -M /GR/CCL from 4,180 -ft to surface. ND Shooting Flange. Run Storm Packer /RBP Retrieval Assembly and set at 100 -ft. Pressure Test 7 5/8" Casing to Storm Packer 3500 psi. 00:00 01:00 1.00 0 270 COMPZ EVALWE ELOG P Repeat MTTX Log from 270 -ft to surface. LD and push out PDS Caliper / HES MTTX / GR / CCL. 01:00 02:00 1.00 270 0 COMPZ EVALWE ELOG P PJSM- Bring in, MU GYRO / GR / CCL. 02:00 07:00 5.00 0 0 COMPZ EVALWE ELOG P RIH w/ GYRO / GR / CCL and Log up from 4,225 -ft to surface. 07:00 10:30 3.50 0 0 COMPZ EVALWE ELOG P Rehead 5/16" Line through grease injector. Calibrate cast -m tool. 10:30 10:45 0.25 0 0 COMPZ EVALWE SFTY P Held PJSM with rig crew on on rigging up tool string and lubricator. 10:45 14:00 3.25 0 0 COMPZ EVALWE ELOG P Rig up tool string and lubricator. Pressure test lube to 1,000 psi standby for rig to change valve and tighten shooting flange. Pressure test lubricator to 1,000 psi. Page 5 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 18:00 4.00 0 0 COMPZ EVALWE ELOG P RIH w/ Cast -M tool to 4,207 -ft. Log Cast -M tool in pipe inspection mode to surface. 18:00 20:30 2.50 0 0 COMPZ EVALWE ELOG P Bleed off lubricator and and RD Tools, Lubricator, Sheaves and ND Shooting Flange. NU riser. 20:30 21:00 0.50 0 0 COMPZ WELLPF RURD P RU Floor to run 4 1/2" Tubing 21:00 23:00 2.00 0 948 COMPZ WHDBO TRIP P PU MU RBP retrieving head, 9 stands of 4 1/2 ", 12.6# L -80 IBTM Tubing (843 -ft= 10,620 Ibs) hang below 7 5/8" Model "EA" Retrievamatic Storm Packer assembly. RIH w/ BHA #3 on 1 std DP to set Storm Packer @ 100 -ft, bottom of assembly @ 948 -ft. Up wt 48k, Dn wt 50k. POOH w/ Running tools. 23:00 00:00 1.00 0 0 COMPZ WHDBO PRTS P RU and Attempt Pressure test 7 5/8" Casing to Storm Packer to 3500 psi, slow leak off rate. troubleshoot and attempt again w/ same results. X8/18/2011 Pressure Test Storm Packer. ND BOPE and Tubing Head. NU New 5.5" Casing Head and New Tubing Head. Test ODC connection. NU BOPE. Test Breaks to 250/3500 psi. POOH and LD Storm Packer. RBIH w/ RBP Retrieval head on 4 1/2" Tubing and DP. Circulate out sand. Release RBP and Stand back DP, Single out 4 1/2" Tubing. LD RBP. C/O Pipe Rams to 5 1/2 ". 00:00 01:00 1.00 0 . 0 COMPZ WHDBO PRTS P Pressure test 7 5/8" Casing to Storm Packer to 3500 psi, Charted and passed. 01:00 02:00 1.00 0 0 COMPZ WHDBO NUND P ND BOPE. 02:00 04:30 2.50 0 0 COMPZ WHDBO NUND P ND Tree head- NU New Casing Head, Tree Head. ODC Adapter tested to 5000 psi for 15 minutes, Passed. Tree orientation verified by DSO (Donna Collins at 04:00) Measure new RKB's. 04:30 08:00 3.50 0 0 COMPZ WHDBO NUND P NU BOPE 08:00 10:00 2.00 0 0 COMPZ WHDBO PRTS P RU and Pressure test New Tubing Spool to CSG head break at 3,500 psi for 20 minutes with no pressure loss. RD Test equipment. 10:00 10:15 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with Rig crew and Baker Service hand on engaging and releasing Storm packer. RIH and washing sand off RBP and Releasing RBP. 10:15 11:30 1.25 0 0 COMPZ WHDBO MPSP P RIH and Retrieve Storm packer at 100 -ft. and lay down same. 11:30 14:00 2.50 0 4,221 COMPZ WELLPF TRIP P Continue to RIH with 4 1/2 IBTM TBG to 3,442 -ft and Cross over to 3 1/2 DP. Continue to RIH w/ 3 1/2 DP to 4,221 -ft and tag top of sand. Page 6 of 9 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:00 2.00 4,221 4,229 COMPZ WELLPF CIRC P MU Top drive and wash down to RBP and engage at 4,229 -ft. Release off RBP and PU 2 -ft, Pump 30 bbl hi visc sweep at 8 bpm at 800 psi taking returns to kill tank with 189 bbls of filtered 3% KCL.Release RBP and let elements relax. 16:00 17:00 1.00 4,229 3,442 COMPZ WELLPF TRIP P POOH standing back 3 1/2 DP to 3,442 -ft. 17:00 22:00 5.00 3,442 0 COMPZ WELLPF PULD P POOH laying down 4 1/2 IBTM TBG and Baker "G" Bridge plug 22:00 00:00 2.00 0 COMPZ WHDBO BOPE P Set Test Plug. Change out Rams to 2 7/8" Upper and 5.5" Lowers 08/19/2011 C/O Pipe Rams to 5 1/2" Lower, 2 7/8" Upper and Test 250/3500. MU PU and RIH w/ 5.5" Casing Completion. Load Annulus and Casing w/ 180 bbls 9.6 ppg inhibited brine. Position and Set Packers. Shear PBR, Space out and land Casing Hanger. Test Annulus 1500 psi. Test Casing Hanger. RD Casing Crew. Bring in 2 7/8" Jet Pump Completion equipment and Tubing, Rack and Tally. 00:00 00:30 0.50 0 0 COMPZ WHDBO BOPE P Continue changing out Rams to 2 7/8" Upper and 5.5" Lowers. 00:30 04 :30 4.00 0 0 COMPZ WHDBO BOPE P RU and Test @ 2 7/8" Upper pipe rams 250/3500, Annular 250/3000. Test 5.5" Lower pipe rams 250/3500. 04:30 05:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM- Running 5.5" Inner Casing Completion. Third party Casing crew. 05:00 05:30 0.50 0 0 COMPZ RPCOM OTHR P Change over floor to RIH w/ 2 7/8 and 3 1/2 Tail assy. 05:30 06:30 1.00 0 318 COMPZ RPCOM PUTB P PU MU and RIH w/ Lower Casing Completion as per run order to 318 -ft. 06:30 07:00 0.50 318 318 COMPZ RPCOM OTHR P Change over floor to RIH w/ 5 1/2 Casing 07:00 11:00 4.00 318 4,296 COMPZ RPCOM RNCS P RIH w/ Lower Casing assy from 318 -ft, picking up 5 1/2 Casing to 4,296 -ft. Up wt 110k, Dn wt 75k 11:00 11:15 0.25 4,296 4,296 COMPZ RPCOM SFTY P Held PJSM on spotting CI 9.6 ppg Brine 11:15 14:00 2.75 4,296 4,296 COMPZ RPCOM CIRC P Reverse circulate 80 bbls of CI 9.6 ppg Brine at 3 bpm at 80 psi. Switch to bullhead 100 bbls CI 9.6 ppg Brine down 5 1/2 Casing. ICP at .5 bpm at 950 psi for 2 bbls, then broke down and was able to increase rate to 3 bpm at 500 psi - seen increase to to 800 psi. FCP at 320 psi at 3 bpm. SWI and insert ball. Drop ball and wait for 30 minutes. Pressure up to 1,500 psi and set Premier Packers 7" at 4,250 -ft and 7 5/8" at 4,105 -ft. Slack off from 75k to 70k, pressure up to 3,000 psi and hold pressure for 10 minutes. Bleed off pressure. 14:00 14:30 0.50 4,296 4,296 COMPZ RPCOM PRTS P Pressure test 7 5/8" x 5 1/2" annulus at 1,500 psi for 15 minutes and chart. - Good test. 14:30 15:00 0.50 4,296 4,296 COMPZ RPCOM PACK P Pressure up to 1,500 psi and shear out of PBR at 127k. Page 7 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:45 0.75 4,296 4,088 COMPZ RPCOM HOSO P POOH and lay down Tag joint. PU and MU 10 3/4" x 5 1/2" Casing hanger and landing joint. Land Hanger - seen seals engage PBR 4,074 -ft. RILDS. 15:45 16:00 0.25 4,088 4,088 COMPZ WHDBO PRTS P Pressure test Casing hanger void at 250/5,000 psi 16:00 17:30 1.50 4,088 4,088 COMPZ RPCOM PRTS P Pressure test 7 5/8" x 5 1/2" annulus at 1,500 psi for 15 minutes and chart. - Good test. 17:30 19:00 1.50 4,088 0 COMPZ RPCOM OTHR P LD Landing joint, RD Casing crew, send out tools. 19:00 20:00 1.00 0 0 COMPZ WHDBO BOPE P Change out Lowers to 2 7/8" - 5" VBR's 20:00 21:00 1.00 0 0 COMPZ WHDBO BOPE P Test Lower VBR's 250/3500. RD test equipment. 21:00 23:45 2.75 0 0 COMPZ RPCOM PULD P Bring in remainder of 2 7/8" Tubing and Completion Equipment. Rack and Tally 2 7/8" Tubing. bring in TEC wire spool and spooler. Set up and test Guardian Gauge for installation. 23:45 00:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Running 2 7/8" Jet Pump completion. 38/20/2011 PU and RIH w/ 2 7/8" Jet Pump Completion. Space out and MU Tubing Hanger. Circulate well full. Land Tubing Hanger and RILDS. PIT Tubing Hanger Packoff. PIT Tubing and Tubing x Annulus. Shear SOV. ND BOPE. NU Tubing Head Adapter and Tree. Freeze Protect Tubing and IA. 00:00 07:30 7.50 0 3,974 COMPZ RPCOM TRIP P PU and RIH w/ 2 7/8" Jet Pump Completion as per run order. Test and install Guardian Gauge, TEC wire adding Single- channel cross - coupling clamps at each joint. stop just above SBE at Up wt 63k, Dn wt 53k. No -go out at 3,950 -ft with mule shoe at 3,974 -ft. 07:30 09:00 1.50 3,974 3,943 COMPZ RPCOM HOSO P Mark pipe and POOH laying down tag joints. PU 18 -ft of space out pups and TBG hanger with full joint below. MU landing joint. RU circ hose to circulate, lower hanger down to Rotary Table for Tec wire splice. 09:00 10:00 1.00 3,943 3,943 COMPZ RPCOM OTHR P Install Penetrators and and splice Tec wire. MU Tec wire to Penetrator and check installation. - working good. 10:00 11:00 1.00 3,943 3,943 COMPZ RPCOM CIRC P Pump 20 bbl spacer @ 2 bpm @ 320 psi and follow with 114 bbls of CI Sea water at 2 bpm @ 300 psi. 11:00 11:30 0.50 3,943 3,967 COMPZ RPCOM HOSO P Locate seals at SBE at 3,950 -ft, open bleeder and land hanger w/ Mule shoe at 3,967 -ft.. Dn wt 53k RILDS. 11:30 12:30 1.00 3,967 3,967 COMPZ RPCOM PRTS P Pressure test TBG hanger void at 250/5,000 psi for 15 minutes. Page 8 of 9 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:30 14:00 1.50 3,967 3,967 COMPZ RPCOM PRTS P RU Testing equipment to TBG and 2 7/8" x 5 1/2" IA. Pressure up to 2,500 psi on TBG and chart for 15 minutes. No Losses. Leave pressure on TBG and Pressure up on 2 7/8" x 5 1/2" IA to 3,500 psi for 30 minutes. Good test - no losses. Bleed off IA first then follow TBG pressure. Pressure up IA and Shear SOV at 2,000 psi. RD Test equipment. 14:00 14:15 0.25 3,967 3,967 COMPZ - RPCOM SFTY P Held PJSM with Crane operator on loading Empty ESP spool. 14:15 14:45 0.50 3,967 3,967 COMPZ RPCOM OTHR P RU crane and load Empty ESP Spool. RD Crane. 14:45 15:15 0.50 3,967 24 COMPZ WHDBO OTHR P Back out Landing jt at 24.45 -ft and recover ISO sleeve. Drain stack and set 3" H - BPV. 15:15 15:30 0.25 24 24 COMPZ WHDBO SFTY P Held PJSM on ND BOPE 15:30 19:30 4.00 24 25 COMPZ WHDBO NUND P Change Upper Rams from 2 7/8 to 3 1/2 Solid Rams. Swap out HCR Valve on kill line. ND BOPE. 19:30 21:30 2.00 25 COMPZ WHDBO NUND P NU tree and accuator, Accuator orientation verified by Ricky Lawless DSO lead. Test Tubing Hanger Packoff 5000 psi, good. 21:30 22:30 1.00 COMPZ WHDBO PRTS P Pressure Test Tree 250/5000 psi, Chart and RD test equipment. 22:30 00:00 1.50 COMPZ WHDBO FRZP P MIRU Little Red Services. Pressure Test Lines and equipment 3500 psi. Pump 70 bbls Diesel Dn IA taking returns to Kill tank. ICP 1850 psi, FCP 2150 psi @ 2 bpm. 08/21/2011 Continue Freeze Protect TBG & IA. Set BPV. Dress Tree. Clean Cellar. RDMO. 00:00 00:30 0.50 0 0 COMPZ WHDBO FRZP P Continur pumping Diesel Freeze Protect Diesel Dn IA taking returns to Kill tank. ICP 1850 psi, FCP 2150 psi @ 2 bpm. Bleed TBG and IA to 0 psi. 00:30 01:30 1.00 0 0 COMPZ WHDBO SEQP P Set BPV. Dress Tree. Clean cellar. 01:30 01:45 0.25 0 0 COMPZ MOVE SFTY P PJSM- Moving on pad well to well. 01:45 02:00 0.25 0 0 COMPZ MOVE MOB P Jack up Rig. Move off mats. Rig Released @ 02:00. Page 9 of 9 • • 1.11AU SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. 23 P.O. Box 100360 -----'' -------:6-.1° ° ‘.-- Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-102L1 Sundry Number: 311 -235 Dear Mr. Packer: r'' JUL , 9 n!`t Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday o , eekend. ..- - , - S if Seamount, C IF DATED this g day of July, 2011. Encl. , 10,7 • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ". ' July 22, 2011 Commissioner ` ., }s;. , }sGCaott3Sfl�ti State of Alaska Alaska Oil & Gas Conservation Commission .Jsa 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover West Sak Well 1D- 102 (PTD# 200 -075 L\ tip, Producing well 1D -102 was drilled and completed in June 2000. It was first brought online in July 2000 as a West Sak dual lateral A/B/D sand ESP producer. This well has had a fair share of problems due to heavy sand and gravel production from a matrix bypass event with injector 1D -139, and also due to the failed RMLS junction in the upper lateral. We have worked this well over five times in the past, and this will be the sixth. The most recent failure occurred in December 2009, when the ESP went down unexpectedly. Subsequent attempts to restart the pump were unsuccessful, and during an attempt to freeze protect the IA, the well pressured up to 3500 psi indicating a sand plug below the ESP. Due to the heavy sand production from this well, and the numerous ESP failures, we have decided that an ESP is not the desired artificial lift mechanism we want to pursue in the future for this well. This time, we plan to install a surface powered iet pump, similar to what has been done on four of our West Sak 1C single casing wells. This completion will allow CTD access below the tubing tail for cleanouts and such. ConocoPhillips has initiated a new two- barrier policy from any energized fluid (i.e. reservoir fluids, power fluid, lift gas), consequently, in order to install a surface powered jet pump, this well requires another string of casing to provide that 2 barrier. "Ths ro osed workover will pull the 4 ''/2" ESP completion, install an inner string of 5Y2" casing and re- complete the well with a 2'/8" jet -pump /gas -lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP is 1650 p( at the mid -perf depth of 3,708' TVD, which equates to an EMW of 8.6 ppg. Current SITP is 150 psi. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells ` STATE OF ALASKA CH,. r^� ? _` } t ` �' ALASK. AND GAS CONSERVATION COMMISSI Cr APPLICATION FOR SUNDRY APPROVA S 20 AAC 25.280 Air .x,. i , _ • erh4, L'): .11SSIQf 1. Type of Request: Abandon r Rug for Redd! f r Perforate New Pool Repair well r Cfiange AApprovea Program Suspend r Rug Perforations r Perforate r Pull Tubing ` me' '-' @ti ion r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing Other: ASP ' 0 f ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 200 -076 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22960 -60 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No Fr 1D - 102L1 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25650 - Kuparuk River Field / West Sak Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7407 3647 - 7354' 3651' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 13.375 110' 110' SURFACE 4145' 7.625" 4175' 3439' SURFACE 754' 7" 4929' 3752' LINER 3025' 4.5" / 4" 7393' 3648' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4999' - 7393' 3693' - 3648' 4.5 L - 3658 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer no SSSV 12. Attachments: Description Sunmary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory ` Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/8/2011 Oil r Gas r WDSPL r Suspended T 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer © 265 -6845 Printed Name Brett Packer Title: Wells Engineer Signature (t- ? Phon 265 -6845 Date : / 72` /( � 9 Commission Use Only `,� ✓ ✓ ✓✓ Sundry Number:3) 1.C71 Conditions of approval: Notify Commission so that a representative may witness ��/// Plug Integrity r BOP Test Mechanical Inte rityTest r Location Clearance r ' Other: 3So6 Ps` J31' o Te5 1- 11- 25oa psi Ann Lc-6 1+ !eS f (h.'`^. Subsequent Form Required: / - t1 • - ier /"Ili APPROVED BY ,/y.� 2 ^ 4 r� Approved by: , OM I : IONER THE COMMISSION Date: / �c � ff tl Form 10 -4Ct3 P €4i3 i iJi 1112 9 11; � 7 Z ORIGINAL Submit in DupIicatt7'1 x�' 0 • . 1D-102 Rig Workover Install 5 casing and 2'/8" JP Completion (PTD #: 200 -075) Current Status: West Sak ESP producer was SI January 2010. The ESP cannot be re- started due to a sand bridge below the ESP. Scope of Work: Pull the 4 '/2" ESP completion, cleanout down to the RMLS junction, pressure test the casing, run a suite of diagnostic e-line logs in the 7 %" casing, install a 5 '/2" inner casing string, install a 2 7 /8" Jet Pump completion. General Well info: Well Type: Producer MPSP: 1,279 psi Reservoir pressure /TVD: 1,650 psi / 3708' TVD (8.6 ppg) Wellhead type /pressure rating: Vetco Gray Horizontal, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA/OA not possible due to single casing packerless ESP completion. Earliest Estimated Start Date: August 8, 2011 Production Engineer: Jenn Gauer Workover Engineer: Brett Packer (265 -6845 / j.brett .packer @conocophillips.com) Pre -Rig Work: 1. RU Slickline: a. Pull slipstop, packoff, and pump. b. Swap out SOV for DV in GLM #2 at 3,509' RKB. 2. PT tubing & casing packoffs. 3. Set BPV. Proposed Procedure: 1. MIRU Nordic 3. Pull BPV. Reverse circulate hot filtered seawater w/ 3% KCL to clean the ESP & tubing. Stop circulating and bullhead another 25 bbls down the IA to the formation. Obtain SITP & SICP, and verify needed KWF. Repeat circulation using filtered KWF if necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE & test.. 35o a p>i. PT. 3. Pull blanking plug & BPV, install side isolation sleeve in hanger, screw in landing joint, BOLDS's and pull to the floor. 4. POOH w/ ESP completion, standing back tbg, spooling up ESP cable & heat trace. Lay down ESP equipment. 5. RIH w/ 7 %" scraper assembly on old 4 %2' tubing, cleanout down to RMLS junction at 4,369' MD. POOH standing back tubing. 6. MU 7" RBP and 7 %" test packer, RIH on old 4 ''/2" tubing to 4,275' MD. Set RBP and release from RBP. Pull up into the 7 S /8" casing and set the test packer. PT the RBP to 1500 psi. PT back side to 1500 psi. a. If pressure tests OK: Release test packer & RBP, POOH laying down tubing, and proceed with running E -line logs • 7. RU E -line: RIH w/ Microvertilog, 40 -Arm Caliper, and Gyro; log from 4150' back to surface. • 8. Unload old tubing and rack & tally new casing and tubing in pipe shed. • 9. PU and RIH w/ 5 1/4", 15.5 #, L -80 BTCM -SCC casing, SBE, PBR Seal Assy, 3 ' /2" x 7" Premier Packer, solid seat SOS, and WLEG. " Ica, 10. Install storm packer at —100' MD w/ casing hanging below. NDBOP. 11. Remove old wellhead and install new wellhead to accommodate the 5 1/4" casing. ✓ 12. NUBOP & test. V 13. Release storm packer and POOH laying down storm packer. • 14. Continue RIH w/ 5 1/4" casing to packer setting depth of 4,275' MD. Land the 5 1/4" casing hanger, RILDS. • 15. Bullhead gelled diesel down the 5 1/4" x 7 %" annulus to below the packer. Pressure up on casing to set the packer. PT the annulus w/ diesel to 1500 psi. BOLDS, pull up on 5 'h" casing to shear the PBR. 16. Space out 7' off bottom and land 5 1/4" casing hanger. RILDS. Pressure test 5 1/4" x 7 5 /8" annulus to 1500 psi."' 17. PU and RIH w/ 2 %" jet pump completion w/ downhole gauge and seal assy. ✓ 18. Sting seals into SBE, mark pipe, pull seals from SBE, circulate well full of CI brine, space out 7' off bottom, make up hanger and splice TEC wire to penetrator, land the hanger. RILDS. 19. PT tbg to 3000 psi, monitor annulus, bleed tbg to 2750 psi. PT IA to 3500 psi for 30 min. Record casing test on chart recorder. Bleed IA to zero, bleed tbg to zero. Ramp up IA pressure to shear SOV.. 20. Pull landing joint, drain stack, remove side -port isolation sleeve, set two -way check, NDBOP. 21. NU and test tree. Pull two -way check, freeze protect through the SOV, set BPV. 22. RDMO Nordic 3. Post -Rig Work: 1. Reset well house(s) and flowlines of adjacent wells. 2. Make necessary S -riser mods 3. Re -attach flowline. Connect new Guardian gauge. 4. Pull BPV. 5. RU slickline, replace SOV w/ DV. 6. Turn well over to production. • • • West Sak Well: 1D-102 2011 RWO PROPOSED COMPLETION API: 500292296000 Conductor: PTD: 200-075 13.375 ", 68 #, L -80 at 110' Wellhead: Gray Horiz DS • X -mas Tree: 4- 1/16 ", 5K psi Surface Casing: Lift Threads: 4.909" MCA 7.625 ", 29.7 #, L -80 to 4175' BPV: 4" 'H' 7 ", 26 #, L -80 from 4175' to 4929' RMLS Junction at 4,369' MD Proposed 2'/•" Completion • Tubing = 21/2", 6.5 #, L -80, 8rd EUE. New Inner Casing: • 2.313" DS- nipple at 500' I 5.5 ", 15.5 #, L -80 BTCM • CMU Sliding Sleeve w/ 2.25" D J profile. Bakerweld Pre -pack screens: • Guardian Pressure Gauge. 4' x 4.5 ", Alt. screen /blank liners • Baker locator w/ 17' seal assy. f �T tau A.A. p t t i M ) / CMU Sliding Sleeve ` Proposed 5' /z" Inner Csq. String • Guardian Sidemount Gauge Carrier • Casing = 5'/2',15.5 #, L -80, BTCM -SCC. • XO from 51/2' BTCM -SCC to 5" BTCM. 41- 5" SBE (20' long) • 20' SBE. 3 -1/2" EUE Tbg • XO from 5" BTCM to 3 EUE. • 31/2" EUE Tubing. t PBR (20' long) • Baker locator w/ 17' seal assy. X f Premier Packer to be set @ 4275' RKB • 20' PBR sce • Baker 3 x 7" Premier Packer \ -4 2-7/8" EUE Tbg Tail w/ SOS & WLEG • XO from 3%" EUE to 2'/" EUE. f RMLS Jxn @ 4369' RKB • 21/2" EUE tubing tail 1-- • Shear out Sub �/ g • WLEG Last Updated: 22- Jul -11 Updated by: JBP • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ~' Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~' Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Weli ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Driil Number: COnOCOPhllllps Alaska, InC. Development ~• Exploratory ~ 200-076 /. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22960-60 ' 7. KB Elevation (ft): 9. Well Name and Number: ~ RKB 30' 1 D-102L1 8. Property Designation: 10. Field/Pool(s): ADL 25650 • Kuparuk River Field / West Sak Oil Pooi . 11. Present Well Condition Summary: Total Depth measured 7407' ' feet true vertical 3647' • feet Plugs (measured) Effective Depth measured 7354' feet Junk (measured) true vertical 3651' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 13-3/8" 110' 110' SURFACE 4145' 7-5/8" 4175' 3439' SURFACE 754' 7" 4929' 3752' LINER 3025' 4.5" / 4" 7393' 3648' Perforation depth: Measured depth: 4999'-7393Q.$~,,;,~~3~p~~ ~~.1L i~~ ~-~U~ ~~~~~~~D true vertical depth: 3693'-3648' `~~~ a~ z~o~ ,~ ::~:~ ~~r`I 8~ Gas C 0 Tubing (size, g~ade, and measured depth) tbg in main wellbore, , MD. ~~~ C0-11fpi~sj~~ An~h,~rapQ Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not app/icab/e 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 364 8 399 -- 191 Subsequent to operation 304 • 15 368 ^ -- 174 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~~ Service ^ Daily Report of Well Operations _X 16. Weli Status after work: Oil^~ ' Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Engineer / ~ ~ ~ ~~ Signature -- Phone: 265-6845 Date ~7 / U Pre red b aron Allsu -Drak 263-4612 ~t ~ ~," Z~' c'~' ~ ,, Form 10-404 Revised 04/2006 ~~ ~ ~~ ~1~~~- ~ ~ ~009 ~~mit Original Onl . ~~~~~~ _... ' KU P 1 D-102L1 .- /~ _._.- -- _ ~Qn~Q~~~l~~+~ ~ Z'~ WeII Attributes _ ~Max Mgle & MD ;TD ~' ~y WellboreAPUUWI FieltlName 'WeIlStatus Incl(°) MO~ftKB) ActBtrn(flKB) ~ 500292296060 .WESI SAK :PRODUCING ' 93J6 I 7,29451 7,407.0 . .. :_ ICommen~ IH2S(ppm) IDate IMnotation IEnd Date ,KB-Grtl (k) Rig Ralease Da~ ,._ wenc ng io~io2,s~^asoUeiqSaaanr~n _. SSSV.NONE I 0 1/1/2009 LastWQ Si3/2009 i 39.60 i 6/22/2000 .. .. Sdiem.e(k ncwal _. . ~ IAnnotauon Depin (HKB) End Date Mnotation Last Motl By ~End Da1e Last I ag~ Rev Reason: Workover, GLV C/O, set Pump Imostwr S174/2009 C8S1~ $t~lfl S ~ ~ HANGER. 31 ' . ~ Casing Descrip[ion String 0... String ID ... Top (HKB) Se~ Dapt~ (f... Set Dep~h (ND) ... String Wt... String ... String Top ThM ~coNOUCi ~ ~ ~e I W~NDOW 7 ~~ 6.151 4,368.0 4,383.0 3,56).3 _ ~ Casing Description String 0... 'IString ID ... Top (HKB) Se~ Dapth (f... Set Depth (ND) ... String WI... Str ng _. String Top ThN ' 'D-SANOLWER 4V2 3.958 4,369.3 7,393.0 3,6476 12.60 L-80 BTCMOD oR. `~ ~4 Sx4" 10 3 548 ~ i 60-110 . . ._.... ____- ._. . . _ . _ ....._ _ __- . _.. esa ° ~ Liner Details ___._ _. _.. - - MANDREL, ', Top Dep~h 2.501 ~ (ND) ToP In<I __ ~I Top (kK8) ~. ~hKB~ (°) ~ Item Dascription CommeM _ _ ID Si MnrvoRE~ ~ 4.645.9 3,663.9 75.03'ICMT VLV ~BAKER HMCV CEMENTING VALVE _ 3.B 3,~9 ~ ~, q,664J 3,667.9'~, 78J4!ECP :BAKERCTCISOZONEECP ~~~ 39', "~ ~~, 4,850.4: 3,690.5' 87.19IECP ~~BAKERCTCPAYZONEECP 3.9'. ~ o~scnarge. _. ___ ~ 4,907J 3,692JI 89.62~ KOIV VLV I BAKER KOIV KNOCK OUT ISOLATION VALVE ~ ~~ 3.9'. 3.586 - _ _ ._. .-__ -__. _ . .. nSSV, 3.sos-~-~~ ~R -= 4,942.0 3,692.9: 89.72 SLEEVE BAKER CMD SLIDING SLEEVE ~~ 3A~. PUMP. 3.fiM INTAKE. 3,6581~ 0,368-4,383 S/9/2008 JUNKVV••~.~~ -- ,4,363 - -- - -- - 6/17/2008- SURFACE. 6.175J.929 Saeen, 4,925~],35] N8 SAND ~INEft 4.Sx6', E.7]8-7.357 TD (1 D-10P), 7.378 Alaska U, 1D-102L7 I7/li _L B-SAND (1D-1( iMMI INI('ATInN = Com ent thru screens m _ . _ _... __. _. . . -_.. _ . . . -_ Port OD I ~ Valve I Latch Size TRO Run Make Modal (iN ` Sarv ~~ Type Typ (in) (ps{) Run Date Can... amco ~~.KBG2-iR 1IESP ~IDMY IBK-5 ~0.000~~ 005/2l2009 I C~na-c+~Ph~#lips Time Log & Summary 6YedJview Web Reporting Re po rt Well Name: 1 D-102 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/30/2009 10:30:00 PM Rig Release: 5/3/2009 6:00:00 PM 4/30/2009 2a hr Summarv Moved rig from 2K-22 to 1 D-102, spotted rig over well, bermed up, RU hardlines to kill tank and MI filter van, heatin 9.6 brine with LRS. 08:30 15:30 7.00 COMPZ MOVE TRNS P Move rig from 2K pad to 1 R turn off. Pull off to side road and let Doyon 15 Cam ass. 15:30 17:00 1.50 COMPZ MOVE TRNS P Continue to move rig from 1 R turn off to KOC CPF 1. 17:00 19:00 2.00 COMPZ MOVE OTHR P Stand by with crews at KOC for field wide chan e out. 19:00 2130 2.50 COMPZ MOVE TRNS P Cont moving rig from KOC to 1 D Pad. 21:30 22:30 1.00 COMPZ MOVE PSIT P Spot rig over well, levei up, install Handy Berm. Accepted Nordic Rig 3 at 22:30 hrs on 4/30/2009 22:30 00:00 1.50 COMPZ RPCOM RURD P Spot tanks and mudshack, start RU hardline from rig to kill tank and filter van, spot LRS and start heating 9.6 brine for well kill. 5/01 /2009 Tested hardline to kill tank, RU circ lines in cellar, pulled BPV, reverse circ 200 bbls hot 9.6 brine down IA, shut in IA and bullheaded 100 bbis down tbg, installed BPV, ND tree, NU BOP, tested all BOPE at 250/3,000 psi, pulled blanking plug and BPV, MU landing jnt, pulled hange rto floor and LD, POOH stand back 4 1/2", s oolin u ESP cable. 00:00 01:00 1.00 COMPZ RPCOM RURD P Cont RU hardline to kill tank and filter van, heat brine, RU circ lines in cellar. 01:00 02:00 1.00 COMPZ RPCOM KLWL P RU lubricator and pull BPV, 280 psi on tb and annulus. 02:00 02:30 0.50 COMPZ RPCOM KLWL P Pressure tested hardline to kill tank at 250l3,000 si, ood test. 02:30 03:30 1.00 COMPZ WELCTL KLWL P Notified security and DSO of possible venting gas, pumped 160 degree 9.6 ppg brine down IA at 4 bpm, holding 280 psi backpressure on choke until fluid started up the tbg, had good fluid returns whi~e pumping a total of 200 bbls, shut down and shut in well, monitored for pressure, 0 psi on gauge, slight gas ca on bleeder. 03:30 05:00 1.50 COMPZ WELCTL KLWL P Off loaded remaining 80 bbls into pits, strapped kill tank (196 bbls), RU next vac truck, shut in IA and bullheaded 100 bbls down tbg, staging pump rate up to 3.5 bpm - FCP 560 psi. 05:00 06:30 1.50 COMPZ WELCTL OWFF P Shut down and shut in well, monitored for pressure, 0 psi on gauges but stiil a slight gas cap, opened tree, well dead, instailed BPV. 06:30 07:30 1.00 COMPZ WELCTI NUND P ND and inspect tree, install blanking lu . 07:30 09:30 2.00 COMPZ RPCOM OTHR P Spot crane and remove ESP cable spool and replace with empty spool for ullin com letion. 09:30 14:00 4.50 COMPZ WELCTL RURD P NU 13 5/8" BOPE w/11" DSA and w/ 2 7/8" x 5 1/2" variable rams in both u er & lower i e rams. 14:00 17:00 3.00 COMPZ WELCTI BOPE P RU test equipment, function and PT BOP rams, choke manifold and annular to 250/3000 psi. Witnessing of test waived by AOGCC (Bob Noble 15:30 hrs on 4-30-2009. 17:00 18:00 1.00 COMPZ RPCOM PULL P Pull BPV, set isolation sleeve. MU landin 't in han er. BOLDS. 18:00 18:30 0.50 3,701 3,671 COMPZ RPCOM PULL P Heat wellhead w/steam. Unland tubing hanger w/150k, pulled hanger to floor up wt 90K. Break out penetrators, LD hanger and landing ~t. 18:30 00:00 5.50 3,671 1,660 COMPZ RPCOM PULL P POOH standing back 4 1/2" tubing, spooling up ESP cable and heat trace from 3,701' to 1,660' 5/02/2009 Cont POOH stand back 4 1/2" tbg, RIH with test packer to 4,150' and test 7 5/8" csg, POOH LD packer and DP, stand back tb , MU new ESP um assembl , RIH with 4 1/2" IBTM ESP com letion to 1,380'. 00:00 03:30 3.50 1,660 54 COMPZ RPCOM PULL P Cont POOH with 4 1/2" ESP completion from 1,660' to pump assembly, hole taking 10 to 11 bph, had dama ed cable at MLE. 03:30 06:30 3.00 54 0 COMPZ RPCOM PULD P Cut cable, test motor (bad test indicating grounded), obtain oil samples, break down pump assembly, bottom of motor had oily water, top section had burnt oil, cross over on coupling is good, clean and box up for shipping, clean rig floor, all SS bands and cannon clamps accounted for, wrap used ESP cable for shipping. Set wear rin . 06:30 08:30 2.00 0 1,624 COMPZ RPCOM TRIP P RU tools for running RBP & packer. PU, MU RBP & Retrievamatic packer, 18 jts of 3 1/2' drillpipe and RIH on 4 1/2" IBT tubing from derrick to 1624'. 08:30 09:30 1.00 1,624 1,624 COMPZ RPCOM OTHR P Shut down, RU crane and swap out ESP cable s ools. 0930 12:00 2.50 1,624 4,147 COMPZ RPCOM TRIP P Contine to RIH w/ w/ RBP & packer to 4147'. Set retrievamatic packer. Hole still taking approximately 10 , + ~ . 12:00 13:00 1.00 4,147 4,147 COMPZ RPCOM PRTS P Pressure test IA to 2500 psi and chart for 30 min. ood test. 13:00 16:30 3.50 4,147 0 COMPZ RPCOM TRIP P Release Retrievamatic Packer @ 4147'. POOH standing back 4 1/2' IBT tubing and laying down 3 1/2" drill i e. 16:30 19:00 2.50 0 45 COMPZ RPCOM RCST P Pull wear ring. RU tools and rig floor for running ESP completion. PU motor and seais and service both. 19:00 00:00 5.00 45 1,380 COMPZ RPCOM RCST P PJSM, RIH with 4 1/2" IBTM ESP completion, to 688', MU heat trace, cont RIH testing ESP cable every 1,000', to 1,380'. 5/03/2009 Cont RIH w 4 1/2" IBTM ESP completion, MU hanger and landing joint, splice ESP and heat trace, landed hanger, RILD's, tested void, LD landing jnt and installed 2 way check, ND BOPE, NU and tested tree, pulled 2 wa check, freeze rotected well, set BPV, ulled ri off well, cleaned well site. 00:00 06:00 6.00 1,380 3,665 COMPZ RPCOM RCST P Cont RIH with 4 1/2" IBTM ESP completion checking integrity every 1,000', to 3,633' MU hanger and landin 'nt. 06:00 09:00 3.00 3,665 COMPZ RPCOM HOSO P Splice ESP cabie and heat trace to enetrators. 09:00 09:30 0.50 COMPZ RPCOM HOSO P Drain stack, Land hanger. RILDS. Test ackoff /void 5000 si. 09:30 11:30 2.00 COMPZ RPCOM NUND P Pull isolation sleeve. Set Two-way check. ND BOPE. 11:30 12:00 0.50 COMPZ RPCOM OTHR P Checked the ESP cable/motor electrical integriry and megger the Heat Trace and record same. RD both cabie s oolers. 12:00 13:00 1.00 COMPZ RPCOM NUND P NU tubing head and adapter and tree. Test tree to 5000 psi. Test hanger void/packoff to 5000 psi. Puil two-wa check. 13:00 15:30 2.50 COMPZ RPCOM FRZP P Freeze protect the weli by pumping 40 bbls diesel down the tubing and 70 bbls down the IA. 15:30 16:30 1.00 COMPZ RPCOM OTHR P RU lubricator and set Vetco-Gray 4" H-BPV in tubing hanger profile, SITP = 400 si, IA = 400 si. 16:30 18:00 1.50 COMPZ RPCOM RURD P Pull rig off the well, remove mat boards, clean cellar box and tree. Released Nordic Rig 3 at 18:00 hrs on 5/3/2009 • STATE OF ALASKA .~ . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT '~ ~~~ ~°n~• ~o~Is 1381On 1. Operations Pertormed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnocOPhillips Alaska, Inc. Development ^~ Exploratory ^ 200-076 /' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22960-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 30.5' r 1 D-102L1 ' 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field !West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 7407' feet true vertical 3647' feet Plugs (measured) Effective Depth measured 4363' feet Junk (measured) true vertical 3555' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 13-3/8" 110' 110' SURFACE 4074' 7-5/8" 4175' 3439' PRODUCTION 754' 7" 4929' 3752' LINER 3025' 4.5" x 4" 7393' 3648' Perforation depth: Measured depth: perfs thru screens 4999'-7393' true vertical depth: 3693'-3648' ~,~~ pp~~g~ ~~pp gtlttQ ~~i1V11111~V ~~L ~. 2008 Tubing (size, grade, and measured depth) tbg in 1 D-102, , MD. Packers &SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 348 - 17 280 - 188 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Pack r Signature ~~ e~~~~~~„~ Title Phone: 265-6845 Wells Group Engineer /' Date ~ ~ 6 ~ P ared b Sh ron Al su Form 10-404 Revised 04/2006 ~ ~ G ~ ~ A L 5 ~~ '~~~- ~ #~ ~~Q~ Submit Original I ~,J 1 r7" • 1 D-102 Post Workover • DATE SUMMARY 5/17/08 ATTEMPTED TO SET 46' TTC ESP PUMP . UNABLE TO GET PUMP PAST 3640' SLM. REMOVED PUMP FROM WELL AND NOTICE VISIBLE SCRAPE MARKS THE LENGTH OF THE PUMP. IN PROGRESS. 5/18/08 SET 4 1/2 TTC ESP PUMP (46' OAL )@ 3649' RKB. SET 4 1/2 D&D PACKOFF ASSEMBLY W/ KOBE AND CHECK VALVE (100.5" OAL) IN TOP OF PUMP @ 3603' RKB. PULLED DGLV AND SET 2000 PSI TBG. SHEAR VALVE @ 3506' RKB. TESTED PACKOFF AND SOV TO 1000 PSI (GOOD TEST ). (( DID NOT INSTALL SLIP STOP )). JOB COMPLETE. ~- -.. ~ !4 \ ~Csrtolcol~~!lips =asks, Ir1o. '. ~.vPu s~nt~,~o;.- HANGER 26 _~ ~- CONDUCTOR, 0.110 ESP DISCHARGE, 3,560 PACKOFF ASSV, 3,595 PUMP, 3,803 XO W/INTAKE, 3,649 ESP SEAL, 3,fi66 ESP MOTOR, 3,662 ESP GAUGE, 3,fi99 CENTRALIZER, 3,701 r 7 j 4,{ f L SURFACE, 0-0,176 WINDOW, 4,368-0,363 WINDOW, 4,368-0,383 ( I~ JUNK, 4,383 SURFACE, 4,176-0,929 L1 UPPER LINER, 4,368-0,999 LI LOWER LINER ~,~\~ 4,999-7,393 ~ J , { , TD (1 D-102L1), 7,407 ' •KUP 1D-102L1 PI I UWI Field Name Well J[a[us Maximum Incllnatlon (`) I OWI Depth (ttkfi) D02922960 WEST SAK PROD 93.76 7407.0 omment H2S (ppm) Date Annotatl... Entl Date KB-Ground Distance (ft) Rig Release Dale SSV: NONE Last WO: 5/9/2008 39,60 6/222000 nnotation Depth (RKB) Entl Date Annotation - End Date ast Tag: 4,363.0 5/4/2008 Rev Reason: FORMAT UPDATE 6/18/2008 - ® _ ~. m . sing Description OD (In) ID (in) Top (ttKB) Set Dep[h (ttKtl) Jet Depth (I VU) (ttKB) Wt (Ibs/tt) Grade (Op COnneCtfOn lINDOW 7 6151 4,368.0 4,383.0 3,567.3 asing Description OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (ND) (ttKB) Wf (Ibs/ft) Grade Top Connection 1 UPPER LINER 41/2 3.958 4,368.0 4,999.0 3,693.1 12.30 L-80 BTC-MOD asing Descriphon OD (in) ID (in) Top (RKB) Set Depth (ftKe) Set Depth (ND) (RKB) Wt (Ibs/ft) Gratle Top Connection 1 LOWER LINER 4 3548 4,999.0 7,393.0 3,647.6 9.5n L-80 HSLHT ".. e ~ .. _ Shot I Galcul... . Btm Top (ND) Btm (ND) Dens Shot op (RKB) (ftK8) (RKB) (RKB) Type Zone (sho... Total Date Comment 4,999.0 7,393.0 3,693.1 3,647.6 SCREEN WS D,. 50.0 7/12/2000 ~ Perfs thru screens 1D-102L1 ~ ~ End D ate Annotation Yelve Latcn Port TRU RUn Make Motlel OD (in) Type Type (Size (in) (pal) Run Date Comment r~ ConocoPhiiiips Time Log Summary Welh7eyv Web ReD°rting Well Name: 1 D-102 Job Type: RECOMPLETION Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/27/2008 08:00 09:30 1.50 MIRU MOVE OTHR NP Standby w/ crews while waiting on hi hline ower to ri down. 09:30 14:00 4.50 MIRU MOVE MOB P Move rig from 1J-174 to 1D-102. 4 miles, derrick down. 14:00 15:00 1.00 MIRU MOVE RURD P MIRU, spot & level rig over 1D-102. ACCEPT NORDIC RIG 3 THIS DATE 1500 HRS 15:00 17:00 2.00 COMPZ RPCO RURD P Spot misc. rig equipment. 17:00 18:30 1.50 COMPZ RPCOh NUND P R/U lubricator and pull BPV. 350 psi on Tb & IA. 18:30 00:00 5.50 COMPZ RPCOti OTHR P Flush lines & clean pits w/ filtered seawater in re for filtered brine. 04/28/2008 00:00 01:00 1.00 COMPZ RPCO CIRC P Take on 255 bbls hot filtered seawater w/ 6% KCL to rig pits. RU tree lines for well kill. Plumb to kill tank /all related a ui . 01:00 03:00 2.00 COMPZ RPCO CIRC P PT hard lines to 2500 psi. Vent gas off tbg & IA. Reverse circ. 255 bbls hot filtered seawater w/ 6% KCL down annulus taking returns out the tubing. Good returns. Shutdown w/ 140 psi on tbg & IA. Calc'd KWF to be 9.5 03:00 04:00 1.00 COMPZ RPCO CIRC P Load pits w/ filtered 9.6 ppg brine w/ 6% KCL. 04:00 06:30 2.50 COMPZ RPCO CIRC P Reverse in 9.6 ppg filtered brine w/ 6% KCL at 3 bpm. ICP = 220 psi, FCP = 160 psi. Still seeing some diesel/crude in returns. Cont circ clean 4 b m / 260 si. 06:30 07:30 1.00 COMPZ WELCT OWFF P Monitor well pressures, confirm well dead. "O" psi tbg /annulus. Well on vac. 07:30 09:30 2.00 COMPZ RPCOti NUND P PJSM, Set BPV, ND prod tree. 09:30 10:30 1.00 COMPZ RPCOh PULD P PJSM, Place ESP spools /equip to ri floor. 10:30 14:30 4.00 COMPZ RPCOh NUND P PJSM, NU BOPE, all related equip. C/0 lower pipe rams to 4-1/2" because no test joint on hand yet for 2-3/8". 14:30 21:30 7.00 COMPZ WELCT BOPE P PJSM, test BOPE to 250/2500, all components, all floor safety valves. BOP test witnessed by Chuck Sheve-AOGCC. Perform time / volume / ress test to accumulator. ~~ Page 1 of 1fl Time Logs Date From To Dur S De th E. De th Ph se Code Subcode T COM 04/28/2008 21:30 22:30 1.00 COMPZ RPCOh PULD P Pull blanking plug, pull BPV & install side isolation sleeve. 22:30 23:00 0.50 COMPZ RPCO PULD P PU landing jt. & attach pup, BOLDS. Pull hanger free w/ 180K Ibs (35K block wt . 23:00 00:00 1.00 COMPZ RPCOh PULD P Pull hanger to rig floor, 95K up wt. Test ESP & heat trace penetrators and lower connectors. Cut connector & s lice. La down han er 04/29/2008 00:00 01:00 1.00 COMPZ RPCOh CIRC P RU to tubing and circ bottoms up @ 5 b m, 160 si. 01:00 02:00 1.00 COMPZ RPCOh PULD P Attach ESP cable and Heat trace to s ools. RU to ull com letion. 02:00 12:00 10.00 COMPZ RPCOh PULD P Pulling ESP completion, standing back 4-1 /2" tubing, spooling up ESP cable and heat trace, removing clamps and bands. 12:00 13:30 1.50 COMPZ RPCO PULD P UD ESP Seals & Motor. 13:30 15:00 1.50 COMPZ RPCOh PULD P Clean and clear rig floor. RU to run BHA #1 and drill i e. 15:00 15:30 0.50 COMPZ RPCOh TRIP P Set wear ring. 15:30 17:00 1.50 0 294 COMPZ FISH TRIP P PU BHA #1, 5 3/4" Washpipe w/ 6.125" Shoe & VACS Tool., on 3 1/2" IF Drill Pipe. Total BHA Length = 294.35' 17:00 21:00 4.00 294 4,000 COMPZ FISH TRIP P Trip in hole with BHA #1 picking 3 1!2" drill i e sin les. RIH to 4000' MD. 21:00 22:00 1.00 4,000 4,000 COMPZ RIGMN SVRG P Service Top Drive. Change out saver sub. Set torque values for milling arameters. 22:00 22:30 0.50 4,000 4,177 COMPZ FISH TRIP P Continue TIH picking up DP singles from 4000', to tag on 'junk" at 4177' DPM. UP WT = 90K, SO WT = 73K. 22:30 00:00 1.50 4,177 4,177 COMPZ FISH MILL P Make up Top Drive. Obtain milling parameters. ROT WT - 80K. Pumps at 208 GPM's -1080 PSI. Tag & mill on "junk" at 4177', with 1-2K WOB, milling torque from 2-6K ft/Ibs, and 80 RPM's. Observed little or no success in gaining hole, with string stalling. Utilize MI Swaco filtration unit to filter returns pits at 2.5 - 5 BPM. Brine weight - 9.4 PPG. Total fluid losses for the da = 397 bbls. 04/30/2008 00:00 00:30 0.50 4,177 4,177 COMPZ FISH MILL P Continue mill on'junk". @ 4177' MD. ROT WT - 80K. Pumps at 208 GPM's - 1080 PSI, with 1-2K WOB, milling torque from 2-6K ft/Ibs, and 80 RPM's. Observed little or no success in gaining hole, with string stalling. Utilize MI Swaco filtration unit to filter returns pits at 2.5 - 5 BPM. Brine wei ht - 9.4 PPG. Decision to POOH. ~~e__~s_ Page 2 rsf Ott Time Lo s Date From To Dur 5 De th E. De th Phase Code Subcode T COM 04/30/2008 00:30 02:00 1.50 4,177 4,177 COMPZ FISH CIRC P Circulate bottoms up at 4 BPM - 1100 PSI. No gas, minimal fluid loss. Blow down To drive. Monitor well -static. 02:00 04:00 2.00 4,177 294 COMPZ FISH TRIP P POOH with BHA #1 from 4177' - 294'. Observed displacement 12 BBLS more than calculated. 04:00 05:00 1.00 294 0 COMPZ FISH PULD P Break out & lay down BHA #1. Inspect and guage shoe to 6.125". Make up BHA #2, with 6" milling shoe on wash i e. Total BHA len th = 293.0'. 05:00 08:00 3.00 0 4,292 COMPZ FISH TRIP P Trip in hole with BHA #2 on 3 1/2' DP from derrick to 4292'. 08:00 09:30 1.50 4,292 4,292 COMPZ RPCO OTHR P Change out ESP cable spool while crane available. 09:30 10:00 0.50 4,292 4,353 COMPZ FISH TRIP P Continued to RIH tagged @ 4353'. Up wt 95K Dwn 75K. 10:00 11:00 1.00 4,353 4,353 COMPZ FISH MILL P Attempt to circulate down, unsuccessful. PU est. rotation, attempt to work past tag depth 4353'. ROT 80 RPM Up wt 95K Dwn wt 75K, ROT wt 82K. Stopped rotation, attempt to push down by putting 10K on obstruction, unseccessful. 11:00 11:30 0.50 4,353 4,353 COMPZ FISH CIRC P Circulate hole clean. 11:30 13:00 1.50 4,353 0 COMPZ FISH TRIP P POH with BHA #2. 13:00 15:00 2.00 0 0 COMPZ RPCO TRIP P UD BHA #2. Cutting edge of 6"shoe worn down smooth. 15:00 18:00 3.00 0 4,359 COMPZ FISH TRIP P PU 2 3/8" mule shoe, 2 jts 2 3/8" tubing, bumper sub and jars on 3 1/2" drill pipe, RIH. Tagged solid @ 4359'. Rotate mule shoe 1/2 turn attempting to work buy bad spot with no success. PU 6', kicked pump on and tried to wash down with no success. 18:00 21:00 3.00 4,359 336 COMPZ FISH TRIP P Breakout & blowdown TD. Monitor well - static. POOH from 4359' - 336'. 21:00 22:00 1.00 336 0 COMPZ FISH PULD P Lay down BHA. Inspect mule shoe. Obtain pictures. No damage observed. SIMOPS: RU Halliburton Slickline unit. 22:00 00:00 2.00 0 0 COMPZ FISH SLKL P Held PJSM. Discuss safety & hazard issues. make up Halliburton Slickline sheaves. MU 5.9" Lead Impression block assembly. WLIH to tag @ 4359' WLM. Tap LIB with spangs one time. WLOH. Inspect LIB, obtain pictures.L16 indicated setting down on pipe. Total Fluid loss for the day = 187 BBLS. 05/01/2008 00:00 01:00 1.00 0 0 COMPZ FISH SLKL P Rig down Slickline sheaves & unit. Clean & clear floor area. 01:00 02:30 1.50 0 0 COMPZ EVAL WOEQ P Load pipe shed with ESP completion equipment, while wait on Halliburton E-line Video unit & e ui ment. Page 3 ~af'itt Time Logs D e From To Dur S. Depth E. De th Ph e Code Subcode T COM 05/01/2008 02:30 04:30 2.00 0 4,359 COMPZ EVAL TRIP P Decision to TIH with mule shoe assembly to circulate and attempt to clean wellbore fluid for video run. Utilize MI filtration unit on location. TIH to to at 4359' PU 3 ft. 04:30 06:30 2.00 4,359 4,359 COMPZ EVAL CIRC P Circulate at 84 GPM's -100 PSI. Stage pump rate up to 296 GPM @ 820 psi. Run returns through filtration unit, and pump cleaner fluid into well bore. Well bore fluids clean for running Haliburton down hole video. 06:30 08:30 2.00 4,359 0 COMPZ EVAL TRIP P POOH from 4359' standing back drill pipe, laying down bumper sub, jars and muleshoe. 08:30 12:00 3.50 0 0 COMPZ EVAL ELOG ND riser from to of BOP stack. NU shootin flan a for wireline lubricator. 12:00 18:30 6.50 0 0 COMPZ EVAL ELOG P PJSM , RU Haliburton Wireline unit for running video. Ran video to top of obstruction @ 4353 wireline measurements. Results not conclusive enough to make determination on what is in hole @ 4353'. WLOH, lay down camera assembl . 18:30 00:00 5.50 0 0 COMPZ EVAL ELOG P Rehead, and change out spools on Eline unit. Make up Gyro data assembly. Troubleshoot communication issues. There was a voltage issue, suspecting trouble with the 30,000 ft of line on spool. Total fluid loss for the da = 47 BBLS 05/02/2008 00:00 02:30 2.50 0 0 COMPZ EVAL ELOG T Continue trouble shoot issues with communication to Gyro data assembly. No success. Decision to get Sperry Sun Gyro unit. Standby for unit to arrive. RD Eline truck to make room for next unit. 02:30 04:00 1.50 0 0 COMPZ EVAL ELOG T Spot & RU Gyro unit. MU Gyro Data assembl . 04:00 07:00 3.00 0 0 COMPZ EVAL ELOG P WLIH with Gyro Data assembl to 4350' WLM. Obtain data surveys. WLOH, la down assembl . 07:00 08:00 1.00 0 0 COMPZ EVAL ELOG P ND shooting flange. NU riser. 08:00 09:00 1.00 0 0 COMPZ EVAL TRIP P MU Baker 7 5/8" Retrievamatic. Move drill collars to off drillers side of derrick to et out of the wa . 09:00 11:30 2.50 0 4,083 COMPZ EVALV~ TRIP P RIH and set 7 5/8" Retrievamatic @ 4083'. UP WT = 85K, SO WT = 70K 11:30 18:00 6.50 4,083 4,083 COMPZ EVAL RURD P RU safety valves xovers etc to get to Eline BOP and lubricator. RU Schlumberger (Nitrogen) pumper and hardline. ~~g~ 4 of 10 I Time La s Date From To Dur S De th E. De th Phase Code Subcode T COM 05/02/2008 18:00 19:30 1.50 4,083 4,083 COMPZ EVALVI~ ELOG P WLIH with 1 11/16" camera to 2400' WLM @ 10-100 ft/min. Observed camera lens became covered with grease. Pump down drill string with SWS nitrogen, and observe 1250 PSI surface ressure. 19:30 20:00 0.50 4,083 4,083 COMPZ EVAL ELOG P WLOH. Shut in drill string. Bleed lubricator. Break off lubricator, and re lace camera lens. 20:00 22:00 2.00 4,083 4,083 COMPZ EVALIPo ELOG P Make up Lubricator, Pressure to equalize at 1350 PSI. WLIH to 3000' and observe camera lens once again blacked out covered in rease. 22:00 22:30 0.50 4,083 4,083 COMPZ EVALVI~ ELOG P WLOH. Shut in drill string. Bleed lubricator. Break off lubricator, and clean camera lens. 22:30 00:00 1.50 4,083 4,083 COMPZ EVALVI~ ELOG P Make up Lubricator, Pressure to equalize at 1380 PSI. WLIH to 3100' observing camera lens clear with no issues. Running speed from 10 100 ft/min. Surface pressure observed = 1420 PSI. 05/03/2008 00:00 03:00 3.00 4,083 4,083 COMPZ EVAL ELOG P Continue WLIH with 1 11/16" Video camera assembly from 3100' - 4351' WLM. Observed clean lens, and nitrogen pressure at surface =1680 PSI. Observed with camera that there is a 3" "ring" from the 6" milling shoe hung in the 7" casing collar at 4351' WLM. We could not see very far past the ring, and did not observe any collapsed casing or further obstruction. Repeat attempts to get camera beyond the ring, with no success. Pull back up hole and obtain good video of the transition from 7 5/8" casing to 7" casing. WLOH with camera. 03:00 03:30 0.50 4,083 4,083 COMPZ EVAL ELOG P Shut in the drill string with camera in the lubricator. Bleed lubricator pressure. Breakout & lay down assembly. Breakout and rig down Schlumber er nitro en crew. 03:30 04:30 1.00 4,083 4,083 COMPZ EVAL RURD P Breakout crossover above pump in sub. Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to bleed pressure, and release packer. Rig up and make up Top drive to drill string. Pump down drill string 40 BBLS to kill well. Pick up drill string to observe packer valve equalized and open. Immediate returns in the annulus. F'agz-~a ~sf 1Q Time Logs Date From To Dur S De th E. De th P Subcode T COM hase Code 05/04/2008 03:15 03:45 0.50 0 0 _ COMPZ _ FISH PULD P Clean & clear floor area. Pull tools to rig floor. Held PJSM with crew & fishin tool re . 03:45 04:45 1.00 COMPZ FISH PULD P Make up BHA #6, 6" Milling shoe with 1 joint of 5 3/4" washpipe & boot baskets. 04:45 07:15 2.50 0 4,177 COMPZ FISH TRIP P Trip in hole with BHA #6. Observed ro er dis lacement. 07:15 08:00 0.75 4,352 4,352 COMPZ FISH TRIP P Tagged up on Sperry Alignment Tool @ 4177', worked thru with 20K overwt. continued on and tagged up @ 4351.5'. 08:00 10:00 2.00 4,352 4,353 COMPZ FISH MILL P Milled on obstruction from 4351.5' to 4353'. Up wt 90K Dwn wt 74K Rot wt 83K Free Torque ZK, ROT Torque 3K to 5K max. Returns showing signs of cement, scale and ossibl formation. 10:00 11:00 1.00 4,353 4,353 COMPZ FISH CIRC P PU to 4345' circulated hole clean. 11:00 14:00 3.00 4,353 0 COMPZ FISH TRIP P POOH standing back drill pipe and drill collars. LD BHA. 14:00 15:00 1.00 0 0 COMPZ FISH OTHR P Load out fishing tools for shipping back to sho . 15:00 17:00 2.00 0 0 COMPZ RPCOh RURD P Clean rig floor and prep tools for running ESP completion. Hang Sheave. 17:00 00:00 7.00 0 0 COMPZ RPCO RCST P Held PJSM. Discuss safety & hazard recognition issues. Pick up Motor , Phoenix gauge, Tandem Seal section. Fill motor with oil, ensure good rotation of motor. Continue MU ESP assembly attaching control line to discharge sub. Megger test line, continue RIH with completion on 4 1/2" tbg string in derrick. Total fluid loss for the da = 3 BBLS. 05/05/2008 00:00 04:30 4.50 0 1,063 COMPZ RPCO RCST P Continue run ESP completion on 4 1/2" tbg string in derrick. Inistall GLM's as er detail. 04:30 10:00 5.50 1,063 1,063 COMPZ RPCO RCST T Observed ESP cable hung up in slips, and damaged the armor and wires. Pick u ,ins ect. Make news lice. 10:00 12:00 2.00 1,063 1,886 COMPZ RPCOh RCST P After splice, check electrical on cable, heat trace, and Phoenix Guage. Continue in hole with ESP on 4 112" tb strin from derrick.to 1886'. 12:00 19:30 7.50 1,886 3,655 COMPZ RPCOh RCST P Continue RIH with ESP completion to 3655'. UP WT = 95K, SO WT = 72K Observed ro er dis lacement on TIH. 19:30 20:30 1.00 3,655 3,655 COMPZ RPCO RCST P Make up landing joint & hanger. Ru to s lice ESP cable. Page 7 of 1a f ~ Time Logs _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 05/07/2008 17:00 20:00 3.00 122 1,063 COMPZ RPCOh RCST T Rih w! 4 1/2 ESP Completion f/ 122' to 815'. Start heat trace, bottom of heat trace will be @ 2899' when landed. Continue to Rih to 1,063' 20:00 00:00 4.00 1,063 1,063 COMPZ RPCOh OTHR T Splice ESP Cable 05/08/2008 00:00 00:30 0.50 1,063 1,063 COMPZ RPCOti OTHR T Test Electronics for continuity 00:30 09:00 8.50 1,063 3,655 COMPZ RPCOh RCST T Continue to Rih from 1,063' w/ 41/2 ESP Com letion to 3655'. 09:00 10:00 1.00 3,655 3,655 COMPZ RPCO HOSO T PU hanger and MU landing jt. RIH,get measurements on ESP cable, 5' short from cuttin while RIH. 10:00 12:30 2.50 3,655 3,655 COMPZ RPCO HOSO T Laydown landing jt, hanger & pup. Remove top jt 31' jt, replace with 2 - 10' - 4 1/2" IBT pups jts. PU hanger and landin 't. Lower into well. 12:30 16:00 3.50 3,655 3,677 COMPZ RPCOM1 HOSO T Install Penetrators in hanger. Perform splicing operation on ESP cable and heat trace to pig tails. Re-test ESP cable and heat trace. Monitor well - static. Land hanger. Up wt 90K Dwn wt 70K Ran a total of Protectorlizers -3, Stainless Steel Bands - 19, Single Channel Xcoup.- 20, 5' Dual Channel Mid jt coup - 446, Dual Channel Xcoup - 92, 2' Dual Channel Mid jt coup - 3, 3' Dual Channel Mid jt coup - 2, and 4' Dual Channel Mid 't cou . 2. 16:00 17:00 1.00 COMPZ RPCO HOSO T RILDS, test hanger to 5000 psi. ND landin 't. Set TWC. 17:00 19:00 2.00 COMPZ RPCO NUND T ND ROPE. Set back 13 5/8 BOP out of the way and secure. 24 hr Notice was given to AOGCC for 1 D-134 18:45 hrs on 5-8-08 19:00 20:00 1.00 COMPZ RPCO DHEQ P Test ESP cable, Heat Trace and Downhole Gauges through the Penetrators. All tested ood. 20:00 21:30 1.50 COMPZ RPCO NUND P Set 13 5/8 BOP back on well and break stack. Remove Choke side and Rack back 13 5/8 BOP. 21:30 22:30 1.00 COMPZ RPCOh DHEQ P Test through Penetrators again -test ood. 22:30 23:30 1.00 COMPZ RPCO NUND P Set and NU Tree. 23:30 00:00 0.50 COMPZ RPCOh SFEO P Test tree 250/5,000 psi 05/09/2008 00:00 01:00 1.00 COMPZ RPCOh SFEO P Continue to Test Void and Tree @ 250/5,000 si. 01:00 01:30 0.50 COMPZ RPCOh DHEQ P Test ESP Cable, heat trace and down hole au es -test ood 01:30 03:30 2.00 COMPZ RPCOh OTHR P RU Lubricator and Pull TWC. Lay down Lubricator 03:30 05:30 2.00 COMPZ RPCO FRZP P RU Little Red Services. Held PJSM. PT lines @ 2,500 psi. Pump 85 bbls diesel for Freeze protect. RD LRS. Allow well to U tube. ~~_v-~~. Page 9 of 1t~ ~~ r~ ~, Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 05/09/2008 05:30 08:30 3.00 COMPZ RPCOh NUND P Set Vetco Gray H-BPV. Clean cellar area and wellhead. RDMO. Release Nordic 3 ri 08:30 hrs 5-6-08 :image 30 0~ ~U 1\t\v 1L-1VG Regg, James B (DOA) l ~.- f r] ~~10 ~- t' t > rake i ui i From: Crisp, John H (DOA) [john crisp@alaska.gov] \~~ ~~ ~ i .~ I ~,; Sent: Sunday, May 04, 2008 1:14 PM To: Nordic 3 Company Man; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: KRU 1 D-102 Your reques# is granted. If for any reason your plans change please call AOGCC Inspectors fior a chance to witness BOP test. Thanks. ~a0°- °'~ From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Sunday, May 04, 2008 12:09 PM To: aogcc_prudhoe_bay@admin.state.ak.us Subject: KRU 1D-102 As per our conversation. We are due a weekly BOP test on Monday May 5,2008. We will start our completion this afternoon approximately 3:OOpm and be landing completion sometime Monday afternoon. We would like to ask for a variance since we will be completing the well and nippling down the BOPE and moving to the next workover. Thanks, Rick Overstreet ConocoPhillips Nordic 3 Rig Supervisor 659-7446 5/5/2008 Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Operat. ShutdownD Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Service RECEIVED JAN 1 8 2006 Alaska Oil & Gas Cons. Conn O Anehorago Other Time Extension 0 o Exploratory 0 o Re-enter Suspended Well 5. Permit to Drill Number: 200-076 1 6. API Number: 50-029-22960-60 P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 30.5' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING LINER Perforation depth: 9. Well Name and Number: 1 D-102L 1 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 7407' feet true vertical 3647' feet measured 7354' feet true vertical 3651' feet Length Size MD 80' 13-3/8" 110' 4145' 7-5/8" 4175' 754' 7" 4929' 3025' 4.5"x4" 7393' Plugs (measured) Junk (measured) TVD 110' 3439' 3752' Measured depth: pre-packed screens 5029'-7292' ~hNNE[) JAN 1 9 2005 true vertical depth: 3693'-3654' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4063' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Burst Collapse 13. Treatment descriptions including volumes used and final pressure: not applicable RBDMS BFl JAN 1 8 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 7~ ~9 27 518 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl 286 326 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature Jim Ennis @ 265-1544 ~ ~:nnis .~ f Title Wells Engineer Phone (9 G)) ). (, r -I j"- Y 'i ORIGINAL Form 10-404 Revised 04/2004 Casinç¡ Pressure Tubinç¡ Pressure 549 192 WDSPL 0 ::æd ~dA~":-DŒke 263-4612 Submit Original Only ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 3S Spud Date: 6/1/2000 End: 9/17/2005 Group: 6.75 MOVE RURD RIGUP Move camp from 1 C pad to 1 D and reconnect to generator and telecom. Layout Herculite for containment under rig. Continue to spot rig, pipe shed and pit module. 0.75 MOVE OTHR RIGUP Derrick sub spotted. While lowering sub stabilizers, rear stabilizer has pressed mat upwards into wellhead front casing valve, breaking ring gasket seal. Approx 1100 psi on annulus venting gas to atmosphere. Pull sub off well row out of hazardous area. Wind direction blowing away from equipment. Evacuate area, notify DSO, DSL T, Wells Coordinator, and Nordic 2 (further down pad) of situation. 1.00 WAlTON OTHR RIGUP Nipple up and bleed off annulus to production header. Note: reading once gauge was re-installed = 420 psi after approx 10 mins of bleeding, 185 psi header pressure). Rig up Hot Oil pump to tubing and jumper to tiger tank off rear casing valve. 0.50 WAlTON OTHR RIGUP Annulus pressure 220 psi- well still flowing (WHTP not appearing to fall any further). Hearlsee gas leak swapping to fluid, tighten up flange with hand tools. Leak stopped, few teaspoons of fluid spilled on ground. Call valve shop to VR install plug. 3.00 WELLSR OTHR RIGUP Plug installed; well secure. Conduct pre-job safety meeting. Replace rig mats and resume spotting rig. Security on site due to reports on bear on pad; suspend work until bear is located (off pad). Resume work. 8.50 MOVE RURD RIGUP Call PEAK back out. Get derrick sub spotted. Spot up pipe shed and pits. Tight fit (6"- 1 ') to adjacent wellheads. Build berms for kill tanks. Rig ready to raise derrick and scope up. 2.00 WAlTON WOW RIGUP Winds blowing @ 29 MPH gusting to 40 MPH. Waiting on wind to die down to raise derrick. 1.50 MOVE RURD RIGUP Winds calmed down to 24 MPH just below the limit. Raised derrik, scoped up and secured. Raise windwalls, tighten stablizer lines. Hook up flowlines, choke and killllines and stand pipe maifold. NU hard line and flowback tanks. Rig up LRS for pumping. Accept rig @ 2400 hrs 9/11/2005. 2.00 WELLSR PLGM DECOMP Accept rig @ 2400 hrs 9/11/2005. PU lubricator, pulled BPV 4.00 WELCTL KILL DECOMP Pre~ob safety meeting on well kill. Well press @ 450 psi. Start pumping seawater @ 125 deg 2.35 BPM 450 psi. Pumped 200 bbls seawater shut down had 100 psi on well. Switched to 9.6 ppg 3% KCL filtered brine. 125 deg 2.3 BPM 200 psi shut down monitor well 30 psi. Pumped another 50 bbls 5.00 WELCTL CIRC DECOMP Pump 50 bbls, SI to check press = 20 psi. Rig down Hot Oil Svcs pump and rig up to pump with the rig pump taking return to the pits. Come online circulating brine down tubing taking rtns up IA at 4 bpm, 510 psi circ pressure. 200 bbls away, shut down and monitor well. Bleed off residual pressure. 0 psi tbg IIA. Install back pressure valve. ND tree. Install plug off tool in lift threads. NU 11" BOPE State witness of BOP test waived by John Spaulding. Function test and PT BOP rams and choke manifold to 250 1 3000 psi, annular to 250 12500 psi. Dig and install mousehole. RU camera for spooler. NU TIW valve. Pull test plug. Retrieve BPV. Check well for press. static. Install side port isolation sleeve in hanger. MU landing jt and mark the pipe at the rotary table. Prejob safety meeting BOLDS. Unland tubing hanger, pulled loose at 90K. Up wt =65K. Pull hanger to rig floor. Cable connection on bottom of penetrator blown copper wire exposed. Filled hole, took 5 bbls to fill. Measured and recorded 9/11/2005 00:00 - 06:45 06:45 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 - 20:30 20:30 - 22:30 22:30 - 00:00 9/12/2005 00:00 - 02:00 02:00 - 06:00 06:00 - 11 :00 11 :00 - 12:00 1.00 WELLSR PLGM DECOMP 12:00 - 14:30 2.50 WELCTL NUND DECOMP 14:30 - 22:30 8.00 WELCTL NUND DECOMP 22:30 - 00:00 1.50 WELLSR PLGM DECOMP 9/13/2005 00:00 - 01 :00 1.00 WELCTL OBSV DECOMP I ! I 01 :00 - 03:15 2.251 FISH [PULL DECOMP Printed: 11/14/2005 2:28:32 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 38 Spud Date: 6/1/2000 End: 9/17/2005 Group: 9/13/2005 01 :00 - 03:15 2.25 FISH PULL DECOMP distance from the hanger to the mark on the landing jt. Lay down hanger. RU cable spooler. Start pulling out of hole standing back 4.5" tubing in derrick and spooling ESP cable. 03:15 - 05:00 1.75 FISH PULL DECOMP Start pulling out of hole standing back 4.5" tubing in derrick removing clamps and spooling ESP cable. 05:00 - 08:00 3.00 WAlTON EQIP DECOMP Tranformer for hydraulic pump blown on rig; power packlelectrician on way to to fix. NOTE: 3 HOURS OF DOWNTIME 08:00 - 12:00 4.00 FISH PULL DECOMP Continue pulling out of hole, racking back. 12:00 - 16:00 4.00 FISH PULL DECOMP Continuing to pull out of the hole with 4-1/2 completion. Hole stable/static. 16:00 - 20:00 4.00 FISH PULL DECOMP Pump equipment at surface; begin breaking pump equipment down laying it down. Inspection of pump shows partial collapse of housing at intake screens; screens collapsed as well). TCC x-over full of sand & what appears to be gravel. Lrg. (3/4"x1") rocks found in string - apears to be cement. 20:00 - 00:00 4.00 WAlTON EQIP DECOMP Wait on clean-out shoe from Baker and cossover form 4.5" NSCT to 3.5" IF 9/14/2005 00:00 - 06:00 6.00 WAlTON EQIP DEMOB Trouble locating crossovers ( BP tool services sent wrong x-over and Baker Fishing sent shoe that won't mate up to their x-over sub). Prep rig for clean-out run, install wear ring. 06:00 - 14:00 8.00 WELLSR TRIP WRKOVR Make up tools for cleanout run. Run in hole with 6" burn shoe on 4-1/2" NSCT production string I PH-6 drill pipe. Soft tag at 4353' orig RKB, set down 5k#. Pick up off tag approx 20'. Tested rotation, able to rotate freely at 1900#. Note: Removed front annulus valve (valve hit previously with rig mat) and replaced studs (slightly bent), ring gasket, inspect seal areas-good. Re-installed valve and tested against VR plug to 5k#-good. 14:00 - 16:00 2.00 WELLSR CIRC WRKOVR Rig up to rev-circulate. Begin pumping at 4.0 bpm taking rtns across shaker. Circulate 120 bbls around; watching for solids, none seen. Shut down. 16:00 - 21:00 5.00 WELLSR TRIP WRKOVR Begin POOH, rack back 4 stand of PH-6, lay dawn remainder. Rack back NSCT. 21 :00 - 22:30 1.50 WELLSR RURD WRKOVR Make up BHA retrievable bridge plug and test packer 22:30 - 00:00 1.50 WELLSR TRIP WRKOVR RIH wi BHA and 4.5" NSCT tubing 9/15/2005 00:00 - 03:00 3.00 WELLSR TRIP WRKOVR Continue in hole with test packer and RBP 03:00 - 04:30 1.50 WELLSR TRIP WRKOVR Continue in hole with test packer and RBP. 04:30 - 05:30 1.00 WELLSR PLGM WRKOVR Up weight 52K Down weight 38K. Set RBP (turn freely to set at 2200# of torque). Release from RBP. Lay down one joint of tubing. 05:30 - 07:00 1.50 WELLSR DEQT WRKOVR Rig-up head pin and prep to pt casing to 2500PSI 07:00 - 10:00 3.00 WELLSR TRIP WRKOVR Pressure up on annulus to 2500 psi. Bleeding off slowly. Locate slight leak on kill line, break apart and replace brass. Casing valve stem packing leaking, energize packing with grease gun. Pressure up again to 2500 psi; holdlchart for 30 mins- good test. Bleed off and prep to pull out of hole standing back. 10:00 - 17:00 7.00 WELLSRTRIP WRKOVR Begin pulling RBP/test packer standing pipe back in the derrick. Hole stable, cont to pump across the top while pulling out of hole. 17:00 - 18:00 1.00 CMPL TN RURD CMPL TN At surface; lay down RBP/packer assembly and begin prepping to run new ESP completion. 18:00 - 19:00 1.00 CMPLTN RURD CMPL TN Make up running tool and pull wear ring. 19:00 - 22:00 3.00 CMPL TN PULD CMPL TN Rig up to run ESP motor assembly. 22:00 - 00:00 2.00 CMPL TN PULD CMPL TN Pick up motor centralizer/phoenix sensorlesp motorldual seal sectionlTCC crossover. 9/16/2005 00:00 - 05:00 5.00 CMPL TN PULD CMPL TN Finish making ESP BHA as per procedure 05:00 - 08:00 3.00 CMPL TN RUNT CMPL TN RIH wi 4.5" ESP completion string Printed: 11/14/2005 2:28:32 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 0-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 38 :::Sû'i:i: ¡~qÇ1:ª: 1.00 CMPL TN RUNT CMPL TN Stop running completion in order to rig up to run heat trace. Begin heat trace 35' down on stand #17 placing bottom of heat trace at 2995' orig RKB. 2.00 WAlTON ORDR CMPL TN Shut down to address clamp issue. All 2" cross clamps of on locationand in stock are "back- wards" meaning they would have to be flipped over and pinned from underneath if run. Attempt to locate correct clamps. Confer with WIO Engineer I Centrilift on options. Continue RIH with completion. Note: Clamps being run as per program, however, 2' cross clamps being run upside-down. Well stable. Seal area dinged on bottom of stand #31, remove from string. Continue running in the hole. Continue in hole with 4.5" ESP completion string with heat trace to 4121. Make up hanger assembly. Perform final test on ESP and heat trace line. Set penetrators. Make final splice of ESP cable and heat trace to penetrators. Heat trace splice complete. Centrilift having difficulties making their splice. Centrilift has figured out how connector works; complete splice. Wash out stack and pump out through annulus valve. Land hanger with iso sleeve installed and RLDS. Test upper and lower hanger seals to 5k#- good. Remove ¡so sleeve and install 2-way check. Begin Nippling down BOP stack Bop stack layed down; perform heat trace and power cable conductivity test. Nipple up tree. Test heat trace and ESP cable Test well head void and tree to 5000psi Pull two way check. Install BPV. Secure well. Release rig @ 22:00 on 9/17105 (1 D-1 02) Prep rig to lay down derrick 9/16/2005 08:00 - 09:00 09:00 - 11 :00 11 :00 - 17:00 6.00 CMPL TN RUNT CMPL TN 17:00 - 00:00 7.00 CMPLTN RUNT CMPL TN 9/17/2005 00:00 - 03:00 3.00 CMPL TN RUNT CMPL TN 03:00 - 04:30 1.50 CMPL TN RURD CMPL TN 04:30 - 06:00 1.50 CMPL TN RURD CMPL TN 06:00 - 09:30 3.50 CMPL TN RURD CMPL TN 09:30 - 10:00 0.50 CMPL TN RURD CMPL TN 10:00 - 11 :45 1.75 CMPL TN RURD CMPL TN 11 :45 - 13:00 1.25 WELLSR PLGM CMPL TN 13:00 - 17:45 4.75 WELCTL NUND CMPL TN 17:45 -18:15 0.50 CMPL TN DEQT CMPL TN 18:15 - 19:30 1.25 WELLSR NUND CMPL TN 19:30 - 21 :00 1.50 CMPL TN SEQT CMPL TN 21 :00 - 22:00 1.00 WELLSR PLGM CMPL TN 22:00 - 00:00 2.00 MOVE RURD MOVE Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 38 Spud Date: 6/1/2000 End: 9/17/2005 Group: Printed: 11/14/2005 2:28:32 PM ) ) . .. . .., . . . "' . ". . . .... .... ....... :. ¢QnqcoÞhillips¡Ala$k~ .:.. .... . ..... . ... .......... .' ..' . . .... -. '. . .. . .. . . . ... ... .. . . . ..... . .._. . . . .. ... .... ..". '." ....... ... ............ .... . .. . . ...:¡ !(þp~r~ti¡~H$¡:~ Llrnm~~!R~pö.-t: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S . ·From!+TO iHoursCods' :~~dbe · pha$~<: 12/24/2005 13:30 - 20:30 7.00 MOVE RURD MOVE 20:30 - 22:30 2.00 MOVE MOVE MOVE 22:30 - 00:00' 1.50 MOVE RURD MOVE 12/25/2005 00:00 - 06:00 6.00 MOVE RURD MOVE 06:00 - 09:00 3.00 MOVE RURD MOVE 09:00 - 10:00 1.00 MOVE RURD MOVE 10:00 - 12:00 2.00 WELLSR PLGM DECOMP 12:00 - 18:00 6.00 WELLSR RURD DECOMP 18:00 - 00:00 6.00 WELCTL CIRC DECOMP 12/26/2005 00:00 - 06:00 6.00 WELCTL NUND DECOMP 06:00 - 10:30 4.50 WELCTL NUND DECOMP 11:30-16:00 4.50 WELCTL BOPE DECOMP 16:00 - 18:00 2.00 WELCTL NUND DECOMP 18:00 - 00:00 6.00 FISH PULL DECOMP 12/27/2005 00:00 - 01 :30 1.50 FISH PULL DECOMP 01 :30 - 06:00 4.50 FISH PULL DECOMP 06:00 - 16:30 10.50 FISH PULL DECOMP 16:30 - 18:00 1.50 FISH PULL DECOMP 18:00 - 00:00 6.00 CMPL TN RUNT CMPL TN 12/28/2005 00:00 - 08:00 8.00 CMPL TN RUNT CMPL TN 08:00 - 15:30 7.50 CMPL TN RUNT CMPL TN 15:30 - 16:30 1.00 CMPL TN RUNT CMPL TN I i I 16:30 -17:30 1.00 i CMPL TN; RUNT CMPL TN I : I 17:30 - 20:30 3.00 i CMPL TNI RUNT CMPL TN ! 20:30 - 00:00 3.50: CMPL TN'; RUNT CMPL TN I ! I I Spud Date: 6/1/2000 End: Group: Start: 12/24/2005 Rig Release: 12/29/2005 Rig Number: 3S ...... ..... . . ........ ,",.........."... . '" .. . . ... ..... , .. . . .' .. .. . . ... . .. .. ..... . .......... . . . ![)~~9~ìþtl()n ¡of.C)þøratì()n~·' . Rig released from 1 D-137 start to de-mob. Move rig from 1 D-137 to 1 D-1 02 Spot rig on 1 D-1 02 and begin to rig up Rig up over 1D-102; raise mast. Crew change. Telescope out derrick and continue rig up. Begin nippling up kill line to tree, move lubricator to rig floor to pull BPV. Accept rig at 9:00 am, 12/25/05. Pull BPV. Having difficulties with lubricator. Waiting on brine from M-I (apparently having problems filtering). Rig up cablelheat trace sheaves, move tubing into pipe shed, repair rig heaters, etc. Circulate SW down tubing back up OA 290 bbls @ 3.25 BPM 610 psi. Holding 500 psi on OA. Continue circulating in Kill WT brine 9.6 ppg hole volume 170 bbls. Taking returns to tiger tank. Pumped 24 bbls bullheaded down tubing into formation. Monitor pressure well stable Set BPV and ND tree. NU BOP's; OA open, 0 psi on tubing. Tower meeting. Continue to NU BOP's; well is stable, 0 psi on OA. Begin testing BOPE, (25013000 psi). Witness of BOPE test waived by state rep John Crisp. Finish BOPE test. Pull test plug and BPV. Screw in landing joint, BOLDS, and pull hanger to the floor. Hanger would not pull free pulling 125K, no stretch visible from the floor, hung up in the well head. Steam well head and working pipe completion came free with 11 OK up wt. pulled hanger to the floor 65K up wt. Lay down hanger and pup and Rig up spoolers Continue to Rig up spoolers Pull old completion out of hole laying down sideways, spooling ESP cable and Heat trace. Well is losing approx. 2 bbls per Hr. Tower meeting. Continue out of hole with old completion. Out of hole with old ESP completion. Begin laying pump equipment down. SWS hand on location to redresslverify ESP equipment is working properly. Well still taking approx. 2 bblslhr fluid loss. Start running new completion. PU centrlilizer, Phoenix sensor and motor. Service motor. MU seal section and service same. Feed motor lead extension through sheave to floor and connect. Install Phoenix pressure tbg sub and connect cap. tbg. Install Cannon single-channel cross-coupling cable clamps on every connection until three full jts. and every other collar from there up. Picking up new 4.5" 12.6# IBT tubing drifted to 3.833". Total fluid losses for last 24 hrs = 43 bbls. Continue running ESP completion, picking up new tubing. Install heat trace 6' up from pin on jt #36 (2958'). Continue in hole with completion testing cablelheat trace every 1000'. Out of correct dual-channel cross-coupling clamps with none available at warehouse; discuss with WIO engineer. Begin running mis-manufactured clamps upside down on bottom of jt 81. Follow-thru at wharehouse shows additional clamps "correct" available in stock. Have delivered to location and begin running correct clamps in correct position from jt #86 (clamps run upside down from jt.#81-85). Continue in hole with completion testing cablelheat trace every 1000'. PU and MU hanger with full jt 4.5" IBT wi side port isolation sleeve and landing jt. Orient hanger, meg. both cables OK. Install penetrators. Make final splice of ESP cable and Heat Trace to penetrators. Megged cables again everything good. Lowered hanger down and landed on Printed: 1/17/2006 1:13:24 PM ) ) . . ......... !?Qrqq~AhiniÞ~Ala6k~.. . ()perçltiºn~·.:SUITlm~irY·.R~pOrt: 3.50 CMPL TN RUNT CMPL TN mark. Up wt 62K Dwn wt 36K. Checked side port on hanger lined up good. Fluid for last 24 hrs = 18 bbls. 1.50 CMPL TN SOHO CMPL TN Run in lock down screws, Test hanger voidlpackoff to 5000 psi. Back out the landing joint, drain stack. Remove side port isolation sleeve from hanger. Install BPV. See remarks tab for band count. Change rams in BOP from 4.5" to 3.5". Nipple down BOPE. Checked the ESP cablelmotor electrical integrity. Meggar the Heat Trace. NU tree and test to 5000 psi. Pull 2-way check. Rig up Hot Oil. Circulate in diesel down lA, up tbg until diesel seen at pits (158 bbl total) for freeze protect. Begin cleaning pits. Install BPV. Finish cleaning pits. Telescope derrick down, lower derrick. Prep for move. Rig ready to move, waiting on CTU to finish on 1 D-113 in order to move down pad with rig to 1D-134. Released rig @ 1900 hrs on 12/29/2005. Pulled pipe shed forward, moved pit module out. Moved carrier unit out, moved crane in. Removed BOPE stack out from behind well. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S . .. ..... . ··.$ub "Date 'Frqrrp·To HOÜrsQodeQc>d~Pha$$ 12/28/2005 20:30 - 00:00 12/29/2005 00:00 - 01 :30 01 :30 - 06:00 4.50 WELCTL NUND CMPL TN 06:00 - 08:00 2.00 WELCTL NUND CMPL TN 08:00 - 11 :00 3.00 WELLSR FRZP CMPL TN 11 :00 - 14:00 3.00 WELLSR PLGM CMPL TN 14:00 - 17:00 3.00 MOVE MOVE MOVE 17:00 - 22:00 5.00 WAlTON OTHR MOVE 22:00 - 00:00 2.00 MOVE MOVE MOVE Start: 12/24/2005 Rig Release: 12/29/2005 Rig Number: 3S Spud Date: 6/1/2000 End: Group: ... ... .... .... ......... . . . ...... ...", ". .... . .... . ... o .... ....... ,". [)~¢çrìp~jqo ()fi(~p~r~tiOn$ , Printed: 1/17/2006 1:13:24 PM ConocoPhillips AlaSK¡. Inc:, 11D~1021..1 Heat Trace (0-3023, 00:1.000) TUBING (161-4076, 00:4.500, 10:3.958) XO (4076-4086, 00:5.130) SEAL (4086-4100, 00:5.130) SURF CASING (0-4175, 00:7.625, Wt:29.70) MOTOR (4100-4117, 00:5.620) GAUGE (4117-4119, 00:5.500) Centralizer (4119-4120, 00:5.880) CMTVALVE (4646-4647, 00:5.625) ECP (4665-4666, 00:5.625) ECP (4850-4851, 00:5.625) SLEEVE (4942-4943, 00:5.500) O-SANO LINER (4368-5029, 00:4.000, Wt:9.50) Perf (5029-7292) ] ~¡:;-..: i I !!i ]r: I'· ~ i I I ~ .-... DI- --_..- --- ----.-- = --.-....-- -) KRU 1)-1 02L 1 API: 500292296060 Well Type: PROD SSSV Type: NONE Orig Completion: 7/12/2000 Annular Fluid: Last W/O: 9/17/2005 Reference Log: 31' RKB Ref Log Date: Last Tag: 3997 TD: 7407 ftKB Last Tag Date: 12/11/2001 Max Hole Angle: 94 deg @ 7295 Casing String - COMMON STRINGS Description Size Top Bottom TVD Wt Grade Thread SURF CASING 7.625 0 4175 3439 29.70 L-80 BTC-MOD CONDUCTOR 13.375 0 110 110 68.00 L-80 WELDED SURF CASING 7.000 4175 4368 3558 26.00 L-80 BTC-MOD CSG WINDOW 6.000 4368 4383 3567 0.00 to 10-102 LINER 4.500 4368 4999 3693 12.30 L-80 BTC-MOD Casing String - D-SAND LINER (Alternating 4" blank pipe & Baker Dual Screen Pre-Pack 4"x4.5 Description Size Top Bottom TVD Wt Grade Thread D-SAND LINER 4.000 4368 5029 3693 9.50 L-80 HSLHT SCREENS 4.000 5029 7292 3654 9.50 L-80 HSLHT Tubing String - TUBING Size Top 4.500 0 4.500 161 Perforations Summary Interval I TVD 5029 - 7292 3693 - 3654 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr Angle @ TS: deg @ Angle @ TD: 94 deç¡ @ 7407 Rev Reason: GLV C/O Last Update: 12/15/2005 Bottom 161 4076 TVD 161 3377 Wt 12.60 12.60 Grade L-80 L-80 Thread IBT NSCT Zone WSD Status 1Ft I SPF I Date I Type I Comment 2263 50 7/12/2000 Screens Perfs thru screens V Type Vlv Cmnt (1 ) VOD Latch Port TRO Date Run 12/4/2005 12/4/2005 2574 2442 CAMCO KBG-2 DMY 1.0 3955 3300 CAMCO KBG-2 DMY 1.0 1. S/ick/ine found GLM @l2487' SLM, but tally shows 2574' RKB Other 'plugs, equip., etc.) - JEWELRY Depth TVD Type o 0 HeatTrace HEAT TRACE 31 31 HANGER VETCO GRAY TUBING HANGER 3999 3328 SUB PHOENIX DISCHARGE PRESSURE SUB 4076 3377 XO TCC CROSSOVER/COUPLING 4086 3383 SEAL Centralift Seal Section 4100 3392 MOTOR Centralift PCESP MOTor 4117 3403 GAUGE PHOENIX GAUGE ASSEMBLY 4119 I 3404 Centralizer Centrahft Centralizer Other (plugs, equip., etc.) - D-SAND LINER JEWELRY Depth TVD Type Description 4646 3664 CMT VALVE Baker HMCV Cement Valve 4665 3668 ECP Baker 7' Isozone ECP 4850 3691 ECP Baker 20' Payzone ECP 4942 3693 SLEEVE Baker CMD Sliding Sleeve G èl"íera I·..· NÒtås Date Note 3/6/2001 MULTI-LATERAL WELL: B-SAND (10-102), D-SAND (1O-102L 1) 11/16/2003 TREE: VETCO GREY /4"/ ESP /5M TREE CONNECTION: 7" OTIS BK-5 BK-5 0.000 0.000 o o 1 2 Description ID 0.000 4.500 0.000 4.500 0.000 0.000 4.500 0.000 ID 3.844 3.958 3.958 3.437 ~1TfÆ1TŒ (ffi~ fÆ~fÆ~rßfÆ AI~SIiA OIL AlQ) GAS CONSERVATION COMMISSION I I FRANK H. MURKOWSKI, GOVERNOR Brad Gathman Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU 1D-102L1 Sundry Number: 305-337 Cr'üNto<.,¡¡::f) Or.C 1 9 2005 gv," . . ~\l!;"+¡-'" ,1..,,," Dear Mr. Gathman: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission ·an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, / DATED this-L day of November, 2005 Enc!. ~ STATË OF ALASKA AU SKA OIL AND GAS CONSERVATION COMMISSION APPLI :ATION FOR SUNDRY APPROVAI!I¿¡shrJ 20 MC 25.280 Operational Shutdown 0 Plug Per1oratlon$ 0 PerfOrate New r;>ool 0 No Perfs - Pre pack Sl;:reens In norlzontal latarals Packers and SSSV Type: no packer 00 S$SV 12. Attachments; Description Summary of Propos!: 0 Detailed OperatIons Program 0 BOP: ;ketol1 0 , 14. Estimated Date for Commencing OperatIons; 16. Varbal Approval: Commission Representativa: 17. I hereby certify tl'lat lhe foregoiog is true and cm ect to the best of my knowladge. Printed Name 8 d Gat man 10/31/2005 20:00 9075597314 1. Type of Request Abandon 0 o o : uspend 0 o o Aller casing Feel ~Ir well cnange approved progra m PUI Tubing 2. Operator Name: ConQcoPhilli s Alaska, Inc. 3. Address: p, O. Box 100360, Anchora e. Alaska 9961: I 7. KB Elevation (ft): RKB 101' e. Property Designation: Kupal\Jk River Unit 11. Total depth MD (ft): 7378' Ca5ing CONDUCTOR Total Depth TVD (ft): Effectl e Deplh MD (I'(); 3721' Len th S\:¡:e 110' 13-3/8" 7-5'S" SURF CASING PROD CASING CSG WINDOw B-SAND LIN~R 4074' 764' 7" 1S' 6-1/2" 4-1/2" 147' Perforation Depth MD (ft): Perf 01 ~tion Depth TVD (ft): No\: ,mber 1 , 2005 Date: Signature NSK WELLS GROUP PAGE 03 """"""~; '~,'( f,~C<-"; L",. , \ ¡ i"" (JJ! ~- ~ 'J. ~-, ~Æ1r1 ! 2005 H{ ( ¡Ii (', \J :~d If (:~ PerfDrate 0 o Time ExtenSion o o o OtM.. 0 waiver Stimulale 4. Current Well Class: Oevelo~mQnl 0 Stratigraphic 0 Exploratory 0 ServIce 0 50-029-22960-60 9. Well Nllme and Number; 10-1 02L 1 1 Q, f:ieId/Pool(s); Kuparuk. River Field I We$t Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured); Junk. (measured): MD Burst TVD Colla se 110' 4175' 492S' 4383' 4925' Tubing Size: 4-112" Tubing Grade; L~80 Tubing MD eft): 4076' Packel'$ and $$SV MD (ft) no SSSV 13. Well Class after proposad work: Exploratory 0 Development [2] 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GIN.) 0 Servî¢e 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact Title: Phone 659"7224 Brad G~hman Problem Wells Supervisor Date October 31, 2005 Commission Use Onl Conditions of approval: Notify CommissiOO So th:," a representative may witness Plug Integrity D BOP Test 0 Location Clearance 0 Meehl nic.alllltegrity Test 0 Oth.., ~~~\"Ô'O,Ù It. ..~\~ \ \ II -{J "\. *- M.ß.'t \¡¡€;. \é~ ~~~. ,t)uMS 8Ft rvov (1 2 2005 M~~~~~~ . COMMISSIONER APPR.OveD BY THE COMMISSION ~ ORIGINAL Submit in Dupllcllla 10/31/2005 20:00 9075597314 NSK WELLS GROUP PAGE 02 ConocoPhillips Alaska, Inc. West Sak In.iection Well ID-l(I ~ (pTD 2000750) & ID~102Ll (PTD 2000760) SUN)RYNOTICE 10-403 VARIANCE REQlÆST 10/31/05 The purpose of this Sundry 'J"otice is for approval to produce multilateral West Sak producer ID- 102 via gaslift. The well is ~ompteted as an ESP (electric submersible pump) producer and does not have a packer. ID-I02 was worked over itl September, 2005 to replace a failed ESP motor. Following the workover, the pump was urllble to be run downhole due to tight collars in the tubing. The collars were milled using a ~oiled tubing unit and it appears the spline shaft of the motor was damaged during the milling process. Because of the damaged spline, the pump cannot be run and it is requested that the,¡ 'ell be produced by gasliftîng the wen. The tubing is configured wib two gas lift mandrels at 2574' RKB (2442' TVD) and 3955' RKB (3300' TVD). Gaslift wil11: e applied in the "standard" configuratíon; i.e., gas will be injected down. the annulus and enter the tubing through the gasHft valves. The following is a summa¡;1 of the proposed plan: 1. The AOGCC approve t1: is request for a time period not to exceed 24 months ttom the approval date; 2. Should a workover not 1: e completed within the approved time period the AOOCe will be contacted for a review a. ~d discussion of the plan forvvard. 10/31/2005 20:00 9076597314 NSK WELLS GROUP PAGE 01 Conocó'Phillipsi Alaské: RECfl i~' A'"\ , V U l 2005 .413SkFlO;¡·· ' r. ,'I & P.O. BOX 1003.60 ANCHORAGE. ALASKA 995] O.{:, ;0 ~ACSmm..E TRANSMITTAL SHEET 10: Tom Maunder From: Brad G:¡rthrnan Company: Company: ConocoPhillip9 Fax: 276-7542 Phme; 659~ 7224 Suqject: KRU tD-102 P.I1; :1uction Wen Pages: 3 Date: 10/31105 . Comments: Tom: Attached is the 10-4(1 ~ for West Sak productìon well 1 D-1 02 to produce via gasli1tThís well may be ready in a few days to br ng on production. Please notify me of your decision. F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~.""'.':'~-. .4 . ':'::; <" ,. t,.,". \'!~""" . · 1 \. .'.t;> Permit to Drill 2000760 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. KUPARUK RIV U WSAK 'lD-102L'l Operator PHILLIPS ALASKA INC. MD 7407 TVD 3647 Completion Dat 7/12/2000~// Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22960-60-00 UlC N REQUIRED INFORMATION Mud Log No Sample N__9o Directional Survey N._9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Name Log Log Scale Media Run No Interval Start Stop OH / Dataset CH Received Number Comments 1,2 09804~;330-7350 9804 DGR/EWR-TVD DGR/EWR-MD SRVY RPT 2/5 2/5 FINAL FINAL 4330 3567 4383 4337 7350 3693 7407 7407 Open 9/8/2000 OH 9/8/2O00 OH 9/19/2000 OH 9/19/2000 OH 7/18/2000 9804 ~sPERRY MPT/GR/EWR 3567.95-3693.64 6/21/00 THRU 4383-7407 6/21/00 THRU SPERRY 4337.54-7407 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis --Y-/--N - RP. nP. ived? Daily History Received? ~ N Formation Tops ,/'_~ / N Comments: Compliance Reviewed By: .............. ~_ ........................................................... WELL LOG TRANSMITYAL Alaska Oil and Gas Conservation Comm. Atto-::. Loft_Taylor 3001 Porcupine Dr. A.,.,l~,_ a~oV,,-:99_501 cro. on ¢ September- tx4, 2000 RE: MWD Formation Evaluation Logs 1D-102 L1, AK-MM-00058 l:h~teehnic, aLdata !im~,~ be~w,w-~subm/tt~-hemwi~.' _-:~ Please~. addmss:.~-prc~blems o~-ca~ to the attention of~ lcerns 2" x 5" TVD Resistivity & Cranuna Ray Logs: 1~ B!ueline [F_~Sepia 1 Blueline SEP 19 2000 Gas Cons. 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.:_. Lod Taylor 3001 Porcupine Dr. Anchorage, . Alaska 99501 MWD Formation Evaluation Logs September 7, 2000 1D-102 L1 , AK-MM-60058 1 LDWG formatted Disc with verification listing. API#: 50-029-22960-60 PLgASEAO~O ..¥O~El~lig RE~IFglIJ6 $!G~,NLN~.G A~ND-RE~A-COP¥ OF ~ ~AL Sperry-Sun Drilling Service 5631 Silverado Way, Suite G. Anchorage,_Alaska99518 RECEIVED SEP 0 8 2000 Date:. Alaska Oil & Gas Cons, 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~l Gas r~ suspended F~ Abandoned Fl Service BI '~ 2. Name of Operator.~'--- 7. Permit Number Phillips Alaska, Inc. ,~-~_ 200-076 / 3. Address~ i 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ 50-029-22960-60 4. Location ofwell at surface i' ',(rTi ;'~"~';~::-~;~1~' i 9. Unit or Lease Name 179' FSL, 595' FEL, Sec. 14, T11N, R10E, UM (ASP:560490.6, 5959844) :: ;';.': -;' ~:. ¢ Kuparuk River Unit At Top Producing Interval i ...7..?-~-~' ~ 10. Well Number 1060' FSL, 991' FWL, Sec. 24, T11N, R10E, UM (ASP:562115, 5955461) ! '.,.;.:~:;;;:;?.!? ~ 1D-102L1 At Total Depth ~ ...... ~L~:--.; ! 11. Field and Pool 1060' FSL, 991' FWL, Sec. 24, T11 N, R10E, UM (ASP: 562115, 5955461) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 30 feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 1,2000 June 23, 2000 July 12, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7407' MD/3647'TVD 7354' MD/3651'TVD YES ['~ No F~I N/A feetMD 1642' 22. Type Electric or Other Logs Run GR/Res/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO1 I-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 13.375" 68# L-80 Surface 110' 20" 7 cu yds High Early 7.625" x 29.7# L-80 Surface 4175' 9.875" 520 sx AS IIIL, 41o sx Class G 7" 26# L-80 4175' 4930' 9.875" see above 4.5" X 12.3# L-80 4368' 4999' 6" 111 sx Class G 4" 9.5# L-80 4999' 7393' 6" SEE ABOVE 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 4129' 4778' No perfs - Pre-pack screens in horizontal laterals 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 22, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 8/4/2000 6 hrs Test Period > 250 49 0 100I 194 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press 234 psi not available 24-Hour Rate > 1004 195 1 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak Sand West Sak A3 Base West Sak Sand GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 4601' 7407' 7407' 3654' 3647' 3647' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~'-~"~'~ ~'~~'~~ Title Randy Thomas Kuparuk Drilling Team Leader Questions? Call Mark Chambers 265-1319 Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. !iii'~.i i.i' {:i:i i:ii!! i:~'-~::!: Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-102 ML STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:06/01/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22960-00 06/01/00 (D1) MW: 9.4 VISC: 251 PV/YP: 46/76 APIWL: 4.0 TD/TVD: 668/666 (668) DRILLING AT 1110' SUPV:DON WESTER & BRIAN NOEL Move from 1D-04 and accept rig at 00:30 hrs. NU diverter system and function test. PJSM, pre-spud meeting. Spud well at 110', drill to 286'. POOH w/hwdp. RIH, drill from 286' to 668' 06/02/00 (D2) MW: 9.1 VISC: 280 PV/YP: 51/68 APIWL: 4.2 TD/TV-D: 0/666 ( 0) DRILLING AT 2567' SUPV:DON WESTER & BRIAN NOEL Drill from 668' to 2422' Using 250-300 vis to clean running rock & gravel from hole. 06/03/00 (D3) MW: 9.3 VISC: 252 PV/YP: 47/64 APIWL: 5.0 TD/TVD: 3645/3102 (3645) DRILLING AHEAD AT 4100' SUPV:DON WESTER & BRIAN NOEL Drill from 2422' to 2581' Gravel and rock from uphole continues to run. Pump high vis sweeps to clean hole. Flowline plugged w/mud over bell nipple but contained in cellar. Unplug flowline and clean gravel from possum belly. Drill from 2581' to 2650', flowline trying to plug. Circulate and move pipe while flushing flowline. Control drill from 2650' to 3645'. Hole periodically unloading gravel and rock but frequency and volume decreasing. 06/04/00 (D4) MW: 10.0 VISC: 260 PV/YP: 52/59 APIWL: 4.0 TD/TVD: 4805/3733 (1160) TD FOR CASING AT 4942', CELLAR BROACHED AT 5:15 AM WHI SUPV:DON WESTER & BRIAN NOEL Drill from 3645' to 4805'. Pump periodic sweeps for hole cleaning and add lubricants for slides. Small amount gravel in sweep returns. 06/05/00 (D5) MW: 10.0 VISC: 260 PV/YP: 52/59 APIWL: 4.0 TD/TVD: 4942/3751 (137) TAG CEMENT AT 107', WASH & REAM AT 250' SUPV:DON WESTER & BRIAN NOEL Drill from 4805' to 4942'. CBU and condition hole prior to POOH for hole opener. Cellar broached. Mud filled cellar and containment berm and spilled 5 bbls onto pad. POOH slow, clean up mud. POOH. Tight spots at 170' and 290'. RIH w/mule shoe joint. Lower mule shoe joint to 120', plugged. Pump water. Full returns. Pump 700 sx ASI. WOC.~ Hold.~sp~d meetings. Date: 08/15/00 ARCO ALASKA INC .......... WELL SUMMARY REPORT 06/06/00 (D6) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 10.0 VISC: 292 PV/YP: 56/67 0) P0H TO RUN CSG. APIWL: 4.2 WOC. Modify trip tank outlet line to 6", work on auger. Tag cement @ 107' Drilling cement from 107' to 230'. Pump away, lost returns. Torque @ 6000#, up ream to 153' & wo water. Switch to mud and attempt to wash down, stalled top drive @ 168' Worked pipe to 153'. Wash and ream from 200' to 340', circ out cement contaminated mud & heavy gravel, wash from 340' to 429'. CBU. P0H slow. RIH, ream tight spot @ 250', RIH, wash & ream from 1610' to 3500' 06/07/00 (D7) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 9.6 VISC: 96 PV/YP: 36/34 0) ORIENT WINDOW APIWL: 5.4 RIH, washing and reaming from 3500' to 4942' TD. Circ and condition hole for casing, spot pill and pump dry job. POH. PJSM. Run 7" and 7-5/8" casing, work thru tight spots. 06/08/00 (D8) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 9.6 VISC: 91 PV/YP: 32/32 0) SLIP & CUT DRLG. LINE. APIWL: 5.6 Reciprocate casing string, attempt to get circ, losing mud while circ going down. Circ, condition mud & hole for wl work, gained lost mud back. RIH w/gyro data. PJSM. Test cement lines. Pump cement. Bump plug. Floats held. ND diverter system. N/U BOPE. 06/09/00 (D9) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 9.3 VISC: 43 PV/YP: 14/ 9 0) DISPLACE HOLE TO NEW MUD. APIWL: 8.0 Function test BOPs, set test plug, test BOPE. PJSM. RIH w/4" dp, wash to 4851' Drilling plug, motor not acting right. PJSM. POH, break bit, adjust mud motor to '0' and day down (appears the shaft is broke, can turn by hand). RIH with new mud motor. 06/10/00 (D10) MW: 9.1 VISC: 42 PV/YP: 12/22 TD/TVD: 5190/3748 ( 248) MAKING HOLE @ 5560' SUPV:M.C. HEIM APIWL: 3.8 RIH to 4853' Break circ, tag @ 4853' Drilling FC, cement, shoe & 20' new hole to 4962'. CBU. Perform FIT 11.0#. Drilling and surveys from 4962' to 5354'. Circ and work pipe for Sidetrack. Sidetrack & drilling from 5190' to 5200' 06/11/00 (Dll) MW: 9.1 VISC: 43 PV/YP: 11/23 APIWL: 3.8 TD/TVD: 6178/3745 ( 988) MAKING HOLE @ 6545' SUPV:M.C. HEIM Drilling and surveys from 5200' to 6454'. Circ, work pipe, poh for sidetrack @ 6170'. Drilling sidetrack #2 from 6166' to 6178' Date: 08/15/00 ARCO ALASKA INC. Page: 3 WELL SUMMARY REPOR~?~k.?~ii~'~..~li~i_>..~i~'ii~i~'~{i~>[~ 06/12/00 (D12) MW: 9.2 VISC: 45 PV/YP: 11/25 APIWL: 3.6 TD/TVD: 6768/3705 ( 590) RUNNING IN HOLE-WENT IN OLD HOLE ~ 5354'-PULLED BACK-O SUPV:M.C. HEIM Drilling and surveys from 6178' to 6768' Sidetrack #2. Pump hi-vis hi wate pill sweep while drilling @ 6646' POH 1 stand, pump hi-vis hi-ware sweep, circ around, recovered substantial amount of cuttings. POH. 06/13/00 (D13) MW: 9.1 VISC: 44 PV/YP: 12/22 APIWL: 3.8 TD/TVD: 7378/3719 (610) POOH SUPV:DON WESTER, G.R. WHITLOCK RIH w/reaming BHA and 1 std 3.5" dp. RIH to 6530'. Circ and cond mud. Start trench for sidetrack from 6530' to 6561' Drill from 6561' to 7378'. Circ and work pipe. Pump weighted sweep. POOH 9 stands. 06/14/00 (D14) MW: 9.1 VISC: 43 PV/YP: 12/21 APIWL: 3.8 TD/TVD: 7378/3719 ( 0) MIXING VISCOUS PILL SUPV:DON WESTER, G.R. WHITLOCK Work pipe past 3rd sidetrack from 6590' to 6520'. POOH to 5210'. Trench from 5210' to 5160'. POOH. RIH with hole opener assembly. Wash and ream from 4935' to 7377'. Circ and pump sweeps. RIH. Circ and work pipe. 06/15/00 (D15) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) CIRC AND FILTERING FLUID SUPV:DON WESTER, G.R. WHITLOCK Circ and build hi-vis sweep w/filtered brine. PJSM. Displaced well with brine. Spotted hi-vis pill. POOH slow. RIH w/scraper assembly. 06/16/00 (Dt6) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) POOH SUPV:DON WESTER, G.R. WHITLOCK Hold safety meeting. Pump caustic flush. Hold safety meeting. Pickle drillpipe with HC1 and reverse out. 06/17/00 (D17) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) L/D SCREENS SUPV:DON WESTER, G.R. WHITLOCK Filter brine. POOH. Test BOPE to 250/3000 psi. PJSM. RIH w/screens. Safety meeting. RIH with 3.5" hwdp. RIH w/screens on 4" dp. Unable to get past 6760' 06/18/00 (D18) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) RUNNINING RETRIEVABLE BRIDGE PLUG SUPV:DON WESTER, G.R. WHITLOCK Attempt to work deeper than 6760' w/o success. POOH. RIH w/screens. Drop plug and pump down, set packer. Shear ball and circ brine. Spot acidize and displace through screens. Date: 08/15/00 WELL SUMMARY REPORT 06/19/00 (D19) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) RIH W/ WHIPSTOCK MILLS SUPV:DON WESTER, G.R. WHITLOCK POOH to 4672' Circ. RIH w/bridge plug and set at 4555.97' Pump 14' of sand on top of RBP. Circ and wash. POOH. RIH w/RMLS combo tool. Latch ~ 4387'. Shear out. POOH. RIH with whipstock to 4387' 06/20/00 (D20) MW: 9.2 VISC: 44 PV/YP: 12/25 APIWL: 4.2 TD/TVD: 4540/3637 ( 0) DRILLING ~ 4675' SUPV:DINK HEIM, G.R. WHITLOCK Set whipstock ~ 4387', survey. POOH. PJSM. Mill window from 4368.5 to 4383.5. Circ sweep and bottoms up. POOH. RIH, slide thru window and make 20' of new hole. Circ and condition mud. Perform FIT to 11.25 ppg EMW. Drill from 4398' to 4540' 06/21/00 (D21) MW: 9.1 VISC: 47 PV/YP: 11/27 APIWL: 4.0 TD/TVD: 5082/3694 ( 542) TRIP OUT TO REPAIR LINK TILT SUPV:DINK HEIM, G.R. WHITLOCK Drill from 4540' to 5082'. Try to make bit drill, no success. Circ. POOH. M/U new motor. RIH. 06/22/00 (D22) MW: 9.1 VISC: 44 PV/YP: 11/26 APIWL: 3.9 TD/TVD: 5082/3694 ( 0) DRILLING @ 6885' SUPV:M.C. HEIM, G.R. WHITLOCK RIH. Work through window. Wash 22' to bottom. Drill from 5498' to 6344' 06/23/00 (D23) MW: 9.1 VISC: 46 PV/YP: 12/25 APIWL: 3.9 TD/TVD: 7407/3648 (2325) CIRC PREPARING TO DISPLACE HOLE W/ BRINE SUPV:M.C. HEIM, G.R. WHITLOCK Drill from 6344' to 7397'. Circ sweeps until hole clean. Drill from 7397' to 7407'. POOH. Test BOPE 250/3000 psi. 06/24/00 (D24) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH W/ HOLEOPENER SUPV:M.C. HEIM, G.R. WHITLOCK RIH w/hole opener BHA. Wash to bottom and circ. Circ hi-vis pill and clean brine. Spot hi-vis pill on bottom with brine. POOH to window. 06/25/00 (D25) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) PICKING UP SCREENS SUPV:M.C. HEIM, G.R. WHITLOCK POOH. Move 3.5" dp to other'side of derrick. RIH to 4175' CBU. Wiper trip to upper scraper,- RIH to 4175'. PJSM. Pump caustic wash and circulate around. Pickle with acid and spot to bottom of dp. Reverse out pickle. Monitor well. PJSM. RIH w/screens. Date: 08/15/00 WELL SUMMARY REPORT 06/26/00 (D26) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) LAYING DOWN 4" SCREEN LINER. SUPV:M.C. HEIM, G.R. WHITLOCK Continue running screens. Run 4.5" tubing. RIH with 2-7/8" tubing. RIH with screens. Unable to work screens past 4834' while circ. String stuck. Pump dry job. POOH. Recover wash string and left screen assembly in hole. 06/27/00 (D27) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH THROUGH WINDOW INTO CASING, BUILDING BRINE VOLUME SUPV:DON L. WESTER, BRIAN NOEL RIH with fishing tools to 1808'. Jar fish loose. POOH. RIH to 4372' Work hole opener and fixed blade stabilizer out through window. Wash and ream from 4372' to 7271' 06/28/00 (D28) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) AT WINDOW RIH W/ SCREENS AND LINER SUPV:DON L. WESTER, BRIAN NOEL Finish reaming hole from 7271' to 7407'. Pump pill. PJSM. RIH w/ screens. 06/29/00 (D29) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) PICK UP CEMENTING CUP TOOL SUPV:DON L. WESTER, BRIAN NOEL Continue RIH w/screens, liner and 2-7/8" inner wash string. Ran 34 pre-pack screens, blanks and liner. Run liner and screens through window at 4368' and upper lateral to 6825' Increased drag last 60' differentially stuck work pipe. Pump brine and flo-pro pill and spot brine. Work pipe, slight movement slid liner to 6840' Pump second flo-pro pill and spot brine. Work pipe free. RIH, space out and land liner/screen assembly at 7393' Set packer. POOH. 06/30/00 (D30) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) TAG TOP TRANSITION JOINT W/ 6" BIT & CIRCULATE OUT GRE SUPV:DON L. WESTER, BRIAN NOEL RIH on 2-7/8" tubing. Pump cement. Test BOP 250/3000 psi. 07/01/00 (D31) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) WAIT ON CEMENT BOND LOG TOOLS FROM ALPINE SUPV:DON L. WESTER, BRIAN NOEL Wash down and tag transition joint at 4370'. No indication of cement. POOH. RIH with 3.75" mill. Wash from top transition joint into 4.5" liner 4370'-4430'. No cement. POOH. RIH, wash 4.5" liner from 4417' to 4895' 07/02/00 (D32) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH AFTER CEMENT SQUEEZE (CIP AT 3:10 AM) SUPV:DON L. WESTER, BRIAN NOEL POOH. Wait on cement bond log tool. RIH w/SCMT to 4670' Log 4665'-4119' PJSM. RIH w/4.5" Halliburton fast drill bridge plug and set at 4405' Date: 08/15/00 WELL SUMMARY REPORT 07/03/00 (D33) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RIH W/ WASHPIPE SUPV:DON L. WESTER, BRIAN NOEL Complete breakdown test and circulate. PJSM. Perform cement squeeze. Tag TOC 8 4134' Drill out cement to 4367' and CBU. RIH with 3.75" mill and 2-7/8" PAC. Tag at 4367' and drill out cement in 4.5" liner to 4384' 07/04/00 (D34) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) WASHING OVER WHIPSTOCK SUPV:M.C. HEIM / S. GOLDBERG Continue drilling cement from 4384' to 4405'. Drill bridge plug and clean out to 4415'. RIH to 4141'. Wash and ream down attempting to clean out. Wash down to 4287'. Torquing up and stacking out weight. Unable to get down. RIH with clean out BHA with mills. RIH to 4127'. Wash and ream down to 4364'. Pump high viscosity sweep. POOH slowly due to drag. Lots of thin cement pieces in junk baskets. RIH to 4095'. Wash down and tag up on whipstock at 4365'. Start rotating and slowly milling down. 07/05/00 (D35) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH WITH WHIPSTOCK RUNNING TOOL SUPV:M.C. HEIM / S. GOLDBERG Continue milling over the top of the liner and whipstock from 4363' to 4384'. Pump high viscosity sweeps to aid hole cleaning. Pull up into 7-5/8" casing with whipstock. Drop dart to open circulating sub. sub would not shear open. Continue to p~ll out of hole wet. Reverse out sand to top of bridge plug. POOH. RIH with completion whipstock. 07/06/00 (D36) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RIH WITH CUP TOOLS AND PERFORATED JOINTS SUPV:M.C. HEIM / S. GOLDBERG PJSM. Pump viscosified brine. Pump HC1. Displace with brine. RIH w/mill. Mill KOIV. Pump high viscosity sweep to clean hole. Continue running in hole to 7370'. POOH. 07/07/00 (D37) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RUNNING IN HOLE WITH ACIDIZING ASSEMBLY SUPV:M.C. HEIM / S. GOLDBERG Continue POOH with clean out assembly. RIH with sliding sleeve shifting tool and cup assembly. Tag up at 4817' Unable to work through. POOH with acidizing assembly. Cup assembly full of iron and cement mixture. RIH with mill. Tag and mill KOIV at 4908'. Work through and clean up. 07/08/00 (D38) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) CIRCULATING CLEAN BRINE IN UPPER LATERAL SUPV:M.C. HEIM / S. GOLDBERG Pump high viscosity sweep. TOOH. Small amount of cement and steel. RIH. Work through KOIV. Tag up on sliding sleeve. Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 Unable to work through. POOH with shifting tool. RIH with reverse circulating junk basket. Wash from 4368' to 4468' Tag up at 4942' Pushed debris through sliding sleeve while circulating with reverse basket. RIH to 7342'. POOH. Small amount of cement and steel in basket. 07/09/00 (D39) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH WITH BRIDGE PLUG SUPV:M.C. HEIM / S. GOLDBERG RIH with sliding sleeve shifting tool. Tag up at 7349' Pump brine. PJSM. Perform acid treatment. POOH. RIH with retrieval tool. 07/10/00 (D40) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RUNNING ESP COMPLETION. SUPV:M.C. HEIM / S. GOLDBERG Continue P0H w/whipstock. RIH with bridge plug retrieving tool. Wash over bridge plug, latch and retrieve. Monitor well, losing 40 bph, slowed down to 20 bph. POH. Run in hole with 4.5" tubing. PJSM. 07/11/00 (D41) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) LAND HANGER SUPV:DON WESTER & BRIAN NOEL POOH. PJSM. RIH and set pump and packoff. RIH with 4.5" tubing. PJSM. RIH with 4.5" tubing and dual channel clamps. Start heat trace. PJSM. Megger heat trace and ESP cable. Run 4.5" tubing and dual clamps. 07/12/00 (D42) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) MOVE to 1D-118 WO. SUPV:DON WESTER & BRIAN NOEL Space out heat trace. Splice ESP Power cable. Set BPV. ND BOP and test cables. NU tree and test to 250/5000 psi. Set BPV and RDMO. Rig release 3:00 PM on 7/12/00. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 21, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-102 and 1D-102L1 (200-075 and 200-076) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the drilling operations on 1D-102 and 1D-102L1. If you have any questions regarding this matter, please contact me at 265-6120 or Mark Chambers at 265-1319. Sincerely, Randy Thomas Kuparuk Drilling Team Leader PAI Drilling RT/skad North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-102 L1 OR ® NAL SURVEY REPORT 17 July, 2000 Your Ref: API-500292296060 Surface Coordinates: 5959844.00 N, 560490.59 E (70° 18' 03.0795" N, 210° 29' 23.7478" E) Kelly Bushing: 101.60ft above Mean Sea Level A Halliburton Company RECEIVED JUL Alaska :9i[ & Gas Co~s. ¢or~missio~ Anch0~'age Survey Ref: svy9261 Sperry-Sun Drilling Services Survey Report for 1D-102 L1 Your Ref: API.500292296060 North Slope Alaska Measured Depth (ft) 4337.54 4368.00 4388.81 4418.29 4451.68 Incl, 51.39o 51.54o 54.610 59.890 65.880 Azim. 138.35o 139.560 138.47o 136.850 135.22o Sub-Sea Depth 3438.26 3457.24 3469.74 3485,68 3500.90 Vertical Depth 3539.86 3558.84 3571.34 3587.28 3602.50 4484.59 66.920 131.900 3514.07 3615.67 4512.71 67,150 132.120 3525.05 3626.65 4544.05 70.170 133.900 3536.45 3638.05 4577.04 74.110 136.770 3546.57 3648.17 4607.50 75.430 137.370 3554.57 3656.17 4641.24 78.160 138.000 3562.28 3663.88 4672.41 79.030 138.860 3568.44 3670.04 4704.10 80.230 140.180 3574.14 3675.74 4731.99 81.670 143.800 3578.53 3680.13 4761.68 82.380 147.670 3582.65 3684.25 4799.91 85.560 152.430 3586.67 3688.27 4834.99 87.170 157.520 3588.90 3690.50 4867.43 87.660 159.150 3590.36 3691.96 4896.44 88.460 160.270 3591.34 3692.94 4931.46 89.690 160.460 3591.91 3693.51 4992,69 89.880 161.160 3592.14 3693.74 5026.89 90.060 161.820 3592.15 3693.75 5059.39 90.310 162.060 3592.05 3693.65 5088.92 89.690 161.860 3592.05 3693.65 5123.04 89.010 164.870 3592.44 3694.04 Local Coordinates Northings Eastings (ft) (ft) 1494,79 S 1128.10 E 1512.76 S 1143.74 E 1525.31S 1154.65 E 1543.62 S 1171.35 E 1565.00 S 1191.98 E 1585.77 S 1213.84 E 1603.10 S 1233.07 E 1623.01S 1254.41E 1645.34 S 1276.47 E 1666.86 S 1296.49 E 1691.15 S 1318.60 E 1714.01S 1338,87 E 1737.72 S 1359,11E 1759.42 S 1376.06 E 1783.71 S 1392.61 E 1816.64 S 1411.58 E 1848.35 S 1426.39 E 1878.47 S 1438.35 E 1905.66 S 1448.40 E 1938.64 S 1460.17 E 1996.47 S 1480.30 E 2028.90 S 1491.15 E 2059.80 S 1501.23 E 2087.88 S 1510.37 E 2120.56 S 1520,14 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/~OOft) 5958358.49 N 561630.57 E 5958340.64 N 561646.36 E 3.15 5958328.18 N 561657.37 E 15.33 5958310.00 N 561674.22 E 18.50 5958288.80 N 561695.02 E 18.46 5958268.20 N 561717.03 E 9.77 5958251,03 N 561736.41E 1.09 5958231.29 N 561757.91E 10.99 5958209.14 N 561780.14 E 14.53 5958187.79 N 561800.33 E 4.73 5958163.68 N 561822.63 E 8.29 5958140.99 N 561843.09 E 3.89 5958117.44 N 561863.51E 5.58 5958095.89 N 561880.64 E 13.82 5958071.73 N 561897.38 E 13.13 5958038.95 N 561916.62 E 14.92 5958007.37 N 561931.67 E 15.19 5957977.35 N 561943.88 E 5.24 5957950.24 N 561954.15 E 4,74 5957917.36 N 561966.18 E 3.55 5957859.70 N 561986.77 E 1.18 5957827.36 N 561997.88 E 2.00 5957796.55 N 562008.21E 1.07 5957768,55 N 562017.58 E 2.21 5957735,95 N 562027.60 E 9.04 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1786.30 Tie-on Survey 1808.47 Window Point 1823.96 1846.81 1873.86 1900.75 1923.52 1949.43 1977.86 2OO4.84 2035.13 2063.46 2092.58 2118.70 2147.14 2184.52 2219.36 2251.74 228O.73 2315.75 2376.98 2411.17 2443.66 2473.18 2507.25 RECEIVED JUL. 1 8 OOC Continued... 17July, 2000- 14:15 -2- Alaska ,Oil & Gas Co;~s. Commissio~ A~.chorag8 DrillQuest 2. 00, 02 Sperry-Sun Drilling Services Survey Report for 1D-102 L1 Your Ref: API-500292296060 North Slope Alaska Measured Depth (ft) 5158.31 5184.69 5218.21 5252.24 5281.42 Incl. 88.370 88.580 88.830 89.140 90.490 Azim. 164.24o 166.420 169.050 170.400 173.780 Sub-Sea Depth (fi) 3593.24 3593.95 3594.70 3595.31 3595.40 Vertical Depth (fi) 3694.84 3695.55 3696.30 3696.91 3697.00 5316.46 90.920 175.000 3594.97 3696.57 5348.42 90.430 177.160 3594.59 3696.19 5376.94 90.550 178.340 3594.35 3695.95 5410.41 89.690 179.850 3594.28 3695.88 5444.75 90.000 179.150 3594.37 3695.97 5473.82 90.430 179.350 3594.26 3695.86 5509.69 90.060 178.920 3594,11 3695.71 5541.36 90.250 179.020 3594.02 3695.62 5570.00 91.420 178.280 3593.61 3695.21 5605.26 90.490 178.290 3593.02 3694.62 5637.54 92.340 179.250 3592.22 3693.82 5666.00 92.460 179.310 3591.03 3692.63 5733.65 91.050 183.420 3588.96 3690.56 5762.39 90.310 183.780 3588.62 3690.22 5793.74 90.480 183.440 3588.40 3690.00 5830.02 91.170 183.230 3587.88 3689.48 5858.76 90.860 180.350 3587.37 3688.97 5892.05 91.780 178.590 3586,60 3688.20 5926.41 91.970 178.140 3585,48 3687.08 5955.98 92.160 178.410 3584.41 3686.01 Local Coordinates Northings Eastings (ft) (ft) 2154.55 S 1529.53 E 2180.06 S 1536.21E 2212.80 S 1543.33 E 2246.28 S 1549.39 E 2275.18 S 1553.41 E 2310.05 S 1556.83 E 2341.93 S 1559.02 E 2370.42 S 1560.14 E 2403.89 S 1560.67 E 2438.23 S 1560.97 E 2467.29 S 1561.35 E 2503.16 S 1561.89 E 2534.83 S 1562.46 E 2563.45 S 1563.13 E 2598.69 S 1564.19 E 2630.95 S 1564.88 E 2659.39 S 1565.24 E 2726.97 S 1563.63 E 2755.65 S 1561.82 E 2786,94 S 1559.85 E 2823.15 S 1557.74 E 2851,87 S 1556.84 E 2885.15 S 1557.15 E 2919.48 S 1558.13 E 2949.01S 1559,02 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5957702.04 N 562037.27 E 2.55 5957676.59 N 562044.15 E 8.30 5957643.90 N 562051.53 E 7.88 5957610.48 N 562057.87 E 4.07 5957581.62 N 562062.11 E 12.47 5957546.78 N 562065.82 E 3.69 5957514.92 N 562068.26 E 6.93 5957486.44 N 562069.61 E 4.16 5957452.98 N 562070.41E 5.19 5957418.65 N 562070.98 E 2.23 5957389.59 N 562071.60 E 1.63 5957353.73 N 562072.43 E 1.58 5957322.08 N 562073.25 E 0.68 5957293.46 N 562074.16 E 4.83 5957258.23 N 562075.50 E 2.64 5957225.98 N 562076.45 E 6.46 5957197.55 N 562077.03 E 0.47 5957129.97 N 562075.97 E 6.42 5957101.28 N 562074.39 E 2.86 5957069.98 N 562072.67 E 1.21 5957033.75 N 562070.85 E 1.99 5957005.03 N 562070.19 E 10.08 5956971.76 N 562070.76 E 5.96 5956937.44 N 562072.02 E 1.42 5956907.91 N 562073.15 E 1.12 -3- Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2542.42 2568.69 2601.93 2635.50 2664.08 2698.08 2728.85 2756.07 2787.78 2820.24 2847.75 2881.73 2911.75 2938.95 2972.51 3003.14 3030,05 3093.19 3119.61 3148.43 3181.84 3208.60 3240.06 3272.73 3300.86 Continued... DrillQuest 2. 00. 02 17 July, 2000 - 14:15 Sperry-Sun Drilling Services Survey Report for 1D-102 L1 Your Ref: API-500292296060 North Slope Alaska Measured Depth (ft) 5985.81 6017.23 6048.81 6082.75 6115.03 Sub-Sea Incl. Azim. Depth (.) 91.970 178,210 3583.34 92.100 178.740 3582.22 92.030 177.890 3581.08 91.790 177.600 3579.95 91.660 177.420 3578.98 Vertical Depth (.) 3684.94 3683.82 3682.68 3681.55 3680.58 6145.97 91.600 176.640 3578.10 3679.70 6178.96 92.340 176.190 3576.97 3678.57 6210.89 92.460 176.560 3575.63 3677.23 6242.49 92.030 176.150 3574.39 3675.99 6278.00 91.420 175.160 3573.32 3674.92 6309.97 90.860 175.620 3572.69 3674.29 6339.38 90.000 176.150 3572.47 3674.07 6373.94 90.680 176.280 3572.26 3673.86 6435.61 91.420 175.600 3571.13 3672.73 6468.14 90.860 175.440 3570.48 3672.08 6500.19 90.740 176.190 3570.04 3671.64 6531.57 92.340 178.800 3569.19 3670.79 6564.37 91.420 178.200 3568.12 3669.72 6595.80 90,680 177.680 3567.54 3669.14 6626.97 90.550 176.390 3567.21 3668.81 6660.72 90.000 176.670 3567.04 3668.64 6692.10 91.110 179.110 3566.74 3668.34 6723.76 90.920 179.970 3566.18 3667.78 6756.03 91.230 183.330 3565.57 3667.17 6788.72 90.800 183.970 3564.99 3666.59 17 July, 2000 - 14:15 Local Coordinates Northings Eastings (ft) (ft) 2978.81 S 1559.90 E 3010.20 S 1560.73 E 3041.74 S 1561.66 E 3075.64 S 1563.00 E 3107.87 S 1564.40 E 3138.76 S 1566.00 E 3171.67 S 1568.06 E 3203.50 S 1570.08 E 3235.02 S 1572.09 E 3270.41 S 1574.77 E 3302.27 S 1577.34 E 3331.60 S 1579.45 E 3366.08 S 1581.73 E 3427.59 S 1586.10 E 3460.01 S 1588.64 E 3491.97 S 1590.98 E 3523.31 S 1592.35 E 3556.08 S 1593.21E 3587.48 S 1594.34 E 3618.61S 1595.95 E 3652.30 S 1597.99 E 3683.65 S 1599.15 E 3715.32 S 1599.40 E 3747.55 S 1598.47 E 3780.17 S 1596.39 E Alaska State Plane 4 Kuparuk 1D Global Coordinates Dogleg Vertical Northings Eastings Rate Section Comment (ft) (fi) (°/lOOff) 5956878.13 N 562074.26 E 0.92 3329.23 5956846.75 N 562075.35 E 1.74 3359.09 5956815.22 N 562076.53 E 2.70 3389.12 5956781.34 N 562078.14 E 1.11 3421.51 5956749.12 N 562079.80 E 0.69 3452.35 5956718.25 N 562081.65 E 2.53 3481.99 5956685.36 N 562083.98 E 2,62 3513.68 5956653.55 N 562086,25 E 1.22 3544.36 5956622.05 N 562088.51 E 1.88 3574.72 5956586.69 N 562091.49 E 3.27 3608.97 5956554.85 N 562094.31 E 2.27 3639.85 5956525.54 N 562096.66 E 3.43 3668.19 5956491.08 N 562099.22 E 2.00 3701.45 5956429.62 N 562104.08 E 1.63 3760.86 5956397.22 N 562106.88 E 1.79 3792.27 5956365.28 N 562109.47 E 2.37 3823.16 5956333.96 N 562111.10 E 9.75 3853.15 5956301.20 N 562112.22 E 3.35 3884.31 5956269.81N 562113.60 E 2.88 3914.28 5956238.70 N 562115.46 E 4.16 3944.15 5956205.04 N 562117.78 E 1.83 3976.58 5956173.69 N 562119.19 E 8.54 4006.51 5956142.03 N 562119.69 E 2.78 4036.43 5956109.80 N 562119.03 E 10.46 4066.49 5956077.17 N 562117.21 E 2.36 4096.53 -4- RECEIVED J~JL ~ g ~00~ Continued... Alaska ~iI & ~s ¢,o~. ~ ~..i~do~ ................................................... ~BCh01'~ OrillOuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 L1 Your Ref: API-500292296060 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 6820.10 90.860 184.960 3564.54 3666.14 3811.45 S 1593.95 E 6851.96 91,350 187.240 3563.92 3665.52 3843.12 S 1590.57 E 6886.79 91.480 187.870 3563.06 3664.66 3877.64 S 1585.99 E 6915.38 92.030 187.000 3562.19 3663.79 3905.97 S 1582.29 E 6947.71 91.660 184.870 3561.15 3662.75 3938.11 S 1578.95 E 6984.38 89.820 183.700 3560.67 3662.27 3974.67 S 1576.21 E 7011.98 89.880 182.310 3560.75 3662.35 4002.24 S 1574.76 E 7048.60 91.050 181.660 3560.45 3662.05 4038.83 S 1573.50 E 7080.69 91.170 181.340 3559.83 3661.43 4070.91 S 1572.66 E 7108.57 91.170 181.130 3559.26 3660.86 4098.77 S 1572.05 E 7141.07 90.750 180.800 3558.71 3660.31 4131.26 S 1571.51 E 7170.63 90.570 180.980 3558,37 3659.97 4160.82 S 1571.05 E 7205.07 92.280 178.580 3557.52 3659,12 4195.24 S 1571.18 E 7294.51 93.760 172.510 3552.80 3654.40 4284.25 S 1578.11 E 7331.41 93.580 175.350 3550.44 3652.04 4320.86 S 1582.00 E 7407.00 93.580 175.350 3545.72 3647.32 4396.05 S 1588.12 E Global Coordinates Northings Eastings (ft) (ft) 5956045.87 N 562115.02 5956014.17 N 562111.89 5955979,63 N 5621.07.59 5955951,26 N 562104.12 5955919.10 N 562101.04 5955882.52 N 562098.59 5955854.95 N 562097.37 5955818.35 N 562096.39 5955786.28 N 562095.81 5955758.41 N 562095.44 5955725.92 N 562095,15 5955696.36 N 562094.93 5955661.94 N 562095.34 5955573.01 N 562102.99 5955536.43 N 562107.17 5955461.29 N 562113.89 Dogleg Rate (°/lOOff) E 3.16 E 7.32 E 1.85 E 3.60 E 6.68 E 5.95 E 5.04 E 3.65 E 1.06 E 0.75 E 1.64 E 0.86 E 8.55 E 6.98 E 7.70 E 0.00 All data is in feet unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 160.430° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7407.00ft., The Bottom Hole Displacement is 4674.12ft., in the Direction of 160.137° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. RECEIVED JUL 'I 8 200C kr~cho~'aga Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4125.18 4153.89 4184.88 4210.34 4239.50 4273.03 4298.52 4332.58 4362.51 4388.57 4419.00 4446.7O 4479.18 4565.36 4601.16 4674.06 Projected Survey Continued... 17 July, 2000- 14:15 -5- DrillQuest 2,00,02 Sperry-Sun Drilling Services Survey Report for 1D.102 L1 Your Ref: API-500292296060 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4337.54 3539.86 1494.79 S 1128.10 E 4368.00 3558.84 1512.76 S 1143.74 E 7407.00 3647.32 4396.05 S 1588.12 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 7407.00 3647.32 Survey Tool Description MWD Magnetic 17 July, 2000 - 14:15 -6- RECEIVED JUL 1 8 200C: Alaska "'~" ,~.. & 6~.s Co,~s. Co~]u:issi~ ................................................... A~chora§e DrillQuest 2.00.02 17-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-102 L1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 4,337.54' MD 4,368.00' MD 7,407.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager R[CE V.FD Attachment(s) JUL '/8 200¢ Alaska 0il & Gas Cons. O0r.~:issi0n Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 I t I I / / / TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kupamk River Unit 1 D- 102L 1 ARCO Alaska, Inc. Permit No: 200-076 Sur Loc: 179'FSL, 595'FEL, Sec. 14, T11N, R10E, UM Btmhole Loc. 1069'FSL, 962'FWL, Sec. 24, TllN, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-102L1. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit is for a new wellbore segment of existing well 1D-102, Permit No. 200-075, APl 50-029- 22960-00. Production should continue to be reported as a function of the original APl number stated above. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~Sincerely, . Commissioner BY ORDER OF THE COMMISSION DATED this .5" ~ day of June, 2000 dlf/Enclosures CC~ Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of w;rk: Ddll' [~] Reddll L~' J lb. Type of well. Exploratory L~ StratigraphicTast[g Development Oil L~] Re-entry BI Deepen [~ Service F~ Development Gas BI SingleZone r~ Multiple Zone 5. Datum elevation (DF or KB) 10. Field and Pool 2. Name of Operator RKB 30 feet /~~laska, Inc~/,~ 6. Property Designation Kuparuk River Field 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAO 25.0251) 179' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1729' FNL, 834' FWL, Sec. 24, T11N, R10E, UM 1D-102L1 #U-630610 At total depth 9. Approximate spud date Amount 1069' FSL, 962' FWL, Sec. 24, T11N, R10E, UM June 6, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) 1069' @ TD feet none feet 2560 7359 ' MD / 3636 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 4469' MD Maximum hole angle 92 o Maximum surface 1297 psig At total depth C-VD) 1705 psig 18. Casing program Setting Depth size __-- Specifications To.~ Bottom Quantity._.~f Cement Hole Casing Weihng~ Grade ~ Len._._~.~.~ MD TVD U'~~ TVD ~._.~,~~ 20" 13.375" 68# L-80 BTC 80' 110' 110' 110' 110' -~ · 9.875" 7.625"x 7" 29.7¢ L-80 BTC Mod 4757' 110' 110' 4867' 3761' ., ........ -- 6" 4.5"x 4" 12.6# L-80 ~ ~ ~ 7359' 3636' 15 bbls Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Intermediate ~:¢¢: '(--' ~ "~'' ~' '"" ~; ~ ~' ;-" Production Liner ORIGINAL - -, ~ Perforation depth: measured 20. Attachments Filing fee Icl Property Plat LI BoP Sketch Icl Piverter Sketch I~l Drilling program Drilling fluid program ~ Time vs depth plot FIReffaction analysis FI Seabed report FI 20 AAO 25.050 requirements r'] 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Carl Mark Chambers 265-151~. Signed ..~.4 _~~ ~.~ ~ Title: OfillingEngin.erfngSut~rviso, Date ch~ A~v¢rd Commission Use 0~_~ Permit Number [ APl number ~.'~---'--~--, 7l Approvaldate ~ Tsee c°ver letter ,~--~-O7~-,~ ~o- O~"~c~-,'~'~"~'~::)-60/ ~I¢ '~ ,~,,DD [for other requirements Conditions of approval Samples required L~ Yes J~ No Mud log required L~ Yes ~ No Hydrogerlsulfidemeasures D Yes [~N~ Directional surveyrequired ~ Yes D No Required working pressure for BOPE D2M; D 5M; D 10M;D Other: ORIGINAL SIGNED BY by order of D Taylor Seamount commissioner the commission Date (-~ Approved by Submit in triplicate Fnrm 10-401 R~.v 12/1/8~ · Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1D-102 Multilateral Producer (Sidetrack Well Bore) Well Plan Summary Surface Location: 179' FSL 595' FEL Sec.14 TllN R10E Main Wellbore B-Sand Lateral - Target 1 1729' FNL 934' FWL Sec 24 TllN R10E B-Sand Lateral - TD 1070' FSL 912' FWL Sec 24 TllN R10E Sidetrack Wellbore D-Sand Lateral - Target I 1729' FNL 834' FWL Sec 24 TllN R10E D-Sand Lateral - TD 1069' FSL 962' FWL Sec 24 TllN R10E I AFE Number: I I I Rig: I Nordic 3 Estimated Start Date: I 6/07/99 I Operating days: I I I I I I 37 I KBE: [ 30' IType of Well Well Desiqn Producer Horizontal Multilateral- Pre-Packed Screen Formation Markers: (all depths adjusted for Nordic RKB) Formation Tops True Vertical True Vertical Measured Hole Angle Depth (SS) Depth (RKB) Depth (RKB) Degrees Main Wellbore and B-Sand Lateral Base Permafrost 1533 1634 1642 15 Ugnu C-Sand 2943 3044 3575 52 Ugnu B-Sand 3204 3305 4000 52 Ugnu A-Sand 3275 3376 4115 52 K-13 Shale 3417 35:[8 4346 52 West Sak D-Sand 3577 3677 4611 57 West Sak C-Shale 36:[6 3717 4694 65 West Sak B-Sand 3642 3743 4772 75 West Sak B-Sand Heel 3660 3761 4867 86 West Sak B-Sand Toe TD 3593 3694 7355 92 Sidetrack Wellbore D-Sand lateral K-13 Shale 3417 3518 4346 52 West Sak D-Sand 3578 3679 4686 78 West Sak D-Sand Heel 3604 3705 5055 92 West Sak D-Sand Toe TD 3534 3635 7359 92 Casing/Tubing Program: (all depths adjusted for Nordic RKB) Hole Size Csg/Tbg Wt/Ft Grade Conn. Length Top Btm OD MD/TVD MD/TVD 9-7/8" 7-5/8" x 7" 29.7 / L-80 BTC - Mod 4,867' Surface 4,867' / 3,76i' 26 6" LoweF 4" Screen 9.5 L-80 HSLHT 4,867' / 3,761' 7,355'/3,694' Lat. 6" Upper 4" Screen 9.5 L-80 HSLHT 4,469'/3,593' 7,359'/3,635' Lat. Logging/Formation Evaluation Program: Open Hole Cased Hole Loqs: MWD/GR/RES/PWD (Pressure while Drilling) None Drilling Fluid Type 6" Production Hole will be drilled with a 6% KCL Drill'N Fluid. Drillinq Fluid Properties: Production Interval (D-Sand Horizontal Lateral): Density Viscosity Y__~P P__~V 9.1 40 - 55 22 - 27 8 - i4 HTHP Chlorides LGS < 10 27 - 32K 12 ppb (drilled LGS) tau0 p~_ API Filtrate 4 - 7 8.0 - 8.5 4 - 6 Drillinq Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. f4ASP (Maximum Anticipated Surface Pressure): Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EHW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.4 ppg can be predicted as a maximum mud weight required to safely drill this formation. Calculating HASP based on the highest recorded reservoir pressure from the WSI~01 well, and assuming a gas gradient of 0.11 psi/ft from maximum TVD in the D-Sand to surface, the following HASP can be computed: MASP = (3707 ft)(0.46 - 0.11 psi/ft) = 1297 psi Based on this calculation for HASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" x 7" surface casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of 1,500 psi. The 7" 26" Sperry Preformed Window has a maximum burst rating of 2,500 psi; 70 % of this burst rating is 1,750 psi. _Drillin_e Area Risks: Drilling risks in the West Sak 1D-102 area are primarily limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 9.8 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-138. _Well Proximity Risks: No Hazards. _Annular Pumpinq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-102 surface casing / production tubing annulus will be filled with diesel and / or non-freezing brine after running the ESP completion and prior to the drilling rig moving off of the well. Drill, Case and Completion Plan for West Sak 1D-102 Multilateral Producer General Procedure (Sidetrack Well Bore): 1. C,f. ~A~,%~ ~,~ Set bridge plug approximately 4 joints below preformed window. Spot +/- 15' of sand on top of bridge plug. 2. Orient and set whipstock assembly. 3. Tag whipstock and displace well with Drill'N Fluid. 4. Mill preformed window and circulate hole clean. 5. PU 6" PDC Bit and Directional BHA. RIH to top of whipstock. 6. Slide out window and drill approximately 20' of new hole. Perform F1T not to exceed 11 ppg EMW and record results. This establishes a maximum allowable drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the Fl-I- or LOT EMW). 7. Directionally drill 6" hole to +/- 5,000' MD / 3,707' TVD. Displace well to clean Drill'N Fluid. 8. Continue to directionally 6" hole to TD at +/- 7,359' MD / 3,636' TVD as per directional plan. 9. Circulate and condition hole to run liner. 10. Lay down MWD, LWD and PWD tools. 11. Displace mud with clean filtered brine and spot viscosified brine in open hole. 12. Perform casing clean-up including Caustic SL Wash and pickle. 13. Run 4-1/2" x 4" Bonzai Liner with pre-packed screen (run liner with 2-7/8" inner wash string). 14. Land liner, inflate lower ECP and release liner running tool. 15. PU and inflate upper ECP. 16. PU cementing BHA, R~H and locate across cementing valve. Open cementing valve, condition the hole and pump cement job as designed. 17. PU 6" Milled Tooth Bit and cleanout excess cement to liner top. 18. Wash over liner top and retrieve whipstock assembly. 19. Dress off window junction with watermelon mill. 20. Orient and set workover whipstock assembly. 21. Cleanout liner to TD. 22. Displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screen while POOH. 23. Displace the well, above the window, with clean filtered brine. 24. Retrieve workover whipstock assembly. 25. Circulate sand and debris off top of bridge plug. 26. Retrieve bridge plug. 27. R~H w/4-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and :I- wire to penetrators. 28. Land tubing hanger. I~LDS, install two-way check and test tubing hanger. 29. ND/NU/Test. 30. Freeze protect with diesel to +/- 2000' TVD. 1D-102 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion ~ Phase 3 13-3/8~ 68# L-80 BTC ~ Conductor @ 80' TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- f000'TVD Production Casing 7~5/8" 29.7# L-80 BTC Mod RMLS to surface Production Casing 7' 26# L-80 BTC Mod TD to RMLS Sand Bridge Upper Lateral 'Bonzai' Comp ? ~ ;,(Run w/2-7/8" Hyd 511 Inner Wash Strinq) Sperry RMLS Transition Joint. Sperry (TAM) Hydraulic Release Sub. 4-1/2" 12,6# L-80 BTC Mod Tbg as required from Indicator Sub to Hyd Release Sub. Baker Hand~ing Pup 4-t/2" 12.6# L-80 IBT Box x Casing BTC Pin (Length 10'), Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12,6# L-80 Casing BTC Box x Pin, Baker Handling Pup 4-1/2" t2.6# L-80 Casing Box x Pin (Length t0% Baker HMCV Cementing Valve 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker 3' Bottom Sub 4-1/2" 12,6¢ L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (es required), 4-1/2" 12.6# L-80 IBT Box x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 10'), Baker CTC 7' Isozone ECP 4-1/2" 12.6# L-80 Casing BTC Box x Sox (3,833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (as required). 4-1/2" 12.6# L-80 IBT Box x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length Baker CTC 20' Payzone ECP 4~1/2" 12.6# L-80 Casing BTC Box x Box (3.833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. 1 Joint 4-1/2" 12~6# L-80 BTC Mod Tubing. Baker Model C 'KOIV' Knock Out isolation Valve w/3.50" ID and 4~1/2" IBT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 BTC Mod Tubing, Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" IBT Box x Pin. 1 Joint 4-1/2" 12.6# L*80 BTC Mod Tubing. Crossover Pup, 4-1/2~ tBT Box x 4" HSLRT Pin. 4" x 4-1/2" Bakerweld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from Drillable Packoff Bushing to Sliding Sleeve. 4" 9.5¢ L*80 Blank Pipe w/HSLHT Connections as required from Driliable Packoff Bushing to Sliding Sleeve. Plan to alternate Prepack Screen and Blank Pipe throuqh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4" HSLHT Box x 5" HSLHT Pin 1 Joint 5" 15# L-80 HSLHT Tubing. Baker Ddllable Packoff Bushing w/5" HSLHT Box x Pin. 1 Joint 5" 15# L-80 HSLHT Tubing. Baker Model 'GPV' Set Shoe (5.560" Max OD). 7" Casing Poird @ 4,887' MD / 3,761' TVD ~D B-Sana Lateral @ +/- 7,355' MAC 05/10/00 D-102 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 4 13-3/8" 68# L-80 BTC Conductor @ 80' TAM 7-5/8" Pod Collar BTC Mod Box x Pin set @ +/- 1000'TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7rr Casing Point @ ,1,867' MD / 3761' TVD 4-1/2" Vetco Gray Tubing Hanger w/4,909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 4~1/2" 12.6# L-80 NSCT Spaceout Pups as required for Heat Trace (Heat Trace Cannot Be Spliced). Raychem Heat Trace @ +/- 3,000' MD. 4-1/2" 12.6# L~80 NSCT Tubing to Surface.. 4-1/2" x 1' Camco 'KBG-2' GLM run open @ +/- __ MD. After rig moves off location, the Welts Group will install a Shear Circulating Valve pinned for 3000 psi Tubing to Casing Differential. 6' handling pups installed on top and bottom of GLM. 2 Joints 4-1/2" 12.6# L-80 NSCT Tubing, Baker Sentry BHP Gauge (at[ached to 2nd 10' Pup Joint above the Slot[ed NippIe) 10' Spaceout Pup 4-1/Z' 12,6# L-80 NSCT Tubing 10' Handling Pup 4-1/Z' 12,6# L-80 NSOT Tubing Centrilif[ ESPCP (components as listed below) w/bottom set @ +/* ' MD, Centritift 4~1/2" Slotted Nipple. Centrilift 4-1/2" TTC Crossover Centdlift Tandem Seal Section: CST3 DB tL H6PFS Centrili~ PC Pump Assembly: R&M 375 Series 40-S-340 Single Lobe PC Pump Centrilift Gear Reduction Unit; 525 Sedes, 9:1 Centrilift Motor: 57 HP 1315126 KMH Centriliff Motor Centralizer TD B-Sand Lateral @ +/- 7.355' MAC 05/~0/00 ~:P~~:~ I North Slope Alaska ~'~~~[~! Alaska State Plane 4 0- /Begin Dir @ 2.000°/100ft · 275.00ft MD, 275.00* TVD ~dginDi~Jir57~5'20.%f~(~b50~t4."~J~.~MD, 634.12ft TVD 800 -- ,~en~inDi~ir9~5'~.00ft00r~l°~bS~3:'~{~.~/f~MD, 993.58* TVD /Increase in Dir Rate @ 3.000°/100ft' 1295.00ft MD, 1293.03, TVD ~) ¢?,End Dir: 1595.00ft MD, 1587.70, TVD 1::3 1600 -- ¥Dir @ 5.000°/100,: 1802.06, MD, 1787.70ft TVD ._ .84* TVD 2400 - II :,= 3200 - ~o '~ /Top 37' Window Joint I I I 0 800 1600 Vertical Section Section Azimuth: 160.431° (True North) Kuparuk 1DI Drt'#Qttest':' 1 D-102 WPs ........ ~' ........ '~ 3600 - II ~ 4000 - Top 37' Window Joint I 2000 Scale: linch = 400ft Bottom 37' Window Joint ST Exit @ 12.000°/100f1, 0.000° TF: 4468.50ft MD, 3593.09ft TVD increase in Dir Rate @ 14.000°/100ft: 4498.50ft MD, 3610.76ft TVD End Dir: 4658.50ft MD~ 3673.42fl TVD / Begin Dir @ 12.003/100fi: 4705.95ft MD, 3683.36ft TVD .... Begin Dir @ 0 000°/100ft: 6572.20fl MD, 3657.72ft TVD / , Decrease in Dir Rate @ 10.000°/100ff 4870 96fl MO, 3705.00ft IVL) End Di~' 6674.21ft MD, 3656.18ft TVD / ...................... fl TVr~ // End Oir: 5055.36ft MD, 3705.94fl TVD ft VD ~ / / / / _Begin D~r @ 4.000°/100fi: 5547.92ft MD, 3686.22 T / / ~ / / / / -I02 T4 ~ _ tal Depth: 7354.86ft MD, 3694.00fl TVD increase in Dir Rate @ 12.503°/100fl: 4653.99ft MD, 3699.20ft TVD Bridge Plug Set Begin Dir @ 10.000°/100fl: 4509.09ft MD, 3618.03ff TVD I I I I I I I 2400 2800 3200 3600 4000 4400 4800 Vertical Section Section Azimuth: 160.431° (True North) IDrillQuest North Slope Alaska Alaska State Plane 4~cale: linch = 600ft Kuparuk 1 D -600 0 1 D-102 WPs I ~ -600 -- -1200 - -1800 - O Z -2400 - -3000 - -3600 - ~o -4200 - Eastings 600 1200 1800 I I I ZBegin Dir @ 2.000°/100ti: 275.00lt MD, 275.00ft TVD End Dir: 575.00ft MD, 574.45ft TVD //~ Begin Dir @ 2.000°/10011: 635.00ft MD, 634.12lt I'VD /////~ End Dir: 935.00ft MD, 933.5811TVD ~~ Begin Dir @ 2.000°/100ft: 995.00ft MD, 993.58ft TVD _~ -- Increase in Dir Rate @ 3.00OD/100ft: 1295.0011 MD, 1293.03ft TVD -- I~_~_~-------- End Dir: 1595.00ft MD, 1587.7011 TVD ~---'---- Begin Dir @ 5.000°/lO0ft: 1802.06ft MD, 1787.70ft TVD End Dir: 2599.80ft MD, 2444.84ft TVD - -600 ' '~ ~ - -1200 /ST Exit @ 12.000°/100ft, O.000° TF: 4468.51 1 MD, 3593.09[t TVD / Increase in Dir Rate @ 14.000°/10011: 44 )8.5011 MD, 3610.76ft TVD B~. OOft: 4509.09ft MD, 3618.03ft TVD ~,/j Begin Dir @ 12.003°/10OI1: 4705.95f MD, 3683.36fl TVD ~ggol~gT~S~ - ~'~ -- -1800 ~.~,/~O Decrease in Bit Rate @ 10.0( )°/10Oft: 4870.96ft MD, 3705.00ft TVD D ...... in Dir Rale @ 10'000°/100[1: 4866'~9ft MD, 3761'00ft TvD '~-~=%~]D-,02~", End Dir 5;54 90fi MD 3764 0011TVD End Bit: 5055.36fl MD, 3705.94 TVD 4000 I 5 I 3 0 Begin DJ, @ . ~nl~lr.': ~...~6.¢8flftl~, ~,74-43t .~)8[1[tT~ Begin Dir ~ 4.0~"/10~: 6617.16ff MD, 3716.~ff ~D E~ Dir: 6624.12fl MD, 3715.8~ ~O Total Depth: 7354.8611 MD, 3694.0011 TVD I I I -600 0 600 1200 Scale: linch = 600ft Eastings Begin Dir @ 4.01 ID-]02 T2 End Dir: 5674.34 Dir @ 0.0OO°/10Of1: 6 ID-I02 TS 6674.21ft MD, 36 ID-102 T4 Tolal Deplh: 7358.801 I 1800 O ---2400 Z °/100fi: 5547.92fl MD, 3686.22ft TVD MD, 3684.0411 TVD - -3000 ,72.20fl MD, 3657.7211 ~D - -3600 6.18ll TVD ---4200 ~o II MD, 3635.0oft TVDJ~ Reference is True North Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Depth Incl. Azim. (ft) 0.00 0.000 0.000 101.00 0.000 0.000 200.00 0,000 0.000 275.00 0.000 0.000 Sub-Sea Vertical Depth Depth (ft) (ft) -101.00 0.00 0.00 101.00 99.00 200.00 174,00 275.00 300.00 0.500 230.000 199.00 300.00 400.00 2.500 230.000 298.96 399.96 500.00 4.500 230.000 398.77 499.77 575.00 6.000 230.000 473.45 574.45 600.00 6.000 230.000 498.32 635.00 6.000 230.000 533.12 700.00 4.700 230.000 597.84 800.00 2.700 230.000 697.63 900.00 0.700 230.000 797.58 935.00 0.000 0.000 832.58 995.00 0.000 0.000 892.58 1000.00 0.100 1100.00 2.100 1200.00 4.100 1295.00 6.000 1300.00 6.150 170.000 897.58 i70.000 997.55 170.000 1097.4~Q 170.000 119~.~!~' 70.0 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 N 0.00 N 0.00 N 0.07 S 1.75 S 5.68 S 10.09 S 599.32 634.12 698.84 '(,~11~18.01 S ~! 21.47 W 798.63 .~ ~ .~, ~,,.~¢~ =; 26.41 W 24.~ 28.68 W 898.58A 93R5~ 24 21 S 28.85 W ~'..~ ',,:~ .... S 28.85 W ¢~998.5~ 24.21 S 28.85 W ~;;*~8~5 ',~;, 26.10 S 28.51 W ~;293~03' 39.66 S 26.12 W 1298.00 40.18 S 26.03 W Northin( igs (ft) 0.00 E 595 0.00 E ~3.87 N 0.00 E L87 N 0.00 E ~7 N ~38.14 N 5959833.69 N .99 N 5959829.62 N 5959825.68 N 5959821.50 N 5959819.57 N 5959819.43 N 5959819.43 N 5959819.43 N 5959817.54 N 5959812.22 N 5959804.00 N 59598O3.48 N ,490.58 E 560490.58 E 560490.58 E 560490.58 E 560490.50 E 560488.51E 560483.86 E 560478.64 E 560476.65 E 560473.87 E 560469.26 E 560464.35 E 560462.09 E 560461.93 E 560461.93 E 560461.93 E 560462.28 E 560463.26 E 560464.78 E 560464.87 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 2.000 2.000 2.000 2.000 0.000 0.000 2.000 2.000 2.000 2.000 0.000 2.000 2.000 2.000 2.000 3.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) o.oo o.oo o.oo o.oo 0.04 0.98 3.17 5.63 6.56 7.88 10.05 12.36 13.43 13.50 13.50 13.51 15.40 20.75 29.00 29.53 Comment Be~in Dir @ 2.000°/100ft: 275.00ft MD, 275.00ft TVD End Dir: 575.00ft MD, 574.45ft TVD Berlin Dir @ 2.000°/100ft: 635.00ft M D, 634.12ft TVD End Dir' 935.00ft MD, 933.58ft TVD Beain Dir @ 2.000°/100fl: 995.00ft MD, 993.58ft TVD Increasein Dir Rate @ 3.000°/100fl'1295.00ff MD, 1293.03ff TVD Continued.. 24 April, 2000 - 13:58 - I - DrillQuest 1o05.05a Sperry-Sun Drilling Services PropoSal Report for 1D-102 WPs - 1D-102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 1400.00 9.150 170.000 1296.10 1500.00 12.150 170.000 1394.36 1595.00 15.000 170.000 1486.70 1600.00 15.000 170.000 1491.53 1800.00 15.000 170.000 1684.72 1802.06 15.000 170.000 1686.70 1900.00 18.997 160.246 1780.37 2000.00 23.423 153.780 1873.58 2100.00 28.034 149.307 1963.65 2200.00 32.751 146.021 2049.89 2300.00 37.535 143.487 2400.00 42.362 141.453 2500.00 47.218 139,764 2599.80 52.087 2600.00 52.087 2800.00 52.087 3000.00 52.087 3200.00 52.087 3400.00 52.087 3600.00 52.087 3800.00 52.087 4000.00 52.087 4200.00 52.087 4390.24 52.087 4400.00 52.087 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 1397.10 53.29 S 23.72 W 1495.36 71.49 S 20.51 W 1587.70 93.45 S 16.64 W 1592.53 94.72 S 16.41 1785.72 145.70 S 1787.70 146.22 S 1881.37 173.73 S 1974.58 206.90 S 2064.65 24~:~ 2150.89 2131.64 2232.64 ~4.57 S 2208.29 2309.29 ~:~=.,.4, 3 S 2279.24 2380.24 43~~ 497.23~*~'' 138.325 2343.84 2444.8, ~ 138.325 2343.96 2~'91 }~¢~ 497.35 S 138.325 2466.85 25~¢~ i~, ~¢~ 5.20 S 138.325 2589.74 ~26~ ~ ....... 733.06 S 138 325 2712.64 ~,,.~8~,~6. t ',~ 850.92 S 138.325 2835.53 ~¢ 2~ ' 968.78 S 138.325 2958.~ ~'~ ~5~;? 1086.63 S 138.325 ~.~0~:~. ~'¥~E32 1204.49 S 138.32¢~,~,~¢.2;1;~, 3305.21 1322.35 S 13&¢~S 3~10 '~;~=:' 3428.10 1440.20 S 1 ~ 34~00 3545.00 1552.31 S 138.3'~ 3~?~9 3550.99 1558.06 S E 95.74 E 134.88 E 179.61E 229.47 E 229.58 E 334.49 E 439.41E 544.32 E 649.23 E 754.15 E 859.06 E 963.98 E 1068.89 E 1168.69 E 1173.81E Glob; (ft) 595 ).39 N N ~.29 N 2N N 170.15 N ;959637.10 N i99.20 N 5959556.76 N 5959510.08 N 5959459.54 N 5959405.50 N 5959348.50 N 5959348.39 N 5959231.38 N 5959114.37 N 5958997.36 N 5958880.35 N 5958763.34 N 5958646.34 N 5958529.33 N 5958412.32 N 5958301.02 N 5958295.31N ~gs i467.29 E 560470.65 E 560474.69 E 56O474.93 E 560484.33 E 56O484.43 E 56O492.24 E 560506.80 E 560527.89 E 56O555.37 E 560589.01E 560628.56 E 560673.72 E 560724.05 E 560724.15 E 560830.01E 560935.87 E 561041.73 E 561147.59 E 561253.45 E 561359.31E 561465.17 E 561571.03 E 561671.73 E 561676.89 E Dogleg Rate (°/100ft) 3.000 3.000 3.000 0.000 0.000 0.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 42.67 60.93 82.95 84.23 135.36 135.88 164.36 200.37 243.13 292.30 347.51 408,35 474.34 544.84 544.98 690,56 836.14 981.72 1127.30 1272.88 1418.45 1564.03 1709.61 1848.09 1855.19 Comment End Dir: 1595.00ft MD, 1587.70ft TVD Beqin Dir @ 5.000°/100ft: 180'2.06ft MD, 1787.70ft TVD End Dir: 2599.80ft MD, 2444.84ft TVD K-13 Shale Continued... 24 April, 2000- 13:58 -2- DrillQuest 1.05.058 Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Depth Incl. Azim. (ft) 445o.oo 52.087 138.325 4487.o0 52.087 138.325 4509.09 52.087 138.325 4600.00 56.852 147.850 4647.00 59.581 152.352 4653.99 6o.0o0 153.0o0 Sub-Sea Ve~ical Local Coordinates Depth Depth Nothings Eastings (fl) (fi) (ft) (ft) 3480.72 3581.72 1587.52 S 12oo.o3 E 3503.45 3604.45 1609.33 S 1219.44 E 3517.03 3618.03 1622.34 S 1231.03 E 3569.92 3670.92 1681.48 S 1275.22 3594.69 3695.69 1716.10 S 1295.1 3598.20 3699.20 1721.47 S 4700.00 65.598 154.491 3619.23 3720.23 1758.16 S 4800.00 77.805 157.347 3650.57 3751.57 1844,70 S .ooo 4900.00 87.076 162.226 3661.99 3762.99 ~i~.33 S ~ 5000.00 90.374 171.670 3664.22 3765.22 20~;~~?=' 5054.90 92.187 176.854 3663.00 3764.0~ ~ 2089.19~'~ ....... 5400.00 92.187 176.854 3649.83 375~3=' ~3.52 S 5600.00 92.187 176.854 3642.20 37~G~ ~j~[~633.07 S 5636.78 91.518 177.929 3640.~ ~ ~7~ 1~~' 2669.79 S 5800.00 S1.51 g 177.020 a~ 20a2.04 8 6000.00 91.5~ 8 177.9~ ~,,~¢~:,~ .,~¢~,,;~ 3732.35 3032.64 S 177~i;~: ..... ~~~ 3727.05 3232.44 S 6200.00 91.518 ~ ~ *~* 1390.03 E 1412.57 E 1418.06 E 1426.01E 1436.98 E 1447.95 E 1448.23 E 1449.67 E 1455.57 E 1462.79 E 1470.02 E No~hin¢ ~t) 595 1.06 N N .49 N N N 5958096.36 N 0.13 N 5957948.79 N 5957917.8O N 5957820.71N 5957766.16 N 5957621.46 N 5957422.00 N 5957222.54 N 5957217.40 N 5957185.84 N 5957022.84 N 5956823.10 N 5956623.37 N ~gs 17o3.36 E 561722.94 E 561734.63 E 561779.30 E 561799.46 E 561802.28 E 561820.65 E 561859.93 E 561885.00 E 561896.16 E 561919.49 E 561925.41E 561934.53 E 561947.11E 561959.68 E 561960.00 E 561961.70 E 561968.91E 561977.74 E 561986.57 E Dogleg Rate (°/100ft) 0.00o 0.000 0.000 10.000 10.000 10,000 12.503 12.503 12.503 10.000 10.000 10.000 0.000 0.000 0.000 0.000 4.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vedical Section (ft) 1891.58 1918.52 1934.59 2004.89 2044.10 2050.08 2090.66 2185.04 2251.23 2284.17 2383.48 2436.89 2576.38 2768.64 2960.90 2965.86 2996.18 3152.29 3343.57 3534.85 Comment Top 37' Window Joint Bottom 37' Window Joint Beqin Dir @ 10.000°/100ft: 450'9.09ft MD, 3618.03ft TVD Bridge Plug Set Increase in Dir Rate @ 12.503°/100ft: 4653.99ff MD, 3699.20ft TVD Decrease in Dir Rate @ 10.000°/100ft: 4866.99ft MD, 3761.00ft TVD End Dir: 5054.90ft MD, 3764.00ft TVD Beqin Dir @ 4.000°/100ft: 560'5.16ft MD, 3743.00ft TVD End Dir: 5636.78ft MD, 3741.98ft TVD Continued... 24 April, 2000- 13:58 -3- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 6400.00 91.518 177.929 3620.75 6600.00 91.518 177.929 3615.45 6617.16 91.518 177.929 3615.00 Vertical Local Coordinates Glob; Depth Northings Eastings (ft) (ft) (ft) (ft) 3721.75 3432.24 S 1477.24 E ~23.63 N 3716.45 3632.04 S 1484.47 E 59~ .~3.90 N 3716.00 3649.19 S 1485,09 E N 6624.12 91,710 178.131 3614.80 3715.80 3656.13 S 1485.33 N 6800.00 91.710 178.131 3609.56 3710.56 3831.84 S 1491 ~N N 955624.66 N ;955470.00 N 7000.00 91.710 178.131 3603.59 3704.59 4031.65 S 1497 7200.00 91.710 178.131 3597.62 3698.62 4231.45 S 7354.86 91.710 178.131 3593.00 3694.00 4386.16 S All data is in feet unless otherwise stated Directions and coordi~!es are r~tive to True North. Vertical depths are relative to 1D-102 W~s. Northings and East~re ~ive to 1D-102 WPs. The Dogleg Severity is in Degrees per 100ft. ~i~' ~r~t}~, Vertical Section is from 1 D-102 WPs and calculatedl~g an~A~imuth of 161.01 3° (True). Based upon Minimum Curvature type The Bottom Hole Displacement is Depth of 7354.86ft., of 161.01 3° (True). tgs 995.41E 562004.24 E 562005.00 E 562005.30 E 562012.45 E 562020.58 E 562028.71E 562035.00 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 4.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 3726,13 3917.41 3933.82 394o.47 41o8.49 4299.54 4490,60 4638.53 Comment Be~in Dir @ 4.000°/100ft: 66I'7.16ft MD, 3716.00ft TVD End Dir' 6624.12ft MD, 3715.80ft TVD Total Depth: 7354.86ft MD, 3694.00ft TVD Target - 1 D-102 B T4 Continued... 24 April, 2000 - 13:58 -4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured S t a t i o n Depth TVD Northings (ft) (ft) (ft) 275.00 275.00 0.00 N 575.00 574.45 10.09 S 635.00 634.12 14.12 S 935.00 933.58 24.21 S 995.00 993.58 24.21 S 1295.00 1293.03 39.66 S 1595.00 1587.70 93.45 S 1802.06 1787.71 146.22 $ 2599.80 2444.83 497.23 S 4450.00 3581.72 1587.52 S 4487.00 3604.45 1609.33 S 4509.09 3618.03 1622.34 S 4647.00 3695.69 1716.10 S 4653.99 3699.20 1721.47 S 4866.99 3761.00 1906.24 S 5054.90 3764.00 2089.19 S 5605.16 3743.00 2638.22 S 5636.78 3741.98 2669.79 6617.16 3716.00 3649.1 6624.12 3715.80 7354.86 3694.00 Coordinates Eastings ~t) 0.00 E 12.02W 16.83W 28.85W 28.85W 26.12W 16.64W 7.33W 229.47 E 1200.03 E 1219.44 E 1231 1509.16 E Comment Begin Dir @ 2.000°/100ft: End Dir: 575.00ft MD, Begin Dir @ End Dir: 935.00ft MD Begin Dir @ 2.0(: Increase in D ~.00ft TVD 2ft TVD vlD, 993.58ft TVD : 1295.00ft MD, 1293.03ft TVD : 1802.06ft MD, 1787.70ft TVD 3( 2444.84ft TVD Joint ow Joint Beg 10.000°/100ft: 4509.09ff MD, 3618.03ft TVD Bridge Plug Set Increase in Dir Rate @ 12.503°/100ft: 4653.99ft MD, 3699.20ft TVD in Dir Rate @ 10.000°/100ft: 4866.99ft MD, 3761.00ft TVD End Dir: 5054.90ft MD, 3764.00fl TVD Begin Dir @ 4.000°/100ft: 5605.16ft MD, 3743.00ft TVD End Dir: 5636.78ft MD, 3741.98ft TVD Begin Dir @ 4.000°/100ft: 6617.16ft MD, 3716.00ft TVD End Dir: 6624.12ft MD, 3715.80ft TVD Total Depth: 7354.86ft MD, 3694.00ft TVD Continued... 24 April, 2000 - 13:58 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D-102 WPs - 1D-102 Wp3 Revised: 24 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 4390.24 3545.00 3444.00 Northings (ft) 1552.31 S Eastings Formation Name (ft) 1168.69 E K-13 Shale Targets associated with this wellpath Target Name 1D-102 B T1 1D-102 B T2 1D-102 B T3 1D-102 BT4 ~? ..... Mean S~.eveVGIol~Goordinates: ~graphi~oordinates: · ~}l~l~n Sea Level/Globa Coordinates: ~ Geographical Coordinates: ~7~ean S~a Level/Global Coordinates: '.~ Geographical Coordinates: ~Mean Sea Level/Global Coordinates: Geographical Coordinates: arget Entry Coordinates TVD Northings (fi) (ft) 3761.00 1906.24 3660.00 5957950.00 70o17'44.3271`' 3743.00 2638.22 3642.00 5957218.00 70° 17'37.1275" 3716.00 3649.19 3615.00 5956207.00 70o17'27.1837'' 3694.00 4386.16 3593.00 5955470.00 70°17'19.9349'' Eastings Target Ct) Shape S 1529.12 E Point N 562O35.OO E N 149° 29'51.6792"W S 1523.23 E Point N 562035.00 E N 149° 29'51.8553"W S 1515.09 E Point N 562035.00 E N 149° 29'52.0984"W S 1509.16 E Point N 562O35.00 E N 149°29'52.2756"W Target Type 24 April, 2000 - 13:58 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 L 1 Wp3 Revised: 8 May, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 4468.50 52.087 138.325 3492.09 4498.50 55.687 138.325 3509.76 4500.00 55.895 138.360 3510.61 4600.00 69.776 140.411 3556.15 4658.50 77.907 141.434 3572.42 4705.95 77.907 141.434 3582.36 4800.00 83.076 151.614 3597.93 4870.96 87.125 159.137 3604.00 4900.00 87.933 161.928 3605.25 5000.00 90.743 171.527 3606.41 5055.36 92.294 176.844 3604.94 5200.00 92.294 176.844 3599.15 5400.00 92.294 176.844 3591.15 5547.92 92.294 176.844 3585.22 5600.00 90.339 176.125 3584.03 5609.03 90.000 176.000 3584.00 5674.34 91.680 178.001 3583.04 5800.00 91.680 178.001 3579.36 6000.00 91.680 178.001 3573.49 6200.00 91.680 178.001 3567.63 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3593,09 1598.43 S 1209.74 E 5958255.24 N 561713.15 E 3610.76 1616.52 S 1225.85 E 5958237.27 N 561729.41E 3611.61 1617.45 S 1226.68 E 5958236.35 N 561730.24 E 3657.15 1684.88 S 1284.37 E 5958169.38 N 561788.47 E 3673.42 1728.47 S 1319.75 E 5958126.08 N 561824.21E 3683.36 1764.75 S 1348.68 E 5958090.03 N 561853.42 E 3698.93 1842.02 S 1399.70 E 5958013.18 N 561905.07 E 3705.00 1906.24 S 1429.12 E 5957949.20 N 561935.00 E 3706.25 1933.59 S 1438.79 E 5957921.93 N 561944.89 E 3707.41 2030.79 S 1461.71E 5957824.91N 561968.60 E 3705.94 2085.83 S 1467.32 E 5957769.92 N 561974.64 E 3700.15 2230.13 S 1475.28 E 5957625.69 N 561983.76 E 3692.15 2429.66 S 1486.28 E 5957426.25 N 561996.37 E 3686.22 2577.24 S 1494.42 E 5957278.74 N 562005.70 E 3685.03 2629.21S 1497.61E 5957226.80 N 562009.31E 3685.00 2638.22 S 1498.23 E 5957217.80 N 562010.00 E 3684.04 2703.43 S 1501.65 E 5957152.62 N 562013.94 E 3680.36 2828.95 S 1506.03 E 5957027.13 N 562019.34 E 3674.49 3028.75 S 1513.00 E 5956827.40 N 562027.92 E 3668.63 3228.54 S 1519.98 E 5956627.67 N 562036.50 E Dogleg Rate (°/100ft) 12.000 14.oo0 14,000 14.000 0.000 12.003 12.003 10.000 10.000 10.000 0.000 0.000 0.000 4.000 4.000 4.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 1911.29 1933.74 1934.89 2017.75 2070.67 2114.54 2204.44 2274.80 2303.81 2403.08 2456.81 2595.44 2787.14 2928.92 2978.95 2987.65 3050.24 3169.98 3360.57 3551.16 Comment ST Exit @ 12.000°/100ft, 0.000° TF: 4468.50ft MD, 3593.09ft TVD Increase in Dir Rate @ 14.000°/100ft: 4498.50ft MD, 3610.76ft TVD End Dir' 4658.50ft MD, 3673.42ft TVD Begin Dir @ 12.003°/100ft: 470'5.95ft MD, 3683.36ft TVD Decrease in Dir Rate @ 10.000°/100ft: 4870.96ft MD, 3705.00ft TVD Target - 1D-102 D-Sand T1 End Dir' 5055.36ft MD, 3705.94ft TVD Be.qin Dir @ 4.000°/100ft: 5547.92ft MD, 3686.22ft TVD Target - 1 D-102 D-Sand T2 End Dir · 5674.34ft MD, 3684.04ft TVD Continued... 9 May, 2000 - 9:05 - I - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D-102 WPs - 1D-102 L1 Wp3 Revised: 8 May, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth ~t) (ft) 6400.00 91.680 178.001 3561.77 6572.20 91.680 178.001 3556.72 6600.00 90.725 177.432 3556.13 6621.09 90.000 177.000 3556.00 6674.21 91.773 178.172 3555.18 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3662.77 3428.33 S 1526.95 E 5956427.94 N 562045.08 E 3657.72 3600.36 S 1532.96 E 5956255.97 N 562052.47 E 3657.13 3628.12 S 1534.07 E 5956228.21 N 562053.81 E 3657.00 3649.19 S 1535.09 E 5956207.16 U 562055.00 E 3656.18 3702.25 S 1537.33 E 5956154.11 U 562057.66 E 6800.00 91.773 178.172 3551.29 3652.29 3827.92 S 1541.34 E 5956028.49 N 562062.69 E 7000.00 91.773 178.172 3545.10 3646.10 4027.72 S 1547.72 E 5955828.74 N 562070.67 E 7200.00 91.773 178.172 3538.91 3639.91 4227.52 S 1554.10 E 5955629.00 N 562078.66 E 7358.80 91.773 178.172 3534.00 3635.00 4386.16 S 1559.16 E 5955470.40 N 562085.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-102 WPs. Northings and Eastings are relative to 1 D-102 WPs. Dogleg Rate (°/100ft) 0.000 0.000 4.000 4,000 4.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section ~t) 3741.75 3905.85 3932.38 3952.57 4003.32 4123.07 4313.47 45O3.87 4655.04 Comment Begin Dir @ 0.000°/100ft: 6572.20ft MD, 3657.72ft TVD Target- 1 D~102 D-Sand T3 End Dir '. 6674.21ft MD, 3656.18ft TVD Total Depth: 7358.80ft MD, 3635.00ft TVD Target - 1D-102 D-Sand T4 The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1 D-102 WPs and calculated along an Azimuth of 160.431° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7358.80ft., The Bottom Hole Displacement is 4655.04ft., in the Direction of 160.431° (True). Continued... 9 May, 2000 - 9:05 - 2 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D-102 WPs - 1D-102 L1 Wp3 Revised: 8 May, 2000 Alaska State Plane 4 Kuparuk 1D Comments Measured Depth ~t) 4468.50 4498.50 4658.5O 4705.95 4870.96 5055.36 5547.92 5674.34 6572.20 6674.21 7358.80 Formation Tops Measured Depth (ft) 4390.24 Station Coordinates TVD ~t) 3593.09 3610.76 3673.42 3683.36 3705.00 3705.94 3686.22 3684.04 3657.72 3656.18 3635.00 Northings (ft) 1598.43 S 1616.52 S 1728.47 S 1764.75 S 1906.24 S 2085.82 S 2577.24 S 2703.43 S 3600.35 S 3702.25 S 4386.16 S Eastings ~t) 1209.74 E 1225.85 E 1319.75 E 1348.68 E 1429.12 E 1467.32 E 1494.42 E 1501.65 E 1532.96 E 1537.33 E 1559.16 E Ve~ical Depth (fi) 3545.00 Sub-Sea Depth (ft) 3444.00 Northings (ft) 1552.31 S Comment ST Exit @ 12.000°/100ft, 0.000° TF: 4468.50ft MD, 3593.09ft TVD Increase in Dir Rate @ 14.000°/100ft: 4498.50ft MD, 3610.76ft TVD End Dir: 4658.50ft MD, 3673.42ft TVD Begin Dir @ 12.003°/100ft: 4705.95ft MD, 3683.36ft TVD Decrease in Dir Rate @ 10.000°/100ft: 4870.96ft MD, 3705.00ft TVD End Dir: 5055.36ft MD, 3705.94ft TVD Begin Dir @ 4.000°/100ft: 5547.92ft MD, 3686.22ft TVD End Dir: 5674.34ft MD, 3684.04ft TVD Begin Dir @ 0.000°/100ft: 6572.20ft MD, 3657.72ft TVD End Dir: 6674.21ft MD, 3656.18ft TVD Total Depth: 7358.80ft MD, 3635.00ft TVD Eastings Formation Name (ft) 1168.69 E K-13 Shale Continued... 9 May, 2000 - 9:05 - 3 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D-102 WPs - 1D-102 L1 Wp3 Revised: 8 May, 2000 Alaska State Plane 4 Kuparuk 1D Targets associated with this wellpath Target Name 1D-102 D-Sand T1 1D-102 D-Sand T2 1D-102 D-Sand T3 1D-102 D-Sand T4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target TVD (ft) 3705.00 3604.00 3685.00 3584.00 3657.00 3556.00 3635.00 3534.00 Entry Coordinates Northings Eastings (ft) (ft) 1906.24 S 1429.12 E 5957949.20 N 561935.00 E 70° 17'44,3273"N 149° 29' 54.5942"W 2638.22 S 1498.23 E 5957217.80 N 562010.00 E 70° 17'37.1275"N 149° 29'52.5839"W 3649.19 S 1535.09 E 5956207.16 N 562055.00 E 70°17'27.1836"N 149° 29'51.5156"W 4386.16 S 1559.16 E 5955470.40 N 562085.00 E 70° 17'19.9348"N 149° 29' 50.8185"W Target Target Shape Type Point Point Point Point 9 May, 2000 - 9:05 - 4 - DrillQuest 1.05.05a 16" DIV RTER SCHEMATIC- I '--' rdic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 10" 150 ANSI Blanked Open ~ ~ ~,- To Accumulator I Closed ' 'q'' ...... ..t i ~_- ~ I.~ From Accumulator 4 3 Closed 3" Ball Valve Blanked Open Maintenance & Operation 1. Upon initial installation: . Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16"x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line- Nordic MAC 3/7/OO .... 11" 5000 psi BOP Sta:: Kuparuk River Unit West Sak Operations - Producer Wells 6 4 2 [ Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Pipe Rams 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines 5. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 6. 11" 5000 psi Annular Preventer MAC 3/15/OO Greater Kuparuk Area Casing Pressure Test Standard Draft 4 The AOGCC requires a 30 minute casing pressure test prior to drilling out the float equipment. Current AOGCC regulations require surface casings to be tested to 1500 psi or 0.25 psi/ft, whichever is greater. This test needs to be charted for the AOGCC. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Casing Test Procedure Pressure test the surface casing to the value specified in the well plan, above and below the stage collar, if one has been run. Hold each of these tests for 10 minutes to insure the stage collar is completely closed. The AOGCC does not require this test to be charted. Check the well plan for any site specific drill out details. 2. Run in hole to top of baffle plate or float collar, whichever occurs fn:st. Establish circulation and insure well is stable for the 30 minute test. Pressure test surface casing to the value outlined in the well plan for 30 minutes. This test needs to be charted for the AOGCC. Pressure vs. volume needs to be plotted for AAI records and as a minimum volume line for the upcoming LOT/FIT. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record the pump pressure every two pump strokes until the pressure specified in the well plan is reached (this will insure enough data points on the LOT/FIT). Monitor shut in casing pressure for 30 minutes. Make sure test is being accurately recorded on a chart. Check surface equipment for leaks if pressure drops more than 10 percent in 30 minutes. If surface leaks are discovered repair them and do the casing test over. If no surface leaks are found and casing pressure continues to bleed off contact, the AAI Drilling Engineer assigned to the rig, prior to drilling out the casing float equipment. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 4. After achieving a successful casing test. Drill out remaining cement and all float equipment. Clean out any existing rat hole. Drill 20 feet of new hole. Perfotw~ a LOT/FITper the standard procedure that follows. RLM 7/31/98 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. 5. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 · --...,0 ;::' ~,! =~ ~l~ ~:"-::: '::,...:':'.::::..~:' '::.~ ~ '~ .? :? :~_ :~:..~:'.-'::' :~-:~:.-..:?.~' ? ::~ :~:-!:.. ~ ' ~-.~~ ~~"~.~0. ~-'."" '- .-"~-":-':-.~':.':~.' '~' "': .... ~i' ~'.'.--/.:'-.":':'-.'~.'" ."'' ' , ~.-..'. "-.' · . .-..' '; '.. ' .'. To ~ order of: 05-z2-00 **************z00. o0- STATE OF ~ Date ~ount ~ OIL & G~ CONSERVATION C~ISSION Void ~ter 90 days 3001 ~R~PINE D~ . . :..;~ :. :. _'--. ... ":....~:"... ~~a~m~-.~m~,~.~.~ ~,~o.~.~_~,i.~:~.~.~}¢'.. '-' '..~' :'.'2'k" ':'.. ' - · -. ' .' '--. 2' .~ :' -- -: " - '~. '" .. ' '" : . . ' ' ~'OOOO ~OOq 5~' I:O~ 3qoc 2& 2': oq qoooo"' WELL PERMIT CHECKLIST FIELD & POOL C/'g](~/ ADMINISTRATION A~..~ DATE 12. ~-7/'7, L~ 13. WELL NAME/Z)-/L.b2../--! PROGRAM: exp __ dev v" redrll __ serv __ wellbore seg __ann. disposal para req COMPANY ENGINEERING _PPR DATE INIT CLASS --'~~"¥ 1. Permit fee attached. 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located 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 ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait. ' 14. Conductor string provided ................... 15. Surface casing protects all known USDWs... ' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program Schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~C~L_%r~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA UNIT# ON/OFFSHORE 30. Permit can be issued w/o hydrogen sulfide measures ..... (:~ N Data presented on potential overpressure zones ....... ,~/. ,~ Y N Seismic analysis of shallow gas zones ............. /t,/~ Y N Seabed condition survey (if off-shore) ............. ,,,rd/-/ Y N Contact name/phone for weekly progress reports [exploratory ot~,l/yi~ Y N GEOLOGY 31. 32. A~ DATE 33. ~/'7 ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N COMMISSION: ENGINEERING: UIC/Annular Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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 SRevision: 3 $ LisLib SRevision: 4 $ Wed Sep 06 14:01:37 2000 Reel Header Service name ............. LISTPE Date ..................... 00/09/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/09/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 1D-102 L1 500292296060 Phillips Alaska, Inc. Sperry Sun 06-SEP-00 MWD RUN 1 AK-MM-00058 D. LABRECQUE D. HIEM MWD RUN 2 AK-MM-00058 D. LABRECQUE D. HIEM 14 lin 10E 179 595 .00 101.60 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 13.375 110.0 2ND STRING 6.000 7.625 4170.0 3RD STRING 6.000 7.000 4368.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUNS l&2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE MWD GR FROM WELL 1D-102. MWD DATA IS CONSIDERED PDC. ALL HEADER AND LOG DATA RETAIN THE ORIGINAL DRILLER'S DEPTH REFERENCES. THIS WELL KICKS OFF FROM 1D-102 AT 4368'MD, 3559'TVD. 4. MWD RUNS l&2 REPRESENT WELL 1D-102 L1 WITH API#: 50-029-22960-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5354'MD, 3741'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (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 ....... 00/09/06 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: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 4330.5 FET 4358.0 RPD 4358.0 RPM 4358.0 RPS 4358.0 RPX 4358.0 ROP 4381.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 7350.5 7357 5 7357 5 7357 5 7357 5 7357 5 7403 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 4331.0 5079.0 2 5079.0 7404.0 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 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 Name Service Unit Min Max Mean Nsam DEPT FT 4330.5 7403.5 5867 6147 ROP MWD FT/H 0 338.94 151.825 6046 GR MWD API 34.22 124.23 78.3815 6041 RPX MWD OHMM 0.17 2000 43.4677 6000 RPS MWD OHMM 0.31 2000 64.0147 6000 RPM MWD OHMM 0.24 2000 60.1262 6000 RPD MWD OHMM 4.01 2000 63.4119 6000 FET MWD HOUR 0.23 12.54 0.974337 6000 First Reading 4330.5 4381 4330.5 4358 4358 4358 4358 4358 Last Reading 7403 5 7403 5 7350 5 7357 5 7357 5 7357 5 7357 5 7357 5 First Reading For Entire File .......... 4330.5 Last Reading For Entire File ........... 7403.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/06 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 ....... 00/09/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4330.5 RPX 4358.0 FET 4358.0 RPD 4358.0 RPS 4358.0 RPM 4358.0 ROP 4381.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT : BIT ROTATING SPEED (RPM : HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: 5035 5035 5079 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA STOP DEPTH 5028 5 5035 5 5O35 5 5035 5 5 5 0 21-JUN-00 Insite 65.44 MEMORY 5082.0 66.9 89.9 TOOL NUMBER PB1542GR4 PB1542GR4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 6.000 4368.0 BARADRIL-N 9.20 44.0 8.2 29000 9.5 .160 .126 .110 .200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 R?D MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 75.0 97.0 75.0 75.0 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR Min 4330.5 0 34 22 0 17 0 31 0 24 4 01 0 25 Max Mean Nsam 5079 4704.75 1498 237.39 86.5429 1397 124.23 91.159 1397 2000 19.0356 1356 2000 24.9671 1356 2000 48.7669 1356 2000 68.7631 1356 2.83 1.36759 1356 First Reading 4330.5 4381 4330.5 4358 4358 4358 4358 4358 Last Reading 5079 5079 5028 5 5035 5 5035 5 5035 5 5035 5 5035 5 First Reading For Entire File .......... 4330.5 Last Reading For Entire File ........... 5079 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/06 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 ....... 00/09/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW 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 STOP DEPTH GR 5029.0 7350.5 RPD 5036.0 7357.5 RPM 5036.0 7357.5 RPS 5036.0 7357.5 RPX 5036.0 7357.5 FET 5036.0 7357.5 ROP 5079.5 7403.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 23-JUN-00 Insite 65.44 MEMORY 7407.0 89.0 93.8 TOOL NUMBER PB1542GR4 PB1542GR4 BOREHOLE AND CASING DATA' OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY {LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 6.000 4368.0 BARADRIL-N 9.10 44.0 9.1 29000 8.9 .160 .137 .110 .200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 75.0 89.0 75.0 75.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min Max Mean Nsam 5029 7403.5 6216.25 4750 0 338.94 171.441 4649 49.91 98.8 74.5378 4644 7.82 2000 50.6016 4644 10.86 2000 75.4162 4644 13.26 1668.56 63.4431 4644 18.39 1650.03 61.8494 4644 0.23 12.54 0.859511 4644 First Reading 5029 5079.5 5029 5036 5036 5036 5036 5036 Last Reading 7403 5 7403 5 7350 5 7357 5 7357 5 7357 5 7357 5 7357 5 First Reading For Entire File .......... 5029 Last Reading For Entire File ........... 7403.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/09/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/09/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File