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} Y STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COIVIDSION CO REPORT OF SUNDRY WELL OPERATIONS A0(-)CC 1. Operations Performed: Abandon E Repair w ell ("" Plug Perforations E Perforate E Other j Alter Casing ("` Pull Tubing (✓ . Stimulate - Frac r Waiver l Time Extension r Change Approved Program i""'Operat. Shutdow n f Stimulate - Other r Re -enter Suspended Well p 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. , Development f;: • Exploratory E 198 -246 • 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service l 50 029 - 22934 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 28242 1C • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool . 11. Present Well Condition Summary: Total Depth measured 11918 • feet Plugs (measured) 11322 true vertical 6804 feet Junk (measured) none Effective Depth measured 11829 feet Packer (measured) 11177, 11275 true vertical 6757 feet (true vertical) 6416, 6467 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 7363 9.625 7404 4520 PRODUCTION 11885 7 11918 6804 I Perforation depth: Measured depth: 11470 - 11510 SCANNED JUN 1 8 2013 True Vertical Depth: 6569 - 6591 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 11255 MD, 6456 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 3 -1/2" X 7" FHL PACKER @ 11177 MD and 6416 TVD PACKER - BAKER S -3 PERMANENT PACKER @ 11275 MD and 6467 TVD SSSV - CAMCO TRMAXX- CMT -5 -SR SSSV @ 2007 MD and 1755 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory F Development ii • Service E Stratigraphic E 16. Well Status after work: Oil F . Gas E WDSPL E Daily Report of Well Operations _XXX GSTOR E WINJ (- WAG E GINJ E SUSP E SPLUG im 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 Jake Voss @ 265 -6935 Email Jake.Vossecop.com Printed Name J ke Vo Title Wells Engineer Signature ,,"■-` Phone: 265 -6935 Date 6 /ttfi 3 1. ''LF RBDMS JUN - 7 2013 4/14 l 1 3 / 0;173 Submit Original Only Form 10 -404 Revised 10/2012 g y KUP • 1C -16 Conoco Phillips n Angle TD D Al, : iSita,~,.; . Wellbore API /UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) P 1ygps Well Attributes Max MaX Aag e & M 500292293400 KUPARUK RIVER UNIT PROD 62.31 10,157.58 11,918.0 " "' Comment H2S (ppm) Date Annotation End Date KB - Ord (ft) Rig Release Date ' SSSV: TRDP 60 9/25/2011 Last WO: 5/17/2013 46.31 1/1/1999 Well Confq -1C- 16,12013' : chematic 614 - Actu12 59 17 PM al Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,627.0 5/24/2013 Rev Reason: Tag, GLV C /O, Pull RHC Plugs & Catcher osborl 6/4/2013 Casing Strings HANGER, 37 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String String Top Thrd 9 P 9 9 P( ) th P P( ) 9 9 9 P -- CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 41.0 7,403.7 4,519.7 40.00 L -80 BTC ql MEril Casing Description Stri 0... String ... (ftKB) Set Depth (f... Set Dep (N ... String Wt... String ... String d PRODUCTION 7 6.276 38.9 11,924.4 26.00 L -80 ABM -BTC Tubing Strings Tubing Description Stri 0... String ID ID ,.. TT (ftKB) Set Depth (1... Set Depth th (TVD) D) ... String Wt... String ... String Top Top Thrd TUBINGWO 3 1/2 2.992 37.1 11,255 6,455,9 9.30 L -80 EUE Thrd CONDUCTOR, Completion Details 42 -121 Top Depth (ND) Top Inc! Noml... Top (ftKB) (558) (°) Item Description Comment ID (In) 37.1 37.1 -0.51 HANGER FMC Gen3 7 X 3 1/2' Tubing Hanger w /pup 2.992 I 2,006.5 1,754.6 52.85 SAFETY VLV 3.5" TRMAXX- CMT -5-SR Safety Valve Ser.# C11S -0617 2.812 SAFETY Z 007 f_ _ ,.=', I 11,147.6 6,400.5 58.76 SEAL ASSY Baker Locator Seal Assembly 2.990 11,154.6 6,404.2 58.76 PBR Baker PBR 3.000 11,177.0 6,415.8 58.76 PACKER Baker 3-1/2" x 7 FHL Packer 2.900 11,198.6 6,425.9 58.01 NIPPLE 3.5 x 2.812 HES "X" Nipple 2.812 GAS LIFT. I _ 11,247.21 6,451.8 58.05 OVERSHOT Baker Poor Boy Overshot 2.990 1 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING (original) 3 1/2 2.992 11,247.8 11,334.0 6,497.7 9.30 L -80 ABM -EUE Completion Details Top Depth GAS LIFT, . (ND) Top'nel Nomi... 6,010 Top (ftKB) (*KB) ( °) Item Description Comment ID (In) 11274.7 6,466.3 58.07 PACKER BAKER S-3 PERMANENT PACKER 3.875 1111 11,321.9 6,491.3 58.11 NIPPLE CAMCO D NIPPLE w/ NO GO PROFILE 2.750 11,333.0 6,497.2 58.12 SOS BAKER SHEAR OUT SUB 3.015 Perforations & Slots BURF -_� Shot a1 - 7,ao4 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (MB) (ftKB) (ftKB) Zone Date inn.- Type Comment GAS LIFT, c 11,470.0 11,510.0 6,569.4 6,590.5 C - 4, 1C - 16 1/21/1999 4.0 IPERF DP, 18odeg ph, 90deg orient from low 7,753 Side Stimulations & Treatments M I Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) P P l ) GASLIF (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 9,1ze 11,470.0 11,510.0 6,569.4 6,590.5 FRAC 11/22/2002 = Notes: General & Safety End Date Annotation - 8/12/2009 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 10.226 GAS LIFT, _ 11,081 MI all SEAL ASSY, 11.148 -...es PBR,11,155 IIIIII PACKER. _ .. - 11.177 NIPPLE,11.199 hi.... OVERSHOT, 11,247 I m PACKER. 11,275 I Mandrel Details IF Top Depth Top Port NIPPLE, 11,322 A S... (TVD) Incl OD Valve Latch Site TRO Run N... Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,445.7 2,498.3 60.06 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,291.0 5/23/2013 SOS. 11.333 2 6,009.9 3,810.0 60.78 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,280.0 5/23/2013 3 7,753.1 4,695.7 59.81 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,305.0 5/22/2013 4 9,127.6 5,397.9 59.61 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 5/22/2013 IPERF, 5 10,225.9 5,946.5 62.18 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/22/2013 11.470 11510 N FRAC, 11,470 _ 7 . 6 11,081.3 6,366.2 58.77 Camco KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 5/16/2013 72,11,918 PRODUCTION, 39- 11,924 1C-16 Pre -Rig Well Work DATE SUMMARY • • 3/23/2013 BRUSHED & DRIFTED TBG, TAGGED @ 11583' SLM. MEASURED BHP @ 11449' SLM: 3717 PSI. LOCKED OUT TRDP -4E SSSV @ 2069' RKB. SET 2.75 CA -2 PLUG @ 11321' RKB. COMBO MIT 2500 PSI / 500 PSI, PASSED. IN PROGRESS. 3/24/2013 SET 3 -1/2 CATCHER ON CA -2 PLUG @ 11321' RKB. PULLED GLVs @ 3623' & 6166', OV @ 7713' RKB. ATTEMPTED SET DVs @ 3623' & 6166' RKB. SET DV @ 7713' RKB. IN PROGRESS. 3/25/2013 SET DVs @ 3623' & 6166' RKB. PULLED DV @ 11179' RKB. READY FOR E -LINE. 4/28/2013 SHOOT STRING SHOT WITH MID SHOT AT 11248' CCL TO MID SHOT 5' CCL STOP AT 11243' JOB STOPPED DUE TO PHASE CONDITIONS JOB CONTINUES 4/29/2013 CUT TUBING WITH A CUT DEPTH OF 11,248'. CCL TO CUT DEPTH WAS 9.5'. CCL STOP DEPTH WAS 11,238.5'. JOB COMPLETED • • Conoc Time Log & Summary We "view Web Reporting Report Well Name: 1C-16 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/10/2013 7:30:00 PM Rig Release: 5/17/2013 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/10/2013 24 hr summary Rig Move from 2F -pad. Accept rig @ 19:30 hrs on 1C -16. Rig up containment and lines in cellar, spot cutting tank with containment. Rig up hard line to Kill tank. Pre -Spud Meeting with Mike's Crew. 03:00 19:30 16.50 MIRU MOVE MOB P Move rig from 2F pad to 1C -16. 19:30 21:30 2.00 MIRU MOVE RURD P Rig Accept. Lay down cellar liner, rig up hoses and lines in cellar. 21:30 23:00 1.50 MIRU MOVE RURD P Spot cutting tank & secondary containment. Rig up hard line to Kill tank. Start taking on 9.6# Brine with .6% safe lube. 23:00 00:00 1.00 MIRU RPCOM SFTY P Pre -spud meeting with Mike's crew. 05/11/2013 Rig up and test all lines, Pull BPV with 1000 psi below. Kill well pumping 9.6# brine, install BPV, ND Tree, NU BOPE & test 250 /3500psi. State test Witnessed b Lou Grimaldi. 00:00 -02 :30 - 2.50 COMPZ WHDBO MPSP P Test surface lines to choke, Rig up Lubricator and Pull BPV. 02:30 04:00 1.50 COMPZ WHDBO PRTS P Finish rigging up hard line to Kill tank. Pressure test 250/3000 psi. 04:00 06:00 2.00 COMPZ WHDBO KLWL P PJSM - Pump 9.6# brine, 3 bpm @ 800 psi. Reverse 50 bbls, Stop record pressures - Start well kill pumping long way. Choke and Kill drill. 06:00 08:00 2.00 COMPZ WHDBO KLWL P Stop Pumping to remove fluid from Kill tank. KWF at the end of the tubing string. Crew change. 08:00 11:00 3.00 COMPZ WHDBO KLWL P PJSM. Circulate 2 bpm holding 690 on Tbg, holding 970 psi on choke intial to 500 psi final. Pumped 320 bbls with 303 bbls to kill tank. 11:00 12:30 1.50 COMPZ WHDBO KLWL P Blow down Hardline. Suck out Kill Tank. Circulate 100 bbls at 2 bpm through Gas Buster until 9.6 ppg returns. ICP 140 psi, FCP 150 psi. 12:30 14:00 1.50 COMPZ WHDBO KLWL P Monitor Well. 10 psi on IA, 0 psi Tbg. Reverse circ 20 bbls down Tbg returns up IA. 14:00 14:30 0.50 COMPZ WHDBO OWFF P IA 0 psi, Tbg 0 psi. Monitor 30 minutes static. 14:30 15:30 1.00 COMPZ WHDBO MPSP P PJSM. Set BPV. Test 1000 psi from below for 10 minutes. Good test. 15:30 17:00 1.50 COMPZ WHDBO NUND P ND Tree 17:00 20:00 3.00 COMPZ WHDBO NUND P NU BOPE Page 1 of S • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment COMPZ WHDBO BOPE P PJSM - Start BOPE 250/3500 psi. State test Witnessed by Lou Grimaldi. Compared both test charts - Barton chart recorder vs Totco system. 05/12/2013 Complete BOPE test, pull test plug and PBV. M/U Landing joint, BOLDS, P/U 128K - broke over to 117K. Circulate 500 bbls @ 5-bpm / 600 psi, well cleaned up, no -flow for 30 minutes. TOOH with decompletion string, recovered all 35 SV bands. Eroded collars started on joint # 289 down to # 300. Pinhole in joints # 290 (9143') & # 290 (9170'). Continue TOOH, heavier scale on tubing from joints # 319 -342. 00:00 02:00 2.00 0 0 COMPZ WHDBO BOPE P BOPE test 250/3500 psi. One failure - manual valve on the choke line. Functioned, greased and tested. 02:00 04:00 2.00 0 11,248 COMPZ RPCOM SEQP P PJSM - pull test plug & BPV. Start loading new 3.5" pipe in ODS shed. 04:00 05:00 1.00 11,248 11,218 COMPZ RPCOM RTWH P PJSM - make up landing joint, P/U on completion string. Max Pull 128K, - broke over to 117K - pull tubing hanger above rig floor. 05:00 07:00 2.00 11,218 11,218 COMPZ RPCOM CIRC P Reverse circulate at 5 bpm - 600 psi ICP. Circulate until returns clean at 491 bbls away- FCP 560 psi. 07:00 07:30 0.50 11,218 11,218 COMPZ RPCOM PULL P Pull Hanger to Floor 110 k #. LD Landing Joint, Hanger. Mionitor Well- static. 07:30 11:30 4.00 11,218 9,158 COMPZ RPCOM PULD P PJSM, RU Camco Spooler, POOH from 11218' to 9158'- 95k# up, 72k# down. RD and offload Spooler- all 35 SS Control Line Bands recovered. 11:30 13:00 1.50 9,158 9,158 COMPZ RPCOM SLPC P Slip and Cut Drill Line 13:00 19:00 6.00 9,158 5,000 COMPZ RPCOM PULL P Continue POOH from 9158' 19:00 22:30 3.50 5,000 2,100 COMPZ RPCOM PULL P Circulate while offloading pipe from shed. Continue TOOH. Stop at damaged section to inspect Tubing. Joint # 289 to # 300 - damaged collars, still had integrity Joint # 290 - Pinhole part way down joint = 9143' Joint # 291 - Pinhole = 9170' 22:30 00:00 1.50 2,100 1,200 COMPZ RPCOM PULL P Continue TOOH J5/13/2013 TOOH with decompletion string, found mechanical cut on joint 355 (11,247'). Load and tally new 3.5" completion string, P/U 7 "scraper and with 5 3/4" wash over boot basket. TIH down to tubing stub @ 11,243' Pre -spud meeting with Cody Crew. 00:00 02:30 2.50 1,200 0 COMPZ RPCOM PULL P TOOH with decompletion string. Heavier scale on tubing from joint 319 - 342. Total joints on surface 354 + 14ft of the cut joint = 11,247' on surface. Clean cut. 02:30 07:30 5.00 0 COMPZ RPCOM PULD P Discuss with town to run 7" scraper due to additional scale and erosion on tubing. Continue loading & drifting new 3.5" completion string. Page 2 of 5 • I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 10:30 3.00 COMPZ RPCOM PULD P Load tools, change out floor equipment, load Drill Collars, and prep for Scraper run. 10:30 12:00 1.50 0 220 COMPZ RPCOM PULD P PJSM, Install Wear Ring, MU BHA #1 Baker 7" Casing Scraper. 12:00 16:00 4.00 220 2,800 COMPZ RPCOM TRIP P Single in with Casing Scraper on 3 -1/2" EUE Tubing to 2800' 16:00 17:00 1.00 2,800 2,800 COMPZ RPCOM OTHR P Rearrange Pipe Shed 17:00 00:00 7.00 2,800 10,400 COMPZ RPCOM TRIP P Continue to single in with Casing Scraper on 3 -1/2" EUE Tubing to 2800' 35/14/2013 Wash over tubing stub @ 11,248' - good pressure indication near no -go over 3.5" stub. P/U weight 110K / Dwn 80K. Circulate B/U @ 9 bpm /1900 psi. - TOOH, layed down BHA #1. Pulled wear ring and noticed a 1" X 6" chunk of steel sheared off top of wear ring. M/U BHA # 2 with 6 1/8" flat bottom shoe and washer over boot. RIH. 00:00 01:00 1.00 10,400 11,200 COMPZ RPCOM PUTB P TIH down to 11,200 01:00 02:00 1.00 11,200 11,200 COMPZ RPCOM CIRC P Make up connection, Circ B/U 5 bpm - 600 psi. Hold Pre -spud with Cody crew. 02:00 03:30 1.50 11,200 11,243 COMPZ RPCOM WASH P Wash over tubing stub, small weight bobble @ 11, 236' (KB correction 11,245') wash down to 11, 243' @ 5 bpm, 600 psi - increased near no -go to 1200 psi. P/U weight 110K, 80K Dwn weight, 9 ft of swallow over stump. Cycle and clean over stump three times, cleaned up. Circulate B/U - 9 bpm © 1940 psi - recovered light sand, scale and metal debris over shakers. 03:30 12:30 9.00 11,243 1,243 COMPZ RPCOM TRIP P Blow down Top drive, Flow check. PJSM - POOH standing back completion string. 12:30 15:00 2.50 1,243 0 COMPZ RPCOM PULD P laid down Drill collars and BHA. 15:00 15:30 0.50 0 0 COMPZ RPCOM OTHR P pulled 7 1/16" wear ring . Ring was damaged ( see photo's in well file) missing appoximatly a 6" X 1" chunk from top of ring. sucked out BOPE stack piece was not in the preventors. 15:30 18:30 3.00 0 0 COMPZ RPCOM OTHR T wait on 6 1/8" shoe. Load and strap 10 more joints of 3.5" completion. Kick out Drill collars. 18:30 20:30 2.00 0 218 COMPZ RPCOM PULD T Make up BHA #2 with 6 1/8" flat bottom shoe and washer boot. 20:30 00:00 3.50 218 10,600 COMPZ RPCOM TRIP T TIH with 3.5" completion string. 35/15/2013 TIH with BHA # 2 to drift down to 3.5" stump. Tagged stump @ 11,245' could not get over with flat bottom shoe, max. set down 5K, pump 5 bpm to sweep the hole. TOOH - found missing chunk of metal in junk basket. P/U completion string. TIH, pump 3 bpm, pressure increase over 3.5" stump @ 11,253' with overshot. Space out and circulate inhibited SW. 00:00 01:00 1.00 10,600 11,200 COMPZ RPCOM TRIP P TIH with BHA # 2 Page 3 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 11,200 11,236 COMPZ RPCOM WASH T Attempt to wash over stump - P/U weight dry 110K / Wet 105K. Dwn weight 80K. Made multiple attempts to get BHA over tubing stump, max set down weight of 5K. No luck tag same spot @ 11,245' with KB correction in. 02:00 02:30 0.50 11,236 11,225 COMPZ RPCOM SFTY T 30 minute flow check - blow down top drive, PJSM - POOH. 02:30 09:30 7.00 11,225 98 COMPZ RPCOM TRIP T POOH WITH 3.5 x 9.3 # L -80 UEU 8rd tubing and BHA 09:30 10:30 1.00 98 0 COMPZ RPCOM TRIP T laid down BHA 2 recovered broken piece of wear ring in boot basket. 10:30 11:30 1.00 0 0 COMPZ RPCOM OTHR P cleared floor of tools 11:30 18:30 7.00 0 9,230 COMPZ RPCOM PUTB P picked up boor boy over shot Baker FH packer 7" -26# RIH with production equipment 18:30 23:00 4.50 9,230 11,244 COMPZ RPCOM PUTB P Make up SSSV line, hold 5000 psi on line while TIH. No go out on joint # 358 - estimated depth 11,244' - corrected depth = 11,253' (7ft swallow). P/U weight 115k, Down 80K. Set down and sheared the screws 8K down weight. Circ 2 bpm - 140 psi - slowly enganged tubing stub and pressure increased 200 psi. 23:00 00:00 1.00 11,244 11,244 COMPZ RPCOM CIRC P Rig up trucks and pump inhibited SW the long way. Pumping 3 bpm @ 385 psi. Outside of packer limitation. 35/16/2013 Circulate inhibited SW. Tag No -go @ 11,243' - P/U 1.5' Up weight 107K / Dn weight 80K, drop 1- 5/16" ball & rod. Pressure up on packer to 2500 psi - good, P/U shear out 30K over. Space out 7ft on seal assembly and land tubing hanger. PT tubing - 3500 psi / 15 min., IA 2500 psi /30 min., No -flow for 30 minutes. pressure up and SOV @ 3000 psi, SSSV tested direction of flow to 1000 psi. Set BPV, RD BOPE, RU Tree, test 250/5000 psi, Freeze protect well. RDMO. ** total of 66 SSSV bands ran in well * ** Rig release @ Midnight. 00:00 02:30 2.50 11,244 11,230 COMPZ RPCOM CIRC P Continue circulating inhibited SW @ 3bpm /480 psi. Total pumped 290 bbls inhibited followed by 105 SW. Let well balance out. 02:30 03:30 1.00 11,230 11,243 COMPZ RPCOM CIRC T Prior to dropping ball & rod. Measured 1 7/8" called Y -pad shop - normally drop 1 - 5/16" with 3.5" completion, wait on correct ball /rod. Drop 1 5/16" ball /rod 03:30 03:30 05:30 2.00 11,243 11,230 COMPZ RPCOM PACK P P/U and space out 1.5' off no -go @ 11,243' mule shoe corrected depth of 11,252'. P/U weight 107K DW weight 80K. Pressure up to 2500 psi. Held for 10 minutes. Good. Bleed down to 1000 psi. P/U & shear 30K over. P/U additional 10ft - RIH and no -go out on seal assembly - P/U weight 106K. Space out 7 ft. Lay down 3 joints and P/U 24' of pups. Page 4 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 11,230 COMPZ RPCOM HOSO P Land Tubing Hanger. * ** Total of 66 bands for SSSV line * ** secured hanger 06:30 09:00 2.50 COMPZ RPCOM PRTS P PJSM rig up to PT TBG. & IA PT tubing to 3500 for 15 mins, bled pressure down to 1500 psi . PT IA to 2500 PSI for 30 mins. Blew SOV @ 3000 Psi . 09:00 09:30 0.50 COMPZ RPCOM OWFF P no flow well for 30 min's good. 09:30 10:00 0.50 COMPZ RPCOM PRTS P Test SSSV from flow direction to 1000 PSI for 15 mins gfood test. 10:00 11:00 1.00 COMPZ RPCOM RURD P Rig down Camco spooler and off load from floor. 11:00 16:00 5.00 COMPZ RPCOM NUND P Installed BPV. ND BOPE stack & NU X Tree 16:00 17:00 1.00 COMPZ RPCOM PRTS P Pressure test tree 250 /5000 p si. Pull BPV 17:00 21:00 4.00 COMPZ RPCOM FRZP P RU LRS pump 90 bbls of diesel down IA let well equalize. Starting pump pressure 300 psi / finish 350 psi. RD LRS Leave 6000 psi on SSSV line. 21:00 22:00 1.00 COMPZ RPCOM MPSP P Set BPV 22:00 00:00 2.00 DEMOB MOVE MOB P RDMO * ** Rig Release at Midnight * ** Page 5 of 5 1C-16 Post -Rig Well Work DATE SUMMARY 5/22/2013 PULLED BALL & ROD @ 11198' RKB, SOV @ 10225' RKB. PULLED DVs @ 9127, 7753 & 6010' RKB. SET DV @ 10225', OV @ 9127', GLV @ 7753' RKB. IN PROGRESS. 5/23/2013 PULLED DV @ 3445' RKB. SET GLVs @ 6010 & 3445' RKB. PULLED RHC PLUG BODY @ 11198' RKB, CATCHER © 11312' RKB. IN PROGRESS. 5/24/2013 PULLED 2.75" CA -2 PLUG @ 11321' RKB. TAGGED @ 11627' SLM. COMPLETE. WELL LOG TRANSMITTAL MAY 1 2013 AOGC1D To: Alaska Oil and Gas Conservation Comm. April 30, 20 Attn.: Makana Bender nt,Z2t G 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record/ String Shot: 1C-16 Run Date: 4/29/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1C-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22934-00 SCANNED MAR 13 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 mattinew.cook@halliburton.com Date: rJ 1G� ‘S Signed: 61 STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO4SION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air well Plug Ferforations Pe Install Patch � P � g r � Othe � Alter Casing E' Pull Tubing r "' Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n 1 Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Development I✓ Exploratory r 198 - 246 3. Address: 6. API Number: ��?? P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service - — 50- 029 - 22934 -00 —00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 28242 — 1C-16 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,- none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 11918 feet Plugs (measured) none true vertical 6804 feet Junk (measured) none Effective Depth measured 11829 feet Packer (measured) 9164, 9186, 11275 true vertical 6757 feet (true vertical) 5417, 5428, 6467 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 SURFACE 7363 9.625 7404 4520 PRODUCTION 11885 7 11918 6804 RECEIVED SCANNED JAN 16 2013 DEC 2 8 2012 Perforation depth: Measured depth: 11470' 11510' AOG+�G True Vertical Depth: 6569' -6591' t �,/ Tubing (size, grade, MD, and TVD) 3.5, L -80, 11334 MD, 6498 TVD ........ Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 9164 MD and 5417 TVD PACKER - WEATHERFORD ER PACKER @ 9186 MD and 5428 TVD PACKER - BAKER S -3 PERMANENT PACKER @ 11275 MD and 6467 TVD SSSV - CAMCO TRDP -4E SSSV @ 2070 MD and 1791 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory f Development ;� ' Service r Stratigraphic r 16. Well Status after work: r Oil 1 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ E SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce Ca)a, 265 -6471 Email John .W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 4 212.7f / z Form 10-404 Revise. 12/2. z- . 3 Lt, 3 1 2012 Aefh , „.. g / -r Submi Original Only 1C-16 Well Work Summary DATE SUMMARY 11/23/12 PULLED ER TEST TOOL AIltEATHERFORD UPPER PATCH ASSE1VOY @ 9164' RKB. CMIT T X IA ( 2500 PSI ) AGAINST LOWER ER PACKER W/ TEST TOOL ( PASS ) IN PROGRESS. 11/27/12 SET UPPERWEATHERFORD PATCH ASSEMBLY @ 9167' RKB. SET 3" ER TEST TOOL IN ER PACKER @ SAME. ATTEMPTED MIT TBG, TEST FAILED. CMIT PASSED. READY FOR E -LINE. 12/8/12 PERFORMED LDL WITH TECWELL ULTRASONIC LEAK DETECTING TOOL. ATTEMPTED TO ESTABLISH LEAK RATE AT 2000 PSI, 2500 PSI, 2700 PSI, AND 3000 PSI BUT UNABLE TO ESTABLISH RATE. PERFORMED MIT ON TUBING AND READINGS ARE AS FOLLOWS: MIT INITIAL T = 2500, IA = 1200, OA = 360 AFTER 15 MINUTES T = 2450, IA = 1230, OA = 360 AFTER 30 MINUTES T = 2450, IA = 1230, OA = 360 MIT PASSED KUP 1C -16 ConocoPhillips \ Well Attributes Max Angle & MD TD . a � { tf1G Wellbore API/UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm OMB) 500292293400 KUPARUK RIVER UNIT PROD 62.31 10,157.58 11,918.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date -iC Aol/ SSSV:TRDP 60 9/25/2011 Last WO: 46.31 1/1/1999 Well Cones Sche-i6,malk -Actual 2:25:05 PM Annotation Depth (KIM) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,600.0 7/24/2012 Rev Reason: SET PACH ASSY, TEST TOOL, GLV C/O ninam 11/6/2012 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd HANGER, 37 CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H - 40 WELDED \ Casing Description 'String 0... 'String ID ... Top (MB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 41.0 7,403.7 4,519.7 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (RK8) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.5 11,918.0 6,803.9 26.00 L -80 ABM -BTC Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 42 - 121 TUBING I 31/2 I 2.992 I Top (R 37.1 11,334.0 I 6,497.7 9.30 I L -80 I ABM -EUE Completion Details Top Depth (TVD) Top Inc! Nomi... i _ -/ Top (MO) (RKB) ( °) Rem Description Comment ID P ^) 37.1 37.1 -0.51 HANGER FMC GEN IV HANGER 3.500 SAFETY VLV, o , j 2,069.7 1,791.2 - 54.29 SAFETY VLV CAMCO TRDP -4E SAFETY VALVE 2.812 2,070 11,229.6 6,442.4 58.04 NIPPLE CAMCO W NIPPLE 2.812 11,274.7 6,466.3 58.07'PACKER BAKER S-3 PERMANENT PACKER 3.875 - - 11,321.9 6,491.3 58.11 NIPPLE CAMCO D NIPPLE w/ NO GO PROFILE 2.750 I -- 11,333.0 6,497.2 58.12 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT, , 3,623 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ' Top Depth - - -- (TVD) Top Inc! Top (ftKB) (ftKB) (9 Description Comment Run Date ID (!n) • 9,164 5,415.8 59.89 TOOL ER TEST TOOL (OAL=48") 10/24/2012 GAS LIFT, T ,_ 9,164 5,415.8 59.89 PACKER WEATHERFORD ER PACKER 10/24/2012 1.750 6,786 T 9,166 5,416.8 59.90 PATCH PATCH ASSEMBLY w/ SNAP LATCH 10/24/2012 1.750 9,186 5,426.7 60.06 PACKER WEATHERFORD ER PACKER 10/14/2012 1.750 Perforations & Slots Shot Top (N VD) D) Btm (T Dens J L Top (RKB) Btm )RKB) (RKB) (MB) Zone Date (sh... Type Comment SURFACE. 11,470 11,510 6,569.4 6,590.5 C 1C - 16 1/21/1999 4.0 IPERF DP, 180deg ph, 90deg orient from IOW 41 7,406 EE side L..._ Stimulations & Treatments GAS LIFT, _ Bottom 7,773 Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (MB) MB) (RKB) (RKB) Type Date Comment 11,470.0 11,510.0 6,569.4 6,590.5 FRAC 11/22/2002 ' '` '', ton, GAS LIFT, L End Date Annotation 8,984 � - 1 8/12/2009 NOTE: View Schematic w/ Alaska Schematic9.0 On PACKER : 9 : 164 TOOL, ,164 PATCH, 9,168 irto PACKER, 9,1 [ u GAS LIFT, _ __ _ B 10.065 GAS LIFT, 11,180 III NIPPLE. 11.230 I IN PACKER, 11,275 R, MI III■ IIII NIPPLE, 11,322 Mandrel Details Top Depth Top Port IF (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model , (in) Sery Type Type (in) (psi) Run Date Com... fie SOS, 11,333 1 3,623.4 2,588.4 59.23 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,290.0 2/5/2012 2 6,166.3 3,885.3 59.83 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,316.0 2/5/2012 3 7,713.2 4,675.8 59.86 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 8/7/2012 4 8,984.1 5,324.4 58.49 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 10/26/2012 Ext IPERF. . Pkg FRAAC, 11,70-11,510 70 III ' FRC, 70 5 10,064.5 5,871.6 62.49 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 11/8/2007 6 11,179.9 6,417.3 58.76 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/11/2002 PRODUCTION, 3717,111,:11:-\ A A STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMIDSION REPORT OF SUNDRY WELL OPERATIONS 4-6 1. Operations Performed: Abandon r Repair well r Plug Pbrforations r Perforate r Other Install Patch Alter Casing r Rill Tubing '"` Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r - 198 - 246 3. Address: 6. API Number: _ Stratigraphic r Service '"°' P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22934 - — 7. Property Designation (Lease Number): 8. Well Name and Number: , ADL 28242 — 1C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 11918 feet Plugs (measured) none true vertical 6804 feet Junk (measured) none Effective Depth measured 11829 feet Packer (measured) 9164, 9186, 11275 true vertical 6757 feet (true vertical) 5417, 5428, 6467 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 7363 9.625 7404 4520 PRODUCTION 11885 7 11918 6804 RECEIVED NOV 1 9 2012 Perforation depth: Measured depth: 11470' - 11510' SCANNED MAR 11 2013' AOGCC True Vertical Depth: 6569' -6591' Tubing (size, grade, MD, and TVD) 3.5, L -80, 11334 MD, 6498 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 9164 MD and 5417 TVD PACKER - WEATHERFORD ER PACKER @ 9186 MD and 5428 TVD i PACKER - BAKER S -3 PERMANENT PACKER @ 11275 MD and 6467 TVD SSSV - CAMCO TRDP -4E SSSV @ 2070 MD and 1791 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f ^ Service r Stratigraphic r 16. Well Status after work: Oil f Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 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 John Peirce Ca 265 -6471 Email John .W.Peirce@conocophillips.com Printed Name John Peirce Title Wells Engineer Signature ` Phone: 265-6471 Date 11 -.1.S Form 10-404 Revised 1 /2012 lZ • f c(. /Z. Submit Original Only d KUP II 1C -16 ConocoPhillips 31114 Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! ( MD (ftKB) Act Btm (ftKB) 500292293400 KUPARUK RIVER UNIT PROD 62.31 10,157.58 11,918.0 Comment H2S (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date SSSV:TRDP 60 9/25/2011 Last WO: 46.31 1/1/1999 Well Confio - 1G16, lI 012 22505 PM chematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,600.0 7/24/2012 Rev Reason: SET PACH ASSY, TEST TOOL, GLV C/O ninam 11/6/2012 Casing Strings Cas Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String . Stnng Top Thrd HANGER, 37 CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 -140 WELDED t Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 41.0 7,403.7 4,519.7 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd limiliniam PRODUCTION 7 6,276 32.5 11,918.0 6,803.9 26.00 L -80 ABM -BTC Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) 1Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 42 - 121 TUBING 31/2 I 2.992 I 37.1 11,334.0 I 6,497.7 I 9.30 I L -80 I ABM -EUE Completion Details Top Depth (TVD) Top Inc! Noml... �... 1 Top (ftKB) (RKB) ( °) Item Description Comment ID (In) 37.1 37.1 - 0.51 HANGER FMC GEN IV HANGER 3.500 SAFETY VLV, 2,070 ,v I 2,069.7 1,7912 54.29 SAFETY VLV CAMCO TRDP -4E SAFETY VALVE 2.812 11,229.6 6,442.4 58.04 NIPPLE CAMCO W NIPPLE 2.812 11274.7 6,466.3 58.07 PACKER ' BAKER S-3 PERMANENT PACKER 3.875 11,321.9 6,491.3 58.11 NIPPLE CAMCO D NIPPLE w/ NO GO PROFILE 2.750 GAS LIFT. 11,333.0 6,497.2 58.12 SOS BAKER SHEAR OUT SUB 3.015 3.623 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 9,164 5,415.8 59.89 TOOL ER TEST TOOL(OAL =48 ") 10/24/2012 GAS LIFT, 9,164 5,415.8 59.89 PACKER WEATHERFORD ER PACKER 10/24/2012 1.750 6,166 9,166 5,416.8 59.90 PATCH PATCH ASSEMBLY w/ SNAP LATCH 10/24/2012 1.750 9,186 5,426.7 60.06 PACKER WEATHERFORD ER PACKER 10/14/2012 1.750 Perforations & Slots , Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm MKS) (MB) (RKB) Zone Dew (eh ... Type Comment SURFACE. - 11,470 11,510 6,569.4 6,590.5 C 1C - 16 1/21/1999 4.0 IPERF DP, 180deg ph, 90deg orient from low 41 side r. _ _ Stimulations & Treatments GAS LIFT, Bottom 7,713 Min Top Max Btm Top Depth Depth lil Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) (966) Type Date Comment la 11,470.0 11,510.0 6,569.4 6,590.5 FRAC 11/22/2002 III Notes: General & Safety GAS LIFT, End Date Annotation _ 8/12/2009 NOTE: View Schematic w/ Alaska Schematic9.0 I PA TOOL, 9,164 4 _. OL. 9,16 III II PATCH, 9,166 ��� k PACKER, 9,788 • • ltd GAS LIFT, 10,065 Ill IIIII _ ----- GAS LIFT. 1 11,180 NIPPLE, 11.230 6 4 IIIF it PACKER, 11,275 NIPPLE, 11,322 ; Mandrel D etails Top Depth Top Port ( (TVD) Inc! OD Valve Latch Size TRO Run ( Stn Top (RKB) (RKB) ( Make Model (in) sery Type Type ON (psi) Run Date Com... SOS, 11,333 1 3,623.4 2,588.4 59.23 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,290.0 2/5/2012 2 6,166.3 3,885.3 59.83 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,316.0 2/5/2012 3 7,713.2 4,675.8 59.86 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 8/7/2012 4 8,984.1 5,324.4 58.49 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 10/26/2012 Ext IPERF, Pkg FR 11,470 . ' ■' FRAC, 71,470 5 10,064.5 5,871.6 62.49 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 11/8/2007 6 11,179.9 6,417.3 58.76 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/11/2002 PRODUCTION, 33-17,918 A ` TD, 17,918 DATE SUMMARY 1C -16 Well Work Summary 7/24/12 TAGGED D NIPPLE @ 1128OM / 11322' RKB) . TAGGED TD @ 116iis LM ( EST. 125' OF RAT HOLE) . HUNG UP UNDER FLAPPER ON SSSV. RAN FLAPPER CRECKER W/ 5000 PSI ON CONTROL LINE AND DETERMINE FLAPPER IS NOT FULLY OPEN. SET FRAC SLEEVE @ 2069' RKB AND MEASURED BHP @ 11490' RKB ( 3332 psi) . PULLED FRAC SLEEVE AND RUN FLAPPER CHECKER W/ 5500 PSI ON CONTROL LINE WITH NO PROBLEMS ( VALVE OPEN ). 7/30/12 TIFL, (FAILED), FLUID INFLOWED A TOTAL 3389' AND INCREASED 100 PSI DURING 1 HOUR MONITOR. 8/6/12 LEAK DETECT W/ HOLE FINDER; INADVERTENTLY SAT DOWN @ 7694' SLM ( OV @ 7713' RKB ) WHILE RIH AND OBTAIN TBG. TEST. IN PROGRESS. 8/7/12 REPLACED OV @ 7713' RKB. SET CAT SV IN D NIPPLE @ 11322' RKB. WITH HOLEFINDER CONFIRMED TBG LEAK ABOVE PKR, BETWEEN 11252' - 9037' SLM. IN PROGRESS. 8/8/12 WITH HOLEFINDER IDENTIFIED POSSIBLE TBG LEAK BELOW 9047' SLM. CAT SV LEFT @ 11322' RKB, READY FOR E -LINE. 8/25/12 PERFORMED LEAK DETECT PUMPING 1 BPM DIESEL DOWN TUBING, DETECTED LEAK AT 9175'. PERFORMED CALIPER LOG FROM 11320' TO SURFACE. PUMPED 120 BBLS DIESEL. 9/7/12 RIH W/ BAKER ATLAS MICROVERTILOG TOOL. FALL TO 7785' (59 DEGREE DEVATION), UNABLE TO TO GET DEEPER. LOG MICROVERTILOG FROM 7785' TO SURFACE AT 120 FPM. 9/30/12 PULLED CAT SV @ 11,322' RKB. BRUSH & FLUSHED TBG FROM 9050' - 9250' SLM. DRIFTED TBG WITH 2.78" x 20' DUMMY PATCH. READY FOR E /L. 10/14/12 SET 2.74" WEATHERFORD ER PATCH / PACKER AT 9186' RKB. CCL TO MID - ELEMENT = 14.70', CCL STOP DEPTH = 9171.3'. LOG CORRELATED TO HALLIBURTON LDL DATED 8 -26- 2012. 10/23/12 RAN TEST TOOL TO LOWER ER PACKER @ 9186' RKB. CMIT TO 2500 PSI PASSED. IN PROGRESS. 10/24/12 SET 22' x 3 1/2" WEATHERFORD PATCH ASS'Y AND UPPER ER PA CKER @ 9164' RKB. MITT M25_00 PSI FAILED., UNABLE TO DRAW DOWN IA PAST 750 PSI. IN PROGRESS. 10/25/12 RAN HOLE FINDER AND IDENTIFY BETWEEN 9045' RKB & 8940' RKB ( GLM @ 8984' RKB) . IN PROGRESS. 10/26/12 PULLED DV AND SET EXTENDED PACKING DV @ 8984' RKB ( TBG X IA CONTINUE TO TRACK ). READY FOR E -LINE (3 1/2 ER TEST TOOL REMAINS IN UPPER ER PACKER ). 11/3/12 (AC EVAL) ESTABLISHED A LLR OF 0.64 GPM @ 2500 PSI. 2a WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 SCANNED FEB 2 5 2013 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log:_I,C -16 Run Date: 8/25/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -16 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22934 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: / Signed: 04 "Sezteip, • 21�i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 6, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED FEB 2 5 2013 RE: Gas Lift Survey: 1C -16 Run Date: 8/20/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22934 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com a Si Date: 4 Signed: 4 �' g • 9t•2`6 C.1)) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 SCANNED Anchorage, Alaska 99501 FEB 2 5 2013 RE: Gas Lift Survey / Bottom Hole Pressure Survey: 1C-16, Run Date: 9/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22934 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 22934 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com 44 0 14 40 Date: 1. Signed: . . Conoc;pt,illips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 S~ANNEO SEP 0 6 20'07 ~q'ð-~4~ Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells fTom the Kuparuk field (KRU). Eac!1 of thesé wells was fóund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. $4~~· M.J.Lel~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date -~ ft bbls ft Qal 10-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199..084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 -1C-11 199-172 - SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199..005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199..043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutd0wn~ 8ti~!ate~xx :.: ~!~gi~ P~rforat~ ~ PulI tubing : 2. Name of Operator ConocoPhilli.ps Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1408' FNL, 4367' FEL, Sec. 12, T11N, R10E, UM 5. Type of Well: Development __ X Exploratory __ Stratigraphic __ Service__ (asp's 561916, 5968826) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk Unit 8. Well number lC-16 At top of productive interval 1174' FNL, 2260' FEL, Sec. 6, T11 N, R11 E, UM At effective depth At total depth 944' FNL, 1944' FEL, Sec. 6, T11N, R11 E, UM (asp's 569175, 5974633) 9. Permit number / approval number 198-246 / 10. APl number 50-029-22934 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 11918 feet Plugs (measured) 6804 feet Effective depth: measured 11725 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth CONDUCTOR 121' 16" 9 cu yards High Early 121' SURFACE 7303' 9-5/8" 885 sx AS III Lite, 696 sx Class G 7404' PRODUCTION 11817' 7" 304 sx Class G 11918' True vertical Depth 121' 4520' 6804' Pedoration depth: measured 11470' - 11510' true vertical 6569' - 6590' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11334' MD. · :: Packers & SSSV (type & measured depth) RECEIVED DEC 1 1 2002 13. Stimulation or cement squeeze summary Intervals treated (measured) 1 I 470-115~0 · . : :. : : Treatment description including volumes used and final pressure pumPed 155321#:0f: 16/20.ceramic proppant 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 520 ~60::: :: : : ! : ~ 230 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed Michael Moone)/ [ ' Form 10-404 Rev 06/15/88 · Title: Wells Team Leader Date / ~_~. Prepared b)/ Sharon Al/sup-Drake 263-4612 6ANNEP DEC ! $ 2002 SUBMIT IN DUPLICATE Date Comment 1 C-16 Event History 11/22/02 11/24/02 PUMP C SAND FRACTURE TREATMENT WITH 40# DELAYED X-LINKED GEL @ 25 BPM. PUMP TOTAL OF 155,321# OF 16/20 CERAMIC PROPPANT. PLACED 154,210# BEHIND PIPE, WITH 10 PPA ON PERF$. LOST 50% OF TREESAVER RUBBER IN WELL. [FRAC-REFRAC] PERFORMED A JET / REVERSE OUT TO 11,774.8' CTMD. WELL FREEZE PROTECTED TO TOP PERF @ 11,470'. RETURNS 1-1 ALL DAY. MANDRELS WASHED ON WAY TO SURFACE FOR WIRELINE EASE OF GL REPLACEMENT. WEEKLY BOP TEST COMPLETED. [FCO] Page 1 of I 11/25/2002 ConocoPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 10, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1C-16 (198-246) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1C-16. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad P.HILLIPS 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 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing almuli during the fourth quarter of 2001, as well as total volumes disposed into armuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kupamk Team Leader RT/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Disposal durin~ the fourth quarter of 2001: h(1) h(2) ' h(3) Total for Freeze Previous New Start 'End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes ~D2'42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 "72P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2p-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-'33, CD2-39, 2001 CD2-14 "1C-16 12338 100 0 12438 0 19679 32117' Sept 2001 'October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 , 1C-14 22389 100 0 22489 0 0 22489 oct 20Ol Nov 2001 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 1 otat voturnes tnto ~nnutt jor wntcn t~tsp.o..sat ,autnortzaaon t,.xptrea aurmg tne fourrn ~,,uarrer zoo1: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CD1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1 D-37, 1D-39 ITl ~nnutar ~Jtsposat aurtng me mtra q'uarter oj zuu~ ' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 ~31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept2001 Sept2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2:.14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141," 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. 198'246-0 KUPARUK RIV UNIT 1C-16 50_ 029_22934,00" PHii~LiPS'AL^sKA1NC Roll #1: Start: Stop Roll #2: Start Stop MD 11918 TVD 06804 Completion Date: (-~2~31/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D 1-5 SPERRY MPT/GR/EWR4/CNP/SLD OH 2/17/99 2/17/99 /~'DGR/CNP/SLD-MD FINAL 121-11918 OH 2/17/99 2/17/99 ~GR/cNP/SLD-TVD FINAL 121-6804 OH 2/17/99 2/17/99 ~DGR/EWR4-MD FINAL 121-I 1918 OH 2/17/99 2/17/99 DGR/EWR4-TVD FINAL 121-6804 OH 2/17/99 2/17/99 ~'~VY CALC BH 0-11918 OH 2/5/99 2/8/99 Thursday, January 25, 2001 Page 1 of 1 1{;~. It.r'lUfl, llllUl¢ll I. Jl~i~UOal Subject: re: lC-16 Annular Disposal Date: Mon, 3 Sep 2001 18:11:30 -0800 From: "Steve McKeever" <smckeev@ppco.com> To: tom_maunder@admin.state.ak.us Here at work on Labor Day! When I left home it was cloudy, and it looked like the right choice, but now the sun is shining. I°m going to finish up and get going. I got your phone message from your Labor Day labors. Thus: Item 1' Here again is the lC-16 Annular Disposal Transmittal form, with ALL reference to lC-17 gone, finally. (See attached file: 1C-16 Annulus Disposal Transmittal Form.xls) Item 2: Second Leak off Test, no pumping after leak off occurred. You're right. In reviewing that test it appears from the data that they stopped pumping at leak off and left the bore hole shut in for +/- 10 minutes. In further reviewing the records of the welt, though, I see that during completion operations they flushed the 9=5/8" x 7" annulus with 300 bbls of water followed by 78 bbls of diesel as freeze protection. The water was pumped at 2 bpm at a pressure of 1900 psi. Please find attached the hourly operations summary for that portion of the well, where this operation was recorded. Will this record be sufficient to show disposal capability? (See attached file: lc-16 hourly ops summary, pdf) Thanks Steve McKeever Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com "It is better to keep your mouth shut and appear stupid than to open it and remove all doubt." - Mark Twain r !~-~ 1C-16 Annulus Disposal Transmittal Form.xls . Name: 1C-16 Annulus Disposal Transmittal Form.xisi Type: EXCEL File (application/msexcel) Encoding: base64 i Name: lc-16 hourly ops summary, pdf! i ~1c-I6 hourly ops summary, pdf Type: Acrobat (application/pdf) i Encoding: base64 1 of I 9/6/01 4:09 PM PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phons (907) 265-6434 Fax: (907) 265-6224 August 30, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7m Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1C-16 Application for Sundry Approval Dear Commissioner Taylor: Phillips Alaska, Inc. hereby files this Application for Sundry Approval for annular disposal down the Kuparuk 1 C- 16 well. Please find attached for your review: · Application for Sundry Approvals Form 10-403 (1 page) · Annulus Disposal Transmittal Form -Well lC-16 (1 page) · 1C-16 Horizontal Clearance Report by Baker Hughes Inteq (1 page) · 1C-16 Horizontal Clearance Plot by Baker Hughes Inteq (1 page) · 1C-16 Surface Casing Running Report (1 page) · 1C-16 Surface Casing Cementing Report (1 page) · 1C-16 Surface Casing Pressure Test Report (1 page) · 1C-16 Surface Casing Drill Out Leak Off Test Report and Chart Record (2 pages) · 1C-16 Open Hole Leak Off Test Report and Chart Record (2 pages) · lc-16 Production Casing Running Report (1 page) · 1C-16 Production Casing Cementing Report (1 page) · 1C-16 Production Casing Pressure Test Report (1 page) · Calculation of Maximum Allowable Fluid Density and Pressure at the Surface Casing Shoe, Burst Limited (1 page) · Calculation of Maximum Allowable Fluid Density and Pressure at the Surface Casing Shoe, Collapse Limited (1 page) If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Drilling Engineering Supervisor PAl Drilling CRM/skad ORIGINAL /? 3 0 200/ -q/as/fa Oil ~ Cas C~ 'dnChoragun~' C°mmissjo, Annulus Disposal Transmittal Form - Well 1C-16 I A. IDesignation of the well or wells to receive drilling · Iwas.tes: . tlC-16 ! lB. I'The to the base of freshwater and depth aquifers m Ipermafrost, if present. INo Aquifers / Base Permafrost = 1,797 TVD RKB lC. 'IA sb-aUgraphic description of the interval exposed to Ithe open annulus and other information sufficient to Isupport a commission finding that the waste will be ifs sr°n~le~rLiS~rLnhoe~d~mca r~enl~rit°P~ILndthatsi.s °pen! ID. IA list of all publidy recorded wells within one-quarter Imile and all publicly recorded water wells within one Imile of the well to receive ddlling waste. ISee attacf~ horizontal plane dearance report and plot indicaUng no wells within 1/4 mile and no water wells within one mile of 1C-16. iE: IIdentify the types and maximum volume of waste to be ~iuSrrypO.sed. of and the estimated densityof the waste Types of waste can be ddlling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids assodat~ with the act of ddlling a well and any added water needed to facilitate pumping of dH,lng mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. IF. )An estimate of maximum anticipated pressure at the [outer casing shoe during annular disposal operaUons land calculations showing how this value was Id~t~3nin~d_ Maximum anticipated pressure at casing shoe during disposal operaUons is 1,853 psi. See attached ]Details that show the shoe of the outer casing is set Ib low ~ b~ of any freshwater aquifer and Ipermafrost, if present, and cemented with sufficient In=_m~nt tn nmvide~ 7nn~ icnlatinn: .... laSe~ a~: cemenUng reports, LOT / FTr reports casing reports. IH. IDetails that show the inner and outer casing strings lhave suffident strength in collapse and burst to Iwithstand anticipated pressure of disposal operations: ISee attached casing summary sheet and calculation pages. II. IAny additional data required by the Commission to Iconfirm containment of drillinq wastes: 1C-16 Annulus Disposal Transmittal Forrn l.xls prepared by Steve McKeever 8/30/0~ 1C-16 Hourly Operatk. .... ~ Well Start Day and End Day and' , commer~ts' Name Time Time 10-16 12/29/98 1:,00 12/29/9,8. 2,[O0 R/U casers and, hold safely meeU, ',ncj, 10.16 !,2/29/982:01).. ' 112/29./9810:01),., Run160 jts 7. casi, ' ,ncJ. Circcasingvotume'every60jls. 10.16 12/29/9810:00 12/29/9811:00 Repairh~,draulic lineon ~ machine, ;1C-16 12/29/98 11:00 12/29/98 18:00 Run 283 jts casing~m casing volume every 60 jts. L/D'fiiluptool. M/U landingjt and land casing a@ 11918'. R/U cement equip rmem , , 10.16 12../'29/98 18:1~)0' 12./29~8 21:30 Cim 1648 bbls 10-1~ 12/29/98 21:30 12/29/98 22:30 Batch mix cement '" 10.16 12/29/98 22:30 12/30/98 0:00 Pump 20 bbl pre. flUSh; 40 bbl spacer, drop plug. Pump 65 bbl 15.8 cement, drop plug. Displace w/453.2 bbl 3% KCI./seawaler !wi rig pump 10-16 12/30/98 0:00 12r30/98 0:30 ,. Finish displacing cement. CIP ~, 029:00. 1 0.16 12/30/98 0:30 12/30/98 1:30 Pressure test casing to 3500psi for 30 mimokau~r Bleed off ,,, pres.sure check floats-ok. R/D cemenU,ng equip.,rnen,t 10.16 12/30/98 1:30 i2/~/98 2:30 PAJ BOPE , , , 10-16 12/30/98 2:30 12/30/~ 3,:,00,,. ~ slips w/, 21OK indica.t.o.rwt. Cut oil casim:j 10.16 12/30/98 3:00 12/30/o~ 4:00 UD cutoff and L/D ,casing ~ 10.16 12/30/98 4i00 12/30~98 5:00 N~0 aOPE lC-16 12/30~ 5:00 ~2/30/98' 7:30' D.~s~ stamp. ,nsta, paci,offand ~,~nm P~. Te~ to 3OO0 p~.' N/U BOPE ~C-16 .~0/98 7:30 .12/30/98'9:00 " Change upper PR'~ to ~l.~ and test to 300r3000.1~' 10-16 :12/30/98 9:00 12-/30/98 14:30 R/U slickJine and make two runs wi 5.95' gauge ring and junk basket to 11808' sim 10-16 12/30/~ 14:30 12/30/98 ;15:00 ~ lubincj tools ' ' 10-16 ~12/30./9,8 15:00 12/31/98 0:O0 Hold safety .nr~.. ~ncj and rukn 3.5' tubing 10-1'6 ' '1~J31/98 0:00 12_/31/984:00 Run 356 its tubing wi 6 GLMS. SSSV. and jeweiry. Test control' line to 5000 p,si and attach to tubing w/35 ss bands lC~-16 12/31/98 4:00' 12/31/98 5:30 '" Land tubing and Iock'~ hanger, preSSUre tabing to 3000 psi for 10 minutes to set packer. Pressure up to 3.900 psi then 4400 psi to shear out SOS w/o success..Apply 3500 psi to annulus and hole for 10 minute,s. Bleed off ,tubing to open RP valve in bot lC~16 ;i2/31/98 5~30 12/31/98 6:00 Repressure annulus to 3800 psi. 10-16 12/31/98 6:00 'r12/3;1/98 8'i30 Reopen ~ssV by pressuring tubing'to 4200 psi and increasing conlrol line pressur to 7500 psi. Bled pressur oil lubing to 0 and decreased control line pressure to 5000 psi. Opened RP valve by . i.,ncreasi ,ng annulus,pre.s,s,,,Ure t° 3400 psi. lC~16 ' 12/31/98 8:30 ' 12/31/98 12:30 R/U slicldine and mn in 'ar/sinker bars and knock' ballseat out !of shean)ut sub. Freeze protect 9.5/8' x 7" annulus ar/300 bbl water ¢~ 2 bpm -1900 psi and ?8 bbl diesel. Rnal oressure -- 1000 =si. R/O ~licklirle .... i0-;16 12/31~ 12:30 ~2/3~/9s 1.4:00 Freeze protect 3-1/2' tuang and 7' x 3.1/2' ann;ui.swi~00'~U d~sa 10-16 12_~1/98 14:00 12/31/98 15:3~ L/D landing jt and install bpv. L/D control line ,e~lui~.nt' ~0-16. 12/31/9815:30 ~2/31/98' 1'6:.00Change top pfs back to 7' ,WR'S 10-16 12/31/98 16:00 12/31/o98 17:30 N/D BOPE 10-16 12/31/98 17:30 i2J31.~8 18:30" N/U, Wellhead and ~st hanger ~r~, packoff tO 5000 psi ' 10-16 1,2/31/98 18:30 12/31/98 20:00 Disconnect linerto floorand drain pumps 10-16 12_/31 ,/~. 20:00 111/99 0:00 L/D d~pipe out of derrick 10.16 111/99 0:00 1/1/99 7:00 UD ddi!,pipe out ~derfick 10-16, 1111997:00 1/1/998:O0 Cut~drfllincjline. (Ricjreleased(~,OS:o0'hrs 1/1/99) ' Kuparuk 1C-16 Annular Disposal Application PTD 198-246 Sundry 301-259 PPCo applied for approval for authorization to use the 9-5/8" x 7" annulus of the subject well for disposal. The well was drilled and completed in the latter part of December 1998. The cementing information attached to the sundry indicates that both the 9-5/8" and 7" operations were accomplished successfully. It is noted that 250 bbls of cement was circulated to surface. According to my cement verification worksheet, this is a little over half of the excess cement volume pumped. The LOT on drillout looks good. There is a fairly clean pressure break and the pressure is fairly consistent while pumping in. On shut down the pressure dropped and stabilized essentially after 1 minute. The leak off test information is plotted to the left of the casing test. On a psi per stroke basis, there is not a lot of difference in the "constant slope" portion of the plots. It appears that the system was not full when the casing test operation was begun, otherwise the pressure rise would have begun sooner. The casing test looks good. The second leakoff could have been pumped a little longer. Based on differential pressures, the pressure plot was just turning over when pumping was stopped. The psi per stroke value is lower which would be expected with the greater open hole when compared to the original leakoff. Based on discussions with the engineer, this test was conducted prior to entering the Kuparuk to determine if sufficient formation strength was available to go to TD. it does not appear that a LOT down the annulus after the casing was cemented was done. Subsequent information regarding the freeze protection operation has been submitted. This summary is only verbal, but it establishes that the annulus has been freeze protected and nothing unusual was reported. I have checked Wendy's database. She notes that hydrate gas was encountered while drilling the surface hole and that fluid broached around the conductor. I have checked the well file and confirmed her notes. The hydrates were initially seen at ~1160' with gas cut mud on occasion being noted down to 4530' and another occasion at ~7120'. The broaching was noted after the well had reache_~d_.¥D. 2 shallow cement plugs were pumped to remedy the broaching. No d~ulties are reported while running or cementing the casing. ~.~_,~-~.~-. ~ I have spoken with PPCo's engineer and requested that an injectivity test be conducted on 1C-16 to provide "leakoff' verification. He indicated that such test could likely be conducted before morning (9/7) and he would send the results. Absent anything unusual on the injectivity test, I recommend approval of annular disposal for 1 C- 16. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Other _X /'~ 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1408' FNL, 4367' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1174' FNL, 2260' FEL, Sec. 6, T1 1 N, R11 E, UM At effective depth At total depth 944' FNL, 1944' FEL, Sec. 6, T11 N, R11 E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service (asp's 561916, 5968826) (asp's 569175, 5974633) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-16 9. Permit number / approval number 198-246 10. APl number 50-029-22934 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured 11918 true vertical 6804 Effective depth: measured 11470 - 11510 true vertical 6569 - 6590 Casing Length Size CONDUCTOR 121' 16" SURFACE 7303' 9-5/8" PRODUCTION 11817' 7" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cy yards High Early 885 sx ASlll Lite, 696 sx Class 304 sx Class G Measured Depth True vertical Depth 121' 121' _ .' :7404' '" 4520' ? 11918' 6804' Perforation depth: measured 11470 - 11510 true vertical 6569 - 6590 Tubing (size, grade, and measured depth ~ackers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11334' MD. BAKER S-3 PERM PACKER @ 11274' MD. CAMCO TRDP-4E. @ 2070' MD. AUG 3 o Alaska 0il & Gas Cons. Anchorage C°rnrnission 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: September 5, 2001 16. If proposal was verbally approved Oil __X Gas __ Name of app.~over _ ~ Date approved Service 17' I herebyf/th~~~is;~.~O~ t.~e best °f mY ~°wledge' Signed ~,._~Ir~,---..~Y~ Title: Drilling Engineering Supervisor Conditions of approval: N~ssion so ~.~entative may witness Suspended__ Questions? Call Steve McKeever 265-3826 pr~;~~datbyeStev~e ever~ ~/ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- .Original¢. vSigned 0,chsl, By Approved by order of the Commission _amm. Commissioner Date Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE Annulus Di, spor al TransmitS! Form - Well 1c-16 IA. IDesignation of the well or wells to receive ddlling Iwastes: , . I tlC-16 l B. IThe depth to the base of freshwater aquifers and .. Ipermaff0$t, if pre~ent. Aquifers / Base Permafrost = 1,797 TVD RKB ] l c.' IA'st Ugraphic description of the interval exposed to Ithe open annulus and other informaUon suffident to Isupport a commission finding that the waste will be Iconfinecl and will not come to the surface or I~nhaminatp fr~:hwat~r _ ID. IA list of all publicly recorded wells within one-quarter Imile and all publidy recorded water wells within one ,. Imile of me well to receive drilling waste. ISee attached horizontal plane dearance report and plot indicaUng no wells within 1/4 mile and no water wells within one mile of 1C-16. IE. Ildentifl/the types and maximum volume of waste to be sdluSrrylrry.X)~ed.°f and the estimated density °f the waste , ,. , , Types of waste can be ddiling mud, ddlling cuUdngs, cement-contaminated ddlling mud, completion fluids, diesel, formation fluids assodated with the act of ddlling a well and any added water needed to fadlitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. IF. IAn estimate of maximum anUdpated pressure at the Iouter casing shoe dudng annular disposal operations land calculations showing how this value was Id~terrnined_ Maximum antidpated pressure at casing shoe during disposal ope~tions is 1,853 psi. See attached calculaUon page. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and ~rmafrost, if present, and cemented with st~fident ~rn~nt tn nmvid~ 7~lnP_ i~c~"dal'inn' laSe~ attached: cemenUng reports, LOT / FIT reports casing reports. IH'. IDe ils u~t show the inner and outer casing strings lhave suflident strength in collapse and burst to Iwithstand anUdpated pressure of disposal operaUons: ]p~.al~d casing summary sheet and calculation II." )Any additional data the Commission to required by lconfirm c0ntainm, ent ,of drillin, q .,wastes: IC-16 Annulus Disposal Transmittal Forrn l.xls prepared by Steve McKeever 8/30/01 Phillips Alaska, Inc. Pad lC 16 slot 916 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : PMSS <0 - 11918'> Our ref : svy5901 License : Date printed : 11-Jul-2001 Date created : 17-Dec-1998 Last revised : 8-Jan-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.295,w149 29 52.562 Slot Grid coordinates are N 5968824.706, E 561914.991 Slot local coordinates are 1411.00 S 910.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet Phillips Alaska, Inc. CLEARANCE LISTING Page 2 Pad 1C,16 Your ref : PMSS <0 - 11918'> KuDaruk River Unit,North Slope, Alaska Last revised : 8-Jan-1999 Reference wellpath Object wellpath : PMSS <0-10980'>,,14,Pad lC Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 7402.2 4519.0 3351.7N 4237.7E 72~9.9 4519.1 1857.3N 5224.8E 146.6 1790.9 1777.9 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORI IN, L ................... Phillips Alaska. PIo~ Reference ~ PUSS <0 - C~r~ote~ o(e ;n fe~t ~c~,e~e s~t ~6. .................................................................................................................................................................................................................. '~True ve~ol ~pt~s are ,efe~e~e R~ (porker 1245~.~ ~ Structure · Pad 1C Well · 16 H~ ~'r~:o Field · Kup~ruk River UnH Loc~fion · Norfh Slope, Alosko [~st (feet) -> 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 L t [ I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ./ 52OO _ - 5000 4800 4600 44OO 4200 4000 _ -5800 _ -3600 5400 I Z 3200 --i- 3000 2800 26OO 24OO 2200 2OOO 18oo 16oo 1400 1200 1000 ORIGINAL CASING / TUBING I LINER DETAIL 9 5/8" SURFACE CASING DETAIL WELL: 1C-16 KRU ARCO Alaska, Inc. DATE: 12/20198 Subsidiary of Atlantic Richfield Company ;1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB 40.98 LANDING JOINT==> 44.66 -3.68 FMC GEN 4 FLUTED CSG. HANGER w/PUP 2.26 40.98 25 Jts. 9 5/8" #40 L-80 BTC CSG (Joints # 167 thru # 191) 957.10 43.24 TAM PORT COLLAR (SCREW IN TOP OF # 166 ) 2.96 1000.34 164 Jts. 9 5/8" ~40 L-80 BTC CSG (Joints # 3 thru # 166) 6322.48 1003.30 GEMOCO Float Collar 1.50 7325.78 2 Jts. 9 5/8" #40 L-80 BTC CSG (Joints # 1 & # 2) 74.68 7327.28 GEMOCO Float Shoe 1.71 7401.96 , BOTTOM OF SHOE==> 7403.67 RATHOLE 8.33' )1 TD OF '12 1/4" HOLE - 74'12' MD * BAKER LOCK ALL CONNECTIONS THUR TOP OF FLOAT COLLAR * RUN 1 BOW SPRING CENTRALIZER ON JOINTS # 1 AND # 2 ON STOP RING ( MIDDLE OF JOINTS) * RUN 1 BOW SPRING CENTRALIZER ACROSS COLLAR ON EACH JOINT# 3 THRU # 15 ( TOTAL oF '15 BOW SPRING CENT. F/SHOE JT. TO JT.# 15 ) * RUN 1 RIGID STRAIGHT BLADE CENTRALIZER ON EACH SIDE OF TAM PORT COLLAR ( 1 EA. ON JOINTS # 166 & # 167 ) / 2 TOTAL RIGID STRAIGHT BLADE CENTRALIZER ) FLUTED HANGER GOES IN TOP OF JOINT # '191 LEAVE OUT JOINTS # 192 THRU # 200 (TOTAL 9 JOINTS) Remarks: String Wei~lhts with Blocks: 330K# Up, 145K# Dn, 70K¢ Blocks. Ran 191 joints of Casing Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Parker Ri~l #245 Drilling Supervisor: Dead W. Gladden ORIGINAL Cementing Details ARCO Alaska, Inc. Well Name: 1C-16 Report Date: 12/24/98 Report Number: 10 Rig Name: RIG # 245 AFC No.: AK9149 Field: Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: % washout: 9.625 12.25 59.89 I 7403.67 7325.78 Centralizers State type used, intervals covered and spacing Comments: I bowspringljt in middle of first 2 its. 1 bowspringljt on collars of next 13 its. I ridgid centralizer on each side of TAM collar Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.2 34 24 I 30 17 Gels before: Gels after: Total Volume Circulated: 10/30 4/8 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.3 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 10.5 Lead Cement 0 Type: Mix wtr romp: No. of Sacks: Weight: Yield: Comments: AS III Lite 75 885 10.7 . :--~4.44 . Additives: G wi 30%D53, .6% D46, 1.5% D79, 1.5% S1, 50% D124 Tail Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G. I 75 _696 ~ I 15.8 - 1;17 Additives: G wi .2% D46, .3% D65, 1% S1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9 bpm 9 bpm 330 Reciprocation length: Reciprocation speed: Str. Wt. Down: 30 ft 30 fpm 145 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 555.29 555.29 Surface Date:12/24/98 Yes Yes Time:05:58 -Remarks;Had full returns throughout jOb. 'Circulated 268 bbl cement and Cement contaminated mud to Surface. Quit reciprocating after taiiwentar°uod S~hoe._~ I Cement Company: Rig Contractor: Approved By: 35 PARKER G.R. Whit ock ORIGINAL CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-16 Date: 12/25/98 Supervisor: G.R. Whitlock Casing Size and Description: 9 5/8", 40.0 ppf, L-80, BMTC Casing Setting Depth: 7,403' TMD 4,505' TVD Mud Weight: 8.5 ppg EMW = Leak-off Press. + MW 0.052 x 'I-VD Hole Depth: 4,515' TVD 1,160 psi + 8.5 ppg EMW LOT = (0.052 x 4,505') = 13.5 ppg Fluid Pumped = 6.4 bbl Pump output = 0.1000 bps , JTIME LINE ~'~On~l i i i i i I i i ii1 i i i i i i i iii iii i iiii i i i 181 i i ill i i I i i i i I i iI iii i i i i i i i i i i iii iiiI }'9oo~ - -: : ~z~ ' -. - 1 ,$0~ p~ ................... . 1:2oo p. t ~ '~-[ ~1 'q-[-'4 q' I -- CAS IN G TEST I H "H I 100 p~ t'ooop, J~~lL~d~ LOT SHUT IN TIME '9oop, 4~~:~'~'~ --,--CASING TEST SHUT IN TIME I 8oop, ~~+~-~kH: ..... ~1 ~ TIME LINE I =~Ig~g: . g: . .... .~.~~~~ ............... :"' : :: .:' :;':' _:.: ::': :.:' :' :::'".: '::': ". ;". ". 0/2~4 6 8 l~4161~4~~24~~07~47~~~1ffi~ffiffil1111111112121~21~3131313131414 ,'~t st ~t at ~t st ~t ~t at st et M at at al ~t at ~l ~1 ~l M St st st st M st at et at at et M at ~t ~t at et at ~t st st at ~t ~t st M st st at 0 2 4 6 8 0 2 ~ 6 80 2 4 6 8 0 2 4 6 B 0 2 ~' k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k ~ k st st si ~t st st ~t ~t st ~t st st st ~t st si st at st kkkkkkkkkkkkkk kkkkkkkk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE .................. T .................. '[ ............ 7 ...... .................. [ ..... .O___s_t_k_s_. .... ! ...... .0_._p.S.L ...... ~,_;,,! 4 stks_,: 110 psi .... ..... .... ,i .... .... .... T'~'~"'~: .... ?~'~ii~--": .... ~-~-~_~'f .... ................ '-f .................. 4 .................. ~,~O ~ 16stks = 600psi ....... i~---q .... ~-o-~i~--'-i .... ~-~-~-~'i'"i ...... ',"~-'~-"~--'~'~'~iR.~';t"" ~-~-;:,~'f ! ...... -~.~ ....... t_ J:. "' ....... '~ ~-'-4 .... ::::::::::::::::::::::::::::::::::::::::::::::::: ! 40stks ~ 970 Esi ................... T .... ;~-~ii~----: .... ~s-~- '~f .... .................. ~ .................. ~ .......... P- ....... : 48stks I 938 psi .................. ! .... _S..2_.s.t..k._s_._.,,, .... ~_3_o__R?j_ .... ................... [ .... _S..~.~t.k._s_._.j .... ~_3_o__p_.s.l .... I 60stks ~ 924 psi ::::::::::::::::::::::::::::::::::::::::::::::::::::: i I CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................... T .................. 1 ............ T ..... : 0 stks j 0 ESl ................... i ..... i~"~ii~- .... ~ ..... ~t"~;i .... .................. ~, .................. -i .................. ..~ ; 12stks I 80nsi .................. ! .... ¥~-;i~----I .... ~-~:~[;F?,~ .................. I .... ~'~i~"--I .... ~'~'~_~i'~ [ .................. ," .... ~'6'~ii~'--'i .... ~'0'B~'i?i ................... l .................. ~ .......... ~- .... i 36stks ~ 780 Esi.~j~,~ , ,," .................. ; .... ;~';ii~----1 .... ~: .................. *: .................. 48stks 4: ................ 1,255Dsi i ........... ;""}-:"~i-;i~----i-'-i;-~z~-~r~ ~ ~.s ............ ~"~---i~';ii~;"-'i'--{~-~?_~ ~t-~ 66stks i 2,1402si .................. i .... 7~"~iE~""1-"~,",~'~b-,:)'~i" ~o ................... .= .... 7_.~..s..t.k..s___.]____2,Z_4_P_~_s_! ':::,q. 84 stks i 3,050.p. si :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i .................. i, SHUT IN TIME ..... ~.'6-'~,~'"'1 .................. I'"§:6'~'~.'~F'j ========================================================= :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ! , i ] ,, t 2.0 min I 3,050 psi ;SHUT IN TIME; SHUT IN PRESSURE ..... ~'.'6-'r~[r~ .... 1 .................. i'-~-;(~§6-~'~i"i i- ............ r ....................... ~ .............. r ..........L ........... ~ .................. .I ........... .x;; .... : 0.0 mln ! I 924£s~ ] 4 0 min I I 3,050DSi ! I .... ~';6'~T~ .... 1 .................. l""~b-0'Ea--! ' ...... - ..... : ....................... ~ ................. ~ · ........................................................ I5.0 mtn I I 3,050psi ; 2.0 rain ! i 790 psi I ..... ~.'O-'r~i'~ .... i .................. i"-~;'(~D'p~"~J"~ ..... §-.'~';~T~ i .... .................. i ~'6-i;~i'"i .... ::::::::::::::::::::::::::::::::::::1.::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::: 8.0mi, j ] 3,050~s, J __,_.~...e_~_Ln. .... t ...... : ........... J .... _7..7..8_p..,,.t_._.~ :::::F:.:.O:~:[n:::::::::::::::::::::::::::::::::::::::: 6.0min j j 777 psi 10.0min j 3,050~si j ..... T.'~'~Tr; i .... .................. i ~'~-p_';i .... .... f'"T~'.'~'~T~-'-i .................. i'"~','~b'-~i--1' .... ~T~-~-i-ri [ .... .................. ] ~-~_~'i .... .... r "~[:)':(:T~'i'ri-'-T .................. i'".~;'~;iii',~'~i"i I 25.0min J I 3,045~si : , .... 6'.'6'~fiT~ .... i .................. i .... 7f-,i-~'i .... " ....... : ............................ " ........... '": ..... "' t ............. : .... t ............................. ~ ..... :::::::::::::::::::::::::::::::::::::::::::::::::::::: t_...3_g:.o_r?__._., ............... :_J._.3,.o.?..3.~.s_L_: NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY //' Y44 ORIGINAL CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1C-16 G.R. Whitlock 9 5/8", 40.0 ppf, L-80, BMTC Date: 12/27/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.8 ppg Hole Depth: 6,418' TVD 7,403' TMD 4,5O5' TVD EMW = Leak-off Press. + MW 0.052 x TVD 752 psi + 9.8 ppg EMW LOT = (0.052 x 6,418') = 12.1 ppg Fluid Pumped = 3.6 bbl Pump output = 0.1000 bps 3,400 ~ I "'- ONE MINUTE : J 3.300 psi ...... ..... 3,200 psi } i i ..... i ....................................... 3,000 psi · 2,900 psi 2,800 psi 2,700 psi i r~ 2.600 psi 2,500 psi ~ · 2,400 psi · · 2,300 psi · · 2,200 psi · · 2.100 psi 2,000 p~ · 1,900 psi · 1,800 psi · 1,700 psi 1.600 psi ~' 1,500 PSI · 1,400 psi · ~ · 1.300 psi 1,2oo psi . ~ .-e-- LEAK-OFF TEST ~,~oo psi i '""~""CASING TEST 1,000900 psi psi · ~' ~ ...... ~'.....' LOT SHUT IN TIME 800 psi "--"~&'~' CASING TEST SHUT IN TIME 700 psi 600 psi .~Jl~' _+_TIME LNE 300 psi III I ICKl~Psi --~-- i lllllll III I I psi 0 2 ~ 6 B 1~1~.~4~51~2~2~2~52B~32~43538~4~4~5~B~525~5B~25~5~7~727~75788~B2B~5~B~2g~g5g~1~1~1~l~11 I1 I1 I1 12 st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st 0 2 4 6 8 0 2 4 6 8 0 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k l( k k k st st st st st st st st st st st k k k k k k k k k I(k STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE '- 4stks : 120psi ~j_ [ J 6stks ! 27 psi .................... -i-,' .................... ',' ................... ' ,~ .................... ~ .................... ~ .................... : 8stks : 215psi ','~i [ 12stks i 80 psi l .................... ? .... :iif-~iE~ .... i .... -:i-i~-~i-x;i~.~ .................. ~ .... 'iif-~ii~i~ .... ] ..... ¥~i'~'-/;~T--'i i .................... T .... :~'if-[ii~ .... i .... -:i-~:-i-i/,~i'~iso~ .................. i .... '~2:~ii~ .... ! ..... .~-,i-§--~-~i-'--i J ..................... ~. .................... ~ ................. ~,-'1 ~.-- ................... r .................... '1 ............... J i 20stks j 480 psi..lc~-~,s· i 30stks i 550psm i .................... -r,. .... ~;r;;ii;;; .... i .... '~iyi~rT']~;,::,:.~- .................. [ .... ~-~ii;~ .... ] .... ~:tf(o[i~EE"-] l .................... T, .... ~ii-;;ii~;; .... ~ .... -~-~-~_i-~..-,~ ................... i .... ~i~-~i-,;~ .... i ..... ~-~-~--/;sr"-i ..................... z .... ~-~ii~;; .... i .... .................... T .... ~'[iR[ .... i .... -7--~-~1--~, %1~,- J 54 stks J 1,540 psi ..................... ~ .................... ~ ..................... F .................... ~ .................... ~ ..................... : i : : 60stks j 1,820psi .................... 't .................... i .................... i ..................... !': .................... t. ..................... SHUT IN TIME J SHUT IN PRESSURE ..... E~'B'i'~ ..... [ .................... i .... ,%=~"6-~i"--i ..... T'EhTf~ .... ? .................... i .... -~iS'i~i .... 2.0 min _j. : 622 psi ...... xz-~-r~ .... .~ .................... i ..... ~-~i .... i- .................... t .... :-iii';ii~; .... i'"~7-i~ii:i'i~;i"i j [ 84stks i 3,050 psi ~ ..................... i .................... i ..................... J ,r .................... ,,. .................... , ,I .................... I i SHUT IN TIME i j 1.0min j ] 3,050 psi i- .... ~j'~[~- ....[ .................... i---~]i~§iJ-~[J--' L .................... t .................... I ................. :'-' i 3.0min ! j 3,050ps~ ..................... · .................... · ..................... i 4.0min i i 3,050 psi r .... §-B'~B- .... ? .................... i'"ii]i:i§i:i-i~;i-" !- ...... : ...... :' ...... i- .................... '~ ................. :-- i 6.Omen ! ] 3,050ps~ r .... :f-B'~fF,' .... r .................... l .... §~B'~[f~' [ j 3,050 p__si 5.0 min i i 580 psi i i 9.0 min ! i 3,050 psi j if;~'Bi'~ ..... .... T .................... ~ '~i:i'~i i :,""-'-I'~;~-~fi'i'~'-"[ .... .... .................... ..... ~:~,--~--i-~ ..... [ .................... i .... -~a~'i~i .... i ~'~ .................... ~.o mi. ~ .................... '~ ................. ~,oso ps,:'" i§[f-Ffii',.i ..... .... T .................... i '~ifiY~]i i [-'iiEi:i'~i'Ff---[ .... .... .................... i'-'!i]iiiiG[i"i "' .................... : .................... i'"iiiiii~-i~[i'-': 9.0 min [ [ 555 ps~ j : 25.0 min [ .... 'l-[~[J-~-i~----[ .................... i .... -~§~-~_'~] .... ] i .... §~;[~-~[1:1'"'! .......... : .........l'"~]iJ~§'~_[J'" ~ .............................................................. L ............................... T .............................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY O0 Ofii~IN~L CASING / TUBING / LINER DETAIL 7" Production Casing WELL: 1C-t 6 KRU ARCO Alaska, Inc. DATE: 12/26198 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES #'ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Parker Rig #245 - RKB to Casing Head = 38.92' TOPS (Landing Joint 423' above RKB) Landing Jo'int, 7" Casing (Joint #284) 36.74 -4.23 1 Jt 7", 26#, L-80, ABM-BTC Casing (Cut-Off Joint, Set on Slips) (Jt #283) 43.58 32.51 271 Jts 7", 26#, L-80, ABM-BTC Casing (Jts #12 thru #282) 11337.65 76.09 Marker Pup Joint, 7" Casing 21.16 11413.74 , Marker Pup Joint, 7" Cas!ng 21.18 11434.90 9 Jts 7", 26#, L-80, ABM-BTC Casing (Jts #3 thru #11) 372.95 11456.08 Gemoco Float Collar 1.32 11829.03 2 Jts 7", 26#, L-80, ABM-BTC Casing (Jts #1 & #2) 86.16 11830.35 Gemoco Float Shoe 1.49 11916.51 Bottom of Shoe ==>> 11918.00 I TD 8-112'" Hole = 11918' MD . Parker Rig #245 - RKB to LDS on Tubing Head = xx.xx' Baker Lock through the Float Collar Put Double Pup Marker Joint on Top of Joint #11 3 Bow Sprin.q & 40 Spira_qlider Centralizers: One Bow Spring on Jt #1 & Jt #3 on stop ring and one on middle of Marker Joint; Slide 2 Spiraglides on each of Joints #2 & ~4 thru #23 & put stop ring between them. I 28 Centering Guides: Slip one on every 3rd joint as follows: Joints #188, #193, 198, 203,208, 213, 218, 199,223, 228, 231,234, 237,240, 243, 246, 249, 252, 255, 258 I 261,264, 267, 270, 273, 276,279, 282 I Joint #284 will be Landing Joint, expect it to be about 4-114' up to tag bottom. (Joint #283 will be landed on slips & cut-off after cement job.) Leave OUT 2 Joints (Joints #285 thru #286). Remarks: String Weights with Blocks: 275K# Up, 120K# Dn, 75K# Blocks. Ran 283 joints of casing. Drifted casing with 6.151" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Torqued connections to the base of the triangle stamp. Set 150K# down on FMC casing slips (225K# with blocks). Parker Rig #245 Drilling Supervisor: G.R. Whitlock ORIGINAL ARCO Alaska, Inc. Cementing Details Well Name: lC-16 Report Date: 12/31/98 Report Number. 17 Rig Name: RIG # 245 AFC No.: AK9149 Field: Centralizers State type used, intervals covered and spacing Comments: 3 Bowspdngs l/it on its 1,3, and middle of marker it. 40 spiragliders 2 perjt sperated by stop collars on its #2 and 4-23. 28 center ing guides on l/jr on 193, 198, 203, 208, 213, 218, 223, 228, 231,234, 237, 240, 243, 246, 249, 252, 255, 258, 262, 264, 267, 270, 273, 276, 270, 279, 282 Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 34 24 30 17 Gels before: Gels after: Total Volume Circulated: 10/30 4/8 1648 Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.3 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 12 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: GI 75 304 15.8 1.2 Additives: 3% D53, .6% D65, .13% D800, .2 gal/sk D47, I1 gallsk D135, 2 gal/sk D600 Tail Cement 0 Type: Mix wtr temp: I No. of Sacks: Weight: I Yield: Comments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6 6 275 Reciprocation length: Reciprocation speed: Str. V~. Down: 35 ~35 fpm 120 Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 453.4 ~457 Calculated top of cement: CP: Bumped plug: Floats held: 10800 Date:12/30198 yes yes Time:00:29 Remarks:Good returns throughout job. Able to reciprocate throughout job. Cement Company: Rig Contractor: Approved By: DS PARKER G.R. Wh tock ORIGINAL Y44 ORIGINAL Calculation of Maximum Allowable Fluid Density and Pressure at the Surface Casing Shoe, Burst Limited Well 1 C-16 Surface Casing: Size 9-5/8 Weight 40# Grade L-80 Shoe Depth 7404 MD 4520 TVD Burst (100%) 5750 psi Burst (85%) 4888 psi Assumptions: Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density (MW) to Reach 85% of Burst Ratinq of 9-5/8" Casinq: 4,888 psi + 8.3 ppg (.052) (4,520' TVD) = 1,500 psi + MW (.052) (4520') Maximum Fluid Density = 22.8 ppg Maximum Pressure on 9-5/8" Shoe: Max Pressure = 1,500 psi + 9.8 ppg (.052) (4,520') - 8.3 ppg (.052) (4,520') Max Pressure = 1,500 psi + 2,303 psi - 1950 psi Max Pressure = 1,853 psi ORIGINAL 1C~ 16 Maximum Pressure at Shoe.xls prepared by Steve McKeever 8/3O/01 Calculation of Maximum Fluid Density and Pressure at the Surface Casin.q Shoe, Collapse Limited Well 1 C-16 Casing: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) Assumptions: 11 26# L-80 11,91 8' MD / 6,803' TVD 5,410 psi 4,598 psi 9-5/8" Casing Shoe @ 4,520' TVD Inside 7" Casing - Diesel from 2,400' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,520' TVD to 2,400' TVD (8.4 ppg) Maximum Fluid Density in 7"x 9-5/8" Annulus to Collapse 7" Casinq: 4,598 psi + 6.7 ppg (.052) (2,400') + 8.4 ppg (.052) (4,380' - 2,400') = 1500 + MW (.052) (4,520) MW = (4,598 psi + 836 psi +864 psi - 1500 psi) / (0.052*4,520) MW = 20.4 ppg ORIGINAL 1C-16 Maximum Pressure to Collapse Casing. xls prepared by Steve McKeever 8/30/01 C! Ft I I--I-- I IM I~ SEFIL/I r-E S To: WELL LOG TRANSMITrAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February 17, 1999 MWD Formation Evaluation Logs 1 C- 16, AK-MM-90045 1 LDWG formatted Disc with verification listing. API#: 50-029-22934-00 PLEASE ACKNOWLEDGE RECEHrr BY SIGNING AND RETURNING THE ATrACltED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: · - Signe 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 , (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska February 17, 1999 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. ~,,~. ~,q (~ Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1C-16, AK-1VhM-90045 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1C-16: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22934-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22934-00 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron & Density Logs: 50-029-22934-00 2" x 5" TVD Neutron & Density Logs: 50-029-22934-00 1 Blueline 1 Folded Sepia 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. "~ -- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 C-16 (Permit No. 98-246) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1C-16. If there are any questions, please call 265-6890. Sincerely, G. C. Alvord Drilling Engineer AAI Drilling GCA/skad 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 ~-~ GAS E~] SUSPENDED [] ABANDONED~ SERVICE E] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-246 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22934 4 Location of well at surface ' ,'~.i"" ' : i' .i · - ~ .-- 9 Unit or Lease Name 1411'FNL, 910'FVVL, Sec. 12, T, 1N, R10E, UM i p...~/.);/~_//~/ !'~i KuparukRiverUni, At Top Producing Interval ./ -.~ 10 Well Number 1174' FNL, 2260' FEL, Sec. 6, TllN, RllE, UM ':: '~ ': ~'~ i' 1C-16 At Total Depth - ./~-~'. . ..... 11 Field and Pool 946' FNL, 2940' FWL, Sec. 6, T11 N, R11 E, UM ~ ........... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41' Pad 60'I ADL 28242 ALK 2292 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 16-Dec-98 28-Dec-98 31-Dec-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11918' MD & 6804' TVD 11829' MD & 6757' TVD YES ~ NO U 2070 feet MD 2060 APPROX 22 Type Electric or Other Logs Run GR/Res/Neu/Dens, CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ;~--~"' CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT I~ECORD 16" 62.5# H-40 SURF. 121' 24" 9 cu yds High Early ., 9.625" 40¢ L-80 SURF. 7404' 12.25" 885 sx AS III L & 696 sx Class G 7" 26# L-80 SURF. 11918' 8.5" 304 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11334' 1127,5' 11470'-11510' MD 6569'-6590' TVD 4 spt 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11470'-11510' see attachment 27 PRODUCTION TEST Date First Production 2/3/99 Method of Operation Gas (Flowing, Lift gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/4/99 12.00 TEST PERIOI: 308 302 48 176I 4 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 210 0 24-HOUR RATE: 603 600 97 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, IMEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 11462' 6565' Top Kuparuk A 11918' 6804' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey :32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ""- Prepared By Name/Nun~r i~ Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/27/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-16 WELL ID: AK9149 TYPE: -- AFC: AK9149 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/16/98 START COMP: RIG:RIG # 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22934-00 12/15/98 (D1) MW: 8.6 VISC: 265 PV/YP: 38/57 APIWL: 72.0 TD: 0' ( 0) DRILLING 12 1/4" HOLE SUPV:DEARL W. GLADDEN Move rig from 1C-15 to 1C-16. Accept rig @ 1700 hrs. 12/15/98. NU diverter and function test. 12/16/98 (D2) MW: 10.4 riSC: 147 PV/YP: 41/45 APIWL: 5.1 TD: 2942' (2942) DRILLING ( NOTE: RIG OFF HI-LI SUPV:DEARL W. GLADDEN Drill 121' to 1166' MD. Hydrates gas to surface @ 1166' Drill 1166' to 1630' Hydrates gas to surface @ 1630' Drill from 1630' to 2942' 12/17/98 (D3) MW: 10.3 VISC: 150 PV/YP: 38/47 APIWL: 5.0 TD: 4904'(1962) TIH W/ BIT #2 SUPV:DEARL W. GLADDEN Drill from 2942' to 3128' Circ out gas cut mud. Cut mud weight to 9.4 ppg. Drill from 3128' to 3875' Circ out gas cut mud, cut mud weight to 8.7 ppg. Drill from 3875' to 4530'. Circ out gas cut mud, mud weight to 9.1 ppg. Drill from 4530' to 4904'. TOH. Tight at 4157'/3504' & 1635'/1071' 12/18/98 (D4) MW: 10.4 VISC: 140 PV/YP: 38/46 APIWL: 4.6 TD: 6200' (1296) TIH SUPV:DEARL W. GLADDEN Drill from 4904' to 6200'. Possible mud motor failed. 12/19/98 (D5) MW: 10.3 VISC: 235 PV/YP: 42/62 APIWL: 4.6 TD: 6316'(116) DRILLING 12 1/4" HOLE ( RIG OFF HI- SUPV:DEARL W. GLADDEN TOH, tight in several spots. Change out mud motors. TIH, bridge @ 1490' ream to 1630' Drill from 6200' to 6256', mud motor stalled. Attempt to free up mud motor. Drill from 6256' to 6300', motor stalling. Drill from 6300' to 6313', attempt to drill and unstall mud motor. TOH, tight in several spots. Date: 1/27/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/20/98 (D6) MW: 10.3 vise: 100 PV/YP: 38/42 APIWL: 3.5 TD: 7412'(1096) TOH SUPV:DEARL W. GLADDEN Drill from 6316' to 7117' Circ out gas cut mud. Drill from 7117' to 7412' 12/21/98 (D7) MW: 10.3 VISC: 75 PV/YP: 34/33 APIWL: 3.3 TD: 7412' ( 0) WOC SUPV:DEARL W. GLADDEN Pump pill. Monitor fluid in hole, fluid broaching up along side the 16" conductor and cellar horn. Pump cement plug at 110' 12/22/98 (D8) TD: 7412' ( 0) SUPV:G.R. WHITLOCK MW: 10.2 VISC: 99 PV/YP: 27/29 CIRC AND CONDITIONING MUD APIWL: 5.5 RIG ON Drill cement from 57' to 123'. Mud started coming over top of cellar from outside. Pump cement. Tag cement @ 45.5' Drill cement to 146'. Had minor gas bubbling outside cellar when drilling at 123'. RIH/hole opener and ream from 1445' to 1861' 12/23/98 D9) TD: 7412' 0) SUPV:G.R. WHITLOCK MW: 10.4 VISC: 100 PV/YP: 41/37 CEMENTING APIWL: 3.5 RIH w/hole opener and ream tight spots. Run 9-5/8" casing. 12/24/98 D10) TD: 7412' 0) SUPV:G.R. WHITLOCK DRILLING MW: 10.3 riSC: 54 PV/YP: 24/17 RIG ON HIGHLINE 24 HRS Pump cement. NU BOPE and test to 300/3000 psi. APIWL: 4.0 12/25/98 (Dll) TD: 9413' (2001) SUPV:G.R. WHITLOCK DRILLING MW: 9.3 riSC: 61 PV/YP: 23/28 RIG ON HIGHLINE 24 HRS APIWL: 4.7 Clean out cement, float equipmnt and drill 20' new hole. Run LOT to 13.45 ppg EMW. Drill from 743' to 9413'. Pump pill. 12/26/98 D12) TD:ll182' 1769} SUPV:G.R. WHITLOCK MW: 9.4 VISC: 58 PV/YP: 20/24 SERVICING RIG RIG ON HIGHLINE 24 HRS APIWL: 4.0 Drill from 9413' to 11182' Pump lo-vis hi-vis sweep. CBU. POOH. Hole not taking proper fill. RIH. Raise mud to 9.7 PPg. 12/27/98 D13) TD:11648' 466) SUPV:G.R. WHITLOCK MW: 10.4 VISC: 97 PV/YP: 40/40 APIWL: 3.4 CIRC FOR WIPER TRIP RIG ON HIGHLINE 24 HRS Run LOT to 12.1 ppg. Drill from 11182' to 11646' Date: 1/27/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/28/98 {D14) TD:l1918' (270) SUPV:G.R. WHITLOCK MW: 10.4 rISC: 95 PV/YP: 46/52 APIWL: 3.2 RUNNING 7" CASING RIG ON HIGHLINE 24 HRS Drill from 11648' to 11918' CBU. Pump out of hole 7 stands. Pump pill. Circ and condition mud. 12/29/98 (D15) TD:l1918' ( 0) SUPV:G.R. WHITLOCK MW: 10.2 VISC: 70 PV/YP: 29/28 N/U TUBING HEAD Run 7" casing. Pump cement. APIWL: 3.5 12/30/98 (D16) TD:l1918' ( 0) SUPV:G.R. WHITLOCK MW: 8.6 VISC: LANDING TUBING 0 PV/YP: 0/ 0 APIWL: 0.0 Pressure test casing. Check floats, OK. N/D BOPE and test to 3000 psi. N/U BOPE. Run 3.5" tubing. 12/31/98 D17) TD:l1918' 0) SUPV:G.R. WHITLOCK 01/01/99 D18) TD:l1918' 0) SUPV:G.R. WHITLOCK MW: 8.6 VISC: LAYING DOWN DRILLPIPE 0 PV/YP: O/ 0 APIWL: 0.0 Run 3.5" tubing and jewelry. Pressure tubing to set packer. Pressure up to shear out SOS w/o success. Run slickline w/sinker bars and knock ballseat out of shearout sub. Freeze protect well. N/D BOPE. N/U wellhead and test to 5000 psi. MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED @ 08:00 HRS 1/1/99 APIWL: 0.0 L/D drillpipe out of derrick. Release rig. Date 01/19/99 UP~'~ming Well Name 1C-16 Job Num 0107990538.6 Service Type ELECTRIC LINE Unit 2128 AFC 999152 0 Prop 230DS10 Uploaded to S Desc of Work NEW PERFORATIONS Supervisor FITZPATRICK Contractor Key Person SWS-JOHNSON Complete [~ Successful [~ Accident ~ Initial Tbg Press 20 Final Tbg Press 550 Injury E~] Initial Int Csg Press 1050 Final Int Csg Press 1050 Spill [~ Initial Out Csg Press 0 Final Out Csg Press 0 Summary PERFORATED C SAND 11470' TO 11510' WITH 4 SPF DEEP PENETRATOR SHOTS, 180 PHASING, +/- 90 DEG FROM LOW SIDE. [Perf] Date printed: 01127199 at: 14:40:02 Date 01/22/99 Well Name 1C-16 Service Type PUMPING Desc of Work PUMP "C" Up~,~ming Job Num 0107990538.6 Unit Supervisor JOHNS Contractor Key Person DS-GALLEGOS Complete [~ Successful [~ Accident E~] Initial Tbg Press 200 Injury E~ Initial Iht Csg Press 3500 Spill [~] Initial Out Csg Press 50 Summary AFC 999152 0 Prop 230DS10 Uploaded to S Final Tbg Press 200 Final Int Csg Press 500 Final Out Csg Press 200 PUMPED "C" SANDS FRAC WITH 31890# 12/18 PROPPANT PLACED IN PERFS . PRESSURED FRAC OUT AT 7.9 PPA PROP AT PERFS. TREATING PRESSURE 9100 PSI. LEFT 30,140 # 12/18 PROP IN PIPE. [Frac-Refrac] Date printed: 01/27/99 at: 14:40:36 i i Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. 1C-PAD/lC#16 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1411.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SS~ Target Description Target Coord. E/VV Slot Coord. E/W 910.00 Magn. Declination 27.338 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30mD 10m0 Vert. Sec. Azim. 51.65 Magn. to Map Corr. 27.338 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~') (DD) (DD) (FI') (FT) (FT) (IT) (Per 400 FT) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 16-DEC-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 9 1/2"MACH 1C-AKO-1.3 DEG. " 16-DEC-98 MWD 203.92 0.50 354.71 82.92 203.92 0.20 0.36 -0.03 0.60 0.60 16-DEC-98 MWD 290.50 1.26 29.70 86.58 290.49 1.29 1.56 0.40 1.04 0.88 16-DEC-98 MWD 378.43 3.31 45.20 87.93 378.34 4.71 4.19 2.68 2.41 2.33 ,_ 16-DEC-98 MWD 468.57 5.83 50.30 90.14 468.19 11.87 8.95 8.05 2.83 2.80 5.66 I 16-DEC-98 MWD 559.55 8.49 51.34 90.98 558.45 23.21 16.10 16.85 2.93 2.92 1.14 16-DEC-98 MWD 650.48 11.85 54.03 90.93 647.94 39.25 25.78 29.66 3.73 3.70 2.96 16-DEC-98 MWD 740.59 15.35 52,25 90.11 735.51 60.43 38.52 46.58 3.91 3.88 -1.98 16-DEC-98 MWD 831.21 18.45 51.19 90.62 822.21 86.77 54.85 67.24 3.44 3.42 -1.17 16-DEc-98 MWD 921.37 2O. 15 51.86 90.16 907.30 116.57 73.39 90.57 1.90 1.89 0.74 16-DEC-98 MWD 1012.49 22.98 52.39 91:12 992.03 150.05 93.94 117.01 3.11 3.11 0.58 16-DEC-98 MWD 1103.51 27.26 52.29 91.02 1074.42 188.68 117.54 147.59 4.70 4.70 -0.11 i 6-DEC-98 MWD 1198.63 30.64 50.81 95.12 1157.65 234.71 146.19 183.63 3.63 3.55 -1.56 16-DEC-98 MWD 1293.90 33.26 50.40 95~27 1238.48 285.11 178.19 222.58 2.76 2.75 -0.43 .. 16-DEC-98 MWD 1386.58 35.78 51.07 92.68 1314.83 337.62 211.42 263.24 2.75 2.72 0.72 16-DEC-98 MWD 1477.36 38.35 51.37 90.78 1387.27 392.33 245.68 305.90 2.84 2.83 0.33 16-DEC-98 MWD 1569.91 41.51 51.23 92.55 1458.23 451.73 282.82 352.25 3.42 3.41 -0.15 16-DEC-98 MWD 1664.19 43.19 51.48 94.28 1527.90 515.24 322.48 401.85 1.79 · 1.78 0.27 ,., 18-DEC-98 MWD 1757.99 46.55 52.41 93.80 1594.37 581.40 363.26 453.96 3.65 3.58 0.99 16-DEC-98 MWD 1853.42 49.50 52.24 95.43 1658.19 652.33 406.61 510.11 3.09 3.09 -0.18 ': 16-DEC-98 MWD 1945.62 50.93 51.43 92.20 1717.19 723.18 450.40 565.81 1.69 1.55 -0.88 · 16-DEC-98 MWD 2037.97 53.84 50.97 92.35 1773.55 796.32 496.23 622.81 3.18 3.15 -0.50 16-D EC-98 MWD 2132.90 56.02 48.54 94.93 1828.09 873.96 546.44 682.09 3.11 2.30 -2.56 i SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0451-02511 Sidetrack No. Page 2 of 3 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. 1C-PAD/lC#16 Survey Section Name SPERRY SUN BHI Rep. ~ilrr~/~i~ WELL DATA Target TVD (ET) Target Coord. N/S Slot Coord. N/S -1411.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL ~ SSD Target Description Target Coord. E/W Slot Coord. E/W 910.00 Magn. Declination 27.338 Calculation Method MINIMUM CURVATURE .Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ 1Om D Vert. Sec. Azim. 51.65 Magn. to Map Corr. 27.338 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DJ:)) (DD) (FT) (F-T) (F'I') (FT) (Per 100 FT) Drop (-) Left (-) 16-DEC-98 MWD 2227.37 58.61 49.42 94.47 1879.10 953.38 598.61 742.08 2.85 2.74 0.93 9 1/2"MACH 1C-AKO-1.2 DEG. 16-DEC-98 MWD 2320.16 58.41 49.55 92.79 1927.57 1032.45 650.01 802.23 0.25 -0.22 O. 14 -- 16-DEC-98 MWD 2600.09 59.48 50.65 279.93 2071.98 1272.16 803.82 986.20 0.51 0.38 0.39 16-DEC-98 MWD 2878.08 60.63 52.27 277.99 2210.75 1513.02 953.88 1174.61 0.65 0.41 0.58 17-DEC-98 MWD 3160.10 58.74 52.18 282.02 2353.09 1758.46 1103.01 1367.04 0.67 -0.67 -0.03 17-DEC-98 MWD 3437.63 60.10 51.87 277.53 2494.28 1995.38 1250.02 1555.38 0.50 0.49 -0.11 17-DEC-98 MWD 3719.98 58.77 52.37 282.35 2637.86 2238.48 1399.30 1747.26 0.50 -0.47 0.18 17-DEC-98 MWD 3998.17 60.41 53.79 278.19 2778.67 2478.30 1543.39 1939.07 0.74 0.59 0.51 17-DEC-98 MWD 4279.06 59.19 53.22 280.89 2919.96 2720.94 1687.77 2134.23 0.47 -0.43 -0.20 17-DEC-98 MWD 4560.00 57.84 53.56 280.94 3066.69 2960.40 1830.64 2326.54 0.49 -0.48 O. 12 17-DEC-98 MWD 4842.96 58.98 51.66 282.96 3214.92 3201.38 1977.01 2518.01 0.70 0.40 -0.67 18-DEC-98 MWD 5120.10 60.72 51.15 277,14 3354.11 3441.01 2126.51 2705.30 0.65 0.63 -0.18 18-DEC-98 MWD 5396.53 58.42 51.20 276.43 3494.11 3679.34 2275.93 2890.97 0.83 -0.83 0.02 18-DEC-98 MWD 5677.99 58.48 51.09 281.46 3641.39 3919.18 2426.41 3077.76 0.04 0.02 -0.04 18-DEC-98 MWD 5957.32 6i .06 51.99 279.33 3782.01 4160,50 2576.48 3266.74 0.96 0.92 0.32 19-DEC-98 MWD 6237.90 59.40 51.74 280.58 3921.32 4404,04 2726.87 3458.30 0.60 -0.59 -0.09 20-DEC-98 MWD 6517.11 57.71. 52.30 279.21 4066.97 4642.23 2873.46 3646.05 0.63 -0.61 0.20 , 20-DEC-98 MWD 6702.74 58.18 50.44 185.63 4165.50 4799.55 2971.67 3768.94 0.89 0.25 -1.00 20-DEC-98 MWD 6889.07 60.76 51.19 186.33 , 4260.15 4960.01 3073.06 3893.34 1.43 1.38 0.40' 20-DEC-98 MWD 7075.29 59.91 51.49 186.22 4352.31 5121.82 3174.15 4019.69 0.48 -0.46 0.16 20-DEC-98 MWD 7263.35 58.58 50.78 188.06 4448.48 5283.42 3275.55 4145.52 0.78 -0.71 -0.38 20-DEC-98 MWD 7351.06 59.89 50.36 87.71 4493.34 5358.78 3323.41 4203.74 1.55 1.49 -0.48 25-DEC~98 MWD 7637.30 59.81 49.17 286.24 4637.11 5606.15 3483.29 4392.69 0.36 -0.03 -0.42 6 3/4"MACH 1XL~AKO-1.2 DEG. 25-DEC-98 MWD 7916.99 59.63 51.56 279.69 4778.16 5847.60 3637.34 4578.67 0.74 -0.06 0.85 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. lC-PAD/lC#16 Survey Section Name SPERRY SUN BHI Rep. ~N~J~Ij~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -1411.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL J-J ssi- Target Description Target Coord. E/W Slot Coord. E/W 910.00 Magn. Declination 27.338 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10oftJ~ 30mJ-J lOmJ-J Vert. Sec. Azim. 51.65 Magn. to Map Corr. 27.338 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (FO (FO (FO (Per 100 FO Drop (-) Left (-) --. 25-DEC-98 MWD 8197.46 59.32 52.02 280.47 4920.61 6089.19 3786.78 4768.51 0.18 -0.11 0.16 25- DEC-98 MWD 8478.59 58.31 51.51 281.1 3 5066.18 6329.69 3935.62 4957.42 0.39 -0.36 -0.18 , -- 25-DEC-98 MWD 8760.56 59.79 50.52 281.97 5211.19 6571.49 4087.76 5145.37 0.61 0.52 -0.35 25-DEC-98 MWD 9041.01 58.93 52.06 280.45 5354.13 6812.77 4238.67 5333.64 0.56 -0.31 0.55 25-DEC-98 MWD 9317.91 61.09 52.26 276.90 5492.53 7052.57 4385.78 5523.03 0.78 0.78 0.07 26-DEC-98 MWD 9600.78 59.73 51.34 282.87 5632.21 7298.54 4537.88 5716.33 0.56 -0.48 -0.33 26-DEC-98 MWD 9879.84 58.02 51.08 279.06 5776.45 7537.41 4687.52 5902.53 0.62 -0.61 -0.09 26-DEC~98 MWD 10157.57 62.31 51.79 277.73 5914.59 7778.27 4837.65 6090.88 1.56 1.54 0.26 26-DEC~98 MWD 10436.87 61.77 51.79 279.30 6045.54 8024.97 4990.25 6284.72 0.19 -0.19 0.00 ,26-DEC-98 MWD 10622.00 61.43 52.12 185.13 6133.59 8187.81 5090.61 6412.97 0.24 -0.i 8 0.18 26-DEC-98 MWD 10808.92 59.42 53.37 186.92 6225.85 8350.33 5189.02 6542.34 1.22 -1.08 0.67 26-DEC-98 MWD 10995.88 58.77 53.36 186.96 6321.87 8510.68 5284.75 6671.07 0.35 -0.35 -0.01 27-DEC-98 MWD 11184.18 58.76 53.95 188.30 6419.52 8671.58 5380.16 6800.75 0.27 -0.01 0.31 27-DEC-98 MWD 11369.64 58.15 54.09 185.46 6516.54 8829.50 5473.02 6928.65 0.34 -0.33 0.08 27-DEC-98 MWD 11558.05 58.30 53.98 188.41 6615.76 8989.53 5567.09 7058.29 0.09 0.08 -0.06 28-DEC-98 MWD 11744.85 58'.58 53.95 186.80 6713.53 9148.58 5660.73 7187.00 0.15 0.15 -0.02 28-DEC-98 MWD 11821.53 58.53 54.07 76.68 6753.53 9213.94 5699.17 7239.93 0.15 -0.07 0.16 PRO.TO TD i28-DEC-98 MWD 11918.00 58.53 54.07 96.47 6803.89 9296.14 5747.45 7306.56 0.00 0.00 0.00 CLO.DIST=9296.18'AZI=51.81 ') sper--r--\l-sun C R I L..L IN G 5 e R V I c: e 5 27 -Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 cr3 ~ ~/J Re: Distribution of Survey Data for Well 1 C-16 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 11,918.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, // g : " ,.. ;1,:\-;:. ~: William T. Allen Su rvey Manager Attachment(s) ö··" ...<-, ·I ~~;' :} LJ ~::- ~.) . .:. 5631 Silverado Way, Suite G . Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535 A Halliburton Company North Slope Alaska ASP Zone 4 Kuparuk lC, Slot lC- 16 lC-16 Job No. AKMM90045, Surveyed: 28 December, 1998 SURVEY REPORT 21 January, 1999 Your Ref: API-500292293400 KBE-101.28 Surface Coordinates: 5968825.37 N, 561916.31 E (70° 19' 31.3018" N, 149° 29' 52.5233" W) si=er',r~j-sun DRILLING SERVICES ORIGINAL Survey Ref: svy1948 Sperry-Sun Drilling Services Survey Report for 1C- 16 Your Ref: AP1-500292293400 Job No. AKMM90045, Surveyed: 28 December, 1998 North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -101.28 121.00 0.000 0.000 19.72 203.92 0.500 354.710 102.64 290.50 1.260 29.700 189.21 378.43 3.310 45.200 277.06 468.57 5.830 50.300 366.91 559.55 8.490 51.340 457.17 650.48 11.850 54.030 546.66 740.59 15.350 52.250 634.23 831.21 18.450 51.190 720.93 921.37 20.150 51.860 806.02 1012.49 22.980 52.390 890.75 1103.51 27.260 52.290 973.14 1198.63 30.640 50.810 1056.37 1293.90 33.260 50.400 1137.20 1386.58 35.780 51.070 1213.55 1477.36 38.350 51.370 1285.99 1569.91 41.510 51.230 1356.95 1664.19 43.190 51.480 1426.62 1757.99 46.550 52.410 1493.09 1853.42 49.500 52.240 1556.91 1945.62 50.930 51.430 1615.91 2037.97 53.840 50.970 1672.27 2132.90 56.020 48.540 1726.81 2227.37 58.610 49.420 1777.82 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5968825.37 N 561916.31 E 121.00 0.00 N 0,00 E 5968825.37 N 561916.31 E 203.92 0.36 N 0.03 W 5968825.73 N 561916.27 E 290.49 1.56 N 0.40 E 5968826.94 N 561916.70 E 378.34 4.19 N 2.68 E 5968829.58 N 561918.96 E 468,19 8.95 N 8.05 E 5968834.39 N 561924.29 E 558.45 16.10 N 16.85 E 5968841.61 N 561933.03 E 647.94 25.78 N 29.66 E 5968851.39 N 561945.75 E 735.51 38.52 N 46.58 E 5968864.27 N 561962.57 E 822.21 54.85 N 67.24 E 5968880.78 N 561983.10 E 907.30 73.39 N 90.57 E 5968899.50 N 562006.28 E 992.03 93.94 N 117.01 E 5968920.27 N 562032.55 E 1074.42 117.54 N 147.59 E 5968944.13 N 562062.93 E 1157.65 146.19 N 183.63 E 5968973.07 N 562098.72 E 1238,48 178.19 N 222.58 E 5969005.39 N 562137.41 E 1314.83 211.42 N 263.24 E 5969038.96 N 562177.80 E 1387.27 245.68 N 305.90 E 5969073.57 N 562220.17 E 1458.23 282.82 N 352.25 E 5969111.09 N 562266.21 E 1527.90 322.48 N 401.85 E 5969151.16 N 562315.49 E 1594.37 363.26 N 453.96 E 5969192.36 N 562367.26 E 1658.19 406.61 N 510.11 E 5969236.18 N 562423.05 E 1717.19 450.40 N 565.81 E 5969280.42 N 562478.38 E 1773.55 496.23 N 622.81 E 5969326.73 N 562535.00 E 1828.09 546.44 N 682.09 E 5969377.42 N 562593.87 E 1879.10 598.61 N 742.08 E 5969430.08 N 562653.42 E Dogleg Rate (°/100ft) 0.000 0.603 1.036 2,414 2.829 2.927 3.731 3.911 3.438 1.901 3.113 4.702 3.632 2.759 2.750 2.838 3.416 1.791 3.650 3.094 1.692 3.176 3.108 2.851 Vertical Section (ft) 0.00 0.00 0.20 1.29 4.71 11,87 23.21 39.25 60.43 86.77 116.57 150,05 188,68 234.71 285.11 337.62 392.33 451.73 515.24 581.40 652.33 723.18 796.32 873.96 953.38 ASP Zone 4 Kuparuk 1C Comment Continued... 21 January, 1999 - 15:02 -2- DriilQuest Sperry-Sun Drilling Services Survey Report for lC- 16 Your Ref: API-500292293400 Job No, AKMM90045, Surveyed: 28 December, 1998 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 2320.16 58.41o 49.550 1826.29 26oo.o9 59.480 50.650 1970.7o 2878.08 60.630 52.270 21o9.47 3160.1o 58.740 52.180 2251.81 3437.63 6O.lOO 51.87o 2393.oo 3719.98 58.770 52.370 2536.58 3998.17 6o.41o 53.790 2677.39 4279.06 59.19o 53.220 2818.68 4560.oo 57.840 53.560 2965.41 4842.96 58.980 51.660 3113.64 512O. lO 60.720 51.150 3252.83 5396.53 58.420 51.200 3392.83 5677.99 58.480 51.o90 354O.lO 5957.32 61.o60 51.990 3680.73 6237.90 59.400 51.740 3820.04 6517.11 57.71o 52.300 3965.69 6702.74 58.18o 50.440 4064.22 6889.07 60.760 51.19o 4158.87 7075.29 59.91o 51.490 4251.03 7263.35 58.580 50.780 4347.20 7351.o6 59.890 50.360 4392.06 7637.30 59.81o 49.170 4535.83 7916.99 59.630 51.560 4676.88 8197.46 59.320 52.020 4819.33 8478.59 58.310 51.510 4964.90 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (fi) (ft) 1927.57 650.01 N 802.23 E 5969481.98 N 562713.15 E 2071.98 803.82 N 986.20 E 5969637.30 N 562895.85 E 2210.75 953.88 N 1174.61 E 5969788.91 N 563083.01 E 2353.09 1103.01 N 1367.04 E 5969939.62 N 563274.20 E 2494.28 1250.02 N 1555.38 E 5970088.19 N 563461.32 E 2637.86 1399.30 N 1747.26 E 5970239.04 N 563651.97 E 2778.67 1543.39 N 1939.07 E 5970384.71N 563842.58 E 2919.96 1687.77 N 2134.23 E 5970530.69 N 564036.54 E 3066.69 1830.64 N 2326.54 E 5970675.15 N 564227.66 E 3214.92 1977.01N 2518.01E 5970823.09 N 564417.92 E 3354.11 2126.51 N 2705.30 E 5970974.13 N 564603.97 E 3494.11 2275.93 N 2890.98 E 5971125.08 N 564788.41 E 3641.38 2426.41 N 3077.76 E 5971277.09 N 564973.94 E 3782.01 2576.48 N 3266.74 E 5971428.72 N 565161.68 E 3921.32 2726.87 N 3458.30 E 5971580.68 N 565351.99 E 4066.97 2873.46 N 3646.05 E 5971728.81N 565538.52 E 4165.50 2971.67 N 3768.94 E 5971828.04 N 565660.60 E 4260.15 3073.06 N 3893.34 E 5971930.45 N 565784.16 E 4352.31 3174.15 N 4019.69 E 5972032.57 N 565909.67 E 4448.48 3275.55 N 4145.53 E 5972135.01 N 566034.67 E 4493.34 3323.41 N 4203.74 E 5972183.36 N 566092.48 E 4637.11 3483.29 N 4392.69 E 5972344.78 N 566280.10 E 4778.16 3637.34 N 4578.67 E 5972500.37 N 566464.81 E 4920.61 3786.78 N 4768.51E 5972651.37 N 566653.41E 5066.18 3935.62 N 4957.42 E 5972801.77 N 566841.09 E Dogleg Rate (°/100ft) 0.246 0.509 0.653 o.671 0.499 0.495 o.736 0.468 0.491 0.700 0.648 0.832 0.040 0.965 0.597 0.629 0.886 1.427 0.477 0.778 1.549 0.361 o.741 0.179 o.391 Vertical Section (ft) 1032.45 1272.16 1513.02 1756.46 1995.38 2238.48 2478.31 2720.94 2960.40 3201.38 3441.01 3679.34 3919.18 4160.50 4404.04 4642.23 4799.55 4960.02 5121.82 5283.42 5358.78 5606.15 5847.60 6089.19 6329.69 ASP Zone 4 Kuparuk 1C Comment Continued... 21 January, 1999 - 15:02 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C- 16 Your Ref: API-500292293400 Job No. AKMM90045, Surveyed: 28 December, 1998 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8760.56 59.790 50.520 5109.91 5211.19 4087.76 N 5145.37 E 5972955.45 N 567027.78 E 9041.01 58.930 52.060 5252.85 5354.13 4238.67 N 5333.64 E 5973107.90 N 567214.79 E 9317.91 61.090 52.260 5391.25 5492.53 4385.78 N 5523.03 E 5973256.57 N 567402.96 E 9600.78 59.730 51.340 5530.92 5632.20 4537.88 N 5716.33 E 5973410.26 N 567595.01 E 9879.84 58.020 51.080 5675.17 5776.45 4687.52 N 5902,53 E 5973561.44 N 567779.96 E 10157.57 62.310 51.790 5813.31 5914.59 4837.65 N 6090.88 E 5973713.11 N 567967.06 E 10436,87 61.770 51.790 5944.26 6045.54 4990,25 N 6284.72 E 5973867.30 N 568159.64 E 10622.00 61.430 52.120 6032.31 6133.59 5090.61 N 6412,97 E 5973968.72 N 568287.06 E 10808.92 59.420 53.370 6124.57 6225.85 5189.02 N 6542.34 E 5974068.20 N 568415.61 E 10995.88 58.770 53.360 6220.59 6321.87 5284.75 N 6671.07 E 5974164.98 N 568543.54 E 11184.18 58.760 53.950 6318.23 6419.51 5380.17 N 6800.75 E 5974261.47 N 568672.44 E 11369.64 58.150 54.090 6415.26 6516.54 5473.02 N 6928.65 E 5974355.38 N 568799.57 E 11558.05 58.300 53.980 6514.47 6615.75 5567.09 N 7058.29 E 5974450.51 N 568928.42 E 11744.85 58.580 53.950 6612.24 6713.52 5660.73 N 7187,00 E 5974545,21 N 569056.36 E 11821.53 58,530 54.070 6652.25 6753.53 5699.17 N 7239.94 E 5974584.08 N 569108.97 E 11918.00 58.530 54.070 6702.61 6803.89 5747,45 N 7306.56 E 5974632.91 N 569175.20 E 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. Magnetic Declination at Surface is 27.332° (28-Dec-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 51.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11918.00ft., The Bottom Hole Displacement is 9296.18ft., in the Direction of 51.811 o (True). Dogleg Rate (°/100fi) 0.605 0.563 0.783 0.558 0.618 1.560 0.193 0.241 1.223 0.348 0.268 0.335 0,094 0.151 0.149 0.000 Vertical Section (ft) 6571.49 6812,77 7O52.57 7298.54 7537.41 7778.27 8024.97 8187.81 8350.34 8510.68 8671.58 8829,50 8989.54 9148.58 9213,94 9296.15 ASP Zone 4 Kuparuk lC Comment Projected Survey Continued... 21 January, 1999 - 15:02 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 1C- 16 Your Ref: AP1-500292293400 Job No. AKMM90045, Surveyed: 28 December, 1998 North Slope Alaska ASP Zone 4 Kuparuk 1C Comments Measured Depth (ft) 11918.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6803.89 5747.45 N 7306.56 E Comment Projected Survey 21 January, 1999 - 15:02 - 5- DrillQuest TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Dcccmbcr 10, 1998 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Team Lcadcr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 1 C- 16 ARCO Alaska: Inc. Permit No: 98-246 Sur Loc: 1411'FNL. 910'FWL, Sec. 12, T1 IN, R10E. UM Btmhole Loc. 1027'FNL, 2226'FEL, Sec. 6, T1 IN. R11E. UM Dear Mr. Alvord: Encloscd is the approved application for pcrmit to drill the above referenced well. Annular disposal of drilling wastcs will not bc approved for this ,,,,'ell until sufficient data is submitted to ensure that thc requirements of 20 AAC 25.080 are met. Annular disposal of drilling wastc ,,,,'ill bc contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records, FIT data. and any CQLs must be submitted to thc Commission on form 10-403 prior to thc start of disposal operations. Plcasc note that any disposal of fluids generated from this drilling operation which are pumped down thc surface/production casing annulus of a well approvcd for annular disposal on Drill Site lC must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs 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 vear. Thc pcrmit to drill docs not cxcmpt you from obtaining additional permits required bv lmv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Blov,'out 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 mav be given . field inspector on thc North Slope pager at 659-3607. David W. J~hnston xx ~ Commission BY ORDER OF THE COMMISSION dlffEnclosurcs cc: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~'SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [~ lb Type of Well Exploratory E~ StratigraphicTest [~, Development Oil X Re-Entry [~ Deepen ~1 Service E~ Development Gas E~ single Zone X Multiple Zone E~, 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 60' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28242, ALK 2292 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1411' FNL, 910' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1271' FNL, 2482' FWL, Sec. 6, T11N, R11E, UM lC-16 #U-630610 At total depth 9. Approximate spud date Amount 1027' FNL, 2226' FEL, Sec. 6, T11 N, R11 E, UM 12/10/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 C-13 11743' MD 1027' @ TD feet 28.1' @ 283' feet 2560 6731' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum i~ole angle 59.44° MaxJrnum surface 2663 psig At total depth (TVD) 3378 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 7324' 41' 41' 7365' 4505' 954 Sx Arcticset III L & 682 Sx Class G 8.5" 7" 26.0# L-80 BTC MOD 11702' 41' 41' 11743' 6731' 199 sx 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 Structural Conductor RECEIVED Surface Intermediate ~irn°edrUCti°n 0 R IGI NAL ,,,OM Perforation depth: measured true vert~ca~ Alaska 0il & Gas Cons. C0fumis Anchorage 20. Attachments Filing fee X Property plat Fi BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Timevs depth plot I'~ Refraction analysis Fi Seabed report Fi 20AAC25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Drilling Team Leader Date · Commission Use Only Permit. Number.... APInumber ./~ IApprova, date ,/6~.../,~..~¢~ J See cover ,etter for - .,~. ~2_'~-j 50- ~ ~"-- ~ ~,~ other requirements L;ona~dons of approval Samples required Fi' Yes No Mud Icg required [] -Yes ~ No Hydrogen sulfide measures N Yes Fi No Directional survey required ~,1 Yes [~ No Required working pressure for DOPE 2M E~ 3M Fi ('~r~E] 1OM [~ 15M Other: !~riginal Signed By byorder of/ F) avid -W. Johnston Approved by Commissioner the commission Date --, Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Nov 17, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re'- Application for Permit to Drill lC-16 Kuparuk Development Production Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" Iongstring to TD and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. 11) ARCO also requests that this well be permitted for annular disposal for future drilling on 1C pad. Appropriate Leak Off Tests and Casing Pressure Tests will be provided. Please note that the anticipated spud date for this well is December 10, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord at (907) 265-6120. Operations Drilling Engineer CC: Kuparuk lC-16 Well File Chip Alvord ATO-1030 MJ Loveland NSK6 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk I C-16 Producer Drilling Fluid Type Surface Hole: Extended Bentonite Slurry Production Hole: Low Solids Non-Dispersed System Drilling Fluid Properties: Formation Density FV YP PV ppg sec/qt lb/100 ft2 cP Filtrate mi/30 min Permafrost 8.9 120-140 25-40 16-20 12-15 West Sak 9.5-9.8 50-80 15-25 20-26 7-8 Colville 8.8-9.9 35-40 5-8 4-8 8-15 HRZ 9.9 40-50 8-20 15-25 5-6 Kalubik 9.9 40-50 8-20 15-25 5-6 Kuparuk C Sands 10.4 50-60 (Tau 0) 7-9 20-30 5-6 Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid FI°w Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure): Based on a Pressure Build Up Well Test from a nearby well, expected reservoir pressures in the Kuparuk sands in the 1C pad area are approximately 9.9 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.4 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6398'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6496 ft)(0.52- 0.11 psi/ft) = 2663 psi 1C-16 Page 1 SG,11/19/98,v. 1 Drilling Area Risks: Drilling risks in the lC-16 area are 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. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. In addition, there is a possibility of shallow gas on lC-Pad. This will be addressed through control drilling and mud treatments. Well Proximity Risks: The nearest existing well to 1C-16 is lC-13. As designed, the minimum distance between the two wells would be 28.1' at 283' MD. Annular Pumping 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 annular disposal permitted existing well on DS-lC. Our record indicate that 1C-13 is under the maximum permitted volume. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The lC-16 well will be freeze protected after running the 3 Y2" tubing and prior to the drilling rig moving off of the well. We request that 1 C-16 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4485') + 1,500 psi Max Pressure = 4,298 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 1 C-16 Page 2 SG,11/19/98,v. 1 Drill and Case Plan for 1C-16 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 12 1/4" hole to the surface casing point at 7365' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job, · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's to 5000 psi high/250 psi Iow. Notify AOGCC 24 hours before test Make up 8 Y2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town . Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 Y2" hole to TD at +11,743' MD 10. Run and cement 7" 26# L80 BTC-Mod 11. RIH · with bit and scrapers Pressure test casing to 3000 psi for 30 minutes Displace well to filtered seawater 12. Run and land 3 1/2" tubing with gas lift completion and packer 13. Nipple down BOP's. Install production tree and pressure test same. 14. Secure well, release rig 1 C-16 Page 1 SG,11/18/98,vl 6OO 6OO 1200 -+- i800 2400 -4-- f-3 3000 0 ,-- 5600 4200 4800 V 5400 o.~.. ~; ..... For: GOLDBERG J:':::;:7,: Co~rdinote$ ore ~n 60OO 6600 7200 rARC0 Alaska, Inc. Sfrucfure: Pad lC Well : 16 Field : Kuperuk River Unit Local[on : North Slope, Aleska East (feet) -> I I NT'~--~ J TD LOCATION: -- !027' FNL, 2226' FEL I SEC. 6 T11N R11E TARGE ,' 51 65 AZIMUTH . ' - . wo=~499 ~o ~ TM0= 11287 fl737 (TO TA~GETI , ---Plone of Proposol.-- NORTH q420 EAST 6~52 ~80 ~/_~/8 cosi~ Pt. ' WSIO ~OCOC ,,Qp ~OP ~D=250 T~9=~50 Dg2=O ~.00 OP SURFACE LOCATION: ~ 1~11' FNL 910' FWL .... I ' SEC. i2, T11N, RIOE 15.00 DLS: 3.00 dee per 100 ft I 21.0~ 27.00 5~.00 59.00 45.00 51.00 ~/ PERMAFROST ~D=1801 TMD=2060 0EP=795 EOC~D=189$ TMD=2251 0EP=939 800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 ] 64C0 I 5600 4800 - 4000 L 3200 2400 I 1600 · i800 !° L 800 AVERAGE ANGLE . 59.44 DEG T/ WEST SAK SANDS WD=3889 TM0=6154 0EP=4316 WSIO TVD=,!-305 TMD=6972 BEP=5021 TV.0=¢419 TMD=7196 0EP=5214 5/8" CASING PT TV0=4-505 TM0=7365 0EP=5360 C80 1-V0=4665 TM0=7680 DEP=563i C50 TV0=5459 TM0=9202 C4-0 -f-VD=5749 TMD=9812 C30 TVD=6112 TMD=10526 C20 TVD=6234 TM0=10766 DEP=a288 BASE HRZ TVD=6285 TMD=10866 DEP=8574"~. K-1 MARKER TV0:6565 TMO=11024- 0EP=8510"%. 7" CASING PT TV0=6448 TMD=11187 0EP--865i T/ D TVD=6465 TMD=I i2i6 DEP=8676 ."3..'"~ TARGET T/ C4 TVD=6499 TMD= 11287-~,--~-.~ ~?~-,~,.~,~ T/.C3 TVD=6533 T~35~ .DE~=879~-~ T/ 02 TV0:6556 TM0=11399 0EP=8833~ T/ C1 TVD=6597 TM0=11480 DEP=8903 T/ El SHALE TV0=6617 TMD=i 15!9 DEP=8936 TD - CSG PT TV-D=6?31 TMD=ll?45 DEP=9130 i i i i i i i i i i i i i i Ji i J i I ii i I I I I i ~ I i i ; ~ O0 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Verf[cal Secffon (feel) -> Azimuth 51.65 with reference 0.00 N, 0.00 E from slot #16 .. , Ic,~o~ ~x ~;~.o. For: GOLDBERG i oot¢ p~otted : 6-Nay-98 olot R~ter~ce ;s ~6 Vets;on ~2. ~l~.e Vefdco~ ~eptns ore ra~erence 80 40 0 4-0 680 I ~ ~ 640 600 560 520 4-8O 44-0 4-00 1 ,360 ~ 320 ! 280 1 400 240 200 160 2900 22~/2800 4O0 50O 1 600 2400 i 200 2300 )0 22O0 i 20 / 1 cc? ¢1 ~00 !2100 80 ~ 1¢00 / ./800 !, 2000 .. 1/~oo \ 700 ~ . ~uu~ % 1200 600~-/700 ~400 .,../'~1800 o ¢ 4oo ~1 zoo %~ 6oo ARCO Alaska, Inc.1 I Structure : Pad IC Well : 16 j Field : Kupcruk River Unit Local[on : North Slope, Alasl<aj 80 0 0 80 East (feet) -> 80 120 160 200 240 280 320 [ I I I I t I I I I I I ! t 300~//2300~,~ 1800 600 1500 1700 360 400 440 480 520 , i I , , ~ ' I ~ 650 640 ,.-I'~oo /' .- / ./1500 ., .- ./ / / 1800 ./![¢00 1900 ./" .........,."1300 / ..'C~oo i i i i 120 160 i i i i t i i i i i i 200 240 280 320 360 400 East (feet) -> 600 h 560 ? 52¢ I /-//"'"/"/ I 400 / I z I320 0 2~C i 2~C 200 ~ !60 ~ 120 ~0 440 4~0 520 mooted bX M,choe~soo For: COIJ313ERG ] Oate plotted : 9-Nov-gB J Plot Reference is 16 Version ~2. ~ JCoordinotes ore in feet reference slo~ ~16. J ...................................A 1'~ (./(.)FieldStruclure-''j: Kuporuk~l: PodRiverA][ ('t S k ['11 91Cl. Jn[l~" Locat[on-~ '": WelINorth: SIope,l;~v~ AloskoCe t East (feel) -> bO0 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 3500 3000 250O 6~00 6000 bOO 1000 1500 2000 7500 3000 3500 4000 4500 5000 ',-~500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 7100 ,,~, 700 55oo .,,~oo .., ' 1~'.~'0 0 5ooo ,,.,,~'~ oo oo ,,,.Goo 1 O0 .,¥~00 4500 ~00 ,,~'500 61 O0 ,.,'~00 59n0 5500.~500 5900 - 4500 A 4000 5700 1500 /,,~'100 4900..~--- I 55oo ,..4~oo 530t ~300 ,./¥'~00 51 ~ 1 O0 ,/'~00 / 3900 .,'~300 ~oo/ ,,,49oo .~9oo ~ ~5oo ,,_'.' ~ 5700 )o// ,/~ zoo ~-"-55oo~ ' -- -' ' -' / 5300 ,//~oo /,~5oo //31 "/ 2000 O0 /./3300 / ..'~ oo ..--- ~5oo ~ 2900 ,/' / 4300 ,./2900 /4100 1500 2700 ,-"-: ~ ~ .-~-~ ~,~,~ /ZIUU /' o/uu ,/' / .3500 /2500 / 3300 /' / 3100 /23OO .~....;~_,~ ~2900 ../ ./" 2700 ,-.-"" 2500 1000 1 /2 100 · " . ........... 2300 ~'1900 500 ,1':?oo '"'190o 6500 6000 5500 5000 4500 4000 A I Z 3500 0 3000 ~, ---4-- 2500 ~ 2OOO 1500 leo0 5(]0 Eas! (feet)-> WELL PROFILE DATA 320 53O 340 ,510 SOu ARCO Alaska, Inc. Structure : Pad !C Well : :6 Field : Kuparuk River Unit Location : North Slope, Alaska TRUE NORTH 350 0 10 150 20 Ic,~o~ea ~ ~e~o. For: GOLDBERGi Dcte ~at~ed : Caordinate~ are :n fee[ reference [ rruc Ver[[cc~ Ccp~s crc r=fercncc RK8 (Pcr~cr I I~EQ 40 60 2C~ 28O 270 25O ! i2{0 i i0 1~0 1 ,o 0 '~ 7O 120 230 !30 22O 210 2OO 440 I 60 1 50~o 180 170 All depths shown ore Measured depths on Reference Wei: NormoI Plane Travelling Cylinder - Feet No Go Areas shown by double crc at appropriate depth No C-o = both wells' major uncertainty raOii in TC plane x Safety Factor of 1 ARCO Alaska, Inc. Pad 1C 16 slot #16 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 16 Version #2 Our ref : prop2940 License : Date printed : 9-Nov-98 Date created : 21-May-98 Last revised : 3-Nov-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.295,w149 29 52.562 Slot Grid coordinates are N 5968824.706, E 561914.991 Slot local coordinates are 1411.00 S 910.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10980'>,,14,Pad 1C Unknown Data,,WS1,Pad 1C GMS <0-7753'>,,5,Pad 1C PMSS <0-17089'>,,12,Pad 1C PMSS <0-11300'>,,il,Pad 1C GMS <O-9784'>,,7,Pad 1C GMS <O-9600'>,,8,Pad 1C GMS <O-7780'>,,1,Pad 1C PGMS <O-9002'>,,lOGI,Pad 1C GMS <O-9700'>,,3,Pad 1C GMS <O-~575'>,,4,Pad 1C ~MS <6948-7570'>,,WS#24,Pad lC GMS <O-10243'>,,6,Pad 1C MSS <O-7000'>,,gGI,Pad 1C GMS <0-7615'>,,2,Pad lC PMSS <O-8677'>,,13,Pad 1C Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Mar-98 276.5 120.0 120.0 2-Nov-98 7250.1 60.0 60.0 5-Aug-92 64.9 550.0 550.0 7-Jan-98 304.0 1405.6 1405.6 19-Mar-97 329.3 283.3 283.3 5-Aug-92 172.0 250.0 250.0 29-0ct-98 292.9 20.0 20.0 5-Aug-92 522.4 1050.0 1050.0 5-Aug-92 243.5 20.0 20.0 5-Aug-92 295.4 761.1 761.1 5-Aug-92 178.7 727.8 727.8 17-Dec-97 2837.2 11743.4 11743.4 5-Aug-92 52.4 250.0 250.0 2-Jan-98 369.2 250.0 250.0 21-Oct-98 407.1 961.1 961.1 17-Feb-98 28.1 283.3 283.3 ARCO Alaska, Inc. Pad 1C 16 slot #16 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 16 Version #2 Our ref : prop2940 License : Date printed : 9-Nov-98 Date created : 21-May-98 Last revised : 3-Nov-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is nT0 19 31.295,w149 29 52.562 Slot Grid coordinates are N 5968824.706, E 561914.991 Slot local coordinates are 1411.00 S 910.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1C,16 Kupaz-uk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 51.65 0.00 0.00 N 0.00 E 250.00 0.00 51.65 250.00 0.00 N 0.00 E 350.00 3.00 51.65 349.95 1.62 N 2.05 E 450.00 6.00 51.65 449.63 6.49 N 8.21 E 550.00 9.00 51.65 548.77 14.59 N 18.44 E 650.00 12.00 51.65 647.08 25.89 N 32.73 E 750.00 15.00 51.65 744.31 40.37 N 51.04 E 850.00 18.00 51.65 840.18 57.99 N 73.31 E 950.00 21.00 51.65 934.43 78.70 N 99.49 E 1050.00 24.00 51.65 1026.81 102.44 N 129.50 E 1150.00 27.00 51.65 1117.06 129.15 N 163.26 E 1250.00 30.00 51.65 1204.93 158.75 N 200.68 E 1350.00 33.00 51.65 1290.18 191.16 N 241.65 E 1450.00 36.00 51.65 1372.59 226.29 N 286.07 E 1550.00 39.00 51.65 1451.91 264.06 N 333.80 E 1650.00 42.00 51.65 1527.95 304.35 N 384.73 E 1750.00 45.00 51.65 1600.47 347.05 N 438.71 E 1850.00 48.00 51.65 1669.30 392.05 N 495.60 E 1950.00 51.00 51.65 1734.24 439.22 N 555.23 E 2050.00 54.00 51.65 1795.11 488.43 N 617.44 E 2060.06 54.30 51.65 1801.00 493.49 N 623.84 E 2150.00 57.00 51.65 1851.74 539.55 N 682.07 E 2231.31 59.44 51.65 1894.56 582.43 H 736.27 E 2500.00 59.44 51.65 2031.18 725.98 N 917.73 E 3000.00 59.44 51.65 2285.41 993.09 N 1255.39 E PROPOSAL LISTING Page 1 Your ref : 16 Version #2 Last revised : 3-Nov-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 KOP 3.00 2.62 3.00 10.46 3.00 23.51 3.00 41.74 3.00 65.08 3.00 93.48 3.00 126.85 3.00 165.12 3.00 208.16 3.00 255.87 3.00 308.12 3.00 364.75 3.00 425.62 3.00 490.56 3.00 '559.38 3.00 631.91 3.00 707.95 3.00 787.27 3.00 795.43 Base Permafrost 3.00 869.68 3.00 938.79 EOC 0.00 1170.16 0.00 1600.70 3500.00 59.44 51.65 2539.63 1260.20 N 1593.06 E 0.00 2031.25 4000.00 59.44 51.65 2793.86 1527.32 N 1930.73 E 0.00 2461.79 4500.00 59.44 51.65 3048.08 1794.43 N 2268.40 E 0.00 2892.34 5000.00 59.44 51.65 3302.31 2061.55 N 2606.06 E 0.00 3322.88 5500.00 59.44 51.65 3556.54 2328.66 N 2943.73 E 0.00 3753.43 6000.00 59.44 51.65 3810.76 2595.78 N 3281.40 E 0.00 4183.97 6153.87 59.44 51.65 3889.00 2677.98 N 3385.31 E 0.00 4316.47 Top West Sak Sands 6500.00 59.44 51.65 4064.99 2862.89 N 3619.07 E 0.00 4614.52 6972.04 59.44 51.65 4305.00 3115.07 N 3937.85 E 0.00 5020.99 WS10 7000.00 59.44 51.65 4319.22 3130.00 N 3956.73 E 0.00 5045.06 7196.25 59.44 51.65 4419.00 3234.85 N 4089.27 E 0.00 5214.05 C100 7365.39 59.44 51.65 4505.00 3325.21 N 4203.49 E 0.00 5359.70 9 5/8" Casing Pt. 7500.00 59.44 51.65 4573.44 3397.12 N 4294.40 E 0.00 5475.61 7680.07 59.44 51.65 4665.00 3493.32 N 4416.01 E 0.00 5630.67 C80 8000.00 59.44 51.65 4827.67 3664.23 N 4632.07 E 0.00 5906.15 8500.00 59.44 51.65 5081.89 3931.35 N 4969.73 E 0.00 6336.70 9000.00 59.44 51.65 5336.12 4198.46 N 5307.40 E 0.00 6767.24 9202.34 59.44 51.65 5439.00 4306.55 N 5444.05 E 0.00 6941.47 C50 9500.00 59.44 51.65 5590.35 4465.57 N 5645.07 B 0.00 7197.79 9812.03 59.44 51.65 5749.00 4632.27 N 5855.79 E 0.00 7466.47 C40 10000.00 59.44 51.65 5844.57 4732.69 N 5982.74 E 0.00 7628.33 10500.00 59.44 51.65 6098.80 4999.80 N 6320.40 E 0.00 8058.88 10525.96 59.44 51.65 6112.00 5013.67 N 6337.93 E 0.00 8081.23 C30 10765.90 59.44 51.65 6234.00 5141.86 N 6499.98 E 0.00 8287.85 C20 10866.21 59.44 51.65 6285.00 5195.44 N 6567.72 E 0.00 8374.22 Base KRZ All data is in feet unless otherwise stated. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,16 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 16 Version #2 Last revised : 3-Nov-98 Dogleg Vert Deg/100ft Sect 11000.00 59.44 51.65 6353.03 5266.92 N 6658.07 E 0.00 8489.42 11023.55 59.44 51.65 6365.00 5279.50 N 6673.97 E 0.00 8509.70 K-1 Marker 11187.09 59.44 51.65 6448.15 5366.87 N 6784.42 E 0.00 8650.53 7" Casing Pt. 11216.29 59.44 51.65 6463.00 5382.47 N 6804.14 E 0.00 8675.67 Top D 11287.07 59.44 51.65 6498.99 5420.28 N 6851.94 E 0.00 8736.62 TARGET - Top C4 11287.09 59.44 51.65 6499.00 5420.29 N 6851.95 E 0.00 8736.64 1C-I Conv or Heel Rvsd 30-Oct'98 11353.96 59.44 51.65 6533.00 5456.01 N 6897.11 E 0.00 8794.22 Top C3 11399.20 59.44 51.65 6556.00 5480.18 N 6927.66 E 0.00 8833.17 Top C2 11479.83 59.44 51.65 6597.00 5523.26 N 6982.12 E 0.00 8902.60 Top Cl 11500.00 59.44 51.65 6607.25 5534.03 N 6995.74 E 0.00 8919.97 11519.17 59.44 51.65 6617.00 5544.27 N 7008.68 E 11743.38 59.44 51.65 6731.00 5664.05 N 7160.10 E 0.00 8936.47 Top B,Shale 0.00 9129.54 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,16 Kupaz-u,k River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 16 Version #2 Last revised : 3-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 2060.06 1801.00 2231.31 1894.56 6153.87 3889.00 6972.04 4305.00 7196.25 4419.00 7365.39 4505.00 7680.07 4665.00 9202.34 5439.00 9812.03 5749.00 10525.96 6112.00 10765.90 6234.00 10866.21 6285.00 11023.55 6365.00 11187.09 6448.15 11216.29 6463.00 11287.07 6498.99 11287.09 6499.00 11353.96 6533.00 11399.20 6556.00 11479.83 6597.00 11519.17 6617.00 11743.38 6731.00 0.00 493 49 582 43 2677 98 3115 07 3234 85 3325 21 3493.32 4306.55 4632.27 5013.67 5141.86 5195.44 5279.50 5366.87 5382.47 5420.28 5420.29 5456.01 5480.18 5523.26 5544.27 5664.05 0.00 E KOP 623.84 E Base Permafrost 736.27 E EOC 3385.31 E Top West Sak Sands 3937.85 E WS10 4089.27 E C100 4203.49 E 9 5/8" Casing Pt. 4416.01 E C80 5444.05 E C50 5855.79 E C40 6337.93 E C30 6499.98 E C20 6567.72 E Base HRZ 6673.97 E K-1 Marker 6784.42 E 7" Casing Pt. 6804.14 E Top D 6851.94 E TARGET - Top C4 6851.95 E lC-I Conv or Heel Rvsd 30-Oct-98 6897.11 E Top C3 6927.66 E Top C2 6982.12 E Top C1 7008.68 E Top B Shale 7160.10 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7365.39 4505.00 3325.21N 4203.49E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11187.10 6448.16 5366.87N 6784.42E 7" Casing 0.00 0.00 0.00N 0.00E 11743.38 6731.00 5664.05N 7160.10E 5 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-I Cony or Heel Rv 568722.000,5974300.000,0.0000 6499.00 5420.29N 6851.95E 21-May-98 ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 16 Version #2 Last revised : 3-Nov-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 51.65 0.00 1411.00 S 910.00 E 0.00 0.00 250.00 0.00 51.65 250.00 1411.00 S 910.00 E 0.00 0.00 KOP 350.00 3.00 51.65 349.95 1409.38 S 912.05 E 3.00 2.62 450.00 6.00 51.65 449.63 1404.51 S 918.21 E 3.00 10.46 550.00 9.00 51.65 548.77 1396.41 S 928.44 E 3.00 23.51 650.00 12.00 51.65 647.08 1385.11 S 942.73 E 3.00 41.74 750.00 15.00 51.65 744.31 1370.63 S 961.04 E 3.00 65.08 850.00 18.00 51.65 840.18 1353.01 S 983.31 E 3.00 93.48 950.00 21.00 51.65 934.43 1332.30 S 1009.49 E 3.00 126.85 1050.00 24.00 51.65 1026.81 1308.56 S 1039.50 E 3.00 165.12 1150.00 27.00 51.65 1117.06 1281.85 S 1073.26 E 3.00 208.16 1250.00 30.00 51.65 1204.93 1252.25 S 1110.68 E 3.00 255.87 1350.00 33.00 51.65 1290.18 1219.84 S 1151.65 E 3.00 308.12 1450.00 36.00 51.65 1372.59 1184.71 S 1196.07 E 3.00 364.75 1550.00 39.00 51.65 1451.91 1146.94 S 1243.80 E 3.00 425.62 1650.00 42.00 51.65 1527.95 1106.65 S 1294.73 E 3.00 490.56 1750.00 45.00 51.65 1600.47 1063.95 S 1348.71 E 3.00 '559.38 1850.00 48.00 51.65 1669.30 1018.95 S 1405.60 E 3.00 631.91 1950.00 51.00 51.65 1734.24 971.78 S 1465.23 E 3.00 707.95 2050.00 54.00 51.65 1795.11 922.57 S 1527.44 E 3.00 787.27 2060.06 54.30 51.65 1801.00 917.51 S 1533.84 E 3.00 795.43 2150.00 57.00 51.65 1851.74 871.45 S 1592.07 E 3.00 869.68 2231.31 59.44 51.65 1894.56 828.57 S 1646.27 E 3.00 938.79 2500.00 59.44 51.65 2031.18 685.02 S 1827.73 E 0.00 1170.16 3000.00 59.44 51.65 2285.41 417.91 S 2165.39 E 0.00 1600.70 Base Permafrost EOC 3500.00 59.44 51.65 2539.63 150.80 S 2503.06 E 0.00 2031.25 4000.00 59.44 51.65 2793.86 116.32 N 2840.73 E 0.00 2461.79 4500.00 59.44 51.65 3048.08 383.43 N 3178.40 E 0.00 2892.34 5000.00 59.44 51.65 3302.31 650.55 N 3516.06 E 0.00 3322.88 5500.00 59.44 51.65 3556.54 917.66 N 3853.73 E 0.00 3753.43 6000.00 59.44 51.65 3810.76 1184.78 N 4191.40 E 0.00 4183.97 6153.87 59.44 51.65 3889.00 1266.98 N 4295.31 E 0.00 4316.47 6500.00 59.44 51.65 4064.99 1451.89 N 4529.07 E 0.00 4614.52 6972.04 59.44 51.65 4305.00 1704.07 N 4847.85 E 0.00 5020.99 7000.00 59.44 51.65 4319.22 1719.00 N 4866.73 E 0.00 5045.06 Top West Sak Sands WS10 7196.25 59.44 51.65 4419.00 1823.85 N 4999.27 E 0.00 5214.05 7365.39 59.44 51.65 4505.00 1914.21 N 5113.49 E 0.00 5359.70 7500.00 59.44 51.65 4573.44 1986.12 N 5204.40 E 0.00 5475.61 7680.07 59.44 51.65 4665.00 2082.32 N 5326.01 E 0.00 5630.67 8000.00 59.44 51.65 4827.67 2253.23 N 5542.07 E 0.00 5906.15 C100 9 5/8" Casing Pt. C80 8500,00 59.44 51.65 5081.89 2520.35 N 5879.73 E 0.00 6336.70 9000.00 59.44 51.65 5336.12 2787.46 N 6217.40 E 0.00 6767.24 9202.34 59.44 51.65 5439.00 2895.55 N 6354.05 E 0.00 6941.47 C50 9500.00 59.44 51.~5 5590.35 3054.57 N 6555.07 E 0.00 7197.79 9812.03 59.44 51.65 5749.00 3221.27 N 6765.79 E 0.00 7466.47 C40 10000.00 59.44 51.65 5844.57 3321.69 N 6892.74 E 0.00 7628.33 10500.00 59.44 51.65 6098.80 3588.80 N 7230.40 E 0.00 8058.88 10525.96 59.44 51.65 6112.00 3602.67 N 7247.93 E 0.00 8081.23 C30 10765.90 59.44 51.65 6234.00 3730.86 N 7409.98 E 0.00 8287.85 C20 10866.21 59.44 51.65 6285.00 3784.44 N 7477.72 E 0.00 8374.22 Base KRZ All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 12, T11N, R10E and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C, 16 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 11000.00 59.44 51.65 6353.03 3855.92 N 7568.07 11023.55 59.44 51.65 6365.00 3868.50 N 7583.97 11187.09 59.44 51.65 6448.15 3955.87 N 7694.42 11216.29 59.44 51.65 6463.00 3971.47 N 7714.14 11287.07 59.44 51.65 6498.99 4009.28 N 7761.94 11287.09 59.44 51.65 6499.00 4009.29 N 7761.95 E 11353.96 59.44 51.65 6533.00 4045.01 N 7807.11 E 11399.20 59.44 51.65 6556.00 4069.18 N 7837.66 E 11479.83 59.44 51.65 6597.00 4112.26 N 7892.12 E 11500.00 59.44 51.65 6607.25 4123.03 N 7905.74 E 11519.17 59.44 51.65 6617.00 4133.27 N 7918.68 E 11743.38 59.44 51.65 6731.00 4253.05 N 8070.10 E PROPOSAL LISTING Page 2 Your ref : 16 Version #2 Last revised : 3-Nov-98 Dogleg Vert Deg/100ft Sect 0.00 8489.42 0.00 8509.70 K~I Marker 0.00 8650.53 7" Casing Pt. 0.00 8675.67 Top D 0.00 8736.62 TARGET - Top C4 0.00 8736.64 1C-I Conv or Heel Rvsd 30-0ct-98 0.00 8794.22 Top C3 0.00 8833.17 Top C2 0.00 8902.60 Top C1 0.00 8919.97 0.00 8936.47 Top B,Shale 0.00 9129.54 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 12, T11N, R10E and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 16 Version #2 Last revised : 3-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 2060 06 2231 31 6153 87 6972 04 7196 25 7365 39 7680 07 9202.34 9812.03 10525.96 10765.90 10866.21 11023.55 11187.09 11216.29 11287.07 11287.09 11353.96 11399.20 11479.83 11519.17 11743.38 250.00 1411.00 S 910.00 E KOP 1801.00 917.51 S 1533.84 E Base Permafrost 1894.56 828.57 S 1646.27 E EOC 3889.00 1266.98 N 4295.31 E Top West Sak Sands 4305.00 1704.07 N 4847.85 E WS10 4419.00 1823.85 N 4999.27 E Cl00 4505.00 1914.21 N 5113.49 E 9 5/8" Casing Pt. 4665.00 2082.32 N 5326.01 E C80 5439.00 2895.55 N 6354.05 E C50 5749.00 3221.27 N 6765.79 E C40 6112.00 3602.67 N 7247.93 E C30 6234.00 3730.86 N 7409.98 E C20 6285.00 3784.44 N 7477.72 E Base HRZ 6365.00 3868.50 N 7583.97 E K-1 Marker 6448.15 3955.87 N 7694.42 E 7" Casing Pt. 6463.00 3971.47 N 7714.14 E Top D 6498.99 4009.28 N 7761.94 E TARGET - Top C4 6499.00 4009.29 N 7761.95 E 1C-I Conv or Heel Rvsd '30-0ct-98 6533.00 4045.01 N 7807.11 E Top C3 6556.00 4069.18 N 7837.66 E Top C2 6597.00 4112.26 N 7892.12 E Top C1 6617.00 4133.27 N 7918.68 E Top B Shale 6731.00 4253.05 N 8070.10 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1411.00S 910.00E 7365.39 4505.00 1914.21N 5113.49E 9 5/8" Casing 0.00 0.00 1411.00S 910.00E 11187.10 6448.16 3955.87N 7694.42E 7" Casing 0.00 0.00 1411.00S 910.00E 11743.38 6731.00 4253.05N 8070.10E 5 1/2" Liner Targets associated with this wellpath _ Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-I Cony or Heel Rv 568722.000,5974300.000,0.0000 6499.00 4009.29N 7761.95E 21-May-98 ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C O O R 0.00 0.00 51.65 0.00 0.00 250.00 0.00 51.65 250.00 0.00 350.00 3.00 51.65 349.95 1.62 450.00 6.00 51.65 449.63 6.49 550.00 9.00 51.65 548.77 14.59 ANGULAR DiNATES PROPOSAL LISTING Page 1 Your ref : 16 Version #2 Last revised : 3-Nov-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. N 0.00 E 0.00 0.00 0.00 0.00 N/A N 0.00 E 0.00 0.65 0.65 0.38 N/A N 2.05 E 2.62 0.93 0.92 0.53 51.65 N 8.21 E 10.46 1.30 1.19 0.68 51.65 N 18.44 E 23.51 1.82 1.47 0.83 51.65 650.00 12.00 51.65 647,08 25.89 750.00 15.00 51.65 744.31 40.37 850.00 18.00 51.65 840.18 57.99 950.00 21.00 51.65 934.43 78.70 1050.00 24.00 51.65 1026.81 102.44 N 32.73 E 41.74 2.55 1.78 0.99 51.65 N 51.04 E 65.08 3.50 2.11 1.15 51.65 N 73.31 E 93.48 4.71 2.47 1.33 51.65 N 99.49 E 126.85 6.18 2.87 1.52 51.65 N 129.50 E 165.12 7.93 3.29 1.73 51.65 1150.00 27.00 51.65 1117.06 129.15 1250.00 30.00 51.65 1204.93 158.75 1350.00 33.00 51.65 1290.18 191.16 1450.00 36.00 51.65 1372.59 226.29 1550.00 39.00 51.65 1451.91 264.06 1650.00 42.00 51.65 1527.95 304.35 1750.00 45.00 51.65 1600.47 347.05 1850.00 48.00 51.65 1669.30 392.05 1950.00 51.00 51.65 1734.24 439.22 2050.00 54.00 51.65 1795.11 488.43 2060.06 54.30 51.65 1801.00 493.49 2150.00 57.00 51,65 1851.74 539.55 2231.31 59.44 51.65 1894.56 582.43 2500.00 59.44 51.65 2031.18 725.98 917.73 E 1170.16 3000.00 59.44 51.65 2285.41 993.09 1255.39 E 1600.70 N 163.26 E 208.16 9.99 3.7~ 1.97 51.65 N 200.68 E 255.87 12.37 4.22 2.25 51.65 N 241.65 E 308.12 15.08 4.72 2.57 51.65 N 286.07 E 364.75 18.13 5.24 2.93 51.65 N 333.80 E 425.62 21.54 5.78 3.35 51.65 N 384.73 E 490.56 25.32 6.32 3.81 51.65 . N 438.71 E 559.38 29.45 6.87 4.34 51.65 N 495.60 E 631.91 33.95 7.42 4.91 51.65 N 555.23 E 707.95 38.81 7.96 5.55 51.65 N 617.44 E 787.27 44.02 8.49 6.24 51.65 N 623.84 E 795.43 44.58 8.54 6.31 51.65 N 682.07 E 869.68 49.57 9.00 6.98 51.65 N 736.27 E 938.79 54.30 9.40 7.62 51..65 N 69.99 10.73 9.76 51.65 N 99.34 13.21 13.78 51.65 3500.00 59.44 51.65 2539.63 1260.20 N 1593.06 E 2031.25 128.77 15.69 17.81 51.65 4000.00 59.44 51.65 2793.86 1527.32 N 1930.73 E 2461.79 158.23 18.16 21.86 51.65 4500.00 59.44 51.65 3048.08 1794.43 N 2268.40 E 2892.34 187.71 20.63 25.90 51.65 5000.00 59.44 51.65 3302.31 2061.55 N 2606.06 E 3322.88 217.19 23.11 29.96 51.65 5500.00 59.44 51.65 3556.54 2328.66 N 2943.73 E 3753.43 246.69 25.58 34.01 51.65 6000.00 59.44 51.65 3810.76 2595.78 N 3281.40 E 4183.97 276.19 28.05 38.06 51.65 6153.87 59.44 51.65 3889.00 2677.98 N 3385.31 E 4316.47 285.27 28.81 39.31 51.65 6500.00 59.44 51.65 4064.99 2862.89 N 3619.07 E 4614.52 305.69 30.52 42.12 51.65 6972.04 59.44 51.65 4305.00 3115.07 N 3937.85 E 5020.99 333.55 32.86 45.95 51.65 7000.00 59.44 51.65 4319.22 3130.00 N 3956.73 E 5045.06 335.20 33.00 46.17 51.65 7196.25 59.44 51.65 4419.00 3234.85 N 4089.27 E 5214.05 346.78 33.97 47.77 51.65 7365.39 59.44 51.65 4505.00 3325.21 N 4203.49 E 5359.70 356.76 34.80 49.14 51.65 7500.00 59.44 51.65 4573.44 3397.12 N 4294.40 E 5475.61 364.71 35.47 50.23 51.65 7680.07 59.44 51.65 4665.00 3493.32 N 4416.01 E 5630.67 375.34 36.36 51.69 51.65 8000.00 59.44 51.65 4827.67 3664.23 N 4632.07 E 5906.15 394.22 37.94 54.29 51.65 8500.00 59.44 51.65 5081.89 3931.35 N 4969.73 E 6336.70 423.73 40.41 58.34 51.65 9000.00 59.44 51.65 5336.12 4198.46 N 5307.40 E 6767.24 453.24 42.89 62.40 51.65 9202.34 59.44 51.65 5439.00 4306.55 N 5444.05 E 6941.47 465.18 43.89 64.04 51.65 9500.00 59.44 51.65 5590.35 4465.57 N 5645.07 E 7197.79 482.75 45.36 66.46 51.65 9812.03 59.44 51.65 5749.00 4632.27 N 5855.79 E 7466.47 501.17 46.90 68.99 51.65 10000.00 59.44 51.65 5844.57 4732.69 N 5982.74 E 7628.33 512.27 47.83 70.52 51.65 10500.00 59.44 51.65 6098.80 4999.80 N 6320.40 E 8058.88 541.78 50.30 74.57 51.65 10525.96 59.44 51.65 6112.00 5013.67 N 6337.93 E 8081.23 543.31 50.43 ' 74.78 51.65 10765.90 59.44 51.65 6234.00 5141.86 N 6499.98 E 8287.85 557.48 51.62 76.73 51.65 10866.21 59.44 51.65 6285.00 5195.44 N 6567.72 E 8374.22 563.40 52.11 77.55 51.65 Ail data is in feet unless otherwise stated. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 2 Your ref : 16 Version #2 Last revised : 3-Nov-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 11000.00 59.44 51.65 6353.03 5266.92 N 6658.07 E 8489.42 11023.55 59.44 51.65 6365.00 5279.50 N 6673.97 E 8509.70 11187.09 59.44 51.65 6448.15 5366.87 N 6784.42 E 8650.53 11216.29 59.44 51.65 6463.00 5382.47 N 6804.14 E 8675.67 11287.07 59.44 51.65 6498.99 5420.28 N 6851.94 E 8736.62 11287.09 59.44 51.65 6499.00 5420.29 N 6851.95 E 8736.64 11353.96 59.44 51.65 6533.00 5456.01 N 6897.11 E 8794.22 11399.20 59.44 51.65 6556.00 5480.18 N 6927.66 E 8833.17 11479.83 59.44 51.65 6597.00 5523.26 N 6982.12 E 8902.60 11500.00 59.44 51.65 6607.25 5534.03 N 6995.74 E 8919.97 11519.17 59.44 51.65 6617.00 5544.27 N 7008.68 E 8936.47 11743.38 59.44 51.65 6731.00 5664.05 N 7160.10 E 9129.54 571.29 52.77 78.63 51.65 572.68 52.89 78.82 51.65 582.34 53.70 80.15 51.65 584.06 53.84 80.39 51.65 588.24 54.19 80.96 51.65 588.24 54.19 80.96 51.65 592.19 54.52 81.50 51.65 594.86 54.75 81.87 51.65 599.62 55.15 82.53 51.65 600.81 55.25 82.69 51.65 601.94 55.3~ 82.85 51.65 615.17 56.45 84.67 51.65 POSITION UNCERTAINTY SUM/W2%RY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 11743 ARCO (H.A. Mag) User specified 615.17 56.45 84.67 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 16 Version #2 Last revised : 3-Nov-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 2060.06 2231.31 6153.87 6972.04 7196.25 7365.39 7680.07 9202.34 9812.03 10525 96 10765 90 10866 21 11023 55 11187 09 11216 29 11287 07 11287 09 11353.96 11399.20 11479.83 11519.17 11743.38 1801.00 493.49 N 623.84 E Base Permafrost 1894.56 582.43 N 736.27 E EOC 3889.00 2677.98 N 3385.31 E Top West Sak Sands 4305.00 3115.07 N 3937.85 E WS10 4419.00 3234.85 N 4089.27 E C100 4505.00 3325.21 N 4203.49 E 9 5/8" Casing Pt. 4665.00 3493.32 N 4416.01 E C80 5439.00 4306.55 N 5444.05 E C50 5749.00 4632.27 N 5855.79 E C40 6112.00 5013.67 N 6337.93 E C30 6234.00 5141.86 N 6499.98 E C20 6285.00 5195.44 N 6567.72 E Base HRZ 6365.00 5279.50 N 6673.97 E K-1 Marker 6448.15 5366.87 N 6784.42 E 7" Casing Pt. 6463.00 5382.47 N 6804.14 E Top D 6498.99 5420.28 N 6851.94 E TARGET - Top C4 · 6499.00 5420.29 N 6851.95 E 1C-I Conv or Heel Rvsd 30-Oct-98 6533.00 5456.01 N 6897.11 E Top C3 6556.00 5480.18 N 6927.66 E Top C2 6597.00 5523.26 N 6982.12 E Top C1 6617.00 5544.27 N 7008.68 E Top B Shale 6731.00 5664.05 N 7160.10 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7365.39 4505.00 3325.21N 4203.49E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11187.10 6448.16 5366.87N 6784.42E 7" Casing 0.00 0.00 0.00N 0.00E 11743.38 6731.00 5664.05N 7160.10E 5 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised lC-I Cony or Heel Rv 568722.000,5974300.000,0.0000 6499.00 5420.29N 6851.95E 21-May-98 ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 16 Version #2 Last revised : 3-Nov-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 51.65 0.00 0.00N 0.00E 0.00 0.00 561914.99 5968824.71 250.00 0.00 51.65 250.00 0.00N 0.00E 0.00 0.00 561914.99 5968824.71 350.00 3.00 51.65 349.95 1.62N 2.05E 3.00 2.62 561917.03 5968826.35 450.00 6.00 51.65 449.63 6.49N 8.21E 3.00 10.46 561923.14 5968831.26 550.00 9.00 51.65 548.77 14.59N 18.44E 3.00 23.51 561933.31 5968839.44 650.00 12.00 51.65 647.08 25.89N 32.73E 3.00 41.74 561947.51 5968850.86 750.00 15.00 51.65 744.31 40.37N 51.04E 3.00 65.08 561965.69 5968865.49 850.00 18.00 51.65 840.18 57.99N 73.31E 3.00 93.48 561987.82 5968883.29 950.00 21.00 51.65 934.43 78.70N 99.49E 3.00 126.85 562013.83 5968904.21 1050.00 24.00 51.65 1026.81 102.44N 129.50E 3.00 165.12 562043.64 5968928.19 1150.00 27.00 51.65 1117.06 129.15N 163.26E 3.00 208.16 56207~.18 5968955.16 1250.00 30.00 51.65 1204.93 158.75N 200.68E 3.00 255.87 562114.35 5968985.06 1350.00 33.00 51.65 1290.18 191.16N 241.65E 3.00 308.12 562155.06 5969017.80 1450.00 36.00 51.65 1372.59 226.29N 286.07E 3.00 364.75 562199.18 5969053.30 1550.00 39.00 51.65 1451.91 264.06N 333.80E 3.00 425.62 562246.61 5969091.44 1650.00 42.00 51.65 1527.95 304.35N 384.73E 3.00 490.56 562297.20 5969132.14 1750.00 45.00 51.65 1600.47 347.05N 438.71E 3.00 559.38 562350.83 5969175.28 1850.00 48.00 51.65 1669.30 392.05N 495.60E 3.00 631.91 562407.34 5969220.73 1950.00 51.00 51.65 1734.24 439.22N 555.23E 3.00 707.95 562466.58 5969268.38 2050.00 54.00 51.65 1795.11 488.43N 617.44E 3.00 787.27 562528.38 5969318.09 2060.06 54.30 51.65 1801.00 493.49N 623.84E 3.00 795.43 562534.73 5969323.20 2150.00 57.00 51.65 1851.74 539.55N 682.07E 3.00 869.68 562592.58 5969369.74 2231.31 59.44 51.65 1894.56 582.43N 736.27E 3.00 938.79 562646.43 5969413.05 2500.00 59.44 51.65 2031.18 725.98N 917.73E 0.00 1170.16 562826.70 5969558.05 3000.00 59.44 51.65 2285.41 993.09N 1255.39E 0.00 1600.70 563162.15 5969827.87 3500.00 59.44 51.65 2539.63 1260.20N 1593.06E 0.00 2031.25 563497.60 5970097.70 4000.00 59.44 51.65 2793.86 1527.32N 1930.73E 0.00 2461.79 563833.06 5970367.52 4500.00 59.44 51.65 3048.08 1794.43N 2268.40E 0.00 2892.34 564168.51 5970637.35 5000.00 59.44 51.65 3302.31 2061.55N 2606.06E 0.00 3322.88 564503.96 5970907.17 5500.00 59.44 51.65 3556.54 2328.66N 2943.73E 0.00 3753.43 564839.41 5971177.00 6000.00 59.44 51.65 3810.76 2595.78N 3281.40E 0.00 4183.97 565174.86 5971446.82 6153.87 59.44 51.65 3889.00 2677.98N 3385.31E 0.00 4316.47 565278.10 5971529.86 6500.00 59.44 51.65 4064.99 2862.89N 3619.07E 0.00 4614.52 565510.32 5971716.65 6972.04 59.44 51.65 4305.00 3115.07N 3937.85E 0.00 5020.99 565827.0t 5971971.38 7000.00 59.44 51.65 4319.22 3130.00N 3956.73E 0.00 5045.06 565845.77 5971986.47 7196.25 59.44 51.65 4419.00 3234.85N 4089.27E 0.00 5214.05 565977.43 5972092.38 7365.39 59.44 51.65 4505.00 3325.21N 4203.49E 0.00 5359.70 566090.91 5972183.66 7500.00 59.44 51.65 4573.44 3397.12N 4294.40E 0.00 5475.61 566181.22 5972256.30 7680.07 59.44 51.65 4665.00 3493.32N 4416.01E 0.00 5630.67 566302.03 5972353.47 8000.00 59.44 51.65 4827.67 3664.23N 4632.07E 0.00 5906.15 566516.67 5972526.12 8500.00 59.44 51.65 5081.89 3931.35N 4969.73E 0.00 6336.70 566852.13 5972795.95 9000.00 59.44 51.65 5336.12 4198.46N 5307.40E 0.00 6767.24 567187.58 5973065.77 9202.34 59.44 51.65 5439.00 4306.55N 5444.05E 0.00 6941.47 567323.33 5973174.96 9500.00 59.44 51.65 5590.35 4465.57N 5645.07E 0.00 7197.79 567523.03 5973335.60 9812.03 59.44 51.65 5749.00 4632.27N 5855.79E 0.00 7466.47 567732.37 5973503.98 10000.00 59.44 51.65 5844.57 4732.69N 5982.74E 0.00 7628.33 567858.48 5973605.42 10500.00 59.44 51.65 6098.80 4999.80N 6320.40E 0.00 8058.88 568193.94 5973875.25 10525.96 59.44 51.65 6112.00 5013.67N 6337.93E 0.00 8081.23 568211.35 5973889.25 10765.90 59.44 51.65 6234.00 5141.86N 6499.98E 0.00 8287.85 568372.33 5974018.74 10866.21 59.44 51.65 6285.00 5195.44N 6567.72E 0.00 8374.22 568439.63 5974072.87 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 16 Version #2 Last revised : 3-Nov-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect ~asting Northing 11000.00 59.44 51.65 6353.03 5266.92N 6658.07E 0.00 8489.42 568529.39 5974145.07 11023.55 59.44 51.65 6365.00 5279.50N 6673.97E 0.00 8509.70 568545.19 5974157.78 11187.09 59.44 51.65 6448.15 5366.87N 6784.42E 0.00 8650.53 568654.91 5974246.03 11216.29 59.44 51.65 6463.00 5382.47N 6804.14E 0.00 8675.67 568674.~0 5974261.79 11287.07 59.44 51.65 6498.99 5420.28N 6851.94E 0.00 8736.62 568721.99 5974299.99 11287.09 59.44 51.65 6499.00 5420.29N 6851.95E 0.00 8736.64 568722.00 5974300.00 11353.96 59.44 51.65 6533.00 5456.01N 6897.11E 0.00 8794.22 568766.86 5974336.09 11399.20 59.44 51.65 6556.00 5480.18N 6927.66E 0.00 8833.17 568797.21 5974360.50 11479.83 59.44 51.65 6597.00 5523.26N 6982.12E 0.00 8902.60 568851.31 5974404.01 11500.00 59.44 51.65 6607.25 5534.03N 6995.74E 0.00 8919.97 568864.84 5974414.89 11519.17 59.44 51.65 6617.00 5544.27N 7008.68E 0.00 8936.47 568875.70 5974425.24 11743.38 59.44 51.65 6731.00 5664.05N 7160.10E 0.00 9129.54 569028.12 5974546.23 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16 and TVD from RKB {Parker #245) (101.00 Ft above mean sea level). Bottom hole distance is 9129.54 on azimuth 51.65 degrees from wellhead. Vertical section is from wellhead on azimuth 51.65 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,16 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 16 Version #2 Last revised : 3-Nov-98 Comments in wellpath ___ MD TVD Rectangular Coords. Comment 250 00 2060 06 2231 31 6153 87 6972 04 7196 25 7365 39 7680.07 9202.34 9812.03 10525.96 10765.90 10866.21 11023.55 11187.09 11216.29 11287.07 11287.09 11353.96 11399.20 11479.83 11519.17 11743.38 250 00 1801 00 1894 56 3889 00 4305 00 4419 00 4505 00 4665 00 5439 00 5749.00 6112.00 6234.00 6285.00 6365.00 6448.15 6463.00 6498.99 6499.00 6533.00 6556.00 6597.00 6617.00 6731.00 0.00N 493.49N 582.43N 2677 98N 3115 07N 3234 85N 3325 21N 3493 32N 4306 55N 4632 27N 5013 67N 5141 86N 5195 44N 5279.50N 5366.87N 5382.47N 5420.28N 5420.29N 5456.01N 5480.18N 5523.26N 5544.27N 5664.05N 0.00E 623.84E 736.27E 3385.31E 3937.85E 4089.27E 4203.49E 4416.01E 5444.05E 5855.79E 6337.93E 6499.98E 6567 72E 6673 97E 6784 42E 6804 14E 6851 94E 6851 95E 6897 11E 6927 66E 6982.12E 7008.68E 7160.10E KOP Base Permafrost EOC Top West Sak Sands WS10 C100 9 5/8" Casing Pt. C80 C50 C40 C30 C20 Base HRZ K-1 Marker 7" Casing Pt. Top D TARGET - Top C4 1C-I Cony or Heel Rvsd'30-Oct-98 Top C3 Top C2 Top C1 Top B Shale TD - Casing Pt .Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7365.39 4505.00 3325.21N 4203.49E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11187.10 6448.16 5366.87N 6784.42E 7" Casing 0.00 0.00 0.00N 0.00E 11743.38 6731.00 5664.05N 7160.10E 5 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-I Conv or Heel Rv 568722.000,5974300.000,0.0000 6499.00 5420.29N 6851.95E 21-May-98 PARKER RiG 245 BOP c:Ab MENTS ROTARY LEVEL HYDRIL ANNULAR PREVENTER 135/8 5000M RO]ARY ~; f~A~..': ·: ( 15.9d z_.. PIPE RAMS VARIABLE 4 1/2"X?" 135/8 5000M I)OUtil [ (;AIE BLIND RAMS 13 5/8 5000M 4 1116 1uM ~1, IIi I lh~ MANUAL MANU L MANUAl. __ 4 I."16" 1oM X 4 1!16 t¢M 5" i~C,~ ~ AfiiY : ·: ;:;.A;'.'; '. PIPE ~MS ( _?_?/.,_ ..~ 135/8 5000M . . . I I __--¢--' 11" 3M X i ~ 5/8" 5M~I BSA: ~ ' ... J 11" 3M I k t lEAD f' ~( ); ARY Tf TOP WELL tfi[:' AD ! 0. ?,I 38.58 t ,-~()iAI~¥' I/'LOC'K O'OWNS 38.70 ~<O~'ARY T! GRdUND LEVE __ 40.77 t.b0 ; ;.ANGL APl RING 4 1/.16 5M ,',--~ 39 r ,1 ii16 i0M BX 155 ../ 1/t6 bM R 45 t 1" 3M R 53 ~'~. ,,, 5/t~ 5M,~BX 160 14.56 _. .......... i()PWE-LL HEAD(7"CSG S/"O()L} GRAVEL PAD LEVI~[. ON RiG MATS OFF RIG MATS DWG 3.82 4.02 NOTE: DWG PARKER RIG 245 DtVE'~'~` '''r ,';' ~::;~ ~'''~ ...... bMENTS 2,-~ ;~} ~.'~ RQ-f'ARY LEV'--r: 29 22 SHAFFER 21 114" 2000K ANNULAR 21 1/4 2M 16" #150 16" QIVERTF.~ 21 1/42M I . .42 r' DSA 16 3/4 2M ..-- QUICK ~..--- ........ P. 1.~ ~.4 r,. ~ ;;]'. ! ...... j CO,',,l~), lC f L:RI i~ NEW QUICK COL~PLING I-- '"'"-~'~ WELDED w/TO? 2" ABOV[ GROUND LEV£:L ~ ,~/4 2M R 65 i ":'".' ~1 -':::,q FLEXTALiC 1 o .... U0 FLEXTALIC 41 :_',8 !-iOTARY TO TOP QUICK k~, EAD 40.6 ROTARY TO _.~ LOCK DOWNS 41.00 GROUND i. EVE[ r'l ON RIG MATS ~ OFF RIG MATS SINGLE PIECE MEASUREMENTS ARE ALL "ACTUAL" LENGTHS. IF USEING THESE MEASUREMENTS 'FO FIGURE A COBINATION OF PIECES. ADD ( ,':),:.'~i PER CONNECTION, · WELL PERMIT CHECKLIST COMPANY WELl_ NAME ,/~ ,,~/, .//('"',-" FIELD & POOL ~' ~_~_.~._.~_._(:~. INIT CLASS ,/'~ ,"/-,~J ~'/ ADMINISTRATION 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 dislance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unil ............ 8. If deviated, is we,bore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CM I' vol adequate to tie-in long string to surf csg ........ '18. CM I' 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 t0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder 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 ~ 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 ................. GEOLAREA N N N N N PROGRAM: exp [] dev~redrll [] serv [] wellbore sag II ann. disposal para req,~. ~"~(:~ UNIT# ///_,~' ~ . ON/OFF SHORE )N N N Y N ~ N N N N ~(~) N N N ~EOLOGY DATE/ 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. Permit can be issued w/o hydrogen sulfide measures ..... ..../Y N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ..... ' ........ Y N,.__., ........................................................................................................... Seabed condition survey (if off-shore) ............. JYY iY N Con. tact.nam, elphon,e .for weekly progress repods ............................................................................................................................. lexp~ora~ory omy] With proper cementing records, this plan ,~~ 1'-2..~.~.~~,., .,~.G/' ~'---TT~,- '--- (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Io surface; (C) wi~'~ibt'impair..._mechanical integrity of the well used for disposal; (D) will nol damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAG 25.412. GEOLOGY: ENG~NEERINGi UIC/Annular coMMISSION: J DJ-I'~,_...~-.--"~ DWJ ~ ,// RNC ' ,'~'J ~ Comments/Instructions: , i Mcheklisl rev 05129198 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Feb 11 15:10:24 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/11 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 ..................... 99/02/11 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 ~/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM- 90045 T. MCGUIRE D. BREEDEN 1C-16 500292293400 ARCO AXJ~SRA, INC. SPERRY-SUN DRILLING SERVICES Il-FEB-99 MWD RUN 2 AK-MM- 90045 S. BURKH3LRDT D. GLADDEN MWD RUN 3 A/<-MM- 90045 C. ULRICH D. GLADDEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MM-90045 S. BURKHARDT D. GLADDEN MWD RUN 5 AK-MM-90045 A. PIEPER GLADDEN/WHIT 12 lin 10E 1411 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 910 .00 101.30 60.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 16.000 120.0 3RD STRING 12.250 9.625 7403.0 PRODUCTION STRING 8.500 11918.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA R_AY (DGR) AND ELECTROM3tGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 3. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) , COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND MEG CREMER OF ARCO ALASKA, INC. ON 06 JANUARY, 1999. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1918'MD, 6804'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 300 PPM. MUD WEIGHT = FORMATION WATER SALINITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 10.3 PPG. 14545 PPM. SAi~DSTONE 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 FET 121 0 RPD 121 0 RPM 121 0 RPS 121 0 RPX 121 0 GR 121 0 ROP 122 FCNT 7350 NCNT 7350 NPHI 7350 PEF 7401 DRHO 7401 RHOB 7401 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 4904.0 2 4904.0 6198.0 3 6198.0 6316.0 4 6316.0 7412.0 5 7412.0 11918.0 STOP DEPTH 11849.0 11849.0 11849.0 11849.0 11849.0 11876.5 11918.0 11856.0 11856.0 11856.0 11865.5 11865.5 11865.5 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BLE 4 1 68 Code Offset Channel 0 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 121 11918 6019.5 23595 GR 10.41 506.71 103.477 23512 RPX 0.24 1873.86 15.4676 23457 RPS 0.13 2000 18.3858 23457 RPM 0.1 2000 27.3663 23457 RPD 0.05 2000 31.4819 23457 ROP 0 1710.77 207.812 23593 FET 0.05 109.51 1.18748 23457 NPHI 18.99 81.6 48.6529 9013 FCNT 405 1049 584.239 9013 NCNT 2110 3544 2580.25 9013 RHOB 1.59 3.51 2.37466 8930 DRHO -0.75 0.51 0.0563337 8930 PEF 0.78 8.34 2.4408 8930 First Reading 121 121 121 121 121 121 122 121 7350 7350 7350 7401 7401 7401 Last Reading 11918 11876.5 11849 11849 11849 11849 11918 11849 11856 11856 11856 11865.5 11865.5 11865.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 11918 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NIIMBER: 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 STOP DEPTH FET 121.0 4864.5 RPD 121 . 0 4864 . 5 RPM 121 . 0 4864 . 5 RPS 121 . 0 4864 . 5 RPX 121.0 4864.5 GR 121.0 4855.0 ROP 122 . 0 4904 . 0 $ LOG HEADER DATA DATE LOGGED: 17-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06/INSITE 3.2 DOWNHOLE SOFTWARE VERSION: HCIM/EWP41.38/SLD10.87/PWD2.41 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 4904.0 TOP LOG INTERVAL (FT) : 121.0 BOTTOM LOG INTERVAL (FT) : 4904.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 M31XI~ ANGLE: 60.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY Pl196CGR8 EWR4 ELECTROMAG. RESIS. 4 Pl196CGR8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER' S CASING DEPTH (FT) : 12.3 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD, LSND 10.40 .0 8.5 200 5.1 8.100 7.070 9.000 4.900 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 GR MWD 1 API 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 0 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 26.7 Name Min Max Mean DEPT 121 4904 2512.5 GR 10.41 143.88 78.8505 RPX 0.24 183.12 29.8774 RPS 0.13 2000 36.3743 RPM 0.1 2000 58.1045 RPD 0.05 2000 58.5317 N s am 9567 9469 9488 9488 9488 9488 First Reading 121 121 121 121 121 121 Last Reading 4904 4855 4864.5 4864.5 4864.5 4864.5 ROP 0.26 1710.77 252.077 9565 FET 0.05 5.62 0.360174 9488 122 4904 121 4864.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4904 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 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 4851 5 6149.0 FET 4859 0 6159.0 RPD 4859 0 6159.0 RPM 4859 0 6159.0 RPS 4859 0 6159.0 RPX 4859 0 6159.0 ROP 4904 5 6198.0 $ LOG HEADER DATA DATE LOGGED: 18-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06/INSITE 3.2 DOWN-HOLE SOFTWARE VERSION: HCIM/EWP41.38/SLD10.87/PWD2.41 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6198.0 TOP LOG INTERVAL (FT) : 4904.0 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 P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6198.0 58.4 60.7 TOOL NUMBER Pl196CGR8 Pl196CGR8 12.250 12.3 LSND 10.30 150.0 9.0 250 5.0 5.500 4.560 8.900 2.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 30.6 RPM MWD 2 RPD MWD 2 ROP MWD 2 FET MWD 2 OHMM OHMM FT/H HOUR 1 68 1 68 1 68 1 68 16 20 24 28 Name Min DEPT 4851.5 GR 35.16 RPX 1.77 RPS 1.07 RPM 0.83 RPD 0.77 ROP 0.33 FET 0.08 Max 6198 135.32 78 33 87 19 103 22 170 68 739 71 12 62 Mean Nsam 5524.75 2694 80.6357 2596 11.6393 2601 12.802 2601 13.4281 2601 14.2558 2601 246.211 2588 0.85654 2601 First Reading 4851.5 4851.5 4859 4859 4859 4859 4904.5 4859 Last Reading 6198 6149 6159 6159 6159 6159 6198 6159 First Reading For Entire File .......... 4851.5 Last Reading For Entire File ........... 6198 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6149.5 6266.5 FET 6159.0 6276.0 RPD 6159.0 RPM 6159.0 RPS 6159.0 RPX 6159.0 ROP 6198.5 $ 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: 6276.0 6276.0 6276.0 6276.0 6316.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT T~MPERATURE (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 19-DEC-98 ISC 5.06/INSITE 3.2 HCIM/EWP41.38/SLD10.87/PWD2.41 MEMORY 6316.0 6198.0 6316.0 59.4 61.1 TOOL NI/MBER Pl196CGR8 Pl196CGR8 12.250 12.3 LSND 10.40 140.0 9.0 250 4.6 5.400 4.770 8.600 2.400 26.7 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 API 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min DEPT 6149.5 GR 47.23 RPX 6.96 RPS 7.54 RPM 7.89 RPD 8.9 ROP 0.74 FET 0.39 Max 6316 136 04 44 11 53 38 63 17 62 65 909 55 13 07 Mean Nsam 6232.75 334 95.1251 235 19.1248 235 22.2726 235 24.4321 235 25.3186 235 215.155 236 5.54991 235 First Reading 6149.5 6149.5 6159 6159 6159 6159 6198.5 6159 Last Reading 6316 6266.5 6276 6276 6276 6276 6316 6276 First Reading For Entire File .......... 6149.5 Last Reading For Entire File ........... 6316 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6267 5 6277 0 6277 0 6277 0 6277 0 6277 0 6316 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7363.0 7372.5 7372.5 7372.5 7372.5 7372.5 7412.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MI/D CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 20-DEC-98 ISC 5.06/INSITE 3.2 HCIM/EWP41.38/SLD10.87/PWD2.41 MEMORY 7412.0 6316.0 7412.0 57.7 60.8 TOOL NUMBER Pl196CGR8 Pl196CGR8 12.250 12.3 LSND 10.30 235.0 8.4 250 4.6 5.000 4.305 6.000 34.5 MUD CAKE AT MT: 2.000 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 4 API 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min DEPT 6267.5 GR 57.38 RPX 1.93 RPS 2.06 RPM 2.1 RPD 2.22 ROP 0.55 FET 0.19 Max 7412 153 04 22 99 25 97 27 44 27 31 520 78 11 07 Mean Nsam 6839.75 2290 106.179 2192 5.56596 2192 5.99529 2192 6.09523 2192 6.35442 2192 135.166 2192 0.975753 2192 First Reading 6267.5 6267.5 6277 6277 6277 6277 6316.5 6277 Last Reading 7412 7363 7372.5 7372.5 7372.5 7372.5 7412 7372.5 First Reading For Entire File .......... 6267.5 Last Reading For Entire File ........... 7412 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE ST~LRT DEPTH STOP DEPTH FCNT 7350.0 11856.0 NCNT 7350.0 11856.0 NPHI 7350.0 11856.0 GR 7363.5 11876.5 FET 7373.0 11849.0 RPD 7373.0 11849.0 RPM 7373.0 11849.0 RPS 7373.0 11849.0 RPX 7373.0 11849.0 PEF 7401.0 11865.5 DRHO 7401.0 11865.5 RHOB 7401.0 11865.5 ROP 7412.5 11918.0 $ LOG HEADER DATA DATE LOGGED: 28-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06/INSITE 3.2 DOWNHOLE SOFTWARE VERSION: HCIM/EWP41.38/SLD10.87/PWD2.41 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11918.0 TOP LOG INTERVAL (FT) : 7412.0 BOTTOM LOG INTERVAL (FT) : 11918.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 58.2 MAXIMUM ANGLE: 61.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER Pl199HWRNLGV6 Pl199HWRNLGV6 Pl199HWRNLGV6 Pl199HWRNLGV6 8.500 8.5 LSND 10.40 97.0 8.0 200 3.4 5.100 2.880 7.200 3.000 54.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 RPX MWD 5 OHMM 4 1 68 12 4 RPS MWD 5 OHMM 4 1 68 16 5 RPM MWD 5 OHMM 4 1 68 20 6 RPD MWD 5 OHMM 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 NPHI MWD 5 P.U. 4 1 68 NCNT MWD 5 CNTS 4 1 68 FCNT MWD 5 CNTS 4 1 68 RHOB MWD 5 G/CC 4 1 68 DRHO MWD 5 G/CC 4 1 68 PEF MWD 5 BARN 4 1 68 32 36 40 44 48 52 9 10 11 12 13 14 Name Min Max Mean DEPT 7350 11918 9634 ROP 0 793.06 167.282 GR 17.39 506.71 135.437 RPX 1.03 1873.86 3.62574 RPS 1.08 1440.93 3.861 RPM 0.86 1465.99 4.09801 RPD 0.98 2000 14.1022 FET 0.26 109.51 2.11302 NPHI 18.99 81.6 48.6529 NCNT 2110 3544 2580.25 FCNT 405 1049 584.239 RHOB 1.59 3.51 2.37466 DRHO -0.75 0.51 0.0563337 PEF 0.78 8.34 2.4408 Nsam 9137 9012 9027 8953 8953 8953 8953 8953 9013 9013 9013 8930 8930 8930 First Reading 7350 7412.5 7363.5 7373 7373 7373 7373 7373 7350 7350 7350 7401 7401 7401 Last Reading 11918 11918 11876.5 11849 11849 11849 11849 11849 11856 11856 11856 11865.5 11865.5 11865.5 First Reading For Entire File .......... 7350 Last Reading For Entire File ........... 11918 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/02/11 Origin ................... STS Scientific Technical Services Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
