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Home My WebLink About193-051Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39619 T39620 T39620 T39620 T39621 T39621 T39622 T39623 T39624 T39625 T39626 T39627 T39628 T39629 T39630 T39631 T39632 T39633 T39634 PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.04 15:10:24 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU P1-17 Install new completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-051 50-029-22358-00-00 10532 Conductor Surface Intermediate Production Scab Liner 9244 80 3807 10481 3521 5934 20" 10-3/4" 7-5/8" 4-1/2" 5189 42 - 122 41 - 3848 37 - 10518 5984 - 9505 42 - 122 41 - 3576 37 - 9230 5228 - 8221 9490 470 2090 5120 / 4790 7500 5934 1490 3580 8180 / 6890 8430 9984 - 10344 4-1/2" 12.6# 13Cr80 35 - 5997 8697 - 9057 Structural 4-1/2" HES TNT , 5774 No SSSV 5774 , 5900 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY / PT MCINTYRE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028297 35 - 5238 552 701 31204 16872 2382 5141 2416 2415 1913 1540 324-414 13b. Pools active after work:PT MCINTYRE OIL 4-1/2" Baker SABL-3 , 5900 , 5163 4-1/2" Baker SABL-9 , 9433 , 8151 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:25 pm, Sep 30, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.30 10:38:57 - 08'00' Bo York (1248) WCB 12-2-2024 DSR-10/2/24 RBDMS JSB 100324 ACTIVITYDATE SUMMARY 7/18/2024 T/I/O=BPV/1450/0. Pre RWO. Removed 4" CIW FLS upper tree with SH-3000 actautor. Installed 4" GE temp valve #85 as dryhole tree. Torqued flanges to spec. RU CIW lubricator and "H" pulling tool to tree. Pressure tested temp valve against MV to 300/5000 psi for 5 min. Passed. Pulled 4" "H" BPV #152 @ 85". LTT on MV passed. RD lubricator and installed tree cap. Pressure tested tree cap to 500 psi. Passed.Cycled dryhole valves. ***Job Complete*** Final WHP's 490/1450/0. 7/18/2024 T/I/O=480/1450/0. Pre RWO, Set 4" H BPV #151 @145", BPV LTT Failed. Pulled 4" "H" BPV # 151. Swapped BPV and tooling. Set 4" H BPV #152 @145", BPV LTT. Passed. PT tree cap to 500 psi. Pass. ***Job Complete*** See Log. Final WHP's BPV/1450/0. 8/10/2024 T/I/O = Vac/Vac/Vac - C/B = 600/600 Set CTS BPV with dry rod. close master & swab. RDMO. 8/10/2024 T/I/O = 471/1399/0 Circ-Out (RWO EXPENSE) Pumped 5 bbls of 50/50, 101 bbls of Deep Clean, 292 bbls of 1% KCL, and 359 bbls of 9.8 brine down TBG taking returns up the IA to an open top tank. Getting ~96% returns for the majority of the circ-out (see log. DSO notified upon departure. FWHP = 0/0/3 8/11/2024 T/I/O = BPV/VAC/VAC. Temp = SI. WHPs (pre RWO). Dryhole tree installed. Wellhouse, scafold, and grating removed. SV, MV = C. IA, OA = OTG. 21:30 8/14/2024 Nabors CDR2 - RWO, Stacker Packer over PC Leak Move Rig from 06-18A to P1-17. 0700 - 1700. ***Rig Accepted @ 1700*** Spot up over well. Call out WH Tech Brian. Check Tree, bleed Void in THA. WS Spotted TT and Rigged up Return Iron. Working on RU Checklists. ND Tree/THA and hang off in rear of Cellar. ***Job Continued to 8/15/2024*** 8/15/2024 Bleed off tubing hanger void & (2) 1/4" control lines, nipple down THA/dry hole tree, cut & cap (2) 1/4" control lines, clean void, ring groove, hanger lift threads, & BPV profile, install CTS plug, make up 4-1/2" TC-II pin x IBT pin cross over to tubing hanger lift threads 8-1/2 RH, make up test sub to cross over, test CTS BPV & lift thread connection to 3800 psi/10 min., good test, bleed off & drain test fluid, remove cross over/test sub, function tubing hanger lock down screws one at a time to 4-1/2" clear bowl, all functioned well & re-torqued to 500 ft/lbs, get upper lock down screws RKB (24.03'), RDMO. Daily Report of Well Operations PBU P1-17 Daily Report of Well Operations PBU P1-17 8/15/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer Completion over PC Leak Continued from 8/14/2024... Continue RU Stack. NU Double Stud adapter, 13-5/8" x 11". NU 13-5/8" BOP. MU Koomey Lines to Choke/Kill. Install TT and Return line, PT to 3300 psi. Continue RU Checklists. 24.03' = LDS to Rig Floor. 8.5 turns with landing thread, 4-1/2" TC-II. Test BOPE, 250/3000, Annular 2500, Per Sundry # 324-414. Valve B3, Fail/Grease/Pass. KillLine Flange Tighten/Pass. AOGCC Witness Waived by Bob Noble. ***Job Continued to 8/16/2024*** 8/16/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer Completion over PC Leak Continued from 8/15/2024... Prep Rig to Pull CTS BPV and Pull Hanger to Floor. Flow Check , IA on a Vac. Remove CTS Plug from BPV. Circulate 40 bbls 9.8 ppg Brine through BPV into IA across tubing cut. 7 bbls to get returns. Shut down Flow Check well, Remove BPV. Circulate 1.5 Surface to Surface volumes while prepping McCoy tongs and Power Unit. Thread in landing joint 8.5 turns to hanger. Pull 83k #'s, lift hanger to rig floor. Cap control lines. Begin LD 4.5", 12.6#, 13CR, VAMTop Completion with thread protectors. Spool up dual Control Lines. Recover 55 of 56 SS bands. 1 band broke and fell downhole. Maintain Continuous hole fill. ***Job Continued to 8/17/2024*** 8/16/2024 Pull CTS plug & BPV w/ T-bar, make up 4-1/2" TC-II landing joint 8-1/2 RH, back out lock down screws, pull hanger to floor, cut & cap (2) 1/4" control lines, wrap hanger in foam & tape & lay it down, RDMO. 8/17/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer over PC Leak Continued from 8/16/2024 LD 4-1/2", 12.6#, 13Cr, VAMTop Completion with 1 Bal-O Safety Valve, 2 GLMs and 1 X-Nipple. Load and Tally 3-1/2" Drill Pipe. Load YJ BHA in Pipe Shed. Install FMC 10" Bowl Protector, 9" ID. MU 6-3/4" Burnover Dress-off Mill & 7-5/8" Casing Scraper YJOS BHA. RIH w/ 3-1/2" Workstring. ***Job Continued to 8/18/2024*** Test BOPE,gg 250/3000, Annular 2500, Per Sundry # 324-414 LD 4-1/2", 12.6#, 13Cr, VAMTop Completion with 1 Bal-O Safety Valve, 2 GLMs and 1 X-Nipple gj g g g Begin LD 4.5", 12.6#, 13CR, VAMTop Completion with thread protectors. AOGCC Witness Waived by Bob Noble. y Daily Report of Well Operations PBU P1-17 8/18/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer over PC Leak Continued from 8/17/2024 Continue RIH with YJ Inner-Mill and Casing Scraper Assembly with 6.75" Wash Over Shoe. Screw into Jt. #182 with Top Drive, torque 10k ft/lbs. SO 2k #'s at tubing cut 3 x's with Shoe, 5883'. PUH, Hook load 93k #'s. Rotate 20 RPMs and SO again carefully (71k #'s) and work over the tubing cut at 5883'. Work Dress-Off shoe down 5.5' (5.8' total coverage length of BHA) at 4 bpm pump rate over tubing stump to inner-mill NOGO. Shoe Depth rotated down over stump to 5888.5'. Light dress off based on quality of inspected cut at surface. Free torque 4200 ft/lbs @ 40 RPMs. See Maximum 4900 ft/lbs while dressing over cut stump. No additional pump pressure increase while dressing over stump. Increased to 5 bpm, pump pressure 670 psi. PUH 2 feet above NOGO to Shoe Depth of 5886.5'. Pump 20 bbl HiVis Sweep. After 270 bbls pumped, Rotate off Stump. 93k #'s. Start LD 3-1/2" Drill Pipe. McCoy Tong Safety feature failure. Continue LD with Rig tongs. BD YJOS Dress-off mill & Casing scraper BHA. Clear wear mark indication on mill. MU YJOS AS1-X Test Packer Shallow Test Packer with 20 joints in the Hole. 600 psi. Held 5 minutes, set 4k down on Packer. Continue PU 3-1/2" DP ***Job Continued to 8/19/2024*** 8/19/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer over PC Leak Continued from 8/18/2024 Continue PU 3-1/2" DP with YJ AS1-X RTTS Packer. Shallow Test Packer 20 joints in the Hole, 600 psi, 5 minutes. Continue down to Joint #140, Packer Set @ 4513'. Stack 13k Down. Test to 3100 psi for 30 minutes, 40 psi/5 psi lost. PASS. Continue in hole with RTTS to lowest test depth of ~5850. Set Packer @ 5852' Joint # 182. Charted 30 min pressure test. 3100 psi, 38 psi/11 psi loss. Release packer, POOH. LD 3-1/2" Drill Pipe. Load and Tally 4.5" Completion and Jewelry. ***Job Continued to 8/20/2024*** MU YJOS AS1-X Test Packer Shallow Test Packer with 20 joints in the Hole. Rotate 20 RPMs and SO again carefully (71k #'s) and workgy() over the tubing cut at 5883'. Work Dress-Off shoe down 5.5' (5.8' total coverageg( length of BHA) at 4 bpm pump rate over tubing stump to inner-mill NOGO The known PC leak is at 5892'. -WCB Shallow Test Packer 20 jointsj in the Hole, 600 psi, 5 minutes. Continue down to Joint #140, Packer Set @ 4513'.@ Stack 13k Down. Test to 3100 psi for 30 minutes, 40 psi/5 psi lost. PASS. Continue in hole with RTTS to lowest test depth of ~5850. Set Packer @ 5852' Joint # 182. Charted 30 min pressure test. 3100 psi, 38 psi/11@ psi loss. Release packer, POOH Daily Report of Well Operations PBU P1-17 8/20/2024 Nabors CDR 2 - RWO, P1-17, Run 4-1/2" Gas-Lifted Completion Continued from 8/19/2024 Finish Strap and Tally of 4-1/2" Completion. Tubing Tally approved by OE. RIH w/ 4- 1/2", 12.6#, 13CR, VamTop Gas-Lifted Completion. Tag with OS Completion on depth at 5886'. Grapple is Set. PUH 20k over to confirm. PU in 5k# Hookload Increments to Shear off screws at 165k #'s hook load. Observe good seal drag in polished bore. Unsting, confirm free from Scoop Guide, good circulation. Stack back down, Tag bottom to mark Joint on Floor. Unsting to Pump 9.8 ppg Brine with Conqor 303a. Reverse in 175 bbls 9.8 ppg Inhibited Brine down IA. ***Job Continued to 8/21/2024 *** 8/21/2024 RWO Completion, PPPOT-T (PASS) Inspect tools and equipment. Stage tools in cellar, S/B for rig to circulate. M/U TBG HGR to string. RIH, land at verified RKB measurement, verify landed through IA valve. RILDS and torque to 450 ft lbs. S/B for rig to test and set packer. Set 4" CTS H BPV. S/B for BOP N/D. Clean void, inspect TBG HGR neck and lift threads. Press in SBMS, install CTS plug and new RX-54. N/U tree. Test void to 500 psi, no loss, test to 5000 psi for 30 min., 200 psi loss first 15 mins, 0 psi loss second 15 mins. Pass. Assist rig w/ tree test. Pass. Pull CTS plug, Pull 4" CTS H BPV. 8/21/2024 IA= 157 Psi (RWO EXPENSE) Pumped 110 bbls of DSL down IA Well left in rigs controll, DSO notified upon departure Finle IA= 523 8/21/2024 Nabors CDR 2 - RWO, P1-17, Stacker Packer Completion. ...Continued from 8/20/2024... Pump 175 bbls Inhibited 9.8 ppg Brine down IA. MU Hanger and Landing Joint. Sting In with Seal Assembly and Land Hanger. RILDS, torque to 450 ft/lbs. PT seals to 500 psi / 10 minutes. Drop Ball and Rod. 1-5/16", 6.8', 1.375" FN. Set HES TNT Packer @ 5773'. MIT-T 3370 psi Lost 28 / 8 psi. Pass. MIT-IA 3230 psi Lost 40 / 15 psi. Pass. Open Shear Valve in upper GLM at 3921'. Set CTS BPV. ND BOPE. NU THA & Tree Pressure test to 5000 psi for 30 min. Pass. Pull BPV. Pump 130 bbls diesel down IA and U-Tube to TBG for 1 hour. *** Job Complete*** 8/22/2024 T/I/O=0/0/0.Post RWO. (CDR2) RD 4" temp valve and RU 4" CIW upper tree with SH- 3000 actuator. Torqued lfnages to spec. Pressure tested upper tree against MV to 300/5000 psi. Pass. Connect flowlines and set wellhouse. (also wellhouse 16 and 18. ***Job Complete*** Final WHP's 0/0/0. 8/23/2024 T/I/O= 441/439/0 MIT T ( Post RWO ) ***Job Continued 8/24/24*** MU Hanger andgg Landing Joint. Sting In with Seal Assembly and Land Hanger. RILDS, torque to 450gg y g ft/lbs. PT seals to 500 psi / 10 minutes. Drop Ball and Rod. 1-5/16", 6.8', 1.375" FN. Set HES TNT Packer @ 5773'. MIT-T 3370 psi Lost 28 / 8 psi. Pass. MIT-IA@ 3230 psi Lost 40 / 15 psi. Pass. M/U TBGgg HGR to string. RIH, land at verified RKB measurement, verify landed through IAg valve. RILDS and torque to 450 ft lbs Daily Report of Well Operations PBU P1-17 8/23/2024 *** WELL S/I ON ARRIVAL *** PULL BALL & ROD FROM RHC BODY@ 5806' MD ***WSR CONT ON 8-24-24*** 8/24/2024 ***WSR CONT FROM 8-23-24*** PULLED ST#2 BK-SHEAR VLV FROM 3925' MD SET ST#2 BK-LGLV (16/64'' ports, 2000#psi) @ 3925' MD LRS PERFORMED PASSING MIT-T (see lrs log) PULLED BK-DMYGLV FROM STA #1 @ 5700' MD SET BK-OGLV ( 22/64" ) IN STA # 1 @ 5700' MD PULLED RHC FROM X NIP @ 5805' MD PULLED JUNK CATCHER FROM 5908' SLM PULLED PRONG FROM PLUG BODY @ 5934' MD PULLED PLUG BODY FROM X NIP @ 5934' MD *** WELL S/I ON DEPARTURE *** 8/24/2024 ***Job Continued from 8-23-24*** (RWO EXPENSE) MIT-T. (PASSED) Pumped .5 bbls down TBG to reach max applied pressure 3215 Psi. 15 min Loss- 98 Psi. 30 min Loss- 33 Psi. Bleed back .5 bbls. FWHP=858/754/0 9/4/2024 LRS CTU #2 / 2.0" Tapered CS (0.134" wall) Blue Coil. Job Scope: Cement PC Leak Through NCS Sleeve MIRU LRS CTU2 & support equipment. Function test BOPE. M/U Baker MHA w/3.80" WS drift and RIH to 6500'. POOH. BD Whipstock Drift. MU NCS Pkr / sleeve shifting tools. Kill Well. RIH. Test Pkr @ 1870'. RIH locate Sleeve @ 5827' md. Set Pkr and open sleeve. Perform Inj Test (see log). Spot PowerVis on backside and diesel. Pump 5 bbls FW + 18.5 bbls 13 ppg FineCem + 7 bbls 15.8 ppg Class G + 5 bbls FW + 42.6 slick 2% KCL (left 1/2 bbl 15.8 ppg in CT) (all behind sleeve except 1/2 bbl 15.8 ppg). Close Sleeve @ 32.5k up wgt. RIH to 5850', PUH 10' reset Pkr, RIH 5845' set Pkr, Reverse out. POOH. FP well w. 40 bbls. Pump 10bbls gel and 2x coil volume 2% KCL through coil w/ 1.25" drift ball. Ball recovered. RDMO ***Man Down Drill / Power Pack stops running drill *** ***Job Complete*** 9/7/2024 ***WELL S/I ON ARRIVAL*** (RWO expense) RAN 4-1/2" BRUSH & 3.70" G. RING TO 6,500' SLM RAN 1.90" CENT & 20' x 1.75" DRIVE DOWN BAILER TO 6,000' SLM T-BIRD LOADED TBG W/ 200 BBLS CRUDE SET 4-1/2" PX PLUG AT 5,934' MD T-BIRD PERFORMED PASSING MIT-T TO 3129 psi RAN HES CBL PER PROGRAM (good data) ***CONTINUE ON 9/8/24 WSR*** RIH locate Sleeve @ 5827' md. Setg@@ Pkr and open sleeve. Perform Inj Test (see log). Spot PowerVis on backside andj(g) diesel. Pump 5 bbls FW + 18.5 bbls 13 ppg FineCem + 7 bbls 15.8 ppg Class G + 5gg bbls FW + 42.6 slick 2% KCL (left 1/2 bbl 15.8 ppg in CT) (all behind sleeve except 1/2 bbl 15.8 ppg). Daily Report of Well Operations PBU P1-17 9/7/2024 T/I/O=2544/0/0 Temp=S/I (Assist Slickline with Load & Test) Pumped 200 bbls Crude down TBG for load. Pumped 18.6 BBLS of Crude while attemping to Reach a passing MIT-T. Last Test ***PASSED*** pumped 3 BBLS of Crude to reach a MAP of 3300 psi on the TBG. 1st 15 min TBG lost 117 psi 2nd 15 min TBG lost 54 psi for a total loss of 171 psi in 30 min test. Slickline in control of Well upon Departure. FWHP=250/0/0 MIT-T Results hung on Master Valve. 9/8/2024 ***WELL S/I ON ARRIVAL*** (RWO expense) RAN 4-1/2" BRUSH & 3.80" G. RING TO X-NIP AT 5,934' MD SET 4-1/2" PX PLUG AT 5,934' MD T-BIRD PERFORMED PASSING MIT-T TO 3166 psi PULLED 4-1/2" PX PLUG AT 5,934' MD ***WELL S/I ON DEPARTURE*** 9/8/2024 ***CONTINUED FROM 9/7/24 WSR*** (RWO expense) PULLED 4-1/2" PX PLUG AT 5,934' MD ***WELL S/I ON DEPARTURE*** 9/8/2024 T/I/O=1656/0/0 Temp=S/I Assist slickline. MIT T PASSED to 3166 psi (RWO Expense) Bullhead 200 bbls crude down tubing. SL set TTP. Pumped a total of 4.8 BBLS crude to achieve test pressure of 3295 psi. T lost 98 psi 1st 15 mins and lost 31 psi 2nd 15 mins for a total loss of 129 psi in 30 mins. This Test was recorded. FWHP=600/0/0 Reach a passing MIT-T. Last Test ***PASSED*** CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240725 1633 Sundry 324-414 PTD 193-051 Install New Completion - Question on stacker packer P1-17 Date:Friday, July 26, 2024 9:47:31 AM Attachments:image001.png From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Thursday, July 25, 2024 4:33 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] Sundry 324-414 PTD 193-051 Install New Completion - Question on stacker packer P1-17 Mel, Per our phone discussion, we will plan to have coil squeeze 20bbl of cement behind the 7-5/8” casing through the leak (step 30 in the sundry program). I calculated the open hole capacity between the 7-5/8” casing and the 9-7/8” hole at 0.0383 bbl/ft. 400’ of cement in that capacity is 15.3bbl. Please let me know if this is acceptable. Thank you, Eric From: Eric Dickerman Sent: Thursday, July 25, 2024 1:42 PM To: 'Rixse, Melvin G (OGC)' <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] Sundry 324-414 PTD 193-051 Install New Completion - Question on stacker packer P1-17 Mel, After reviewing with the team, the minimum pressure required to fracture the overburden at the leak depth (5,157’ TVD) is greater than the shut in pressures measured in P1-17. This is detailed in the charts below. Data from a pressure survey ran in the well on 7-2-2021 measured actual “shut in, stacked out” conditions. The pressure at 5,157’ TVD is 3,347 psi from the pressure survey. From pore pressure fracture gradient data for the Pt McIntyre area, the minimum sand frac pressure at the leak is 3,374 psi and the most likely sand frac pressure at the leak is 3,486 psi The assumption made for the minimum sand frac pressure uses an equivalent mud weight at 5,157’ TVD of 8.35 ppg which is less than the 9.3 ppg EMW that was measured at the P1-17 leak. If 9.3 ppg is used for pore pressure, then the minimum sand frac pressure would come out to 3,520 psi. The calculated highest possible cement top behind the 7-5/8” production casing is ~7,472’. Squeezing cement into the leak could help prevent the potential of gas migration. Thank you, Eric Dickerman Hilcorp – LPC OE Cell: 307-250-4013 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, July 18, 2024 11:00 AM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] Sundry 324-414 PTD 193-051 Install New Completion - Question on stacker packer P1-17 Eric, Please provide assurance that Pt. McIntyre reservoir gas at ~3800 psi ~8850’ TVD would be assured not to fracture the overburden at the IC leak at 5892’ MD ~5140’ TVD. The completion you are proposing would provide a single barrier to the overburden with an unmonitorable annulus below the new production packer. My assumption of .65 psi/ft fracture gradient would put fracture pressure of the overburden at 5140’ TVD (*0.65) = 3341 psi. With the wellbore full of gas in ‘shut-in’ would put pressure on the tubing at the IC leak at ~3429 psi which is ~90 psi above fracture gradient. Also, is there cement external to the 7-5/8” casing above the IC leak at 5892’ MD. If not, could gas migrate to even shallow zones in the overburden if the single tubing barrier were to fail below the new proposed production packer? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Steve Davies, Andy Dewhurst The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email ortelephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P1-17 Install new completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-051 50-029-22358-00-00 ADL 028297 10532 Conductor Surface Intermediate Production Scab Liner 9244 80 3807 10481 3521 5934 20" 10-3/4" 7-5/8" 4-1/2" 5189 42 - 122 41 - 3848 37 - 10518 5984 - 9505 2914 42 - 122 41 - 3576 37 - 9230 5228 - 8221 9490 470 2090 5120 / 4790 7500 5934 1490 3580 8180 / 6890 8430 9984 - 10344 4-1/2" 12.6# 13Cr80 35 - 59978697 - 9057 Structural 4-1/2" Baker SABL-3 No SSSV 5900 / 5163 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 8-1-2024 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.17 15:00:30 - 08'00' Bo York (1248) 324-414 By Grace Christianson at 4:45 pm, Jul 17, 2024 * BOPE test to 3000 psi. Annular to 2500 psi. * Step 30 in program changed to squeeze 20 bbl of cement behind 7-5/8" casing. * Biennial MIT-T to 3000 psi. -Charted. A.Dewhurst 23JUL24 2914 DSR-7/17/24MGR25JUL24 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.26 09:27:21 -08'00'07/26/24 RBDMS JSB 073024 RWO Rev1 07-12-2024 P1-17 PTD:193-051 Well Name:P1-17 API Number:50-029-22358-00 Current Status:Shut-In – Non-Operable Rig:CDR2 Estimated Start Date:Aug 2024 Estimated Duration:7days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:193051 First Call Engineer:Eric Dickerman Contact:307-250-4013 Current Bottom Hole Pressure (perfs):3,799 psi @ 8,850’ TVD 8.26 PPGE | SBHP 7/2/21 Current Bottom Hole Pressure (leak):2,472 psi @ 5,157’ TVD/5,892’ MD 9.3 PPGE Max. Anticipated Surface Pressure:2,914 psi (0.1 psi/ft. gas gradient to surface) Last SI WHP:2,600 psi (Slickline RU on 2/17/23) Min ID:3.725” @ 9,483’ MD (SWN nipple) Max Angle:41.1 deg @ 4,066’ MD Brief Well Summary: P1-17 is a Kuparuk producer in the Point McIntrye field. The well’s GOR has been increasing towards uncompetitiveness and a coiled tubing drilling sidetrack target has been identified. During pre-rig sidetrack wellwork, a leak in the 7-5/8” production casing was identified at 5,892’md with a failing CMIT-TxIA and a leak detection log. In 2007, a RWO was performed to fix a production casing leak between 7400-7500’ with a 4-1/2” cemented scab liner. Objective: Cut and pull the existing 4-1/2” tubing. Test the 7-5/8” casing to determine new production packer set depth. Run a 4-1/2” gas lifted, stack packer completion, to straddle production casing leak. Achieve a passing MIT-IA & MIT-T. Well Completion Information: PPPOT-T: Passed 5,000 psi 5/21/23 PPPOT-IC: Passed 3,500 psi 5/21/23 MIT-T: Passed 3,500 psi 2/18/23. PX plug still in place. MIT-IA: Failed 2/18/23 – liquid leak rate 1bpm at 1,342 psi. MIT-OA: Passed 1,000 psi 8/15/07. OA downsqueezed 8/9/2003. Present Completion Program: Pipe #/ft Grade Connection Top Bottom 10-3/4”45.5 J-55 BTC Surface 3,846’ 7-5/8”29.7 13Cr-80 NSCC 9,424’10,517’ 7-5/8”29.7 NT-95 NSCC Surface 9,242’ 4-1/2” scab 12.6 13Cr-80 VamTop 5,984’9,505’ 4-1/2” tubing 12.6 13Cr-80 VamTop Surface 5,997’ RWO Rev1 07-12-2024 P1-17 PTD:193-051 Pre RWO work: Wellhead:DONE 5/21/23 1. PPPOT-T to 5000 psi. Function all LDS. PPPOT-IC to 3500 psi. Function all LDS. E-line/Fullbore:DONE9/17/23under 10-403 #323-317 2. Cut tubing ~5,883’ MD. 3. Circulate well to 9.8 ppg brine + freeze protect. DHD: 4. Bleed WHP to 0 psi. Valve Shop: 5. Set and test TWC. 6. Nipple down tree and tubing head adaptor. 7. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross, 13-5/8” x 11” adapter. Proposed RWO Procedure: 8. MIRU CDR2. 9. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5” VBRs with 3-1/2” and 4-1/2” test joints. e. Test the annular with 3-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 10. Pull TWC. RU lubricator if pressure is expected. Maintain overbalance with 9.8ppg KWF during operation. 11. PU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up. Lay down existing 4-1/2” 13Cr VamTop tubing to the cut. g. Expected PU weightin 9.8ppg = 63k #. h. 2023 Caliper recorded no significant areas of cross-sectional metal loss. 12. PU 3-1/2” workstring and dress off BHA then wash over the 4-1/2” stub. 13. RIH with 7-5/8” RTTS and set at ~5,850’. Test from above to 3,000psi and chart for 30min. i. If test passes, POOH laying down workstring. j. If test fails, PUH two joints, and re-test. Repeat as necessary until a passing test is achieved. i. STOP POINT: If test does not pass with RTTS at 4,500’, the well should be fixed with a 5- 1/2” tieback at a later date. Lay down the workstring, run a kill string, and RDMO. 14. Run 4-1/2”, 13Cr, VamTop tubing to straddle PC leak with stacker packer completion that includes both a cementing sleeve and a sealing overshot below the new production packer. Production packer depth will be determined from RTTS trip. 15. Reverse in corrosion inhibited 9.8 ppg NaCl. 16. Land Hanger. Pressure test overshot seals. Drop ball and rod then set packer. 17. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. a. IA envelope is 7-5/8” production casing, 7-5/8” x 4-1/2” production packer, 4-1/2” production tubing, and wellhead seals. 18. Set TWC. Ensure well is freeze protected. RWO Rev1 07-12-2024 P1-17 PTD:193-051 19. Rig down CDR2. Post rig valve shop work 20. ND BOPE. 21. NU tree and tubing head adapter. 22. Test both tree and tubing hanger void to 500psi low/5,000psi high. 23. Pull TWC. Post rig Slickline Work 24. Pull ball and rod and RHC profile. 25. MIT-T to 3,000 psi. 26. Pull PX plug from 5,934’ MD. 27. RDMO & POP well for no more than 14 days to allow thermal stabilization. Post rig Coil Work 28. MIRU service coil, after well has been online and completion has thermally stabilized. 29. RIH and open cementing sleeve. 30. Pump 10bbl of 15.8 ppg cement through the sleeve in to the 7-5/8” production casing leak at 5,892’. a. Note on CO736. The well will have a new inner annulus after setting the production packer in Step #16 and pressure integrity will have been verified with a passing MIT-IA after setting the new production packer in Step #17. At that point, the production casing leak at 5,892’ will be below the new production packer, behind the straddle made by the tubing tail and sealing overshot. Cementing the straddle is to reduce the possibility of future external corrosion on the 4-1/2” straddle. The cement is not intended for pressure integrity. Because the cement is not repairing the inner annulus, CO736 is not applicable. 31. Close cementing sleeve. 32. Pressure test against closed sleeve to 500 psi. Post rig Slickline Work 33. Set PX plug at 5,934’. 34. MIT-T to 3,000 psi. 35. Log CBL from 5,900’ up to bottom GLM. 36. Pull PX plug. 37. Set kick off gas lift design. 38. RDMO and return well to production. Well Integrity 39. Update database to include biennial MIT-T to 3,000psi. 20 bbls of 15.3 ppg cement squeeze. - mgr RWO Rev1 07-12-2024 P1-17 PTD:193-051 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO Rev1 07-12-2024 P1-17 PTD:193-051 WellboreSchematic RWO Rev1 07-12-2024 P1-17 PTD:193-051 Proposed Wellbore Schematic RWO Rev1 07-12-2024 P1-17 PTD:193-051 RWO BOPs RWO Rev1 07-12-2024 P1-17 PTD:193-051 Changes to Approved Sundry Procedure Date: 7/12/24 Subject: P1-17 workover to restore well integrity Sundry #: 323-317 Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) 7/12/24 Updated program to reflect rig change from Thunderbird to CDR2.EPD EPD Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU P1-17 Cut Tbg Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-051 50-029-22358-00-00 10532 Conductor Surface Intermediate Production Scab Liner 9244 80 3807 10481 3521 5934 20" 10-3/4" 7-5/8" 4-1/2" 5189 42 - 122 41 - 3848 37 - 10518 5984 - 9505 42 - 122 41 - 3576 37 - 9230 5228 - 8221 9490 470 2090 5120 / 4790 7500 5934 1490 3580 8180 / 6890 8430 9984 - 10344 4-1/2" 12.6# 13Cr80 35 - 5997 8697 - 9057 Structural 4-1/2" Baker SABL-3 No SSSV 5900 5163 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY / PT MCINTYRE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028297 35 - 5238 0 0 0 0 0 0 0 0 0 0 323-317 13b. Pools active after work:PT MCINTYRE OIL 5900 / 5163 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:40 pm, Jul 16, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.16 13:49:03 - 08'00' Bo York (1248) DSR-7/16/24 RBDMS JSB 071924 WCB 11-7-2024 ACTIVITYDATE SUMMARY 5/21/2023 T/I/O = SI/450/0 PPPOT-T (pass) PPPOT-IC (pass) PPPOT-T Sting tubing hanger test port 2000 psi (gas), bled to 0, monitor for 10 min 0 psi. Function all LDS & re-torque to 450 ft lbs., all were a bit tight. Out = 4-3/4". Pump hydraulic fluid across void & test at 5000 psi for 30 min, 50 psi loss after first 15 min 0 psi loss after second 15 min. Sting SBMS port 900 psi bled to 0 psi & remained at 0 psi thought the packoff tests. PPPOT-IC Sting IC upper test port 0 psi, test at 3500 psi for 30 min with no pressure loss. Sting lower test port 0 psi, pump hydraulic fluid across void & stabilize pressure at 3500 psi. Test for 30 min with no pressure loss. Did not function LDS 9/17/2023 *** WELL SI ON ARRIVAL *** INTIAL T/I/O = 1250/400/0 DROP 3.79" JUNK CATCHER w/4.5" G FN FROM SURFACE TO PLUG AT 5934 FT, RUN 3-1/8" CCL TO CHASE AND TAG. TAGGED AT 5918' WELLTEC CUTTER CCL - CUT = 18.3 FT, CCL STOP = 5864.7 FT, CUT DEPTH = 5883.0 FT ELM. OBSERVED WHP CHANGE DURING CUT. WELLTEC REPORTS GOOD INDICATION. ELINE COMPLETE. FINAL T/I/O = 450/425/0 *** WELL SI ON DEPARTURE *** 7/16/2024 AOGCC request close out Sundry 323-317 dated 09/14/23 and submit a new 10-403 request to document RWO change from Thunderbird to CDR-2. Daily Report of Well Operations PBU P1-17 WELLTEC CUTTER CCL - CUT = 18.3 FT, CCL STOP = 5864.7 FT, CUT DEPTH = 5883.0 FT ELM. OBSERVED WHP CHANGE DURING CUT. WELLTEC REPORTS GOOD INDICATION. ELINE COMPLETE. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P1-17 Install new completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-051 50-029-22358-00-00 ADL 028297 10532 Conductor Surface Intermediate Production Scab Liner 9244 80 3807 10481 3521 5934 20" 10-3/4" 7-5/8" 4-1/2" 5189 42 - 122 41 - 3848 37 - 10518 5984 - 9505 2914 42 - 122 41 - 3576 37 - 9230 5228 - 8221 9490 470 2090 5120 / 4790 7500 5934 1490 3580 8180 / 6890 8430 9984 - 10344 4-1/2" 12.6# 13Cr80 35 - 59978697 - 9057 Structural 4-1/2" Baker SABL-3 No SSSV 5900 / 5163 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 7-1-2023 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:49 am, Jun 08, 2023 323-317 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.06.07 14:22:08 -08'00' DSR-6/12/23MDG 6/9/2023 2914 * BOPE pressure test to 3000 psi. Annular to 2500 psi. CONDITIONS OF APPROVAL * CBL after cementing through cementing sleeve. * Biennial MIT-T to 3000 psi to 5934' MD. * Pressure test of tubing overshot seals to 3000 psi. * Maximum 14 days of POP prior to cementing isolated annulus. * Pressure test of tubing to 3000 psi to 5934' MD to assure confined annulus integrity 10-407 MGR14SEP23*&:JLC 9/14/2023 09/14/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.14 15:18:40 -05'00' RBDMS JSB 091423 10-404 MDG 9/14/2023 RWO P1-17 PTD:193051 Well Name:P1-17 API Number:50-029-22358-00 Current Status:Shut-In – Non-Operable Rig:Thunderbird Estimated Start Date:July 2023 Estimated Duration:7days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:193051 First Call Engineer:Eric Dickerman Contact:307-250-4013 Current Bottom Hole Pressure (perfs):3,799 psi @ 8,850’ TVD 8.26 PPGE | SBHP 7/2/21 Current Bottom Hole Pressure (leak):2,472 psi @ 5,157’ TVD/5,892’ MD 9.3 PPGE Max. Anticipated Surface Pressure:2,914 psi (0.1 psi/ft. gas gradient to surface) Last SI WHP:2,600 psi (Slickline RU on 2/17/23) Min ID:3.725” @ 9,483’ MD (SWN nipple) Max Angle:41.1 deg @ 4,066’ MD Brief Well Summary: P1-17 is a Kuparuk producer in the Point MacIntrye field. The well’s GOR has been increasing towards uncompetitiveness and a coiled tubing drilling sidetrack target has been identified. During pre-rig sidetrack wellwork, a leak in the 7-5/8” production casing was identified at 5,892’md with a failing CMIT-TxIA and a leak detection log. In 2007, a RWO was performed to fix a production casing leak between 7400-7500’ with a 4-1/2” cemented scab liner. Objective: Cut and pull the existing 4-1/2” tubing. Test the 7-5/8” casing to determine new production packer set depth. Run a 4-1/2” gas lifted, stack packer completion, to straddle production casing leak. Achieve a passing MIT-IA & MIT-T. Well Completion Information: PPPOT-T: Passed 5,000 psi 5/21/23 PPPOT-IC: Passed 3,500 psi 5/21/23 MIT-T: Passed 3,500 psi 2/18/23. PX plug still in place. MIT-IA: Failed 2/18/23 – liquid leak rate 1bpm at 1,342 psi. MIT-OA: Passed 1,000 psi 8/15/07. OA downsqueezed 8/9/2003. Present Completion Program: Pipe #/ft Grade Connection Top Bottom 10-3/4”45.5 J-55 BTC Surface 3,846’ 7-5/8”29.7 13Cr-80 NSCC 9,424’10,517’ 7-5/8”29.7 NT-95 NSCC Surface 9,242’ 4-1/2” scab 12.6 13Cr-80 VamTop 5,984’9,505’ 4-1/2” tubing 12.6 13Cr-80 VamTop Surface 5,997’ 5,157’ T RWO P1-17 PTD:193051 Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi. Function all LDS. PPPOT-IC to 3500 psi. Function all LDS.DONE 5/21/23 E-line/Fullbore: 2. Cut tubing ~5,883’ MD. 3. Circulate well to 9.8 ppg brine + freeze protect. DHD: 4. Bleed WHP to 0 psi. Valve Shop: 5. Set and test TWC. 6. Nipple down tree and tubing head adaptor. 7. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross, 13-5/8” x 11” adapter. Proposed RWO Procedure: 8. MIRU Thunderbird #1 Rig. 9. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5” VBRs with 2-7/8” and 4-1/2” test joints. e. Test the annular with 2-7/8” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 10. Pull TWC. RU lubricator if pressure is expected. Maintain overbalance with 9.8ppg KWF during operation. 11. PU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up. Lay down existing 4-1/2” 13Cr VamTop tubing to the cut. g. Expected PU weight in 9.8ppg = 63k #. h. 2023 Caliper recorded no significant areas of cross-sectional metal loss. 12. PU workstring and dress off BHA then wash over the 4-1/2” stub. Stand back workstring. 13. RIH with7-5/8” RTTS and set at ~5,850’. Test from above to 3,000psi and chart for 30min. i. If test passes, POOH laying down workstring. j. If test fails, PUH two joints, and re-test. Repeat as necessary until a passing test is achieved. i. STOP POINT: If test does not pass with RTTS at 4,500’, the well should be fixed with a 5- 1/2” tieback at a later date. Lay down the workstring, run a kill string, and RDMO. 14. Run 4-1/2”, 13Cr, VamTop tubing to straddle PC leak with stacker packer completion that includes both a cementing sleeve and a sealing overshot below the new production packer. Production packer depth will be determined from RTTS trip. 15. Reverse in corrosion inhibited 9.8 ppg NaCl. 16. Land Hanger. Pressure test overshot seals. Drop ball and rod then set packer. 17. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. a. IA envelope is 7-5/8” production casing, 7-5/8” x 4-1/2” production packer, 4-1/2” production tubing, and wellhead seals. 18. Set TWC. Ensure well is freeze protected. If test fails contact AOGCC for an approved depth. -mgr RWO P1-17 PTD:193051 19. Rig down Thunderbird #1. Post rig valve shop work 20. ND BOPE. 21. NU tree and tubing head adapter. 22. Test both tree and tubing hanger void to 500psi low/5,000psi high. 23. Pull TWC. Post rig Slickline Work 24. Pull ball and rod and RHC profile. 25. Set kick off gas lift design. 26. Pull PX plug from 5,934’ MD. 27. RDMO & POP well to allow thermal stabilization. Post rig Coil Work 28. MIRU service coil, after well has been online and completion has thermally stabilized. 29. RIH and open cementing sleeve. 30. Pump 10bbl of 15.8 ppg cement through the sleeve in to the 7-5/8” production casing leak at 5,892’. a. Note on CO736. The well will have a new inner annulus after setting the production packer in Step #16 and pressure integrity will have been verified with a passing MIT-IA after setting the new production packer in Step #17. At that point, the production casing leak at 5,892’ will be below the new production packer, behind the straddle made by the tubing tail and sealing overshot. Cementing the straddle is to reduce the possibility of future external corrosion on the 4-1/2” straddle. The cement is not intended for pressure integrity. Because the cement is not repairing the inner annulus, CO736 is not applicable. 31. Close cementing sleeve. 32. Pressure test against closed sleeve. 33. RDMO and return well to production. Approved to POP for no more than 14 days. -mgr MIT-T to 3000 psi. -mgr Post rig Slickline Work Set PX plug at 5934' MD. MIT-T to 3000 psi. Log CBL from 5900' MD to bottom GLM. Pull PX plug Run gas lift design RWO P1-17 PTD:193051 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO P1-17 PTD:193051 Wellbore Schematic RWO P1-17 PTD:193051 Proposed Wellbore Schematic RWO P1-17 PTD:193051 RWO BOPs VBRs Blinds RWO P1-17 PTD:193051 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Joseph Lastufka To:Guhl, Meredith D (OGC); Abbie Barker; Carrie Janowski Cc:Christianson, Grace K (OGC); McLellan, Bryan J (OGC); Roby, David S (OGC); Eric Dickerman Subject:RE: [EXTERNAL] Completed Sundry 323-317 Date:Thursday, September 14, 2023 3:44:49 PM Attachments:image001.png Meredith, Thanks for clarifying, and I appreciate that we could combine both sundries. However, in this case the plan is to repair the well and once the workover is completed to produce at least a couple of months before determining when the sidetrack will be started. More than likely this wouldn’t happen until early 2024 (plug for redrill sundry #323-066 expires in February so we’ll either have to start the work under #323-066 or it will expire and a new sundry will need to be submitted). Under this current plan I’d imagine it best to submit the 10-404 for sundry #323-317 once the workover is done. Please let me know if you have any questions or if it is preferred to wait for the plug for redrill work to be completed and combine both sundries. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, September 14, 2023 3:02 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com> Cc: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] Completed Sundry 323-317 Hello Joe and Abbie, There is an outstanding sundry, 323-066, for this well, for plug for redrill. If Hilcorp plans to do the repair in sundry 323-317, then immediately or within a short period of time, plug for redrill, then a 10-407 is appropriate to cover both sundries. If Hilcorp is no longer planning the plug for redrill, or there’s going to be a large gap of time between the work described in 323-317 and the plug for redrill, then a 404 is appropriate to close out 323-317. Please respond with the current plan for this well so the record is clear, and we will update if a 10-404 is the form due for 323-317. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Thursday, September 14, 2023 1:55 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: FW: [EXTERNAL] Completed Sundry 323-317 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Please answer their question, Thank you. ~Grace From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, September 14, 2023 1:43 PM To: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] Completed Sundry 323-317 Hi Grace, Here is what Joe was talking about specifically. Normally this work would only require a 10-404 not a 10-407. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Thursday, September 14, 2023 1:40 PM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] Completed Sundry 323-317 The form you sent was a 10-403 for PBU P1-17. Can you expand on your question? Thank you, Grace Christianson Executive Assistant From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Thursday, September 14, 2023 1:30 PM To: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>; Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] Completed Sundry 323-317 Grace, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Could you please confirm that the subsequent form is a 10-407? I believe it should be a 10-404. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Thursday, September 14, 2023 1:00 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed Sundry 323-317 Hello, Attached is the completed Sundry for PBU P1-17. Thank you, Grace Christianson Executive Assistant AOGCC (907) 793-1230 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2.1.2023 By Samantha Carlisle at 1:05 pm, Feb 01, 2023 323-066 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.02.01 12:24:29 -09'00' Monty M Myers DLB 02/09/2023 10-407X DSR-2/1/23MGR09FEB23 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate abandonment plug. GCW 02/10/23 JLC 2/10/2023 2/10/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 13:30:54 -09'00' RBDMS JSB 021423 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: February 1, 2023 Re: PBU P1-17 Sundry Request Sundry approval is requested to set a whipstock in P1-17, as part of the pre-rig for drilling and completing of the proposed P1-17A CTD lateral. Proposed plan for P1-17A Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, MIT-IA, and Caliper log. E-line will then mill the SWN-nipple and set a 4-1/2"x7-5/8" whipstock. See P1-17A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x7-5/8" whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling and land in the Kuparuk sands. The lateral will continue in the Kuparuk to TD. Run open hole Density/Neutron logs after reaching TD and prior to running liner. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start end of February 2023): 1. Slickline: Dummy WS drift and caliper log a. Drift and log past whipstock setting location 2. Fullbore: MIT-IA to 3,200 psi 3. E-line: Set 4-1/2”x7-5/8” whipstock and mill nipple a. Mill the SWN nipple to 3.80” at 9,483’ MD (if needed mill with service coil) b. Top of whipstock set at 10,053’ MD c. Oriented at 95° ROHS d. Top of window (whipstock pinch point 7’ down from top) at 10,060’ MD 4. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU P1-17A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 3,000 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Set Whipstock (only if not done pre-rig) 3. Mill Window 4. Drill Build and Lateral 5. Run Open Hole Density/Neutron Logs 6. Run and Cement Liner* 7. Perforate (only if not done post-rig) 8. Freeze Protect and RDMO 9. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Sundry 323-066 PTD 223-007 Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU P1-17 (PTD 193-051) Production Profile 09/27/2021 Report 09/29/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/20/2021 By Abby Bell at 2:36 pm, Oct 20, 2021 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, ~s~ l~l Q;~ i~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, bP ,, 4s . x ~; Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) r Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-OSA 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7!6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 . Page 1 of2 . Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 24,20072:17 PM To: 'Reem, David C' Subject: RE: P1-17 Workover \C\~-05\ Thanks for the compliment. I have run into a few workover snakes in my prior working life. Seems in this "new" job that I get to share snakes when others encounter them. Never did like snakes of any type. Tom From: Reem, David C [mailto:ReemDC@BP.com] sent: Monday, September 24,20072:13 PM To: Maunder, Thomas E (DOA) Subject: RE: Pl-17 Workover I think you hit the proverbial nail on the head and your comments were nearly verbatim to ours as the events were taking place....must be some of that fine historical workover savvy bubbling up to surface! ---"--~--------- ------,.-----.-----. From: Maunder, Thomas E (DCA) [mailto:tom.maunder@alaska.gov] sent: Monday, September 24,20071:53 PM To: Reem, David C Subject: RE: Pl-17 Workover Thanks Dave. Still interesting what was encountered. I think the shallow depth of the packer and nipple for the ball-rod didn't help since it is likely that the fluid column below still kept going south once the ball-rod seated. Once the high volume loss was shut off at the new packer depth, fluid could swap underneath and the fluid above the ball-rod was insufficient to hold it in place. With the packer and nipple at the "normal" depth, I think the fluid column remaining above would have been sufficient to hold the ball-rod in place regardless of what happened underneath. This is definitely something to keep in mind when completion assemblies are shallowed up. Tom ~-~----,---"._- From: Reem, David C [mailto:ReemDC@BP.com] sent: Monday, September 24,20071:42 PM To: Maunder, Thomas E (DCA) Subject: RE: Pl-17 Workover SCANNED SEP 2 5 Z007 Tom, 8.8 ppg was doing its job just fine until we went ahead and freeze-protected this fine well with diesel...a couple of 1000-ft of 6.9 ppg diesel lightened up the entire column sufficiently to under-balance to the reservoir. What we, as a team, re-Iearned on this well is to increase the brine weight prior to setting the packer to counter the addition of the diesel freeze-protect OR opt to for same-weight-as-the.~brin.e mineral oil or oil-based "mud". Hope this explanation helps. DCR From: Maunder, Thomas E (DCA) [mailto:tom.maunder@alaska.gov] sent: Monday, September 24, 20071:36 PM To: Reem, David C Subject: Pl-17 Workover Dave, 9/25/2007 . . Page 2 of2 I was just reviewing the 404 for the recent work on this well. It appears that the final fluid weight was insufficient to kill the well. Was the weight increase necessary due to the relatively "shallow" circulating depth with the packer above the liner top? It appears that while there was a conduit to the reservoir that 8.8 ppg was more than sufficient given the reported loss rate, however things changed once stung over with the OS and the ball-rod on seat. Your comments will be appreciated. Tom Maunder, PE AOGCC 9/25/2007 · STATE OF ALASKA I ~.ø RECEIVED ALASKA OIL AND GAS CONSERVATION COM SION SEP 1 9 Z007 REPORT OF SUNDRY WELL OPERATIONS t\laska Oil & Gas Cons. Commíssion 1. Operations Performed: An CIHJIi:l \:It: D Abandon 181 Repair Well- D Plug Perforations D Stimulate D Re-Enter Suspended Well D Alter Casing 181 Pull Tubing ~ D Perforate New Pool D Waiver D Other D Change Approved Program D Operation Shutdown D Perforate D Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development D Exploratory 193-051 - 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22358-00-00 - 7. KB Elevation (ft): 50' , 9. Well Name and Number: PBU P1-17 - 8. Property Designation: 10. Field / Pool(s): - ADL 028297 ' Prudhoe Bay Field / Point Mcintyre Pool 11. Present well condition summary / Total depth: measured 10532 feet true vertical 9244 / feet Plugs (measured) None Effective depth: measured 10440 feet Junk (measured) None true vertical 9152 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 3805' 10-3/4" 3846' 3574' 3580 2090 Intermediate Production 1 0477' 7-5/8" 1 0518' 9230' 6890 4790 Liner Scab Liner 3411' 4-1/2", 12.6#, L-80 5984' - 9395' 5228' - 8113' 8430 7500 Perforation Depth MD (ft): 9984' - 10344' SCANNED SEP 2 3 2007 Perforation Depth TVD (ft): 8697' - 9057' 4-1/2", 12.6# 13Cr80 9505' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2" Cameo 'Bal-O' Safety Valve; 7-5/8" x 4-1/2" Baker 2097'; 'S-3' packer; 7-5/8" x 4-1/2" Baker 'SABL' packer 5900' & 9433' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 9395'. Run 4-1/2" Scab Liner. Cement Scab Liner w/1 08.7 Bbls Class 'G' Cement (610 cu ft /526 sx). Run new Chrome comcletion to 5997'. 13. Recresentative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinq Pressure Tubina Pressure Prior to well operation: 0 0 0 Subsequent to operation: 3,225 26.996 1,080 860 1,873 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after work: D Exploratory 181 Development D Service 181 Daily Report of Well Operations 16. Well Status after work: 181 Well Schematic Diagram 181 Oil DGas DWAG DGINJ DWINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 307-260 Printed Name Terrie Hubble Title Technical Assistant Signature ~"fIÌ () J..J, J~ Prepared By Name/Number: Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 0 RIG I N A L RBDMS 8Ft SEP 2 4 ZOU7 þ.,"'b '-\ Submit Original Only Æ~~ TREE = VVELLHEAO = A CTUA TOR = KB. ELEV = 4-1/16" CIW FMC OTIS 50' P1-1 Datum 1VD = 10-3/4" CSG, 45.5#, J-55, 10 = 9.953" 4-112" LNR, 12.6#, 13CR-80. 0.0152 bpf, ID = 3.958" CEMENTED 4-1/2" SCA B LINER 7-5/8" CSG. 29.7#, NT95, 10 = 6.875" I 4-1/2" T8G, 126#, 13CR-80, 0,0152 bpf, 10=3.958" I ÆRFORA TION SUMMA RY REF LOG: OLL ON 04/16/93 ANGLE AT TOP ÆRF: 3 @ 9984' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9984-10004 0 05/17/93 3-3/8" 6 10012-10022 0 11/26/93 3-3/8" 6 10046-10079 0 11/26/93 3-3/8" 6 10094-10169 0 11/29/93 3-3/8" 6 10185-10344 0 11/28/93 PBTO 17 -5/8" CSG, 29.7#, 13-CR80, 10 = 6.875" 10440' 10518' OA TE REV BY COMMENTS 5870' 5900' 5934' 5984' . 1V0 OEV 2985 36 5081 40 GAS LIFT MANDRELS TYÆ VLV LATCH KBG2-1R DOME BK KBG2-1R SO BK PORT DATE 16 09/01/07 20 09/01/07 4-1/2" HES X NIPPLE, 10 = 3.813" I 7-5/8" X 4-1/2" BAKER S-3 PKR. 10=3.875" 4-1/2" HES X NIPPLE, 10 = 3.813" I BAKER LINER HANGER/LINER TOP PKR -r.,UNIQUE MACHINE OVERSHOT I 7-5/8" X 4-1/2" BAKER SABL PKR. 10 = 4.750" 9450' 9467' 4-1/2" SWS NIP, ID = 3.813" I 4-1/2" SWN NIP, ID = 3.725" I 4-1/2" TUBING TAIL, WLEG, ID = 4.00" ELMO TI LOGGED 05/13/93 PRUDHOE BAY UNIT WELL: P1-17 ÆRMIT No: 93-051 API No: 50-029-22358-00 SEC 16, T12N, R14E, 111.62' FEL & 49846' FNL BP Exploration (Alaska) Digital Well File Well: Pl-17 Well History Well Date P1-17 8/12/2007 P1-17 8/12/2007 P1-17 8/13/2007 P1-17 8/13/2007 P1-17 8/13/2007 P1-17 8/13/2007 P1-17 8/13/2007 P1-17 8/14/2007 P1-17 8/14/2007 P1-17 8/14/2007 P1-17 8/15/2007 P1-17 8/15/2007 . . Page 1 of , Summary H* WELL SHUT IN ON ARRIVAL *** RAN 3.85" DRIFT DOWN TBG UNABLE TO GET PAST 840' SLM. RAN 3.80" DRIFT DOWN TBG, TAGGED TOP OF SSSV @ 2239' SLM. PULLED 41/2" BTDP-1-TRCF-4A [sIn HWS-943] FROM SVN @ 2260' MD... BTM PACKING TORN, FLAPPER INTACT, THREADS TIGHT. RAN 3.80" DRIFT WITH BRUSH & S. BAILER, TAGGED XN NIPPLE @ 9477' SLM... CLEAR DRIFT, S. BAILER EMPTY. (SEEN TIGHT SPOTS @ 8320' SLM, 8451' SLM, 9050' SLM) CURRENTLY IN THE PROCESS OF SETTING TT PLUG IN XN NIP. H*CONT. JOB ON 08/13/07 WSR*** T/I/0=3000/0/0 Load & Kill well/ MIT T 3000 psi. Pump 5 bbls meth, 280 bbls 2% kcl, 40 bbls crude down tbg to load & kill. S/L set TTP. MIT-T postponed by PE. FWHP's=300/0/620 Slickline on well upon departure. T/I/0=2550/0/0 Assist S/L set TTP [RWO prep] Pumped 150 bbls crude, 60 bbls 2% kcl, & 5 bbls meth down tubing to flush for SILo FWHP's=500/0/0. Annulus valves & Master open. SSV, Wing, & Swab s/i. Tag hung on master. ***CONT. JOB FROM 08/12/07H* (rwo expense) RAN 4 1/2" XXN PLUG, SAT DOWN @ 9477 SLM. UNABLE TO SET... TOOLS CAME BACK W/ SCALE. LRS PUMPED 150 BBLS CRUDE, 60 BBLS KCL. [see LRS WSR] RIG DOWN SLlCKLlNE, AS PER BP REP. **** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. *H*** H* PLUG SETTING - CHEMICAL CUT 4-1/2 12.6# TBG H* WELL SHUT IN ON ARRIVAL. MI, T/I/O 850/0/0, SET HAL FAS nR1I1 PI IIG ::1 RR" )( ?R ~?" on )( I (ii¡ ~494' LR MIT. PLUGTESTED TO 3000 PSI. ***JOB CONTINUED THROUGH NEXT DAY*H T/I/O = 1125/20/20 Temp= S/I Assist E-Line, MIT T PASSED @ 3000 psi. (RWO prep) Pumped 1 bbl. meth spear followed by 8.8 bbls. 90*F crude to reach test pressure of 3000 psi. TBG lost 40 psi. in 1 st 15 min. and lost 0 psi. in 2nd 15 min. for a total loss of 40 psi., _m-Job In Progress-m- ***WSR Continued to 08-14-07*** T/I/O=SSV/O/O, Temp=SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig PPPOT-T: Stung into test port with high pressure bleeder tool to check pressure (0 psi). Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost o psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely with no sign of bent or broken pins. PPPOT-IC: Stung into test port with high pressure bleeder tool to check pressure (0 psi). Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 20 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely with no sign of bent or broken pins. ***JOB CONTINUED FROM PREVIOUS DAY*H *** PLUG SETTING - CHEMICAL CUT 4-1/212.6# TBG H*LOG CORRELATED TO TUBING TALLY DATED 20-APR-93 WELL SHUT IN ON ARRIVAL. MI, T/I/O 850/0/0, SET HAL FAS DRILL PLUG 3.66" x 28.92" OD xL @ 9494', LR MIT. PLUG TESTED TO 3000 PSI. PUNCH 4.5" TUBING AT 9355' TOP SHOT WITH 4 SPF, 9 SHOT SMALL PUNCHER. FIRED 12' x 3 STRINGSHOT FROM 9398 - 9410 FT. CONNECTED IA-T @ SURFACE FOR PRESSURE EQUALIZATION. WHP 500 PSI, CHEM CUT TUBING AT 9408 FT. FINAL T/I/O 574/475/0. RDMO H** JOB COMPLETED ***** T/I/O= 580/400/0 Circ Out (RWO PREP) Pump 5 bbls meth, 226 bbls 9.8 brine, 7 bbls diesel down tubing taking returns up IA through jumper line down P1-18 F/L- Pump 2 bbls meth, 115 bbls 9.8 brine down IA *HContinued on 8-15-07*** *HWSR Continued from 08-13-07*** Circ-out, MIT OA @ 1000 psi. *** Called off to go to another job *** SET BPV/ PRE RIG ***Continued from 8-14-07*** Circ Out, MIT OA PASSED to 1000 psi [RWO Expense] Bullhead 124 bbls 9.8 brine (Total of 239 bbls brine down IA) 5 bbls diesel down lA, Pumped 44 bbls crude, 7.5 bbls diesel through jumper line down P1-18 F/L. MIT OA 1000 psi- PASS Pumped 1.6 bbls crude down OA to achieve test pressure, OA lost 80 psi in 15 min's, 10 psi in 2nd 15 min's for a total loss of 90 psi in 30 min's. Bleed back 1.5 bbls crude- FWHP's = vac/vac/O ***Swab, SSV closed, Master-IA-OA valves open, Master, OA valve's tagged on departure*** http://digitalwellfile.bpweb.bp .comlWIInfo/Reports/Report Viewer. aspx 9/18/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/15/2007 8/26/2007 Spud Date: 4/3/1993 End: 8/14/2007 09:30 - 15:00 5.50 RIGD P PRE RD and back the Rig off of well slot K-14. Stage the Rig on K-Pad while pre-rig work is completed on P1-17. 15:00 - 00:00 9.00 RIGD P PRE Break down the BOP Stack for reconfiguration to a 4 ram setup. Remove single gate and replace with double gate. Load 3 1/2" x 6" VBRs and Blind Shears into the double gate. Continue to wait on pre-rig work on P 1-17 to be completed prior to moving the Rig. 8/15/2007 00:00 - 05:00 5.00 RIGD P PRE N/U BOPs to four ram configuration. Install to BOP moving pedistal 05:00 - 05:30 0.50 RIGD P PRE Position Rig to lay down derrick, drive out derrick pins, UD derrick. 05:30 - 06:30 1.00 RIGD P PRE R/U install booster tires 06:30 - 08:30 2.00 RIGD P PRE Move rig to edge of pad and wait on security 08:30 - 13:00 4.50 RIGD P PRE Move rig from K pad to PM1-17. 13:00 - 15:00 2.00· RIGD P PRE R/D and remove Front and Rear booster wheels. 15:00 - 17:00 2.00 RIGD P PRE Remove BOPs from traveling pedistal and place in cellar, Install 13 3/8"x 11-1/16th XO Spool 17:00 - 00:00 7.00 RIGD P PRE Waiting for well 17 pad preparation to be completed. performing work orders and preventive maintenence projects. 8/16/2007 00:00 - 00:00 24.00 RIGU P PRE Waiting on pad preparation, performing work orders and preventive maintenance. Continue to work on the Skate and Derrick as well as clean up operations around the Rig. Performed Annual PMs on Draworks and Top Drive. 8/17/2007 00:00 - 18:00 18.00 RIGU P PRE Continue pad prep, Inspect and torque bolts on Top Drive Torque Tube. Continue maintenence on Pipe Skate. Extensive cleanup operations continued on the Derrick. Had the mud lines and standpipe inspected by Tuboscope utilizing ultrasonic measuring. 18:00 - 00:00 6.00 RIGU P PRE PJSM Position Rig, Raise Derrick, begin to R/U Rig Floor. 8/18/2007 00:00 - 04:30 4.50 RIGU P PRE Continue to perform Rig Maintenance while waiting on Pad Preparation. Bridle down, R/U Rig Floor. 04:30 - 09:00 4.50 RIGU P PRE Lay Herculite around well head area, Lay matting boards on new gravel. Spot the Tree and Adapter Flange behind the well. 09:00 - 14:30 5.50 RIGU P PRE Notify the Drill Site Operator of moving onto well slot P1-17. Receive verbal OK to proceed without him. MIRU on well slot P1-17 with the Rig. Install double valve on the IA and spot the Slop Tank. RU to circulating manifold in the Cellar. Notate WHPs: Tbg, IA and OA = 0 psi. Begin taking on 9.8 ppg brine into the Pits. Discuss with Anchorage Engineering and we need the brine to be a minimum temperature of 80 degrees prior to pumping downhole. It had cooled to 53 degrees at the mud plant. Wait on Drill Site Maintenance to arrive on location - at Doyon 14 and having trouble. Accept the Rig at 12:00 hrs on 8/18/2007. 14:30 - 16:00 1.50 WHSUR P DECOMP Drill Site Maintenance arrives on location. RU Lubricator. Pressure test Lubricator to 500 psi - OK. Hold PJSM. ~ BPV with Lubricator. The Tubing is on a vac. 16:00 - 19:30 3.50 KILL P DECOMP Continue to steam and heat up the 9.8 ppg brine in the Pits to a minimum of 80 degrees. At 17:00 hrs, the temperature is up to 70 degrees. 19:30 - 20:30 1.00 KILL P DECOMP Pump 20 bbl Hi-Vis Sweep followed by 390 bbls 80 deg, 9.8 ppg brine, at 8 bpm w/ 1,060 psi. 20:30 - 21 :00 0.50 KILL P DECOMP Monitor well, no flow, B/D RID circulating lines. Printed: 9/14/2007 10:06:15 AM . . 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/15/2007 Rig Release: 8/26/2007 Rig Number: Spud Date: 4/3/1993 End: 8/18/2007 21 :00 - 22:00 1.00 WHSUR P DECOMP Install TWC and Test from above to 3,500 psi, and tested from below to 1,000 psi, Injection rate at 1.8 bpm. . c.. _\ _. ,\_ \ DECOMP BID RID test pump lines. '-\ \"-~ n:ro.~tO\,) YCo. 't. DECOMP I Bleed down control lines, begin to N/D Production Tree and J.(., )¥'\" Adapter flange. Id"' b,\ DECOMP Check Hanger Threads, In good condition made up XO sub with 7 1/4" Turns to Right. N/U BOPE, bell nipple, flow line. DECOMP Install 3.5"x 6" rams in upper rams on BOPs DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Sheave. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, HCRs and Upper IBOP with 4" Test Joint. Test #2- 3.5"x 6" VBRs, Lower IBOP, Manual Choke, Manual Kill with 4" Test Joint. Test #3- Choke Valves: 1, 12, 13, 14 and TIW Valve. Test #4- Choke Valves: 9, 11 and Dart Valve. Test #5- Choke Valves: 5, 8 and 10. Test #6- Choke Valves: 4,6 and 7. Test #7- Choke Valve #2. Test #8- 2-7/8" x 5" VBRs with 4-1/2" Test Joint. Test #9- Blind Rams and Choke Valve #3. Test #10- 2-7/8" x 5" VBRs with 4" Test Joint. Test #11- 3-1/2" x 6" VBRs with 4-1/2" Test Joint. The Upper Pipe Rams (3-1/2" x 6") failed with the 4-112" Test Joint due to a completely worn out Wear Plate. Have one brought over from Doyon 15 in Kuparuk to replace. DECOMP MU Landing Joint with Hanger XO and TIW. RU Schlurnberger Spooling Unit. DECOMP Wait on new Wear Plate to arrive on location. DECOMP Wear Plate arrives to the Rig. Install in the BOPE. DECOMP Re-test the 3-1/2" x 6" VBRs with the 4-1/2" Test Joint to 250 psi low and 3,500 psi high - good test. DECOMP RD Test Equipment. RU Lubricator Extension and Lubricator with Drill Site Maintenance. Pressure test Lubricator to 300 psi. Pull TWC. DECOMP PU Landing Joint and screw into Hanger. BOLDS with FMC reps. Pull on the Hanger and the completion does not appear to be free - suspect a mis-cut. Maximum pull = 225K two times. Re-seat the Hanger and fill the backside with 9.8 ppg brine. Discuss with Anchorage Engineering and decision made to RU E-line and re-cut the 4-1/2" Tubing approximately 2' below the previous cut. DECOMP Wait on Schlumberger E-line to arrive on location. Lay down landing jt, BID lines. Pull Riser and P/U M/U Shooting Flange. Prepare for Wire Line Operations. DECOMP Spot and R/U E-Line equipment. R/U Lubricator, Pump in Sub, Wireline BOPs, Pack Off. DECOMP Pressure test Shooting Flange, Lubricator, Wireline BOPE, to 1,000 psi, R/U Jet Cutter, RIH to 9,460' Corralate logs, Cut Tubinq at 9.410'. - DECOMP POOH wi Jet Cutter. Stand back SWS equipment. 22:00 - 22:30 22:30 - 00:00 0.50 WHSUR P 1.50 WHSUR P ~:: ::::~t 6.00 BOPSU1 P 8/19/2007 00:00 - 03:30 03:30 - 05:00 05:00 - 11 :00 11 :00 - 12:00 1.00 PULL P 12:00 - 13:30 1.50 BOPSU N 13:30 - 14:30 1.00 BOPSU N 14:30 - 15:30 1.00 BOPSU N 15:30 - 16:00 0.50 WHSUR P 16:00 - 17:00 1.00 PULL P 17:00 - 22:00 5.00 PULL N 22:00 - 00:00 2.00 PULL C 8/20/2007 00:00 - 03:30 3.50 PULL C 03:30 - 04:00 0.50 PULL C Printed: 9/14/2007 10:06: 15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/15/2007 8/26/2007 Spud Date: 4/3/1993 End: 05:30 - 07:00 1.50 PULL P 07:00 - 08:00 1.00 PULL N 08:00 - 10:00 2.00 PULL P 10:00 - 10:30 0.50 PULL P 10:30 - 16:00 5.50 PULL P 16:00 - 17:00 1.00 CLEAN P 17:00 - 18:30 1.50 CLEAN P 8/21/2007 18:30 - 00:00 i 00:00 - 02:30 02:30 - 03:30 5.50 CLEAN P 2.50 CLEAN P 1 .00 CLEAN P I 03:30 - 04:30 1.00 CLEAN P 04:30 - 08:30 4.00 CLEAN P 08:30 - 09:30 1.00 CLEAN P 09:30 - 13:00 3.50 EV AL P 13:00 - 15:00 2.00 EV AL P 15:00 - 16:00 1.00 EVAL P I DECOMP I N/D shooting flange, N/U riser. ~ \l, ~'Ir-t~ DECOMP M/U landing Jt Engage Hanger, BOLDS, P/t¢"string weight >-"\ 150,000# up. Call out Spooling Unit operators. DECOMP CBU at 11 BPM with 1,090 psi. Shut down and monitor well dead - OK. Break out and lay down the Hanger. DECOMP Wait on the Spooling Unit operators to show on location. They II thought they were needed on Doyon 14. Arrive on location at 07:45 hrs. Finish RU of Spooling Unit with Schlumberger reps. DECOMP POOH with existing 4-1/2",12.6#, 13Cr, NSCT Tubing while spooling up control line. Maintaining the hole full while POOH with 9.8 ppg brine. 30 Jts out at 09:15 hrs. DECOMP SSSV on surface at 10:30 hrs. Recovered 59 of 60 stainless 'I steel bands and appear to have recovered all control line. The records showed it being TRCF-4A but in fact it was a TRM meaning one control line instead of dual. RD Schlumberger Spooling Unit. DECOMP Continue POOH with existing Tubing Completion and laying down in the Pipe Shed. Maintaining the hole full with 110 degree 9.8 ppg brine. Loss rate avg = 5 bph. Recovered a i total of 240 Jts of Tubing, 3 GLMs, 1 Sliding Sleeve and cut joint = 22.22'. DECOMP RD 4-1/2" Handling Equipment. Clear and clean Rig Floor. Set 10" 10 Wear Ring. DECOMP PJSM with Baker fishing rep and crew. PU and MU BHA #1 as I follows: Dressing Mill, Extension, Extension, Polish Mill, Junk Basket, Double Pin Sub, Junk Basket, Junk Basket, 7-5/8" Casing Scraper, Bit Sub, Bumper Sub, Jars, Pump Out Sub, XO and (9) 4-3/4" Drill Collars. OAL = 330.03' DECOMP P/U Drill Pipe 1x1 from pipe shed. DECOMP I Continue to P/U drill pipe II pipe shed, to tubing stub at 9,394' DECOMP Obtain Parameters: up weight=195,OOO#, down weight=137,000#, rotating weight=160,000#, at 50 rpm, 7,000ft-lbs free torque, 5 bpm w/850 psi. Tagged tubing stub at 9,394 Doyon 16 RKB, dress off tubing stub l' to 9,395', Slide over stub 2 times without pumps or rotating. DECOMP Pump Hi-Vis sweep at 10 bpm w/2,950 psi. DECOMP Monitor well dead. TOH with BHA #1 standing back DP in the Derrick. DECOMP On surface with BHA #1. Break down and lay down BHA components with Baker rep. Empty and inspect Junk Baskets - recovered metal shavings, small pieces of control line, a piece of a steel band, small pieces of scale and what appears to be some gel like substance. Clear and clean Rig Floor. DECOMP PU and MU 7-5/8" RTTS with Halliburton rep. RIH with RTTS and 3 stands of 4·3/4" Drill Collars on 4" DP from the Derrick. DECOMP In with 198 Jts of DP. Establish UW = 138K, OW = 108K. Set the 7-5/8" RTTS @ 6,534' COE. RU Test Equipment. - Pressure test the 7-5/8" Casing from 6,534' to surface to 3,500 psi for 30 charted mins - OK. It took 2.4 bbls to reach test pressure. Bleed down test pressure. Line up to inject from below. Establish LLR of 2 bom / 1.300 osi into the CretFlcROI/!> DECOMP Release the 7-5/8" RTTS and POOH standing back DP in the Derrick. Printed: 9/14/2007 10:06: 15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/15/2007 Rig Release: 8/26/2007 Rig Number: Spud Date: 4/3/1993 End: 8/21/2007 16:00 - 17:00 1.00 EVAL P DECOMP Slip and Cut drilling line. 17:00 - 19:30 2.50 EVAL P DECOMP POOH Laying down 93 jts drill pipe. 19:30 - 20:30 1.00 EVAL P DECOMP UD Drill Collars and RTTS assembly. 20:30 - 21 :30 1.00 CASE P TIEB1 ~/U to run 4.5",12.6#, 13CR-80 Vam Top Liner. Change Bails, Elevators, Slips, R/U Torque Turn Equipment. P/U Centrilizers to rig floor. 21 :30 - 00:00 2.50 CASE P TIEB1 P/U and Run Unique Overshot and Pup jt, Baker Type II Landing Collar w/ball on seat and Pup jt with Ported Pup jt, 1jt 4.5",12.6#, L-80, IBT-M tubing, HES 4.5" IBT-M Float Collar with Pup jt, Baker 4.5", IBT-M Landing Collar on XO Joint. Continued to P/U 4.5",12.6#, 13CR-80, Vam Top liner. Using Jet Lube Seal Guard pipe dope and Torque Turning all Connection to an avg make up torque of 4,440 ft-Ibs. 8/22/2007 00:00 - 03:30 3.50 CASE P TIEB1 Continued to P/U 4.5",12.6#, 13CR-80, Vam Top liner. Using Jet Lube Seal Guard pipe dope and Torque Turning all Connection to an avg make up torque of 4,440 ft-Ibs. 03:30 - 04:00 I 0.50 CASE P TIEB1 RID Long Bails, Compensator, Stabbing Board, R/U to Run 04:00 - 04:30 I Liner in Hole on drill pipe. 0.50 CASE P TIEB1 P/U C-2 Liner Top Packer. Up weight=73,000#, Down i weight=70,000#. 04:30 - 05:30 1.00 CASE P TIEB1 Circulate Liner volume @ 7 BPM w/350 psi, Clear and Clean Rig Floor of 4.5" Handling Equipment. 05:30 - 09:30 4.00 CASE P TIEB1 RIH with Liner on 4" drill pipe to 9,401 '. 20-stands RIH @ 0630-hours. 0915-hours, P/U Stand #62 and get Up wt = 170K, Down wt = 118K. P/U stand #63 and RIH and see stub at 9,395' continue slowly in another 4' and see pins shear at -9,000-lbs with No-Go at 9,403'. P/U to 170K plus 2'. 09:30 - 10:00 0.50 CASE P TIEB1 P/U and M/U cementing head assembly. Blow down Line to Dowell. Hold PJSM with Dowell/Schlumberger crew, Veco truck drivers, Rig Crew, MI Engineer, Tool Pusher, WSL, and ADW Supt. 10:00 - 11 :45 1.75 CEMT P TIEB1 PIT lines to 4,500-psi. Establish circulation with 50-Bbls of 9.8-ppg brine from pits. Begin pumping 5-Bbls Class 'G' neat cement slurry followed by 50.5-Bbls Class 'G' with CemNet additive, then 53.2-Bbls Class 'G' neat. 11:45-12:30 0.75 CEMT P TIEB1 Swap over to rig pump to pump displacement. Drop plug and start pumping with rig pump and see plug bump with 1024-strokes or 103-Bbls. Cement-in-Place at 1206-hours. Pressure up to 2,000-psi and stop pump #2 to swap over to pump #1 which has pop-off pinned to 5,000-psi. Continue building pressure to 3,200-psi and see Liner Hanger set. SIO to 140K and pressure up to 4,200-psi, then slowly bleed to 1,000-psi, SIO to 75K and rotate 17-turns to the right to release the Liner Setting Tool. 12:30 - 13:00 0.50 CEMT P TIEB1 Pressure up to 1 OOO-psi and P/U on string and see pressure drop. CBU at 120-SPM and 2100-psi for 50-Bbls, slow pumps to 2-BPM, SIO off to 50K, then P/U to 75K and rotate to the right for 2-minutes per instructions from Baker Completions expert. See cement at surface after 1755-strokes or - 180-BBLs. See clean returns after another 408 strokes or -42-Bbls. P/U wt = 130K, SIO wt = 102K. 13:00 - 14:00 1.00 CASE P TIEB1 Break off cementing assembly on one joint of Drill Pipe and stand back with Tugger. POOH with 4-stands of DP. Hang Printed: 9/14/2007 10:06: 15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 8/15/2007 Rig Release: 8/26/2007 Rig Number: Spud Date: 4/3/1993 End: back cementing assembly and full joint. POH and SIB 4-stands of DP. Secure well. 14:00 - 15:00 I 1.00 CASE P TIEB1 Hold Safety Stand-Up meeting with Day Crew. The Night Crew held their's when the got off tour at 1200-hours. 15:00 - 15:30 0.50 CASE P TIEB1 P/U cementing assembly on single joint and M/U to string. RIH and break off and UD cementing head, swivel, and flag sub. 15:30 - 17:00 1.50 CASE P TIEB1 POH and SIB DP in Derrick. 17:00 - 17:30 0.50 CASE P TIEB1 B/O and UD Liner hanger running tool. 17:30 - 18:30 1.00 CASE P TIEB1 P/U and M/U BOP stack washing tool and RIH to clean out BOP stack. 18:30 - 21 :30 3.00 WHSUR P TIEB1 P/U FMC Packoff pulling tool and RIH and pull the 7-5/8" packoff. And test to 3,800 psi for 30 minutes 21 :30 - 22:00 0.50 CASE P TIEB1 P/U M/U Casing Scraper Assembly, BHA Consist of: 6.75" bit, I 75/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, XO. BHA 1 Lenght=26.46' . i 22:00 - 00:00 2.00 CASE P TIEB1 RIH to 5,990'. 8/23/2007 00:00 - 00:30 0.50 CASE P TIEB1 CBU @ 11 bpm 2,000 psi. Run scraper through packer setting area from 5,920' to 5,990'. 00:30 - 02:00 1.50 CASE P TIEB1 Monitor well, POOH, UD Scraper BHA. 02:00 - 03:00 1.00 I CASE P TIEB1 Clear and Clean Rig Floor, R/U Floor to P/U M/U 2 7/8" BHA. 03:00 - 03:30 0.50 CASE P TIEB1 P/U M/U 2 7/8" Clean Out Assembly, BHA Consists of: Junk Mill, 2-3.5"Junk Baskets, Bit Sub, Bumper Sub, Oil Jars, XO, Pump Out Sub, 114 jts 2.875" Drill Pipe, XO, Double Pin Sub, 2- 4.75"Junk Baskets, Bit Sub, XO. BHA Length=3,563.56' 03:30 - 08:30 5.00 CASE P TIEB1 P/U 2.875" Drill Pipe from Pipe Shed 1 x1. 80-joints RIH at 0700-hrs. 95-joints @ 0730-hrs. 114-joints of 2-7/8" PAC DP, total at 0830-hrs. 08:30 - 11 :30 3.00 I CASE P TIEB1 P/U and M/U 2-ea 4-3/4" Boot Baskets to XO at top of the 2-7/8" PAC DP. Continue RIH with DP from Derrick. Tagged TOL at 5,990', P/U and rotated 1/2-turn, then slowly RIH thru I TOL without any drag. Continue RIH. 25-stands RIH at 1000-hours. Tag soft cement at 9,120'. P/U one stand and R/U to pressure test liner and casing. 11 :30 - 12:30 1.00 CASE P TIEB1 Pressure test casing to 3,500-psi; hold and record for 30-minutes for solid test. 12:30 - 22:30 10.001 CEMT P TIEB1 M/U stand #59 to Top Drive and get parameters: 165K Up wt, 110K Down wt, 40-RPM, 5,500-lb-ft Rot free Torque, 2.5-BPM, 1,200-psi. Slowly lower and tag cement at 9,120', but drill immediately thru and continue milling for remainder of stand within 15-minutes. Reciprocate stand. P/U stand #61 and mill to hard cement at 9,278' which corresponds to the set depth of the top Landing Collar. Continued milling through 2nd Landing Collar and chasing junk to Fas Drill Plug. 22:30 - 00:00 1.50 CEMT P TIEB1 Pump 25 bbl Sweep then Displaced Wellbore to 8.8 ppg Brine at 5.5 bpm with 3960 psi. 8/24/2007 00:00 - 00:30 0.50 DRILL P TIEB1 Continue to RIH to Tag Fast Drill after Wellbore Displacement to 8.9 ppg Brine. TamJed FasDrill at 9,475'. Drilled at 40 rpm, 5 bpm, 1,500 psi, 2,500# WOB, 7,000 ft-Ibs Torque. Pushed plug out of Tail Pipe to 9,490'. 00:30 - 02:00 1.50 DRILL P TIEB1 CBU at 5.5-BPM, 3,250-psi. Establish loss rate of 180-BPH dynamic, monitor well. Well flowinq sliqhtly. 02:00 - 03:00 1.00 DRILL P TIEB1 Stand Back 1 std drill pipe. Dropped Circ Sub Ball, continued to circulate at reduced rate, 3-BPM, 1130-psi. Loss rate at 3-BPM Printed: 9/14/2007 10:06:15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/1 5/2007 8/26/2007 Spud Date: 4/3/1993 End: 8/24/2007 02:00 - 03:00 1.00 DRill P TIEB1 = 120-BPH. On 2-nd bottoms-up slight gas to surface. 03:00 - 09:00 6.00 DRill P TIEB1 Monitor well, still flowing slightly 4-Bbls in 5-minutes, still losing returns 120-BPH at 3-BPM, 1,130 psi. Discussed situation with Anchorage Engineer, began weighting up mud system from 8.9-ppg to 9.1-ppg while circulating at 2.5-BPM, 550-psi. 9.1-ppg in and out at 0900-hours. 09:00 - 10:00 1.00 DRill P !TIEB1 Stop circulating and monitor well. Fluid level falling in annulus I with some bubbles coming at surface for first 15-minutes. Fill ann I ed static fluid loss rate ontinue I monitoring well with constant fill charge-pump on annulus; fluid I loss rate is also 40-BPH. 10:00 - 15:00 5.00 DRill P TIEB1 POH and UD DP. 38-joints POH at 1100-hours. 63-jts @ i I 1200-hrs. 81-jts @ 1230-hrs. 150-jts @ 1400-hrs. last joint of I 4" DP UD at 1500-hours. 15:00 - 15:30 0.50 DRill Ip TIEB1 Breakout and UD 4-3/4" Boot Baskets. Found nothing in the I baskets. Changeout tubing handling equipment to handle 2-7/8" PAC DP. 15:30 - 18:30 3.00 DRill Ip TIEB1 POH and UD 2-7/8" PAC DP. 18:30 - 19:30 1.00 DRill !p TIEB1 POOH and UD 2 7/8" Milling BHA, RID 2 7/8" Handling i Equipment and Pull Wear Ring 19:30 - 20:30 1.00 RUNCO~P RUNCMP R/U to run 4.5",12.6#,13 Cr-80, Vam Top Completion. I Change to long Bails, Change Elevators, R/U Torque Turn RUNCO~P Equipment, and Compensator. 20:30 - 00:00 3.50 RUNCMP PJSM with WSl, Rig Crew, Baker Packer Hand, Casing Crew on Running Completion. P/U and Run 4.5", 12.6#, 13CR-80, Vam Top Completion, Using Jet lube Seal Guard Pipe Dope RUNcot and Compensator on all Connections. Average M/U Torque is 4,400 ft-Ibs. 8/25/2007 00:00 - 01 :30 1.50 RUNCMP PJSM with WSl, Rig Crew, Baker Packer Hand, Casing Crew on Running Completion. Continue to P/U and Run 4.5", 12.6#, 13CR-80, Vam Top Completion, Using Jet lube Seal Guard I Pipe Dope and Compensator on all Connections. Average M/U RUNCO~N Torque is 4,400 ft-Ibs. 01 :30 - 02:30 1.00 RUNCMP Wait on Control Line Hand for Control Line Sheave. 02:30 - 03:30 1.00 RUNcor RUNCMP PJSM with WSl, Rig Crew, Halliburton Control Line Hand, FMC Tech. RlU Control Line, Test to 5,000 psi for 10 minutes. Good Test. 03:30 - 06:00 2.50 RUNCO P RUNCMP Continue to Run 4.5" Completion with Control Line. Stop above I TOl @ 5990' and get Up wt 106K, Down wt 88K. 06:00 - 06:30 0.50 RUNCO RUNCMP Tag TOl at 5,990' and slowly RIH to stack out on NoGo ring installed on top of 10' pup screwed into the WlEG. P/U to calculate Space-out and do not have to add any Space-out pup joints. The TD for the WlEG will be 5,997' which is 7' inside the TOl. While POH to get Space-out, the Control Lines or SS-bands hung up on something downhole, but came free when Driller stopped the P/U and floorhands and Halliburton Tech moved the landing joint. 06:30 - 08:30 2.00 RUNCMP P/U landing joint and M/U to hanger. M/U Control Lines to hanger pentrations. Test Hanger Void and lines to 5,000-psi for 10-minutes--all rock-solid tests. 08:30 - 09:30 1.00 P RUNCMP land tubing hanger and RllDS. 09:30 - 12:00 2.50 P RUNCMP Reverse circulate (all at 3-BPM @ 70-psi) 140-Bbls, 140-F, 9.1-ppg 3% KCI/NaCI brine followed by 150-Bbls, 140-F, Printed: 9/14/2007 10:06: 15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/1 5/2007 8/26/2007 Spud Date: 4/3/1993 End: 16:00 - 17:30 1.50 9.1-ppg 3% KCI/NaCI brine mixed with EC-1124A Corrosion I Inhibitor. Continual returns after the first 55-Bbls are purnped. RUNCMP I Drop Ball and Rod; wait for 15-rninutes. Pressure up on tubing to 3,500-psi, but pressure bleeds down to 3,OOO-psi in 5-rninutes. Burnp back up to 3,500-psi and check stack and Possum Belly in Shaker Roorn. See no indication of leaks. Pressure bleeds off to 3,000-psi in 10-minutes. Bump back up and pressure bleeds off to 3,200-psi in 15-minutes, but no sign of leaks. Decide to bleed off pressure and break-off the sensator cap on the circulating line to let any entrained air escape. Fill the pipe and foam pores out as the fluid level reaches the top of the landing joint. MI engineer said the the 3%-KCI will cause foaming. Call MI and BP engineer. Decided to add some defoamer to the top of the landing joint and wait 15-minutes for it to fall through the fluid. Pressure up on tubing to 3,500-psi and have a chart-recorded, rock-solid 30-minute test. Bleed tubing to 1,500-psi. Pour some defoamer into the dishcarge line of the mud pump and build up pressure in the IA to 3,500- si; holds rock-solid for 30 charted minutes. Bleed off tubing pressure an sear e va ve. Pressure equalized too quickly to see valve open, so pump both ways at 2.5-BPM @ 650-psi taking returns to the Pits. RID circulating lines. B/O and UD landing joint. RUNCMP FMC P/U and install TWC in Hanger. Pressure Test from above and bel~w to 1,OOO-pSI for 10-minutes each. RUNCMP Pump Out Stack, Nipple Down BOPE. RUNCMP Prepare Wellhead and Control Lines, Nipple up Adapter Flange and Production Tree Tie in Control Lines Test Lines to 5,000 psi for 5 minutes. Test Adapter Flange to 5,000 psi for 15 minutes. Test Production Tree to 5,000 psi for 5,000 psi for 30 minutes. R/U to Test DSM Lubricator, to 500 psi. Pull TWC, RID DSM. R/U Manifold to Freeze Protect, Test Lines to 3,500 psi. Good Test. PJSM with Drill Crew and Little Red discussion on Freeze Protection Procedure. RlU to Test LRHOS Lines. Lined up Annulus to begin pumping freeze protection, Well Bore began to flow to Slop Tank before pumping began. Derrick Hand noticed flow and notified Driller. Crew shut in Annulus Valve. Notified Wellsite Leader. It was suspected that gas had migrated into the tubing and IA. WSL held meeting with crew to gather data pertinent to a discussion to be held with the Anchorage-based Engineer. Decide to reverse circulate 9.8-ppg brine through the GLM at 3,084'. RlU Choke and Kill Lines to Circulating Manifold to pump Kill Wt Fluid. Fill De-Gasser. Wait on 9.8-ppg brine to come from MI Plant. Continue to monitor ressures. SI pressures: T = 1460- si, IA = 850- si at 0630-hours: T = 1750- si IA = 850- si at 0700-hours. PJSM for pumping new 9.8-ppg Well Kill fluid. Start pumping by working up to 3-BPM with 2200-psi on IA and hold choke pressure of 1180-1200-psi on the tubing. Good fluid returns to the Slop tank through the gas buster after 35-Bbls. Fluid weight 12:00 - 16:00 4.00 17:30 - 20:00 20:00 - 22:30 2.50 BOPSU 2.50 BOPSU 22:30 - 00:00 1.50 BOPSU RUNCMP 8/26/2007 00:00 - 01 :00 1.00 BOPSU !RUNCMP 01 :00 - 01 :30 0.50 BOPSU RUNCMP 01 :30 - 02:00 0.50 WHSUR P RUNCMP 02:00 - 03:00 1.00 WHSUR P RUNCMP 03:00 - 04:00 1.00 WHSUR P RUNCMP 04:00 - 07:00 3.00 WHSUR P RUNCMP 07:00 - 08:00 1.00 WHSUR P RUNCMP Printed: 9/14/2007 10:06:15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-17 P1-17 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 8/15/2007 8/26/2007 Spud Date: 4/3/1993 End: 8/26/2007 2.50 WHSUR P 11:30-12:30 12:30 - 14:30 1.00 RUNCO 2.00 RUNCO from truck = 9.75-ppg and fluid weight to the slop tank = 8.9-ppg. Pump 133-Bbls and S/I to monitor pressures on the well. RUNCMP Monitor well pressures and see pressure climbing in tubing 'I' -17-psi / 5-minutes, 14-psi / 5-minutes in the IA. Calculated pressure immediately under the ball and rod with 3,500' gas column from 8800' TVD to 5250' TVD is equivalent to -13.2-ppg MW, which means that 9.8-ppg kill wt fluid won't hold ball on seat when well is SI with O--psi at surface. Confer with Engineer and with Wells WL and Completion Supv and decide to perform a combo MIT to 3,500-psi to verify packer is set and ball/rod is on-seat. RUNCMP Close Choke and #14 valve in Choke/Kill manifold and pressure up on IA to 3,500-psi. S/IIA. Took 4-Bbls to reach 3,500-psi. Hold and record on chart for 30-minutes for a rock -sol id test. RUNCMP Reverse circulate remainder of the 9.8-ppg brine. RUNCMP R/U Lil Red to reverse circulate 50-Bbls of diesel freeze protect into IA. PJSM with Lil Red and rig crew to pump Freeze protection fluid. Start pumping freeze protect fluid at 1/2-BPM, 500-psi taking returns through choke and Gas Buster to Slop Tank. Build rate to 1-BPM at 2,000-psi on IA and 1280-psi on tubing. Reverse circulate a total of 50-Bbls diesel freeze protect fluid. RUNCMP Bleed off and R/D Lil Red's lines; bleed off and R/D circulating lines in cellar. RUNCMP P/U DSM Lubricator and install on Tree. Pressure test to 2,500-psi with Diesel. Break Lubricator and install BPV and tool I sub inside: M/U lubricator and RIH and set BPV. Test from I below to 1150-psi. Remove DSM Lubricator and prepare to RDMO. Release rig at 1700-hours. 10:30 - 11 :30 1.00 RUNCO P 14:30 - 16:00 1.50 RUNCO P 16:00 - 17:00 1.00 WHSUR P Printed: 9/14/2007 10:06:15 AM P1-17 (PTD #1930510) Intel Wavier Cancellation . Page 1 of 1 Maunder, Thomas E (DOA) From: Sent: To: NSU, ADW Well Integrity Engineer [NSUADWWe/llntegrityEngineer@BP.com] Monday, August 27, 2007 12:15 PM Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, GPMA OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, LPC DS Ops Lead; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Frankenburg, Amy; Carr, Jessie L Subject: P1-17 (PTD #1930510) Internal Wavier Cancellation All, An internal waiver was issued for a PC leak on well P1-17 (PTD #1930510) on 03/16/07. The well recently had a rig workover that cemented a casing liner in place to repair the production casing leak. The well is reclassified as Operable. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Please call with any questions or concerns. Thank you, - Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~)CANNED AUG 282007 8/27/2007 . ~lf~lfŒ (ID~ ~~~~~~ . AIßASKA. OIL AlQ) GAS CONSERVATION COmnSSION SARAH PAUN. GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 ",,5\ \ q ~-' v Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PBU PI-17 Sundry Number: 307-260 Dear Mr. Reem: 5CANNED AUG 142007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Chai DATED thiS~ day of August, 2007 Enc!. i".>:)':.::(!( 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing . 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program' 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 193-051 ",' 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22358-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU P1-17 Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): \1.\, \J.._T \ I'.... 0\\ 'Ç>cr. \ ADL 028297 / 50' Prudhoe Bay Field / Pr' ,dl:.1gg ¡¡¡BY Peel fM J. 12. , PRESENT WELL CONDITION SUMMARY ", ' > \ >\'Y!Þ"'. ~ , ,.. , Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10532 /' 9244 ' 10440 9152 None None Casina Lenath Size MD TVD Burst Collanse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 3805' 10-3/4" 3846' 3574' 3580 2090 Intermediate Production 10477' 7-5/8" 1 0518' 9230' 6890 4790 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9984' - 10344' 8697' - 9057' 4-1/2", 12.6# 13Cr80 9505' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'SABL' packer I Packers and SSSV MD (ft): 9433' 13. Attachments: 14. Well Class after proposed work: ¿ 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina Ooerations: August25,2007 181 Oil " DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Name/~avid Reem Title Engineering Team Leader ~KeðA- Prepared By Name/Number: Signature Phone 564-5743 Date f '7-~-' Terrie Hubble, 564-4628 -(;7 , Commission Use Only I Sundry Number: 307 ~.J100 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: Subsequent Form Required: ~{)L'(fj APPROVED BY Date~' 9,ð1' Approved Bv: MMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 \..,../ U '--'""'- ~it In Duplicate RBDMS BFl AUG 1 3 2007 ~.,.C> .,tj.-ò 7 STATE OF ALASKA . I ALASKA Oil AND GAS CONSERVATION COMMISSION ~tc; APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 iVt:U .. l ~ ORIGINAL 7 ~Wø? . . P1-17 Rig Workover Scope of Work: Pull 4-1/2" 13Cr-80 completion, run and cement 41/2" scab liner to -7000' to cover cretaceous leak, replace 7-5/8" pack-off, and run 4-%" 13Cr80 completion. v MASP: 3120 psi Well Type: Producer Estimated Start Date: Aug 25, 2007 Pre-Rig: 0 1 S 2 E 3 F 4 0 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e (check one at a time. PPPOT-T & IC. Drift to 9467' for 4 W' XX plug & chemical cutter. Set TTP in the SWN-nipple @ 9467' md. Dum bail 10' of slu its on top of plu . Chemical cut @ -9408', in the middle of the 1 S full joint above the packer. (Ref: 04/20/1993 tubin summary). Circulate well with NaCI brine and FP w/ diesel thru the cut. MITOA to 1000 psi. Bleed WHP's to 0 si. Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU Doyon 16. NO tree. NU and test BOPE with to 250 psi low, 3500 psi high. Due to a MASP >3000 psi, a 4 ram stack will be required. The BOP's will be fitted with, both 3" x 6" and 2 7/8" x 5 W' Variable bore rams. 2. Circulate out freeze protection fluid and circulate well to clean 9.0 ppg brine through the cut. 3. Pull and LD tubing string to the cut. 4. Run 4 1/2" scab liner on drill pipe to cover cretaceous leak 5. Cement new 4 1/2" scab liner to -7000 MD with 68 bbls of cement and set liner top packer and hanger. 6. Change out 7-5/8" packoff and pressure test to 3800 psi. 7. Run 4-%" 13Cr80 completion with Baker S-3 packer. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. NO BOPE. NU and test tree. RDMO. ~REE = FMC SA OTES: IA x CRETACEOUS LEAK FOUND WITH . WELLHEAD - CIW P1-17 LDL ~OO'. IA 1000 psi MAX.TUBING HANGER: FMC BP ACTUA TOR = OTIS 35' MD. TIGHT SPOTS 6720' - 8810' SLM. *** PROD KB. ELEV = 50' CASING x FORMATION LEAK. OPERATING LIMITS: MAX BF. ELEV = lAP = 500 PSI; MAX OAP = 1000 PSI (03/16/03 WAIVER) *** KOP= 2045' ***CHROMETBG & CSG*** ~= 41 10137' . 2260' 4-1/2" CAMCO WRDP-1-CF SSSV W/Ð<T FOR L-O I Datum IVU 8866;88 TRCF-4A. 12' PRONG RAN 03/14/06 (SS#HZS-225) -¡.J ~ GAS LIFT MANDRELS 110-3/4" CSG, 45.5#, J-55. ID = 9.953" I 3846' STI MD TVD DEV TYÆ VLV LATCH PORT DATE U q ~~~! 4201 38 KBMG BK-2 5824 39 KBMG BK-5 3 9305 8025 12 KBMG BK-2 Minimum ID = 3.725" @ 9467' I 9353' 1-14-1/2" BAKER CMU SLIDING SLV, 10 = 3.813" I 4~112" PARKER SWN NIPPLE I I . I 9362' H4-1I2" SWS NIP, 10 = 3.813" I I I 8: ..,..",. ..941ì' -i 7-5/8" X 4-1/2" BAKER SABL PKR, ID = 4.750" I 17-5/8" CSG, 297#, NT95, ID = 6.875" H I "'-'" 9424' ... / <1433 ' 1 TOP OF 7-5/8" CSG H 9424' I I 9450' 1-14-1/2" SWS NIP, ID = 3.813" I I . 9467' H4-1/2" SWN NIP, ID = 3.725" I 14-112" TBG, 126#. 13CR-80, .0152 bpf, 10 = 3.958" I 9504' , 9504' 1-4-2/3" TUBING TAIL, WLEG, 10 = 4.00" I I 9488' l-i ELMO TT LOGGED 05/13/93 I ÆRFORA TION SUMMARY REF LOG m.L ON 04/16/93 ANGLE AT TOP ÆRF: 3 @ 9984' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 6 9984· 10004 0 05/17/93 3-3/8" 6 10012 - 10022 0 11/26/93 3-3/8" 6 10046 .. 10079 0 11/26/93 3-3/8" 6 10094 - 10169 0 11/29/93 3-3/8" 6 10185-10344 0 11/28/93 I PBTD I 10440' , I 17-518" CSG, 297#. 13-CR80, ID = 6.875" I 10518' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE SA Y UNrT 04/22/93 ORIGINAL COM PLETION WELL: P1-17 03/17/06 DRF/TLH SSSV CIO ÆRMrT No: 93-051 03/16/06 RPHlPJC W A IV ER SFTY NOTE UPDA TE API No: 50-029-22358-00 SEC 16, T12N. R14E, 111.62' FEL & 498.46' FNL BP Exploration (Alaska) "fREE "'. .. FMC WELLHEAD = CrN P1-17 Proposed Completion ACTUA TOR = OTIS KB. ELEV = 50' BF. ELEV = KOP= 2045' Max Angle = 41 @ 4066' Datum MD = 10137' . I H 4-1/2" HES X-Nip I Datum TVD = 8800' SS ~ GAS LIFT MANDRELS I 10-3/4" CSG, 45.5#, J-55, ID = 9.953" I 3846' ~ ST MD TVD DEV TYÆ VLV LATCH PORT DATE L Minimum 10 = 3.725" @ 9467' 4-1/2" PARKER SWN NIPPLE · · 4-1/2" HES X-Nip · ;g: .......... -6900 H 7-5/8" X 4-1/2" BAKER S-3 PKR I ¡..:::::. · · I H 4-1/2" HES X NIP I I I -7000 I- -7000 H BAKER LINER HANGER/LINER TOP PKR I 4-1/2" LNR, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" I CEMENTED 4-1/2" SCAB LINER I I I H UNIQUE MACHINE OVERSHOT I ~ J ¡.:: JM17' H 7-5/8" X 4-1/2" BAKER SABL PKR, ID - 4.750" I 7-5/8" CSG, 29.7#, NT95, ID = 6.875" I 9424' µ ~ Q<.{ö3' · 9450' H 4-1/2" SWS NIP, ID = 3.813" I · 9467' H 4-1/2" SWN NIP, ID = 3.725" I I 4-1/2" TBG, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" I 9504' rf- 9504' H 4-1/2" TUBING TAIL, WLEG, ID - 4.00" I I 9488' H ELMD TT LOGGED 05/13/93 I ÆRFORA TION SUMMARY REF LOG: DLL ON 04/16/93 ANGLE AT TOP ÆRF: 3 @ 9984' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 6 9984-10004 0 05/17/93 3-3/8" 6 10012-10022 0 11/26/93 3-3/8" 6 10046-10079 0 11/26/93 3-3/8" 6 10094-10169 0 11/29/93 3-3/8" 6 10185-10344 0 11/28/93 I PBTD I 10440' 17 -5/8" CSG, 29.7#, 13-CR80, ID = 6.875" I 10518' I I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 04/22/93 ORIGINAL COMPLETION WELL: P1-17 08/12/01 RNlTP CORRECTIONS ÆRMIT No: 93-051 08/13/03 JLA/KK WAIVER SAFETY NOTE API No: 50-029-22358-00 SEC 16, T12N, R14E, 111.62' FEL & 498.46' FNL BP Exploration (Alaska) . . Review of Sundry Application 307-262 BP Exploration (Alaska) Inc. Well Prudhoe Bay Unit K-08A Prudhoe Bay Field, Prudhoe Oil Pool AOGCC Permit 203-140 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to plug the existing well to prepare it for sidetracking. Recommendation: I recommend approval of BPXA's request. Discussion: Well K-08 was originally drilled and completed in 1985. The well produced about 7.4 MMBO before being plugged in preparation ofthe K-08A sidetrack in 2003. The K-08A sidetrack was drilled and completed in September 2003. The well produced on an essentially continuous basis until July 2004 and then was cycled, producing for about 10 days per month, through December 2005. Since that time production has been attempted on an infrequent basis. Initial production was approximately 2,500 BOPD at a GOR of about 4,500 SCF/STB. The GOR began rapidly climbing almost immediately and reached 45,000 to 50,000 SCF/STB. According to BPXA's application they detennined the gas was probably coming in from the toe ofthe well so in January 2006 they set a plug in an attempt to shut off the gas, but this did not work. In March 2007 they attempted to access additional reserves by adding 50 feet of perfs. After perfonning this operation they were unable to return the well to production, even when a nitrogen lift was attempted. BPXA's application stated "the well was blown dry with no signs of inflow." (Note: I believe a 10-404 is required for the add perfs operation that was perfonned in March 2007, but none is in our files.) BPXA states that the gas there is not enough offset between the current set of perfs and the gas oil contact to make it viable to add new perfs in an attempt to return this well to production. . . Conclusion: Since the well is currently incapable of production and was a marginal well due to high GOR before the well was lost during the March workover it does not appear that the current wellbore has any future value. Therefore, BPXA's proposal to abandon the existing well so that the well can be sidetracked to a more favorable location appears to be the best option for this well. D.S.RObY~~ Reservoir En~ August 9, 2007 a STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 0 4 2006 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development [;'1 Stratigraphic r Stimulate 0 Alaska ~ s (;ons. (;ommisslOn Waiver 0 Time Extension Anchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 193-0510 6. API Number: 50-029-22358-00-00 9. Well Name and Number: Exploratory Service 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 50 KB P1-17 8. Property Designation: ADL-028297 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PT MCINTYRE OIL Pool Total Depth measured 10532 feet Plugs (measured) None true vertical 9244.37 feet Junk (measured) None Effective Depth measured 10440 feet true vertical 9152.48 feet Casing Length Size MD TVD Burst Collapse Conductor 68 20" 91.5# H-40 42 - 110 42 - 110 1490 470 Surface 3807 10-3/4" 45.5# J-55 41 - 3846 41 - 3574.36 3580 2090 Production 9387 7-5/8" 29.7# NT-95HS 37 - 9424 37 - 8141.82 8180 5120 Production 1094 7-5/8" 29.7# 13CR80 9424 - 10518 8141.82 - 9230.39 6890 4790 Perforation depth: Measured depth: 9984 - 10344 True Vertical depth: 8697.02 - 9056.58 - I \.';"¡¡ '.''''-''' v . ; Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 35 - 9504 Packers and SSSV (type and measured depth) 4-1/2" Cameo WRDP-1 SSSV 4-1/2" Baker SABL-9 Packer 2260 9417 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 551 1842 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 8145 1542 0 19951 5269 0 Tubing pressure 946 832 15. Well Class after proposed work: Exploratory Development [;'1 16. Well Status after proposed work: Oil ¡;;) Gas r WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service x GINJ WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal / Printed Name Sharmaine Vestal / Title Data Mgmt Engr ~~'" c:::-:: -.. Signat - .., . . Phone 564-4424 Date 3/30/2006 . . Form 10-404 Revised 04/2004 0 RIG I N A L R8DMS 8FL APR t'#'...."I1..J' I) 20067<'~l Submit Original Only .. e e P1-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMM~RY 2/5/2006 ***WELL FLOWING UPON ARRIVAL***(waiver compl) RAN 3.75 LIB TO 6727' SLM, NO PICTURE. UNABLE TO GET 3.5" G- RING PAST 8150' SLM, 3.25" G-RING PAST 9334' SLM. DRIFT WI 3.125" G-RING OUT TT @ 9480' SLM. RAN BRUSH & 3.70 G- RING TO SVLN @ 2238' SLM. SET WRDP-1-TRCF (DB LOCK)(S/N HZS-225)(OVERSIZED PACKING WI O-RING) @ 2236' SLM ***WELL LEFT S/I*** 3/13/2006 *** JOB CONT. FROM 3/12/06*** PULL P-PRONG FROM PXN PLUG UNABLE TO LATCH UP TO PXN PLUG BODY TWO RUNS W/5 & 10' OF 3" PUMP BAILER WI SCALE RETURNS RAN 2.25" BAILER WI SNORKLE BOTTOM, BACK WI RETURNS AND MARKS ON BOTTOM RIH WI 4.5" GR, LATCHED PLUG BODY @ 9445' SLM, PULLED AND HUNG UP @ 9320' SLM, TOOL SHEARED RIH W 4.5" GS, UNABLE TO LATCH UP POH TOOL NOT SHEARED RIH WI 8' OF 3" PUMP BAILER *** JOB CONT. ON 3/14/06*** 3/13/2006 T/I/O=2500/2010 MIT-OA TO 3000 PSI PASSED Pump 3.5 bbls crude to reach test pressure OA lost 250 psi in first 15 min and 110 more in second 15 min test 2 OA lost 80 psi in first 15 min and 40 psi in second 15 min total of 120 psi lot in 30 min bled OA back to 0 FWHP=2500/2010 3/14/2006 ***JOB CONT FROM 3/13/06*** TWO BAILER RUNS TO 9348' SLM WI RETURNS OF SCALE BAILER BACK WI 2 QUARTS OF SCALE LATCHED UP TO PLUG BODY @ 9348' SLM, GR SHEARED PULLED PLUG BODY FROM 9330' SLM WI 4.5" GS SET 4.5" WRDP-1 WI OVERSIZE PACKING @ 2236' SLM ***SAFETY SYSTEMS NORMAL, WELL TURNED OVER TO DSO*** FLUIDS PUMPED BBLS 3 3 I ;;::L , ~. STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate 0 WaiverD OtherD Alter CasingD Repair Weill!) Plug PerforationsO Stimulate D Time ExtensionO Change Approved ProgramD Pull TubingD Perforate New PoolO Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. . 193-0510 Development ŒJ ExpldratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-22358-00-00 7. KB Elevation (ft): 9. Well Name and Number: 50.00 P1-17 8. Property Designation: 10. Field/Pool(s): ADL-028297 Pt Mcintyre Oil Field / Pt Mcintyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 10532 feet true vertical 9244.4 feet Plugs (measured) None Effective Depth measured 10440 feet Junk (measured) None true vertical 9152.5 feet Casing Length Size MD TVD Burst Collapse Conductor 68 20" 91.5# H-40 42 - 110 42.0 - 110.0 1490 470 Production 9387 7-5/8" 29.7# NT-95HS 37 - 9424 37.0 - 8141.8 8180 5120 Production 1094 7-5/8" 29.7# 13CR80 9424 - 10518 8141.8 - 9230.4 6890 4790 Surface 3807 10-314" 45.5# J-55 41 - 3848 41.0 - 3575.9 3580 2090 Perforation decth: Measured depth: 9984 - 10004, 10012 - 10022, 10046 - 10079, 10094 - 10169, 10185 - 10344 True vertical depth: 8697.02 - 8716.99,8724.98 - 8734.97,8758.93 - 8791.89,8806.87 - 8881.78,8897.76 - 9056.58 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 35 - 9505 RECEIVED Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-9 Packer @ 9433 4-1/2" Camco WRDP-1 SSSV @ 2265 JAN 16 2.004 12. Stimulation or cement squeeze summary: . Cons Commission Intervals treated (measured): A\aska 0" & Gas. Treatment descriptions including volumes used and final pressure: Anchorage 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 77 0.03 710 Vacuum 872 Subsequent to operation: 957 4.7 6465 0 874 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature 1:1 ~. C~ Phone 564-4657 Date 1/14/04 ~~!\!EÐ' JAil! 2 @ 2004 n Q I GIN A L,):~i~ ~ iJ ' Form 1 0-404 Revised 12/2003 . ( ( P1-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/09/03 T/I/O= 720NAC/400. OA downsqueeze. FU Cementers to OA, PJSM PT to 3200 psi. Started down OA with 10 bbl smethanol spear. Pumped 20 bbls DS CW101 Surfactant and 50 bbls of freshwater at 2.5 bpm @ 1300 pis. Increased rate to 5.0 BPM @ 1400 psi. Pumped an additional 150 bbls of freshwater, 15 bbls CW 101 surfactant, 5 bbls freshwater, 20 bbls Arctic Set 1 with Celloflake. Displaced cement to shoe with 3 bbls of freshwater and 125 bbls of crude at 4.9 BPM @ 900 psi. Cut rate to 1 BPM at 115 bbls of crude away, pumped 5 bbls at this rate. Cut rate to 0.5 BPM the last 5 bbls of crude. Had a slight increase with the last 5 bbls. SD and monitored pressure for 10 minutes. OAP slowly dropped off to 790 psi. Top of cement at 33461. RD MOL. Final WHp1s == 720NAC/790. 08/11/03 T/I/0=720NAC/280. SI @ wing. LNFT-IA PASSED (PC Leak Waiver). IA FL @ 1381. Opened bleed to bucket and vac went to 0 psi in 5 min. Started LNFT. lAP remained @ 0 psi with no fluid to bucket. Monitor for 30 min. lAP remained @ 0 psi. Final WHp1s=720/0/280. 08/12/03 T/I/0=720/0/250. MIT - OA to 3000 psi PASSED. (Post OA DWN SQZ). Pressured OA to 3000 psi with 2.2 bls of crude. Started 30 min test. OA lost 160 psi in 10 min. Re-pressured OA to 3000 psi. OA lost 120 psi in the first 15 min and 40 psi in the 2nd 15 min. Bled OA to 100 psi. Final WHP=71 0/0/1 00. 09/11/03 MILUUNDERREAM SCALE/ MIRU CTU #9. RIH WITH MILL. ENCOUNTERED MINOR MOTOR WORK FROM 8500' IN TUBING. STALLED IN VICINITY OF GLM #3. HAD OVERPULLS ATTEMPTING TO PUH. SWAPPED RETURNS FROM SYSTEM TO TANK, DROPPED WHP. PIPE FREE. PUMPED BOTTOMS UP. WENT BACK MILLING. MILLED TO 10130' CTMD. HARD MILLING AT 101301. POOH TO PU UNDERREAMER FOR LINER. RIH WITH DB UNDERREAMER. START UNDERREAMING LINER FROM 95501 CTMD. 09/12/03 MILUUNDERREAM SCALE/ SCALE INHIBITOR TREATMENTI Continued from 9/11/03 WSR.--Underream 7 5/8in liner from 95501 to 10400' ctmd. Saw initial motor work at 98601 and reamed thru hard bridge at 101331 with 3 stalls. Minimal motor work beyond that. Pumped flopro sweeps with short trips to TT. Pumped 25 bbl flopro final sweep from bottom and chased to surface at 80%. Inspect uR on surface, showed wear on leading edges of all 3 knives. RU BHA #3, Attempted injectivity test. Well will not take fluid. RIH encountered slush? Circulate 60/40 MeOH down to 25001. Still cannot establish injection into well. RIH to 50001, Pressured up to 3000 psi, still zero injection. RIH to 93241 tagged up. Started jetting and went through. Tagged up again 93481. Jetted through and saw WHP change and injectivity return. RIH and tagged TD @ 103881. PUH to tubing tail. Pumped well kill volume down backside, including injectivity test. (4 bpm @ .690 psi WHP). Pump Scale Inhibitor treatment as per program. 09/13/03 Scale Inhibitor Treatment! Continued from 9/12/03 WSR/ Complete pumping SI treatment POOH FP coil w/60/40 meth. FP flowline. Shut in well for 8 hrs. Perform weekly BOP test. Bring well back on with N2 lift. Left flowing at 2000bpd @ 840 psi WHP *** Job 09/21/03 ( WELL FLOWING ON ARRIVAL) ( POST CTU UNDER-REAM) DRIFT WI 3.73in G. RING 41/2in B. BRUSH 3.83in CENT TO SV NIP. SD @ 22341 SLM. ATTEMPTED TO SET 41/2in CAMCO WRDP-1 CON OP. SSSV (HXS-1458 DB LOCK MIN I.D=2.12in) 2 TIMES WOULD NOT HOLD PRESSURE. Unable to Set SSSV. RDMO. (DSO will POP well). 10/16/03 Set DSSSV @ 2231 SLM. Balance line still restricted tight, control line working properly. Pulled DSSSV. Set 4 1/2 DB WRDP-1 SSSV, two sets oversized pkg. Good closure test. Page 1 { I - ~ P1-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 73 Methonal 35 CW 101 Surfactant 208 Freshwater 20 Arctic Set, 1 w/celloflakes 128 Crude 1072 1 % KCL Slk 35 Flo Pro 30 1 % X-SLK 1030 Gals N2 2631 TOTAL , . Page 2 ~ ( ( lREE= Frvc SAFETY NOTES: IA x CRETACEOUS LEAK FOUNJ WELLHEA D = aw P 1 1 7 WITH LDL @ 7400'. IA 1000 psi MAX. TlBlNG AClUA TOR = OllS - HAt-Gæ: FM C BP 35" MD. TIGHT SPOTS 6720'- KB. 8..BI = SO' 8810' SLM. *"** PROD CASING x FORMATION LEAK BF. 8..EV = OPERATING LlM rrs: M AX lAP = SOO PSI; MAX. OAP KOP= 2045' = 1000 PSI (08113103 WAIVæ) *** Wax Angle = 41 @ 4066' DatumrvD= 10137' 8 4-1/2"CAMCOWRrP-1-CFSSSVW1EXTFOR Datum lVD = 8800' SS L-O TRCF-4A. 12' PRONG AAN SS#HXS-1458 GAS LIFT M<\NI:R8..S 10-314" CSG, 45.5#, J-55, ID = 9.953" DBI lYÆ VLV LATCH FORT DATE 38 KBWG BK-2 39 KBWG BK-5 12 KBWG BK-2 Minimum ID = 3.725" @ 9467' 4-112" SAKERCWU SLIDNG SLV, ID= 3.813" 4-1f2" PARKER SWN NIPPLE 4-1f2" sws NP, ID = 3.813" 941T 7-518" X4-1/2"BAKERSABLPKR, D=4.750" I 7 -5/8" CSG, 29.7#, NT95, ID = 6.875" H 9424' I I TOPOF 7-5/8" CSG H 9424' I 9450' 4-112" SWS NP, ID= 3.813" 4-1f2" SWN NP, ID = 3.725" I 4-1/2" TBG, 12.6#, 13CR-BO, 0.0152 bpf, ID = 3.958" I 4-213" lUBING TAIL, WLEG,ID = 4.00" EUvD IT LOGGED 05113/93 ÆRFOAAllON SLlv1MARY REF LOG: Œ.L ON 04/16/93 ANGLEA TTOP PERF: 3 @ 9984' Note: Refer to Production DB for his to riea 1 perf data SIZE SR= INTERVAL Opn/Sqz DATE 3-318" 6 9984-10004 0 05/17/93 3-318" 6 10012-10022 0 11/26/93 3-318" 6 10046-10079 0 11/26/93 3-318" 6 10094-10169 0 11/29/93 3-318" 6 10185-10344 0 11/28/93 10440' 7-5/8" CSG, 29.7#, 13-CRBO, D = 6.875" 10518' DATE REV BY COMrvENTS DATE REV BY COMMI3\JTS FRUDHOE SA Y UNIT 04/22/93 ORIGINAL COMPLETION W8..L: P1-17 08/12/01 RN'TP OORRECTIONS ÆRMIT No: 93-051 08/13/03 JLA/KK WAIVER SAFETY NOlE APII'b: 50-029-22358-00 SEC 16, T12N, R14E, 111.62' FEL & 498.46' FNL 8P Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/31/03 NO. 3017 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-19B I c_,[ ~.~ ~ L~ MEM PPROF & IPROF LOG 09/29/03 1 H-27A ~r~"~ ..~ Of MEM PPROF & IPROF LOG 10/01/07 1 D.S. 1-10. ~ ~--~~ PSP LDL 10/25103 1 _. D.S. 16-23 ~ ~ I - I ~ RST G~VEL PACK LOG 07/10/03 JX-02A ~1' I~ LDL 07/18103 D:S. 14-23 i~'O~ PSP LDL 10/24/03 I .- P1-17 }~'~-~ ( PROD PROFILE WIDEFTIGHOST ~0126103 , ,. D.S. 6-16 i~0~ LDL 1011~07 1 ... PI-~SA ~-~~ PROD PROFILE W/DEFT 10115107 D.S. 5-28A ~1 - ~ ~ LDL 10/14/03 D.S. ,2-20 [~-I~l LDL " 10/21/03 1 2-32/SN-03~ ~OL~I~ , LDL 10125107 I ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. '. "' ........ ~:~ ........ '~ ~'~ .......... '- .: .j~:..~,~.[ .,~._~.~ : ,,_ ~ ',~ Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth MEMORANDUM State of Alaska Alaska Oil and Gas Conservation COmmission TO: THRU: FROM: Julie Heusser, ~ ~,~1- DATE: Commissioner Tom Maunder, P. I. Supervisor ~.[~' ~ \ ' John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-O1 April 11, 2001: I traveled to BPX's Lisbume Gas Injection (LGI) and also on to- the Point Mclntyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports are attached for reference. As noted 3 failures were observed on both pads; with 2 being repaired and retested immediately. The third failure asssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an eXcellent job. Summary: I witnessed the SVS tests on LGI and PM-01 LGI, 3 wells, 9 components, 1 failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rate Attachment; Svs bpx Igi 4-10-0 ljs Svs bpx pm-01 4-10-0 ljs Nqn. con.f, identiaI Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Wysocki AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Pt McIntYre~BU/PM-01 Separator psi: LPS 460 HPs 4/9/01 Well Permit Separ Set L/P Test Test Test Date I Oil, WAG, GI1NJ, Number Number PSI PSI Trip Code Code Code Passed G~S or CYCLE 12 1910370 ............... Pi'02 1880050 ......... i ............................ P1-03 189013'0 460 350 310 P P P OiL P1-04 1930630 460 700 700 :P ..... ~ ' P .... OIL P1-05 1930870 460 350 3001 P P 9 OIL PI-06 ~ 1961376 460 '700 ...... 67~ P ....... P "P ....... 0IL P 1-07 1891340 i P1'-08 1930980 460 1500 1200' P' P ....... ~ ............. oil PLi'-09'" 1'961540 460 350 30'0 P P "'P ...... 0I'L Pi-11 1920860 460 350 250 p p p OIL Pl-12 1910130 Pl'-i3' 1930740 460 ...... 1'5'00'1150 P .... P' P ........... OIL 193051'6 ....... /;60 .....3'50 "280 ' P" 'P P ...... ' ........ 0-i'L P1-20' i'9209~0"' ~¢60" 350 ...... 175 5 ' P ' P ............ z~9701.... OIL Pl.23' i 1961240. P1-24 19614901 P l.Ol~ 1921150 .... 3600 2900 '2850 p ..... p ~ p ........ dlNj, Wells: 11 Components: 22 Failures: .2 Failure Rate: 9.09% [7190 Day Remarks: P1-08 & P1-3, we,re c~oke,d,. ,back, hence the .ltl ..~...er Pilot settings ......................... P1220 pilot reset and. retested. ~ ~ :. .................................... RJF 1/16/01 Page 1 of l 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX ...... Operator Rep: M,ark W¥socki AOGCC Rep: John H. Spaulding :-. ,: _ ,~ ,,, _ Submitted By: .John Spa,,,u.!d~ FielclfU~t~ad: Lisburne/PBU/LGI Separator psi: LPS : .-. : , .: .~1 Date: 4/9/01 '' . ' i , t l .... Well Permit Separ Set L/P Test Test Test Date oil, wac, ~j, Number Number PSI PSI Trip Code Code Code ·Passed GAS or CYCLE LGI-02 1861400 3800 2900 2300 ~ P P 4/9/01 GINj LGI-04 1880130 LG~-06 1860670 3800 2900 2500 P ' P P GINi iLGI-0'~ 1860550 ................. LGI-10 '1 ~0690 3800 2600 2300 " P ' "P P ' ' G1NJ LGI-12 1860540 .............. . Wells: 3 Components: 6 FaEures: 1 Failure Rate: 16.67~,~]0o Day Remarks: · L.G. 1-02. Pflot. t.ripped to !0...w .and... .w._as .reset, retest_~, and.pass~t,, ..................... RJF 1/16/01 Page 1 of l 010409-SVS LGI Lisburne-js STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3879' FNL, 864' FEL, Sec. 16, T12N, R14E, UM At top of productive interval 292' FNL, 4143' FEL, Sec.15, T12N, R14E, UM At effective depth At total depth 280' FNL, 4105' FEL, Sec. 15, T12N, R14E, UM 5. Type of Well: Development ~X Explorato~___ Stratigraphic_ Service__ (asp's 674192, 5994526) (asp's 676101, 5998161) (asp's 676137, 5998172) 6. Datum elevation (DF or KB feet) RKB 50 feet 7. Unit or Property name Point Mclntyre Unit 8. Well number P1-17 9. Permit number / approval number 193-051 10. APl number 50-029-22358 11. Field / Pool Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured true vertical 10532 feet Plugs (measured) 9244 feet PBTD tagged (4/23/1999) @ 10399' MD. Effective depth: measured true vertical 10399 feet Junk (measured) 9112 feet Casing Length Conductor 80' Surface 3796' Production 10477' Size Cemented Measured Depth True vertical Depth 20" 280 cubic ft AS 80' 80' 10-3/4" 2385 cubic ft PFE & 406 cubic tt 3846' 3574' Class G 7-5/8" 633 cubic ft Class G 10518' 9230' ORIGINAL Perforation depth: measured 9984' - 10004'; 10012' - 10022'; 10046' - 10079'; 10094' - 10169'; 10185' - 10344'. true vertical 8697' - 8717'; 8725' - 8735'; 8759' - 8792'; 8807' - 8882'; 8898' - 9057'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) JUL t 2 2000 4-1/2", 12.6#, 13-CR80 Tbg @ 9504' MD. 7-5/8" X 4-1/2" BAKER SABL PACKER @ 9417' MD. 4-1/2" CAMCO TRCF-4A SSSV, ID=3.812" - LOCKED OPEN (NO WRSSSV INSTALLED)I" @ 2260' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 1765 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 2650 5800 1800 2100 5251 Casing Pressure Tubing Pressure 774 801 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Mike Bi// Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE P1-17 DESCRIPTION OF WORK COMPLETED MARASEAL GEL CRETACEOUS SQUEEZE Date Event Summary 5/22/2000: 5/27/2000: Loaded IA w/110 bbls of 9.45 Brine. FP'd IA w/Crude. Performed a FB Maraseal Gel Squeeze for the purpose of sealing up a casing leak that is in communication w/the Cretaceous Zone @ 7400' MD as follows: MIRU. Opened up IA. Pumped 500 bbls of 70° F KCL Water w/corrosion inhibitor for cool down. Pumped 281 bbls of Maraseal Gel, followed by 117 bbls of Brine w/corrosion inhibitor, followed by 13 bbls of Diesel. Placed 216 bbls of Gel behind pipe. RD. Placed well BOL & obtained representative welltest data. Page 1 Re: P 1-17 Cretaceous Leak Subject: Re: Pl-17 Cretaceous Leak Date: Thu, 16 Mar 2000 08:30:48 -0900 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 @mail.aai.arco.com> CC: tom_maunder~admin.state.ak.us 93- cDS"t Jerry, Thanks for the information. Since this is a production well, nothing further is needed at this time. Thanks, Blair PRB Problem Wells wrote: > Blair and/or Tom: ARCO just completed a leak detect log on Pt. Mac well Pl-17. > The well was suspected of T x IA communication, but the leak detect log showed > no leaks in the tubing. A production casing by formation leak was confirmed ~ > between 7400-7500'. The leak zone is detected with a temperature probe in the > tubing while pumping down the IA at a high rate. Our plan is to perform an MITT > on the tubing to verify its integrity before returning it to production. Please > call me or Joe Anders if you have any questions or comments. > Jerry Dethlefs > ARCO Problem Wells 3/16/00 8:31 AM Re: P1-17 Cretaceous Leak-PTD 193-051 Subject: Re: P1-17 Cretaceous Leak-.PTD 193-051 Date: Thu, 16 Mar 2000 07:51:19 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: PRB Problem Wells <P1041@mail.aai.arco.com> CC: Blair_Wondzell@admin.state.ak. us Jerry/Joe: Another one. Your plan sounds good. Keep us informed. Tom Maunder PRB Problem Wells wrote: > Blair and/or Tom: ARCO just completed a leak detect log on Pt. Mac well P1-17. > The well was suspected of T x IA communication, but the leak detect log showed > no leaks in the tubing. A production casing by formation leak was confirmed > between 7400-7500'. The leak zone is detected with a temperature probe in the > tubing while pumping down the IA at a high rate. Our plan isto perform an MITT > on the tubing to verify its integrity before returning it to production. Please > call me or Joe Anders if you have any questions or comments. > Jerry Dethlefs > ARCO Problem Wells Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission . A~. 3/16/00 7:51 AM PERMIT 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 93-051 DATA 5673 5674 5744 DRY DITCH DRY DITCH 407 DWOP FINAL WELL SURVEY SURVEY BD-GR BHP CBT DATA FRAC DLL/GR/SP DPR/GR DPR/GR EPT MUD (FEL) MUD (FEL) NGT NP/DP/DPR/GR NP/DP/DPR/GR >-~- AOGCC Individual Well Geological Materials Inventory T DATA_PLUS ~9743-10530 SGR/SDN/CNTG ~ 7738-10465 DLL/CN/ZDL/GR ~" 9421-10533 DPR/NP/DP/GR ST#I LS 7600-10520 SS#876 ~ 10520-10532 SS#876 LR~COMP DATE:05/17/93 [.-R~'64/03-04/23/93 ~a 04/12-04/16/93 ,LR 0-10433 BAKER HUGHES MWD ~4~ 0-10433 BAKER HUGHES MWD ~/R 0-10433 BAKER HUGHES MWD ~ 9420-10519 MD C/L 7738-10438 t/ZL 9200-10413 L 9700-10250 77 - 0 6s TVD 7600- 0 0 % 7800- 0 C/L 7800-10532 TVD L~ 9746-10519 9420-10519 TVD ~L 9420-10519 MD NP/DP/GR NP/DP/GR PERF PERF ~-L 9420-10519 MD ~L 9420-10519 TVD L 9860-10100 ~L 9600-10250 Page · 1 Date: 01/13/95 RUN DATE_RECVD 1 06/17/1993 1 06/17/1993 5,5rr 08/23/1993 04/28/1993 04/28/1993 06/09/1993 06/09/1993 11/19/1993 06/09/1993 10/14/1993 5-5rr 08/23/1993 1 06/17/1993 1 06/17/1993 1 12/06/1993 1 06/17/1993 5-5rr 08/23/1993 5-5rr 08/23/1993 1 11/19/1993 1 11/19/1993 1 11/19/1993 1 06/17/1993 5-5rr 08/23/1993 5-5rr 08/23/1993 5-5rr 08/23/1993 5-5rr 08/23/1993 1 06/17/1993 1 12/06/1993 __ AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS Page- 2 Date: 01/13/95 RUN DATE_RECVD 93-051 PERF ~ 9600-10370 1 PRESSURE DATA L ~6500-9250 93-05i 1 / 93-051 PROD ~L 9850-10380 1 ~/~ 9746-i0519 ~% 7738-10465 MD t.~ 7738-10438 C~SEE BAKER HUGHES SURVEY 93-051 SDPORO/CN/LD 93-051 SSTVD 93-051 ZDL/CNL/GR 93-051 SURVEY 93-051 SURVEY 93-051 SURVEY SEE BAKER-HUGHES SURVEYS ~D~SEE BAKER-HUGHES SURVEY 12/06/1993 11/19/1993 04/19/1994 06/17/1993 06/17/1993 06/17/1993 06/17/1993 11/19/1993 11/19/1993 Are dry ditch samples required? yes ~no~ And receiv~ yes no Was the well cored? yes Analysis & description receiv yes no Are wel~ tests required? yes ~ Received? ~~ no Well is in compliance ~ Initia 1 COMMENTS Date: Subject: From: To: ----,. ARCO Alaska Inc. Great~. Point Mclntyre Engineering April 19, 1994 Transmittal Number ARCO Alaska, Inc. Bob Cranda11 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 720 ';he following and your cooperation in maintaining confidentiality is appreciated: NK-26 FINAL DISKETTE: MWD w/Sub-Surface 3-17-94 qt~_,c~ Directional Survey "/FINAL LOG: Production Profile 1 3-7-94 P1-17 Greater Point McIntyre Area data are enclosed. This information is confidential ,/ Pl'-21 'FINAL LOG: Per£ Record 3 3/8" HSD - 6 SPF 1 2/5/94 P2-06 P2-06 P2-06 P2-12' 72-12 72-15 72-15 72-15 ~-~AL LOG: Perforation Record 2 1/8" Phased 1 Enerjet ~'/~AL LOG: Static Pressure Survey 1 Press-Temp-Gr/CCL ~FI2~AL DISKE~: GCT -Surface 1 w/SuJ Directional Survey ~ ~( ~/'INAL LOG: Perf Record 3 3/8" H~, 6 SPF I ./ "'FINAL LOG: Static Pressure Survey 1 Press-Temp-Gr/CCL /__ ~'i~INAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver 1 1/30/94 1/31/94 Anadrill Schlumberger Schlumberger Schlumberger V/FINAL LOG: Sub-Sea Vertical Depth (MWD 1 Directional Survey) V~FINAL LOG: Borehole Profile I Schlumberger 1-7-94 Schlumberger d/FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper 1/29/94 ~2-15 1/29194 Schlumberger Schlumberger 3-5-94 Atlas 3-5-94 Atlas 3-5-94 1 3-5-94 Atlas Wireline Atlas xN%& ~,bx, " Well Name P2-15 P2-15 P2-15 P2-15 P2-15 P2-16 P2-16 P2-23 qq.O~2. P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 Data Description "F/INAL LOG: Dual Induction Focused Log GR/SP Run # 1 FINAL DIS~I<o~.,~: MWD Survey w/LIS Ver 1 v/~INAL LOG: Cement Evaluation (CET-GR) 1 V~FINAL LOG: Cement Bond Log (CBT-GR) '--FINAL DISKETTE: GCT w/Sub-surface Directional Survey LIS Ver INAL LOG: Perforating Depth Control 1 Powered Gun GR '~AL LOG: Perforation Record 3 3/8"HJ II, 6 1 SPF V/FINAL DIS~K~MWD Survey w/LIS Ver W'FINAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver 1 '/FINAL LOG: Borehole Profile W~INAL LOG: Sub-Sea Vertical Depth (Directional Drillers Data) d/FINAL LOG: Z-Densflog Comp NEUTRON GR/Caliper v/FINAL LOG: Dual Induction Focused Log 1 GR/SP {- "J~INAL DISKETTE:v ~ Survey w/LIS Ver M~INAL DISKETTE: Electronic Multi-shot Survey w/LIS Ver A~w,'FINAL LOG: Cement Evaluation Log (CET-GR) Date Run 3-5-94 3-9-94 3-26-94 3-26-94 3-26-94 1/26/94 1/27/94 3-23-94 2/12/94 2-12-94 2-12-94 2-12-94 2-12-94 2-10-94 2-10-94 3-25-94 Company Atlas Sperry Sun Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Sperry-Sun ATLAS Atlas Atlas Atlas Atlas Sperry-Sun Sperry Sun Schlumberger Transmittal Number: 720 Page: 2 Well Name. P2-29 P2-29 P2-30 P2-30 P2-30 Data Description Vf~AL LOG: Cement Bond Log (CBT-GR) "/FINAL DISKETTE: _Sub_,S~rface Directional Survey (GCT) ~ "/FINAL TAPE: CH Edit 3 Pass CNT-G with Average Pass w/Ver List d/FINAL TAPE: CH Edit TDTP 3 Passes and Average w/Ver List LOC..' e_ ~O'r'- ~ / ~ FINAL LOG: TDTP Depth Corrected Run # 1 Date Run 3-25-94 3-20-94 1-8-94 1-8-94 12-8-93 Comp,.any Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P2-31 P2-31 P2-31 P2-31 P2-31 P2-31 P2-42 P2-42 P2-42 P2-42 P2-42 FINAL DISKETTE: MWD w/Sub-Surface Directional Survey f-~d 5FzSAL. v~D~7.~TTE: Electronic MultiShot w/LIS FINAL LOG: Sub Sea VD (Multi-shot Directional Survey) V/FINAL LOG: Dual Laterolog/GR/SP FINALLOG: Borehole Profile FINAL LOG: Z-Densilog/CompNeutron/GR/Caiiper · /~AL LOG: Dual Induction Focused Log/GR/SP '/'FINAL LOG: Formation Multi-Tester/GR ~FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) V/FINAL LOG: Z-Densilog/Compensated Neutron/GR/Caliper /FINAL LOG: Borehole Profile 04-08-94 4-10-94 4-10-94 4-10-94 4-10-94 4-10-94 1/9/94 119194 1/9/94 119194 1/9/94 Sperry Sun Sperry Sun Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Atlas Atlas Atlas Atlas l'ransmittal Number: 720 Page: 3 Well Name Data Description / P2-42 '/FINAL DISKETTE: M~D Survey w/LIS Vet P2-51 W/FINAL LOG: TDTP Depth Corrected P2-51 :~~AL T~E: CH Edit 3 Pass ~~ w/Average P~ss w/Vet List / P2-51 ~INAL TAPE: CH Edit 3 Pass CNTG and Average w/Vet List P2-57 ~AL LOG: 2.5" C~'~Depth Corrected P2-57 F~AL T~E: CH Edit 2.5 C~-D 3 passes w/Average w/Ver List Run # Date Run Company 1/8/94 Sperry-Sun 1-11-94 1-11-94 Schlumberger Schlumberger 1-11-94 Schlumberger 11-14-93 11-14-93 Schlumberger Schlumberger Please sign ~ ~P~ and return to: Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal Number: 720 Page: 4 Date: Subject: From: ARCO Alaska, Inc. Lisburne/Point Mclntyre Engineering December 2, 1993 Transmittal #367 ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are endosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Well Log ',,!7 1 blueline 1 sepia I~Z~)-- l~7~L~ 5" ~ P1-01 Perforation Record 2-1/~'' BH ENERJET -'6'? P1-05 -'Static Pressure Survey ~tPRESS/TEMP/GR/CCL) ..~. /I"I-(]~ff~VLWD Very'Enhanced Resistivity CDR ~qqrl°a~'crn~F~'' .2 ~-'~I~V'LWD True Vertical Depth CDR. ~tq- ,0, % ~ ~crnt~ '/Perforation Record 3~/e" HSD -4lB ']~0o-to7.-50 ~ s" 1 '"Perforation Record 3-%~"HSD-4lB ~0o--.10~% ~" 1 ,.'Data Frac Log 'Y/0o--t~zSo~ 5" 1 ~'Cement Evaluation Log (CET-GR) '~vo-~zs, 5" 1 ,'Cement Bond Log (CBT-GR) 3~0-10q0v s" 1 vCement Evaluation Log (CET-GR) ~TZ-~z~0~ ~" 1 Pl-17 ?~ Pl-17 Pl-17 -~!P2-16 ' ~P2-16 Run # Run Date Company 1 11/3-4/93 Schlum~ 7/18-28/93 7/'i8-28/93 n/26/93 11129193 11107/93 o/24/93 o/24/93 10/24/93 ~P2-46 7~P2-57 P2-57 P2-60 P2-60 P2-60 \! ./Cement Bond Log (CBT-GR) ~tTz-~22S', s" 1 10/24/93 /2~tatic Bottou-d,ole Sux-v:y (FRESS/TEM-F/G~)~m-~o i, ~!~i93 eCompensated Neuron Log (2.5" CNT-D/~) q~-~q~: s, ._ '11/14/~3 ~Perforafion Record (~/~Gun-41B ~) 1 11/14(,93 ~afic Press~e s~ey ~SS/~~/GR/CCL)~Zz~I 11Z~8/93 ~efforafion Record ~/~' -41B ~ I~U~5~ ~, 5"1 1~/14/93 PLEASE SIGN ONE COPY AND RETURN Transmittal #367 (AOGCC) Page 2 Well Tape/Diskette w/ver~cation o~ '~ ~2.% -'\°~"~ Run # Run Date Company P14~T#1 C~M3~Data in 2 ST Bit Runs (w/Orig. Well) 4* ! 7/18/93_ Sd~um~ Pl-16 Dual' PropResis/Neu/Dens/GR -DePth Shifted°~ P1-21 Dual PropResis/Neu/Dens/GR-Depth Shifted~ 3-~ P2-12 Final MWD ~.~v,i.~'c,b~,,, - 8/31/93 Schlm~ P2-16 DIFL/GR, CN/ZDL/GR (LDW~ Tape & DiskV~ette) - , 9/13/93 Atlas P2-16 Final MWD ~t~K +c~_ oH --~ ff~zq 7~SO-IOS~_o 9/11/93 Schlum~ P2-46 0R DIFL/CN/ZDL/GR (LDWG Ta~e & Disk~ette) ,u5 - 9/27/93 Atlas P2-46 Final MWD k'~k s~(~ ~' cl~%~c 5q2,2, u~S-qz=t8' - 9/26/93 Schlum~ Please sign ~~. ~~~-~ and return to: · Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #367 .4,d?,,. ,,_ PLEASE SIGN ONE COPY AND RETURN STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. lype of Hequest: Abandon Suspend Alter casing__ Repair well__ Change approved program 2. Name of Operator ARCO ALASKA INC. 3. Address P.O. BOX 100360 ANCH. AK 99510 Operation shutdown Re-enter suspended well~ Plugging__ Time extension__ Stimulate X Pull tubing.__ Variance Perforate__ __ Other 5. Type of Well: Development__X__ Exploratory__ Stratigraphic Service 4. Location of well at surface 1399' NSL, 866' WEL, Sec. 16, T12N, R14E At top of productive interval 291' SNL, 1136' EWL, Sec. 15, T12N, R14E At effective depth 291' SNL, 1136' EWL, Sec. 15, T12N, R14E At total depth 280' SNL, 1163' EWL, Sec. 15, T12N, R14E Datum elevation (DF or KB) RKB 50' feet 7. Unit or Property name Point Mclntyre 8. Well number P1-17 9. Permit number 93-51 10. APl number 50-029-22358 11. Field/Pool Point Mclntyre 12. Present well condition summary Total depth: measureo 10532' true vertical 9243' feet feet Plugs (measured) None Effective depth: measured 9934' true vertical 8647' feet feet Junk (measured) None Casing Length Size Conductor 80' 20" 3876' 10-3/4" Surface Cemented Measured depth True vertical depth 280 cu ft Arcticset 110' 110' 2385 cu ft PF "E" & 406 cu ft G 3846' 3574' Production Liner 10548' 7-5/8" 633 cu ft Class 'G' 10518' Perforation depth: Measured Depth 9984 - 10004' True Vertical Depth 8647 - 8667' Tubing (size, grade, and measured depth) 4 1/2 12.6 # 13CR-80 @ 9505' md Packers and SSSV (type and measured depth) SABL Pkr @ 9433' md, TRCF-4A SSSV @ 2260' md 9230' RECEIVED OCT 2 9 199, Alaska 0ii & Gas Cons. 0ornmissto~' Anchorage 13. Attachments Description summary of proposal Detailed operations program BOP sketch_ ~Y~, , 14. Estimated date for commencing operation November 01, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¥ Signed / '--,/04~~ ./ T.E. Krawietz Title: Sr. Operation Enqr. ATO 484 FOR COMMISSION USE ONLY Date 10/27/93 Conditions of approval: Notify Commission so representative my witness '1 Approval No. ~' ~ - ,,~ ~ ~" Plug integrity BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 1.0- ~Or-~ Approved Returned //. ~.- ?.:~ OrJgina! $;gned /3y Commissioner "'-' "Date Approved by order of the Commission David W. uohn~ton'" Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Point McIntyre P1-17 Stimulation Procedure 1, 2, 3, RU E-line and pumping equipment. Run base GR-TS. Perform data frac on Kuparuk 9,984 - 10,004' with 715 bbls of 2% KcL and 128 bbls of 40 pptg gelled water. Run GR-TS. RD E-line. Hydraulically fracture Kuparuk 9,984- 10,004' down 4 1/2" production tubing with the following fluids. Maximum treating pressure is 9,500 psig. 421 bbls 40 pptg gelled water. 45,344 lbs proppant. RD stimulation company. Estimated Static BHP = 4,350 psig at 8,600' ss. RECEI¥ . Alaska Oil & Gas f3ons. Anchorage WIRELINE BOP EQUIPMENT i i i jli, i IiI,, ,~1 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK OFF Date: Subject: From: October 13, 1993 Transmittal /$359 ARCO Alaska Inc. ARCO Alaska, Inc. L~sburne/Point McIntyre Engineerk~, To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidemial and your cooperation in maintaining confidentiality is appreciated. Log Well Title P1-04 Completion Record, Perforation HSD 6 sfp 33/8" P1-05 Perforating Record 3 %8" HSD 41B HJ II RDX- P1-05 P1-05 P1-05 P1-08 P1-08 Pl-08 Pl-08 Perforating Record 33/8" HSD 4lB HJ II RDX-- 5" Perforating Record 3%8" HSD 4lB HJ II RDX- 5", Perforating .Record 3%a"ZISD 4lB HJ II RDX" 5"~ Perforating Record 3%8" HSD 4lB ~ II RDX Integrated Formation Idog ~)~ c0°~- loevo~{~ ,;" . Integrated Formation Log..~) (065z.--~772.'~ .~" - Engineering Parameters ~ 2."~ t~co--lOo~o' - Pressure Data Log -MD lu ~ ~ - ~?~6' - Run # 'Run Date Company 1 8/19/93 Schlumberger. 11 z~0'' 8/23/93 Schlumberger 1 ~ '~ 8/30/93 Schlumberger 1~i-~8/31/93 Schlumberger 1~,.~9/01/93 Schlumberger 1 ,,47--" 9/02/93 Schlumberger 7/19-24/93 7/19-24/93 7/19-24/93 7/19-24/93 Exlog Exlog Exlog Integrated Formation Log ~2", ~-/o-~o~' _ Integrated Formation Log <~)~"~ O,~O-%?~o* _ Engineering Parameters 2~ ~"~ ~tTo-. l~co' . Pressure Data Log-MD !~ 8lz5--~7~~ - 7125-31/93 7/25-31/93 7/25-31/93 7/25-31/93 Exlog Exlog Exlog Exlog Pl-13 P1-13 Pl-13 .Pl-13 Integrated Formation Log Integrated Formation Log Engineering Parameters Pressure Data Log -MD 6/1-11/93 6/1-11/93 6/ -n/93 6/1-11/93 Exlog Exlog Exlog Exlog Pl-17 Pl-17 P1-17 Pl-17 Integrated Formation Log 4~ ,,2'~, 7~o-iog~Z - Integrated Formation Log-~)~ ~ 7~soO-~v53z En~~r~g Par~eters ~ ~", 7~- i~ - Press~e Data Log -MD ~" PLEASE SIGN ONE COPY AND 4/12-16/93 4/12-16/93 4/12-16/93 4/12-16/93 RE~URN Exlog , Exlog Exlog Exlog Date: Subject: From: ARCO Alaska, Inc. ,~isburne/Point McIntyre Engineering November 17, 1993 Transmittal #361 ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 Enclosed are sepias for the following Point McIntyre logs. These sepias were erroneously omitted from Transmittal #359, sent 10/13/93. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title Run St Run Date Company 1 sepia P1-04 Completion Record, Perforation HSD 6 sfp 3%8" 1 8/19/93 Schlumberger )P1-05 [P1-05 IP1-05 ~P1-05 ~/'Perforating Record 33/8" HSD 4lB HI 11 RDX 1 ~/Perforating Record 3%8" HSD 4lB HI 11 RDX 1 ,w'Perforating .Record 33/s'' HSD 4lB I-If II RDX1 vlSerforating Record 3%8" HSD 4lB HJ II RDX 1 v'Perforating Record 3%s" HSD 4lB HJ II RDX 1 8123193 8/30/93 · 8/31/93 9/01/93 9/02/93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Pl-08 Pl-08 Pl-08 Pl-08 ,,/~tegrated Formation Log-MD v/Integrated Formation Log-TVD ,/Engineering Parameters-MD w'Pressure Data Log-MD 7/19-24/93 7/19-24/93 7/19-24/93 7/19-24/93 Exlog Exlog Exlog Exlog ~/P1-08STI' Integrated Formation Log -MD xZPl-t38STI Integrated Formation Log-TVD w'P1-08ST1 Engineering Parameters-MD ~P1-08ST1 Pressure Data Log-MD · - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 . Exlog Exlog Exlog Exlog I PI-13 ,/'Integrated Formation Log-MD c~'~ ~ Pl-13 V' Integrated Formation Log -TVD ~Pl-13 v'Engineering Parameters -MD /Pl-13 w'Pressure Data Log-MD' 611-11/93 6/1-11/93 6/1-11/93 6/1-11/93 Exlog Exlog Exlog Exlog ;Pl-17 v/Integrated Formation Log-MD Pl-17 v/Integrated Formation Log-TVD Pl-17 v/ Engineering Parameters -MD Pl-17 w"Pressure Data Log-MD - 4/12-16/93 - 4/12-16/93 - 4/12-16/93 - 4/12-16/93 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Transm/ttal t¢359 (AC)GCC) "~-- Page 2 Log Well Tide 1blue line P1-21 ~tegrated Formation Log ~- P1-21 ~tegrated Formation Log -(~/ P1-21 Engineering Parameters ~ - Run # Run Date Company 4/30-5/5/93 Exlog ~--[t~%5', .7" -- 4/30-5/5/93 Exlog ~:~oo- II 57-5/, 4/30-5/5/93 Exlog ~"; P1-21 Pressure Data Log -MD`'/- 4/30-5/5/93 Exlog ~" ~az:z~ .- ~' 'P2-06 Z-Densilog/Cmpnstd ~~ON/GR/C~iper ~ ~5") ~oo - 8/17/93 Atlas P2-06 Du~ Laterolog/G~a Ray/SP ' 1 8/17/93 Atlas ~5'~ P2-06 Sub-Sea Verdc~ Depth (S~gle Shot Data)%1 8/17/93 Atlas P2-06 Borehole Profile 1 8/17/93 Atlas ~ ~2t' ~ tq0~- ~ 5"~ Itq~a-ttqS~ ~ ~a~0~9/13/931o~ Atlas P2-16 Z-Densflog/Cmpnstd ~~ON/GR/C~per/F2-- P2-16 Du~ ~ducfion Fo~sed Log/G~a Ray 1 9/13/93 Atlas ~-16 Sub-~a Vertical Dep~ (M~fi Shot Data) 1 9/13/93 Atlas P2-16 Borehole Profile I 9/13/93 Atlas P2~ Z-Densflog/Cmpnsta ~~ON/CR/Caiper 2¢'~' ~b9T=39~**s' Atlas P2~ Du~ ~ducfion Fomsed Log/G~ma Ray I 9/~/93 Atlas P2~ Sub-Sea Verfic~ Depth (Dire~on~ Drlg Data) N I 9/~/93 Atlas P2~ Borehole Profile 1 9/~/93 Atlas ~> le~',, ~o- Diskeffe~a~e (w/ve~ication 1~~) Well Tire ~ ~ R~ Date Company GCT ~skeff~om~iete C~c.¢ ~ 7/~/93 Sc~umbe~ge~ GCT ~skeff~Com~iete C~c.~ ~ 8/~2/~ Sc~umbe~ge~ CDN/CDR ~D Data ~ 1 Bit R~ (O~ E~t)~~ ~ ~~/~~Schlumbe~ge~ P1-04 P1-05 P1-05 P1-05 ~'q~ iPi_08 IP1-13 %-7q IPl-13 %- 5~ I Pl-17 rP2-06 P2-06 CDN/CDR in 3 Bit Runs (O__~H Edi0 CDR/GR'Oay m 5 Bit R~ (OH DuM ~op Res~/D~siW/Neu2on/GR w/~s~g 5-7 CDN/CDR ~ 3 Bit R~s (O~ DLL/~/ZDL/GR ~ LDWG Fo~at w/~s~g 1 6/27/93 7/13/93 7/24/93 6/6/93 6/07/93 4/16/93 4/16/93 8/17/93 8/17/93 8/17/93 Schlumberger Schlumberger Schlumberger Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Schlumberger Arias PLEASE SIGN ONE COPY AND RETURN Transmittal ,9361 (AOGCC) Page 2 Log Well Title 1 sepia }P1-21 ,,/Integrated Formation Log -MD ~o~/P1-21 V' .Integrated Formation Log-TVD P1-21 ~Engineering Parameters -MD P1-21 /Pressure Data Log-MD P2-06 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-06 x/Dual Laterolog/Gamma Ray/SP 1 P2-06 v/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 w/Borehole Profile 1 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper P2-16 w'Dual Induction Focused Log/Gamma Ray P2-16 x/Sub-Sea Vertical Depth (Multi Shot Data) P2-16 ~/Borehole Profile P2-46 P2-46 P2-46 P2-46 d'Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 v/Dual Induction Focused Log/Gamma Ray 1 ,/Sub-Sea Vertical Depth (Directional Drlg Data) 1 dq3orehole Profile 1 Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9127193 9/27/93 9127193 9127193 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. · P.O, BOX 100360 Anchorage, Alaska 99510-0360 Transmittal //361 RECEIVED NOV 79 1993 ~Jaska 0il & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal ~361 (AOGCC) Page 2 Lo§ Well Title 1 sepia P1-21 ~/Integrated Formation Log-MD P1-21 V' Integrated Formation Log-TVD P1-21 fEngineering Parameters -MD P1-21 dPressure Data Log-MD P2-06 v'Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-06 ~/Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 ,//Borehole Profile 1 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-16 v'Dual Induction Focused Log/Gamma Ray 1 P2-16 ,./Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 ~/BorehOle Profile 1 P2-46 P2-46 P2-46 P2-46 d'Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 v/Dual Induction Focused Log/Gamma Ray 1 ~/Sub-Sea Vertical Depth (Directional Drlg Data) 1 ./Borehole Profile 1 Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9/27/93 9/27/93 9/27/93 9/27/93 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #361 RECEIVED IVOV 79 1993 'Alaska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #359 (AOGCC) Page 3 Report Well P1-04 P1-05 P1-08 Pl-13 Pl-17 P1-21 Title Sub-Surface Directional Survey (2 copies)v/ Sub-Surface Directional Survey (2 copies) Final Well Report ~' Final Well Report~" Final Well Report,-' Final Well Report~, Date 7/28/93 8/12/93 7119-811/93 6/1-11/93 4/12-16/93 4/30-5/5/93 Company Schlumberger Schlumberger Exlog Exlog Exlog Exlog Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 ' Anchorage, Alaska 99510-0360 12- 5 Please note: The Exlog blueline logs are located within the Final Well Report binders. Transmittal #359 PLEASE SIGN ONE COPY AND RETURN ARCO Alaska, Inc. ~sburne/Point McIntyre Engineez Date: Subject: From: To: August 19, 1993 Transmittal #350 ARCO Alaska Inc. Bob Crandall AC)GCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point Mclntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title 1blue line, 1 sepia P1-Gl-'Perforating Record Run # 1 Run Date 7/4/93 Company Schlumberger P1-04 'Z-Densilog Compensated Neutron -GR P1-04-Dual Laterolog, GR / SP ,k'vSt' P1-04- Borehole Profile ~°' P1-04- Sub-Sea Vertical Depth (Single Shot Data) g-pt" P1-04-Cement Bond Log '* P1-04-"Cement Evaluation Log (CET) 2~1-04--Gyro Continuous Survey (GCT) I 5/22/93 Altas I 5/22/93 Atlas 1 5/22/93 Atlas I 5/22/93 Arias 1 6/12/93 Schlumberger 1 6/12/93 Schlumberger 1 7/28/93 Schlumberger P1-05-Segmented Bond Log, Gamma Ray-CCL P1-05-, Cement Bond Log-CBT w/Jewelry P1-05-' Cement Evaluation Log-CET w/Jewelry P1-05- Gyro Continuous Survey -GCT 1 7/11/93 1 8/12/93 I 8/12/93 1 8/12/93 Atlas Schlumberger Schlumberger Schlumberger P1-13-'Neutron Poro, Density Poro, GR -MD P1-13-Neutron Poro, Density Poro, GR -TVD Pl-13 -- Dual Prop Resis, GR -MD Pl-13 WDual Prop Resis, GR -TVD 5-7 6/2-6/93 5-7 6/2-6/93 5-7 6/2-6/93 5-7 6/2-6/93 P1-13-Dens Poro, Neu Poro, Dual Prop Resis, GR-MD 5-7~c~ 6/2-6/93 Pl-13 ~'Dens Poro, Neu Poro, Dual Prop Resis, GR-TVD 5-7 . 0/2-6/93 Pl-13 wBulk Density, Gamma Ray-MD 5" 5-7 6/2-6/93 BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes P1-14- Engineering Parameters P1-14- Pressure Data Log Pl-14--Formation Evaluation MD P1-14-Formation Evaluation TVD - 2/26-3/6/93 - 2/26-3/6/93 - 2/26-3/6/93 - 2/26-3/6/93 Exlog Exlog BakerHughes BakerHughes PLEASE SIGN ONE COPY AND RETURN Transmittal #350 (AOGCC) Log (contd.) Well Title 1blue line, 1 sepia IPl-16 -' Engineering Parameters MD ~- P1-16 '~ Pressure Data Log Pl-16--Formation Evaluation MD Pl-16,.-Formation Evaluation TVD Run. # P1-17-' Bulk Density -Gamma Ray -MD Pl-17---Dual Prop Resis -GR-MD 21'5" Pl-17-'Dual Prop Resis -GR-TVD 24'5 Pl-17--'Dens Poro, Neutron Poro -GR-MD P1-17- Dens Poro, Neutron Poro -GR 5,5RR 5,5RR 5,SRR 5,5RR 5,SRR Pl-17-'E~sPoro, NeuPoro, DualProp, Resis-(~-MD :~X~" 5,SRR IP1-17 - EPms Poro, Neu Poro, Dual Prop, Resis-GR -TVD .leS" 5,SRR Run Date - 3/19-28/93 - 3/1%28/93 - 3/19-28/93 - 3/19-28/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 4/14-16/93 Page 2 Company Extog Exlog BakerHughes BakerHughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Diskette/Tape (w/verification) Well Title Run # \P1-04 q-,~--'~ ~ P1-13 q'k;Sq, P1-16 Final MWD Survey blc~t. - DLL/CN/ZDL/GR in LDWG Format ~ ~?qt¢ t>t~ 1 · Final MWD Survey bt~~.. - Dual Prop Resis, Neutron, Density, GRPr ~7t4~o14 6 q:5-Sk P1-17 Dual Prop Resis, Neu, Dens, GR-Depth Shifted 5~-RR Run Date 5/24/93 5/22/93 6/11/93 3/29/93 4/16/93 Company BakerHughes Atlas Sperry Sun BakerHughes BakerHughes Please sign ___ and return to: Transmittal #350 Laura S. Lahrson, ATC)-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN ARCO Alaska, Inc. Lisburne/Point Mclntyre Engineering Date: June 15, 1993 Subject: Transmittal #333, P1-17 From: ARCO Alaska Inc. To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre Well Pl-17 data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log 1 blue line, 1 sepia v'Z-Densilog Compensated Neutron-Gamma Ray v/Sub-Sea Vertical Depth (Single-Shot Data) V/Dual Laterolog, Gamma Ray/SP ~Borehole Profile v/Simultaneous Dual Porosity- Comper~sated Neutrton Litho Densi'ty ~/Natural Gamma Ray Spectrometry -1,/' Cement Bond Log (CBT) ,/'Perforating Record Run # Run Date Company I 4/16/93 Atlas I 4/16/93 Atlas 1 4/16/93 Atlas 1 4/16/93 Atlas 4/~//70 Schlumberger 1 4/17/93 Schlumberger 1 5/13/93 Schlumberger 1 5/16/93 Schlumberger TAPE/DISKETTE w/printout Run # ~"Finai MWD Survey (._~ ') - ,,/DLL/CN/ZDL/GR in LDWG format ~ ~~c/~ o~t 1 ~'~OH~dit: SGR/SDN/CNTG in LDWG format ~?~ I Run Date Company 4/16/93 Baker Hughes 4/16/93 Atlas 4/17/93 Schlumberger Please si gn_~~_~.~_~T& a n d r e t urn to: Transmittal #333 PLEASE SIGN ONE RECEIVE.D Laura S. Lahrson, ATO~a ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska .-~la~a Oil & COPY AND RETURN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMivllSSION INr::! I CO.P! I::TION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classitication of Service Well OIL [] GAS [] SUSPEkDED [] ABANDONED [] SERVICE [] x ComDleted 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-51 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22358 4. Location of well at surface 9. Unit or Lease Name ~ COMPLET!ON ~: 1399' NSL, 866' WEL, SEC. 16, T12N, R14E t LlATE ,,, i : :,,:':,C..- ,'"~. ,ut ~ Point Mclntyre At Top Producing Interval ! "~/~'~- !{ VERiFiED i '. ~-,~_~:-.,i ';'I 10.p1.17Well Number 291' SNL, 1136' EWL, SEC. 15, T12N, R14E ';~ 11 Field and Pool At Total Depth ...... ~i. Point Mclnt~re 280' SNL, 1163' EWL, SEC. 15, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 50' I ADL 28297 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. o~ Aband. 115. Water Depth, if oflshore 116. No. of Completions 4/3/93 4/17/93 5/17/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey FO. Depth where SSSV set Fl. Thickness of Permafrost 10532' MD/9243' TVD 10440' MD/9152' TVD YES E] N3 []! 2265' feet MD ! 1750' (Approx.) 22. Type Electric or Otha' Logs Run Run #1 GR/RES/NEUTRON/DEN, Run #2 LDT/CNL/MCT, Run ~3 ClBL 23. CASING, LINER AND CEMENTING RECORD SETtiNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surface 80' 26" 280 cu ft Arcticset 10-3/4" 45.5# J-55 41' 3846' 13-1/2" 2385 cu ft PF "E"/406 cu ft "G" 7-5/8~' 29.7# NT95HS 41' 9424' 9-7/8" 7-5/8" 29.7# 13CR 9424' 10518' 9-7/8" 633 cu ft 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) Gun Diameter 3-3/8" 6 spf 4-1/2", 13CR 9505' 9433' MD TVD 9984'- 10004' 8647'-8667' _)6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protected to 2300' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not yet on production I N/A Date of Test Hours Tested ~RODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED ^iask~ Oil & Bas 6oBs. Anch0rag~ .... Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate , , 30. GEOLOGIC MARKERS r-~.~r,MATION TESTS , , NAME .... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea West Sak 7855' 6645' Kalubik 9898' 8568' Kuparuk 9918' 8598' R'EEEIVED Alaska Oil & Gas Cons. Commission 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best ot my knowledge ~/'~~ ~ ~' ~d/),~.~. ~ Dr illino Eno in ocr Suoe rvisor Date 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 PRUDHOE BAY DRILLING GROUP POINT MCINTYRE Pl-17/F7 NORTH SLOPE, ALASKA BIT DATA EECOED ~ ~ EUN ,' Bit ,' MFE ,' TYPE ', SIZE { IADC I JET I STAET { DEILLED ,' AVH ,' WOB ,' EPM ,' PUMP ,' SPM/HPM ,' BIT ' ~OP lllO001 I P~ESSI ICOND ' { ' ' ' ' CODE I SIZE I DEPTH I FT I H~S , t I I I I { ' ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... ' 3X16 ' 80' I 3780 : I4,51 261 ' ' ' ' ' I I 1 {SECURITY1 SG210 I 13,500"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 t I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... ' __I3X12,1XI61 3780' ' ' ' ' ' ' 2 ' SMITH I MFDSHCL I 9 875", { LOST IN HOLE I I ' I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... 3 I 3 I SMITH I MFDSHCL I 9,875"I 13XI2,1XI6{ 4200' I 3144'{ 14,5{ 217 130-451 215 I 3000 I 140/600 ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... 4 ,' 4 ISECUEITYI S82FJ4 ,' 9,875"', ,'3X12,1X18{ 7344' ,' 2134' 1 35,5{ 60,1 ,'30-801 215', 3000 ' 140/600 {, ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... 5 I 5 ,' SMITH I FtCL I 9,875"I ,'3X12,1118', 9479' ,' 1041' { 22,31 46,7 , ' 5-50', 215 { 3200 I 140/800 1 ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... 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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 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 I I I I i I I I 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 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 I l 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 I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: Pl-17 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/02/93 08:00 SPUD: 04/03/93 04:30 RELEASE: 04/22/93 12:00 OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 04/03/93 (1) TD: 300'( 0) 04/04/93 (2) TD: 1470' (1170) 04/05/93 (3) TD: 3860'(2390) 04/06/93 (4) TD: 3860' ( 0) 04/07/93 (5) TD: 3870' ( 10) 04/08/93 (6) TD: 5707' (1837) 04/09/93 ( 7) TD: 5707' ( 0) 04/10/93 ( 8) TD: 4233' ( 0) DRLG. MW: 8.5 VIS: 0 MOVE IRG. RIG ACCEPTED @ 20:00 HRS, 4/2/93. N/U DIVERTER. TEST SAME. OK. M/U BHA. SPUD WELL @ 04:30 HRS, 4/3/93. DRLG F/ 112'-300'. DRLG. MW: 9.0 VIS:152 DRLG F/ 300'-636'. CIRC. POOH. RIH. DRLG F/ 636'-666' POOH. RIH. DRLG F/ 666'-1452' CIRC. SHORT TRIP TO 370' DRLG F/ 1452'-1470'. POOH. MW: 9.3 VIS:109 DRLG F/ 1470'-2011'. SHORT TRIP TO 1270' DRLG F/ 2011'-3860'. CIRC. POOH. WAIT ON FMC WELLHEAD. MW: 9.3 VIS: 42 POOH. RIH. REAM F/ 2534'-2721' CIRC. POOH. RIH W/ 10-3/4" CSG. CIRC. PUMP 75 BBLS WATER, 425 BBLS LEAD CMT, 72 BBLS TAIL CMT. DISP. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. TOP JOB W/ 250 SX 'C' PERMAFROST. C/O TO KCL MUD. MW: 8.5 VIS: 48 M/U WELLHEAD. N/U BOPE. TEST BOPE. RIH W/ BIT, BHA. TAG FC @ 3768'. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CBU. LOT. WORK STUCK PIPE. MW: 9.3 VIS: 55 LOT (13.7 PPG EMW). CIRC. DRLG F/ 3870'-4681'. CBU. SHORT TRIP TO SHOE. RIH. DRLG F/ 4681'-5707' CIRC. SHORT TRIP. SWAB F/ 5330'-5147'. PUMP & ROTATE OUT OF HOLE. WORK PIPE TO 5084' MD/4518' TVD. WORK STUCK PIPE. RIH W/ STRING SHOT. MW: 9.2 VIS: 62 WORK STUCK PIPE @ 5084' R/U ATLAS. RIH W/ FREEPOINT. RIH W/ STRING SHOT. BA~KOFF OFF @ 4840' R/D ATLAS. POOH. RIH W/ JARS. SCREW INTO FISH. JAR. R/U ATLAS. RIH W/ STRING SHOT. DRLG. MW: 9.2 VIS: 65 RIH W/ FREEPOINT. RIH W/ STRING SHOT. BACK OFF @ 4443'. CIRC. R/D ATLAS. POOH. RIH W/ BHA. REAM F/ 3846'-4200' START SIDETRACK @ 4200'. DRLG F/ 4200'-4233'. RECEiV£D J UN - 9 199 Alaska 0ii & Gas Cons. Anchorage WELL - Pl-17 OPERATION: RIG : POOL 7 PAGE: 2 04/11/93 ( 9) TD: 7049' (2816) 04/12/93 (10) TD: 7575' ( 526) 04/13/93 (11) TD: 8735' (1160) 04/14/93 (12) TD: 9479' ( 744) DRLG. lvs~: 9.4 VIS: 62 DRLG F/ 4233'-4999'. CBU. SHORT TRIP 8 STDS. DRLG F/ 4999'-6027'. CBU. SHORT TRIP 11 STDS. DRLG F/ 6027'-7049'. DRLG. MW: 9.4 VIS: 63 CBU. SHORT TRIP 11 STDS. DRLG F/ 7049'-7344'. CIRC. POOH. RIH W/ BIT. DRLG F/ 7344'-7575'. DRLG. DRLG F/ 7575'-8354' 8354'-8735'. MW: 9.4 VIS: 56 CBU. SHORT TRIP 11 STDS. DRLG F/ POOH. DRLG F/ 8735'-9479' CIRC. POOH. MW: 9.5 VIS: 61 04/15/93 (13) TD: 9775'( 296) 04/16/93 (14) TD:10520' ( 745) 04/17/93 (15) TD:10520' ( 0) 04/18/93 (16) TD:10520' ( 0) 04/19/93 (17) TD:10532' ( 12) 04/20/93 (18) TD:10532 PB: 0 DRLG. MW: 9.8 VIS: 57 POOH. BACK REAM F/ 8077'-6030' TEST BOPE. CHANGE BIT, BHA. RIH. WASH & REAM TO BTM. DRLG F/ 9479'-9775' CIRC FOR LOGS. MW: 9.9 VIS: 58 DRLG F/ 9775'-10061' MAD LOG RUN F/ 10016'-10061' DRLG F/ 10061'-10520' TD WELL @ 00:30 HRS, 4/16/93. CBU. SHORT TRIP 20 STDS. CBU. RIH. MW: 9.9 VIS: 55 POOH. R/U ATLAS. LOG RUN: GR/RESISTIVITY/NEUTRON/DENSITY. RUN #2 STOPPED @ 7900' R/D ATLAS. RIH W/ BIT, BHA. POOH W/ LOGS. MW: 9.8 VIS: 53 RIH TO 10100' LOG W/ TELECO F/ 10100'-10165' TOOL FAILED. RIH. DRLG F/ 10520'-10532' CIRC. POOH. R/U SWS. LOG RUN: LDT/CNL/MCT. R/U ATLAS. RIH W/ CIBL. POOH. MW: 9.8 VIS: 60 LOG RUN: CIBL. R/D ATLAS. RIH W/ TELECO. LOG F/ 10150'-10532'. CBU. POOH. RIH W/ CSG. MW: 9.8 KC1 POOH. L/D BHA. TEST BOPE. R/U WOTCO. RIH W/ 7-5/8" CSG. R'ECEIVF. D 0il & Bas Coos. Gommission Anchorage WELL : Pl-17 OPERATION: RIG : POOL 7 PAGE: 3 04/21/93 (19) TD:10532 PB: 0 04/22/93 (20) TD:10532 PB:10440 RIH W/ TBG. MW: 8.6 Seawater RIH W/ 7-5/8" CSG. CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS ARCO SPACER, 530 SX 'G' CMT W/ 2% KCL, .9% LAP-l, .45 HALAD-344, .3% E.LITE, .2% CFR-3, .5% HR-5, .01 GPS FDP-434B, .01 GPS DAIR-3. DISP W/ SEAWATER. BUMP PLUG W/ 3000 PSI. INSTALL & TEST PACKOFF. TEST CSG. R/U ATLAS. RIH W/ GR/JB. R/D ATLAS. RIH W/ 4-1/2" 13 CR TBG. PULL CHECK VALVE. MW: 8.6 Seawater RIH W/ 4-1/2" 13 CR TBG. LAND TBG HGR. TT @ 9505', PKR @ 9433'. N/D BOPE. N/U TREE. TEST TREE. R/U LUB. 04/23/93 (21) TD:10532 PB:10440 RIG RELEASED. MW: 8.6 Seawater PULL CHECK VALVE. R/U LUB. PUMP 207 BBLS DIESEL DN TBG TO 2300' DROP BALL. SET PKR. TEST TBG. OK. TEST ANNULUS. OK. SET BPV. SHUT SSSV. SECURE WELL. RIG RELEASED @ 12:00 HRS, 4/22/93. NOTE: EFC RAISED DUE TO STUCK PIPE. SIGNATURE: (drilling superintendent) DATE: R'ECEIVED Alaska Oil & Gas Cons. Commission Anchorage Baker Hughes INTEQ ANCHORAGE, ALASKA Well Name Date Surveyed Survey Performed By : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17~ : NORTH SLOPE, ALASKA : : 04/16/93 : : TOMMY FOSTER/PAUL SMITH ~his survey is correct to the best of my knowledge ~nd is supported by actual field data. Baker Hughes INTEQ Well Name : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17 : NORTH SLOPE, ALASKA : Date 04/16/93 Filename : PMPi-17 No Interpolation Directions Referenced To .Depth at Drill Floor Plane of Vertical Section : 29.4° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft : TRUE NORTH : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.00°WELLSITE North Grid convergence : +0.0000° PRUDHOE BAY DRILLING GROUP +0 ° 0' 0' ' (T) Well Name PRUDHOE BAY PT. McINTYRE NORTH SLOPE, Baker Hughes INTEQ DRILLING Pl-17 ALASKA Page 1 of 3 Date 04/16/93 Filename : PMPi-17 No Interpolation MD CkL INC DIR TVD VS LAT DEP ft ft deg deg ft ft ft ft 0 0 0.0 0.0 0 0 0 0 218 218 0.1 356.3 218 0 0 -0 399 181 0.2 118.3 399 0 0 0 579 180 0.4 88.8 579 1 0 1 759 180 0.4 312.0 759 1 0 1 938 179 0.4 338.1 1116 178 0.4 340.9 1303 187 0.7 321.2 1486 183 1.7 18.5 1580 94 2.8 26.6 1672 92 3.2 34.7 1764 92 3.7 34.7 1858 94 5.6 35.7 1951 93 8.1 29.7 2045 94 10.8 31.1 2136 91 14.3 30.4 2229 93 15.5 33.6 2320 91 18.3 32.9 2412 92 21.4 28.3 2502 90 22.7 28.7 2593 91 25.2 25.2 2686 93 25.9 25.2 2779 93 28.5 26.2 2871 92 29.9 27.6 2964 93 33.5 27.6 3058 94 35.9 28.0 3152 94 37.9 28.3 3244 92 39.2 31.5 3334 90 39.6 29.0 3424 90 39.5 29.0 3518 94 39.5 28.0 3610 92 39.7 28.3 3700 90 40.0 30.4 3803 103 40.5 30.1 3974 171 41.0 27.3 4066 92 41.1 27.6 4160 94 40.8 26.9 4281 121 37.9 29.7 4373 92 37.7 30.4 4747 374 38.6 32.9 D ' LEG BUILD TURN o o °/100 /100 /100 0.0 0.0 0.0 0.0 0.0 -1.7 0.1 0.1 67.4 0.1 0.1 -16.4 0.4 0.0 · -76.0 938 2 1 1 1116 2 3 0 1303 3 4 -1 1486 6 8 -1 1580 10 11 1 , 0. 0. 0. 1. 0.0 14.6 0.0 1.6 0.2 -10.5 0.5 31.3 1.2 8.6 1672 15 15 3 1764 20 20 7 1857 28 26 11 1950 39 35 17 2042 54 49 25 0.6 0.4 8.8 0.5 0.5 0.0 2.0 2.0 1.1 2.8 2.7 -6.5 2.9 2.9 1.5 2131 74 66 35 3. 2221 98 86 47 1. 2308 124 108 62 3. 2395 156 135 78 3. 2478 189 165 94 1. 8 3.8 -0.8 6 1.3 3.4 1 3.1 -0.8 8 3.4 -5.0 5 1.4 0.4 2561 226 197 111 3. 2645 266 234 128 0. 2728 309 272 146 2. 2808 354 312 166 1. 2887 402 355 189 3. 2 2.7 -3.8 8 0.8 0.0 8 2.8 1.1 7 1.5 1.5 9 3.9 0.0 2964 456 403 214 2. 3040 512 452 241 2. 3112 570 502 269 2. 3181 627 551 298 1. 3251 684 602 326 0. 6 2.6 0.4 1 2.1 0.3 6 1.4 3.5 8 0.4 -2.8 1 -0.1 0.0 3323 744 654 354 0. 3394 802 706 382 0. 3463 860 756 410 1. 3542 927 814 444 0. 3671 1038 912 497 1. 0.0 -1.1 0.2 0.3 0.3 2.3 0.5 -0.3 0.3 -1.6 3741 1099 965 525 3812 1160 1020 553 3905 1237 1087 590 3978 1293 1136 618 4272 1524 1333 739 · 0. 2. 0. 0. 2 0.1 0.3 6 -0.3 -0.7 8 -2.4 2.3 5 -0.2 0.8 5 0.2 0.7 Well Name MD ft 5028 5122 5215 5308 5495 5680 5868 6055 6243 6425 6611 6798 6982 7169 7277 7460 7553 7645 7735 7829 7922 8014 8111 8203 8297 8390 8484 8577 8672 8763 8856 8951 9044 9138 9231 9325 9419 9508 9603 9698 CkL ft 281 94 93 93 187 185 188 187 188 182 186 187 184 187 108 183 93 92 90 94 93 92 97 92 94 93 94 93 95 91 93 95 93 94 93 94 94 89 95 95 Baker Hughes PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA INC DIR TVD deg deg ft 39.0 28.3 4491 38.9 28.7 4564 39.2 29.0 4636 39.3 28.7 4708 39.7 29.0 4853 39.9 29.4 4995 40.0 27.3 5139 40.3 27.3 5282 39.8 27.3 5426 39.4 27.3 5566 39.0 27.3 5710 39.0 27.3 5855 39.5 27.3 5998 39.3 26.6 6142 39.2 26.6 6226 36.9 26.2 6370 35.8 26.2 6445 34.9 24.1 6520 33.8 24.5 6594 32.6 25.9 6673 31.3 25.2 6752 30.1 25.5 6831 29.1 24.8 6915 28.1 26.9 6996 26.7 27.3 7080 25.2 29.0 7163 24.0 30.8 7249 22.9 31.8 7334 21.7 33.6 7422 20.3 35.4 7507 19.4 36.1 7594 18.4 39.2 7684 16.9 41.3 7773 15.5 43.4 7863 13.7 44.5 7953 12.2 47.0 8045 10.7 50.1 8137 10.1 50.1 8224 8.9 51.9 8318 6.2 49.1 8412 VS ft 1700 1759 1818 1877 1995 INTEQ Page 2 of 3 Date 04/16/93 Filename : PMPi-17 No Interpolation LAT DEP D' ft ft o/ 1484 829 1536 857 1588 885 1639 914 1743 971 2114 1847 1029 2235 1953 1086 2355 2060 1141 2476 2168 1197 2592 2271 1250 2709 2375 1304 2827 2480 1358 2943 2583 1411 3062 2689 1465 3130 2750 1496 3243 2851 1546 3298. 2901 1570 3351 2949 1593 3401 2995 1614 3453 3042 1636 3502 3086 1657 3549 3128 1677 3597 3172 1697 3640 3211 1717 3684 3250 1736 3724 3286 1755 3763 3320 1775 3800 3351 1794 3836 3382 1814 3869 3409 1832 3900 3434 1850 3931 3459 1869 3958 3480 1887 3984 3499 1905 4007 3516 1921 4027 3531 1936 4045 3543 1950 4060 3554 1963 4074 3564 1975 4086 3572 1985 LEG 100 1.0 0.3 0.4 0.2 0.2 BUILD o/loo 0.1 -0.1 0.3 0.1 0.2 TURN o/loo -1.6 0.4 0.3 -0.3 0.2 .2 .7 .2 .3 .2 0 0 0 -0 -0 .1 .1 .2 .3 .2 0.2 -1.1 0.0 0.0 0.0 .2 .0 .3 .3 .1 -0 0 0 -0 -0 .2 .0 .3 .1 .1 0.0 0.0 0.0 -0.4 0.0 .3 .2 .6 .2 .5 -1 -1 -1 -1 -1 .3 .2 .0 .2 .3 -0.2 0.0 -2.3 0.4 1.5 .5 .3 .1 .5 .5 -1 -1 -1 -1 -1 .4 .3 .0 .1 .5 -0.8 0.3 -0.7 2.3 0.4 .8 .5 .3 .5 .7 -1 -1 -1 -1 -1 .6 .3 .2 .3 .5 1.8 1.9 1.1 1.9 2.0 .0 .5 .8 .6 .0 -1 -1 -1 -1 -1 .0 .1 .6 .5 .9 0.8 3.3 2.3 2.2 1.2 .7 .7 .7 .3 .9 -1 -1 -0 -1 -2 .6 .6 .7 .8 2.7 3.3 0.0 1.9 -2.9 Well Name Baker Hughes PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA MD CkL INC DIR TVD VS ft ft deg deg ft ft 9791 93 6.2 49.8 8505 4095 9885 94 5.4 54.7 8598 4104 9979 94 3.2 66.3 8692 4110 10072 93 2.9 63.1 8785 4114 10167 95 2.9 65.9 8880 4118 10261 94 2.6 64.9 8974 4122 10356 95 2.7 62.8 9069 4125 10443 87 2.7 58.9 9155 4129 INTEQ Page 3 of 3 Date 04/16/93 Filename : PMPi-17 No Interpolation LAT DEP ft ft 3578 1992 3584 2000 3587 2006 3590 2010 3592 2015 D' LEG o/lOO 0.1 1.0 2.5 0.4 0.1 BUILD o/100 0.0 -0.9 -2.3 -0.3 0.0 TURN °/100 0.8 5.2 12.3 -3.4 2.9 3594 2019 0.3 -0.3 -1.1 3595 2023 0.1 0.1 -2.2 3597 2026 0.2 0.0 -4.5 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 4129 ft 29.4° Baker Hughes INTEQ ANCHORAGE, ALASKA Well Name Date Surveyed Survey Performed By : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17 : NORTH SLOPE, ALASKA : : 04/16/93 : : TOMMY FOSTER/PAUL SMITH This survey is correct to the best of my knowledge and is supported by actual field data. ........................... COMPANY REPRESENTATIVE Baker Hughes INTEQ Well Name : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17 : NORTH SLOPE, ALASKA : Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of MD Plane of Vertical Section : 29.4 ° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.00°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) PRUDHOE BAY DRILLING GROUP Well Name Baker Hughes INTEQ PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA Page 1 o f 3 Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of MD MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 100 100 0.0 163.4 200 100 0.1 326.9 300 100 0.1 248.5 400 100 0.2 118.1 5OO 600 700 8O0 900 1000 1100 1200 1300 1400 100 0.3 101.7 100 0.4 114.8 100 0.4 238.8 100 0.4 318.0 100 0.4 332.6 100 100 100 100 100 0.4 339.1 0.4 340.6 0.5 332.1 0.7 321.5 1.2 160.8 1500 100 1.9 19.7 1600 100 2.9 28.4 1700 100 3.4 34.7 1800 100 4.4 35.1 1900 100 6.7 33.0 2000 100 9.5 30.4 2100 100 12.9 30.7 2200 100 15.1 32.6 2300 100 17.7 33.1 2400 100 21.0 28.9 2500 100 22.7 28.7 2600 100 25.3 25.2 2700 100 26.3 25.4 2800 100 28.8 26.5 2900 100 31.0 27.6 3000 100 34.4 27.8 3100 100 36.8 28.1 3200 100 38.6 30.0 3300 100 39.4 29.9 3400 100 39.5 29.0 3500 100 39.5 28.2 3600 100 39.7 28.3 3700 100 40.0 30.4 3800 100 40.5 30.1 3900 100 40.8 28.5 TVD ft 0 100 200 300 400 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1799 1899 1998 2096 2193 2289 2383 2476 2567 2658 2746 2833 2917 2998 3077 3155 3232 3309 3386 3463 3539 3615 VS ft 0 0 0 0 0 7 1i 16 23 33 47 66 91 119 152 189 229 273 319 369 423 481 542 605 669 732 796 86O 925 990 LAT ft 0 0 0 0 0 8 12 16 22 .30 42 59 79 103 131 164 200 240 281 326 374 425 478 533 588 644 700 756 8'12 869 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.0 0.0 99.0 -0 0.1 0.0 99.0 0 0.2 0.1 -78.4 0 0.3 0.1 -99.0 1 0.1 0.1 -16.4 1 0.1 0.1 13.1 1 0.7 0.0 99.0 1 0.5 0.0 79.1 1 0.1 0.0 14.6 0 0 -0 -1 -1 -0 1 4 8 14 0.0 0.0 6.5 0.0 0.0 1.6 0.2 0.1 -8.6 0.2 0.2 -10.5 1.9 0.5 -99.0 2.9 0.6 -99.0 1.1 1.0 8.7 0.6 0.5 6.3 1.1 1.1 0.4 2.3 2.3 -2.1 21 2.8 2.8 -2.6 31 3.4 3.4 0.2 43 2.3 2.2 1.9 59 2.6 2.6 0.5 76 3.6 3.3 -4.2 93 112 130 151 173 1.7 1.7 -0.2 2.9 2.6 -3.5 1.0 1.0 0.2 2.6 2.5 1.2 2.3 2.2 1.1 199 3 .4 3.4 0.2 226 2.4 2.4 0.4 256 2.1 1.8 1.8 287 0.9 0.9 -0.0 318 0.6 0.1 -0.9 349 379 410 443 474 0.5 -0.0 -0.8 0.2 0.2 0.1 1.4 0.3 2.1 0.5 0.5 -0.3 1.1 0.3 -1.6 Well Name Baker Hughes INTEQ PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA Page 2 of 3 Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 45OO 4600 4700 4800 4900 5OOO 5100 5200 5300 5400 55OO 56OO 5700 5800 5900 6OO0 6100 6200 6300 6400 65O0 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD ft deg deg ft 100 41.0 27.4 3691 100 41.0 27.3 3766 100 39.8 27.8 3843 100 37.9 29.8 3920 100 37.8 30.6 3999 100 38.0 31.2 4078 100 38.2 31.9 4156 100 38.5 32.6 4235 100 38.7 32.0 4313 100 38.8 30.4 4391 100 39.0 28.8 4469 100 38.9 28.6 4547 100 39.2 29.0 4625 100 39.3 28.7 4702 100 39.5 28.8 4779 100 39.7 29.0 4857 100 39.8 29.2 4933 100 39.9 29.2 5010 100 40.0 28.1 5087 100 40.1 27.3 5163 100 40.2 27.3 5240 100 40.2 27.3 5316 100 39.9 27.3 5393 100 39.7 27.3 5470 100 39.5 27.3 5547 100 39.2 27.3 5624 100 39.0 27.3 5702 100 39.0 27.3 5779 100 ' 39.0 27.3 5857 100 39.3 27.3 5934 100 39.5 27.2 6012 100 39.4 26.9 6089 100 39.3 26.6 6166 100 38.9 26.5 6244 100 37.7 26.3 6323 100 36.4 26.2 6402 100 35.3 25.1 6483 100 34.2 24.3 6566 100 33.0 25.5 6649 100 31.6 25.4 6733 VS ft 1055 1121 1186 1249 1310 1372 1433 1495 1557 1620 1682 1745 1808 1871 1935 1999 2063 2127 2191 2255 2320 2384 2448 2512 2576 2639 2702 2765 2828 2891 2955 3018 3081 3144 3206 3266 3325 3382 3437 3490 LAT ft 927 985 1042 1098 1150 1203 1256 1308 1361 1415 1469 1524 1579 1635 1690 1746 1802 1858 1914 1971 2029 2086 2143 2200 2256 2313 2369 2425 2481 2537 2593 2650 2706 2763 2818 2872 2925 2977 3027 3075 DEP D'LEG BUILD TURN o o ft °/100 /100 /100 505 0.8 0.2 -1.1 535 0.0 -0.0 -0.0 565 1.2 -1.2 0.5 596 2.4 -2.0 2.0 627 0.5 -0.1 0.7 659 0.5 0.2 0.7 692 0.5 0.2 0.7 724 0.5 0.2 0.7 756 0.4 0.2 -0.6 788 1.0 0.1 -1.6 820 1.0 0.1 -1.6 850 0.1 -0.0 -0.2 881 0.3 0.2 0.3 911 0.2 0.1 -0.2 942 0.2 0.2 0.1 973 0.2 0.2 0.2 1004 0.2 0.1 0.2 1035 0.1 0.1 -0.1 1065 0.7 0.1 -1.1 1096 0.5 0.1 -0.8 1125 0.2 0.2 0.0 1155 0.0 -0.0 0.0 1184 0.3 -0.3 0.0 1214 0.2 -0.2 0.0 1243 0.2 -0.2 0.0 1272 0.2 -0.2 0.0 1301 0.2 -0.2 0.0 1330 0.0 -0.0 0.0 1359 0.0 0.0 0.0 1388 0.3 0.3 0.0 1417 0.2 0.2 -0.1 1445 0.3 -0.1 -0.4 1474 0.2 -0.1 -0.3 1502 0.4 -0.4 -0.1 1529 1.3 -1.3 -0.2 1556 1.2 -1.2 -0.1 1582 1.3 -1.1 -1.1 1606 1.2 -1.1 -0.8 1629 1.4 -1.3 1.1 1652 1.4 -1.4 -0.1 Well Name Baker Hughes INTEQ PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA Page 3 of 3 Date 04/16/93 Filename : PMPi-17 Interpolated 100 £t of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 8000 100 30.3 25.5 6819 3542 8100 100 29.2 24.9 6906 3591 8200 100 28.1 26.8 6994 3639 8300 100 26.7 27.4 7082 3685 8400 100 25.1 29.2 7172 3729 8500 100 23.8 31.0 7263 3770 8600 100 22.6 32.2 7355 3809 8700 100 21.3 34.2 7448 3846 8800 100 19.9 35.7 7542 3881 8900 100 18.9 37.5 7636 3914 9000 100 17.6 40.3 7731 3945 9100 100 16.1 42.6 7827 3974 9200 100 14.3 44.1 7923 3999 9300 100 12.6 46.3 8020 4022 9400 100 11.0 49.5 8118 4041 9500 100 10.2 50.1 8217 4058 9600 100 8.9 51.8 8315 4074 9700 100 6.2 49.1 8414 4086 9800 100 6.1 50.3 8514 4096 9900 100 5.0 56.6 8613 4105 10000 100 3.1 65.6 8713 4111 10100 100 2.9 63.9 8813 4115 10200 100 2.8 65.5 8913 4119 10300 100 2.6 64.0 9013 4123 10400 100 2.7 60.8 9112 4127 10443 43 2.7 58.9 9155 4129 LAT ft 3122 3167 3210 3251 3289 DEP D ' LEG BUILD TURN o o ft °/100 /100 /100 1674 1.3 -1.3 0.1 1695 1.1 -1.1 -0.6 1716 1.4 -1.1 2.0 1737 1.5 -1.5 0.5 1757 1.8 -1.6 1.8 3325 1778 1.5 -1.3 1.8 3359 1799 1.3 -1.2 1.3 3390 1819 1.5 -1.3 1.9 3419 1839 1.4 -1.3 1.5 3445 1859 1.2 -1.0 1.9 3470 1879 1.6 -1.3 2.8 3492 1898 1.7 -1.5 2.2 3511 1916 1.8 -1.8 1.6 3527 1932 1.8 -1.7 2.2 3541 1948 1.7 -1.6 3.1 3553 1962 0.9 -0.8 0.6 3563 1975 1.2 -1.2 1.7 3572 1985 2.8 -2.7 -2.7 3579 1993 0.1 -0.1 1.2 3584 2001 1.2 -1.1 6.3 3588 2007 2.0 -1.9 9.0 3590 2011 0.2 -0.2 -1.7 3592 2016 0.1 -0.1 1.6 3594 2020 0.2 -0.2 -1.5 3596 2024 0.2 0.1 -3.2 3597 2026 0.2 0.1 -5.1 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 4129 ft 29.4° Baker Hughes INTEQ ANCHORAGE, ALASKA Well Name Date Surveyed Survey Performed By : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17 : NORTH SLOPE, ALASKA : : 04/16/93 : : TOMMY FOSTER/PAUL SMITH ?his survey is correct to the best of my knowledge ~nd is supported by actual field data. ........................... COMPANY REPRESENTATIVE Baker Hughes INTEQ Well Name : PRUDHOE BAY DRILLING : PT. McINTYRE Pl-17 : NORTH SLOPE, ALASKA : Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of TVD Plane of Vertical Section : 29.4° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.00°WELLSITE North Grid convergence : +0.0000° PRUDHOE BAY DRILLING GROUP +0° 0' 0'' (T) Well Name Baker Hughes PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA INTEQ Page 1 o f 3 Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of TVD MD ft 0 100 200 300 400 5OO 600 700 8OO 900 1000 1100 1200 1300 1400 CkL INC DIR ft deg deg 0 0.0 0.0 100 0.0 163.4 100 0.1 326.9 100 0.1 248.5 100 0.2 118.1 100 100 100 100 100 100 100 100 100 100 0.3 101.7 0.4 114.8 0.4 238.8 0.4 318.0 0.4 332.6 0.4 339.1 0.4 340.6 0.5 332.0 0.7 321.5 1.2 160.7 TVD ft 0 100 200 3OO 400 5OO 600 700 8OO 900 1000 1100 1200 1300 1400 1500 100 1.9 19.7 1500 1600 100 2.9 28.4 1600 1700 100 3.4 34.7 1700 1801 100 4.4 35.1 1800 1901 101 6.8 32.9 1900 2002 101 9.6 30.5 2000 2104 102 13.1 30.6 2100 2207 103 15.2 32.9 2200 2312 104 18.0 33.0 2300 2418 106 21.5 28.3 2400 2526 108 23.4 27.8 2500 2636 110 25.5 25.2 2600 2748 112 27.6 25.9 2700 2862 114 29.8 27.5 2800 2980 118 33.9 27.7 2900 3102 123 36.8 28.1 3000 3229 127 39.0 31.0 3100 3358 129 39.6 29.0 3200 3488 130 39.5 28.3 3300 3618 130 39.7 28.5 3400 VS ft 0 0 0 0 0 7 11 17 23 33 47 67 92 122 158 199 245 294 349 411 LAT ft 0 0 0 0 0 8 12 17 22 3O 42 60 81 106 137 173 214 259 308 3.63 DEP D ' LEG BUILD TURN o o o ft /100 /100 /100 0 0.0 0.0 0.0 -0 0.0 0.0 99.0 -0 0.1 0.0 99.0 0 0.2 0.1 -78.4 0 0.3 0.1 -99.0 1 0.1 0.1 -16.4 1 0.1 0.1 13.1 1 0.7 0.0 99.0 1 0.5 0.0 79.1 1 0.1 0.0 14.6 0 0 -0 -1 -1 0.0 0.0 6.5 0.0 0.0 1.6 0.2 0.1 -8.6 0.2 0.2 -10.5 1.9 0.5 -99.0 3748 131 40.2 30.3 3500 891 783 3880 132 40.7 28.8 3600 977 858 4012 132 41.0 27.4 3700 1063 934 4145 132 40.8 27.0 3800 1150 1011 4274 130 38.1 29.5 3900 1233 1084 483 426 227 2.4 2.4 0.4 560 494 265 2.2 1.7 2.2 642 565 306 1.1 0.5 -1.5 725 637 345 0.3 -0.1 -0.5 807 710 384 0.2 0.2 0.1 21 2.8 2.8 -2.4 31 3.4 3.4 0.2 44 2.1 2.1 2.1 61 2.7 2.7 0.1 79 3 · 6 3 · 2 -4 · 4 98 1.7 1.7 -0.5 118 2.2 2.0 -2.3 140 1.9 1.9 0.6 164 2.0 1.9 1.4 193 3.5 3.5 0.2 426 1.0 0.4 1.4 468 0.8 0.4 -1.1 509 0.7 0.2 -1.1 549 0.2 -0.1 -0.3 588 2.5 -2.2 2.0 -0 2.9 0.6 -99.0 1 1.1 1.0 8.7 4 0.6 0.5 6.3 8 1.1 1.1 0.4 14 2.3 2.3 -2.2 Well Name Baker Hughes INTEQ PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA Page 2 o f 3 Date 04/16/93 Filename : PMPi-17 Interpolated 100 ft of TVD MD ft 4401 4528 4655 4783 4911 5O4O 5168 5297 5427 5557 5687 5817 5948 6079 6209 6339 6469 6598 6727 6856 6985 7114 7243 7371 7497 7620 7742 7861 7978 8093 8207 8320 8430 8540 8648 8756 8862 8967 9072 9176 CkL ft 127 127 127 127 128 128 129 129 130 130 130 130 131 131 131 130 1-30 129 129 129 129 129 129 128 126 123 121 119 117 115 114 112 111 109 108 107 106 106 105 104 INC DIR TVD deg deg ft 37.8 30.6 4000 38.1 31.4 4100 38.4 32.3 4200 38.7 32.3 4300 38.8 30.2 4400 39.0 28.3 4500 39.0 28.8 4600 39.3 28.7 4700 39.6 28.9 4800 39.8 29.1 4900 39.9 29.3 5000 40.0 27.9 5100 40.1 27.3 5200 40.2 27.3 5300 39.9 27.3 5400 39.6 27.3 5500 39.3 27.3 5600 39.0 27.3 5700 39.0 27.3 5800 39.2 27.3 5900 39.5 27.3 6000 39.4 26.8 6100 39.2 26.6 6200 38.0 26.4 6300 36.5 26.2 6400 35.1 24.7 6500 33.7 24.6 6600 32.2 25.7 6700 30.6 25.4 6800 29.3 24.9 6900 28.0 26.9 7000 26.3 27.7 7100 24.7 29.8 7200 23.3 31.4 7300 22.0 33.1 7400 20.4 35.3 7500 19.3 36.3 7600 18.1 39.6 7700 16.5 41.9 7800 14.8 43.9 7900 VS ft 1311 1389 1468 1547 1627 1707 1788 1870 1952 2035 2118 2202 2286 2370 2454 2537 2620 2701 2782 2863 2945 3027 3109 3188 3265 3337 3405 3470 3530 3588 3642 3694 3741 3786 3827 3866 3902 3936 3966 3993 LAT ft 1151 1218 1285 1352 14'21 1491 1562 1633 1705 1778 1851 1924 1999 2074 2148 2222 2295 2368 2440 2512 2585 2658 27.31 2802 2871 2936 2998 3057 3112 3164 3213 3259 3300 3339 3374 3406 3436 3462 3486 3506 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 627 0.6 -0.2 0.8 668 0.5 0.2 0.7 709 0.5 0.2 0.7 751 0.2 0.2 0.0 791 1.0 0.1 -1.6 832 0.9 0.1 -1.5 871 0.2 0.0 0.4 910 0.2 0.2 -0.1 950 0.2 0.2 0.1 990 0.2 0.2 0.2 1031 0.1 0.1 0.1 1071 0.7 0.1 -1.1 1110 0.3 0.1 -0.4 1148 0.1 0.1 0.0 1187 0.3 -0.3 0.0 1225 0.2 -0.2 0.0 1263 0.2 -0.2 0.0 1300 0.2 -0.2 0.0 1337 0.0 -0.0 0.0 1375 0.1 0.1 0.0 1412 0.3 0.3 -0.0 1449 0.3 -0.1 -0.4 1486 0.1 -0.1 -0.2 1521 1.0 -0.9 -0.2 1556 1.2 -1.2 -0.2 1587 1.3 -1.1 -1.2 1615 1.2 -1.2 -0.1 1643 1.4 -1.3 0.9 1669 1.4 -1.4 -0.2 1694 1.1 -1.1 -0.4 1717 1.4 -1.1 1.7 1741 1.5 -1.5 0.7 1764 1.7 -1.5 1.9 1786 1.4 -1.2 1.5 1809 1.4 -1.2 1.6 1831 1.6 -1.5 2.0 1852 1.1 -1.0 1.0 1872 1.5 -1.1 3.1 1893 1.7 -1.6 2.3 1912 1.7 -1.7 1.8 ~ell Name Baker Hughes INTEQ PRUDHOE BAY DRILLING PT. McINTYRE Pl-17 NORTH SLOPE, ALASKA Page 3 o f 3 Date 04/16/93 Filename : PMPI-17 Interpolated 100 ft of TVO MD CkL INC DIR TVD VS ft ft deg deg ft ft 9279 103 12.9 45.8 8000 4017 9381 102 11.3 48.9 8100 4037 9483 102 10.3 50.1 8200 4055 9585 101 9.1 51.6 8300 4071 9686 101 6.6 49.5 8400 4084 9786 101 6.2 49.8 8500 4095 9887 101 5.4 54.9 8600 4104 9987 100 3.2 66.0 8700 4110 10087 100 2.9 63.5 8800 4115 10187 100 2.8 65.7 8900 4119 10287 100 2.6 64.3 9000 4123 10387 100 2.7 61.4 9100 4127 10443 56 2.7 58.9 9155 4129 LAT ft 3524 3538 3551 3562 3570 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 1929 1.8 -1.8 1.9 1945 1.7 -1.6 3.0 1959 1.0 -1.0 1.2 1973 1.1 -1.1 1..4 1983 2.6 -2.6 -2.1 3578 1992 0.4 -0.4 0.3 3584 2000 1.0 -0.8 5.1 3588 2006 2.3 -2.2 11.1 3590 2011 0.3 -0.3 -2.5 3592 2015 0.1 -0.1 2.1 3594 2020 0.2 -0.2 -1:.4 3596 2024 0.2 0.1 -2.9 3597 2026 0.3 0.1 -5.4 9rigin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 4129 ft 29.4° FINAL WELL REPORT PRUDHOE BAY DRILLING GROUP POINT McINTYRE Pl-17/F7 NORTH SLOPE, ALASKA 12 APRIL 1993 TO 16 APRIL 1993 RECEIVED OCT 1 4 199] · Alaska Oil & Gas Cons. Commission' Anchorage THE INFORMATION, INTERPRETATIONS, RECOMMENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORMANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. EXPLORATION LOGGING OF USA, INC. COMPILED BY: DARREN MCINNIS SAM HEWITT MATT GATES APPROVED BY: LARRY SHIELDS TABLE OF CONTENTS PAGE INTRODUCTION ............................................ SUMMARY OF DATA ......................................... 2 METHODS OF: ............................................. 3 MUDLOG .......................................... 3 DRILL DATA ACQUISITION .......................... 3 COMMUNICATIONS .................................. 3 SAMPLING PROCEDURES AND INTERVALS ............... 3 FORMATION EVALUATION WEST SAK LITHOLOGY ............................... 4 DRILL AND GAS DATA ...................... 4 OIL AND GAS SHOWS ....................... 4 HUE SHALES (K10,K5-SHALE WALL, HRZ,) LITHOLOGY ............................... 5 DRILL AND GAS DATA ...................... 5 OIL AND GAS SHOWS ....................... 5 KALUBIK AND KUPARUK LITHOLOGY ............................... 6 DRILL AND GAS DATA ...................... 6 OIL AND GAS SHOWS ....................... 6 MILUVEACH LITHOLOGY ............................... 7 DRILL AND GAS DATA ...................... 7 OIL AND GAS SHOWS ....................... 7 APPENDIX I. SAMPLE DISTRIBUTION II. SHOW REPORTS III. BIT RECORD IV. INTEGRATED FORMATION LOG (MD), INTEGRATED FORMATION LOG (TVD), DRILLING DATA LOG, AND PRESSURE DATA LOG INTRODUCTION THE Pl-17/F7 WELL IS ONE OF A SERIES OF POINT McINTYRE DEVELOPMENT WELLS, DRILLED ON THE POINT McINTYRE P1 PAD, APPROXIMATELY 12 MILES NORTH WEST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 1399' FSL & 866' FEL, IN SECTION 16, T12N, R14E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 308' FNL & 1127' FWL IN SECTION 15, T12N, R14E UM. THE MAIN OBJECTIVE OF THIS WELL WAS THE THE KUPARUK RIVER FORMATION, A LOWER CRETACEOUS AGE MEMBER OF THE UGNURAVIK GROUP, AT A PROJECTED DEPTH OF 8614' SUB SEA TRUE VERTICAL. PROJECTED TARGET (KUPARUK RIVER) COORDINATES WERE: 308' FNL & 1127' FWL, IN SECTION 15, T12N, R14E UM. THE PROPOSED TARGET WAS REACHED BY DRILLING A DEVIATED HOLE; THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES. SUCH THAT THE PROPOSED BOTTOM HOLE LOCATION WOULD BE NORTH EAST AT AN AZIMUTH OF 29 DEGREES, WITH A DEPARTURE OF 4089' WITH RESPECT TO SURFACE LOCATION. THE WELL PROGRAM WAS DESIGNED TO SET 10 3/4 INCH CASING AT 3777 FEET (3550 FEET TVD). THE REMAINDER OF THE HOLE WOULD BE DRILLED USING A 9 7/8 INCH BIT TO PROPOSED TD OF 10543 FEET (9165 FEET TVD). THIS "SLIM HOLE" DRILLING PROGRAM WOULD ELIMINATE AN INTERMEDIATE CASING RUN. THE PROJECTED STRATIGRAPHIC SEQUENCE PENETRATED BY THIS HOLE INCLUDED THE PERMAFROST, T-3, K-15, WEST SAK, K-10, HRZ, KALUBIK, KUPARUK RIVER, AND MILUVEACH FORMATIONS WITH PROPOSED FINAL WELL T.D. 61 FEET (MEASURED DEPTH) INTO THE MILUVEACH FORMATION. -1- WELL NAME: API NUMBER: OPERATOR: PARTNERS: CONTRACTOR: LOCATION: SUMMARY OF PERTINENT DATA POINT McINTYRE Pl-17/F7 50-029-22349 PRUDHOE BAY DRILLING' GROUP ARCO ALASKA, BP EXPLORATION, AND EXXON POOL ARCTIC ALASKA RIG #7 1399' FSL, 866' FEL SEC 16, T12N, R14E UMIAT MERDIAN ELEVATION: GROUND LEVEL 9' ABOVE SEALEVEL ROTARY TABLE 41' ABOVE GROUND LEVEL CASING: 7.625" 10.75" AT 3848' RTE AT 10520' RTE DATE SPUDDED: APRIL 4, 1993 DATE TOTAL DEPTH REACHED: APRIL 16, 1993 FINAL TOTAL DEPTH: 10520' MD, 9232' TVD HYDROCARBON SHOWS: SEE SHOW REPORTS - APPENDIX II. EXLOG GEOLOGISTS: FINAL WELL STATUS: DARREN MCINNIS, SAM HEWETT, MATT GATES BILL STEVENS, RUN LOGS AND COMPLETE FOR PRODUCTION -2- METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DMS). THE SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS" (MS-196). MUDLOG THE MUDLOG FORMAT WAS PREVIOUSLY ESTABLISHED ON FORMER POINT McINTYRE WELLS LOGGED BY THIS CREW. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, RESISTIVITY AND GAMMA RAY DATA WAS IMPORTED FROM TELECO AT THE END OF EACH BIT RUN. TOTAL GAS, RATE OF PENETRATION, CUTTINGS GAS AND GAMMA RAY ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITHMICALLY. LOGS WERE PLOTTED AS 2 INCHES PER 100 FEET (1:600), WITH THE EXCEPTION OF THE PRESSURE DATA LOG. DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE BLOCK HEIGHT SYSTEM, ROTARY SPEED, HOOKLOAD, WEIGHT ON BIT, TORQUE (MINIMUM, MAXIMUM, AND AVERAGE), MUD FLOW IN AND OUT, MUD TEMPERATURE IN AND OUT, STANDPIPE PRESSURE, CASING PRESSURE, PUMP STROKES, AND ALL PITS WERE MONITORED. ALSO THREE H2S STATIONS WERE MONITORED AT ALL TIMES. THIS.DATA WAS PLOTTED ON THE LOGS AS WELL AS BEING DISPLAYED ON REMOTE TERMINALS. COMMUNICATION EXLOG PROVIDED ONSITE AND OFF LOCATION REMOTE TERMINALS FOR THE DISPLAY OF ALL DRILLING PARAMETERS. THERE WAS A MODEM CONNECTION WITH A REMOTE TERMINAL IN THE DRILLING OFFICE. AN EXPLOSION PROOF DRILL MONITOR (HAD) WAS PROVIDED FOR THE DRILLER ON THE RIG FLOOR. SAMPLING SAMPLES WERE COLLECTED AT 30 FOOT INTERVALS FROM 7600' TO TD. THREE WET AND FIVE DRY SAMPLES WERE COLLECTED, AS WELL AS ONE SET OF SAMPLEX TRAYS. ALL SAMPLES WERE SHIPPED TO THE BAYVIEW GEOLOGIC FACILITY WAREHOUSE IN ANCHORAGE, IN CARE OF M.V. STANFORD. A COMPLETE LISTING OF SAMPLE SHIPMENTS CAN BE FOUND IN THE APPENDIX. -3- LOGGING COMMENCED AT 0615 HOURS, APRIL 12, 1993 AT 6476 FEET TVD (7600 FEET MI)) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE REFERENCED FROM THE ROTARY TABLE WHICH WAS 50 FEET ABOVE SEA LEVEL. ALL FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE, AND BASED ON CUTTINGS EVALUATION. WEST SAK INTERVAL LITHOLOGY THE WEST SAK 6740' - 8330' TVD (7914'- 9620' MD) CLAY AND SILTSTONE WITH ABUNDANT VERY FINE TO COARSE GRAINED SAND CHARACTERIZED THE WEST SAK FORMATION. MINOR LIGNITE AND COAL INTER- BEDS WERE ALSO OBSERVED. THE MAJOR LITHOLOGIC COMPONENT OF THE WEST SAK WAS A LIGHT TO MEDIUM GRAY CLAY. THIS CLAY WAS OFTEN VERY SILTY AND AT TIMES SANDY. MINOR PYRITE AND BLACK LITHIC FRAGMENTS WERE ALSO PRESENT. SILT AND SILTSTONE IN THE FORMATION WAS VERY SIMILAR IN APPEARENCE TO THE CLAY. IN FACT, A GRADATION BETWEEN SILTY CLAYSTONE AND CLAY-RICH SILTSTONE, BEST DESCRIBES THE WEST SAK IN THIS WELL. SANDS IN THE WEST SAK WERE GENERALLY UNCONSOLIDATED. GRAIN SIZE RANGED FROM VERY FINE TO COARSE, AND GRAIN SHAPE WAS VARIABLE BUT PREDOMINANTLY SUB-ANGULAR. SORTING OF THE SANDS WAS POOR TO FAIR, WITH MATRIX COMPRISED OF ABUNDANT SILT AND CLAY. MINOR BLACK LITHIC FRAGMENTS WERE OBSERVED THROUGHOUT THE INTERVAL. THESE SANDS WERE COMMON ABOVE 6930 FEET TVD (10570 FEET MD). BETWEEN 6930 FEET AND 8330 FEET TVD (8133 AND 9620 FEET MD), THE LITHOLOGY CHANGED TO ALMOST ENTIRELY CLAY AND CLAYSTONE WITH ASSOCIATED (AND SIMILAR) SILT AND SILTSTONE. VERY LITTLE SAND WAS SEEN IN THIS INTERVAL. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 20 TO 400+ FEET PER HOUR THROUGH THIS HOLE SECTION. DRILL RATES WERE GENERALLY VERY ERRATIC UP TO A DEPTH OF 6830 FEET TVD (8025 FEET MD) AND AVERAGED 150 FEET PER HOUR. THIS IS LIKELY DUE TO THE VARIABLE SAND AND SILT CONTENT IN THE FORMATION. BELOW 6830 FEET TVD, DRILL RATES WERE MORE STABLE AND AVERAGED 70 FEET PER HOUR. DITCH GAS RANGED FROM 2 TO 70 UNITS IN THE UPPER (SANDY) PORTION OF THIS SECTION, AND AVERAGED 20 UNITS. AN 66 UNIT GAS PEAK OCCURRED AT 6746 FEET TVD (7922 FEET MD). ALL GASSES TO 6840 TVD WERE Cl. BELOW 6840 FEET TVD (8036 FEET MD), BACKGROUND GAS INCREASED AND RANGED FROM 1 TO 132 UNITS, AVERAGING 50 UNITS. C1 THROUGH C4 WERE COMPONENT GASSES THROUGHOUT MOST OF THE LOWER (SILTIER) WEST SAK. OIL AND GAS SHOWS TRACES OF A VERY DULL YELLOW FLUORESCENCE AND A VERY SLOW MILKY YELLOW CUT FLUORESCENCE WAS PRESENT THROUGHOUT MOST OF THE WEST SAK. NO SHOW REPORTS WERE DONE DUE TO THE LACK OF SHOW OR RESERVOIR ROCK. -4- HUE SHALE SECTION (K-10, STUMP ISLAND SAND, HRZ) LITHOLOGY THE HUE SHALE CONTAINING THE K-10, STUMP ISLAND SAND, AND THE HRZ WAS. FIRST ENCOUNTERED AT APPROXIMATELY 8330 FEET TVD (9620' MD) AND CONTINUED TO 8650' TVD (9938' MD). IT CONSISTED FIRST OF THE K-10/STUMP ISLAND ZONE, WHICH WAS OBSERVED AT 8330 FEET TO 8541 FEET TVD (9620 TO 9825 FEET MD}. THIS ZONE CONSISTED OF INTERBEDDED FINE GRAINED, MEDIUM BROWN SANDSTONES AND GREY SILTY SHALES. STRONG FLUORESCENT CUTS WERE COMMON IN THE SANDSTONES. TRACES OF WHITE INOCERAMUS PRISMS WERE COMMON THROUGHOUT THE SECTION. FROM 8471 FEET TVD (9760 FEET MD) THE CUTTINGS EMITTED A BURNING OILY ODOUR UPON DRYING. FROM 8541 TO 9938 FEET TVD (9825 TO 8650 FEET MD), WAS THE HRZ. THIS VERY FISSILE DARK GRAY SHALE WAS SILTY WITH MINOR VOLCANIC ASH PRESENT AS INTERBEDS. THE SHALE APPEARRED MICRO MICACEOUS AND VERY CARBONACEOUS. FLUORESCENT CUTS FROM THE ASH WAS A A MILKY WHITE TO YELLOW COLOR. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 25 TO 300 FEET PER HOUR IN THE UPPER SECTION, AVERAGING 90 FEET PER HOUR. THE HRZ DRILL RATES RANGED FROM 15 TO 100 FEET PER HOUR, AVERAGING 40 FEET PER HOUR. DITCH GAS READINGS WERE WIDELY VARIED, WITH A HIGH OF 829 UNITS AND A LOW OF 30 UNITS, WITH AN AVERAGE BEING 125 UNITS. THE HIGH READINGS CORRESPONDED TO POROUS SANDSTONES BETWEEN 8412 AND 8511 FEET TVD (9705 TO 9800 FEET MD). C1 TO C4 WERE PRESENT THROUGHOUT THIS INTERVAL. OIL AND GAS SHOWS AN EVEN BROWN OIL STAIN AND A DULL TO BRIGHT YELLOW FLUORESCENCE AND A BLUE WHITE CUT WAS OBSERVED IN THE INTERVAL 8412 TO 8511 FEET TVD (9705 TO 9800 FEET MD). THIS SHOW WAS GIVEN A FAIR RATING ( SEE APPENDIX 2 FOR SHOW REPORT). -5- KALUBIK AND KUPARUK SECTION LITHOLOGY THE NEXT SECTION COMPRISING THE KALUBIK AND KUPARUK FORMATIONS WERE ENCOUNTERED FROM 8650 TO 9136 FEET TVD (9938 TO 10420 FEET MD). THE KALUBIK WAS ENCOUNTERED FROM 8650 TO 8682 FEET TVD (9938 TO 9970 FEET MD). THE KALUBIK CONSISTED OF A MEDIUM BROWN SILTSTONE AND SANDSTONE, WITH MINOR SHALE. THE SANDSTONE WAS PREDOMINANTLY UNCONSOLODATED, WITH VERY FINE TO MEDIUM, ROUNDED TO SUBROUNDED QUARTZ GRAINS. IN PART IT WAS POORLY CEMENTED WITH SIDERITE AND HAD TRACES OF GLAUCONITE THROUGHOUT. THE KUPARUK RIVER FORMATION (PRIMARY OBJECTIVE) WAS ENCOUNTERED FROM 8682 TO 9136 FEET TVD (9970 TO 10420 FEET MD). IT CONSISTED PRIMARILY OF LOOSELY UNCONSOLIDATED SANDS TO FRIABLE SANDSTONE, BUT HAD ZONES OF HARD, WELL CEMENTED SANDSTONES. THE SANDS WERE LIGHT BROWN OIL STAINED THROUGHOUT THE SECTION AND WERE VERY FINE TO COARSE GRAINED. THE SHAPE OF THE SAND GRAINS WERE HIGHLY VARIABLE FROM SUBANGULAR TO ROUNDED, AND THE SORTING WAS POOR. THE SECTION CONTAINED A HIGH PERCENTAGE OF GLAUCONITE AT TIMES. ALSO PRESENT WAS SIDERITE NODULES AND CEMENT AND PYRITE. MINOR SHALE AND SILTSTONE WAS PRESENT THROUGHOUT THE SECTION, BECOMING MORE PREVALENT NEAR THE BASE. DRILL RATE AND GAS DATA DRILL RATES FOR THE KALUBIK RANGED FROM 20 TO 150 FEET PER HOUR, AVERAGING 50 FEET PER HOUR. DRILL RATES IN THE KUPARUK RANGED FROM 10 TO 600 FEET PER HOUR, AVERAGING 80 FEET PER HOUR. BETWEEN 10060 AND 10150 FEET MD, DRILLING WAS CONTROLLED AT 50 FEET PER HOUR TO ENABLE MWD LOGGING. DITCH GAS IN THE KALUBIK RANGED FROM 75 TO 175 UNITS, AVERAGING 110 UNITS. DITCH GAS IN THE KUPARUK RANGED FROM 100 TO 1230 UNITS, AVERAGING 200 UNITS. BLENDER GAS READINGS FOR THE KALUBIK AND KUPARUK MIRRORED THE OIL PRESENCE SEEN IN SAMPLES AND REACHED A PEAK OF 70 UNITS IN THE KUPARUK. C1 THROUGH C4 WERE PRESENT THROUGHOUT THE INTERVAL. OIL AND GAS SHOWS THE KALUBIK EXHIBITTED A POOR SHOW. THE KUPARUK EXHIBITTED A FAIR SHOW. THIS RATING WAS BASED ON THE OIL STAINING, BACKGROUND GAS INCREASE, AS WELL AS GOOD VISIBLE POROSITY EXHIBITTED IN THE SANDS. SEE THE APPENDIX SHOW REPORT #3 FOR MORE DETAILS ON THE SHOW QUALITY. MILUVEACH SECTION LITHOLOGY THE TOP OF THE MILUVEACH WAS ENCOUNTERED AT APPROXIMATELY 9136 FEET TVD (10420 FEET MD). IT WAS DEFINE BY A DRASTIC REVERSE DRILLING BREAK FROM 80 TO 20 FEET PER HOUR. A SHARP DECREASE IN BACKGROUND GAS AS WELL AS A GRADUAL INCREASE IN A BROWN SHALE ALSO MARKED THE TOP OF THE MILUVEACH. OVERALL THE FORMATION WAS A BROWN SILTY SANDSTONE, WHICH BECAME INCREASINGLY ARGILLACEOUS WITH DEPTH. ONLY 100 FEET OF THE MILUVEACH WAS PENETRATED, IN ORDER THAT'SUFFICIENT "RAT HOLE" WAS PRESENT FOR ELECTRIC LOG AND PRODUCTION LINER RUNS. DRILL AND GAS DATA THE DRILL RATES IN THIS SECTION WERE VERY CONSISTENT. BETWEEN 16 AND 60 FEET PER HOUR AVERAGING 2§ FEET PER HOUR. IN THE TOP SECTION THERE WAS 3 TO 4 FOOT OF SLOWER DRILLING SECTION (UNDER 10 FEET PER HOUR) WHICH MARKED THE BOUNDARY OF THE LOWER KUPARUK AND THE MILUVEACH. AFTER THIS SLOWER INTERVAL, DRILL RATES INCREASED TO AN AVERAGE OF 2§ FEET PER HOUR. GAS READINGS IN THIS SECTION DROPPED TO AN AVERAGE OF 25 UNITS. C1 THROUGH C4 WERE PRESENT THROUGHOUT MUCH OF THIS SECTION. OIL AND GAS SHOWS OIL SHOWS GRADUALLY DECREASED IN THIS HOLE SECTION. PRESUMABLY, ANY FREE OIL WAS A RESULT OF THE OVERLYING OIL-RICH KUPARUK SANDS. -7- SAMPLE SHIPMENT FROM Pl-17/F7. POINT McINTYRE UNIT 242, POOL RIG 7 04/17/93 WET SAMPLES SETS A, B, C BOX NO. W1A, WIB, WlC W2A, W2B, W2C W3A, W3B, W3C INTERVAL 7600'-8800' 8800'-9720' 9720'-10520' TOTAL 9 BOXES WET SAMPLES DRY SAMPLES SETS A, B, C, D, E (STATE OF AK) BOX NO. (SHIPPING) INTERVAL (CARD BOXES) D1 A, B, C, D E 7600'-9990' 7600'-9130' D2 A, B, C, D E 9900'-10520' 9130'-10520' TOTAL 2 BOXES DRY SAMPLES TOTAL 11 BOXES SHIPPED TO: ARCO ALASKA INC. 619 WAREHOUSE AVE. ANCHORAGE, AK 99501 ATTN: MARTIN SANFORD (907)-265-6340 FIELD REQUISITION - MATERIALS, TOOLS, AND EQUIPMENT NO. CHARGE CODE 2C 0033 (PT. McINTYRE Pl-17/F7, CO. MAN T. JOHNSON} DELIVERED TO "C" PAD 04/16/93 SHIPPED ON FLIGHT 56 AK AIR SAMPLE SHIPMENT FROM Pl-17/F7, POINT McINTYRE UNIT 242, POOL RIG 7 04/19/93 WET SAMPLE SETS A, B, C, DRY SAMPLE SETS A, B, C, D, E (STATE OF AK SET) INTERVAL 10520'-10532' 20 SAMPLEX TRAYS INTERVAL 7600'-10520' ALL SAMPLES SHIPPED IN ONE BOX TO: ARCO ALASKA INC. 619 WAREHOUSE AVE. ANCHORAGE, AK 99501 ATTN: MARTIN SANFORD (907) 265-6340 FIELD REQUISITION - MATERIALS, TOOLS, AND EQUIPMENT NO. CHARGE CODE 2C 0033 (PT. McINTYRE Pl-17/F7, CO. MAN T. JOHNSON) DELIVERED TO "C" PAD 04/18/93 SHIPPED ON FLIGHT ARCO CHARTER 5452 ON 04/20/93 SHOW REPORT #1 0IL COMPANY: PRUDHOE BAY DRLG. WELL NAME: Pl-17/F7 LOCATION: NORTH SLOPE, AK DATE: 4/15/93 TIME: 05:30 SHOW INTERVAL: 9705' TO 9800' (MD) 8412' TO 8511' (TVD) ,. BIT SIZE: 9.875" MUD WEIGHT: 9.8 ppg BIT TYPE: STC FICL VISCOSITY: 54 WOB: 25 klb LOGGING COND: GOOD RPM: 215 HOURS: 5.6 FEET: 221' FILTRATE: 6.6 EST. PORE PRES: 9.3 PUMP PR: 3250 PUMP SPM: 142 BEFORE ? DURING AFTER ROP 3O 250+ MAX 3O TOT GAS C1 50 4500 829 MAX 88K 80 7881 OIL IN MUD: TRACE FLUOR: YELLOW C2 300 8925 741 C3 150 4270 441 C4 C5 140 2040 254 CHL 17K 17K 17K LITHOLOGY SILTSTONE: M GY - BRN SS: M BRN, VF - F GR, FRI, SBANG, W SRT SHALE: M - DK GY, PLTY SOLVENT CUT FLUOR: MILKY YELLOW - BLUE WHITE INTENSITY: DULL-BRIGHT UNWASHED CUT FLUOR: YELLOW TYPE & SPEED: INSTANT WASHED CUT FLUOR: YELLOW NAT COLOR & RESIDUE: PALE YELLOW STAIN: MED BRN VISUAL POROSITY: POOR TO FAIR COMMENTS: STUMP ISLAND. SECONDARY TARGET OF WELL. FRIABLE TO MODERATELY HARD SANDSTONE, IRREGULAR ROP INDICATE AN INTERBEDDED RESEVOIR. THE QUALITY OF CUT DECREASED WITH DEPTH, ALTHOUGH GAS AND CHROMATOGRAPH READINGS REMAINED HIGH. OVERALL A FAIR RATING. RATING: FAIR LOGGING GEOLOGIST: M. GATES, D. McINNIS, B. STEVENS SHOW REPORT #2 OIL COMPANY: PRUDHOE BAY DRLG. WELL NAME: P1-17/F7 LOCATION: NORTH SLOPE, AK DATE: 4/i5/93 TIME: 13:30 SHOW INTERVAL: 9938' TO 9970' (MD) 8650' TO 8682' (TVD) BIT SIZE: 9.875" MUD WEIGHT: 9.8 ppg BIT TYPE: STC FICL VISCOSITY: 54 WOB: 25 klb LOGGING COND: GOOD RPM: 215 HOURS: 11.5 FEET: 492' FILTRATE: 6.6 EST. PORE PRES: 9.3 PUMP PR: 3250 PUMP SPM: 142 BEFORE DURING AFTER ROP 4O 102 34 TOT GAS 68 180 MAX 87 C1 6767 24K 10K OIL IN MUD: TRACE FLUbR: YELLOW C2 498 1681 825 C3 222 894 466 C4 110 402 216 C5 CHL 17K 17K 17K LITHOLOGY SILTSTONE: M GY - BRN SS: M BRN, VF - F GR, FRI, SBANG, W SRT SH: M BRN- DK GY, PLTY SOLVENT CUT FLUOR: MILKY YELLOW - WHITE INTENSITY: DULL-BRIGHT UNWASHED CUT FLUOR: YELLOW TYPE & SPEED: INSTANT WASHED CUT FLUOR: YELLOW NAT COLOR & RESIDUE: PALE YELLOW STAIN: MED BRN VISUAL POROSITY: POOR TO FAIR COMMENTS: KALUBIK IS A SECONDARY TARGET OF THIS WELL. FRIABLE TO MODERATE- HARD SANDSTONE, IRREGULAR ROP INDICATES AN INTERBEDDED RESEVOIR. THE QUALITY OF CUT WAS POOR. GAS AND CHROMATOGRAPHY READINGS WERE LOW THROUGHOUT. OVERALL A POOR RATING. RATING: POOR LOGGING GEOLOGIST: M. GATES, D. McINNIS, B. STEVENS ~SINNIO~ '~ 'S3£VD '~ :£SlDOqO3D DNIDDOq HIVM :DNI£VH 'DNI£VH 8IVM V qqVHMAO 'OgqV &~OHD~OMH~ SDNI~VMH SV9 ~NV %HdVHDO£V~OHHO ~OOD '$~OHD~OHH~ i~O (lO(MO 'HIOAMSMH ~M~M~HM£NI NV S3£VOI~NI dOH HVq~DMHHI ~MNO~S~NVS ~{VH -M£VHM~O~ O£ Mq~VIHM 'qqMa SIH£ MO £MDHV£ NIV~ MH£ SI M~h'Vd~M HIVM Oi HOOd :X£ISOHOd ~VflSIA NH8 ~M~ :NIV£S MOqqMX 3qVd :MflaISMH ~ HOqOO £VN QqOD-MOqqM% :HOQqM £QO ~3HSVM iNV£SNI :~MMdS ~ MdX£ ~qOD-MOqq3% :HO~qM i~O ~MHSVMN~ £HOIHfl-qq~ :%£ISNM£NI M£IHM ~qOD - MOqqMX XMqI~ :80~qM £~0 £NMAqOS ~qOO-MoqqM% :HO~qM MOV8£ :~fl~ NI ~IO '8D A - AA 'NHg ~ NH~ - AD ~ :MNO£S£qIS XDOqOH£Iq qHO ~O Z919 99~ gO )I88 IO 98 L8 £0£ 0/.,9 gg dOH ONIHfl~ g}I :~dS d~fld 0§g~ :Hd d~fld g'6 :gaHd aaOd 'iSM 9'9 :M£VH£qIM g'CI :SHilOH gIZ ~OOO :~NOO'DNIDDOq qI~ gg :HOM [§ :X£IgOOglA qOlM O£g :MdXi £IH Mdd 8'6 :£HDIMM QflN ,,~A8'6:22IS lift (~A£) ~9gI6 O£ , g898 ((I14) ,0Z~0I O£ , 0A66 :qVASMSNI MOHS 0C:g0 :~I$ g6/§I/~ :M~V~ MV 'MdO]S H£HON :NOISVOO] £~/£I-Id :MI4VN ]]MM '9]H~ XVH MOH~Md :XNVd~OO ]IO g# £8Od~ ~OHS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA OPERATOR: ARCO SAMPLE TYPE: STATE DRIES DATE: 27 April, 1993 AIRBILL: US MAIL AFT#: CHARGE CODE: 2C0033 NAME: P! 17 F-7 ~ ~ NUMBER OF BOXES: I SAMPLES SENT: STATE DRY SAMPLES: PI 17 F-7 I SAMPLE AT THE FOLLOWING DEPTH. 10520'-10532' SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND'" SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 : D. L. Przywojski ABV-~00 RECEIVED BY: D--~ :__~~ ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA DATE: 23 April, 1993 AIRBILL: AL646208 AFT#: 3-04-23-93 CHARGE CODE: 2C0033 OPERATOR: ARCO SAMPLE TYPE: STATE DRIES NAME: PI 17 F-7 NUMBER OF BOXES: 1 SAMPLES SENT: STATE DRY SAMPLES: PI 17 F-7 7600'-9130' 9130'-10520' SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, 99510-0360 AK. y ~/~~ ATTN= D. L. Przywojsk, yAO ./ RECEIVED ~~~~'~'~~.. D A T E · __~~__~_._.~~~_. . ~,_~.~~.~/~ ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C ALASKA OIL AND GAS CONSERVATION COMMISSION April 1, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORA(3E, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Russ Strickland Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Pl-17 ARCO Alaska, Inc. Permit No: 93-51 Sur. Loc. 1399'NSL, 866'WEL, Sec. 16, T12N, R14E, UM Btmhole Loc. 308'SNL, l127'EWL, Sec. 15, T12N, R14E, UM Dear Mr. Strickland: · Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. erely, - David W. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ prinled on recycled STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work Drill [] Redrill E]llb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RTE =50' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28297 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1399' NSL, 866' WEL, SEC. 16, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 308'SNL, 1127'EWL, SEC. 15, T12N, R14E P1-17 . U-630610 At total depth 9. Approximate spud date Amount 308' SNL, 1127' EWL, SEC. 15, T12N, R14E 4/5/93 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ad/34622-308' feet P1-14 -45'@ 400' MD feet 2560 10543' MD/9220' TVD[eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ,~c 25.035 Ce)(2)) Kickoff depth ~soofeet Maximum hole an~lle4~.39° Maximum surface 3330pslg At total depth (TVD) ~'~{~O'/4~Opslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 281 cu ft Arcticset 13-1/2" 10-3/4" 45.5# J-55 B TC 3736' 41' 41' 3777' 3550' 2386 cu ft PF"E"/406 cu ft "G"/235 cu ft "G" 9-7/8" 7-5/8" 29.7# YT95H~ NSCC 9609' 41' 41' 9650' 8281' 9-7/8" 7-5/8" 29.7# 13CR NSCC 893' 9650' 8281' 10543' 9170' 569 cu ft Ckass "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 Production MAR 3 1 199; Liner Alaska 0il & Gas Cons. Commission Perforation depth' measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportr-I 20 AAC 25.050 requirementsCI 21. I hereby ce~fy that~ true and correct to the best of my knowledge Signed~,.Lv.M~ ~ Title Drilling Engineer Supervisor Date Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'~-~-/ 15 o- ~ ~-~-- 2. ~- .~ .5'~' I "~-',/'- ~'__~ Ifor other requirements Conditions of approval Samples required [] Yes ,~No Mud Icg required []Yes J~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey requ~reo ,1~ Yes [] No Required working pressure for BOPE []2M; I-]3M; 1~5M; r-'I1OM; I-I15M; Other: Original ~,n.~-~d~._.~.,, ,,j By by order of Approved by David W, johnston Commissioner ~ne commission Ddt Form 10-401 Rev. 12-1-85 Submit ir~ triplicate WELL PLAN SUMMARY WELL NAME: P1-17 / F7 WELL TYPE: Slimhole, Iongstring AFE NUMBER: AFC #2C0033 INITIAL COMPLETION: Producer SURFACE LOCATION: 1399'FSL, 865'FEL, SEC 16, T12N, R14E TARGET LOCATION: 308' FNL, 1127' FWL, SEC 15, T12N, R14E BOTTOM HOLE LOCATION: 308' FNL, 1127' FWL, SEC 15, T12N, R14E TOTAL DEPTH: 10543' md / 9220' tvd brt CONTRACTOR: POOL 7 ELEVATION: RTE-SS: 50' RTE-GL: 41' GL-SS: 9' DIRECTIONAL INFORMATION: S-Shape to vertical at target=8666' tvd brt, 4089' departure. KOP: 1500' Angle/dir.: 41°/N29°E Build Rate: 2.0/100'md EOB: 3394' TVD/3570' MD. Start drop- 7227' md, 6138' tvdbrt, 1.5°/100', vertical at top of Kuparuk=9987' md, 8664' tvdbrt. MUD PROGRAM: Surface hole = typical spud mud. Production hole (9-7/8")=3% KCL water. FORMATION MARKERS: TVDss M D WEST SAK 6690 7970 K-10 8330 9702 STUMP ISLAND 8330 9702 HRZ 8490 9863 KALUBIK 8584 9957 TARGET (KUPARUK) 8614 9987 MILUVEACH 9109 10482 TD 9170 10543 CASING PROGRAM: HQle C$~ wt Grade CQnn 26" 20" 1/2" wall conductor WELD 13-1/2" 10-3/4" 45.5# J-55 BTC 9-7/8" 7-5/8" 29.7# NT95HS NSCC 9-7/8" 7-5/8" 29.7# 13 Cr NSCC Length 80 3736 9609 893 Too Btm GL 80 " 41 3777(3550tvdbrt) 41 9650 9650 10543 Tbg Wt Grade 4-1/2" 12.6# 13Cr Cpupling Length NSCT 9859 ToD Btm 41 9900 MEM P 1 - 17 Page 1 3/31/93 LOGGING PROGRAM: Open Hole Logs: Surface NONE Final M~d LOGS: Top of West Sak to TD. MWD: Teleco GR/Resistivity/Neutron/Density from top of K-10 to TD Wireline: GR/Resistivity/Neutron/Density from top of West Sak to TD. Neutron and Density will be run by both Atlas and Schlumberger. A 4-arm caliper will also be run. Cased Hole Logs: All cased hole logs to be run after rig release: Atlas SBT from PBTD to tubing tail. Gyro from PBTD to Surface (Schlumberger) COMPLETION' 4-1/2" 13Cr tubing with 5 GLM's (4-1/2" x 1") above top packer. Tubing retrievable sub-surface saftey valve. Baker sliding sleeve will be run above packer to accomodate future downhole separator. MUD PROGRAM SURFACE MUD Spud TD Surface PROPERTIES: TYPICAL Density Marsh Yield 10 sec 10 min pH Fluid (ppg) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 100 20-40 15-20 20-30 9-10 15-25 FINAL HOLE MUD PROPERTIES: Density PV (PPg) TD Surf 9.5 8-15 T D 10.2 15-30 Final 3% KCL YP 10 sec 10 min pH Fluid gel gel Loss 10-25 5-15 10-20 9-10 10-15 25-35 8-12 <25 9-9.5 4-15 <12HTHP NOTE' ADJUST YP FOR HOLE CLEANING. MEM P1-17 Anchort~(~ Page 2 3/31/93 ~' .... P1-17/F7 CASING DESIGN SPECiE[CATIONS · , SURFACE CASING 10-~14" 45..5#/FT. J-.55 .... BTC BURST COLLAPSE PBYS # TJYS # J-55 3580 2090 715000 796000 ,1 Burst Pressure The burst rating is based on shutting the well in on a gas kick with pressure equivalent to the leak-off at the surface casing shoe: Burst Pressure = 14 ppg (LOT) @ 3500' tvd = 2548 psi. Safety Factor = 1.41 Collapse Pressure The scenario for collapse rating is. based on having lost circulation such.that the, fluid level drops below the surface casing shoe and there is 9,5 ppg mud in the annulus: Collapse pressure = 9,5 * 3500 * ,052 = 1729 psi Saftey Factor = 1.21 Tension Tension is based on full string weight in mud, A maximum casing length of 4000' is assumed, and a vertical hole is assumed (for worst case scenario): Tension- 45.5 * 4000 * .86- 154700 # Saftey Factor (pipe body)= 4.62 Sattey Factor (joint) .~ 5,15 PRODUCTION CASING NT95HS (0'- 8281! tvd) 13GR80 (828t'- TD) BUR:ST COLLAPSE PBYS ii TJY$ # 8180 7200 811000 813000 6890 4790 683000 721000 , Burst Pressure The worst case scenario is a tubing leak at reservoir pressure at the suria[;e (with the NT95HS grade) with no annulus backup, Maximum shut-in tubing pressure= burst pressure=- 4360 - (.15" 9120') = 2992 psi Seftey Factor -. 8180 / 2993 = 2.73 Collapse Pressure Assume the casing is evacuated to gas lift gas with 10,0 ppg mud in the annulus (worst ease on bottom with 1 $CR80 grade): Collapse pressure= 9120"10,0'.052 = 4742 psi Saftey Factor -- 47~0 / 4742 = 1.01 Based on a full string weight in 1,0 ppg mud, A maximum casing length of 11000' is assumed as a worst c~.a~,e a~enano (at surface with NT gSH~3 grade): flr' Tension = 29.7'11000.85= 277,e95 #. ~ ¢ E IV E D Sattey Factor = $11000 / 277695 = 2.92 APR 0 ! 1993 Alisa.Oil & Gas Cons, Commission '' Anchorage Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed T°p of Cement Bit Diameter: Excess Factor: P1-177~, Cement Volumes Surface String 3777 10 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density I 2 # sacks 1099 (2386 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Intermediate String 10543 7 5/8 29.7 9200 9 7/8 1.9 LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 4 90 # bbls 1 01 (0 Cu. Ft.) (569 Cu. Ft.) , 2, . 4. 5, 6. o o o 10. MIRU drilling rig. P 1-1 Operations Summary Spud well and drill 13-1/2" hole to 3777' md/3550' tvd building angle to 41 degrees. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7/8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 10543' md / 9220 tvd. Run open hole logs. Run 7 5/8" casing and cement same. Displace well to seawater with oxygen scavenger and corrosion inhibitor. Test casing to 3500 psi for 30 minutes. Run 4-1/2" chrome tubing completion. Freeze protect well with 600' of diesel. NU dry hole tree and test to 3000 psi. Release rig. Run GCT gyro directional survey and cement bond log. · , o , . , , , . 10. MIRU drilling rig. P1-17/F7 Operations Summary Spud well and drill 13-1/2" hole to 3777' md/3550' tvd building angle to 41 degrees. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7/8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 10543' md / 9220 tvd. Run open hole logs. Run 7 5/8" casing and cement same. Displace well to seawater with oxygen scavenger and corrosion inhibitor. Test casing to 3500 psi for 30 minutes. Run 4-1/2" chrome tubing completion. Freeze protect well with 600' of diesel. NU dry hole tree and test to 3000 psi. Release rig. Run GCT gyro directional survey and cement bond log. Prudhoe Bay Drillin~ Poin[ MeIntyre Pl-17/F7 Dote Ptotted ~ 2123/93 Crea±ed By Checked By Approved By Dote VERTICAL VIEW SCALE 500 ft. / DIVISION TVD REF: R.K.B. ELEVATION VERTICAL SECTION REF: WELLHEA]) 12.00' @ 2100 MD 22.:0' 8 2600 MS 716 [2-'8.: .' :993 12: pm HORIZON?AL VI£W SCALE 500 ft, / DIVISION SURVEY REF: WELLHEAD 38.00' 8 ~400 M] ! k4x~I.39' E 3570 MD EN2 OF BUILD 1,39' i 3777 MD 10-3/z' CASING PDiNT ~x~l.2~' 8 3E31 MD ? - ~ 3134 4078 4087 ~088 4089 4089 4089 --3500 I25C0 20~C' --15OC --1065 0 C 500 iOOC 15:00 200~ 2500 START ~ 1500 ¢.00 [.00 1500 0 ~ILD e ~ oo ~fi/100 ~ ~n 0F ~ZLD 3570 4i.~9 ~ 04 3~4 ~ 347/ i0-~/4' ~SING ~777 41.2~ 2~,04 3~0 7~ 414 [ ~INT rs 79713C.~5 ~ 0467~031~ 173~ ~TUWP ~703~.B~2~ 04 B~O 3~ 1979 : ~LAND/K-I 0 K-5 / ~J 98633.~6~. 04 8~0 3~ 1983 KALUBIK 9957o ~529 03 8~4 35~ 198m {laaGET / 9987G.IO[.QO8~4 3~ 198~ T~TAL D~TW 10543~.~O[ O0 92203~ 1984 1.39' ~ 78~7 ND START OF 9RDs ~ 1.50 ~[~/100 FT 38.3? 8 7z27 MD ~ 35.39' E 76~7 MD ~32.39' ~ 7887 MD ~ 30,~5' 8 7971 MD ~ST ',, -~9' ~ 8387 YC 21.89' B 8587 WD ~0.39' 8 868T MD ~ 18.89' 8 87E7 MD · i7.39' 8 88Er MD ~ 15.89' ~ 89!7 , 1~.39' ~ 9CE7 ' 12.89' ~ 91!7 ' 1.39' t 91~7 ~ 9.89' ~ 93E7 Mi · 8.39' ! 92~7 6.89' ~ 9~E7 a.a6' ~ 9703 wE STUMm ISLAND/K-10 1.86' ~ 9~63 0.45' ~ 9957 ~5 KALU~IK 0.00' ~ 9~7 wZ TAR~[T / <UPARUK 0.00' ~ 11482 wD 0.00' ~ I%5~2 ~D T~TAL DE=TM Oil & Gas Cons, -500 o 5~o ~ ooo ~5oo 8ooo 2500 VERTICAL SECTION PKiNE: 29.04' 3200 4 C',S0 I I 3500 4500 5£:0 BHL DATA T~D 9220 0Ci ~ 10543.0~! VS 4088.591 Nor'.h~574.721 E~st 1984.4~i Pmudhoe Boy DmilLin9 Point Hcln-~yme P~-:~7/,::-7 T~veWn9 Cyiinde~ - Le~s± D,s±~nce ReFePence ~ell - P~-~7~P TVD 0 - 9220 C~, tnte~vo[, 50 AU ~necti~s Ret 450 3o0° ~70~ / WA[Doth Slot D~-'tonce DPe~ic~ Re-F' H3 F,.~¢ 7V~ SeD.Foctor' P1-0I/FI,'f7PJ-0J~ 390z5 7100 200C0 _-::~'JO.,90 373.70 PJ-(}2/Pt"t3PJ-02/F~',¢3 Jc)0~-'~J:~.g:~=2~E,~.c)~ ='~'J50.C0 ~0.~0 P1-0"3/PH4 PJ--O3/Fh',44 210.~x~ 7:.03 50.00 50.00 3447.~O 109,~:~ 1 !3.868L~fB.84-:_~-JO.O0 6.70 ~:34 ,,-O.5e450.03 450.03 3e.30 75.S~ 7:.15 5000 50Z)3 15Y0.70 4~.~_~ 71.77 40000 400.00 j 4 c.,~7 7'..,680.00 0.00 14,90 44.4~ ~:~-~46L:~)O-O0L:~O.O0 42.50 ! 1g.78 ~'-3~ 91 50.00 50.03 2364.80 48~..-~4J ?_-052207.J6 -~'~-'~i30.00 85.40 NVA N,'- N/A N/A N/A N/A N,'-~ N/A N/A N/A NV/~ N'-~ N/A N/A N/A NVA N..'-" N/A N/A N/A NVA N'-~ N/A N/A N/A N/A N,'*- N/A N/A N/A N/A N,': N/A N/A NVA N/A N~ N/A N/A N/A '\ RECEIVED MAR 2 5 1992 Jaska Oil & Gas Cons. 6ormuissio~ Anchorage Smith In aational, Inc. Travelling Cylinder Report Computed by ~he Sii Win-CADDS Syssem Least Distance Method RE}~RENCE WELL: Prudhoe Bay Drilling Point McIntyre Pl-17/F7 N/S and E/W are measured from the WELLHL:~ TVD is measured from the ¥~LLHE3~D'~ Closest Points Wellpath Slot Dis%ance Direction Ref MD Ref TVD P1-01/PM7 ?i-01/PM,7 390.45 71.00 200.00 Pi-02/PM3 P1-02/PM..3 190.28 116.86 2362.99 P1-03/PM4 P1-03/PM..4 210.56 71.03 50.00 P1-07/PM8 P1-07/PM, 8 109.62 113.86 2258.84 Pi-llGCT Pi-ll 9~.34 70.52 450.00 Pi-12/PMll Pi-12/PM..ll 75.32 71.15 50.00 Pi-14MWD Pl-14 45.06 71.77 400.00 Pi-16MWD Pl-16 14.87 71.68 0.00 P1-20GCT 71-20 44.46 250.46 200.00 Pl'25/PM12 ?1-25/-mM. 12 1!9.78 250.9! 50.00 P1-G1GCT P1-G1 486.94 118.05 2207.16 P2-30GCT 22-30 7581.99 80.08 6909.86 P2-48GCT ?2-48 7232.05 84.58 6909.86 P2-49GCT P2-49 7515.61 79.05 6909.86 P2-50GCT P2-50 7224.62 84.96 6843.21 P2-51GCT 22-51 62[~3.37 58.55 8320.73 P2-55GCT P2-55 4045.04 25.03 8430.34 P2-57/PM10 P2-57/R.[10 590~.37 110.49 7563.76 P2-58/PM6 P2-58/P~-.6 6715.47 76.1! 7686.49 P2-59/PM9 72-59/PM. 9 7022.76 76.23 7243.08 P2-60/PM13 -P2-60/~'~!3 7254.76 79.11 6443.3C PM1 'PM1 22~.80 i20.33 2521.51 PM2 PM2 219.80 120.33 2521.51 PM5 PM5 8019.7! 132.48 0.00 200.00 2350.00 50.00 2250.00 450.00 50.00 400.00 0.00 200.00 50.00 2200.00 5900.00 5900.00 5900.00 5850.00 7~50.00 ~150.00 6400.00 6500.00 6150.00 5550.00 2530.00 2~00.00 0.00 Se.~. Factor 373.7 10.8 3447.3 6.7 32.3 1570.7 36.8 !4.9 42.5 2364.8 ~5.4 77.3 77.5 79.3 77.8 34.8 17.0 36.4 51.2 61.9 54 .1 '_1.2 11.2 8019.7 PaTe 4 Date: 3/23/93 Bay }¢il~in9 320° 270~ 240° lt~O '",,, ' 5L-rj . ~ :50.0O =%Z350.0C 5003 ~JBE 30 50.00 157.; 40 400.0g 96.90 OZ)3 ~4gO EO03 ~:~gE 70 ~JA Nt.:. :~A N/' ,",b"A · "~A N/-' N/A N/" N/A N/-' tU'A N/.:. ,%/A N/" './A N/~,. ,"'L/A N/~ ~¢ Smith ~ ,rnational, Inc. Travel .... g Cylinder Report Com~,~:ed by ~he $ii Win~C&~D$ System Horizontal Slice Method P~EFERENCE WELL: Prudhoe Bay Drilling Point Mclntyre Pi-17/F? N/S and E/W are measured from the WELLHF_~j TVD is measured from the h~LLHL=.D Closest Points Wellpath Slot Distance PI-O1/PM7 P1-01/PM.7 390.44 PI-O2/PM3 P1-02/PM..3 190.29 PI-O3/PM4 P1-O3/PM4 210.56 Pi-O7/PM8 Pl-O7/..~W. 8 109.63 PI-llGCT PI-ll 90.34 Pi-12/PMll P1-12/.~..11 75.32 Pi-14MWD Pl-14 45.[6 Pi-16MWD P1-16 14.57 P1-20GCT P1-20 44.46 P1-25/PM12 ?1-25/PM.!2 119.78 P1-G1GCT P1-G1 486.94 P2-30GCT P2-30 8378.69 P2-48GCT P2-48 8178.22 P2-49GCT ?2-49 8146.25 P2-50GCT P2-50 8134.79 P2-51GCT 72-51 7275.S! P2-55GCT ?2-55 4741.~8 P2-57/PMlO 22-57/~10 5946.77 P2-58/PM6 72-58/..~M6 7949.21 P2-59/PM9 72-59/-.~{.9 7929.~5 P2-60/PM13 ~2-60/PM.13 7911.48 PM1 ~MI 219.55 PM2 PM2 219.~0 PM5 ?M5 8019.71 D!rec~lon Ref MD Ref TVD 7C.99 150.00 11(.86 2362.99 71.03 50.00 11~.86 2258.84 7~.52 450.00 71.15 50.00 71.77 400.00 71.68 0.00 25{.46 200.00 25~.91 50.00 !!~.04 2207.!6 6~.86 400.00 6~.!4 700.00 6f.33 50.00 65.40 600.00 4!.72 6709.90 i(.76 7043.16 !iC.73 7243.C8 6~.27 750.00 6~.06 600.00 64.99 600.00 12:.33 2521.51 !2C.~3 252i.51 132.48 50.00 150.00 2350.00 50.00 2250.00 450.00 50.00 400.$0 0.00 200.00 50.00 2200.00 400.00 700.90 50.90 600.00 5750.D0 6000.~,0 6150.C0 750.~9 600.00 600.i0 2500.:0 2500.90 50.30 Sep. Factor 559.3 10.8 3362.3 6.7 32.3 1572.4 36.5 14.9 42.5 2362.7 85.4 3428.9 3582.5 139915.6 4236.4 37._¢ !9.9 36.4 1626.5 2065.1 2060.4 11.2 11.2 46632.7 Date: 3123/93 'i,P oe ~ay ~l Poln-I; lVicln-'cyme P ~ - 17/77 .; T~aveWnq C~,qcie~ - ,%k,'~ma P~ane ii Re£er'en~e '~'ell - P:-~TWP All D~ec'tions ~'el 55O 71 870° /' / // I' CLOSES; ;>-diNTS ,,,/'; : /' / / RECEIVED Alaska Oil & Gas 6ono. 6ommiSs'ion Anchorage HYORIL 15 5/~-5000PSI ..... ~1 GK ANNUb~ BOP LATCHED HF_AD J 15 5/8'-10,000PSI HUB BOTTOM CONNECTION J HYDRIL 15 5/8'- 10, O00?S! '~ -~ MPL RA~ BOP HUB CONNEC770NS 4 1/16'-10,0007Si SIDE OUTLETS --~::~t..2~ HYDR/L I3 5/8'-IO, O00PS! ' --'. J MPL RAM BOP HUB CONNECTIONS · 4 1/I~-IO, O00PSI SIDE O~S CHECK VAL~ CHOKE. WING KILL WING ~¢EVO¥ 4. 1/'16"-'10,000P,~ .. ~c~OY $ 1/16"-10,000PSI I-h'DRIL I3 5/8'- l O, O00PSl , J MPL RA~ BOP HUB CONNECTIONS ~ ,] 4 ~/l¢'-7o, ooo?sl SID£ OUTZ_gS 5/~'-7o, oooPs~ HUB X FLANGE ADAPTOR BLOW-OUT PREVENTER STACK PM ,RIG 7 PRUDHOE BAY DRILLING ~ ,OUP 20" DIVERTER SCHEMATIC POOL 7 FILL UP LINE ii ii · FLOWLINE 20" 2OOO PSI DIVERTER C( 10" BALL VALVE 10" BALL VALVE )NDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE usE OF THE SECOND DIVERTER LINE, THE SECOND VENT LINE CAN BE REMOTELY OPENED TO ACHIEVE DOWNWIND DIVERSION. THIS IS A VARIANCE FROM 20AAC25.035. RE(EIVED MAR ~. 5 1995 ,Aiaska, Oil & Gas Cons, Ocr Ar~chorage .o I D State: ,4/8,~,~ Engineer: 'W'eli; P 1 - 17 'W'od<. Sheet: Field: PT. MCINTYRE Date: State Permit It 98.-51 ~o~ C.a/cubtion~ 37317£3 Casing Type Casing Size Casing Length Hole Diameter Cement- Sacks Cement- Yield Cement- Cubic ft Cement- Cubic fl Cement- Sacks Cement- Yield Cement- Cubic ft Cement- Cubic fl Cement- Sacks Cement- Yield Cement- Cubic fl Cement- Cubic fl -Inches - Feet -Inches 111 111 111 111 112 112 112 112 113 113 113 113 Cement- Cubic ftt Vol Cement- Fill Factor Conductor Surbce 20.000 10.750 80.000 3,736.000 26.000 13.500 0.000 0.000 0.000 0.000 0.000 0.000 281.000 2,386.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 406000 0.000 0.000 0.000 0.000 281.000 2,79Z000 2.333 2.055 Liner 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 OLO00 0.000 ItDIVIO! Casing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks 111 Cement- Yield 111 Cement- Cubic fl 111 Cement- Cubic fl 111 Cement-Sacks:1:I2 Cement- Yield 112 Cement- Cubic fl 112 Cement. Cubic ft 112 Ceme. r~- Sacks 113 Cement- Yield 113 Cement- Cubic ft 113 Cement-Cubic ft 113 Cement- Cubic ft / Vol Cement- Interval fl Top of Cement- Feet Intermediate 111 Intem'~:liate 112 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIVtO! 11DIVtO! :ItDIV/O! IIDIV/O! Rinted 4/2/93 Production 7.625 10,543.000 9.875 0.00 0.00 0.00 569.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 569.00 2,649.55 7,893.,4 Measured Depth State: Alaska Borough: Well: P1-17 Field: PT. MCINTYRE St. Perm # 93-51 P1-17CS G.XLS Date 3/31/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length Description Description Description Tension lA 10.75 3550 41 2A 7.625 8281 41 3A 7.625 9170 8281 4A 0 0 0 ,SA 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 3736 9609 893 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 45.5 J-55 BTC 0 29.7 NT95HS NSCC 0 29.7 13CR80 NSCC 26521 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/It psi/It lB 9.5 0,494 0.394 2B 10.2 0,530 0.430 3B 10.2 0.530 0,430 4B 0.0 0.000 -0.100 5B 0.0 0.000 -.0.100 6B 0.0 0.000 -0.100 7B 0.0 0,000 -0.100 8B 0.0 0.000 -0.100 919 0.0 0.000 -0.100 10B 0,0 0,000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3330 3580 1.1 3330 8180 3330 6890 2.1 0 0 #DIV/O! 0 0 #DIV/O.I 0 0 #DIV/O! 0 0 #DN/0! 0 0 #DN/0.1 0 0 #DIV/0.1 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 1C 169.988 715 2C :311.9083 811 3C 26.5221 68'3 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 4.21 2.60 25.75 o #DIV/O! 0 #DIV/O.I 0 #DIV/0! 0 #DIV/O! 0 #DIV/O! 0 #DN/0! 0 #DN/O! Collapse Collapse Pr-Bot-Psi Resist. CDF 1399 2090 1.494 3564 7200 2.020 3947 4790 1.214 0 0 #DIV/0! 0 0 #DiV/O! 0 0 #DIV/0.1 0 0 #DIV/0.1 0 0 #DN/O! 0 0 #DIV/D,I 0 0 #DIV/0! Page 1 ITEM (1) Fee (2) Loc ;:* CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE (3) Admin [/~]C..~t ~ hru 13] [10 & 13] [14 thru 22] (5) BOPE ~/~,~::/~/, ~-$~-~.,. [23 thru 28] (6) Other ~2~9Cthru 31] (7) Contact ~ .:~,//.~_..<~.?~' . [32 ] (8) Addl geology' engineerinq' DWJ MTM//~F-~~- RPC~/~c~ . BEW JDH ~7-[-~- LG rev ..... 12/92 le 2. 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Company A~E.~__.) Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nt~nber appropriate .......................................... Does well have a unique name & n~ber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface ~ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel]bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ~3N/OFF POOL CLASS STATUS AREA ~ SHORE Oe. , f Lease & Well REMARKS ,/Vl / /, O -rZ Add i t i onal remarks' uM MERIDIAN: SM TYPE' Exp D~.~. ,~ Red ri 11 Rev Well History File APPENDIX Information of detailed nature that is not padiculady 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. ALASKA COMPUTING CENTER *-------$CHLUMOERGER COMPANY NA~g ~ ARco ALASKA FIELD NA~E : POINT ~CINTYRE BOROUG~ : NORTH S[~OPE STATE : ALASKA API NUMBER : 50-029-22358-00 ~EFERE~CE NO : 93175 RECEIVED JUN 1 7 199) iC OFILHED IS Tape Verification Listino chlumberger AlasKa Computing Center 28-MAY-~993 ~3:34 **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 93/05/28 ORIGIN : FLIC PEEL NAME : 93175 CONTINUATION # : P~EVIOUS REEL : COMMENT : ARCO ALASKA INC.,POINT ~CINTYRE,Pl-17,50-029-22358-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 93/05/28 IAPE NA~E : 93175 CONTINUATION # : { PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,POINT ~CINTYR£,P~-17,50-0~9-22358-00 TaPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS API NUMBER: OPERATOR: bOGGING COMPANY: TAPE CREATION DATE: jOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FEL: RUN I 93175 SMITH DEAL FWL: ELEVATION(FT FROM ESL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 2ND STRING P1-17 5002922358o0 ARCO ALASKA INC.: SCHLUMBERGER WEGb SERVICES 28-MAY,,93 RUN 2 RUN 3 12N :14E 1399 865 41.00 9.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH eFT) 26.000 20.000 80.0 13.500 ~O,750 3~46,O PAGE: :IS Tape Verification Listing chlumberger Alaska Computing Center 28-MAY-lg93 13:34 3R9 STRING PRODUCTION STRIN~ # PEMaRKS: FIELD ENGINEER;S RE~ARK$: LOG CORRELATED TO W/A D!L RAN 4-16-93, CNTH RAN TO ECCENTER CNTG, THERMAL NEUTRON POROSITY DERIVED FROM CNTG. $ LIS FORMAT DATA LIS FORMAT DATA PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01A07 DATE : 93/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FIL? NUMBER: EDITED CU~¥ES .All tool strings; Depth shifted and clipped curves; all runs merged~ no cased ~ole data, DEPTH INCREMENT: 0,5000 # FILE SU~AR~ VENDOR TOOL CODE START DEPT~ SGR 10471,0 C~TG I0480,0 EDN !0499,0 $ B.~S~LINE CURV~ FOR SHIFTS: GR CURVE SHIFT DATA (~ASURED DEPTH) 88888.0 I0409,0 10364,0 10349,0 103139,0 10291,5 ~0265'5 0 0222.0 0202'0 ~0190'5 10171.5 STOP DEPTH ~mmmmmmmmm 9746~0 9746o0 ~?~6~0 "~T DE'PTH--~--'---- ----------EOUIVALEL~ 88882.5 10403.5 10363-5 ~029~,0 10265-5 10239.0 1O221,5 10190,0 10171,0 TaPe Yeriflcation Listing chlumberger Alaska Computing Center 28-MAY-1993 13:34 lols~.o ~o~51.o ~0122,5 10123.0 !0094.5 10093,5 10077 S 10076,5 ~0048,5 10047.5 ~oo31.o 10030.5 loo2o.5 loo2o.o ~ool~.o loo12.o ~ooo~.o lOOO1.5 9977,5 9977,5 ~955,0 9953,5 .94~.0 994~,0 9936,5 9936.5 99~9.5 9929.0 9915.5 9915.5 9897.5 9896,5 987~,0 9870 5 9~61.5 9~54.o 9854.0 9825.5 9825,5 98~7,5 9817,0 9802,5 9802,5 9800.0 9800.5 977!.5 9771.:5 9759 5 9760..0 100~0 100.5 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO, S PASS MO,, MERGE TOp MERGE BASE THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT SWS SGR G:AM~IA RAY TO ATLAS DIb GAM}~'A RAY DATED 16-APR'93, ALL OTHER CURVES WERE CARRIED WITH THE SGR SHIFTS, # bib FORM.AT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB **. TYPE REPR COD~ VA~UE mmmmmmmmmmmmmmmmmmmmmmmmmm~.mm I 66 0 2 66 0 3 73 84 4 66 Tape Verification Listing chlumberger AlasKa Computing Center 28-~AY-1993 13:34 PAGE: TYPE REPR CODE 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 12 12 68 13 66 0 ~4 65 FT 15 66 68 16 66 1 0 66 0 mmmmmm.mmmmmmmmmmmmmmmm.mmm.mm ~* SET TYPE - ..-.,--.,...---..-------.------------------,,-,,,,--------.---------------------------- NA~ $ RV UNIT SERVICE APl API API A NUmB NUMB SIZE REPR PROCES~ ID ORDER # LOG TYPE CLASS ~OD NUmB SA~P ELE~ CODE (HEX) .............,,............................-.-...-........,.......-.,..,.........-...... DEPT 599481 O0 000 O0 0 ! I 4 8 0000000000 GAPI 59948! O0 000 O0 0 ! 1 1 4 68 0000000000 SGR SGR C~R SGR THOR SGR POTA SGR URAN SGR TE~$ SGR ~TE~ ~RE$ SGR R~OBSDN DRHO SDN PEF 8DN Cah! SD~ IN 599481 NPH! CNTG P[)-S 599481 NRAT CNTG 599481 CRAT CNTG 599481 NCN? CNTG CPS 599481 FCNT CNTG CPS 599481 C~TC CNTG CPS 599481 CFTC CNTG CP$ 599481 bB 599481 LB 599481 DEGF 599481 OHMM :599481 G/C3 599481 G/C3 599481 BN/E 599481 GAP! 599401 O0 000 O0 0 I I ~ 4 68 PPM 599481 O0 000 O0 0 1 I 1 4 68 PU-S 599481 O0 000 O0 0 1 1 I 4 68 PPM 599481 O0 000 O0 0 ! 1 ~ 4 68 O0 000 O0 0 I I ! 4 60 O0 000 O0 0 1 1 ~ 4 60 O0 000 O0 0 1 ,1 I 4 68 O0 000 O0 0 I 1 I 4 68 O0 000 O0 0 I I I 4 68 O0 000 O0 0 I 1 1 4 68 O0 000 O0 0 1 1 1 4 68 O0 000 O0 0 1 I 1 4 68 O0 000 O0 0 1 I I 4 68 O0 000 O0 0 I I 1 4 68 O0 000 O0 0 I 1 ! 4 68 O0 000 O0 0 1 I I 4 68 O0 000 O0 0 1 1 ! 4 68 O0 000 O0 0 I 1 1 4 68 O0 000 O0 0 1 I I ,4 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 68. 0000000000 ** DATA ** DEPTo !0516,000 SgR!,$GR -999,2'50 CGR,SGR POTA-gGR -999,~56 URAN,$GR -999'250 TEN$.SGR MTE~,SGR -999.250 MRES-SGR -999,250 RHOB.SDN I,C,TG~M PEF.SDN -999'250 CALI'SDN -999'250 NPH, C~:AT,CNTG -999,~50 NCNT CMTG -999.250 FC,~t.CNTG N CFTC.CNTG -999'250 -999.250 TMOR*SGR .4075. =000 T EMD. SGR 999.250 DRHO,SDN -999.2:50 NRAT'CNTG -999-250 CNTC,{NTG~ i 2 08 -999.250 999.250 -'999,250 IS Taoe Verification hist~no chlumherqer AlasKa Computing Center 28-MAY-1993 13:34 PAGE: D~PT 1_0.500,000 SGR.SGR POTA:$GR 999,250 URAN.SGR MTEM.$GR '999,250 MRES.SGR D~F.SDN '999.250 CALI,SDN C~AT.CNTG '999,250 NCNT,CNTG CFTC.CNTG '999,250 D~PT. 10400.000 SGR.SGR POT~.SGR 1.214 URAN.SGR ~TE~.SG~ 150,561 ~RES.SGR PEF SDN 2,890 CALI.SDN CRAT~CNTG 2.682 MCNT.CNTG CFTC.CNTG ~ 01 ~ .000 D~PT. 10300,000 SGR,SGR POTA SGR 1.2~0 URAN,SGR MTE~SG~ 152.059 MRE&.SGR ~EF.SDN 2,964 CALI,SDN C~AT,CNTG ~,713 NCNT.CNTG CFTC,CNTG I061,813 D~PT. I0200.000 SGR.SGR POTA.SGR 1-.560 URAN.SGR ~TE~,SGR 151,719 ~RES,SGR PEF,SDN 7,238 CALI,SDN C. AT CNTG 3-293 NCNT, CNTG CFTC,CNTG 6~9,406 D~PT. 10100,000 SGR,SGR POTA,SGR i' 761 URAN,SGR MT~,SGR 149.8~8 NRES,SGR PE. ,SDN 5'396 CALI,SDN CPAT,CNTG 2,974 NCNT,CNTG CFTC,CNTG 698' 867 DEPT, 10000.000 SGR:,SGR pOT~.SGR 51 URAN'SGR PEF,SDN 3,558 CALt'SDN cRAT,CNTG ~,446 NCNT,CNTG CFTC,CNTG I187'906 DEPT, 9900,000 SGR':SG:R POTA'SGR 3.033 LtRAN.SGR MTEM.SGR 146,560 MREM.SGR PEr,SDN 4,322 C~LI'GD~ C~AT'CNTG 3,389 NCNT,CNTG CFTC,CNTG 517'457 EPT, : 9800,000 SGR,SGR OT~,SGR 2-205 URAN"SGR MTE~,SGR 143,770 MRE&'SGR PEF.SDM 3,090 CALI,SDN CRAT.CNTG ~,542 NCNT,CN'rG ~999 250 CGR,SGR -999.250 999~250 TEN$.SGR 5360.000 -999.250 RHOB.$D~ -999.250 7.379 NPHI,CNTG -999.250 -999,250 FCNT,CNTG -999.250 35,137 CGR,SGR 26.182 1,371 TENS.$GR 5000.000 0,103 RHOB,SDN 2.242 9,758 NPHI.CNTG 27.597 2771.141 FCNT,CNTG 962.781 52.282 CGR.SGR 30.966 3,263 TENS,SGR 4863.844 0.102 RHOB,SDN 2,366 9,7~4 NPHI,CNTG 28.354 280i.5 0 FCNT,CNTG 985,063 77 719 CGR,SGR 54.344 3:577 TENS,$GR 4896,750 0.102 RHOS.SDN 2.:738 g 879 NPHI,ONTG 37o~57 i95:930 FCNT,CNTG 571. 50 59,1~ CGR'SGR 49-438 TENS !,4 ,SGR 4886.594 04 RHOB,SDN 2,374 O, 41 NPHI'CNTG 31,747 208~:1250 FCNT.¢NTG 658.438 O, 105 RHOB,$DN 2~5'25 i0.053 NPHI.CNT'G 2~:~91 2924'250 FCNT,CNTG 1t5 69 0 ~06 RHOB,SDN 1o: 63 ~P~,:CNTG 37.,~02 1714,625 FCNT,:CNTG 464-1:25 91:867 CGR'$GR 64.400 663 TEN$'$GR. 4885.086 RHOB,SDN 2.433 0,108 10'21! NPHI.CNTG 24.944 3000.500 FCNT,CNTG 1054.844 TNOR.SGR T~ND.SGR DRHO.SDN NRAT.CNTG CNTC.CNTG THOR.$GR TEND.$GR DRHOoSDN NRAT,CNTG C~TC.CNTG THOR.SG~ TEND.SGR DRHO.$DN NRAT,CNTG C~TC.CNTG THOR.SGR TEND.SGR DRHO,SDN NRAT,CNTG CMTC.CNTG THOR,SGR TEND' SG~ DRHO,MDN NRAT'CNTG CMTC.CNTG. THOR'MGR TEND.$GR DRHO-$DN NRAT CNT~ C N T C: C N T G THOR.SGR TEND.SGR DRHO,$DN NRAT'CNTG CNTC,CNTG THOR'$GR TEND.SGR DRHO'.SDN · ~r NRAT.CN :G. CNTC.CNTG -999,250 945.000 -999.250 -999,250 -999,250 2,635 633.563 -0,007 2,817 2766,016 4.012 625,500 O.OO2 2.921 2810.375 9,461 645'666 0,002 3 5i6 2052:367 7 185 638 990 0 000 3 061 2028,063 5' ss 668' 344 0,002 2 · 567 2824'563 779' 000 0,137 3 ' 499 1. 691.98.4 9 705, O, 5 2,589 2870,609 IS Tape Verification Listing chlumberger AlasKa Computing Center CFTC.CNTG 1138.906 28-MAY-1993 13:34 DMPT. 9746,000 SGR.SGR 95,770 CGR.SGR POTa,SGR 2,862 URAN,SGR 3.672 TENS.SGR MTE~.SGR 143,263 MRE$.SGR 0,109 RHOS,SDN PEF.SDN 3,547 CALI,SDN 9.906 NPHI,CNTG CR~T.CNTG 2.800 NCNT.CNTG 2561.383 FCNT.CNTG CFTC.CNTG 946.360 END O? DATA 71.783 THOR.SGR 4790.000 TEND.SGR 2.403 DRHO.SDN 29.173 NRAT.CNTG 853.575 CNTC,CNTG PAGE: 9,164 727,500 0.001 2.833 2574,611 **** FILE TRAILER **** FILE NAME : EDIT ,001 SERVICE : FLIC V~R$ION : O01A07 DAT~ : g3/05/2~ ~AX R~C SIZ~ : 1024 FILE TYPE : LO L~ST FILE : **** FTLE HEADER **** FIL~ NAME : EDIT ,002 SERVICE : FLIC VERSION : O01A07 DATE : 93/05/28 MAX REC SIZE : !024 FILE TYPE ~ LO LAST FILE : FILE HEADER FIL~ NUMBER 2 data.~for each.run and.tool str~n~ ~.n seParatet~iles;u Tool String #~ fo Curves and log header Sadlerochit run presented first (primary.depth control"string used depth shift the'~Sadler ~nterval) followed bY files for other m~ln Pass tool strings per ru~,: RUN NU~BER~ TOOL STRING NUMBER: I PASS NUMBER: 2 DEPT~ INCREMENT: -.5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH NGT ~0477,0 CNL ~0492.0 LDT 10504.0 $ STOP DEPTH 9746,0 9746 IS ?ape Ver~fication Listing chlumberger Alaska Comput],n~ Center 28-MAY-1993 13:34 PAGE{ 7 LOG HEADE~ DATA OATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTO": TD DRILLER (FT)~ TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED CFPHR): TOOL STRING (TOP TO BOTTOm) VEN00R TOOL CODE TOOL TYPE TCC TCM NGT NGT NGT NGT NGT CNL CHh LOT LOT ~OREHOLE A~D CASING DATA OPE~ HOLE 8IT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH B~REHOLE CONDITIONS NUD TYPE: DENSITY (LB/G): VISCOSITY PH: FLUID bOSS ~AXIM'UM R..~.CORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT T~PE~ATURE (DEGF): MUD AT ~EASURED TENPERATURL ~UD AT BOTTOM HOLE TEMPERATURE (B. HT): ~D FILTRATE AT ~UD FILTRATE AT (BHT): ~UD CAKE AT (gT): MUD CAKE AT (BHT): 17-APR-g3 CP 32.6 1300 {0530.0 10521.0 9746,0 105{9,0 1800.0 TOOL NUMBER 'ELE'~TRY CARTRIDGE TCC'B 420 TELE,ETRY ~ODULE TCN-A 19 NGT DETECTOR NGD'D 756 .CT GAM"A RAY CARTRIDGE NCC-8 1915 NGT SOURCE NSR-FA 226 NGT SOURCE GSa'JO 7271 NGT CARTRIDGE NSC'E 760 CNT~ HOUSING CNC'H ]27 DENSITY-RESISTiVITY DRS'C 4847 POWERED GR DETECTOR PGD-D 1800 NEUTPOM TOOL TOOL TYPE (EPITHERMAL OB THERMAL): ~ATRIX: ~ATRIX DENSITY: HOb~ CORRECTION (IN): 17-APR-93 TOOL STANDOFF (IN): 1 ~~ 500 §46.0 3846,0 9,90 57,00 g,60 !.54,0 0,260 0,019 0,040 · 48.0 40,0 EPITHER~AL SANDSTONE 2,65 IS TaPe Verification Listina chlumberqer AlasKa Computing Center 28-MAY-/993 13:34 PAGE: REMARKS: LOG CORRELATED TO W/~ DIS RAN 4-16-93, CNTH RAN TO ECCENTER CNTG. THERMAL NEUTRON POROSITY DERIVED FROM CNTG. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 244 4 66 5 66 7 65 @ 68 0,5 9 65 FT ~ 66 4 12 68 13 66 0 14 65 ~T 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** N~ME SERV UNIT SERVICE API API AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 59948~ O0 000 O0 0 ~ ! I 4 68 000.0000000 SGR NGT CGR NGT THOD NGT POTA NGT [IRAN NGT WING NGT W4N~ NOT W5NG MGT TEN~ NOT ~TE~ NOT MRK$ NOT CS NGT GAPX 599481 O0 GAPI 599481 O0 PPg 599481 O0 PU 599481 O0 PPM 599481 O0 CPS 599481 00 CPS 599481 O0 CPS 599481 O0 CPS 599481 O0 CPS 599481 O0 LB 59948! 00 DEGF 599481 O0 OHMM 59948~ O0 F/HR 59948! 00 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 1 1 4 68 0000000000 I 1 4 68 0000000000 I 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 ! 4 68 0000000000 i 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 IS I~ape Verification Listing chlumberger AlasKa Computing Center 28-MAY-lgg3 13134 PAGE= gF SERV UNIT SERVICE APl PI A FILE; ~ NUmB $ REP PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEN CODE (HEX) ......HTENNGT' .....'''''''''''''''''''~;''''~'''''''';'''';'''''''''''''''''''''''''''''''''''58 599481 O0 . 1 4 68 0000000000 RHOB BDT G/C3 599481 O0 000 O0 0 2 ! 1 4 68 0000000000 DRHO LDT PEF LDT QLS LDT OSS LDT L$ LDT LU LDT LL LDT LITH LDT SS1 LDT SS2 LDT LSH¥ LDT SSHV LDT LSRH LDT LURH LDT CAL! LDT SGR LDT CGR LDT T~NS LDT ~TE~ LDT ~RES LDT HTE~ LDT E~PH CNL ENRA CNL CFEC CNL C~EC CNL RCEF CNL RCEN CNL NPH! CNS: TNPH CNL TNRA CNL RTN~ CNL ~PO~ CN5 G/C3 599481 O0 000 O0 5994~1 O0 000 O0 599481 O0 000 O0 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 00 000 00 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 V 599481 O0 000 O0 V 599481 O0 000 O0 G/C3 599481 00 000 00 G/C3 599481 00 000 00 G/C3 599481 O0 000 O0 IN 599481 O0 000 O0 GAP! 599481 O0 000 O0 GAPI 599481 O0 000 O0 LB 599481 O0 000 O0 DEGF 599481 O0 000 O0 OH~ 599481 00 000 O0 LB 599481 O0 000 O0 PU 599481 00 000 O0 599481 O0 000 O0 CP6 599481 00 000 O0 CPS 599481 00 000 O0 CPS 59948~ O0 000 00 CPS 599481 00 000 00 PU 599481 O0 000 O0 PU 599481 O0 000 O0 599481 O0 000 O0 599481 O0 000 O0 PU 599481 O0 000 O0 RCNT CNL CPS 599481 O0 000 O0 RCFT CNL CPS 599481 O0 000 O0 CNTC CNL CPS 599481 O0 000 O0 CFTC CNL CPS 599481 O0 000 O0 SGR CNL GAPI 599481 O0 000 O0 CGR CNL GAPI 599481 O0 000 O0 CALl CNL TENS CNL ~TE~ 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 .2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2¸. IN 599481 O0 000 O0 0 2 bB 599481 O0 000 O0 0 2 DEGF 599481 O0 000 O0 0 2 1 I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 ! 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 I I 4 68 0000000000 I i 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 1 t 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 1 ! 4 68 0000000000 I ! 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 I I 4 68 0000000000 I ! 4 68 0000000000 ** DATA IS Tape Verification Listino chlumberoer Alaska Computino Center DEPT 10530.000 SGR.NGT POTA:EGT 0.000 URAN.NGT W3NG.NGT 79,310 W4NG.NGT MTE,.NGT 150.125 ~RE$.NGT RMOB,LDT 2,038 DRMO,LDT OSS.LDT 0,057 LS. bDT LITH.LDT 119.625 SS1.LDT SSHV.LDT 1190,000 S1RH,LDT CALI.LDT 9,875 SGR.LDT MTE~.LDT 150,125 MR£S,bDT EMRA.CNL 6,642 CFEC.CNL RCEM.CNL 1803,081 NPMI.CNL RTNR CNL 4.026 NPOR,CNL C~TC:CNL 14!1.800 CFTC.CNL C~LI.CNL 9,875 TENS,CNL HTEN.CNL -49,594 DEPT. 10500.000 SGR.NGT POTA.NGT 1.901 URAN.NGT W]NO.NGT 79,310 W4NG,NGT ~TE~.NGT 150,125 MRE&,NGT RHOB.LDT 2.101 DRHO,LDT OSS.LDT -0.012 L$.LDT LIT~,LDT 87.43B SS1,LDT SSH¥,LDT 1189 ~00 $1RH.LDT CALI,LDT 81:~86 SGR-LDT ~TE~,LDT~ · 150,12~ ~RE$,LDT E.,RA CNL 5':92 CFEC,CNL RCEN.,CNL !725.993 NPHI,CNL RTNR,CNL 4,208 NPOR,CNL CNTC,CNL 1389,243 CFTC,CNL CAL!,CNL 8,586 TENS-CNL HTE~,CNL 955.000 D~PT 10400,000 SGR'NGT POT ~: ~ G T 1 · 259 U R A N N ~ T W]~G,NGT 19'88! W4NG"NGT ~TEM.NGT 150,913 MRES.NGT R. HOB.LDT 2,229 DRHO.bDT OSS.LDT 0.O09 bM,bDT LITM.LDT 1 t8, ~ 25 SSI,bDT SSHV.LDT 1190.000 S!RH.bDT CAbI bDT .9'758 SGR.bDT ~TEM'LDT {50.913 MRES-LDT ENRA CN[. 4':445 CFEC,CNL RCEN CNL 2726.!52 NPHI.CNL RTN,.CNL 2.651 N~O~'CNL C~TC.CNL 2801,=752 C.f TC,CNb C,ALI CNL 9 758 28-~AY-1993 13:34 0.000 CGR.NGT 0.000 W1NG.NGT 25.287 W5MG.NGT 0.104 C$.NGT 0,049 PEF.LDT 561.500 LU,~DT 222.000 SS2,~DT 1.866 LSRH,LDT 0.000 CGR.bDT 0.104 HTE~,bDT 292.566 CNEC,CN5 56,916 TNPH,CNL 46.405 RCNT.CNL 373,327 SGR,CNL 2285.000 ~TE~.CN~ 134.175 CGR,NGT 15.521 WlNG,NGT 25'287 W5NG, NGT 0,104 CS,NGT 0.002 PEF,LDT 461,250 LU,LDT 201.250 $$2.LDT 2,084 5$RH,LDT 134,175 CGR'LDT O, 04 EN DT 96 CNEC.CNL 46, 5 RCNT'CNL 370,758 SGR,CNL 5225.000 MTEM,CNL 0.000 412.644 6.897 ~51.250 3.027 509.250 310.250 1.984 0.000 -49.594 1943.090 46,405 1430 647 0~000 150.125 32.784 412.644 6.897 1562.000 5 ~34 4 51 ~o~'§oo ~.094 s9-ooo 1888~569 45.83.4 I398'106 134':175 150'!25 9 ~ W1NG,NGT 136,!83 W5NG.'NGT 0,994 0,1 3 CS,NG~ 1889'000 3~0'008 PEF'~hDT 2.818 3'500 LU,LDT 348'000 3~':264 DSRH,bDT 230 .874 CGR,:5DT 218 62~ 79 CNEC,C~ 29 13 27,9~5 RCNT'CNB 2832.004 1072,9 7 SGR,CN5 39,874 4960'000 ~TEM,CNL 150o913 THOR.NGT W2NG.NGT TENS,~GT HTEN,NGT OL$.LDT LL,LDT LSHV.LDT bURH,LDT TENS,bDT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL CGR.CNL MREM,CNL THOR.NGT W2NG,NGT TENS,NGT HTEN.NGT OLS,LDT Lb,LOT bSHV,LDT LURH,LDT TENS,LDT ENPH,CNL RCEFoCNL RCFT'CNL CG~.CNL MRES.CNL THO~,NGT W2MG,NGT TENS,NGT HTEN,NGT ~UR bDT TENS,bDT ENPH,CNL RCEF,CNL INRA'CNL RCFT,CNL CGR,CNL MRES,CNL PAGE: O. 191. 2285. -49. O. 306. 1247, 2, 2285. 55. 286. 3. 350, O, O, . 191. 5225, 955, ~0. 243. 1247. 5225, o 3 58 4960 630 199- 1249 4960. 26. 650, 991, 28- O, 000 954 000 594 012 750 000 016 000 633 101 874 995 000 104 718 954 000 000 :040 750 000 104 000 630 601 884 O82 784 104 069 648 000 000 002 500 000 236 000 735 812 631 t40 30:3 ! 03 10 18 Tape Verification Llstlno chlumberqer Alaska Computing Center DEPT. 10300.000 SGR.NGT POTa. NGT 1.133 URAN.NGT ~]NG.NGT ~8,302 W4NG.NGT MTE,.NGT 152,038 ~RE$,MGT R~OB.LDT 2.425 DRMO,LDT OSS,LDT 0,028 L$.LDT LITH.LDT 60,344 SS1,LDT SSHV.LDT 1190,000 S1RH.LDT CaLI.LDT 9,758 SGR,LDT MTE~.LDT 152,038 MRE$,LDT ENRA.CNL 4.149 CFEC.CNb RCEM.CNL 2905.540 MPMI,CNL RTNR.CNL 2.905 NPOR,CNL CNTC.CNL 2756.022 CFTC,CNb C~LI.CN'L 9,758 TENS,CNL HTEM.CNL 63],000 DEPT. 10200,000 SGR.NGT POT~.NGT 1.595 !]RAN,NGT W3NG,NGT 43,4]2 W4NG,NGT MTE~.MGT 151.700 MRE$,,NGT RHOB.LOT 2,742 DRHO,LDT OSS,BDT 0,0~4 L$,LDT LITH.LDT ~3 000 SSI.bDT SSHV.LDT 111~000~ S1RH:'LDT C~LI.LDT 9,875 SGR,LDT MTE~,LOT 15!,700 MRE$'LDT ENRA:,CNL 4,932 CFEC,CNL RCEN,CM5 2828,654 NPHI,CNL RTNR.CNL 3,54.9 NPOR,CNL CNTC,CML 2052'206 CFTC,CNb CALI,CNL 9,875 TEN$.CNL HTEM,CNL 645,500 DEPT,, 10100.000 MGR':NGT POT~'NGTw3NG'MGT 3~'780 URAN.NGT ,~920 W4NG'NGT MTE~ MGT 149,900 MRES.'NGT RHOB~LDT 2,4,72 DRHO,LDT OSS.LDT 0,0~0 LS:,LDT LITM,LDT 46,844 SSt,bDT $$HV,LDT ~190,000 S!RH'bDT CALt,LDT 9,906 SGR,LDT MTE~,LDT 149,~900 MRE$,LDT ENRA,CNL ~ .783 CFEC'CNb ~c~.c~b ~74 1:3o9 ~PHZ'C~b RTNR,CNL 3,024 NPOR,CNL C~LI,CNL 9~=906 TEN~.CNb HTEM,CNL 644'O00 DEPT. 10000.O00 SGR.NGT POT~,MGT 2,117 URAN,NGT ~3NG.MGT 46,4!3 W4NG,NGT MTE~,MGT 147,988 ~RE$,NGT 28-~AY-!993 13:34 48.913 CGR.MGT 3.132 W1NG.NGT 3.145 W5NG.NGT 0,102 CS,NGT 0.003 PEF,bDT 268.750 LU,BDT 185.500 S$2,LDT 2,400 LS~H,DDT 48.913 CGR,DDT 0.102 HTEN,LDT 761,~30 C~EC,CNL 28,~3 T~PH.CNL 25. 1 RCNT,CNb 1087.306 SGR.C~L 28.450 139.413 2.096 1889.000 3.311 257.750 249.125 ~.414 28.450 633.000 3~60.772 26.650 2881.355 48.91] 152,O38 70,78g CGR.NGT §.67 WlNG.NGT 8.475 W5MG'NGT 0,102 C$,NGT 0,003 PEP,bDT ~6~,625 LU,bOT ~67,750 SS2,LDT 2-721 LSRH,bDT 32i 6 CNEC,CNb 637 698 TNPH-CNL 4i.004 RCNT'CNL 62~,~96 SGR,CNL 49! ,000 MTEM,CNL 55 2 13.771 1904.000 7.379 170.875 209.375 2.730 55~762 645:500 3118.295 38,279 1959'i~2 79,787 151.700 61,045 l. 5 ~ 6 5, ::2 74 0'104 -~.003 24 i 500 179~500 2.480= 61.045 0:1~4 68 ooo 4O CGR*NGT 51' O08 W1NG,NGT 18~ 435 W5NG'NGT 384 CS,NGT 1922.000 PEF'hDT 5.168 LU,LDT ~37.750 LSRH,LDT 2,469 CGR'bDT 5!,=008 HTEN,bDT 64.4~000 CNEC*CNb 2911..!58 TNPH':CML 33,011 RCNT,CNL 2057.!93 SGR,CN5 61 045 MTE~,C~b: 1491~900 67,354 CGR,NGT 46 ~66 3.136 WlNG'NGT 198:12 4,219 W5NG,NGT 5,274 0.105 CS,,NGT~.. ~ ~!917'000 THOR,NGT W2NG,NGT TENS,NGT HTEN.NGT OBS,LDT LL.LDT BSHV.LDT LURH.LDT TENS.bDT ENPH.CNL RCEF.CNL TNRA.CNL RCFT,CNL CGR.CNL MRES.CNb THOR,NGT W2NG,NGT TENS,NGT HTEN,NGT OLS,LDT LL,LDT LSHVLDT TENS.LDT EMPH.CNL RCEF,CNL TNRA,CNL RCFT.CNL CGR,CNL MRES.CNL THORi, NGT W2NG*~GT TENS. GT HTEN,NGT QL$,LDT Lb.bDT bSMV.LDT LURH.LDT TENS,bDT ENPH,CNL RCEF.CNL RCFT Nb CGR,CNL MRES,CNL THOR. N GT W2NG:NGT :TEMS, NGT HTEM,NGT PAGE: 3,639 76.520 4875,000 633.000 -0.003 139,875 1249.000 2,428 4875,000 24,057 744,982 2,731 1028.027 28.450 0.102 9.731 121.822 4915.000 645.500 -0,046 78,188 1250.000 2.736 4915,000 31.353 624'917 3,311 564'560 55,762 0.i02 7 69 4960 ! 644::~00 '0,008 125 688 1249 000 2 484 4960 000 29 879 586,65! 2.953 660'076 51,008 0,104 oI:: 266 4825. 000 673 · 500 11 I8 Tane Ver~fication Listing chlumberger Alaska Computing Center RgOR.LDT 2.503 DRHO.LDT OSS.LDT 0.035 L$.LDT L~TH.LDT 57.969 S$1,LDT $SHV,LDT llgi.o00 S1RH.LDT CALI.LDT 10.023 SGR.LDT MTEM.LOT 147.988 MRE$.LDT ENRa.C~L 3,795 CFEC.CN5 RCEN.CNL 3146,835 NPHI.CN5 R?N~.CNL 2.373 NPOR.CNL CNTC.CNL 2864.9!4 CFTC.CNL CALI.CNL 10.023 TEN$.CNL HTEN.CNL 673.500 DEPT. 9900,000 SGR,NGT POTA.NGT 2.984 URAN.NGT W3NG.NGT 68.856 W4NG.NGT MTE~.NGT ~46.413 ~R£S.NGT RMOB.LDT 2.345 DRHO.LDT ~S$.LDT 0,055 L$.LDT LITM.LDT 87.750 $$1.LDT $SMV.LDT 1190,000 $1RH.LDT CALI.LDT 10.703 SGR,LDT MTE~.LDT 146.4~3 ~RES.LDT ENRA.CNL 5.348 CFEC.CNL RCE~,CNL 2323,613 NPHI.CNL R:TNR,CNL 3,636 NPOR.CNL CNTC,CNL !688.$t2 CFTC.CNL CAL!.CNL 10'703 TEN$.CNL ~TEN.CNL 796.500 DEPT. 9800.000 SGR.NGT POTA,NGT ,832 W4NG.NG~ MTEM,NGT 143.8~5 R~OB.LDT 2,434 OSS,LDT 0.031 L$.LDT L!TM.LD'T 72.'313 S$1,LDT SSHV.LDT 1190.000 S1RH.LDT CALI.LDT 10,211 SGR,LDT MTE".LDT ~4] ~5 'RES.LDT EMRA CNL : 61 CFEC,=CNL, RCEM:CNL 3041,550 NPHI,CNL RTN~,CML 2,618 MPORi, CNb CMTC.CNL ~857,697 CFTC,CNL ~A~!,CNL 10,211 TEN$,CNL NTEN,CNL 722,000 28-~AY-1993 13:34 -0.003 PEF.LDT 236.375 LU,LDT 178.000 S$2.LDT 2.510 LSRH,LDT 67,354 CGR,LDT 0.105 HT~N.LDT 9~7.916 CNEC,CNb 23.056 TNPH,CNL 23,166 RCNT,CNL 1202,402 SGR,CNL 4~25.000 ~TE~.CNL 173.935 14.932 8.475 0.106 0.121 375.000 228.500 ,976 17 .935 0,106 480 725 38 088 42 440 494 5O3O 000 CGR.NGT wING.NGT W5NG.NGT CS.NGT P~F.bDT LU..LDT $$2.LDT LSRH.LDT CGR,LDT HTEN.LDT CMEC,CNb TNPH,CNL RCNT.CNL SGR.CNL MTEg.CNL 96 921 12,739 0 08 276.750 9 .921 8 24, 59 1~30.{~58 4890.000 CGR.NGT WlNG.NGT WSNG,NGT C$.NGT PEF.LDT LU,.LDT S$2,LDT LSRH,LDT CGR'LDT HTgN.LDT CNEC.CNL TNPH.CNL RCNT.CNL $GR,CNL MTEM,CNb DEPT. 9743,500 SGR,NGT 99.236 CGR,NGT POT~..GT 2.952 URAN:.NGT ~.~5 WlNG.NGT W3NG.MGT 53,-i91 ~4NG.NGT , 4 W5NG.NGT MTE~.NGT 143,094 MRE$'NGT 0.109 C$.MGT RHOS.LDT 2.427 DRHO.LOT 0 00! PEF.LOT OS$.LDT 0.007 L$.LDT 270:000 LU.LDT LITM,LDT 74~,563 SSi,bDT 18~.000 $S2.LDT SSHV,LDT 1190,000 S1RH,LDT 2.416 LSRH.LDT 3.289 229.625 233.125 2.498 46.866 673.500 3483.617 24.246 3000.937 67.354 147.988 76.394 587.924 10.593 1926.000 ~50 303.500 2.217 76.~94 796. 00 2570.764 39.887 1620 248 173:935 146.413 65 331 320i594 7 431 1931,.000 2,980 263,250 260,250 2 40~ 65 33 722 000 3265 348 26 334 2929 436 96 25 74.446 290.426 8.511 1976.000. 3.1.58 259..000 ~53,750 2.420 OLS.LDT LL.LDT LSMV.LDT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL CGR.CNL MRES.CNL THOR,NGT W2NG.NGT TENS,NGT HTEN.NGT OLS.LDT LL.LDT LSHV.LDT LURH,LDT TEMS.LDT ENP~.CNL RCEF.CNL TN~.A.CNL RCFT,CNL CGR,CNL ~RES.CNL THDR.NGT ~2NG.NGT TEN$.NGT HTEN.NGT OhS.LOT LL.LDT LSHV.LDT LURH.LDT TENS.LDT ENPH CNL RCEFiCNL TNRA CNL RCFT,CNL CGR.CNL MRES.CNL THOR NGT W2NG,NGT TEN$,NGT HTEN.NGT OLS.LDT LL bDT LSHV!LDT LURH LDT PAGE: 12 0.000 121,625 1250,000 2.508 4825.000 20.912 874.078 2.401 1130,274 46.866 0.105 10.010 231.992 5030.000 796.500 -0,023 198,000 1249,000 2,227 5030.000 35,323 492,537 3'401 492'537 761.394 0.106 144 374 4890~000 722000 0 006 145,!25 1249~000 2 414 4890 000 2~.281 76 ,862 1069, .: ! 77 4865 00 734;600 '0,003 140 5OO 1249 000 2 424 Tape Verification Listing chlumberoer AlasKa Computing Center 28-MAY-1993 13134 PAGE: 1¸3 CAL!.LDT 10,055 SGR.LDT MTE~.LDT 143.094 MRE$,LDT E~RA.CNL 3.876 CFEC.CNL RCEN.CNL 3005,036 NPHI.CNL RTN~,CNL 2,824 NPOR,CNb CNTC,CNL 2774,640 CFTC,CNL CALI.CNL 10.055 TENS.CNL HTEN.CNL 734.000 99,236 CGR,LDT 0.109 HTEN,LDT 840,747 CNEC,CNL 25.440 TNPH.CN5 28,344 RCNT,CNL 1083.585 SGR.CNL 4865,000 MTEM.CNL 74.446 . 26.917 2701,813 99.236 143.094 TENS.LDT ENPH.CNL RCEF.CNL TNRA.CNL RCFT.CNL CGR.CNL MRES.CNL 4865.000 21.589 806.404 2.563 1043,542 74,446 0.109 ** END OF DATA *~* FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01A07 DATE : 93/05/28 MAX REC SIZE : ~024 FIL~ TYPE : LO L~ST FILE : S~RVICE : FLIC V~RSION : O0~AO7 DAT~ ~ 93 05/~8 ~AX REC sIZE : ~024 FIL~ TYPE : LO LAST FILE ~ FTLE HEADER RAW OPEN HOLE Curves and RU~ NU~BE~: TOOL STRING NUMBER~ PASS NUMBER: DEPTH INCREMENTI VENDOR TOOL CODE BDT # LOG HEADER DATA DATE LOGGED: 3 REPEAT PASSES lo~ header data ~or each Da~, O,50OO START DEPTH ~0477.0 ~049~.0 I0504.0 too1 string, STOP DEPTH 9746,0 9746,0 9746,0 and run in separate ~iles' I5 Ta~e ver.~f~.cation Listing chlumberger Alaska Computing Center 28-MAY-1993 13:34 PAGE: 14 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRItLER (FT): TD LOGGE~(FT){ TOP LOG INTERVAL (FT): ~OTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TCC TCM NGT NGT NGT NGT CML bDT LDT $ CP 32.6 1300 10530.0 10521.0 9746.0 10519.0 1800.0 TOoL NUMBER '"'"'" AUXILblARY MEASUERMENTS AMM-A TELEMETRY CARTRIDGE TCC-B 420 TELEMETRY MODULE TC,-A 19 NGT DETECTOR MGD-D 756 NGT GAMMA RAY CARTRIDGE NGC-B 1935 NGT SOURCE NSR-FA 226 NGT SOURCE GSR-JD 7271 NGT CARTRIDGE NSC-E 760 CNTG CARTRIDGE CNC-G 65 CNTG HOUSING CNC-H ~27 DENSITY-RESISTIVITY DRS-C 4847 POWERED GR DETECTOR PGD-D ~800 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): ROREHOLE CONDITIONS MUD TYPE: ~I.]D FLUID LOSS MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) ~T TEMPERATURE (DEGF): ~UD AT ~EASURED TEMPERATURE (MT): ~UD AT BOTTOM HOLE TEMPERATURE ~UD FILTRATE AT ~TE AT( FILT~A CAKE AT CAKE AT ~EUTRON TOOL TOOL TYPE (EPITHERMAb OR THERMAL): ~ATRI×~ MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF # 6.0 3846,0 KCL/PObY 990 7:oo 9,60 0,260 0,o~g 0,040 17-APR-g3 48.0 48.0 40.0 EpITHER~AL SANDSTONE 2.65 bOG CORRELATED TO W/A DIL RAM 4-t6-93. IS Tape Verification Listing chlumberger Alaska Computing Center 2~-~AY-1993 CNTH RAM TO ECCEMTER CNTG, ~HERMAb NEUTRON POROSITY DERIVED FROM CNTG, D~S FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYP E REPR CODE YAbUE ! 66 2 66 0 3 73 244 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 4 12 68 13 66 0 I4 65 FT 1.5 66 68 16 66 1 0 66 1 mmmmm~mmmm,~mm~mmm~mmmmmmmmmm ** SET TYPE - CHAN ** .---.----...........-,,,,.................-........,...,..........,...................... NA~E SERV UNIT SER API API AP/ APl FiLE N NB ~U~B IZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUmB SAMP ELEM CODE (HEX) D.~P~ FT 59948! O0 000 O0 0 ] ! I 4 b8 0000000000 SgR NGR CGR NGR THO~ NGR POT~ NGR U~AN NGR W~NG NGR W~NG NGR W3NG NGR W4N~ NGR WLNG NOR TMNS NGR MTE~ NOR M~ES NOR CS NOR HTEN NOR RHOB LDR GAPI 599481 O0 000 O0 0 3 GAPI 599481 O0 000 O0 0 3 PP~ 599481 O0 000 O0 0 3 PU 599481 O0 000 00 0 3 PP~ 599481 O0 000 O0 0 3 CPS 59948! O0 000 O0 0 3 CPS 599481 O0 000 O0 0 3 CPS 599481 O0 000 O0 0 3 CPS 599481 O0 000 O0 0 3 CPS 59948~ O0 000 O0 0 3 hB 599481 O0 000 O0 0 3 DEGF 599481 O0 000 O0 0 3 OH~ 599481 O0 000 O0 0 3 F/HR 599481 O0 000 O0 0 3 LB 599481 O0 000 O0 0 3 G/C3 599481 O0 000 O0 0 3 1 1, 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 ! 4 68 0000000000 1 I 4 68 0000000000 t I 4 68 0000000000 I ! 4 68 0000000000 I 1 4 68 0000000000 ! 1 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 ! I 4 68 0000000000 1 ! 4 68 0000000000 1 1 4 68 0000000000 PAGE: 15 IS Tape Verification bistinq chlumberqer AlasKa Computinq Center 28-MAY-lg93 13:34 PAGE! 16 s ,v ;.i. ;;i . KIbE )~UMB NLMB 8IZE REPR PRDCE88 tD ORDER # LOG TYPE ChASS MOD NUMB SAMP ELEM CODE (HEX) ................ ---;;;----;----;;; ....... .,..-....................................,,,.. D~HO LDR G/C] 5 81 0 O0 3 1 1 4 68 0000000 PEF LDR QLS LD~ OSS LDR LS LDR LU LDR LL LDR SS1 LDR $S2 LDR LSHV LDR SSH¥ LDR S1RH LDR LSRH LDR bURN LDR CAb! LDR SGR LDR C~R TENS LDR MTE~ LDR MRES LD~ HTEM LDR ENpH CNR ENR~ CNR CFEC CNR CMEC CNR RCE? CNR RCEM CNR NPH! CNR TNP~ CN~ TNRA CNR RTNR CNR NPO~ CNR RCNT CNR RCFT CNR CNTC CNR CFTC CNR CGR CNR CAb! CNR 599481 O0 000 O0 599481 O0 000 O0 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 O0 000 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 V 599481 O0 000 O0 V 599481 O0 000 O0 G/C3 599481 O0 000 O0 G/C3 599481 00 000 00 G/C3 599481 O0 000 O0 IN 599481 O0 000 O0 GAPI 599481 O0 000 O0 GAP] 599481 O0 000 O0 LB 599481 O0 000 O0 DEGF 599481 O0 000 O0 OH~M 599481 O0 000 O0 GB 599481 O0 000 O0 PU 599481 O0 000 O0 59948~ 00 000 00 CPS 599481 O0 000 O0 CPS 599481 O0 000 O0 CPS 59948! 00 000 00 CPS 599481 O0 000 O0 PU 599481 O0 000 O0 PU 599481 O0 000 O0 599481 O0 000 O0 599481 O0 000 O0 PU 599481 O0 000 O0 CPS 599481 O0 000 00 CPS 599481 O0 000 O0 CPS 599481 O0 000 00 CPS 599481 00 000 O0 GAPI 599481 O0 000 O0 GAPI 599481 O0 000 O0 IN 599481 O0 000 00 TENS CNR hO 599481 O0 000 O0 MTE~ CNR DEGF 599481 O0 000 O0 MRES CMR OHMS 599481 O0 000 O0 HTEN CNR LB 599481 O0 000 O0 0 3 1 0 3 0 3 1 o 3 0 3 0 3 0 3 1 0 3 0 3 0 3 0 3 1 0 3 1 0 3 1 0 3 0 3 0 3 0 3 1 0 3 ! 0 3 0 3 1 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 1. 1 1 1 1 I 1 1 1 1 1 1 1 1 1 t 1 1 t 1 1 1 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 t 4 68 0000000000 ! 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 00:00000000 I 4 68 0000000000 1 ~ 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 I 4 68 0000000000 IS Tape verification blsting chlUmberger Alaska Computing Center DEPT. 10530.000 SGR.NGR POTA.NGR 0,000 URAN.NGR W3NG,NGR 76,923 W4NG,NGR MTE,,NGR 146,975 ~RE$,NGR RMOB.LDR 2.027 DRHO.LDR OSS LDR -0,009 L$,LDR LITH~LDR 113.750 SSI.LDR SSHV,bDR 1189,000 SlR,,hDR CALI,LDR 2.617 SGR,LDR MTEM,LDR 146,975 MRES,LDR ENR~.CNR 6.328 CFEC.CNR RCEN,CNR 223~,607 NPHI,CNR RTNR.CNR 4,000 NPOR.CNR CNTC.CNR 1564,797 CFTC,CNR CALI.CNR 2,617 TENS.CNR HTEN.CNR 100.313 DEPT 10500,000 SGR,NGR POT~:NGR 3.6~6 URAN,NGR W3NG NGR 76,923 W4NG,NGR MTEM~NGR 146,975 MRE$,NGR R~OB.LDR 1,752 DRHO,SDR QS~,LDR -0,082 LS, LDR LITW.LDR 166.500 S$1,LDR $SHV,LDR ~1.~9.000 $1RH'LDR CADI,LDR 13,914 SGR,LDR MTEM.,LDR 1146,975 MRE$*LDR ENRA.CNR 6,6~7 CFEC.CNR RCE~,CN~ 2178,253 NPHI,CNR RTNR,CNR 3.887 NPOR,CNR CNTC,CNR 1525-151 CFTC,CNR CALI,CNR 13,914 TEN$,CNR HTEN,CNR 750,500 DEPT,, 10400.000 SGR'NGR POTA,NGR 1,249 URAN,iNGR W3N'G,NGR .29,851 W4NG,NGR ~TE~,NGR 148,325 MRES*NGR RHOB.LDR 2,267 DRHO,LDR O$$.LDR 0,004 L$*LDR LITH,LDR !10.i.375 $$1,LDR SSHV ~DR I~90'000 SlRH,'LDR CALI:~DR 9,~58 SGR*LDR MTEM,LDR 1.48,325 MRES,LDR ENRA,CNR 4,492 CFEC,CNR RCEN CNR 2756,335 NPHI*CNR RTN~:CNR 2,551 NPOR'CNR CN~TC.CNR ~689,634 CFTC,CNR CAL!,CNR 9,758 TENS,CNR HTEN.CNR 635,500 D~PT.. 10300,000 SGR-NGR POT~,NGR 1.108 URA. N'NGR W3NG,NGR '~7'7t9 W4NG,:NGR MTEi NGR 149,900 ~RES*NGR 28'MAY-1993 13:34 0.000 CGR.NGR 0.000 W1NG.NGR 13.575 W5NG,NGR 0.112 CS.NGR 0.008 PEF.LDR 532,000 LU,LDR 208,250 SS2,LDR 1,982 5SRH,LDR 0,000 CGR,LDR 0.112 HTEN,LDR 38t.236 CNEC.CNR 56.351 TNPH.CNR 47.007 RCNT.CNR 415,970 SGR,CNR 2565,000 MTEM,CNR 101 ~6 CGR.NGR 13 575 W5NG,,NGR 0.112 CS,NGR !!006 PEF LDR 000 LU.LDR 2! 000 $S2,LDR 1.782 LSRH,LDR 101,3!6 CGR'LDR 0.112 HTEN'LDR 347.734 CNEC.CNR 42.409 TNPH.CNR 39,852 RCNT,CNR 436'272 SGR,CNR 5{90.000 MT£M-CNR 40,7~2 CGR,NGR 1.B 9 W1NG.'NGR 9,595 WSN.G,NGR 0,109 CS,NGR '0.011 PEF,bDR 345,750 LU,LDR 18~,375 $$2,LDR 40, CGR,bDR 66~,i09 HT£N,LDR .00] CNEC,CNR 2~,627 TNPH,CNR 2 ,'979 'N RC.T,CNR i073'342 SGR.CNR 5050'000 ~TE~.CNR 0.000 294.118 7.919 183.750 4.117 493.250 317.250 2.016 0.000 100.313 2412.436 47,007 1585,686 0,000 ~46.975 77,109 294.118 7,919 1895.000 5,750 786,000 373 ~00 57 77:,!09 750.500 2300.959 39'242 1524,964 101.316 146,975 27 628 114 072 3 198 1890 000 3 279 3.18 250 264,250 2:,:275 27~.,:628 635 500 2973~.943 26=,,294 2750:,i::479 40 702 I48 325 47' 917 CGRi. NGR 32'384 2 * 232 w I N G. N G R 143 :'. 923 8,529 WSNG,NGR 4,:264 0.108 'CS.:NGR I880.000 THGR.NGR W2NG.NGR TENS,NGR HTEN.NGR OLS.LDR LL,LDR LSHV,LDR LURH,LDR TENS,LDR ENPH.CNR RCEF.CNR TNRA,CNR RCFT,CNR CGR.CNR MRES.CNR THOR NGR W2N~:NGR TEN$.NGR HTEN.NGR QLS,LDR LL,LDR LSHV,LDR LURH.LDR TENS,LDR ENPH.CNR RCEF.CNR TNRA,CNR RCFT,CNR CGR.CNR ~RES*CNR THOR,NGR W2NG,NGR TEN$.NGR HTEN,NGR QLS-LDR LL.LDR LSHV.LDR T~; .LDR ENPH ~NR TNRA,CNR RCFT.CNR CGR.CNR MRE$,CNR THOR,'NGR W2NG, NGR TEN$.NGR HTEN. NGR PAGE: 17 0,000 148.190 2565.000 100.313 -0,012 285.750 1249,000 2,033 2565.000 51.370 372.811 3,849 391.088 0.000 0,112 6,063 148,190 5190 000 750:500 -0,014 437,000 1249,000 000 49,!43 ~41:452721 43i'797 77,109 0.112 2,471 58 635 5050:000 635*500 0.025 !86.500 1250.000 505~ .291 ,000 27,176 670,958 2,551 1019,530 27,628 0,1:09 501 o. ooo 626'500 IS Tape Verification Listinq chlumberger AlasKa Computino Center RHOS.LDR 2.253 OSS.LDR 0.014 LITH.£.DR 94.438 SSHV.6DR 1190.000 CALI.LDR 9.711 aTEM.LDR 149.900 ENRA.CNR 4.241 RCEN.CNR 2644.104 RTNR.CNR 2.746 CNTC.CNR 2719.057 CALI.CNR 9.711 HTEN.CNR 626.500 DEPT 10200.000 POTA:NGR 1,7~7 W3NG.NGR 44 776 MTE~'.NGR 149:563 RHOB.LDR 2.512 0SS.6DR 0.027 L!TH.LDR 47.000 C~LI.LDR 9.609 ~TE~.LDR ~49.563 ENR~.CNR 4.259 RCEN.CNR 2908.472 RTNR.CNR 2.707 CNTC..CNR 23~7.605 CALI.CNR 9.609 HTEN.CNR 637.000 D~PT.: 10i00,O00 POT~.NGR 1.597 W3NG,NGR 35'857 NTE~.NGR 148,100 R~OB.LDR 2,553 O$~.SDR 0.022 LIT...,LDR 34,O31 SSHV'LDR 1191.000 CALi.LDR 9.758 ~TE~,LDR 148'100 ENRA CNR 5.110 RCE~CNR 2596'327 RTN~,CNR 3'523 CNTC CNR i896,5~6 HTEN CNR 673.500 D.~PT, 10000,000 POTA.~GR !,I~5 W3N~ NGR 28.,602 NTE~'NGR 1.46 244 · . R~OB.LDR 2,518 OS$.LDR 0,019 LITM.LD~ 54.938 SSM~.LDR ~192.000 DRHO.LDR LS.LDR $SI.LDR S1RH.LDR SGR.LDR ~RES.LDR CFEC.CNR NPHI.CNR NPOR.CNR CFTC.CNR TEN$.CNR SGR.NGR URAN.NGR W4NG.NGR ~RES.NGR DRHO.LDR L$.LDR SSI.LDR S1RH.LDR SGR.LDR MRE$.LDR CFEC.CNR NPH!.CNR NPOR,CNR CFTC.CNR TENS.CNR URAN.NGR W4NG.:~NGR MRE$,NGR DRHO, LDR LSLDR SSi~LDR $1RH~,LDR SGR LDR MRESLDR CFEC~CNR NPHI.CNR NPOR.:CNR CFTC~CNR TEN$~CNR SGR.NGR URAN-:NGR w4NG:.NGR MRE$,NGR DRHO,LDR L$'LDR SSi LDR St Hi: DR 28-MAY-1993 13:34 '0.011 PEF.LDR 350.750 LU.bDR 186.500 $$2.LDR ~.303 LSRH,LDR 47.917 CGR.LDR 0.10~ HTEN.LDR 681.220 CNEC.CNR 27.448 TNPH,CNR 28,591 RCNT,CNR 1029.766 $GR,CNR 5010,000 MTE~.CNR 70.~]4 CGR.NGR 2, 5 W1NG,NGR 11,727 WSNG NGR 0.109 C$:NGR 0.007 PEF.LDR 232.625 LU.LDR 152.500 SS2.LDR 2.475 LSRM.LDR 70.774 CGR.LDR 0.109 MTEN.LDR 720.955 CNEC,CNR 25.650 TNPH'CNR 27,545 ~CNT.CNR ~80.610 SGR,C~R 4985,000 MTEM,CNR 61.437 CGR.NGR 1,977 W1NG.,NGR 2,988 W5NG-NGR 0,:111 CS,NOR '0.006 PEF,SDR 211,~75 !73, 50 SS ,-bOR 2.5~ bS~H,SDR 61'43 CGR'bDR 0,111 HTEN'LDE 560,9~9 CNEC,CNR 40.6~1 TNPH,CNR 36-762 RCNT,CNR 58 ~489 500~ SGR,CNR .000 MTE~.CNR 53.577 CGR.NGR 2-240 WiNG'NGR 8.475 W5NG.NGR. 0,1.12 CS,NG~ 0,003 PEF'LDR 23~,000 LU.5DR 179~750 SS2'LDR 2.502 3.512 328.500 263.250 2.262 32.384 626.500 2889.103 28 375 47.~17 ~49. 00 21 . 50 6.397 1896.000 5.879 225.625 241 125 2:502 56.612 637.000 3070.472 28.490 '~74 149.563 47-677 192.231 !90~ '98'0 .000 ':242 209.000 228.125 ~',557 47.:677 673.500 2866.245 37'601 1959'i16~ 61 7 00 37'984 1907.1000 4.602 226,500 239 0 QLS.LDR LL.LDR DSHV.LDR DURH.LDR TENS.LDR ENPH.CNR RCEF.CNR TNRA.CNR RCFT.CNR CGR.CNR MRES.CNR THOR.NGR W2NG.NGR TEN$.NGR HTEN.NGR OLS.LDR 5L.LD~ 5$HV.LDR LURH.DDR TENS.LDR ENPH.CNR RCEF CNR TNRA:CNR RCFT,CNR CGR,CNR ~RES.CNR THOR,NGR W2NG.NGR TENS'NGR HTEN.NGR OL$.LDR LL.LDR LSHV'LDR LURH.LDR ~EN$.LDR EN~.CNR RCEF'CNR TNRA,CNR RCFT.CNR CGR.CNR ~RES.CNR THO.'NGR W2NG.NGR TEN$.NGR HTEN:.NGR OL$,LDR 5L,LDR LSBV.LDR DURH,LDR PAGEI 18 -0.002 186.625 1251,000 2.271 5010,000 24.894 653,610 2,669 949.569 32,384 0,108 8.501 98.081 4985,000 637.000 0 005 119:813 1251.000 2.520 4985,000 25,089 683,214 2 542 861:997 56.6~2 0,'109 9 614 500~,000 3,50O Io:oo 106.813 1251,1000 576 soo :ooo 33'183 539-875 3'428 531'248 '47,677 0,111 5,596 86,864 4970.000 676.500 -0.'012 117'688 1251:000 '518 IS Tape Verification Listing chlumberger AlasKa Computing Center CAL!.LDR 9.9o6 SGR.LDR ~TEM.LDR 146.244 MRES.LDR ENR~.CNR 3.681 CFEC.CNR RCEN.CNR 3030.643 NPHI.CNR RTNR.CNR 2.423 NPOR.CNR CNTC.CNR 2895.813 CFTC.CNR CALI.CN, 9.906 TEN$.CNR HTEN.CNR 676.500 DEPT 9900.000 SGR.NGR PDTA:NG~ 2.9~2 W~NG.NGR 89,172 W4NG.NGR MTE~.NGR 144,7~5 ~ES.NGR 9~GB.LDR 2,632 DRMO,LDR OSS.LDR O,024 L$.LDR LIT~.LDR 49.344 $SI.LDR SS~V.LDR 1191.000 $1RH LDR CaLI.LDR 10.523 SGR:LDR MTE".LDR 144.725 ~RES.LDR E~R~.¢~R 4.83~ CF~C.CN~ RCEN.CNR 2662.864 NPMIoCNR ~TNR.CNR 3 424 NPOR,CNR CNTC.CNR 17852636 CFTC,CNR CA~.C~ 10.523 ?ENS.CN~ HTEN.CNR 767,500 DEPT, 9800,000 SGR'NGR POT~,NGR 1o944 URAN,NGR W3NG.NGR 66,737 W4NG,NGR ~TE~.NGR 142,250 M~E$-NGR RHOB.LDR 2.343 DRHO:,LDR QSS.LDR o o15 LITH,LDR. g0:750 $$1,5DR $SHV LDR 1191.000 SIR. H,LDR CAL!:LDR 10,086 SGR'LDR MTE~:LD~ 142'250 MRE$'LD~ ENRA C~R 4,268 CFEC'CNR RCEN-CNR 2834,:860 NPHI,CNR RTNR,CNR 2.':718 NPOR,CN~ CNTC,CNR 2720'7]0 CFTC,CNR CALI,CN~ 10,086 TENS...CNR HTEN.CNR 722,000 DEPT 9745,000 SGR'NGR POTA'NGR 2,763 W3NG~NGR 49,894 W4NG,NGR ~TE~,NGR 141,7.44 HE£$-NGE RHOB,LDR 2'427 DRHO,LDR OSS.LDR 0.024 LS,LD~ LITH LDR 69'i125 SS1,LDR SSHV:LD~ 1191.000 C~LI.LDR 10'078 SGR*LDR ~TEM.LDR !41,744 MRES,.LDR ENRA CNR 3,975 CFEC'CNR ~CEN]C~ 32~6.6~5 ~PH~.C~R 28-MAY-lq93 13:34 53.577 CGR,LDR 0.112 891.941 CNEC,CNR 24.417 TNPH.CNR 23.609 RCNT.CNR 1207 064 SGR.CNR 4970~000 MTEN.CNR 151.551 CGR,NGR 13.300 WING,NGR 13.800 W5NG.NGR 0.113 CS.NGR 0.O75 PEF.LDR 216,500 LU,LDR 196,500 S$2.LDR 2.391 LSRH.LDR 151.551 CGR: 5DR O.113 HT£N:5DR 583.622 CNEC,CNR 36.460 TNPH'CNR 35,570 RCNT,ChR 545.564 SGR,CNR 5025°000 ~TE~.CNR 84 920 CGR,NGR 4i861 WING,NGR tl 653 W5NG, NGR 0 14 CS,NGR 01:~27. PEr'LDR 84 20 CGR.LDR 0 114 HTEN,LDR 718:1 98 CNEC,CNR 5,710 TNPH,CNR 6-651 RCNT, CNR I04~,800 SGR,CNR, 477 .000 9 ~ 784 8.493 0,!14 0.003 268.250 185'000 2;408 91.784 25,i90 37.984 TEN$.EDR 5 . 77 o .ooo 58.988 TENS.LO, 767:~00 2820 69 RCEF CaR ~7.717 ?~:c~ 1901 606 RCFT.CNR 151~55~ CGR..CNR 144.725 ERE$.CNR 51.088 THOR'NGR 258.475 484 OLS,SDR 306,250 L5,LDR 277'.750 5SHV,LDR 2-314 LURH,LDR 51.088 TEN$'LDR 722.,.000 ENPH.CNR 3066,230 27,:522 TNRA.CN~ 2825.791 RCFTiCNR 84 920 CGR.CNR CGR.NGR 68 ~ THOR NGR W5NG, NGR: 9,554 TENS'NGR CS,NGR 1950.000 HTEN,NGR PEF,LDR 2,~959 QLS.LDR LU,bDR 254,000 LL.LDR SS2-bDR! 249,.500 LSHV.LDR LSRH-hDR~ 2,420 LURH.LDR CGR,LDR 68,355 TEN$,LDR. HTEN,LDR 736'~500 ENPH,CNR CNEC'CNR 3221.885 RCEF,CNR PAGE: 19 4970.000 19.990 872.209 2.482 1123.757 37.984 0,112 4,174 231. 22 5025,000 767.500 -0.023 108,813 1251,000 2,555 5025 000 o: 71 548.505 3.297 512,899 58,988 0,113 6,077 11~:466 477 :000 000 50 '25.020 719'436 989 09 88 7,464 144,374 4800~000 736,500 0.020 141,250 1251, 000 4800,000 22.432 790,905 2.548 Tape v~rlflcatlon Listing chlumberger Alaska Computing Center 28-~AY-199~ 13:34 PAGE: RTNR.C.RN 2.536 NPOR.CNR CNTC.CNR 2633.956 CFTC.CNR CALI.CNR 10.078 TEN$.CNR HTEN.CNR 736.500 25.679 RCNT.CNR 1026.448 $CR.CNR 4800.000 MIE~.CNR 2771.414 RCFT.CNR 91.784 CGR.CNR 141.744 MRE$.CNR 971.595 68.355 0.114 END OF DATA **** FILE TRAILER **** FIbK NA~E : EDIT .003 $~RVICE : FLIC VERSION : 001A07 DATE : 93/05/28 ~AX REC SIZE : 1024 F~L~ TYPE ~ LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 93/05/28 ORIGIN : FLIC TAP~ NAME : 9~.175 CONTINUATION ~ : ! PREVIOUS TAPE : COMMENT : ARCO: ALASKA INC.,pOINT ~CI T 1 :I, N:~YRE,P - 7 50-029-22358-00 **** REEL TR~:ILER SKRVICE NAME : EDIT DATK : 93/05/~8 ORIGIN : FLIC REEL NA~E: . : 93175 CONTINUATION # PREVIOUS REEL : COMMENT : ARC© ALasKA INC.,POINT MCINTYRE,PI-17,50-0~9-~358-O0 ARCO ALASKA INC' PI - 17 POINT MCINTYRE RECEIVED JUN 1 7 1993 Oil & Gas Cons. Commission .:-"~% ~"~,~;~:% ,,/',. ~%. .[:'-.. Run 1' 16 - April - 1993 DLLJCN/ZDI_/GR 7738 10465 Tape Subfile 2 is type: LIS TAPE HEADER POINT MCINTYRE UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: RUN1 5929.00 BRAD ESARY JOHNSON/DEAL P1 - 17 500292235800 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 29-APR-93 RUN2 RUN3 16 12N 14E 1399 865 50.00 9.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 3848.0 9.875 10520.0 DLL/CN/ZDL/GR CIRCULATION STOPPED @ 06:00 16-APR-93. COMPENSATED NEUTRON IS CALIPER CORRECTED, CHISM FILTER- ING NOT ACTIVE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth (including cased hole). DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GR DLL 2435 SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH 7738.0 7738.0 7738.0 7738.0 GR (MEASURED DEPTH) BASELINE DEPTH 7733.0 7741.5 7745.5 7749.0 7759.0 7769.0 7775.5 7815.5 7821.5 7822.0 7829.0 7831.0 7844.0 7857.5 7860.5 7866.0 7866.5 7868.5 7873.0 7877.0 7877.5 7909.0 7930.5 7939.5 7943.0 7968.5 7979.5 7993.5 7999.5 8002.5 8032.5 8066.0 8073.5 8127.5 8141.0 8151.0 8172.0 8172.5 8179.0 8184.5 LL3 7733.0 7745.5 7759.0 7822.0 7860.5 8002.5 8172.5 shifted and clipped curves; all runs merged STOP DEPTH 10413.0 10465.0 10420.0 10437.0 EQUIVALENT UNSHIFTED DEPTH ......... LLD RHOB NPHI 7733.0 7733.0 7733.0 7741.5 7821.5 7748.5 7759.0 7759.5 7769.0 7769.0 7775.5 7815.0 7821.5 8032.5 8127.5 7828.0 7843.0 7860.0 7865.5 7867.5 7876.5 7908.0 7930.5 7943.0 7968.0 8000.0 8001.5 8141.0 8171.5 7830.0 7843.0 7857.5 7860.0 7865.0 7873.0 7876.5 7908.0 7930.5 7939.5 7968.0 7980.0 7993.0 8000.0 8001.5 8066.0 8073.5 8141.5 8151.5 8171.5 8184.5 8178.5 8191.0 8208.5 8212.0 8214.5 8286.5 8287.0 8289.5 8343.0 8359.5 8369.5 8370.0 8388.0 8393.0 8398.5 8407.0 8430.5 8448.0 8525.0 8536.0 8609.5 8701.5 8702.0 8788.5 8800.5 8807.0 8812.5 8952.0 8952.5 9156.5 9157.5 9259.5 9319.5 9326.0 9356.5 9357.0 9427.5 9431.0 9445.5 9506.5 9555.5 9558.0 9561.5 9578.5 9585.0 9592.5 9596.0 9602.0 9607.0 9616.0 9616.5 9621.0 9627.0 9629.0 9640.0 9645.0 9649.5 9659.0 9663.5 9664.5 9665.5 8209.5 8212.5 8287.5 8290.0 8370.5 8399.0 8702.5 8952.5 9357.0 9555.0 9596.0 9607.5 9615.5 9627.0 9645.0 8215.0 8287.5 8286.5 8393.5 8388.0 8536.0 8701.5 8801.0 8807.5 8812.5 8952.0 8952.0 9157.5 9356.5 9319.5 9326.0 9356.5 9431.0 9506.0 9561.0 9578.5 9592.5 9602.5 9607.5 9621.0 9616.0 9628.5 9649.5 9664.5 9665.0 8190.5 8286.5 8342.5 8359.5 8369.5 8388.5 8407.5 8430.5 8448.5 8525.5 8609.5 8788.5 8951.5 9156.5 9259.5 9326.0 9356.5 9427.0 9445.5 9558.5 9585.0 9607.5 9616.0 9640.0 9659.5 9664.0 9670.0 9671.5 9675.0 9691.0 9694.0 9698.0 9701.0 9703.0 9708.0 9713.0 9718.0 9724.5 9725.0 9726.0 9727.0 9733.0 9740.5 9749.0 9760.0 9762.5 9763.5 9764.5 9766.5 9772.0 9774.5 9784.0 9798.5 9799.0 9800.5 9802.0 9802.5 9807.0 9808.5 9815.0 9816.0 9842.5 9847.5 9854.0 9858.0 9859.0 9881.0 9903.0 9904.0 9904.5 9909.5 9914.0 9920.0 9920.5 9927.0 9933.0 9933.5 9943.0 9948.0 9949.5 9951.0 9961.5 9974.0 9976.5 9986.5 10001.0 9697.5 9708.0 9713.5 9740.5 9760.0 9771.5 9801.0 9803.0 9808.0 9854.5 9903.5 9909.5 9920.0 9933.5 9943.5 9949.5 9702.5 9718.5 9725.5 9726.0 9762.5 9763.0 9774.0 9784.0 9799.0 9809.5 9816.0 9843.0 9858.5 9859.0 9881.0 9902.5 9914.0 9961.5 9974.0 9976.0 9670.0 9675.0 9694.0 9701.0 9707.5 9713.5 9725.0 9733.5 9766.5 9802.0 9847.5 9853.5 9904.0 9909.5 9920.0 9932.5 9947.0 9951.0 9986.5 10001.0 9671.5 9690.5 9708.0 9727.0 9749.0 9764.5 9772.5 9799.5 9816.0 9848.5 9854.0 9904.0 9921.0 9926.5 9934.5 9951.0 10001.0 10003.0 10011.5 10024.5 10027.0 10033.5 10035.0 10043.5 10047.5 10048.0 10052.0 10056.5 10071.0 10108.0 10118.0 10127.5 10131.5 10143.0 10145.0 10151.0 10170.0 10170.5 10175.0 10182.5 10188.5 10195.5 10196.5 10200.0 10222.5 10223.5 10290.0 10293.5 10347.5 10348.5 10392.0 10401.5 10407.0 10409.0 10414.5 10425.5 10477.0 $ MERGED DATA SOURCE LDWG TOOL CODE GR DLL 2435 SDN $ REMARKS: CN WN FN COUN 10002.5 10026.5 10034.5 10048.0 10118.0 10131.0 10142.5 10182.5 10289.5 10348.0 10027.0 10033.0 10034.5 10047.0 10052.0 10056.5 10108.5 10118.0 10127.0 10131.5 10145.0 10150.5 10169.5 10170.5 10188.5 10196.0 10196.5 10200.0 10222.5 10223.0 10012.0 10025.0 10044.0 10047.0 10056.5 10071.0 10108.0 10143.5 10150.5 10175.0 10289.5 10293.5 10347.5 10347.5 10391.5 10401.0 10407.0 10408.5 10414.0 10425.5 10477.0 10477.0 10477.0 10477.0 RUN NO. PASS NO. MERGE TOP 1 3 7738.0 1 3 7738.0 1 3 7738.0 1 3 7738.0 MERGE BASE 10413.0 10465.0 10420.0 10437.0 TENS, TEND, & MTEM WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : P1 - 17 : POINT MCINTYRE : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GR DLL 68 1 GAPI 2 LL3 DLL 68 1 OHMM 3 LLD DLL 68 1 OHMM 4 SP DLL 68 1 MV 5 MTEM DLL 68 1 DEGF 6 TEND DLL 68 1 LB 7 TENS DLL 68 1 LB 8 NPHI 2435 68 1 PU-S 9 NUCT 2435 68 1 CPS 10 FUCT 2435 68 1 CPS 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 1 IN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 57 515 01 6 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 56 * DATA RECORD (TYPE# 0) Total Data Records: 344 966 BYTES * Tape File Start Depth = 10477.000000 Tape File End Depth = 7733.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82336 datums Tape Subfile: 2 625 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 7738.0 DLL 7738.0 2435 7738.0 ZDL 7738.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON PCM PULSE CODE MODULATOR ZDL Z-DENSITY KNJT KNUCKLE JOINT TEMP TEMPERATURE PCM PULSE CODE MODULATOR KNJT KNUCKLE JOINT MIS MASS ISOLATION SUB DLL DUAL LATEROLOG FTS FEED THROUGH SUB FTS FEED THROUGH SUB $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : STOP DEPTH 10422.0 10474.0 10428.5 10446.0 16-APR-93 FSYS REV. J001 VER. 1.1 600 16-APR-93 1741 16-APR-93 10520.0 10478.0 7738.0 10465.0 1800.0 TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508XA 2222EA/MA 3921NA 2806XA 3506XA 3921NA 3967NA 1229EA/MA 9.875 3848.0 0.0 KCL POLYMER 9.90 20.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P1 - 17 : POINT MCINTYRE : NORTH SLOPE : ALASKA 9.1 5.2 164.0 0.227 0.113 0.227 0.000 0.364 0.000 78.0 164.0 78.0 0.0 78.0 0.0 THERMAL SANDSTONE 2.65 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 785 Tape File Start Depth = 10477.000000 Tape File End Depth = 7733.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 197587 datums Tape Subfile: 3 869 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH GR 9499.0 DLL 9499.0 2435 9499.0 ZDL 9499.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10415.0 10467.0 10422.0 10438.0 16-APR-93 FSYS REV. J001 VER. 1.1 600 16-APR-93 1615 16-APR-93 10520.0 10478.0 7738.0 10465.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN PCM ZDL KNJT TEMP PCM KNJT MIS DLL FTS FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508XA 2222EA/MA 3921NA 2806XA 3506XA 3921NA 3967NA 1229EA/MA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 3848.0 0.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): KCL POLYMER 9.90 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P1 - 17 : POINT MCINTYRE : NORTH SLOPE : ALASKA 20.0 9.1 5.2 164.0 0.227 0.113 0.227 0.000 0.364 0.000 THERMAL SANDSTONE 2.65 0.000 0.0 78.0 164.0 78.0 0.0 78.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DLL 68 1 GAPI RS DLL 68 1 OHM/~ RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 279 68 Tape File Start Depth = 10470.000000 Tape File End Depth = 9494.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 152627 datums Tape Subfile: 4 364 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 93/ 4/29 01 **** REEL TRAILER **** 93/ 4/30 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 30 APR 93 9:lla Elapsed execution time = 1 minute , 17.1 seconds. SYSTEM RETURN CODE = 0 US VERIFICATION ESTING FOR: P1-17 ST-1 ~ POINT MClNTYRE RECEIVED MICROFILMED BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE US TAPE GENERATED FOR ARCO ALASKA INC. P1-17 ST-1 BDCM BDC1 BDEM BDE1 CADE CAD1 CPDE CPD1 DCCM DCCl DLAM DLA1 DPEM DPE1 DPLM DPL1 DPSM DPS1 DRHM DRH1 DSAM DSA1 GRAM GRA1 LPOM LPO1 NFBM NFB1 NNBM NNB1 NPCM NPEM NPE1 NPLM NPL1 ~ NPSM NP$1 NRCM NRC1 PDCM PDCl PDD1 PDEM PDE1 RACM RAC1 RADE RAD1 ROPA ROPS RPCM RPCl RPDE RPD1 Bulk Density Compensated [RWD] Bulk Density Compensated Relog 1 [RWD] Bulk Density Tlme Since Drilled [RWD] Bulk Denstty Tlme Since Drilled Relog I [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (AT) Corrected for Dielectric Effect Relog 1 [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Conductivity (PD) Dielectric Corrected Relog I [RWD] Calculated Dielectric Constant Calculated Dielectric Constant Relog 1 Density Long Space Apparent [RWD] Density Long Space Apparent Relog 1 [RWD] Photoelectric Cross Section [RWD] Photoelectric Effect Relog I [RWD] Density Porosity (LS) [RWD] Density Porosity (LS) Relog 1 [RWD] Density Porosity (SS) [RWD] Density Porosity (SS) Relog I [RWD] Delta RHO - Density [RWD] Delta Rho Correction Relog I [RWD] Density Short Space Apparent [RWD] Density Short Space Apparent Relog I [RWD] Gamma Ray Memory (APl) [RWD] Gamma Ray Memory (APl) Relog 1 [RWD] Neutron Porosity (LS) Borehole Corrected [RWD] Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Neutron Porosity (LS) Borehole Corrected Relog I [RWD] Far Base [Base] Far Base Relog 1 [RWD] Near Base [Base] Near Base Relog 1 [RWD] Porosity Borehole Corrected [RWD] Porosity Porosity Porosity Porosity Porosity Porosity Porosity Time Since Drilled [RWD] Time Since' Drilled Relog 1 [RWD] (LS) Borehole Corr [RWD] (LS) Borehole Corr Relog 1 [RWD] (SS) Borehole Corr [RWD] (SS) Borehole Corr Relog 1 [RWD] Ratio Borehole Corr. [RWD] Neutron Porosity Phase Difference Phase Difference Phase Difference Phase Difference Ratio Borehole Corr. Relog I [RWD] Borehole Corrected [RWD] Borehole Corrected [RWD] Data Density Relog 1 [RWD] Elapsed Time [RWD] Phase Difference Elapsed Time Relog 1 [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Borehole Corrected Relog 1 [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Resistivity (AT) Corrected for Dielectric Effect Relog 1 [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Borehole Corrected Relog 1 [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] Resistivity (PD) Corrected for Dielectric Effect Relog 1 [RWD] g/cc mins mins mmho/m mmho/m mmho/m mmho/m g/cc g/cc B/e B/e p.u. p,u, p.u, p.u, g/cc g/cc g/cc g/cc MWD-API MWD-API p.u. p,u. cps cps cps cps p,u. mins. mins. p.u, p.u, p.u, p.u. p.u. p.u. deg deg pt/ft rains rains ohm-m ohm-m ohm-m ohm-m ft/hr ft/hr ohm-m ohm-m ohm-m ohm-m SPOM SPO1 TCDM TCD1 Note: Neutron Porosity (SS) Borehole Corrected [RWD] Neutron Porostty (SS) Borehole Corrected Relog 1 [RWD] CDS Temperature [RWD] CD$ Temperature Relog 1 [RWD] AT i~ Attenuation PD la Phase Difference LS I~ Limestone SS Is Sandstone RWD Is Recorded While Drilling pou. deg F deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Mon 9 AUG 93 2:18p != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 I AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, 1 =ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO,I=YES 5 LISTMETHOD = 0 , !Listing Method: 0=depth.units 1=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 I ISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=ArrayAccoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = 1 , ! Write Tape-Image File: 0=NO, I=YES 12 SPMTLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection 0NRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'o¢NO') 15 END != = USER INPUT PARAMETERS -! AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , ESTMETHOD = 0 , MSTFREQ = 50, LISTMAX = 0 , STATS = 0, FORCETYP = 0 , WRITEASCll = 0 , WRITETAP = 1 , SPUTES = 1 ! SUBFILES = /0/, INTERPOLATE ='YES' END PROCESSING INTERVAL FROM 0.000 TO 0.000 I- CONSTANT PARAMETERS AUTOCURV= 0.000000E+00 AUTOFILE= 0.000000E+00 COMMENTS= 1.00000 FORCETYP= 0.000000E+00 INFORECS= 1.00000 LISTFREQ= 50.0000 USTMAX = 0.000000E+00 LISTMETH= 0.000000E+O0 SELl=TEST= 0.000000E+00 SPLITUS= 1.00000 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 ddength= 0.000000E+00 listwave= 0.000000E+00 maxrecln= 0.000000E+00 minrecln= 0.000000E+00 nsamples= 0.000000E+00 numcurvs= 0.000000E+00 numdatar= 0.000000E+00 numrecfl= 0.000000E+00 tfendep = 0.000000E+00 tflevsp = 0.000000E+00 tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 wcdevsp= 0.000000E +00 wcrtop = 0.000000E +00 !- ARRAY PARAMETERS SUBFILES(1) = O.O00000E+O0 SUBFILES(3) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(9) =-9999.00 SUBFILES(11) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(17) = -9999.o0 SUBFILES(19) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.0o SUBFILES(47) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(63) = -9999,00 SUBFILES(65) = -9999.00 SUBFILES(67) = -9.q99.00 SUBFILES(69) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) = SUBFILES(77) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES( 2) = -9999.00 SUBFILES( 4) = -9999.00 SUBFILES( 6) = -9999.00 SUBFILES( 8) = -9999,00 SUBFILES(10) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999.00 SUBFiLES(30) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(66) = -9999,00 SUBFILES(68) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(80) = -9999,00 SUBFILES(82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(86) = -9999,00 SUBFILES(88) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) == -9999.00 SUBFILES(99) = -9999.00 SUBFILES(IO 1) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.OO SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES (121 ) = -9999.00 SUBFILES (123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(100) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) - -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 , SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 STRING PARAMETERS INTERPOL= YES input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: C:~LISAF~1208.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled.,. (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE: n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE = 1 to enable this feature) LiS comment record decoding (COMMENTS = 1) has been enabled by user input. LiS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC = 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD 93/8/9 1208 01 **** TaPE HEADER **** MWD 93/8/9 1208 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS US COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS # WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN1 JOB NUMBER: 1208 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD P1-17 ST-1 50-029-22358 ARCO ALASKA BAKER HUGHES INTEQ 09-AUG-93 BIT RUN2 BIT RUN3 1208 T. FOSTER J. BURTON T. JOHNSON T. JOHNSON 16 12N 14E 1399 865 50.00 9.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 10.750 130.0 2ND STRING 9.875 3848.0 3RD STRING PRODUCTION STRING REMARKS: $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s)' 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; ali bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 9421.0 10533.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ~- EQUIVALENT UNSHII~'ED DEPTH ......... BASELINE DEPTH GR02 GRAC 9528.0 9517.5 9517.5 9653.5 9645.0 9645.0 9682.0 9673.5 9673.5 9994.0 9987.0 9987.0 10059.0 10048,0 10048.0 10124.0 10118.0 10118.0 10246.0 10239.0 10239.0 10295.5 10288.0 10288.0 10420.0 10408.5 10408.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD 5 MWD 5 REMARKS: CN WN FN COUN STAT BIT RUN NO MERGE TOP 9421.0 10485.0 10100.0 15033.0 : ARCO ALASKA INC. : P1-17 ST-1 : POINT MCINTYRE : NORTH SLOPE :ALASKA MERGE BASE US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD :.TYPE# 64) Entry Type(4) Size(1) Repcode(66) .... Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -9.99.250000 ,_~ Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 1415 16 0001 00000001 0001 Rep Code Count Bytes 68 8 32 Sum: 8 32 32 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 RHOB MWD 68 I G/C3 4 2 PEF MWD 68 1 BN/E 4 3 DRHO MWD 68 1 G/C3 4 4 GR MWD 68 1 GAPI 4 5 RA MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 RP MWD 68 1 OHMM 4 8 NPHI MWD 68 1 PU-S 4 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 66O 71 6 4 98 66O 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 32 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 28 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 80 Tape File Start Depth = 9421.000000 Tape File End Depth = 10533.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3058 datums Tape Subtile: 2 159 records... Minimum record length: 62 bytes Maximum recoro length: 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MAD .002 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using eadiest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MAD 10117.0 10400.0 # MERGED DATA SOURCE PBU TOOL CODE .... MAD 1 $ REMARKS: $ CN WN FN COUN STAT MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 10117.0 10400.0 : ARCO ALASKA INC. : P1-17 ST-1 : POINT MCINTYRE : NORTH SLOPE : ALASKA LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MAD DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD 0'YPE# 64) Entry Type( 4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Elock Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 ? 8 910111213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 8 32 Sum: 8 32 32 fndun a IF ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 RHOB MAD 68 1 G/C3 4 2 PEF MAD 68 1 BN/E 4 3 DRHO MAD 68 1 G/C3 4 4 GR MAD 68 1 GAPI 4 5 RA MAD 68 1 OHMM 4 6 ROP MAD 68 1 FPHR 4 7 RP MAD 68 1 OHMM 4 8 NPHI MAD 68 1 PU-S 4 32 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 28 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 21 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 792 datums Tape Subtile: 3 45 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MAD .003 1024 LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678901234567890123456789012345678`90 FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MAD 10117.0 10400.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ---- EQUIVALENT UNSHIFTED DEPTH ........ BASELINE DEPTH GR02 GRAC 9528.0 9517.5 9517.5 9653,5 9645.0 9645.0 9682.0 9673.5 9673.5 9994.0 9987.0 9987.0 10059.0 10048.0 10048.0 10124.0 10118.0 10118.0 10246.0 10239.0 10239.0 10295.5 10288.0 10288.0 10420.0 10408.5 10408.5 $ REMARKS: $ CN : ARCC ALASKA INC. WN : P1-17 ST-1 FN : POINT MCINTYRE COUN : NORTH SLOPE STAT :ALASKA LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED DATA FROM MAD PASS 1 THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered' 1 2 3 4 5 6 7 8 91011 1213141516 000 1 O0 0 0 0 0 0 1 000 1 Rep Code Count Bytes 68 8 32 Sum: 8 32 32 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 RHOBMAD 68 1 G/C3 4 4 33 821 00 0 2 PEF MAD 68 1 BN/E 4 4 33 821 00 0 3 DRHO MAD 68 1 G/C3 4 4 33 821 00 0 4 GR MAD 68 1 GAPI 4 4 33 821 00 0 5 RA MAD 68 1 OHMM 4 6 ROP MAD 68 1 FPHR 4 7 RP MAD 68 1 OHMM 4 8 NPHI MAD 68 1 PU-S 4 32 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 28 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 21 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3850 datums Tape Subtile: 4 57 records... Minimum record length: 62 bytes Maximum record length' 1014 bytes Tape Subtile 5 is type: LIS **** FILE HEADER **** MWD .OO4 1024 US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9421.0 10485.0 $ LOG HEADER DATA DATE LOGGED: 16 APR 93 SOF'I'WARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 0.0 TOP LOG INTERVAL (FT): 9421.0 BOTTOM LOG INTERVAL (FT): 10485.0 BIT ROTATING SPEED (RPM): 0 tHOLE INCLINATION (DEG) MINIMUM ANGLE: 2.7 MAXIMUM ANGLE: 10.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ BOREHOLE AND C,:~,SING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (F'l'): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 58.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 150OO FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 1529 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.150 MUD FILTRATE AT MT: 0.130 140.0 MUD CAKE AT MT: 0.000 0.0 0,0 140.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 9.875 TOOL STANDOFF (IN)' EWR FREQUENCY (HZ)' 0,0 0 REMARKS: INTERVAL FROM 10117 TO 10400' MD (8830 TO 9112' TVD) WAS LOGGED DURING WIPER TRIP 72 HOURS AFTER BEING DRILLED DUE TO POWER PROBLEM WITH LOGGING SUITE. INTERVAL FROM 10010 TO 10420' MD (8722' TO 9132' TVD) WAS CONTROL DRILLED AT ABOUT 50 F-F/HR. $ CN : Arco Alaska Inc. WN : P1-17 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD 0'YPE# 64) Entry Type(4) Size(1) Repcode( Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator, Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 30 120 Sum: 30 120 120 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 30 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 BDCM MWD 68 1 G/C3 4 2 BDEM MWD 68 1 MINS 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 DLAM MWD 68 1 G/CC 4 7 DPEM MWD 68 1 MINS 4 8 DPLM MWD 68 1 PU 4 9 DPSM MWD 68 1 PU 4 10 DRHM MWD 68 1 G/CC 4 11 DSAM MWD 68 1 G/CC 4 12 GRAM MWD 68 1 GAPI 4 13 LPOM MWD 68 1 PU 4 14 NFBM MWD 68 1 CPS 4 15 NNBM MWD 68 1 CPS 4 16 NPCMMWD 68 1 PU 4 17 NPEM MWD 68 1 MIHS 4 18 NPLMMWD 68 1 PU 4 19 NPSMMWD 68 I PU 4 20 NRCM MWD 68 1 PU 4 21 PDCM MWD 68 1 DEG 4 22 PDEM MWD 68 1 MINS 4 23 RACM MWD 68 1 OHMM 4 24 RADE MWD 68 1 OHMM 4 25 ROPA MWD 68 1 FPHR 4 26 ROPS MWD 68 1 FPHR 4 27 RPCM MWD 68 I OHMM 4 28 RPDE MWD 68 1 OHMM 4 29 SPOM MWD 68 1 PU 4 30 TCDM MWD 68 1 DEGF 4 120 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 -6 4 98 660 71 6 4 98 66O 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 8 FRAMES * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 533 Tape File Start Depth = 9421.000000 Tape File End Depth = 10485.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21730 datums Tape Subtile: 5 603 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separ.ate files. BIT RUN NO: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 10100.0 10533.0 $ LOG HEADER DATA DATE LOGGED: 17 APR 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY mD DRILLER (FT)' 0.0 TOP LOG INTERVAL (FT)' 10100.0 BOTTOM LOG INTERVAL (FT). 10533.0 BIT ROTATING SPEED (RPM): 0 - HOLE INCLINATION (DEG) MINIMUM ANGLE: 2.7 MAXIMUM ANGLE: 10.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 55.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 15000 FLUID LOSS (C3)' 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 2501 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.120 MUD FILTRATE AT MT: 0.100 140.0 MUD CAKE AT MT: 0.000 0.0 0.0 144.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN)' 9.875 TOOL STANDOFF (IN)' EWR FREQUENCY (HZ)' 0.0 0 REMARKS: INTERVAL FROM 10434 TO 10520' MD (9194 TO 9233' TVD) WAS LOGGED DURING WIPER TRIP 72 HOURS AFTER BEING DRILLED DUE TO POWER PROBLEM WITH LOGGING SUITE. INTERVAL FROM 10520 TO 10533' MD (9233 TO 9247' TVD) WAS NOT LOGGED DUE TO BIT TO SENSOR OFFSETS. $ CN : Arco Alaska Inc. WN : P1-17 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 1234567890123456789012345678901234567890123456789012345678901234b~78901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5RR. * FORMAT RECORD (TYPE# 64) Ent,¥ Type( 4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 30 120 Sum: 30 120 120 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 30 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 BDCM MWD 68 1 G/C3 4 2 BDEM MWD 68 1 MINS 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 DLAM MWD 68 1 G/CC 4 7 DPEM MWD 68 1 MINS 4 8 DPLM MWD 68 1 PU 4 9 DPSM MWD 68 1 PU 4 10 DRHM MWD 68 1 G/CC 4 11 DSAM MWD 68 1 G/CC 4 12 GRAM MWD 68 1 GAPI 4 13 LPOM MWD 68 1 PU 4 14 NFBM MWD 68 1 CPS 4 15 NNBM MWD 68 1 CPS 4 16 NPCM MWD 68 1 PU 4 17 NPEM MWD 68 1 MINS 4 18 NPLM MWD 68 1 PU 4 19 NPSM MWD 68 1 PU 4 20 NRCM MWD 68 ~ PU 4 21 PDCM MWD 68 1 DEG 4 22 PDEM MWD 68 1 MINS 4 23 RACM MWD 68 1 OHMM 4 24 RADE MWD 68 1 OHMM 4 25 ROPA MWD 65 1 FPHR 4 26 ROPS MWD 68 1 FPHR 4 27 RPCM MWD 68 1 OHMM 4 L28 RPDE MWD 68 1 OHMM 4 29 SPOM MWD 68 1 PU 4 30 TCDM MWD 68 1 DEGF 4 120 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 66O 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 4 98 660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 8 FRAMES * DATA RECORD (TYPE# O) 998 BYTES * Total Data Records: 217 Tape File Start Depth = 10100.000000 Tape File End Depth = 10533.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12394 datums Tape Subtile: 6 287 records... Minimum record length: Maximum record lerlgth: 62 bytes 998 bytes Tape Subtile 7 is type: LIS **** FILE HEADER **** MAD .006 1024 US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each ru.n in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MAD 10117.0 10400.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWAR2. 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 INCUNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ 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): STOP DEPTH 17 APR 93 M1.33 M1.33 MEMORY 0.0 10117.O 10400.0 0 2.7 10.7 TOOL NUMBER 2501 9.875 0.0 KCL POLYMER 0.00 o.0 0.0 15000 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 9.875 TOOL STANDOFF (IN)' EWR FREQUENCY (HZ)' 0.0 0 REMARKS: $ CN ' Arco Alaska Inc. WN ' P1-17 FN 'Pt. Mclntyre COUN ' North Slope STAT 'Alaska 0.0 0,0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MAD PASS DATA FROM MAD PASS 1. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Rep'-ode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered' 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 0 0 0 1 Rep Code Count Bytes 68 28 112 Sum: 28 112 112 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 28 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I BDC1 MAD 68 1 G/C3 4 2 BDE1 MAD 68 1 MINS 4 3 CAD1 MAD 68 1 MMHO 4 4 CPD1 MAD 68 1 MMHO 4 5 DCC1 MAD 68 1 4 6 DLA1 MAD 68 1 G/C3 4 7 DPE1 MAD 68 1 MINS 4 8 DPL1 MAD 68 1 PU 4 9 DPS1 MAD 68 1 PU 4 10 DRH1 MAD 68 1 G/C3 4 11 DSA1 MAD 68 1 G/C3 4 12 GRA1 MAD 68 1 GAPI 4 13 LPO1 MAD 68 1 PU 4 14 NFB1 MAD 68 1 CPS 4 15 NNB1 MAD 68 1 CPS 4 16 NPE1 MAD 68 1 MINS 4 17 NPL1 MAD 68 1 PU 4 18 NPS1 MAD 68 1 PU 4 19 NRC1 MAD 68 1 G/C3 4 20 PDC1 MAD 68 1 DEG 4 21 PDD1 MAD 68 1 PTFT 4 22 PDE1 MAD 68 1 MINS 4 23 RAC1 MAD 68 I OHMM 4 24 RAD1 MAD 68 1 OHMM 4 25 RPC1 MAD 68 1 OHMM 4 26 RPD1 MAD 68 1 OHMM 4 27 SPO1 MAD 68 1 PU 4 28 TCD1 MAD 68 1 DEGF 4 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 £? 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 59 602 51 0 4 33 5..'1 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0- 112 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 8 FRAMES * DATA RECORD (TYPE# 0) 934 BYTES * Total Data Records: 142 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27036 datums Tape Subtile: 7 208 records... Minimum record length: Maximum record length: 62 bytes 934 bytes Tape Subtile 8 is type: LIS **** TAPE TRAILER **** MWD 93/8/9 1208 01 **** REEL TRAILER **** MWD 93/8/9 1208 01 Tape Subtile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 9 AUG 93 2:20p Elapsed execution time = 1 minute, 32.9 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH RHOB RA ROP PEF RP DRHO GR NPHI 9421.0000 2.4340 3.8843 0.0280 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 9421,5000 2.4355 3,8741 0.0416 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9450.0000 2.3147 4.4806 0.1516 122.7883 2.4075 -999.2500 2.0227 29.4871 9500.0000 2.4818 3.6362 0.0014 120.2759 2.4294 34.2162 1,9067 25.5175 9550.0000 2,4515 3.6474 0.0080 119.0416 2.7250 43,3341 2,2713 24,2332 9600.0000 2,4964 3.5460 0.0041 94.6868 2.4943 35.6551 1,8439 23.1687 9650,0000 2.4579 3,3491 0.0653 122.3146 6.3255 81.7569 3.1322 25.2966 9700,0000 2.2789 3.3928 ~.0271 118.8655 10.4075 48,2370 12,0622 25.9052 9750.0000 2,3302 3,2754 -0.0138 111.0338 33.1475 126.5310 10.7800 23.9268 9800.0000 2.4712 3.0585 0.0638 110.4404 7.8797 59,9746 4.0835 21.0557 9850.0000 2,3716 4.7989 ~.0675 219.5488 2.2694 34.0476 1.5966 25.9253 9900.0000 2.4452 3.9536 0.0104 191,8012 2.9016 44.2831 2.4888 32.0696 9950.0000 2.4712 5,0059 0.0124 88.6694 12,2105 38.5963 6,8610 25.6062 10000.0000 2,5027 4,1339 ~.0163 81.5965 7.3878 161.2130 9.4145 21.5424 10050.0000 2.5362 6.7329 ~.0584 76.5070 -999.2500 53.9080 26.0848 27.9740 10100.0000 2.4149 5,0565 0.0117 61.4966 -999.2500 47.7002 33.4441 30.3691 10150.0000 2.3566 2.9599 0.0464 68.7367 22.4574 53.4454 13.6108 25.7459 10200.0000 2.7051 7.3243 ~,0232 91.9820 18,8790 52,9246 11.3766 29.0551 DEPTH RHOB PEF DRHO RA ROP RP NPHI 10250.0000 2.3068 2.9889 0.0362 -999.2500 64.1425 35.7262 23.4318 10300.0000 2.3603 3.3771 0.0170 -999.2500 107.6107 34.5276 22.2922 10350.0000 2.4047 3.1068 ~.0346 22.4298 42.8481 14.9088 18.2564 10400.0000 2.2388 2.6806 0.0002 2.4750 95.7346 2.2185 25.2767 10450.0000 2.4725 3.9872 0.1074 5.7578 19.0322 5.4828 16.7659 10500.0000 -999.2500 -999.2500 1.8775 29.0705 1.4895 -999.2500 -999.2500 10533.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 GR 48.9958 56.8611 55.7453 37.3997 114.3249 108.8023 -999.2500 Tape File Start Depth -- 9421.000000 Tape File End Depth = 10533.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS DEPTH RHOB PEF RA ROP RP DRHO NPHI 10117,0000 2,4621 5.1269 0.0135 -999.2500 48.8889 35.3939 24.9899 10117.5000 2.4485 4,9970 0.0190 -999.2500 48.8889 47.1522 23.7760 10150.0000 2.3566 2.9599 0.0464 22.4574 53.4454 13.6108 25.7459 10200.0000 2.7051 7.3243 ~.0232 18.8790 52.9246 11.3766 29.0551 10250.0000 2.3068 2.9889 0.0362 -999.2500 64.1425 35.7262 23.4318 10300,0000 2.3603 3,3771 0,0170 -999,2500 107.6107 34.5276 22,2922 10350.0000 2.4047 3.1068 -0,0346 22.4298 42.8481 14.9088 18.2564 10400.0000 2,2388 2.6806 0.0002 2.4750 95.7346 2.2185 25.2767 GR 59.8467 54,1152 68.7367 91.9820 48,9958 56.8611 55.7453 37.3997 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS DEPTH RHOB PEF RA ROP RP DRHO NPHI 10117.0000 2.4621 5.1269 0.0135 -999.2500 48.8889 35.3939 24.9899 10117.5000 2.4485 4.9970 0.0190 -999.2500 48.8889 47.1522 23.7760 10150.0000 2.3566 2.9599 0.0464 22.4574 53.4454 13.6108 25.7459 10200.0000 2.7051 7.3243 ~.0232 18.8790 52.9246 11.3766 29.0551 10250.0000 2.3068 2.9889 0.0362 -999.2500 64.1425 35.7262 23.4318 10300.0000 2.3603 3.3771 0.0170 -999.2500 107.6107 34.5276 22.2922 10350.0000 2.4047 3.1068 ~.0346 22.4298 42.8481 14.9088 18.2564 10400.0000 2.2388 2.6806 0,0002 2.4750 95.7346 2.2185 25.2767 GR 59.8467 54.1152 68.7367 91.9820 48.9958 56.8611 55.7453 37.3997 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 5 is type: LIS DEPTH BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPCM NPEM NPLM NPSM NRCM PDCM PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 9421,0000 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250O 9421.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 °999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9450,0000 2.3524 -999.2500 -999.2500 -999,2500 -999.2500 2.2369 4.1389 20.9127 18.0368 0.1014 2.1693 121.8227 27.1970 19.4517 6023.9844 30.6248 -999.2500 30.6248 34.4979 306.2825 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 31,2587 -999.25O0 9500.0000 2.4941 108.0000 401.2633 504,4736 162.0239 2.4973 3.7978 12.6246 9.4473 ~.0034 2.5006 129.4073 23.2847 22.1516 6195.8271 24.9407 87.5945 24.9407 28.6648 276.6241 18.2169 63.0000 2.6387 2.4921 55.5223 58.5930 1,9254 1.9823 27.1731 115.9250 9550.0000 2.4404 123.0000 270.8389 362.4337 138,6000 2,4294 3.6742 15.7640 12.7009 ~.0008 2.4302 123.9345 19.6100 25.0595 6254.4365 20.1679 103.9667 20.1679 23.7114 246.8382 14.9915 60.0000 3.9922 3.6922 40.6892 35.4100 2,6691 2.7591 23.3013 112.3250 9600,0000 2.4166 95.0000 477.5218 642,5106 181.8054 2.3955 3.7247 17.1589 14.1465 0,0321 2,3743 135,9803 25,1158 20,6646 6077,1621 27,7606 73,9833 27.7606 31.5675 290.8514 20.9354 54.0000 2,2069 2.0941 56.6424 38.9110 1,5154 1,5564 29,0900 120,7625 DEPTH DCCM DRHM NNBM NRCM ROPA TCDM 9650.0OO0 112.2087 0,0406 6311.9307 239.9384 57,1694 120.0875 9700.0000 131.1889 0.0308 6327.8711 273.1615 30.0059 125.9375 9750.0O00 81.3194 0.0434 6305.9736 241.7170 59.9859 127.2875 9800.0000 97.7635 0.1080 6441.3750 220.5504 80.8985 126.5375 9850.0000 164.1822 0.0005 6059.3877 259.8754 33.4666 128.7500 9900.0000 142.6219 -0.0263 6163.4072 279.2082 51.5337 128.0750 BDCM DLAM DSAM NPCM PDCM ROPS 2.4124 2.3755 2.3485 19.1247 11.3598 57.1754 2.4728 2.4432 2.4227 24.4971 13.9707 30.2896 2.4241 2.3898 2.36O9 19.3903 7.1629 62.1734 2.4209 2.3481 2,2761 16.3709 9.3837 96.6426 2.4038 2.3846 2.3824 22.2393 18.5139 33.7513 2.4977 2.5114 2.5378 25.5780 15.5455 64.4342 BDEM DPEM GRAM NPEM PDEM RPCM 113.0000 3.3737 114.2098 96.6500 65.0000 4.1693 58.0000 3.5862 119.6030 52.3500 35.0000 2.9960 82.0000 3.8126 97.2570 68.3167 58.0000 8.3314 107.0000 3.4128 107.9474 84.4834 58.0000 5.5955 118.0000 4.5555 267.1130 98.5166 79.0000 1.8731 93.0000 4.3469 216.8239 79.3500 50.0000 2.5136 CADE DPLM LPOM NPLM RACM RPDE 178.0987 17.4009 18.7737 19.1247 6.2415 4.3346 233.1075 13.8712 22.8486 24.4971 4.6879 3.1018 104.6798 16.7221 18.9891 19.3903 11.1133 8.7458 78.5352 16.9090 16.4265 16.3709 20.5634 5.8401 417.3731 17.9080 21.2006 22.2393 2.5324 1.9276 306.5204 12.4144 23.6123 25.5780 3.4965 2,5964 CPDE DPSM NFBM NPSM RADE SPOM 230.7041 14.3973 26.0171 22.6220 5.6149 22.4156 322.3926 10.7393 22.9105 28.2066 4.2899 26.7154 114.3406 13.6938 25.8013 22.8995 9.5529 22.6439 171.2296 13.8875 28.8847 19.7345 12.7331 19.92O3 518.7719 14.9228 23.0600 25.8674 2.3959 24.9814 385.1429 9.2295 21.8318 29.3223 3.2624 27.5167 DEPTH DCCM DRHM NNBM NRCM ROPA TCDM BDCM DLAM DSAM NPCM PDCM ROPS BDEM DPEM GRAM NPEM PDEM RPCM CADE DPLM LPOM NPLM RACM RPDE CPDE DPSM NFBM NPSM RADE SPOM 9950.0000 86.0976 0,1380 6277.9551 280.3443 97.3226 128.7500 10000.0000 42.0307 0.0009 6408.584O 214.4370 283.1801 132.3500 2,6617 2.5880 2.4960 25.7850 7.8035 107,3904 2.3717 2,3817 2,3824 15,5524 2.2610 406.9011 113.0000 4.6934 81,1560 68.0833 49.0000 7.3592 114.0000 3,1326 58.4062 96.0167 72,0000 37,3O67 72.3082 2.8244 23.7569 25.7850 18.1486 7.7114 -999.2500 19.7864 15.6835 15.5524 -999.2500 40,1291 129.6790 ~.7092 22.1474 29,5357 13.8297 27.6683 24.9196 16.8696 29.5569 18.8731 -999.2500 19.1276 10050,0000 38.2841 0,0133 6014.0967 346.5582 40.2536 132.2938 2.4434 2.4669 2.4581 40.4308 1.8613 40.2430 80.0000 7.368O 79,5365 64.1833 44.0000 46,7839 -999.2500 15.5913 33.3822 40.43O8 -999.2500 50.5368 19.7876 12.5219 17.1629 44.3919 -999,2500 37.64O8 10100.0000 51.4531 -999,2500 6283.3535 3O4.83O6 49.7778 134.2625 -999,2500 -999.2500 -999.2500 30.5719 3.3410 48.8281 -999.2500 -999,2500 70,6662 68.1333 44.0000 23.1896 -999,2500 -999.2500 26.9960 30.5719 -999,2500 24.7380 40,4237 -999,2500 20.3859 34.4440 -999.2500 31,0497 10150.0000 -999.2500 -999.2500 -999.2500 -999,2500 45.2222 135.7250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 45.7764 -999.2500 -999.25O0 -999.2500 -999.2500 -999.2500 -999,250O -999,2500 -999.25OO -999,2500 -999.2500 -999.2500 -999.25OO -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 -999.2500 -999.2500 37.1067 136.4000 -999.2500 -999.2500 -999.2500 -999.25OO -999.2500 36.2585 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DEPTH DCCM DRHM NNBM NRCM ROPA TCDM 10250.0000 -999.2500 -999.2500 -999.2500 -999.2500 68.1940 136.7375 10300.0000 -999.2500 -999.2500 -999.2500 -999.2500 88.2384 138.2000 10350.0000 -999.2500 -999.2500 -999.25OO -999.2500 120.4021 138.0125 10400.000O 118.2098 0.0622 6364.9580 249.7501 83.0367 139.2875 10450.0000 117.1014 O.0024 6338.9687 182.1646 17.7072 141.1812 10485.0000 -999.25OO -999.250O -999.2500 -999.2500 32.9997 142.7000 BDCM DLAM DSAM NPCM PDCM ROPS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 66.5838 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 89.3197 -999.2500 -999.25OO -999.2500 -999.25OO -999.25OO 136.3032 2.4111 2.3944 2.3529 20.6189 12.1842 80.5428 2,57O5 -999.25OO -999.2500 11.5715 12.0318 17.5924 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 33.2919 BDEM DPEM GRAM NPEM PDEM RPCM -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 164.0000 3.3426 35.4172 126.7500 73.0000 3.7331 153.0000 3.4855 119.0840 122.4123 82.OOOO 3.8083 -999.2500 -999.25OO -999.25OO -999.2500 -999.2500 -999.2500 CADE DPLM LPOM NPLM RACM RPDE -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250O -999.25OO -999.25OO -999.25OO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25OO -999.2500 -999.2500 -999.25O0 309.3535 17.4802 19.9638 20.6189 3.4207 3.8748 174.7278 8.1555 11.7023 11.5715 6.4100 3.9543 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 CPDE DPSM NFBM NPSM RADE SPOM -999.2500 -999.2500 -999.2500 -999.25O0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25OO -999.25OO -999.2500 -999.2500 -999.2500 258.0771 14.4795 25.2050 24.1816 3.2325 23.6756 252.8883 4.8157 34.4153 14.6619 5.7232 14.8568 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25OO Tape File Start Depth = 9421.000000 Tape File End Depth = 10485.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 6 is DEPTH DCCM DRHM NNBM NRCM ROPA TCDM 10100.0000 51.4531 -999.2500 6283.3535 304.8306 49.7778 134.2625 10100.2500 53.2667 -999.2500 6287.2480 302.1384 49.7778 134.2625 10150.0000 -999.2500 -999.2500 -999.2500 -999.2500 45.2222 135.7250 10200,0000 -999.2500 -999.2500 -999.2500 -999.2500 37.1067 136.4000 10250.0000 -999.2500 -999.2500 -999.2500 -999.2500 68.1940 136.7375 10300.0000 -999.2500 -999.2500 -999.2500 -999.2500 88.2384 138.2000 type: LIS BDCM DLAM DSAM NPCM PDCM ROPS -999.2500 -999.2500 -999.2500 30,5719 3.3410 48.8281 -999.2500 -999.2500 -999.2500 30.0134 3.5588 49.4612 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 45.7764 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 36.2585 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 68.5838 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 89.3197 BDEM DPEM GRAM NPEM PDEM RPCM -999.2500 -999.2500 70.6662 68.1333 44.00O0 23.1896 -999.2500 -999.2500 72.8670 68.3042 43.0000 21.4128 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 CADE DPLM LPOM NPLM RACM RPDE -999.2500 -999.2500 26.9960 30.5719 -999.2500 24.7380 -999.2500 -999.2500 26.6264 30.0134 -999.2500 22.8128 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25OO -999.2500 -999.2500 -999.2500 CPDE DPSM NFBM NPSM RADE SPOM 40.4237 -999.2500 20.3859 34.4440 -999.2500 31.0497 43.8351 -999,2500 20.5803 33.8739 -999.2500 30.6651 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DEPTH BDCM BDEM CADE CPDE DCCM DL,AM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPCM NPEM NPLM NPSM NRCM PDCM PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 10350,0000 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 120,4021 136,3032 -999,2500 -999,2500 -999,2500 138,0125 10400,0000 2,4111 164,0000 309,3535 258,0771 118,2098 2,3944 3,3426 17,4802 14,4795 0,0622. 2,3529 35,4172 19,9638 25,2050 6364,9580 20,6189 126,7500 20,6189 24,1816 249,7501 12,1842 73,0000 3,4207 3,2325 83,0367 80,5428 3,7331 3,8748 23,6756 139,2875 10450.0000 2.5705 153.0000 174,7278 252.8883 117.1014 -999.2500 3.4855 8.1555 4.8157 0,0024 -999.2500 119.0840 11.7023 34.4153 6338.9687 11.5715 122.4123 11.5715 14.6619 182.1646 12.0318 82.0000 6.4100 5.7232 17.7072 17.5924 3.8083 3.9543 14,8568 141.1812 10500,0000 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 30.4869 30.7740 -999.2500 -999.2500 -999.2500 143.3750 10533,0000 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 36,3456 36.3456 -999,2500 -999,2500 -999,2500 -999,2500 Tape File Start Depth = 10100.000000 Tape File End Depth = 10533.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 7 is type: LIS DEPTH BDC1 BDE1 CAD1 CPD1 DCC1 DLA1 DPF1 DPL1 DPS1 DRH1 DSA1 GRA1 LPO1 NFB1 NNB1 NPE1 NPL1 NPS1 NRC1 PDC1 PDD1 PDE1 RAC1 RAD1 RPC1 RPD1 $PO1 TCD1 10117.0000 58.7649 0.0470 6623.0771 4.2312 17.1200 2.5017 2.4792 2.4479 4631.0000 4.0404 18.1891 10117.2500 59.7727 0.0379 6649.2041 4.3574 16.4889 2.5095 2.4884 2.4631 4630.0000 4.1636 17.5094 10150.0000 72.8131 0.0678 6607.3340 6.0336 10.6252 2.5605 2.5248 2.4796 4626.0000 5.8095 11.2024 10200.0000 63.6292 0.0340 6638.0371 4.8446 14.3160 2.5329 2.5214 2.5001 4609.0000 4.6412 15.1649 10250.0O00 53.0885 0.0006 6608.0762 3.5345 21.5877 2.5336 2.5240 2.5238 4603.0O00 3.3600 23.0268 10300.0000 42.1674 0.0464 6628.5020 2.2904 37.0519 2.2439 2.2017 2.1707 4633.0000 2.1526 39.5452 10350.0000 41,5974 0.0274 6657.1504 2.2110 38.2719 2.2522 2,2141 2.1956 4644,000O 2.0753 41.2580 4623.0000 5.3240 70.8732 16.9051 4602.0000 27.4587 4622.0000 5.3766 69.2991 16,4459 4601.0000 26.9915 4618.0000 6.1163 76.5799 22.0651 4598.0O00 32.2346 4602.000O 4.8780 71.8508 13.8559 4577.0000 24.1884 4596.0000 5.8034 60.1927 14.9350 4576.00OO 25.3926 4626.0000 2.5299 50.3978 16.1740 4605.00O0 26.7116 4636.0000 2.8442 45.2404 13.0779 4615.0000 23.2844 31.2239 12.1828 23.6499 20.2959 65.4187 46.2637 30.6593 11.7235 23.2114 19.8133 69.4750 46.1875 54.55O8 8.7404 28.1568 25.6864 24.9200 44.3125 37.0820 10.3576 20.5887 17.0827 47.3880 44.5886 24.5322 10.3168 21.7136 18.2222 118.2455 46.2659 -999.2500 27.2586 22.9488 19.5274 -999.2500 47.5811 -999.2500 26.7719 19.7461 16.2596 -999.2500 48.5625 54.9781 8.9894 28.8408 224.4442 32.0267 57.1120 8.5135 29.2448 221.0968 32.6165 89.2662 5.4219 24.8174 258.8052 18.3316 65.9416 7.0979 32.6002 201.2124 26.9673 43.4277 7.0556 31.3064 209.7074 40.7628 25.2875 24.6134 30.2275 219.0948 -999.2500 24.2377 24.1091 33.4381 194.8895 -999.2500 DEPTH BDC1 BDE1 CAD ~ CPD1 DCC1 DLA1 DPE1 DPL1 DPS1 DRH1 DSA1 GRA1 LPO 1 NFB1 NNB1 NPE1 NPL1 NPS ~ NRC1 PDC1 PDD1 PDE1 RAC 1 RAD1 RPCl RPD1 SPO1 TCD1 10400.0000 2.4427 4661.0000 322.4228 201.6536 105.4664 2.3638 3.1207 15.6305 12.5625 0.1442 2.2676 41.0870 20.2991 32.8996 6589.7109 4668.0000 13.5870 16.7983 199.0351 10.4332 10.1589 4641.0000 3.2534 3.1015 4.7588 4.9590 23.8778 50.0625 Tape File Start Depth = 10117.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 8 is type: LIS