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Home My WebLink About193-0747. 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 P1-13 Acid Wash Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 11010 Conductor Surface Intermediate Production Liner 8745 80 3521 10238 888 9025 20" 10-3/4" 7-5/8" 4-1/2" 8401 39 - 119 39 - 3560 37 - 10275 10122 - 11010 39 - 119 39 - 3558 37 - 8744 8746 - 8745 9676 520 2480 5120 7500 9073, 9165, 9390, 10150 2300 5210 8180 8430 8801 - 10987 4-1/2" 12.6# L-80 36 - 8696 8248 - 8744 Structural 4-1/2" TIW HBBP Packer 2239, 2238 8617 8100 Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907)903-5990 PRUDHOE BAY, Point McIntyre Oil, Pt M Stump Island 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 0028297 36 - 8165 Perforations 8801 - 9025'MD Pump 201-bbls 15% HCl Acid. Final treating pressure = 1778-psi. 286 308 3167 1227 9 9 1343 867 646 609 N/A 13b. Pools active after work:Point McIntyre Oil, Pt M Stump Island Oil 4-1/2" Camco TRCF-4A 8617, 8100 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 8:26 am, Jul 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.07.24 07:03:55 - 08'00' Bo York (1248) RBDMS JSB 072525 DSR-7/24/25JJL 8/12/25 CDW 07/28/2025 ACTIVITY DATE SUMMARY 6/10/2025 (TFS unit 1 assist S-Line) Traveled to load fluid for job and arrived at job. ******WSR Continued on 6-11-2025******* 6/10/2025 ***WELL S/I ON ARRIVAL*** RAN FLAPPER CHECKER TO SSSV @ 2238' MD (flapper not fully closing, tap down to fall) ***WSR CONT. ON 06-11-2025*** 6/11/2025 *******WSR Continued from 6-10-2025****** T/I/O 2500/1250/275 Temp S/I (TFS unit 1 assist S-Line) Pumped 49 BBLS of diesel down TBG to assist SL setting lockout tool. Final WHPS=2500/1300/300 SL in control of well upon departure. DSO notified of departure. 6/11/2025 T/I/O= 2200/1250/250. LRS 72 Assist Slickline (ACID). Open SSSV / SB for SL ***Job Cont to 6-12-2025 WSR*** 6/11/2025 ***WSR CONT. FROM 06-10-2025*** RAN 3.85'' CENT, 3' x 1-7/8'', FRICTION TOOL. ATTEMPT TO EXERCISE TRCF SSSV (no movement need 5K+ on CTRL LN SITP 2500psi) T-BIRD PUMPED 30 BBLS DIESEL RAN 4-1/2" HYDRAULIC LOCKOUT TOOL / LRS PUMPS 60 BBLS (w/o penetrators- collets damaged). RAN 3.85" CENT, BULLNOSE, TAGGED TRCF-4A SSSV NO-GO @ 2213' SLM/2238' MD RAN FLAPPER CHECKER TO TRCF-4A SSSV @ 2213' SLM / 2238' MD (No Issues Pins past flapper) RAN 4-1/2'' WHIDDON TO 2219' SLM (Unable to work further at flapper while pumping) ***WSR CONT. ON 06-12-2025*** 6/12/2025 ***WSR CONT. FROM 06-11-2025*** RAN 5' x 2.5'' DD BAILER(msfb) TO S/D @ 2219' SLM (Unable to work past) RAN 3.85'' CENT, 3' x 1-7/8'', 3.75'' CENT, 4-1/2'' BRUSH, 3.50'' G. RING TO S/D @ 2211' SLM (Unable to work further While online w/LRS) RAN 3.85'' CENT, 3' x 1-7/8'', 3' x 2-1/8'', 3.75'' CENT, 3.73'' LIB TO SSSV. (s/d @ 2211' slm, impression of flapper/ lrs pumping .5 bpm @ 3450 psi) RAN 3.85" CENT, 3' x 1-7/8" STEM, 3' x 2-1/8" STEM, 3.75" CENT, 3.50" LIB TO SSSV (work tools through flapper w/ lrs pumping .5 bpm @ 3450 psi, lib inconclusive) RAN 3.85" CENT, 3' x 1-7/8" STEM, 3' x 2-1/8" STEM, 3.75" CENT, 3.21" CENT, BULLNOSE (workt tools through flapper w/ lrs pumping .5 bpm @ 3450 ring on nogo) SET 4-1/2" DB LOCK (3.835" no-go) w/ 13' 5" x 3.5" PIPE w/ SPOON BTTM (175" lih 2.20" ID) IN SSSV @ 2238' MD (see log) PULLED BK-OGLV FROM ST# 1 @ 4168' MD - (Turned down KOT body @ WLB) RAN 2'x1-1/2'', 2.00' CENT, TEL, 1.75'' S. BAILER TO LOC. TTL @ 8691' SLM, TAG SAND @ 9036' SLM ***WSR CONT. ON 06-13-2025*** 6/12/2025 ***Job Cont from 6-11-25 WSR** Assist SL (ACID) Fire Drill Pumped 140 bble DSL down tbg to assist SL ***job continued to 06-13-25*** Daily Report of Well Operations PBU P1-13 Daily Report of Well Operations PBU P1-13 6/13/2025 ***WSR CONT. FROM 06-12-2025*** LRS LOADED IA w 131 BBLS CRUDE SET BK-OGLV (28 x 20/64" orifice) IN STA #1 @ 4168' MD ***WELL LEFT S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** 6/13/2025 ***job continued from 06-12-25*** Pumped 131 bbls 100*F crude down IA to load. Final T/I/O= 2200/800/580. 6/24/2025 LRS CT #2 1.75" CT 0.156 WT - Job Scope = Acid Wash Road from DS06 to P1, MIRU ***Job Continued 6/25/25*** 6/25/2025 LRS Test Unit 6, Begin WSR on 6/25/25, P1-13 IL, OL, Continue WSR on 6/26/25 6/25/2025 LRS CT #2 1.75" CT 0.156 WT HT-110 Job Scope: Acid Wash Rig up. Function test BOP, MU LRS MHA w/ 2" JSN, attempt to bullhead load well with 3% KCL but injectivity was too low. RIH and tag sand at 9060'. Pickup to tubing tail and circ well over to 3% KCL. Injectivity test 2420psi @.75bpm, 2240psi @ 0.5bpm, 2070psi @ 0.4bpm. Pump 15%HCL acid down ct, reciprocating from 8750' - 9050'ctm at 0.4bpm. Once 15bbls acid across the perfs, whp trends from 2080psi to 1566psi. Continue reciprocating across perf interval at 10fpm pumping 0.4bpm 15%HCL acid, WHP trends down slowly to 1506psi. ***Continue on 6-26-25 WSR*** 6/26/2025 LRS CTU #2 1.75" CT 0.156" WT HT-110 Job Objective: Acid Wash Pump 201bbls 15%HCL acid at 0.4bpm, reciprocating across interval 8750 - 9050'ctm, displace acid with 232bbls of 3% KCL.before pump went down. Call out LRS pumping to finish displacement. POOH RDMO CTU. ***Job Complete*** 6/26/2025 LRS Test Unit 6, Continue WSR from 6/25/25, P1-13 IL, 08 OL, Unit move, Begin RU,, Contiue WSR on 6/27/25 6/26/2025 T/I/O= 500/600/430 Displace acid post CTU acid treatment. Pump 100 bbls 3% kcl & 10 bbl;s 60/40 down tbg. FWHPs=1500/650/700 6/27/2025 LRS Test Unit 6, Continue WSR from 6/26/25, P1-13 IL, 08 OL, Continue RU, PT, POP, Contiue WSR on 6/28/25 6/28/2025 LRS Test Unit 6, Continue WSR from 6/27/25, P1-13 IL, 08 OL, Continue Flowing, Contiue WSR on 6/29/25 6/29/2025 LRS Test Unit 6, Continue WSR from 6/28/25, P1-13 IL, 08 OL, Continue Flowing, 12 Hr Piggyback Well Test, RD MO, END WSR on 6/29/25 g Injectivity test 2420psi @.75bpm, 2240psi @ jy @ @ 0.5bpm, 2070psi @ 0.4bpm. Pump 15%HCL acid down ct, reciprocating from 8750' - @g 9050'ctm at 0.4bpm. Once 15bbls acid across the perfs, whp trends from 2080psi to 1566psi. Continue reciprocating across perf interval at 10fpm pumping 0.4bpmg 15%HCL acid, WHP trends down slowly to 1506psi. 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 P1-13 Patch Perfs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 11010 Conductor Surface Intermediate Production Liner 8745 74 3521 10275 888 9073 20" 10-3/4" 7-5/8" 4-1/2" 8430 38 - 112 37 - 3558 36 - 10274 10122 - 11008 38 - 112 37 - 3558 36 - 8744 8746 - 8745 9676 520 2480 5120 7500 9073 , 9139 , 9373 , 10150 2300 5210 8180 8430 8801 - 10987 4-1/2" 12.6# L-80 33 - 8696 8248 - 8744 Structural 4-1/2" TIW HBBP , 4-1/2" TIW SS Horiz 8098 , 8746 / 2235 8614 , 8098 10122 , 8746 Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907)903-5990 PRUDHOE BAY / PM STUMP ISL 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 0028297 286 218 3167 4143 9 28 1343 1132 646 649 324-611 13b. Pools active after work:PM STUMP ISL OIL 4-1/2" Camco TRCF-4A 8614 , 10122 / 2236 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 Gavin Gluyas at 8:54 am, Feb 28, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.02.27 15:11:12 - 09'00' Bo York (1248) CDW 02/28/2025 DSR-2/28/25 RBDMS JSB 030325 ACTIVITYDATE SUMMARY 10/26/2024 ***WELL FLOWING ON ARRIVAL*** HES 759 R/U ***CONT WSR ON 10/26/2024*** 10/27/2024 ***CONT WSR FROM 10/26/2024*** RUN 4-1/2" TRCF SSSV FLAPPER CHECKER TO 2,238' MD (flapper open) SET 4-1/2" WCS (WC-47) IN PARKER SWN NIP @ 8,671' MD PULL 1" BL-OGLV FROM STA #1 @ 4,168' MD T-BIRD LOAD IA 105 BBL's KCL,4BBL's60/40,65 BBL's DIESEL (see pump log for details) SET 1" BK-DGLV IN STA #1 @ 4,168' MD SET DOWN @ 4,147'SLM POSSIBLE HHYDRATES PUMP 20 BBL'S NEAT 45 BBL'S DIESEL PULL 4-1/2" WCS FROM XN @ 8,671' MD T-BIRD LOAD TBG 5 BBLS 60/40, 146 BBLS 2% KCL, 40 BBLS DIESEL SET 4-1/2" PXN IN XN @ 8,671' MD ***CONT WSR ON 10/28/2024*** ****RUN BLOWOUT DRILL FROM UNKNOWN SOURCE W/ HES DAY CREW & HILCORP WSS (SOROKA) 10/27/2024 T/I/O=1600/1800/0 TFS Unit 1 Assist Slickline (Circ-out) Pumped 10 BBLS of 60/40 and 100 BBLS of 2% KCL followed by 65 BBLS of Diesel to Load and Freeze Protect the IA. During IA Load Bled Tubing Pressure off down P1-13 Flowline. Pumped 27 BBLS 60/40 and 46 BBLS of DSL to Assist Slickline down hole. Then Pumped 9 BBLS of 60/40 followed by 146 BBLS of 2% KCL and 40 BBLS of Diesel to Load and Freeze Protect the Tubing to 2500ft. ***JOB CONTINUES to 10-28-2024*** 10/28/2024 ***CONT WSR FROM 10/27/2024*** SET P-PRONG IN 4-1/2" PXN @ 8,671' MD T-BIRD PERFORM 6 FAILING MIT-T TO 3000# TESTS (see log for details) T-BIRD PERFORM PASSING MITxIA 3000# (see log for details) PULL P-PRONG FROM 4-1/2" PXN @ 8,671' MD PULL 4-1/2" PXN FROM XN @ 8,671' MD BRUSH X NIPPLE @ 8,654' MD & XN @ 8,671' MD ***CONT WSR ON 10/29/2024*** 10/28/2024 ***JOB CONTINUES from 10-27-2024*** TFS Unit 1 Assist Slickline Pumped a total of 53.4 BBLS of Diesel to Assist Slickline and to Test the Tubing and IA. Pumped 9 BBLS of 60/40 to Freeze Protect P1-13 Flowline Pressured FL to 1100 psi per Pad Op . MIT-T and MIT-IA none successful tests all logged. ***JOB CONTINUES to 10- 29-2024*** 10/29/2024 ***CONT WSR FROM 10/28/2024*** SET 4-1/2" PXN IN PARKER 4-1/2" PARKER SWN NIP @ 8,671' MD PASSING MIT-T @ 3,300# W/ T-BIRD PULL 4-1/2" PXN FROM PARKER SWN NIP @ 8,671 DRIFT W/ 25'x3.66" RING DUMMY PERF GUNS TO 9,061' MD ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU P1-13 Daily Report of Well Operations PBU P1-13 10/29/2024 ***JOB CONTINUES from 10-28-2024*** TFS Unit 1 Assist Slickline (MIT-T) Pumped 3 bbls 60/40 followed by 43 bbls DSL down TBG for Load. Further pumped 1.5 bbls DSL to reach MIT-T test pressure. MIT-T **PASS** @ 3159 psi 1st 15 min TBG lost 101 psi 2nd 15 min TBG lost 40 psi FWHPS = 500/1309/0 Halliburton SL in control of well upon TFS departure 11/9/2024 ***WELL S/I ON ARRIVAL*** RAN 3-1/2" X 10' DUMP BAILER (DRY) S/D @ 9,032' SLM (CEMENT CHUNK IN DUMP BAILER) DUMP BAIL 3.5 GAL. 20/40 RIVER SAND @ 9,038' SLM DUMP BAIL 3.5 GAL. 20/40 @ 9,042' SLM DUMP BAIL 3.5 GAL. 20/40 @ 9,041' SLM (10.5 GAL. 20/40 RIVER SAND) RAN TEL. & SAMPLE BAILER LOCATE TUBING TAIL @ 8,674' SLM, S/D @ 9,040' SLM (OBTAINED RUNNY SAND SAMPLE) DUMP BAIL 14 GAL. OF 20/40 RIVER SAND FROM 9,041' SLM TO 9,035' SLM (24.5 GAL. TOTAL) ***CONTINUE 11/10/24*** 11/10/2024 ***CONTINUE FROM 11/9/24*** DUMPED 20/40 RIVER SAND FROM 9,035' SLM TO 9,033' SLM (35 GALLONS TOTAL) DUMPED 100 MESH SAND FROM 9,033' SLM TO 9,025' SLM (10 GALLONS TOTAL) CLEAN DRIFT FOR PATCH w/ 10' x 3.70" DUMMY WHIPSTOCK TO 9,017' SLM ***WELL LEFT S/I*** 11/11/2024 ***WELL S/I ON ARRIVAL*** RIG UP HES EQUIPMENT SET OWENS PATCH @ 8564' - 8585 (CCL TO TOP ELEMENT OFFSET- 18.23') OAL 21.7, MIN ID 2.992 RDMO HES ***WELL S/I UPON DEPARTURE*** 11/12/2024 ***WELL S/I ON ARRIVAL*** RAN 3.84" NO GO w/ 4-1/2" BRUSH TO TRSV @ 2,238' MD SET CA-TRCF FRAC SLEEVE IN TRSV @ 2,238' MD (2.24" ID) ***WELL S/I ON DEPARTURE*** 11/19/2024 IA starting psi - 660. ( FRACTURING ) Pumped 1.2 bbls dsl to reach max psi 2500 psi. maintained the IA pressure @ 2500 psi. Total pumped 1.5 bbls diesel *** Job Continued 11-20-24*** 11/19/2024 Assist Frac ( FRACTURING ) heating diesel tanker started at 10 degrees, finished at 80 degrees Daily Report of Well Operations PBU P1-13 11/20/2024 MIRU HES Frac, Oil States Tree Saver, LRS backside pump. Pressure test treating lines and tree saver to 7524 psi. Function test pressure safety systems. LRS pressure up IA to 2,600 psi. Load well with 166 bbl 20# linear gel at 20 bpm. Pump Mini-frac at 35 bpm with 527 bbl 35# XL, flush with 20# linear gel & 10gpt BA- 20). FET 43%. FG: 0.71 psi/ft. Closure time 6 min. Pump 6400# 100 mesh scour stage at 10 bpm ramping from 0.5 -1.0 ppg with 48bbl pad and 192 bbl 20# linear gel at 10 bpm. Flush with 148 bbl 20# linear gel at 10 bpm. Shut in let sand settle 1hr. Pump frac at 32 bpm, max pressure 4,658 psi: Pad, 763 bbl 35# XL pad. 2.0 ppg 20/40 CarboLite, 155 bbl 35# XL. 4.0 ppg 20/40 CarboLite, 196 bbl 35# XL. 5.0 ppg 20/40 CarboLite, 233 bbl 35# XL. 6.0 ppg 20/40 CarboLite, 302 bbl 35# XL. 8.0 ppg 20/40 CarboLite, 191 bbl 30# XL. 10.0 ppg 20/40 CarboLite, 87 bbl 30# XL. Flush, 156 bbl 20# linear gel. Step rate down in 5 bpm increments as flush neared the perfs. LRS Freeze protect with 40 bbl diesel. 202k# 20/40 and 6,400# 100 mesh placed in formation. 2076 bbl 35# Hybor G XL, 212 bbl 30# Hybor G XL, 855 bbl 20# linear gel pumped. ***Job Complete*** 11/20/2024 ***Job Continued from 11-19-24*** Assist Frac. ( FRACTURING ) Pumped 1 bbl DSL down IA to maintain 2500 psi for Frac. Freeze Proted Down TBG = 5 - bbls 60/40, 40 - bbls DSL. Secure well. FWHP=2450/0/500 11/24/2024 ***WELL S/I ON ARRIVAL*** RAN 3.80'' G. RING TO FRAC SLEEVE @ 2238' MD (No Issues) ***WSR CONT. ON 11-25-2024*** 11/25/2024 LRS Test Unit 2, Begin WSR on 11/25/24, Post Frac FLowback, IL P1-13, OL P1-24, Unit Move, Begin RU, Continue WSR On 11/26/24 11/25/2024 ***CONT. FROM 11-24-2024*** HOLD WELL CONTROL DRILL w/WSL PULLED 4-1/2'' CA-TRCF FRAC SLEEVE @ 2230' MD RAN 4-1/2'' BRUSH, 3.80'' G. RING TO PATCH @ 8540' SLM (No Issues) SET 4-1/2'' WHIDDON CATCHER @ 8540' SLM PULLED BK-DGLV FROM ST #1 @ 4168' MD SET BK-OGLV IN ST #1 @ 4168' MD PULLED 4-1/2" WHIDDON CATCHER SUB FROM TOP OF PATCH @ 8536' SLM (empty) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 11/26/2024 LRS Test Unit 2, Continue WSR from 11/25/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue RU, Continue WSR On 11/27/24 11/27/2024 LRS Test Unit 2, Continue WSR from 11/26/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 11/28/24 11/28/2024 T/I/O = 220/820/50. Temp = 89*. IA FL (well Testers). On AL = 900 psi. TBG FL @ surface, IA FL @ 4168' (Sta#1 SO). LRS testers in control of well on departure. Daily Report of Well Operations PBU P1-13 11/28/2024 LRS Test Unit 2, Continue WSR from 11/27/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 11/29/24 11/29/2024 LRS Test Unit 2, Continue WSR from 11/28/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 11/30/24 11/30/2024 ***WELL FLOWING THRU TESTERS ON ARRIVAL*** RAN 4-1/2" BRUSH w/ 3.80" GAUGE RING, SD @ 4,146' SLM RAN 2-1/2" SAMPLE BAILER TO 4,030' SLM (blr full of hydrates) LRS PUMPED 140 BBLS HOT DIESEL TO TBG (final rate: .4 bbls/min @ 2300 psi). RAN 4 1/2" BRUSH, AND 3.55" GAUGE RING TO PATCH @ 8564' MD. RAN 10' x 2.5" DD BAILER; TAGGED 9001' MD (UPPER 3 PERF INTERVALS OPEN; ~62' OF FILL ABOVE BOTTOM PERF). Frac & formation sand in bailer. ***CONTINUED ON 12-1-24*** 11/30/2024 T/I/O= 1847/1069/47. LRS 72 Assist Slickine and Testers with Hydrates (FRACTURING). Pumped 15 bbls of 100*F 60/40 MeOH and 140 bbls of 180*F diesel into the TBG. *** job continued to 12-01-24*** 11/30/2024 LRS Test Unit 2, Continue WSR from 11/29/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/01/24 12/1/2024 LRS Test Unit 2, Continue WSR from 11/30/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/02/24 12/1/2024 ***CONTINUED FROM 11-30-24*** BAILED ~6 GALLONS OF SAND FROM 8,976' SLM (9,001' MD) LRS TESTER POP'D WELL FOR SEVERAL HOURS RAN 2-1/2" SAMPLE BAILER TO 8,976' SLM PERFORMED FBHPS PER PROGRAM WHILE WELL FLOWED THROUGH TEST UNIT ***LRS TEST UNIT IN CONTROL OF WELL ON DEPARTURE*** 12/2/2024 LRS Test Unit 2, Continue WSR from 12/01/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/03/24 12/2/2024 ***WELL FLOWING THROUGH LRS TEST UNIT*** RAN 5' x 2.25'' DD BAILER TO S/D ON PATCH @ 8538' SLM / 8564' MD. UNABLE TO WORK PAST. RAN 2.25'' CENT, 3' x 2-1/8'' STEM, 2.50'' CENT, 2'' S-BAILER. TAG TD @ 8968' SLM / 8994' MD. (empty) ***WSR CONT. ON 12-03-2024*** 12/3/2024 LRS Test Unit 2, Continue WSR from 12/02/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/04/24 12/3/2024 ***WSR CONT. 12-03-2024*** PERFORMED HES MEMORY P-PROF PER PROGRAM (see log) ***JOB COMPLETE / TESTERS CONTINUE TO FLOW WELL ON DEPARTURE*** 12/4/2024 LRS Test Unit 2, Continue WSR from 12/03/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/05/24 12/5/2024 LRS Test Unit 2, Continue WSR from 12/04/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/06/24 Daily Report of Well Operations PBU P1-13 12/5/2024 CTU#1 1.5" Blue Coil. Job Scope: FCO / Contingent N2 Lift Testers unable to POP well, Tbg appears to be hydrated off. Call out hot oil pump truck. LRS pump truck pumped warm 15 bbl 60/40 & 73 bbls hot diesel. Injectivity = ~ 0.3bpm at ~ 3000psi. Release LRS. Nipple up BOPs and function test on the well. Make up 2.5" JSN fill clean out BHA. Bleed tubing pressure and the IA is not responsive. Begin troubleshooting. ***Job Continued on 12/6/2024*** 12/5/2024 T/I/O = 11/2344/13 Assist Coil Tubing Hydrate / Ice Plug ( FRACTURING ) Well Testers bled all gas out of the TBG. Pumped 15 bbls of 70*F 60/40 & 73 bbls of 180*F diesel down TBG in attempt to clear obstruction. Possible hydrates or tight formation. After pumping 29.5 bbls of fluid, TBG immediately pressured up to 2000 psi. I was able to pump through the obstruction @ somwhere between 0.2 - 0.3 BPM. DSO notified upon departure. FWHP = 2219/2408/26 12/6/2024 T/I/O=1880/105/1 Assist Coil Pump 128 bbls 180* DSL down IA. After coil bled the tubing, IA & TBG communication was able to be established and confirmed. Sim Ops complete DSO notified upon departure. FWHP = 1190/998/160 12/6/2024 CTU#1 1.5" Blue Coil. Job Scope: FCO / Contingent N2 Lift LRS Hot Oil pumped 128 bbls Hot Diesel, 19 bbls through Sta#1. Have TxIA communication now. RIH w/ 2.50" JSN taking returns thru Testers. Tag top of fill at 9000'. Bypass micromotion to get higher pump rate. Cleanout fill w/ Gel sweeps. Stack weight at 9032' ctm. Pump final gel sweep and chase ooh taking returns thru Test Unit. Finish chasing to surface. RBIH to circulate well to diesel. Tagged at 9005 CTMD. Discuss with OE and decision to proceed with circing well to diesel. Circulate out steadily increasing choke pressure to 1300psi. Jetted diesel across perfs. POOH. ***Job Continued on 12/7/2024*** 12/6/2024 LRS Test Unit 2, Continue WSR from 12/05/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/07/24 12/7/2024 CTU#1 1.5" Blue Coil. Job Scope: FCO / Contingent N2 Lift Continue circulating well to diesel and POOH. Turn over to Well Testers to POP. Well Flowing at ~ 50-100 bpd, 2mm GL Rate, 4mm Total Gas. Flowed back 300 bbls at 10am from time Coil turned over to Testers. Discuss w/ OE. RIH w/ 2.50" JSN. Dry Tag at 9009' ctm down / 9006' up.(Uncorrected Coil Depths). Cleanout with gel sweeps. Stack weight at 9016'. Increase to 2.75 bpm and cleanout down to 9032'. Unable to make any further hole. Pump final 21 bbl gel pill and chase to surface. Jet jewelry on way ooh. ***Continued on 12/8/2024*** 12/7/2024 LRS Test Unit 2, Continue WSR from 12/06/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/08/24 12/8/2024 LRS Test Unit 2, Continue WSR from 12/07/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/09/24 12/8/2024 CTU#1 1.5" Blue Coil. Job Scope: FCO / Contingent N2 Lift RBIH with 2.5" nozzle to circ well to diesel. Dry tagged at 9034'e / 9046'm. PUH and begin jetting perfs with diesel. Circulate Liner and Tbg to Diesel. Turn over to Testers to POP. Rig down CTU. ***Job Complete*** Daily Report of Well Operations PBU P1-13 12/9/2024 LRS Test Unit 2, Continue WSR from 12/08/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/10/24 12/10/2024 LRS Test Unit 2, Continue WSR from 12/09/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, Continue WSR On 12/11/24 12/11/2024 LRS Test Unit 2, Continue WSR from 12/10/24, Post Frac FLowback, IL P1-13, OL P1-24, Continue Clean Out, RD, Move Unit to LRS camp. End WSR On 12/11/24. 12/22/2024 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD UNIT 61 ***WSR CONT. ON 12-23-2024*** 12/22/2024 T/I/O = SSV/1725/0. Temp = SI. IA FL (WIC Req.). ALP = 2230 psi, SI @ CV. IA FL @ 2880' (1288' above sta #1, SO, 76 BBLS). SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 12/23/2024 ***WSR CONT. FROM 12-22-2024*** RAN 3.84'' NO-GO, 3' x 1-7/8'', 3.49'' CENT, 3' x 1.25'', 3.60'' FLAPPER CHECKER (92'' No-Go to Flap Checker) TO SSSV @ 2215' SLM/2238' MD (pins untouched) RAN 4-1/2" BRUSH, 3.79" G-RING, TAG TOP OF PATCH @ 8542' SLM/8564' MD (+22' correction) SET 4-1/2" WHIDDON C-SUB ON TOP OF PATCH @ 8564' MD PULLED BK-OGLV FROM ST #1 @ 4168' MD SET BK-OGLV (20/64" orifice) IN ST #1 @ 4168' MD PULLED EMPTY 4-1/2" WHIDDON C-SUB FROM TOP OF PATCH @ 8564' MD SET 3.81" X-LOCK, FLOW THRU SUB w/ DUAL SPARTEK GAUGES (battery connected @ 08:39 12-23-24, sec lockdown installed, 83" lih) IN BAKER CMU SLD SLV @ 8542' MD RAN 4-1/2" CHECK SET(sheared) ***WELL LEFT S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** 1/15/2025 T/I/O = SSV/1870/60. Temp = SI. Cold TIFL PASSED (eval TxIA). ALP = 2430, SI @ CV. IA FL @ 2880' (1288' above sta # 1 SO). Sacked well out to 2640/2410/180 in 2.5 hrs. Depressed IA FL 2990' (1178' above sta # 1 SO). Bled IAP to OT to 860 psi in 30 min. TP decreased 130 psi, IA FL foamed up 270' to 2720' (1448' above sta # 1 SO). Monitored for 1 hr. IAP increased 30 psi showing signs of stabilization, IA FL fell 270' to 2990' (1178' above sta # 1 SO). Extended monitor 1 hr. TP decreased 10 psi, IAP & IA FL unchanged. Released to Ops for POP. Final WHPs = 2480/890/10. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 1/23/2025 ***WELL S/I ON ARRIVAL*** (Fracturing) RIGGED UP POLLARD #61 ***CONTINUE ON 1/24/25 WSR*** 1/24/2025 ***CONTINUED FROM 1/23/25 WSR*** (Fracturing) PULLED 4-1/2" FLOW-THRU SUB W/ SPARTEK GAUGES AT 8,542' MD SET 4-1/2" FLOW-THRU SUB W/ SPARTEK GAUGES AT 8,542' MD ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 2/1/2025 LRS WTU #2, Begin WSR, RU, Contine WSR on 2/2/25 Daily Report of Well Operations PBU P1-13 2/2/2025 T/I/O= 2,480/945/167 (FRACTURING) Assist WTU #2: Pumped 110.5 bbls of 190* Crude down TBG and 10 bbls of 190* Crude down FL. WTU in control of well upon departure. FWHPs= 2654/1017/703 2/2/2025 LRS WTU #2, Continue WSR from 2/1/25, RU, Flowback, Continue WSR on 2/3/25 2/3/2025 LRS WTU #2, Continue WSR from 2/2/25, Well Test, SB, Pop PM1-13, Flow and stabilize well. Continue WSR on 2/4/25 2/4/2025 LRS Well Testing Unit#2. Continue WSR from 02/03/24. Well Test. IL PM1-13, OL PM1-08. Continue to stabilize well. Achieved FOC. Continue WSR on 02/05/2024. 2/4/2025 T/I/O = 650/1350/0. Temp = 76°. IA FL (Well Testers request). ALP = 1400 psi, online. IA FL @ 2725' (1443' above sta #1, SO, 72 BBLS). SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:00 2/5/2025 LRS Well Testing Unit #2. Continue WSR from 02/04/25. Well Test. IL PM1-13, OL PM1-08, Continue to stabilize Well. Continue WSR on 02/06/25. 2/6/2025 LRS Well Testing Unit #2. Continue WSR from 02/05/25. Well Test. IL PM1-13, OL PM1-08. Continue Flowback. RD, End WSR on 02/07/25. Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 11/20/2024 Job End Date: 11/20/2024 State: Alaska County: Beechey Point API Number: 50-029-22372-00-00 Operator Name: Hilcorp Alaska, LLC Well Name and Number: P1 13 Latitude: 70.390279 Longitude: -148.588502 Datum: NAD83 Federal Well: NO Indian Well: NO True Vertical Depth: 8248 Total Base Water Volume (gal)*: 132008 Total Base Non Water Volume: 0 Water Source Percent Surface Water, > 1000TDS 100.00% Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments BA-20 BUFFERING AGENT Halliburton Buffer BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CARBOPROP 20/40 Carbo Ceramics Proppant CL-28M CROSSLINKER Halliburton Crosslinker CLA-WEB(TM) Halliburton Clay Stabilizer LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Sand-Common White-100 Mesh, SSA-2 Halliburton Proppant SEAWATER Operator Base Fluid WG-36 GELLING AGENT Halliburton Gelling Agent Items above are Trade Names. Items below are the individual ingredients. Water 7732-18-5 100.00000 82.82739 None Ceramic materials and wares, chemicals 66402-68-4 100.00000 12.99376 None Sodium chloride 7647-14-5 5.00000 4.14137 None Crystalline silica, quartz 14808-60-7 100.00000 0.48554 None Guar gum 9000-30-0 100.00000 0.31252 None Water 7732-18-5 100.00000 0.18995 None Borate salts Proprietary 60.00000 0.05975 None Ethanol 64-17-5 60.00000 0.04734 None Ammonium salt Proprietary 60.00000 0.04277 None Ammonium acetate 631-61-8 100.00000 0.03180 None Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02367 None Oxyalkylated nonyl phenolic resin Proprietary 30.00000 0.02367 None Sodium hydroxide 1310-73-2 30.00000 0.02199 None Monoethanolamine borate 26038-87-9 100.00000 0.01529 None Ammonium persulfate 7727-54-0 100.00000 0.01317 None Acetic acid 64-19-7 30.00000 0.00954 None Oxyalkylated phenolic resin Proprietary 10.00000 0.00789 None Inorganic mineral 1317-65-3 5.00000 0.00498 None Potassium chloride 7447-40-7 5.00000 0.00498 None Ethylene glycol 107-21-1 30.00000 0.00459 None Oxylated phenolic resin Proprietary 30.00000 0.00395 None Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)- omega-hydroxy-, branched 127087-87-0 5.00000 0.00395 None Naphthalene 91-20-3 5.00000 0.00395 None 2-Bromo-2-nitro-1,3- propanediol 52-51-7 100.00000 0.00150 None Sodium chloride 7647-14-5 1.00000 0.00145 None Gluteraldehyde 111-30-8 1.00000 0.00100 None Calcium magnesium carbonate 16389-88-1 1.00000 0.00100 None Polymer Proprietary 1.00000 0.00100 None Inorganic mineral Proprietary 1.00000 0.00100 None 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00079 None Sodium bisulfate 7681-38-1 0.10000 0.00010 None Methanesulfonic acid, 1- hydroxy-, sodium salt 870-72-4 0.10000 0.00010 None Quaternary amine Proprietary 0.10000 0.00007 None Amine salts Proprietary 0.10000 0.00007 None 2,7- Naphthalenedisulfonic acid, 3-hydroxy-4-(4- sulfor-1-naphthalenyl) azo -, trisodium salt 915-67-3 0.10000 0.00002 None Magnesium nitrate 10377-60-3 0.01000 0.00001 None 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01000 0.00001 None 2-Methyl-4-isothiazolin- 3-one 2682-20-4 0.01000 0.00001 None Magensium chloride 7786-30-3 0.01000 0.00001 None * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 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 P1-13 Recomplete to New Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 11010 Conductor Surface Intermediate Production Liner 8745 74 3521 10275 888 9073 20" 10-3/4" 7-5/8" 4-1/2" 8430 38 - 112 37 - 3560 35 - 10275 10122 - 11010 38 - 112 37 - 3558 35 - 8744 8746 - 8745 9676 520 2480 5120 7500 9073 , 9139 , 9373 , 10150 2300 5210 8180 8430 8801 - 10987 4-1/2" 12.6# L-80 33 - 8695 8248 - 8744 Structural 4-1/2" TIW HBBP, 8617 , 8098 2238 8617 8098 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY / PT MCINTYRE OIL / PM STUMP ISL 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 0028297 33 - 8163 0 498 31176 6223 0 33 0 1652 2427 576 324-169 13b. Pools active after work:PM STUMP ISL OIL 4-1/2" Camco TRCF-4A 2238 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 1:13 pm, Jun 13, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.06.12 20:48:28 - 08'00' Bo York (1248) RBDMS JSB 061924 WCB 11-7-2024 DSR-6/13/24 ACTIVITYDATE SUMMARY 3/31/2024 ***WELL S/I ON ARRIVAL***(drift for eline) HES-046 RIG UP & AUDIT OF PCE - WAITING ON WINDS TO DECREASE (high winds) ***CONT WSR ON 4/1/24*** 4/1/2024 *** CONTINUE FROM 03/31/2024 *** (trblsht trsssv, drift for eline) RAN 3.84" NO-GO CENT 98" 3.50" CENTRALIZED PRONG W/ 3.5 TT PINS TO TRCF-SSSV @ 2,204' SLM / 2,238' MD (pins untouched) RAN 3.70" GAUGE RING S/D @ 2,204' SLM RAN 3.84" NO-GO CENT TO 2,204' SLM RAN 3.5" CENT, 5' x 2.5" DRIVE DOWN BAILER TO 2,204' SLM RAN 3.84" NO-GO CENT 98" 3.50" CENTRALIZED PRONG W/ 3.5 TT PINS TO TRCF-SSSV @ 2,204' SLM / 2,238' MD (pins untouched) PUMP VIA TRIPLEX/DIESEL TOTE FOR APPROX 5 MIN PRESSURE DECREASES FROM 2517 TO 2483 PSI. RAN 3.84" CENT, 3' x 1-7/8" STEM, 5' x 3.0" DRIVE DOWN BAILER TO 2,204' SLM (while pumping above, no psi changes from no-go, good ring on cent) RAN 3.84" NO-GO CENT, DOUBLE 4.5" BRUSH, 3.25" GAUGE RING TO TRCF- SSSV @ 2,204' SLM / 2,238' MD (ring on no-go) RAN 5' x 3.0" DRIVE DOWN BAILER W/ V-TAPERED BALL BTM (71") TO 9,301' SLM (no issues) ***CONT WSR ON 4/2/24*** **Conduct h2s/man down drill w/ wsl & crew** 4/2/2024 ***CONT WSR FROM 4/2/24***(drift for eline/ibp) RAN 3.50" CENT, 5' x 3.0" DRIVE DOWN BAILER TO 9,301' SLM (no issues) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 4/2/2024 T/I/O = xx/xx/xx Temp = xx (Assist E-Line with.....) 4/8/2024 T/I/O = 1200/223/0 LRS 70 - Assist E-Line (PERFORATING) Pumped 270 bbls 160* 1% KCL and 40 bbls Crude into TBG for load and FP. E-Line in cotrol of well and DSO notified upon LRS departure. Daily Report of Well Operations PBU P1-13 Daily Report of Well Operations PBU P1-13 4/8/2024 ***WELL S/I ON ARRIVAL*** (CBL AND IBP SET) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH LRS LOAD TBG W/ 270 BBLS OF2 % KCL AND 40 BBLS OF CRUDE TO FREEZE PROTECT RUN#1 W/CH/1.69'' WB/3 1/8'' CCL/1.69'' CENT/3 1/4'' CBL/1 69'' CENT/2.75'' GR/1.69'' CENT TO REORD CBL LOG FROM 9250' TO 8695' MD RUN#2 W/CH/1.69'' CCL/BAKER IBP SETTING TOOL AND 3.38'' IBP TO SET PLUG AT 9165' MD, CCL TO MID ELEMENT 25.85' ,CCL STOP DEPTH 9139.15' MD CCL CORRELATE TO YELLOWJACKET PERFORATING RECORD DATED 11- OCT-2023 JOB COMPLETE ***WELL S/I ON DEPARTURE*** 4/13/2024 *** WELL S/I ON ARRIVAL *** RUN FLAPPER CHECKER TO TRCF @ 2,238' MD LOCATED IBP @ 9,127' SLM DUMPED 7.5 GALLON OF SLUGGET ON TOP OF IBP @ 9,139' MD *** CONIUE WSR ONTO 4/14/24 *** 4/14/2024 *** CONTINUED WSR FROM 4/13/24 *** DUMPED 2.5 GALLON OF SLUGGISH ON TOP OF IBP @ 9,139 MD (10 GALLON TOTAL) LOCATE TUBING END @ 8,667' SLM (-29' CORRECTION) *** WELL S/I ON DEPARTURE *** 4/18/2024 LRS CTU #1, 1.5" Blue Coil, Job Objective: Log/Cement Plug MIRU. No uprights on location and MM in choke trailer is nonoperational. Techs troubleshoot MM and determine we need to swap out trailer. Rig down trailer and wait for replacement. ~6hrs until trailer swapped out and fully operationally. Continue rigging up. ***Job Continued on 19-Apr-2024*** 4/19/2024 LRS 72 Assist CTU 1. Pumped 200 bbls of warm diesel into the coil as directed. 10 gal of sluggits translates to 5', so top of sluggits would be @9160' MD. -WCB IBP TO SET PLUG AT 9165' MD, CCL TO MID ELEMENT DUMPED 2.5 GALLON OF SLUGGISH ON TOP OF IBP @ 9,139 MD (10 GALLON TOTAL) LOCATED IBP @ 9,127' SLM DUMPED 7.5 GALLON OF SLUGGET ON TOP OF IBP @ 9,139' MD @ Daily Report of Well Operations PBU P1-13 4/19/2024 LRS CTU #1, 1.5" Blue Coil, Job Objective: Log/CMT Plug ***Continued from 18-Apr-2024*** RIH w/ HES GR/CCL 3.25" Nozzle. Tagged 9143' CTM, logged up to 8400' w/ flag @ 9040'. POOH and check data. Log shows a +18' correction. Make up and RIH with 2.25" pig shear nozzle BHA. Corrected depth at flag and circulate the well to diesel. POOH due to hydraulic leak on SSV. Install fusible cap and continue out of hole. Repair SSV. RBIH and tie in at flag. Load 4 bbl of 15.8ppg cement into coil and foam pig with 3/4" ball. Cement spotted form 9160.5 to 9073. Good indication of shear on the pig shear. Pull out of cement to a corrected depth of 9019 and open nozzle. POOH pumping pipe displacement. Wash up BOPs and surface lines. Ball recovered. Begin BOP test WELL CONTROL DRILL ***Job in Progress*** 4/20/2024 LRS CTU #1, 1.5" Blue Coil, Job Objective: Log/Cement Plug ***Job continued from 19-Apr-2024*** Finish BOP testing. RDMO. ***Job Complete*** 4/24/2024 T/I/O=560/922/0 Temp=SI AOGCC MIT T FAILED (Witnessed by AOGCC Inspector Sully Sullivan) Pumped 3.5 bbls of crude down tubing to achieve test pressure of 3247 psi. T lost 309 psin in 15 mins. Bleed down and repressurize to 3248 psi with 3.5 bbls of crude. T lost 258 psi in 15 mins. The witnessed test failed but continue to pressure test tubing on 5th attempt T lost 159 psi in 15 mins and 78 2nd 15 mins for a total loss of 237 psi in 30 mins. Bled down pressures. Final WHPS=575/0/0 4/24/2024 ***WELL S/I ON ARRIVAL*** RAN KJ, 2' x 1-7/8" STEM, 3.68" CENT, 4-1/2" TEL, 2.50" S. BAILER(msfb). LOC TT @ 8690' SLM/8696' MD(+6' correction), TAG TOC @ 9066' SLM/9072' MD(bailer full of good cement) T-BIRD ATTEMPT PRE-AOGCC MIT-T, NOT LOOKING GOOD(see t-bird log) RAN KJ, 2' x 1-7/8" STEM, 3.68" CENT, 2.50" S. BAILER(msfb). PERFORM AOGCC WITNESS TAG, TAG TOC @ 9066' SLM/9072' MD(bailer full of fluid, cement set, state witness SULLY good with tag) T-BIRD ATTEMPTED AOGCC MIT-T( fail, see t-bird log) T-BIRD PERFORMED PASSING MIT-T TO 3,009 psi (see t-bird log, bled back 2 bbls) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 4/24/2024 Travel to location 4/25/2024 T/I/O= 743/478/0 MIT-T PASSED to 3036 psi.(Perforating) RIg up to IA and apply 1000 psi with 2 bbls of diesel. RU to tubing. Pumped 2.2 bbls of diesel to achieve test pressure of 3334 psi.. Tubing lost 204 psi 1st min and lost 94 psi 2nd 15 mins for a totalo loss of 298 psi in 30 minst. Bled back 2 bbls.Final WHPs = 647/641/0 Valve Positions: SV/WV/SSV = Closed, MV = Open, IA/OA = OT state witness SULLY good with tag) ( T-BIRD PERFORMED PASSING MIT-T TO 3,009 psi MIT T FAILED (Witnessed by AOGCC Inspector Sully Sullivan) (g) PERFORM AOGCC WITNESS TAG, TAG TOC @ 9066' SLM/9072' MD@ 4 bbls of cement translates to 87' (7-5/8" cap = .0459 bbl/ft), placed to meet the 75' minimum specified in 20 AAC 25.112 (c). -WCB SL tagged TOC @9072' MD, which is 88' from the calculated top of sluggits. 20 AAC 25.112 (c) is met. -WCB Load 4 bbl of 15.8ppg cement into coil andgg foam pig with 3/4" ball. Cement spotted form 9160.5 to 9073. Good indication ofg shear on the pig shear. Pull out of cement to a corrected depth of 9019 and openg nozzle. POOH pumping pipe displacement. MIT-T PASSED to 3036 psi Daily Report of Well Operations PBU P1-13 4/26/2024 T/I/O=932/1004/1 Temp- SI AOGCC MIT T FAILED (Witnessed by AOGCC Inspector Austin McLoed ) Pump 2.8 bbls diesel to 3337 psi for Pre State MIT T. T lost 197 psi 1st 15 mins and lost 103 psi 2nd 15 mins. Bled back ~2.8 bbls to 467 psi. Pumped 1.1 bbls diesel to 3360 psi. T lost 126 psi 1st 15 mins and lost 85 psi 2nd 15 mis for a total loss of 211 in 30 mins.. Repressurize with 0.25 bbls to 3338 psi for test #2. T lost 94 psi 1st 15 mins and lost 76 psi 2nd 15 mins. Ran test an additonal 15 mins. T lost 68 psi 3rd 15 mins for a total loss of 233 psi in 45 mins. Bled back ~1.4 bbls. Final WHPs=465/950/0 4/30/2024 ***WELL S/I ON ARRIVAL*** R/U POL-61 ***WRS CONT ON 5-1-24*** 5/1/2024 ***WSR CONT FROM 4-30-24*** TAGGED & BRUSHED 3.725'' SWN NIP @ 8671' MD & BRUSHED 3.81'' SWS NIP @ 8654' MD SET 3.725'' PXN PLUG BODY (4 x 3/16'' ports, 26'' lih) IN SWN NIP @ 8671' MD SET P-PRONG(1.75" fn & body, 96" oal) IN PXN PLUG BODY @ 8671' MD MULTIPLE MIT-T ATTEMPTS (see log) WHILE RIH TO PULL P-PRONG, BOBBLED THRU TRSSSV @ 2338' MD, AND SNIPPED WIRE OFF ROPE SOCKET WHILE PICKING UP 2338' MD TAGGED TRCF SSSV w/ 3.84'' NO-GO CENT @ 2215' SLM / 2238' MD RAN 3.84'' NO-GO & 4-1/2'' FRICTION TOOL (NO-GO TO SLIPS 44'') TRCF SSSV @ 2214' SLM / 2338' MD (see log) RAN 3.84'' NO-GO CENT & FLAPPER CHECKER (3.68'' pins) (all pins intact, one pin slightly bent upward, all other pins look good) RAN 3.84'' NO-GO & 4-1/2'' FRICTION TOOL (NO-GO TO SLIPS 40'') TRCF SSSV @ 2214' SLM / 2338' MD (see log) ***WSR CONT ON 5-2-24*** 5/2/2024 ***WSR CONT FROM 5-1-24*** RAN 3.84'' NO-GO CENT & FLAPPER CHECKER (3.68'' pins) (all pins intact, one pin slightly bent upward - possibly from while running in hole) RECOVERED TOOL STRING & PX- PRONG w/ 3.60'' BELL GUIDE, 2-1/2'' JD FROM 8644' SLM PULLED 4-1/2" PXN PLUG BODY FROM SWN NIP @ 8671' MD PERFORMED MAN DOWN DRILL w/ WSS & SSE ATTEMPT MULTIPLE PRESSURE TEST's ON TUBING (see log) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 5/3/2024 T/I/O 675/1095/7 MIT - T **PASS** to 2359 psi. Max applied = 2500 psi. Pressured up TBG with 1.6 bbls crude. 1st 15 min. TBG lost 102 psi. 2nd 15 min. TBG lost 47 psi. Bled back ~ 1.6 bbls FWHP's = 610/1095/8 5/9/2024 T/I/O=565/1111/0 AOGCC MIT T PASSED to 2200 psi ( Witnessed by Guy Cook ) Pumpoed 2 bbls diesel down tbg to 2510 psi. TP lost 145 psi 1st 15 min & 64 psi 2nd 15 min. Bled back 2 bbls FWHPs=565/1115/0 AOGCC MIT T PASSED to 2200 psi ( Witnessed by Guy Cook ) ( MULTIPLE MIT-T ATTEMPTS AOGCC MIT T FAILED (Witnessed by AOGCC Inspector Austin McLoed ) Daily Report of Well Operations PBU P1-13 5/12/2024 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) MIRU AKEL RIG UP PCE PT 250LP 3000HP PERF (9026-9063') 2.75" 6 SPF RZR CHARGES CCL STOP DEPTH= 9017.2 CCL-TS=8.8' PERF (8989-9026) 2.75" 6 SPF RZR CHARGES CCL STOP DEPTH=8980.2 CCL-TS=8.8 LAY DOWN FOR THE EVENING ***JOB CONTINUES ON 13-MAY-24 WSR*** 5/13/2024 ****JOB CONTINUES FROM 13-MAY-24 WSR*** (ADPERF) RIG UP AKEL PT PCE 250LP 3000HP PERFORATE WITH 2.75" 6 SPF GEO DYNAMIC RAZOR CHARGES. (8956-8989) (CCL STOP DEPTH= 8941.3) CCL-TS=14.7 (8925-8956) (CCL STOP DEPTH= 8916.2) CCL-TS=8.8 (8894-8925) (CCL STOP DEPTH= 8885.2) CCL-TS=8.8 LAY DOWN FOR THE EVENING ***JOB CONTINUES ON 14-MAY-24 WSR*** 5/14/2024 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) RIG UP PCE PT 250LP 3000HP PERFORATE THE FOLLOWING ZONES WITH 2 3/4 6 SPF RAZOR CHARGES (8863-8894) CCL STOP DEPTH=8854.2 (CCL-TS=8.8') (8832-8863) CCL STOP DEPTH=8823.2 (CCL-TS=8.8') PERFORATE THE FOLLOWING ZONE WITH 3 1/8 6 SPF RAZOR CHARGES (8801-8832) CCL STOP DEPTH= 8791.2 (CCL-TS=9.8') ALL GUNS CORRELATED TO YJT CBL DATED 09APR24 ***WELL SHUT IN ON DEPARTURE, READY FOR SLICKLINE*** 5/17/2024 ***WELL S/I ON ARRIVAL*** (Perforating) POLLARD #60 RIG UP ***CONTINUE ON 5/18/24 WSR*** 5/18/2024 ***CONTINUED FROM 5/17/24 WSR*** (Perforating) RAN FLAPPER CHECKER TO 4-1/2" TRCF AT 2,238' MD (confirmed open) SET 4-1/2" SLIP STOP CATCHER AT 4,313' SLM PULLED BK-DGLV FROM ST# 1 AT 4,168' MD SET BK-OGLV IN STA #1 AT 4,168' MD PULLED 4-1/2" SLIP STOP CATCHER AT 4,313' SLM SET 4-1/2" X-LOCK W/ FLOW THRU SUB, SPARTEK GAUGES IN SWN AT 8,671' MD (confirmed with check set) ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS**** Top of sluggits calculates to be 9160' MD. -WCB Nolan 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: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 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 P1-13 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 ADL 0028297 11010 Conductor Surface Intermediate Production Liner 8745 74 3521 10275 888 9073 20" 10-3/4" 7-5/8" 4-1/2" 8430 38 - 112 37 - 3558 36 - 10274 10122 - 11008 3085 38 - 112 37 - 3558 36 - 8744 8746 - 8745 9676 520 2480 5120 7500 9073 , 9139 , 9373, 10150 2300 5210 8180 8430 8801 - 10987 4-1/2" 12.6# L-80 33 - 86968248 - 8744 Structural 4-1/2" TIW HBBP , 4-1/2" TIW SS Horiz 4-1/2" Camco TRCF-4A 8614 , 10122 / 8098 , 8746 2236 / 2235 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY 11/11/2024 Current Pools: PM STUMP ISL OIL Proposed Pools: PM STUMP ISL 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 By Grace Christianson at 12:45 pm, Oct 23, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.10.23 07:10:07 - 08'00' Bo York (1248) 324-611 10-404 MGR28OCT24 DSR-10/23/24SFD 10/28/2024 11/11/2024 CDW 10/28/2024 JLC 10/29/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.11.01 09:25:44 -08'00'11/01/24 RBDMS JSB 110124 P1-13 : Stump Island Fracture SƟmulaƟon Page 1 of 4 Well Name:P1-13 API Number:50-029-22372-00 Current Status:Operable, Shut in Permit to Drill Number:193074 Estimated Start Date:Nov 11, 2024 Rig:Slickline, Frac Regulatory Contact:Carrie Janowski Estimated Duration:4 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Brief Well Summary: P1-13 was drilled in June 1993 in the Gravity Drainage fault block at Pt. Mac. The well was a mostly steady producer until going Not Operable in 2013 for a production casing leak. An IA cement job in August 2015 restored well integrity and the was made Operable. Post repair the well has been high GOR and has not had on time. In April 2024, the well was recompleted to the Stump Island interval. Subsequent diagnostics and well testing have indicated the reservoir is single digit millidarcy permeability and that the well performance could improve with a hydraulic fracture stimulation. Objective: Perform hydraulic fracture stimulation on Stump Island. Current Bottom Hole Pressure:3,900 psi at 8,144’ TVD Max. Anticipated Surface Pressure:3,085 psi (0.1 psi/ft gas gradient) Last Shut-in WHP:1,700psi – WSR 9/23/24 Min. ID:3.725” at 8,671’md (SWN Nipple) Max. Deviation:92.1deg at 10,265’md H2S Concentration:80 PPM 6/29/24 Well Integrity Information: Tbg & IA: MIT-T passed 3,036psi 4/25/24 OA: MIT-OA passed 1,200psi 6/8/2013 Well Completion Information: Wellhead: FMC, 11”, 5M Tree: CIW, 4-1/16”, 5M SVLN: Camco, 4-1/2”, TRCF GLM: Merla, TMPDX Production Pkr: TIW, 7-5/8” x 4-1/2” HBBP LTP: TIW, 7-5/8” x 4-1/2” ‘SS’ Existing Casing/Tubing Program: String Pipe #/ft Grade Connection Top Bottom Cap. (bbl/ft) Surface csg.10-3/4”45.5 L-80 BTC Surface 3,558’0.0943 Prod. Csg.7-5/8”29.7 NT95HS NSCC Surface 10,274’0.0459 Tbg.4-1/2”12.6 L-80 TDS Surface 8,696’0.0152 Prod. Lnr.4-1/2”12.6 L-80 TDS 10,122’11,008’0.0152 80 PPM 6/29/24 P1-13 : Stump Island Fracture SƟmulaƟon Page 2 of 4 Wellwork Procedure: Fullbore: 1. Sand back to ~8,880’ md. Slickline: 2. Tag top of sand. 3. Load IA with seawater and diesel freeze protect. 4. STA 1 DGLV. 5. MIT-IA to 3,000 psi. 6. Set frac sleeve across subsurface safety valve at 2,238’. Frac: 7. Perform hydraulic fracture treatment per pump schedule in sundry application. Treating pressures also noted in sundry application. Stage #Fluid Stage Volume Rate Prop. Conc. (ppa)Proppant Name Proppant (#) 1 20# Linear Load 6,300 10 2 20# Linear FET 8,700 25 3 Shutdown 4 20# Linear Pad 2,000 25 5 20# Linear Diverter/Scour 2,000 25 0.5 100 mesh 1,000 6 20# Linear Diverter/Scour 1,400 25 0.75 100 mesh 1,050 7 20# Linear Diverter/Scour 1,000 25 1.0 100 mesh 1,000 8 20# Linear Over Flush 8,400 25 9 Shutdown 10 30# X-Link Pad 9,000 25 11 30# X-Link 1 PPA 10,000 25 1.0 20/40 CarboLite 10,000 12 30# X-Link 2 PPA 10,000 25 2.0 20/40 CarboLite 20,000 13 30# X-Link 3 PPA 10,000 25 3.0 20/40 CarboLite 30,000 14 30# X-Link 4 PPA 10,000 25 4.0 20/40 CarboLite 40,000 15 30# X-Link 5 PPA 10,000 25 5.0 20/40 CarboLite 50,000 16 30# X-Link 6 PPA 10,000 25 6.0 20/40 CarboLite 60,000 17 20# Linear Flush 8,400 6a. Install and test tree saver to 6275 psi. 6b. Pressure test treating lines to 6275 psi. 6c. Pressure test pump kick outs to 4750 psi and global kick outs to 5015 psi. 6d. Pressure test IA pop-offs to 2850 psi. - mgr P1-13 : Stump Island Fracture SƟmulaƟon Page 3 of 4 MIT-T 3000 psi MIT-IA 3000 psi Maximum Anticipated Treating Pressure:4020 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):2850 psi IA Minimum Hold Pressure (POP-off – 300 psi):2550 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T/1.1):5275 psi w/ 2550 psi on IA Stagger Pump Kickouts Between 90 – 95% of MATP:4750 psi Global Kickout (95% of MATP):5010 psi N2 POP-off set pressure (MATP):5275 psi Treating Line Test Pressure (MATP + 1000 psi):6275 psi OA Pressure:Monitor Max Anticipated Proppant Loading:6 PPA Slickline: 8. Pull frac sleeve. 9. Set kickoff GLVs. Well Testing: 10. Post frac flowback with contingent coil cleanout. P1-13 : Stump Island Fracture SƟmulaƟon Page 4 of 4 Wellbore Schematic: Date: Oct 19, 2024 Subject: P1-13 Stump Island Sandstone Fracture Stimulation From: Eric Dickerman O: (907) 564-4061 C: (307) 250-4013 To: AOGCC Estimated Start Date: Attached is Hilcorp’s proposal and supporting documents to perform a fracture stimulation on well P1- 13 in the Stump Island reservoir of the Prudhoe Bay Unit. P1-13 was recently recompleted from the Point McIntyre pool to the Stump Island Pool. The well was perforated and tested, and resulting diagnostics indicate single digit mD formation permeability with high oil cuts and little to no water production. Pressure transient analysis indicates a positive 30 skin factor. These diagnostics indicate that the well performance could improve with a hydraulic fracture stimulation. P1-13 is currently the only well completed and producing from the Stump Island pool. As a continuation of evaluating the Stump Island pool, P1-08A is also planned to be recompleted and fracture stimulated in the Stump Island to allow pulse testing. Well location: Section 16, T12N, R14E. Hilcorp requests an exception to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling, based on Area Injection Orders. Please direct questions or comments to Eric Dickerman. 11/11/2024 SECTION 1 - AFFIDAVIT (20 AAC 25. 283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1. SIGNED AFFIDAVIT: COPY OF NOTIFICATION SENT VIA EMAIL: Estimated start date is Nov 11, 204 SECTION 2: PLAT IDENTIFYING ALL WELLS WITHIN 1/2 MILE – SURFACE (20 AAC 25. 283, a, 2, B): List of wells in Plat (20 AAC 25.283, a, 2, B): SECTION 3: EXEMPTION FOR FRESWATER AQUIFERS (20 AAC 25. 283, a, 3): Well P1-13 is located in the Eastern Operating Area of Prudhoe Bay (AIO 4G, 2015). In 1993 AIO 4 was amended to include the Pt. Mcintyre, Stump Island, and West Beach Oil pools in AIO 4A. Conclusion #10 (Area Injection Order 4A, August 12, 1993, Page 5) states that “No underground sources of drinking water (USDWs) are known to exist in the Eastern Operating Area of the Prudhoe Bay Unit and the Pt. McIntyre oil field.” Area Injection Order 4G, October 15, 2015, Page 3 states that “All information related to AIO 4, AIO 4A, AIO 413, AIO 4C, AIO 4D, AIO 4E and AIO 4F is hereby incorporated by reference into the record for this order.” Based on the Area Injection Order sections referenced above, Hilcorp requests exemption from 20 AAC 25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water sampling.Agree that there are no freshwater aquifers within 1/2-mile radius AOR surrounding P1-13 fracturing interval. SFD SECTION 4: PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS (20 AAC 25.283.a): There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5: DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25. 283, a, 5): All casing is cemented in accordance with 20 AAC 25.52, b and tested in accordance with 20 AAC 25.030, g when completed. See wellbore schematic for casing details: SECTION 6: ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL (20 AAC 25.283, a, 6): Summary: Spud date for P1-13 was 5/28/1993. A 13-1/2” hole was drilled and 10-3/4” surface casing was ran to 3,570’ md. The surface casing was cemented with a lead of 2,235 cubic ft of Type E Permafrost cement followed by 403 cubic ft Class G tail. The plug bumped and pressured up to 2,000psi. A 235 cubic ft sx top job was also performed. A 9-7/8” intermediate hole was drilled to 10,275’ md and cased with 10,275’ of 7-5/8” casing. The casing was cemented with 163.2 bbl of 15.8ppg cement, no losses reported, and the top plug bumped at 472 bbl (reported 4,682 strokes at 0.1008bbl/stroke) versus a calculated volume to float collar of 468 bbl. Accounting for the shoe track and zero rathole puts 159.5 bbl of cement in the annulus (897 cu ft or 159.8bbl reported on the 10-407). A 1.3 excess factor (1.3 times the openhole x casing capacity) places the cement top behind the 7-5/8” casing at 6,649’ md (6,377’ ssTVD). Using an additionally conservative 2.0 excess factor (2 times the openhole x casing capacity) puts the calculated top of cement at 8,193’ md (7,689’ ssTVD). A Cement Bond Log was pulled on April 8, 2024 and logged good cement behind the 7- 5/8” from the bottom of the logging interval at 9,050’md (8,368’ ssTVD) up to the 4-1/2” tubing tail at 8,704’ (8,123’ ssTVD). This log indicates that the top of cement behind the 7-5/8” casing is above 8,704’ md. Current pick of top of Stump Island interval is 8,797’ md (8,196’ ssTVD). This log indicates good cement isolation above and below the Stump Island pool. A 6-3/4” production hole was drilled and the well was completed with a 4-1/2” un-cemented production liner down to 11010’. On 8/20/2015, 108 bbl of Class G cement was circulated in to the 7-5/8” x 4-1/2” annulus to cement off a production casing leak. A subsequent MIT-IA to 2,500psi passed. All casing is cemented in accordance with 210 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, Hilcorp has determined that this well can be successfully fractured within well design limits. CBL demonstrates very good-quality cement across the Kuparuk and Stump reservoirs continuing upward to top of log at 8,704' MD. SFD SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL (20 AAC 25.283, A, 7): On 4/25/24, the tubing was pressure tested to 3036psi for a passing MIT-T. As part of the well preparation pre-frac, the 7-5/8” x 4-1/2” annulus will be tested to 3,000psi. The 7-5/8” x 4-1/2” and the 10-3/4” x 7-5/8” annulus pressures will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before frac operations continue. SECTION 8: PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD (20 AAC 25.283, A, 8): Wellbore Tubular Ratings Size/Name Weight Grade Burst, psi Collapse, psi 10-3/4” Surface Casing 45.5#NT80 5,210 2,470 7-5/8” Intermediate Casing 29.7#NT95HS 8,180 5,130 4-1/2” Production Liner 12.6#L80 8,430 7,500 4-1/2” Production Tubing 12.6#L80 8,430 7,500 Wellhead FMC manufactured wellhead, rated to 5,000 psi. Tubing head adaptor: 11" 5, 000 psi x 4-1/16" 5,000 psi Tubing Spool: 11" 5, 000 psi w/ 2-1/16" side outlets Casing Spool: 11" 5, 000 psi w/ 2-1/16" side outlets Tree: CIW 4-1/16" 5,000 psi A 10k psi rated TreeSaver will be used during these fracturing operations.TreeSaver SECTION 9: DATA FOR FRACTURING ZONE AND CONFINING ZONES (20 AAC 25.283, A, 9): >ĺıÍťĖĺĲ a" ĺŕ a" ÍŜô «"ŜŜ ĺŕ «"ŜŜ ĺťťĺı «" ēĖèħĲôŜŜ >ŘÍè @ŘÍîϟ ŕŜĖϯċť [Ėťēϟώ"ôŜèϟ ĺīīŽĖīīôaŪîŜťĺĲôŜ ϼa͒Ͻ ͖͔͖͔͔͕͕͕͒͒͗͒͗͐͒͐͑͘͏͏͏ϟ͖͏ēÍīô ĺŕώťŪıŕώIŜīÍĲîώēÍīô ͖͔͔͖͔͕͔͗͗͗͐͒͗͐͒͑͘͘͏ϟ͖͐ĖīťϯēÍīô ťŪıŕώIŜīÍĲî ÍĲîŜťĺĲô ͖͔͗͘͘͏͕͔͖͔͑͗͐͗͒͐͗͘͏͏ϟ͕͕ĖīťϯÍĲîŜťĺĲô F¾͘͏͕͕͖͖͔͓͕͕͑͐͗͒͗͒͐͘͏ϟ͖͏ēÍīô XŪŕÍŘŪħ ͕͖͐͘ϱ ͓͕͗͒ϱ ϱ ͏ϟ͕͒ÍĲîŜťĺĲô SECTION 10: LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE (20 AAC 25.283, a, 10): Plat of wells within one-half mile of P1-13 wellbore reservoir trajectory and location of faults. Black squares indicate Stump Island pool intersections. The plat shows the location and orientation of each well that transects the confining zone. Hilcorp has formed the opinion, based on the following assessments for each well, seismic, and other subsurface information currently available, that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing and Cement assessments for all wells that transect the confining zone: P1-02 (PTD 188005) Formerly Point McIntyre #3 Well was spudded 3/12/1988. The 12-1/4” surface hole was drilled down to 4,496’ and 9-5/8” casing was ran to 4,483’ md. The 9-5/8” casing was cemented with 2,000sx CS II and 400 sx of Class G, with cement returns to surface. The 8-1/2” hole was drilled to 9,416’ md and 7” casing was run to 9,407’ md. The 7” casing was cemented with 444 sx (187 bbl) 12.5 ppg Class G with 12% gel slurry lead and a 290 sx (60 bbl) 15.7 ppg Class G tail. An external casing packer was run as part of the 7” casing with a set depth of 8,933’ – 8,954’. A cement bond log was ran in the 7” casing on 4/6/1988 and the Tail TOC picked from that log is 8,725’ md (8,168’ ssTVD) with the Lead TOC picked at 6,160’ md (5,755’ ssTVD). Top of Stump Island interval is at 8,171’ ssTVD. On 3/22/02, coiled tubing layed in a Class G cement abandonment plug from 9,343’ md up to 7,000’ md (8,778’ – 6,480’ ssTVD) after squeezing 15 bbl behind pipe. The tubing was then cut at 6,530’ and the well was sidetracked to P1-02A which penetrates the Prudhoe Bay, Pt M Stump Is Oil Pool outside of the 1/2” mile radius of P1-13. P1-G1 (PTD 192113) P1-G1 was spudded 11/3/1992. The 16” surface hole was drilled down to 3,500’ md and 13-3/8” casing was ran to 3,485’ md. The 13-3/8” casing was cemented with 1,329 sx (513 bbl) Permafrost E lead and 400 sx (82 bbl) of Class G tail cement. The plug was bumped and 30bbl of losses were noted. A 107 sx Permafrost C top job was performed with a 1” workstring and cement was returned to surface. The 12- 1/4” hole was drilled to 8,607’ md and 9-5/8” casing was ran to 8,607’ md. The 9-5/8” casing was cemented with 435 sx (89 bbl) of Class G cement and the plug was bumped. The 8-1/2” hole was drilled to 8,840’ md and a 7” liner was ran from 8,432’ md down to TD at 8,840’ md. The 7” liner was cemented with 115 sx (25 bbl) Class G cement. The plug was bumped and excess cement was reversed off the liner top. A Segmented Bond Log was ran on 11/26/1992. The log showed cement all the way up to the 7” liner top and logged a TOC behind the 9-5/8” casing at 7,602’ md (7,498’ ssTVD). Top of Stump Island interval is 8,150’ ssTVD. TOC behind the 9-5/8” casing at 7,602’ md (7,498’ ssTVD). Top of Stump Island interval is 8,150’ ssTVD. Lead TOC picked at 6,160’ md (5,755’ ssTVD). Top of Stump Island interval is at 8,171’ ssTVD. P1-08 (PTD193098) and P1-08A (PTD 202199) P1-08 was spudded 7/14/1993. The 13-1/2” hole was drilled to 3,560’ and 10-3/4” casing was ran to 3,560’. The 10-3/4” casing was cemented with 1,027 sx (397 bbl) of Permafrost E lead and 350 sx (72 bbl) of Class G tail cement. The plug was bumped. A 250 sx (42bbl) top job was performed. The 9-7/8” hole was drilled to 10,193’ and 7-5/8” casing was ran to 10,193’ md. The 7-5/8” casing was cemented with 630 sx (135 bbl) of Class G cement. The plug did not bump, however only 3’ of excess cement was noted when cement was tagged at 10,110’ versus a float collar depth of 10,113’ while drilling out the 7- 5/8” shoe tract. No CBL was logged in the 7-5/8”. Volumetric and lift calculations from data available on the 7-5/8” primary cement job put the TOC at 7,741’ md (7,146’ ssTVD). This is equivalent to a 40% excess factor and accounts for the rathole and shoe tract volumes. The 6” production hole was drilled to 10,900’ and completed with a 4-1/2” slotted liner. P1-08 was sidetracked to P1-08A on 12/21/2002. The rig drilled out of the shoe of the existing 4-1/2” slotted liner to a TD of 12,444’ with the entire lateral in the Kuparuk reservoir. The 3-1/2” x 3-1/4” x 2- 7/8” CTD liner was ran to 12,444’ and cemented with 41bbl of 15.8ppg Class G cement. Full returns were noted throughout the job. A CBL logged on 7/23/2024 logged the TOC behind the CTD liner at 9,751’ md. ®ôīī ĺŕ ťŪıŕ IŜīÍĲî ÍŜĖĲČ ĖƏô èŘĺŜŜ ťŪıŕ IŜīÍĲî ÍŜĖĲČ ēĺô "ôŕťē ÍŜĖĲČ ēĺô "ôŕťē iiώaôťēĺî ¾ĺĲÍī IŜĺīÍťĖĺĲ ŜŜ«"ĖĲ ċťώıî ċťŜŜ«"ċťŜŜ«" ͐ϱ͏͖͖͑͗͐͐Г ͓͘͏͖͓͕͗͗͑͗͐͗ôıôĲťώĺĲîώ[ĺČ ´ôŜ ͐ϱ@͔͐͗͐͏͘ϱ͔ϯ͗Г ͕͗͏͖͓͗͏͖͖͓͗͘ôıôĲťώĺĲîώ[ĺČ ´ôŜ ͐ϱ͏͕͖͗͗͑͑ϱ͔ϯ͗Г ͐͏͕͓͖͓͕͐͒͗͐͘͘«ĺīŪıôťŘĖèϯ[Ėċť ´ôŜ Volumetric and lift calculations from data availabl e on the 7-5/8” primary cement job put the TOC at 7,741’ md (7,146’ ssTVD). In P1-08, the top of the Stump Island reservoir was encountered at 9,168' MD (8,238' TVDSS). SFD SECTION 11: LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFING ZONES (20 AAC 25.283, A, 11): Hilcorp’s technical analysis based on seismic, well and other subsurface information available indicates that there are twomapped faults that transect the Stump Island interval and enter the confining zone within the 1/2 mile radius of the production and confining zone trajectory for P1-13. Fracture gradients within the confining zone (top - Top Stump Island Shale and bottom - HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Faults 1 and 2 intersect the production interval and confining zone within the 1/2 mile radius of the planned frac. Their displacements, sense of throw, and zone in which they terminate upwards are given below. >ÍŪīť ēŘĺſ "ĖŘôèťĖĺĲ ĺŕώ¾ĺĲô ĺťťĺıώ¾ĺĲô ͐ϱ͐͒ώ"ĖŜťÍĲèôώťĺώ>ÍŪīť ͐͏ϱ͐͐͏ώċť "b ĺīīŽĖīīôώaŪîŜťĺĲôŜ ÍŜôıôĲť ͑Ϡ͔͕͒ώċť ͑͏ϱ͑͏͏ώċť "b èēŘÍîôŘώbϱÍĲîŜ ÍŜôıôĲť ͐Ϡ͑͒͗ώċť Plat of wells within one-half mile of P1-13 wellbore reservoir trajectory and location of faults. Black squares indicate Stump Island pool intersections. Faults 1 and 2 called out. Fault 2 Fault 1 Maximum stress direction is estimated to be North – South plus or minus 15 degrees based on breakout observations from the P1-02 FMS log from 30-MAR-1988. The planned frac half-length of 258’ should not reach any of the mapped faults. Fault 2 is the closest to P1-13, at 1,238’ away. If a sudden drop in treating pressure or increase in pump rate is seen during the stimulation that cannot be explaining by fluids pumped or annular pressure monitoring, pumping operation will stop until a plan forward and explanation can be put forth. SECTION 12: PROPOSED HYDRAULIC FRACTURING PROGRAM (20 AAC 25.283, a, 12): Fracture Stimulation Pump Schedule Stage #Fluid Stage Volume Rate Prop. Conc. (ppa)Proppant Name Proppant (#) 1 20# Linear Load 6,300 10 2 20# Linear FET 8,700 25 3 Shutdown 4 20# Linear Pad 2,000 25 5 20# Linear Diverter/Scour 2,000 25 0.5 100 mesh 1,000 6 20# Linear Diverter/Scour 1,400 25 0.75 100 mesh 1,050 7 20# Linear Diverter/Scour 1,000 25 1.0 100 mesh 1,000 8 20# Linear Over Flush 8,400 25 9 Shutdown 10 30# X-Link Pad 9,000 25 11 30# X-Link 1 PPA 10,000 25 1.0 20/40 CarboLite 10,000 12 30# X-Link 2 PPA 10,000 25 2.0 20/40 CarboLite 20,000 13 30# X-Link 3 PPA 10,000 25 3.0 20/40 CarboLite 30,000 14 30# X-Link 4 PPA 10,000 25 4.0 20/40 CarboLite 40,000 15 30# X-Link 5 PPA 10,000 25 5.0 20/40 CarboLite 50,000 16 30# X-Link 6 PPA 10,000 25 6.0 20/40 CarboLite 60,000 17 20# Linear Flush 8,400 Estimated cumulative fluid volume: 107,000 gal (2,548 bbl) Estimated total proppant: 210,000 # Table 5– Anticipated Pressures MIT-T 3000 psi MIT-IA 3000 psi Maximum Anticipated Treating Pressure:4020 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):2850 psi IA Minimum Hold Pressure (POP-off – 300 psi):2550 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T/1.1):5275 psi w/ 2550 psi on IA Stagger Pump Kickouts Between90 – 95% of MATP:4750 psi Global Kickout (95% of MATP):5010 psi N2 POP-off set pressure (MATP):5275 psi Treating Line Test Pressure (MATP + 1000 psi):6275 psi OA Pressure:Monitor Max Anticipated Proppant Loading:6 PPA There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. Frac Modelling: Maximum Anticipated Treating Pressure: ~4020 psi Surface pressure is calculated based on a conservative closure pressure of 0.70 psi/ ft or ~5,760 psi. Net pressure estimated to be built (600 psi). Total friction pressure estimated at1,300 psi between pipe friction and perforation friction. Hydrostatic pressure of the pad fluid is estimated at 3,640 psi (8.5ppg) to mid perf. 5760psi (closure)+ 600psi (net)+ 1300psi (friction) - 3640psi (hydrostatic) = 4020psi (max surface press) The difference in closure pressures of the confining shale layers determines height of the fracture. Average top confining layer stress is anticipated to be 0.71 psi/ ft and average bottom confining layer stress is anticipated to be 0.70 psi/ft. Fracture half-length is determined from confining layer stress as well as leak-off and formation modulus. The modeled frac is anticipated to reach a half-length of ~258 ft with a height of ~180 ft TVD. The Kuparuk interval below the Stump Island in P1-13 has a high gas-oil ratio making marginal production. This fracture stimulation was specifically designed to reduce the likelihood of inducing a fracture that will penetrate through the lower confining interval to avoid linking up to the high gas-oil ratio Kuparuk production. Disclaimer Notice: This model was generated using commercially available modelling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. 4020 psi Pre-Job Anticipated Chemicals to be pumped: SECTION 13: POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN (20 AAC 25.283, A, 13): After the fracture stimulation and potentially during the post frac coiled tubing fill cleanout, the well will be put on production through a portable well test unit. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if proppant production is above the acceptable threshold. The initial flowback period is intended to produce back the treating fluid volume to tanks as quickly as possible. When production is less than 20% water cut and less than 0.5% solids the flowback will be routed to the LPC production facility. There will be a flowback tank farm on pad to store any produced fluids from flowback operations that do not meet the LPC facility specifications mentioned above. The fluids and proppant not suitable for LPC processing will be hauled to GNI for disposal. Hilcorp will work to separate and recover fluid that meets the facility specification for the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. 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:Eric Dickerman To:Davies, Stephen F (OGC) Cc:Rixse, Melvin G (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] PBU P1-13 (Permit 193-074, Sundry 324-611) - Question Date:Monday, October 28, 2024 10:04:56 AM Mr. Davies, Thank you for working on this sundry. Modeled top of induced fracture is 8,780’ MD / 8,231’ TVD / 8,183’ TVDss. Regards, Eric Dickerman Hilcorp – LPC OE Cell: 307-250-4013 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, October 28, 2024 8:28 AM To: Eric Dickerman <eric.dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] PBU P1-13 (Permit 193-074, Sundry 324-611) - Question Erik, I’m reviewing Hilcorp’s Sundry Application to fracture PBU P1-13. Please provide the MD and TVD for the top of the modeled induced fractures in P1-13 as required by 20 AAC 25.283(a)(12)(F). Regards, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov 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. 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 October 28, 2024 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. SFD 10/27/2024 (a)(2) Plat Provided with application. SFD 10/27/2024 (a)(2)(A) Well location Provided with application. Well lies in Sections 16 and 15 of T12N, R14E, UM. SFD 10/27/2024 (a)(2)(B) Each water well within ½ mile None: According to the Water Estate map available through DNR’s Alaska Mapper application (accessed online October 24, 2024), there are no wells are used for drinking water purposes are known to lie within ½ mile of the surface location of P1-13. There are no subsurface water rights or temporary subsurface water rights within 11-1/2 miles of the surface location of P1-13. SFD 10/27/2024 (a)(2)(C) Identify all well types within ½ mile List of wells provided with application. SFD 10/27/2024 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth None. Absence of freshwater aquifers is supported by AIO 4A Finding 17 (salinity of 12,000 to 20,000 ppm for all aquifers in the Pt. McIntyre oil field) and AIO 4A Conclusion 10 (no USDWs are known to exist in the PBU Eastern Operating Area and Pt. McIntyre oil field). The Affected Area of AIO 4A includes P1-13. A review of nearby well Pt. McIntyre 3 (PTD 188-005), which is the closest well with shallow porosity data that lies within ½ mile of P1-13, shows all sands between the base of permafrost and surface casing shoe are very low in resistivity, clearly indicating brackish formation water. AOGCC’s quick-look analysis using Pickett Plots demonstrates that these sands all contain formation waters that exceed 10,000 mg/l TDS. SFD 10/28/2024 (a)(4) Baseline water sampling plan None required. SFD 10/27/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 October 28, 2024 (a)(5) Casing and cementing information Provided with application. CDW 10/28/2024 (a)(6) Casing and cementing operation assessment 10-3/4” surface casing cemented to surface and a top job performed. 7-5/8” intermediate casing cemented with cement calculations indicating TOC of 6649 ft or conservatively TOC of 8193 ft. CBL (4/8/2024) indicates good cement from 8704 ft (tubing tail). 4.5” tubing and liner run un-cemented. CDW 10/28/2024 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 No freshwater aquifers present. (See Section (a)(3), above.) SFD 10/27/2024 (a)(6)( B) Each hydrocarbon zone is isolated Yes: Surface casing was set at 3,560’ MD (-3,510’ TVDSS) and cemented. A 235-sack top job was performed. For P1-13, 9-7/8” hole was drilled to 10,275’ MD (-8,696’ TVDSS). The top of the Stump Island reservoir was encountered at 8,797’ MD (-8,194’ TVDSS), and the top of Kuparuk reservoir was encountered at 9,170’ M (-8,437’ TVDSS). Intermediate casing (7/5/8”) was set at 10,275’ MD and cemented with 163.2 barrels of 15.8 ppg cement. CBL indicates very good-quality cement across the top of the Kuparuk reservoir, across the Stump Island reservoir, and continuing upward to at least 8,704’ MD (-8,122’ TVDSS), which is the top of the bond log. So, cement isolates each hydrocarbon zone. SFD 10/27/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 October 28, 2024 (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 3000 psi MITIA planned, 3036 psi MITT (4/25/2024). CDW 10/28/2024 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 5K psi wellhead while frac will have a 10K psi tree saver installed. Max. frac. pressure est. 4020 psi. Pump knock out 4750-5010 psi and GORV 5275 psi., lines test 6275 psi. CDW 10/28/2024 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zones: Colville mudstones, shales, and siltstones that have an aggregate thickness of about 1,200’ true vertical thickness (TVT) underlain by the Stump Island siltstone and shale that is 32’ TVT. Fracture gradients are about 0.70 to 0.71 psi/ft (about 13.5 ppg EMW). Fracturing Zone: Stump Island consisting of very fine- grained sandstone and siltstone is cemented. Fracture gradient expected to range from about 0.66 psi/ft (12.7 ppg EMW). Lower confining zones: HRZ Shale with an aggregate TVT of about 60’. Fracture gradient expected to range from about 0.70 psi/ft (13.5 ppg EMW). SFD 10/27/2024 (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory It is highly unlikely that any of the wells and wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance. Three wells transect the confining zones within the AOR (P1-08, P1-02, and P1-G1). All display cement isolation of the Stump interval. None of these wells will interfere with containment of the frac fluids. SFD 10/27/2024 CDW 10/28/2024 (a)(11) Faults and fractures, Sufficient information to determine no interference with containment of the hydraulic Two faults, interference is highly unlikely: The operator has identified two faults using seismic and well data within a ½-mile radius of P1-13. These faults do not intersect P1-13. They lie 1,200’ and 2,500’ from the proposed fracturing interval, and the modeled half-length of the induced SFD 10/27/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 October 28, 2024 fracturing fluid within ½ mile of the proposed wellbore trajectory fractures is 258’. So, it is unlikely that this fault will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. (a)(12) Proposed program for fracturing operation Provided with application. CDW 10/28/2024 (a)(12)(A) Estimated volume Provided with application. 2548 bbl total dirty vol. 210K lb total proppant CDW 10/28/2024 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 10/28/2024 (a)(12)(C) Chemical name and CAS number of each Provided with application. Halliburton disclosure provided. Proprietary chemicals on file at AOGCC. CDW 10/28/2024 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 10/28/2024 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max surface pressure 4020 psi. Max. 5275 psi (with 2550 psi backpressure) allowable treating pressure. Max pressure is 4750-5010 psi to Pump shutdown with 5275 psi N2 popoff. With 2550 psi back pressure IA (IA popoff set 2850 psi), max tubing differential should be 2725 psi. (5275 psi-2550) CDW 10/28/2024 (a)(12)(F) Fractures – height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-length of the induced fractures is 258’ according to the Operator’s computer simulation. Computer simulation indicates the anticipated height of the induced fractures will be 180’, and the modeled top of induced fracture is 8,780’ MD (8,231’ TVD, -8,183’ TVDSS). So, the induced fractures may penetrate a short distance into the overlying confining Colville confining layer that is about 1,300’ thick in this area. SFD 10/28/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 October 28, 2024 They may also penetrate a short distance into, but will not penetrate through, the underlying, dense, 60-foot thick HRZ shale that provides lower confinement. (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. GNI disposal identified CDW 10/28/2024 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 2550 psi back pressure, plan to test to 3000 psi, popoff set as 2850 psi CDW 10/28/2024 (c) Fracturing string (c)(1) Packer >100’ below TOC of production or intermediate casing 4.5” tubing is anchored to the 7-5/8” casing with a packer at 8617 ft and cement squeeze (08/20/2015) 4567 ft. 7-5/8” intermediate casing cemented with cement calculations indicating TOC of 6649 ft or conservatively TOC of 8193 ft. CBL (4/8/2024) indicates good cement from 8704 ft (tubing tail). 4.5” tubing packer > 100’ below TOC of intermediate casing. CDW 10/28/2024 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 3000 psi. Max pressure differential is estimated as 2725 psi (5275 with 2550 psi backpressure) so test of 3000 psi satisfies 110% CDW 10/28/2024 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 6275 psi line pressure test, pump knock out 4750-5010 psi with max. global kickout 5275 psi. IA PRV set as 2850 psi. CDW 10/28/2024 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 10/28/2024 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 2850 psi. Surface annulus open. Frac pressures continuously monitored. CDW 10/28/2024 (g) Annulus pressure 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time CDW 10/28/2024 20 AAC 25.283 Hydraulic Fracturing Application – Checklist PBU P1-13 (PTD No. 193-074; Sundry No. 324-611) Paragraph Sub-Paragraph Section Complete? AOGCC Page 6 October 28, 2024 monitoring & notification during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report(i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac watersampling planNot required (see Section (a)(3), above). SFD 10/27/2024 (k) ConfidentialinformationClearly marked and specific facts supporting nondisclosure Non-confidential well. SFD 10/27/2024 (l) VariancesrequestedModifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. Nolan 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: 7/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240730 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 5/22/2024 YELLOW JACKET PERF BCU 14B 50133205390200 222057 6/11/2024 YELLOW JACKET GPT-PLUG-PERF BCU 19RD 50133205790100 219188 7/17/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/1/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 7/11/2024 AK E-LINE PressureTemp CLU 16 50133207200000 224021 5/16/2024 YELLOW JACKET SCBL CLU 16 50133207200000 224021 5/31/2024 YELLOW JACKET SCBL END 2-14 50029216390000 186149 5/9/2024 YELLOW JACKET PLUG KU 33-08 50133207180000 224008 5/9/2024 YELLOW JACKET GPT-PLUG-PERF MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey MPU I-40 50029236890000 220071 7/6/2024 AK E-LINE TubingCut MPU R-101 50029237930000 224078 7/16/2024 YELLOW JACKET SCBL MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey PBU NK-43 50029229980000 201001 6/11/2024 YELLOW JACKET PL PBU PTM P1-13 50029223720000 193074 7/4/2024 YELLOW JACKET PL Pearl 11 50133207120000 223032 7/10/2024 AK E-LINE Plug/Perf Please include current contact information if different from above. T39310 T39310T T39311T T39312T T39312 T39313 T39313 T39314 T39315 T39316 T39317 T39318 T39319 T39319 T39320 T39321 T39322 YELLOW PBU PTM P1-13 50029223720000 193074 7/4/2024 JACKET PL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.30 13:09:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-13 PRUDHOE BAY UN PTM P1-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2024 P1-13 50-029-22372-00-00 193-074-0 N SPT 8100 1930740 2200 564 2510 2365 2301 0 0 0 0 OTHER P Guy Cook 5/9/2024 MIT-T to 3000 psi per Sundry 324-169. Mel Rixse gave permission to test to 2200 psi. instead of 3000. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-13 Inspection Date: Tubing OA Packer Depth 1111 1214 1220 1218IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240508183027 BBL Pumped:2 BBL Returned:2 Friday, June 14, 2024 Page 1 of 1           1-Oil producer Nolan 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: 5/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240501 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 3/27/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 4/1/2024 YELLOW JACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/22/2024 YELLOW JACKET GPT-PERF KU 33-08 50133207180000 224008 4/30/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP MPU F-30A 50029226230100 213188 4/12/2024 READ CaliperSurvey MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey NCI A-17 50883201880000 223031 3/22/2024 AK E-LINE Perf Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL SRU 232-15 50133207140000 223091 3/28/2024 YELLOW JACKET GPT-PLUG-PERF SRU 232-15 50133207140000 223091 4/22/2024 YELLOW JACKET PLUG-PERF SRU 241-33B 50133206960000 221053 4/12/2024 YELLOW JACKET GPT-PERF SRU 241-33B 50133206960000 221053 4/4/2024 YELLOW JACKET GPT-PERF Please include current contact information if different from above. T38745 T38746 T38746 T38746 T38747 T38748 T38748 T38749 T38750 T38751 T38752 T38753 T38754 T38754 T38755 T38755 PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:32:35 -08'00' 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:Eric Dickerman Cc:DOA AOGCC Prudhoe Bay Subject:20240506 1653 APPROVAL PTD 193074 - Sundry 324-169 - P1-13 Pressure test cement plug Date:Monday, May 6, 2024 4:55:23 PM Eric, Regarding a lower test pressure for the reservoir abandonment plug: Per 20 AAC 25.112. Well plugging requirements (g) (2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing Hilcorp is approved to pressure test the reservoir abandonment P&A plug to 0.25 psi/ft * TVD of the Pt. McIntyre Oil Pool at 8484’ TVD or ~2200 psi. 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). AOGCC Inspectors From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Monday, May 6, 2024 4:18 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 193074 - Sundry 324-169 - P1-13 Pressure test cement plug Mel, As discussed on the phone, we have pumped the cement plug on P1-13 for reservoir P&A of the Pt. McIntyre pool. The top of cement was tagged at 9,072’ with AOGCC witness, however we were not able to get a passing MIT-T to 3,000 psi with AOGCC witness. We have confirmed tubing integrity with a plug set in the tubing tail and a passing MIT-T. After pulling the tubing tail plug, we were able to perform three passing MIT-Ts to 2,500 psi against the reservoir P&A cement plug. The TVD of the top of the Pt. McIntyre Pool (being abandoned) is 8,484’ TVD. Using 0.25psi/ft x TVD regulation would put a passing test at 2,121 psi. We are requesting approval to proceed by retesting the MIT-T with a passing test above 2,121 psi with AOGCC witness. The original sundry is attached for reference. Thank you, Eric Dickerman Hilcorp – LPC OE Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:16 Township:12N Range:14E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:11010 ft MD Lease No.:ADL 028297 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:10-3/4"O.D. Shoe@ 3560 Feet Csg Cut@ Feet Intermediate:7-5/8"O.D. Shoe@ 10275 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:4-1/2"O.D. Shoe@ 11010 Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 8695 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Bridge plug 9165 ft 9072 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 3360 3232 3149 IA 1044 1135 1127 OA 3 2 1 Initial 15 min 30 min 45 min Result Tubing 3338 3244 3168 3100 IA 1137 1130 1125 1119 OA 2 3 4 4 Remarks: Attachments: I traveled to location to witness the mechanical integrity test (MIT) of the cement plug that was laid 4/19/2024 inside the 7-5/8" casing. This was to abandon the Pt McIntyre pool and perforate the Pt. McIntyre Stump Island pool. A slickline tag and failing state witnessed tubing MIT was done 4/24/2024. We made two attempts to get a passing pressure test with no signs of stabilzation. No tag done during this inspection. Above plugging data reflects when previous Inspector was on location. April 26, 2024 Austin McLeod Well Bore Plug & Abandonment PBU P1-13 Hilcorp North Slope LLC PTD 1930740; Sundry 324-169 none Test Data: F Casing Removal: Jerry Culpepper F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0426_Plug_Verification_PBU_P1-13_am             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:16 Township:12N Range:14E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:11010 ft MD Lease No.:ADL 028297 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:10-3/4"O.D. Shoe@ 3560 Feet Csg Cut@ Feet Intermediate:7-5/8"O.D. Shoe@ 10275 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:4-1/2"O.D. Shoe@ 11010 Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 8695 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Bridge plug 9165 ft 9072 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 3248 2990 IA 945 947 OA 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jerry Culpepper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): The well plan is to plug back the PBU Pt. McIntyre pool and begin devolepment of the Stump Island pool. This tag and test represents the P&A of the Pt McIntyre pool. Solid wireline tag of cement top at 9072 ft MD. Tubing MIT failed @ 22 minutes - pressure declined to 2924 psi, exceeding 10% pressure loss. April 24, 2024 Sully Sullivan Well Bore Plug & Abandonment PBU P1-13 Hilcorp North Slope LLC PTD 1930740; Sundry 324-169 Well Schematic Test Data: F Casing Removal: rev. 3-24-2022 2024-0424_Plug_Verification_PBU_P1-13_ss             PBU P1-13 (PTD 1930740) Wellbore Schematic 4/24/2024 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 P1-13 Recomplete to New Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 ADL 0034624 11010 Conductor Surface Intermediate Production Liner 8745 74 3521 10275 888 9373 20" 10-3/4" 7-5/8" 4-1/2" 8592 38 - 112 37 - 3560 35 - 10275 10122 - 11010 2860 38 - 112 37 - 3558 35 - 8744 8746 - 8745 9676 520 2480 5120 7500 9373 , 9380 , 10150 2300 5210 8180 8430 9170 - 10987 4-1/2" 12.6# L-80 33 - 86958486 - 8744 Structural 4-1/2" TIW HBBP, 8617 , 8098 4-1/2" Camco TRCF-4A 2238 2238 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY 3-27-24 Current Pools: PT MCINTYRE OIL Proposed Pools: PT M STUMP IS 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 By Grace Christianson at 1:21 pm, Mar 18, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.18 12:40:57 - 08'00' Bo York (1248) Slickline tag TOC ~ 9078' MD. MIT-T to 3000 psi. DSR-3/21/24SFD 3/19/2024 Perforate New Pool MGR22MAR24 10-404 ADL 028297 SFD PT M STUMP IS OIL JLC 3/22/2024 P1-13 : Perforate Stump Island Sandstone Page 1 of 7 Well Name:P1-13 API Number:50-029-22372-00 Current Status:Operable, Shut in Permit to Drill Number:193074 Estimated Start Date:April 2024 Rig:CT/EL/SL Regulatory Contact:Carrie Janowski Estimated Duration:7 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Brief Well Summary: P1-13 was drilled in June 1993 in the Gravity Drainage fault block at Pt. Mac. The well was a mostly steady producer until going Not Operable in 2013 for a production casing leak. An IA cement job in August 2015 restored well integrity and the well was made Operable. Post repair the well has been high GOR and has not been competitive. Kuparuk LC1 and UC1 perforations were added in Q4 2023 but were high GOR. P1-13 was originally completed with intention to produce from the Stump Island Sandstone after the Pt McIntyre Kuparuk reservoir became uncompetitive. The 7-5/8 casing cement program targeted a top of cement 500 above the top of the Stump Island Sandstone or 1,000 above the top of Kuparuk. The 7-5/8 casing was run to bottom and tagged TD at 10,275. The casing was cemented with 163.2 bbl of 15.8ppg cement, no losses reported, and the top plug bumped at 472 bbl (reported 4,682 strokes at 0.1008bbl/stroke) versus a calculated volume to float collar of 468 bbl. Accounting for the shoe track and zero rathole puts 159.5 bbl of cement in the annulus (897 cu ft or 159.8bbl reported on the 10-407). A CBL was not ran on the 7-5/8, however top of cement calculations indicate the Stump Island Sandstone has cement coverage. A 1.3 excess factor (1.3 times the openhole x casing capacity) places the cement top behind the 7-5/8 casing at 7,066 md. Using an additionally conservative 2.0 excess factor (2 times the openhole x casing capacity) puts the calculated top of cement at 8,193 md. Current pick of top of Stump Island Sandstone is 8,797 md. Objective: Uphole recomplete. Abandon Pt McIntyre pool with cement plug. Perforate Pt McIntyre Stump Island pool. P1-13 : Perforate Stump Island Sandstone Page 2 of 7 Current Bottom Hole Pressure (Pt Mac pool):3,574 psi at 8,600 TVDss Expected Bottom Hole Pressure (Stump Island pool): 3,650 psi at 8,200 TVDss Max. Anticipated Surface Pressure:2,860 psi (0.1 psi/ft gas grad. from 8200 TVDss) Min. ID:3.725 at 8,671md (SWN Nipple) Max. Deviation:92.1deg at 10,265md H2S Concentration:100 PPM 4/10/2018 Well Completion Information: Wellhead: FMC, 13-5/8, 5M Tree: FMC, 4-1/16, 5M SSSV: Camco, 4-1/2, TRCF GLM: Merla, TMPDX Production Pkr: TIW, 7-5/8 x 4-1/2 HBBP LTP: TIW, 7-5/8 x 4-1/2 SS Existing Casing/Tubing Program: String Pipe #/ft Grade Connection Top Bottom Cap. (bbl/ft) Surface csg. 10-3/4 45.5 L-80 BTC Surface 3,558 0.0962 Prod. Csg. 7-5/8 29.7 NT95HS NSCC Surface 10,275 0.0459 Tbg. 4-1/2 12.6 L-80 TDS Surface 8,696 0.0152 Prod. Lnr. 4-1/2 12.6 L-80 TDS 10,122 11,008 0.0152 7-5/8 Casing Cement Calculations: A 7-5/8 Casing capacity = 0.0459bbl/ft B 9-7/8" Open hole x 7-5/8" casing capacity = 0.0383bbl/ft C Float shoe depth = 10,275ft md D Float collar depth = 10,194ft md E Cement Volume pumped = 163.2bbl F = A x (C D)Shoe track Volume = 3.7bbl G Rathole Volume = 0.0bbl H = E F G Volume cement in Open hole x Csg. annulus = 159.5bbl I = B x 1.3 1.3 excess factor - 9-7/8" Open hole x 7-5/8" casing capacity = 0.0497bbl/ft J = H / I Cement column height in annulus (1.3 E.F.) = 3,209ft K = C J Top of cement in annulus (1.3 E.F.) = 7,066ft L = B x 2.0 2.0 excess factor - 9-7/8" Open hole x 7-5/8" casing capacity = 0.0766bbl/ft M = H / L Cement column height in annulus (2.0 E.F.) = 2,082ft N = C M Top of cement in annulus (2.0 E.F.) = 8,193ft md H2S Concentration 100 PPM P1-13 : Perforate Stump Island Sandstone Page 3 of 7 Wellwork Procedure: Slickline: 1. Drift for eline. Eline: 2. Set IBP at 9,165. a. Plug must be within 50 of the top existing perforation. Coiled Tubing: 3. Drift/log with GR/CCL to determine correction for target TOC. 4. Lay in 4 bbl (87) of 15.8 ppg Class G cement on top of retainer. a. Must have at least 75 of cement on top of bridge plug, which would be 9,090. b. 4 bbl of cement will put top of cement at 9,078. 5. Leave wellbore full of diesel before RDMO. Slickline: 6. Tag TOC with AOGCC witness. a. Provide at least 24hr notice for witness. 7. MIT-T to 3,000 psi to test cement plug with AOGCC witness. a. Provide at least 24hr notice for witness. 8. Set kickoff gas lift design. Eline: 9. Add Stump Island perforations from 8,801 to 9,063 with 2-3/4 perforating guns. Attachments: - Current Wellbore Schematic - Proposed Wellbore Schematic - Reference log of target interval - Sundry change form P1-13 : Perforate Stump Island Sandstone Page 4 of 6 Current Wellbore Schematic: P1-13 : Perforate Stump Island Sandstone Page 5 of 6 Proposed Wellbore Schematic: P1-13 : Perforate Stump Island Sandstone Page 6 of 6 Reference log of target interval: P1-13 : Perforate Stump Island Sandstone Page 7 of 7 Sundry change form 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 Nolan 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: 3/14/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240314 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL BRU 221-35 50283201930000 223077 11/18/2023 AK E-LINE Perf HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL IRU 41-01 50283200880000 192109 11/16/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 1/16/2024 AK E-LINE GPT/Perf KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF KU 3-06A 50133207160000 223112 1/12/2024 AK E-LINE CBL KU 21X-32 50133202040000 169100 12/8/2023 AK E-LINE JetCut MPU CFP-02 50029212580000 184242 3/9/2024 READ CaliperSurvey NCI A-18 50883201890000 223033 12/8/2023 AK E-LINE Perf/GPT NIA NK-18 50029224210000 193177 12/13/2023 AK E-LINE IPROF PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf TBU M-15 50733204220000 190109 2/7/2024 AK E-LINE GPT/Perf Please include current contact information if different from above. T38615 T38615 T38616 T38617 T38618 T38619 T38620 T38621 T38622 T38623 T38624 T38625 T38626 T38627 T38628 PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -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 P1-13 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-074 50-029-22372-00-00 11010 Conductor Surface Intermediate Production Liner 8745 74 3521 10275 888 9373 20" 10-3/4" 7-5/8" 4-1/2" 8592 38 - 112 37 - 3560 35 - 10275 10122 - 11010 38 - 112 37 - 3558 35 - 8744 8746 - 8745 9676 520 2480 5120 7500 9373 , 9380 , 9400 , 10150 2300 5210 8180 8430 9170 - 10987 4-1/2" 12.6# L-80 33 - 8695 8486 - 8744 Structural 4-1/2" TIW HBBP , 8617 , 8098 4-1/2" Camco TRCF-4A, 2238 , 2236 8617 8098 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 0034624 34 - 8163 0 0 30382 31176 0 0 1 0 2606 2427 N/A 13b. Pools active after work:PT MCINTYRE OIL 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 Samantha Coldiron at 9:09 am, Mar 08, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.07 10:08:00 - 09'00' Bo York (1248) RBDMS JSB 031324 DSR-3/11/24WCB 2024-06-25 ACTIVITYDATE SUMMARY 8/19/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-4000HP(good) UNABLE TO TRACTOR FROM DEVIATION AT 9570' MD INTO LINER ENTRY GUIDE AT 10122' MD. ATTEMPTED FOR 30 MINS WITH ALTUS AND 212 TRACTORS. LOADED WELL WITH 200 BBLS OF CRUDE, PUMPED PLUG INTO LINER WHILE TRACTORING AT 3.5 BPM. SET 3.50" CIBP AT 10150' MD, CCL TO ME=11.2', CCL STOP DEPTH=11.2'. ***CONTINUED ON 8-20-2023 WSR*** 8/19/2023 T/I/O=2700/200/0 Assist Eline With pump down, Pumped 261 BBLS crude to Pump Eline down, Pumped 1 BBLS crude tov pressure up Plug. FWHP=1000/250/0 8/20/2023 ***CONTINUED FROM 8-19-2023 WSR*** PT PCE 250LP-3000HP PERFORATE FROM 9615- 9640' MD WITH 15 GRAM, 6 SPF, 60 DEG PHASED GEO RAZOR XDP CHARGES. CCL STOP DEPTH=10138.8' MD, CCL TO TS=9.3, LOG CORRELATED TO BAKER MWD LOG DATED: 02-JUNE-93. ***WELL LEFT S/I, PAD OP NOTIFIED*** 9/15/2023 ***WELL S/I UPON ARRIVAL*** SPINNER/PRESSURE/TEMPERATURE/IBP MIRU HES MIRU T-BIRD PRESSURE TEST LOW 300PSI HIGH 3500PSI T-BIRD LOAD WELL T-BIRD PUMP BETWEEN 0.1 AND 0.3 BBL/M MAX PRESSURE 2500PSI STATION STOP AT 9550 UP/DOWN 100 FPM 9550 TO 9650 UP/DOWN 120 FPM 9550 TO 9650 STAION STOP AT 9650 NO FLOW DETECTED BELOW 9640' ***CONTINUED ON 16-SEP-2023 WSR*** 9/15/2023 T/I/O=2700/200/0 (Assist Eline) TFS U-3, Loaded TBG with 190 BBLS of crude. Pumped 5 BBLS of crude while EL ran logs.See log for details. ***Job continued on 9/16/23*** 9/16/2023 ***CONTINUED FROM 15-SEP-2023*** SPINNER/PRESSURE/TEMPERATURE/IBP POOH WITH SPINNER TOOL STRING, NO FLOW OBSERVED BELOW PERFORATIONS SET 3.375" BAKER IBP ME AT 9390' RDMO HES ***WELL S/I UPON DEPARTURE*** 9/16/2023 ***Job Continued from 9-15-23*** (Assist EL) TFS U-3, Rigged down Final WHPS=600/250/0 Daily Report of Well Operations PBU P1-13 PERFORATE FROM 9615- 9640' MD SET 3.375" BAKER IBP ME AT 9390' SET 3.50" CIBP AT 10150' MD NO FLOW DETECTED BELOW 9640' Daily Report of Well Operations PBU P1-13 9/27/2023 ***WELL S/I ON ARRIVAL*** (5 x) RAN 3.5'' DUMP BAILER TO TOP OF CIBP @ 9390' MD (~15 gal sand dumped) ***WSR CONT ON 9-28-23*** 9/28/2023 ***WSR CONT FROM 9-27-23*** (2x) RAN 3.5'' DUMP BAILER TO TOP OF CIBP @ 9390' MD (~5gals) (total overall ~20gal sand S100l) ***JOB COMPLETE, WELL LEFT S/I*** 9/29/2023 T/IA/OA= Spot unit, RU,PT JOB CONTINUES ON 09/30/23 9/30/2023 JOB CONTINUES FROM 09-29-23, PT IBP to 1000PSI, Pumped 12 BBLS Crude FWHP=540/200/0, S/W/SSV/M/IA/OA=C/C/C/O/OTG/OTG 10/10/2023 ***WELL SHUT IN UPON ARRIVAL*** OBJECTIVE: ADD PERF'S FROM 9170'-9214' W/2 7/8'' GEO RAZOR XDP MIRU YELLOW JACKET E-LINE. PT PCE 250 PSI LOW./3500 PSI HIGH RIH W/CH/2.75'' GUN GAMMA/25' OF 2 7/8'' GEO RAZOR GUN AND PERFORATE INTERVAL 9189'-9214' CCL TO TOP SHOT=8.2' CCL STOP DEPTH=9180.8' LAY DOWN FOR THE NIGHT ***CONTINUE JOB ON 10/11/23*** 10/11/2023 ***CONTINUED JOB FROM 10/10/23*** OBJECTIVE: PERFORATE INTERVAL W/2 7/8'' GEO RAZOR GUN PT PCE 300 PSI LOW./3500 PSI HIGH RIH W/CH/2.75'' GUN GAMMA/19' OF 2 7/8'' GEO RAZOR 6 spf 60 DEG PHASE TO PERFORATE INTERVAL 9170'-9189', CCL TO TOP SHOT=14.3' CCL STOP DEPTH=9155.7' , GUN GAMMA RAY-CCL CORRELATED TO AK ELINE PLUG AND PERFS DATED 19-AUG-2023 10/24/2023 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(pprof) PT 300L/3000H RIH W/ PPROF TS(CH/WB/WB/WB/TLEMETRY/GR/QPC/PRC/ILS/PRC/HCTF/CFS) OAL: 37.18', TW: 324#, MAX OD: 1.69". PERFORM S/I TEMPERATURE BASELINE FROM 9100' TO 9350' AND BRING WELL ONLINE TO TEST SEPARATOR AND MAKE DYNAMIC PASSES FROM 9100' TO 9250' AT 30/60/90 FPM STATION STOPS AT 9350',9240',9200',9180',9160, OBSERVED 10% OF PRODUCTION COMING FROM THE UPPER PERF INTERVAL(9170'-9214'). 3 3/8'' IBP AT 9390' IS LEAKING. SPINNER RESPOND BELOW PERFS AT 9350' FTP:2575 psi PSI FTT:83 DEG F BOPD:3 GR: 25.5 MMSCF 11/3/2023 T/I/O = 2750/240/0. Temp = SI. T FL (OE). AL disconnected. T FL @ 8670' (500' above perfs). 11/14/2023 ***WELL S/I ON ARRIVAL***(perforating) DRIFTED TBG/LINER W/ 3.50" CENT, TEL & 3.00" SAMPLE BAILER.(no sample) LOCATED TBG TAIL @ 8705' SLM/ 8704' ELMD, TOOLS DEVIATED OUT @ 9564' SLM.(ibp blown down in deviation) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** PERFORM S/I TEMPERATURE BASELINE FROM 9100' TO 9350' AND BRING WELL ONLINE TO TEST SEPARATOR AND MAKE DYNAMIC PASSES FROM 9100' TO 9250' AT 30/60/90 FPM STATION STOPS AT 9350',9240',9200',9180',9160, OBSERVED 10% OF PRODUCTION COMING FROM THE UPPER PERF INTERVAL(9170'-9214').() 3 3/8'' IBP AT 9390' IS LEAKING. SPINNER RESPOND BELOW PERFS AT 9350' RAN 3.5'' DUMP BAILER TO TOP OF CIBP @ 9390' MD (~15 gal sand dumped) IBP RIH W /CH/2.75'' GUN GAMMA/25' OF 2 7/8'' GEO RAZOR GUN AND PERFORATE INTERVAL 9189'-9214' PERFORATE INTERVAL 9170'-9189', IBP RAN 3.5'' DUMP BAILER TO TOP OF CIBP @ 9390' MD (~5gals) (total overall() ~20gal sand S100l) Daily Report of Well Operations PBU P1-13 12/2/2023 MO/RU SSSV OPENED AND LOCKED OUT WITH @ 4500#'s PLUG BROKEN - UNABLE TO CONTINUE RIG DOWN MOVE OFF - JOB POSTPONED ***WELL SHUT IN ON DEPARTURE*** 12/8/2023 T/I/O=2550/250/0 Load Tbg ( Pre-Eline ) Pump 3 bbls 60/40, 160 bbls Seawater, 2 bbls 60/40, & 38 bbls crude. Freeze protect flowline with 6 bbls 60/40 FWHPs=1400/500/0 12/9/2023 ***WELL S/I ON ARRIVAL*** DHD SHOOTS FLUID LEVEL AT 1512' SET 7-5/8" NEO T-TBP AT 9400' MD(basket depth) CCL STOP DEPTH=9386.8' MD, CCL TO BTM=14.2' MD. T-TBP EJT DEPTH=9401' MD. LOG TIED INTO AKES PLUG AND PERF RECORD DATED:19-AUG-2023 DUMPED 2 GALLONS OF BEADS AND 4 GALLONS OF CASING CLEANER IN T- TBP BASKET AT 9400' MD. DUMPED 5 GALLONS OF 17 PPG NEO CEMENT SLURRY ON BEADS IN NEO BASKET AT 9400' MD. ***LAY DOWN FOR THE NIGHT, CONTINUED ON 12-10-2023 WSR*** 12/9/2023 T/I/O = 1100/220/+0. Temp = SI. T FL (E-line request). AL disconnected. T FL @ 1500'. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 12/10/2023 ***CONTINUED FROM 12-9-2023 WSR*** PT PCE 250LP-3000HP TAGGED NEO T-TBP BAILER STOPS/BEADS & 5 GALLONS OF CEMENT LIGHTLY AT 9398' MD WITH 2.50" BAILER. DUMP BAIL 20 GALLONS OF 17 PPG NEO CEMENT WITH 4 RUN OF 2.50" X 30' DUMP BAILER. ESTIMATED TOC=9387' MD. ***CONTINUED ON 12-11-2023 WSR*** 12/11/2023 1850'. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 12/11/2023 ***CONTINUED FROM 12-10-2023 WSR*** DHD SHOOTS FLUID LEVEL AT 1850' MD PT PCE 250LP-3000HP TAG HARD BTM AT 9393' MD WITH 2.50" DUMP BAILER. MADE 4 DUMP BAILER RUNS AND DUMPED 20 GALLONS OF 17 PPG NEO CEMENT MIXED FOR 170 degF BOTTOM HOLE. TAG BTM AT 9376' MD WITH 2.50" X 30' BAILER, DUMPED 5 GALLONS OF NEO CEMENT AT 9373' MD. ESTIMATED TOC=9373.4' MD. TOTAL OF 50 GALLONS OF 17 PPG CEMENT AND 2 GALLONS OF BEADS IN NEO BASKET AT 9400' MD. ***DO NOT FLOW UNTIL 14-DEC-2023 @ 7 PM*** 12/16/2023 POP'D PUT INTO TEST 12/21/2023 WELL SI FOR HIGH UNCOMPETITIVE GOR 1/9/2024 ***WELL S/I ON ARRIVAL*** (PPROF) RAN 1.90" CENT & 30' x 1.75" BAILER TO 8,683' SLM (unable to get further, bailer empty) RAN 2.50" CENT BARBELL & 3" LIB TO 8,683' SLM (impressions of cement chunks) ESTIMATED TOC=9373.4' MD. TOTAL OF 50 GALLONS OF 17 PPG CEMENT AND 2 GALLONS OF BEADS IN NEO BASKET AT 9400' MD DUMPED 5 GALLONS OF 17 PPG NEO CEMENT SLURRY ON BEADS IN NEO BASKET AT 9400' MD. SET 7-5/8" NEO T-TBP AT 9400' MD(basket depth) TAGGED NEO T-TBP BAILER STOPS/BEADS & 5 GALLONS OF CEMENT LIGHTLY AT 9398' MD WITH 2.50" BAILER. DUMP BAIL 20 GALLONS OF 17 PPG NEO CEMENT WITH 4 RUN OF 2.50" X 30' DUMP BAILER. ESTIMATED TOC=9387' MD g TAG BTM AT 9376' MD WITH 2.50" X 30' BAILER, DUMPED 5 GALLONS OF NEO CEMENT AT 9373' MD. Daily Report of Well Operations PBU P1-13 1/10/2024 ***CONTINUED FROM 1/9/24 WSR*** (PPROF) RAN 3.80" G. RING TO XN AT 8,658' SLM/ 8,671' MD RAN 3.25" STAR BIT TO 8,680' SLM RAN 10' x 3.50" PUMP BAILER TO 8,681' SLM (recovered ~1 gal of cement chunks) RAN 2.60" STAR BIT TO 8,683' SLM RAN 3.25" STAR BIT TO 8,680' SLM RAN 10' x 3.50" PUMP BAILER TO 8,682' SLM(recovered ~1 gal of cement chunks) RAN 2.60" STAR BIT TO 8,682' SLM RAN 10' x 3.50" PUMP BAILER TO 8,681' SLM (recovered ~1 gal of cement chunks/ slurry) RAN 2.60" STAR BIT TO 8,684' SLM 1/11/2024 ***CONTINUED FROM 1/10/24 WSR*** (PPROF) RAN 10' x 3.50" PUMP BAILER TO 8,684' SLM (recovered ~1 gal cement chunks) RAN 2.60" STAR BIT TO 8,685' SLM RAN 10' x 3.50" PUMP BAILER TO 8,684' SLM (recovered ~1.5 gal cement chunks) RAN 2" STAR BIT TO 8,689' SLM RAN 10' x 3.50" PUMP BAILER TO 9,053' SLM (recovered ~1.5 gal cement chunks) RAN 2" STAR BIT TO 9,140' SLM RAN 10' x 3.50" PUMP BAILER TO 9,140' SLM (recovered ~1 gal cement chunks) RAN 5' x 3.50" DRIVE DOWN BAILER TO 9,140' SLM (no recovery) RAN 2" START BIT TO 9,141' SLM RIG DOWN DUE TO INCOMING WEATHER ***WELL LEFT S/I ON DEPARTURE*** 1/15/2024 ***WELL S/I ON ARRIVAL*** (PPROF) RAN 10' x 3" PUMP BAILER TO 9,141' SLM (rec. 1/2 gallon of cement) RAN 2.60" STAR BIT TO 9,141' SLM MOVE CEMENT TO 9,321' SLM RAN 3.65" GAUGE RING TO 9,322' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 1/15/2024 OE CANCELLED PPROF SINCE PLUG FAILED. CONSIDERING OPTIONS FOR ANOTHER 7-5/8"PLUG TO ISOLATE BETWEEN KUPARUK INTERVALS AND 2/12/2024 OE UNABLE TO SOURCE REPLACEMENT PLUG. WRITING NEW PROGRAM FOR SUNDRY REQUEST TO MOVE UPHOLE AND RECOMPLETE Nolan 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: 11/30/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231130 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 11/13/2023 YELLOW JACKET GPT BCU 13 50133205250000 203138 10/5/2023 YELLOW JACKET PERF KBU 13-08 50133203040000 177029 10/16/2023 YELLOW JACKET CALIPER KU 12-17 50133205770000 208089 10/4/2023 YELLOW JACKET CALIPER/TEMP KU 24-7RD 50133203520100 205099 10/4/2023 YELLOW JACKET CALIPER MPU B-32 50029235700000 216151 9/20/2023 YELLOW JACKET RCT MPU L-47 50029235500000 215117 10/25/2023 YELLOW JACKET CUT NS-05 50029232440000 205009 9/9/2023 YELLOW JACKET PERF NS-16A 50029230960100 206141 9/12/2023 YELLOW JACKET PERF NS-20 50029231180000 202188 9/11/2023 YELLOW JACKET PERF NS-24 50029231110000 202164 9/10/2023 YELLOW JACKET PATCH PTM P1-13 50029223720000 193074 10/24/2023 YELLOW JACKET PL Please include current contact information if different from above. T38164 T38164 T38165 T38166 T38167 T38168 T38169 T38170 T38171 T38172 T38173 T38174 12/1/2023 YELLOW PTM P1-13 50029223720000 193074 10/24/2023 JACKET PL Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 10:42:44 -09'00' Nolan 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: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38072 T38073 T38074 T38075 T38076 10/20/2023 T38070 T38071 PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing FZI Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Cement IA 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number' 193-074 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: " 50-029-22372-00-00 7. Property Designation(Lease Number): �L DL 003,462q„�LOQ �� 8. Well Name and Number: J PTM P1-13 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 7.,.i 11.Present Well Condition Summary: i'-� - 't Total Depth: measured • 11010 feet Plugs measured feet C true vertical • 8745 SEP � ) feet Junk measured feet ' Effective Depth: measured 8554 feet Packer measured 8614 feet (�°�j i true vertical 8047 feet Packer true vertical 8097.41 feet �° r Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20"94#NT6OLE 38-112 38-112 2300 520 Surface 3520 10-3/4"45.5#L-80 37-3558 37-3556 5210 2480 Intermediate 10275 7-5/8"29.7#NT-95 35-10310 35-8743 8180 5120 Production Liner 888 4-1/2"12.6#L-80 10122-11010 8746-8745 8430 7500 Perforation Depth: Measured depth: 10132-10193 feet 10193-10987 feet True vertical depth: 8746-8747 feet 8747-8744 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 33-8693 33-8162 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRCF-4A SSSV 2236 2234 12.Stimulation or cement squeeze summary: Intervals treated(measured): 4567'-8617' Treatment descriptions including volumes used and final pressure: 110 Bbls 15.8 ppg Class G Cement,2700 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 724 30413 17 2169 2932 Subsequent to operation: Shut-In 200 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development,0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 • Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-419 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature N '1Yc....47 Phone +1 907 564 4424 Date 9/15/15 g Form 10-404 Revised 5/2015 �� q// /i RBDMS4ey�SEP 1 7 1015 Submit Original Only AOr /T/. —" • • Packers and SSV's Attachment PTM P1-13 SW Name Type MD TVD Depscription P1-13 SSSV 2235.68 2234.39 4-1/2" Camco TRCF-4A SSSV P1-13 TBG PACKER 8613.75 8097.41 4-1/2"TIW HBBP Packer P1-13 PACKER 10122.31 8745.95 4-1/2"TIW SS Horiz Packer 0 0 0R LU / / E U E z = 2 / Ct W / n / % \ / \ \ CC 0 < \ / / > ƒ / o / ± R ¥ 2 20 ƒ % ƒ < Z / w ƒ \ / _1 _$ I- / / - 0 0 5 / 0 Z = 0 k k E ' / � / / / \ 0 \ -J ± RO a ,- m 0 L L / Z I -I -0 -61 < \ / 0 0 L / Z 0 ƒ\ ± p 0 D ƒ � / / D D � / O x H I 0 0 CC ± ca L 2 Et / ± L 0 CO \ \ o ƒ R ƒ $ / U 0 ® 2 i / 0 -J < Z < L CD / / 0 0- ca $ / - / 0 / / 0 o ® » 3 _Z GG < » O � ) ~ ® Z « � O ^m0 Ij 2 - = 3 + ± ¥ 0 3 L _ tn o R > \ O 0 Ci) Z n / $ § 0 c _i2 0 2 R � \ k / \ g \ / / / �� co Z ,- �/ f_ E q $ y \ / I J G \ ® ® ° 2 / 0 E i p\ CO / § < < 0 / £ / LU 0 d \ E/ a - o O x 2 a ± > 10 a u = L = o @ i : - 2 R -' 2 _ 0) H ' - Z121 x \ 2 i / # E 0 Ce / f \ H / / / ƒ \ k 9 ® -0- NO® � 2 = 7 £ 2 - > 2 $ 6 2 0 - / 2 « @ \ ƒ / m 2 Z U) c - t p \ E \ / OO (N ff \ $ $ < 0 / >ctE / / / kO < 2c) O00@) - 22 / ± per m @ � H111u) Z -J 0 ƒ R 0 a 0 \ Z ® \ - o ii w O ® u / O z / / u) \ _ O Z Z Z / _ ƒ - - / O H00 ,0 / » Z Z % -) -0 -0 2 0 O g . 2 Y 2 m - M ¥ ƒ E g 2 / 0 0 5 > -J Cr) R@ c o Z x \ \ E Z m 2 < u E 0 Z Q / L ® / WD00 EE ¥ LLLI.- 7 62 ƒ W � \ y g 0 O Z Z b \ @ % Q Z ƒ \ < L ZO Z ¢ ƒ k O '202 (1 (§ : E : : J ƒ / O. 0 : i k cc w D H � } 0 O 3 : / / f L I— < © r r r H \ d \ / / ~ @ 2 / G co Co Co co 0 < • • O y • ° o } i. • , Y C Z 4= a) (n c C a) Q- N (/) N = o C N E o O m -0 O Q O L U Q C ftQ N O p Z �' O () U _• 0) Q u) a) 5 •E O p O Q O N CES E O W W O -O O W• W N t� m c Q O E O Lp 4-_, U Q O N H "0 0 0 c 0 a) rn w o0- 13o cn > - _ z EL) as 0) O m - 92 o -0 U H HO � � 0 mQ 4 0) mN ° cM Z O W o U t �[ o L D 2 CO Cr L u) N c o Q- v a) (o m = •- W U H U Q _o _c O c 0 h N c c o z H w _0 O E as -0 r .p co 4- •c m O 0 v)- w F N Orn Q▪ O = C i U 7a)3 co 0o 4- CD (n • W 2 Y 0-• -- p J co a. 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E . - E _, o + _ \ \ / 0 ƒ R / / / e 5 = •G \ & / $ 0 $ b ƒ 2 C_\ 'Cl- / f 0 f / o p � / \ \ @ \ ego # ▪ 1- - ƒ 5 5 7 6 / o \ E ƒ / / / § / \ \ ca)e si 2- / � \ \ / �\ / k > = c O / £ i — t ▪ni / /y a9 .§ / / 2 a) G CI / / k 0 \ § \ t a) \ e \ / R Q c 0 G = _ ¥ 22 e \ 0 \ / / \ ƒ \ § c o_ ƒ \ \ / \ \ / \ k t % ci 3 % f ° ƒ / U „ .c E> o g $ ® [ » c/ 0 / / E9 ? / 00 .\k X2@CL 7 _1 / / / / $ / \ co \ / o -cI / / / / ƒ U \ / to in d \ / / m / oc \ 7 % m » I # � # m � � m / / TRIS_ ? • WELLHEAD= CAIY SAO NOTE WELL ANGLE-70' 9500'.TUBING ACTUATOR= BAKER C P1 -13 BANGOR-FM C fD 36'M D HORIZONTAL WELL OKB.ELEV= 48.5' BF.ELEV= KOP= 4400* 2238' H4-1/2"CAMCO TRCF SSSV,D=3.812" Nix Angle= 92°G 10229' 0 Datum MD= 11143' Datum TVD= 8800'SS GAS LFT MANDRELS 10-3/4"CSG,45.5#,L-80,D=9.953" H 3660' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4168 4165 6 MEM BK 0 04/14/13 L 2 8475 7980 31 TNFDX DRAY BK 0 03/06/01 CMT SQUEEZE(08/20/15) —I —4667' .1} 6800' —17-5/8"PRODUCTION CSG LEAK(06/08/13) I 411. Minimum ID = 3.725" @ 8671' .,# k• •4-1/2" PARKER SWN NIPPLE I 8542' J�BAKERC31AUsLIOINGstV. ' I • 13=3.813',FROFLE 8668'-8673' —1TBG PUNCH(08/10/15) I. PERFORATION SUMMARY '+ C, 8617' —17-5/8"X 4-1/T TM/F-eBP PKR,D=3.950" RE=LOG:CDR ON 11/06/95 ANGLE AT TOP PERF:87°@ 10132' Note:Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Cpn/Sgz SI-OT SQZ r 8664' H4-1/2'PARKER SWS ,D=3.813" PL 52 10132-10193 0 06/14/93 SL 52 10193-11010 0 06/14/93 I I 8671' H4-1/2"PARKER SWN NIP,D=3.725' 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" —1 8695' a 8696' H 4-1/2"TUBSIG TAX.W/4"PARKER WLEG 8704' —1 ELMD TT LOGGED 07/12/96 L 10122' —I5-1/2"CTU ENIRY GUDE �'�i R,10124' --1 TPA(SS HY D PKD=3.950" TOP OF 4-1/2"LNR-UNCEN NTED --1 10122' v 4-1/2-LNR-UN( ITED,12.6#,L-80,.0152 bpf,D=3.953" H 10193' \• • • TOP OF 4-1/2'LNR-sumoH 10193' \• • • \• ‘ 2.o, 7-5/8"CSG,29.7#,NT95HS,0=6.875' --1 10275' • PBTD H 10987' \ 4-1/2'LNR-SLID,12.6#,L-80,.0152 bpf,D=3.953" —1 11010' DATE REV BY COMMENTS DATE REV BY COMMENTS PONT MCNTY RE LINT 06/14/93 ORIGINAL COMPLETION 11/09/13 PJC REMOVE IN-OPS STATUS WELL: P1-13 08/12/01 RNfTP CORRECTIONS 09/14/15 JLS/JND PULLED PXN PLUG(08/08/15) PBRNA1 No: 1930740 09/18/02 DTR/KK GLV 00 09/14115 CJS/JMD SET CMF RETNRJCBPM3G Ra4CH AR No: 50-029-22372-00 08/24/06 RLWlPAG EAU TT CORRECTION 09/14/15 JLSIJMD CMF SQUEEZE(08/20/15) SEC 16,T12N,R14E,1419'FSL&809'FEL 04/23/13 PJM)SET PXN/GLV CIO(04/13-14/13 09/14/15 JTCIJM) NLLEU CMF RETN?/CBP(08/27/15) 10/23/13 RVWJMD PRODUCTION CSG LEAK(6/8/13) ( BP Exploration(Alaska) F(fr., � �7, THE STATE Alaska ail and Cas '� o� ASISf Conservation Commission ��- � l ` t ih-_=- 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Op Main: 907 279.1 433 ALAS Fax 907.276 7542 www.aogcc alaska.gov Aras Worthingtonsame U 2 3 ) 1 Wells Engineer BP Exploration (Alaska), Inc. q 3-0 - -- - P.O. Box 196612 t Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PTM P1-13 Sundry Number: 315-419 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /4„, Cathy '. Foerster Chair DATED this W day of July, 2015 Encl. STATE OF ALASKA `iU 0 9 2015 ALASKA OIL AND GAS CONSERVATION COME. .ION 7 19-t I S APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A G C C 1 Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ , Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing '0' Change Approved Program 0 , Plug for Redrill 0 Perforate New Pool 0 - Repair Well ® Re-enter Susp Well 0 Other e'1-7(('2f 1,4 t7 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class. 5. Permit to Dnll Number: 193-074 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 •Development 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22372-00-00 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? YesNo m Will planned perforations require a spacing exception? 0 PTM P1-13 • 9. Property Designation(Lease Number): 0- 10. Field/Pools: ADL . J_ __. C.:,07.—i',441.7 1,/v'/...r PRUDHOE BAY,PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft): Effective Depth TVD(ft)• Plugs(measured): Junk(measured): 11010 ' 8745• 8671 8145 8671 Casing Length Size MD TVD Burst Collapse Structural Conductor 75 20"94#NT6OLE 38-112 38-113 2300 520 Surface 3520 10-3/4"45.5#L-80 37-3558 37-3556 5210 P480 Intermediate 10275 7-5/8"29.7#NT-95HS 35-10310 35-8743 8180 5120 Production Liner 888 4-1/2"12.6#L-80 10122-11010 8746-8745 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 33-8693 Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"Camco TRCF-4A SSSV 2236, 2234.50 12.Attachments: Description Summary of Proposal RI 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ® • Gas 0 WDSPL 0 Suspended 0 16 Verbal Approval: Date. WINJ 0 GINJ 0 WAG 0 Abandoned ❑ Commission Representative' Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed Name Worthington,Aras J phione +1 Title Wells Engineer Signature '_..../— - 'i � *91 907 564 4102 Date S COMMISSION USE ONLY Conditions of approval'Notify Commission so that a representative may witness Sundry Number: 3 15— £{\`Z Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other Spacing Exception Required" Yes 0 No Fi Subsequent Form Required' //(> — -4P Z- APPROVED BYTHE Approved by:alet7 COMMISSIONER COMMISSION Date:7_/��, 1- q 1 ��5 ��o4b� RBDM$ % JUL 1 7 2015 ORIGINAL R: 7io.-/� Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. • a, H CO Ca N N L Nr cs5 Ni0 NI- NI- O r- ti G co co a 0 I- ,- N L M N- C c0 c0 0 G r � > O co co 0 wce 0 W Z Lu I- I- O O w co m 0 0 < Y I- cc g L M S J Q Q W W W r O) QJ J J J d d Zce C 0 0 0 0 0 < J W W 0J 0 tn d '_ E2 Z 0 _J0 d w d as < a Q 0 0 E 0 II 0w 0 Z 0 Z V M 2 2 2 0 (/) 0)i co c i 0)) RS r Z 1 Qr a a12 C C at+ N CO 0 CO O c I d r a 0 0 yam L 0 0 2 cc u_) Y 0 0 co cc 2 2 O cn cco co cn co ^a) a.. 0 0 0 0 c o (j) (I) coag mmm a 0 0 m a d 1- m M CO :D ;7 00 1 a a > OO O W J J Z N N Z D W V N L.L. co CO M0 WJJ01) JJa W cr ` Z S. a � J :7 0 L W W U W v - Q 0 2 JH J J D J D d' d O m 0X01 W J JQ 0 W W < 0Q V) Er. LI ✓) w co a w a) E ca Z C7 M 7 7 LL d co 0 LL N CL L. N < < m m u i. cnn ccn a D- CL a cc • Packers and SSV's Attachment PTM P1-13 SW Name Type MD TVD Depscription P1-13 SSSV 2235.68 2234.39 4-1/2" Camco TRCF-4A SSSV P1-13 PACKER 8613.75 8097.41 4-1/2"TIW HBBP Packer P1-13 PACKER 10122.31 8745.95 4-1/2"TIW SS Horiz Packer • •P1-13 PC Leak Cement Squeeze Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Chidi lgbokwe (907) 564-4795 History P1-13 was completed in 1993 as a horizontal well in the gas cap of the field. P1-13 was completed with -800' of slotted liner in the LB1 zone which limits remedial profile modification options. It is a high GOR well as one would suspect. This well cycles with P1-08. The well had a bradenhead weld in March 2001. P1-13 failed an integrity test in April, 2013. An LDL run shortly afterwards confirmed PC leak at 5800' and 6080' MD. It is currently classified as "Non Operable" due to the PC leaks. Objective This cement job is to repair PC leaks @ -5800' MD and @ 6080' MD and make this well operable. Cement will be circulated down CT and up the IA. The new cement top in the IA will be @ -4500' MD. Procedural steps Slickline 1. Pull tubing tail plug. E-Line 2. Set bridge plug just above production packer 3. Punch holes in tubing directly above bridge plug 4. Set cement retainer above tubing holes Coiled Tubing 5. Sting into cement retainer and pump Class G cement into the IA to get the TOC in the IA up to -4500' MD Fullbore 6. MITIA to 2500 psi Coiled Tubing 7. Mill out cement retainer and Bridge plug Operations 8. Bring well online SAFETY NOTE NEIL ANGLE-70'fil 9500'.TURING AE111-EAD= ovi 1 -1 3 HANGER .RIC•NT MO HORIZONTAL NELL : ACTUATOR• BAKER G OKB.E3.EV= 46,5 BF,REV= KM. 4400 ikka Angle= 92'@ 10229 11143 lurn IV Delurn A4)= CeO- 8&X? GAS LFT MANS ST22! 1:380. T:'El DEV4-I/7TYCAPEPAMVL:LASTR:1-1V PO=li813Al2.1E 10-314'CSG,45.5%.L.bo,(P.•9.953". -11 scow - ._ _1( 1 ,4168 4165, 6 11•11:0( OW SVC 0 .04/14M --4,- 2 18475 7980 31 TLEFOX 01.4Y BK 0 I03/06101 Minimum ID =3.725'0 8671' d ,, ,---4(„- ..._ may }-17-54"PROCI.CT1ON CSG LEAK(08/09/132...1 , 0 . 4-1/7"PARK ER SWN NPPLE * o aux 1--- BAKER caeu SLUNG SLV, E: D-3,811",PROFILE PERFORATION SLIMINJ?Y , PEF LOG.CM ON 11/06195 k . ANGLE AT TOP MY:87' 10137 27„, I 8617' H 7-518'X 4-172'1WI-13BP PKR 13=3.950' i 0 WO.Wet to Production OB for ht.torical pert data SE sPF 14TERVAL Opel/3w 3110T SOZ _ Ft 52 10132-10193 0 06/14/93 I I 864 H 4-1/2'PARKER SANS SIP,13=3.813' SL 52 10193.11010 0 06/14793 ' — 8671' --I 4-1/2'RAMER SWI MP,0=3.725' 8171. -43 r2-Fxri FLOG(04/13(13) I 4-1i7"15G.126%.L-80..0/52 MO.LI•-."3.958 MIK' . • RIM' H 4-1 a-nom TAL WA"Pf•RKER AtLas I 8704' H ELMD TT LOGGED 07/12/96 10127 -- 5-107MU BURY GUDE iit, I 10124' I- TFN SS HY 0 FKR,0=3.950'1 =r lOP Of 41-172'LNR-Lf.CB/EN1ED 10122 #4. , 4-1I?LP R-LN /T ,12,611,L-IO,.0152 bpi,0•3_953- --110.1113j. • • • • TOP Cf 4-1/2'VA-SLID - 10193' • • • • • • • • • • • • • 7.5/8"CSG,291*,NT95113,13 4 6_875' I-I 10275, 1 • }ATM H 1008T 4-1/2'LNR-SOIL 126*.L-80, 0152 Opt,0.3,953" 11010' ... GATE REV BY COOAENTS WOE REV BY I COAMENTS PONT NUMLNT Of/14/13 ORIGINAL COMPLETION 11/09013 PJC !RBADVE 14-OPS STATUS MIL P1-13 011/12701 MVP ,CORFCCTIOtS MUT Ft.):1930740 I 09114/02 CETTAKK I GLV VO AR I% 50-029-22372-00 08124/06 WAWA( ELA4)TT COFifECTIZ*4 SEC 16,T1214,R14E,1419'FSL&BOW FEL 04/23/13 LEINJILT SET PX/VOLV GO(04/1344/13I 10123f13 1404,443,fRIOCUCTEN CSG LEAK(66/13) • BP Exploration Vitas kai 2 "`P' BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 < Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 G ~: ~• Mr. Tom Maunder ~ ~~~~'~~ ~~I! ~ ~ ~~~`r Alaska Oil and Gas Conservation Commission 3 O 333 West 7t" Avenue ~(~ ' Anchorage, Alaska 99501 ~"' ~ 3 ~1~ Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, 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, 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) 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-O6 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julia Heusser, DATE: Commissioner Tom Maunder, ~.~-~SUBJECT' P. I. Supervisor ~[~'~" ~ \ ' John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-O1 April 1'1, 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 a sssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an excellent job. Summary: ! witnessed the SVS tests on LGI and PM-01 LGi, 3 wells, 9 components, I 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 prm01 4-10-01js Non C. onf, ide.n.~i~a! Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX operator Rep: ~k Wysocki " AOGCC Rep: J0hn,H. Spaulding Submitted By: Jotm Spaulding_. Date: Field/Unit/Pad: Pt McIntyre/PBU/PM-01 Separator psi: LPS 460 HPS 4/9/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Numbe, r Number PSI PSI Trip,, , Code Code Code Passed G,AS o,r CYCLe: 12 1910370 P1-02 1880056'" P1-03 1890130 460 350 '310 P P P " 'OIL PI'-04 "1930630: "460 ...... 700 ' 700 "P ..... P P " 0IL P1-05 '1930~70 " ~0' 350:' ' 300 P J P "9 ' ' OIL Pl'06' 1961376 ' ' 460 '700 .... 67~' P P ' 'P ' ' OiL P1-07 i8915~0! '~ .................. P1-08 1930980 460 1500 1200 P P p oIL el-09 1961540 460 350 300 P P e OIL PI'-I 1' i920860 460 350 250 P" ' p ' "P" ' oIL ,pl'.12' ' i91'0i'501 .................... ;¥[;i9~'.i.:--:. J:~ 1930740' ' 4'60 " ' 15'00':"'1'150 e ' P ' P ' - - OIL :Pl-17 1930510 460 350: 280 P P P OIL P1-20 ' ' 1920940 460' 350 175 3 P ''P "' 4/9'/01 ...... OIL PI-23 ...... 196i240 ................. ' P1-24 1961490 PI-G1 '~ "192i'15'0 "' 3600' "'2966' 2850 P P ..... P "' GIZNi Wells: 11 Components: 22 FaEures: 2 Failure Rate: 9.09% ["]90 Day ~ . Remarks: P1-08 & P1-3 were choked back, hence the h[,gl],.er,,pilot settings P 1-20 pilot reset and retested ILIF 1/16/01 Page 1 ofl 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: M,,ark Wysocki AOGCC Rep: John H' Spaulding Submitted By: .John ,Spau!d'mg Field/Unit/Pad: Lisburne/PBU/LGI Separator psi: LPS Date: 4/9/01 Well Permit Separ Set L/P Test Test Test Date oil, waG, GI~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 LGI-06 1860670 3800 2900 2500 P P P GINJ LGi-o8 18605;/0 ' " LGI- 10 18g0690 3800 2600 2300 P P P LGI- 12 1860540 Wells: 3 Components: 6 Failures: 1 Failure Rate: 16.67~[~190 Day Remarks: ~ L.0!,-0._2.P~0[tripped to low and was reset-retested and passed .... ~ RJF 1/16/01 Page 1 of 1 010409-SVS LGI Lisbume-js THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL E W M ATE IA L U N D ER T H IS M ARK ER C:LO~ILM-DOC PE R iff I T 93 --- 07 93---07!~- 93 -.. 0 7 a- 9 3 --- 0 7 a. 93 -'-074 o..:, 3 .... O. '? a. 93 .... 074 93 .... 0 '? h. 9:~,.., .... 07i~. 93 .... 074 D A T A 58i5 [i:,RY DITCH 4 07 FINAL WELL 93 --- 0 7 4 N P /D P/":Si R A l" e CJ r' y d '¥ ~.: O h '¥,;a s 'i: ~'. 'i i T D A TAI_PI~ I..i Y COkiP DATE:06 ~ 05/27/93---06/ ,..~ (~ R5..-7 ~ 5 ~HD ~ 87 x~:.5 TVD 67 0 . (L 2&5 ~:HD~67a0 ..... ~d.. o%5~lTVD 67i~0 [~' 6900'-1 ~000 ~ 6900'~'1 i005 ~ 6640 .... 87a. 5 ,~ 8850 ..... 8750 ~:' 2&S"HD~6?a. 0 ..... ~.. ,~.5e° ,,TV.D~6740._ ~ P C) R i' _~ ~F-]i N A L iq W D Date: Subject: From: ARCO Alaska, Inc. ourne/Point Mclntyre Engineeria November 17, 1993 Transmittal #361 ARCO Alaska Inc. To: Bob Crandall AC)C~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 # Run Date Company 1 sepia P1-04 Completion Record, Per/oration I-LSD 6 sip 33/8" 1 8/19/93 Schlumberger t P1-05 v/Perforating Record 3%8" HSD 4lB I-~ ]2[ RDX 1 P1-05 ~/Perforating Record 3%8" HSD 41B I~ ri RDX 1 P1-05 x/Perforating .Record 33/8'' HSD 4lB I-1J ]2[ RDX 1 1-05 vlSerforating Record 33/8'' I-LSD 4lB I-~ 12[ RDX 1 1-05 v, Perforating Record 3%8" HSD 4lB ~ II RDX 1 8/23/93 8/30/93. 8/31/93 9/01/93 9/02/93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P1-08 ,,/'Integrated Formation Log-MD P1-08 x/Integrated Formation Log-TVD P1-08 v/En~ee~g Parameters -MD P1-08 ,,'Pressure Data Log-MD 7/1%24/93 7/1%24/93 7/19-24/93 7/19-24/93 Exlog Exlog Exlog Exlog v/PI-GSST1 Integrated Formation Log -MD ~'PI-(BST1 Integrated Formation Log-TVD v'P1438~ Engineering Parameters -MD ,/~-(BST1 Pressure Data Log-MD · - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 - 7/25-31/93 Exlog Exlog Exlog Exlog Pl-13 ,/'Integrated Formation Log -MD Pl-13 v' Integrated Formation Log -TVD Pl-13 ,,,'Engineering Parameters -MD 'Pl-13 v'Pressure Data Log-MD' 6/1-11/93 6/1-11/93 6/1-11/93 611-11193 Exlog Exlog Exlog Exlog P1-17 v"Integrated Formation Log -MD P1-17 v?Integrated Formation Log-TVD Pl-17 v/ Engineering Parameters -MD Pl-17 ,/ff3ressure Data Log-MD - 4/12-16/93 - 4112-16193 - 4112-16193 - 4/12-16/93 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Date: Subject: October 13, 1993 Transmittal #359 ARCO Alaska Inc. ARCO Alaska, Inc. ~burne/Point McIntyre Engineer~_.~. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well P1-04 Completion Record, Perforation HSD 6 sfp 33/8'' IP1-05 P1-05 P1-05 P1-05 P1-05 P1-08 P1-08 P1-08 P1-08 Title Run # 'Run Date Perforating Record 33/8'' HSD 4lB HJ Perforating Record 3%8" HSD 4lB HJ II RE)X- Perforating Record 3%8" HSD 41B HJ Perforating Record 3%8"HSD 41B HJ Perforating Record 3%8" HSD 41B HJ Il RDX Company 8/19/93 Schlumberger 8/23/93 Schlumberge~ 8/30/93 Schlumberger 1~i'48/31/93 Schlumberger ,.,J9/01/93 Schlumberger 4--""9/02/93 Schlumberger Integrated Formation Log Integrated Formation Log.~~~, En~n~g Parameters Press~e Data Log-MD 7/19-24/93 7/19-24/93 7/19-24/93 7/19-24/93 Integrated Formation Log ~.~"~, erf/o-to~c~' _ Integrated Formation Log ~a'~ 0~0--%?~/ _ Engineering Parameters ~ ~"~ ~70 ~ l cqc~' .: _ Pressure Data Log-MD I~ E~lz5 -~7~5' - 7/25-31/93 7/25-31/93 . E~do~ 7/25-31/93 . Exlog 7/25-31/93. Ex, log Exlog Exlog Exlog Exlog . .. IPI-13 Pl-13 Pl-13 Pl-13 Integrated Formation Log -t~ 2", co~oo -- ~ ~o5 _ Integrated Formation Log._.'~ ~"~ (~qO-77~5 - Parameters Engineering , .- - Pressure Data Log -MD ~' co(,,,5o -- %-t 5o - 6/1-11/93 Exlog 6/1-11/93 Exlog 6/1-11/93 Exlog 6/1-11/93 Exlog P1-17 P1-17 P1-17 P1-17 Integrated Formation Log Integrated Formation Log Engineering Parameters Pressure Data Log-MD 4/12-16/93 Exlog 4/12-16/93 Exlog 4/12-16/93 Exlog 4/12-16/93 Exlog PLEASE SIGN ONE COPY AND RETURN .,,msmittal ¢¢359 (AOGCC) .... Page 2 Log Well Title Run # Run Date Company 1 blue line P1-21 Integrated Formation Log ~ 4/30-5/5/93 E/dog ~ft.O--lt~;ZS', P1-21 Integrated Formation Log ~¢' -. 4/30-5/5/93 E/dog ~oo- Ii 52-5 / 2" P1-21 Engineering Parameters ~J - 4/30-5/5/93 E/dog ¢ ; ec=~--- P1-21 Pressure Data Log-MD-'/- 4/30-5/5/93 E/dog ~' ~:=~ .- C/~co' 'P2-06 Z-Densilog/Cmpnstd NEUTRON/GR/Caliper ~ ¢~-5"~ 1~ctoo- 8/17/93 Atlas P2-06 Dual Laterolog/Gamma Ray/SP ' 1 8/17/93 Atlas P'U~'~ P2-06 Sub-Sea Vertical Depth (Single Shot Data)--.~1 8/17/93 Atlas ~P2-06 Borehole Profile 1 8/17/93 Atlas ~> lei~' ~ tq0~- x.~ 5", I[q0o- [t-~5~~ ~o7. 0-.9/13/93~o~t0 Atlas P2-16 Z-Densilog/Cmpnstd NEUTRON/GR/Ca~per/72~"~ P2-16 Dual Induction Focused Log/Gamma Ray 1 9/13/93 Atlas .-~ P2-16 Sub-Sea Vertical Depth (Multi Shot Data) 1 9/13/93 Atlas P2-16 Borehole Profile 1 9/13/93 Atlas '",,,'~ ,~'~' P2-46 Z-Densilog/Cmpnstd NEUTRON/GR/Caliper ~51' 9/27/93 Atlas P2-46 Dual Induction Focused Log/Gamma Ray 1 9/27/93 Atlas P2-46 Sub-Sea Vertical Depth (Directional Drlg Data)~'"'~ 1 > 9/27/93 Atlas P2-46 Borehole Profile 1 9/27/93 Atlas I+a"~ ~5c~- Diskette/Tape (w/verification listing) Well Title P1-04 P1-05 P1-05 P1-05 Run # GCT diskette-Complete Calc. v' 1 GCT diskette-Complete Calc. v' 1 CDN/CDR MAD Data in 1 Bit Run (O_.H Edit)~Z'~l CDN/CDR in 3 Bit Runs (O_~H Edit)¢ qq~Cl--t~ ~f~19 Final MWD w/lisdn~~:,-/' - CDR/GR'Ordy in 5 Bit Runs (OH Edit)'~SfSlS/~w'~q.° Dual Prop Resis/Densitv/Neutron/GR w/listing 5-7 Final MWD w/Listing, ~ - Final MWD w/Lisdng'r~ - Final MWD w/Lisdng~r~ - Final MWD w/Listing ~-~ ¢' _ CDN/CDR in 3 Bit Runs (O_.~ Edit)~k/~ !~q-1~7/,, 51 DLL/CN/ZDL/GR in LDWG Format w/Listing 1 '~lq e~t/' tjqbo-I~"JS~ Run Date Company 7/28/93 Schlumberger 8/12/93 Schlumberger P'~Z~?0~/b3a~S chlumberger 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 Atlas PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Log Well Title 1 sepia P1-21 ,./Integrated Formation Log-MD 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/Ca~per 1 P2-06 ,/Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 v/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 v/Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 7'Borehole Profile I P2-46 P2-46 P2-46 P2-46 ,/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 I Run # Run Date - 4130-515/93 - 4130-515/93 - 4130-5/5/93 - 4130-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9113193 9113193 9113193 9127193 9127193 9127/93 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 19 1995 ~aska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Page 2 Log Well Title 1 sepia }P1-21 ,,/Integrated Formation Log -MD ~°~/P1-21 V' Integrated Formation Log -TVD v~t ~ ~]P1-21 ~/Engineering Parameters -MD P1-21 ,/Pressure Data Log-MD Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 P2-06 v2-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 v/Borehole Profile 1 8/17/93 8/17/93 8/17/93 8/17/93 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 7'BorehOle Profile 1 9/13/93 9/13/93 9/13/93 9/13/93 P2-46 iP2-46 iP2-46 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 I 9/27/93 9/27/93 9/27/93 9/27/93 Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Transmittal #361 RECEIVED NOV 19 1993 'Alaska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #359 (AOGCC) Page 3 Report Well P1-04 P1-05 Pl-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 v" Final Well Report,"' Final Well Reportv- Date 7/28/93 8112/93 7119-81~ /93 611-11193 4/12-16/93 4/30-5/5/93 Company Schlumberger Schlumberger Exlog Ex, log Exlog Exlog Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 ' Anchorage, Alaska 99510-0360 27 , -- I Please note: The Exlog blueline logs are located within the Final Well Report binders. Transmittal #359 PLEASE SIGN ONE COPY AND RETURN INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-074 SURVEY 93-074 SURVEY 93-074 BD/GR 93-074 DP/NP/DPR/GR 93-074 DP/NP/DPR/GR 93-074 DPR/GR 93-074 DPR/GR 93-074 NP/DP/GR 93-074 NP/DP/GR 93-074 407 93-074 DAILY WELL OP 93-074 SURVEY 93-074 DRY FINAL MWD FINAL MWD R5-7f5"MD~6740-10240 2&5"MD,6740-10240 2&5"TVD,6740-10240 2&5"MD,6740-10240 2&5"TVD,6740-10240 2&5"MD,6740-10240 2&5"TVD,6740-10240 COMP DATE:06/14/93 05/27/93-06/15/93 MWD 6900-11005,SS#884 Are well tests Was well cored? SUMMARY required? Yes No Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No WELL IS IN COMPLIANCE. INITIAL 10/14/1993 PAGE: 1 Yes No COMMENTS: STATE OF ALASKA ALASK~ ,OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] ~D [] ABANDONED [] SERVICE []~ 2. Name of Operator 7. Permit Number ARCO A/aska, /nc. 93-74 3. Address ~. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22372 4. Location of well at surface 9. Unit or Lease Name ~ ...... ~,u~ ,; Point Mclntyre At Top Producing Interval ~ ~),~? ,~ 10. Well Number At Total Depth ~ ~'~ ...... ~ Point Mclntyre 1119' NSL, 1904' WEL, SEC. 15, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 48.5' J ADL 28297 ~7. Total D~pth (M~+IVD) 18. ~lu~ Back D~th (MD+IVY) 10. Diroctiona~ Su~y ~20. Dopth whore SSSV sot [2~. Ihicknoss o~ ~orma~rosl 22. lypo Eloctdc or Othor Lo~s ~un MWD 23. CASING, LINER AND CEME~I~ ~ ~G DEp~ MD CASING SIZE ~. ~R ~. G~DE T~ ~OM ~E S~E C~~ R~RD A~UNT ~LLED 20" 91.~ H-40 Sudace 80' 30" 281 cufl Arcticset 10-3/4" 45.~ NT-80 39' 3560' 13-1/2" 22~ cufl 'E'Y~ cu fi '~" 7-5/8" 29. 7~ NT95HS 36' 10275' 9-7/8" 897 cufl Class 'G' 4-1/2" 12.~ L-80 10131' 11010' 6-3/4" Not cement~ 24. Pedorations o~n to Production (MD+TVD of Top and BoHom ~d 25. ~ R~ORD interval, size and number) SIZE DEP~ SET,MD) PACKER SET Slotted Liner 10193~ 11010' MD 4-1/2", L-80 8696' 8617'& 10122' 26. ACID, F~C~RE, CEMENT ~UE~, ~C. DEPTH INTERVAL (MD) A~UNT & KIND OF MATERIAL~ 27. PRODUCT~N TEST bate First Production JMethod of Operation (Flowing, gas lift, etc.) Not on production ~ N/A Date of Test Hours Tested ~O~T~N FOR OIL-BBL GAS-~F WATER-BBL C~E~E JGAS-OIL RATIO TEST P~D ~ Flow Tubing Casing Pressure C~CU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 2~UR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fracture, apparent dips, and pr~ence of oil, gas or water. Submit ~re chips. RE E VEP qlaska Oil & Bas Oons. Com~ss~O~ Ano~orage Form 10-407 Submit in duplicate - Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. : 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure dala, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea West Sak Sands 6878' 6564' HRZ 9062' 9004' Kuparuk 9170' 9112' OCT ! I 199; Alaska 0ii & Gas 00ns. 6ornmissiOr~ Anchorage 31. LIST OF ATTACHMENTS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed - "[ Title Drilling Engineer Supervisor 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 BP/AAI SHARED SERVICE DALLY OPERATIONS PAGE: I WELL: P1-13 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 05/27/93 01:30 SPUD: 05/27/93 12:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 05/27/93 (1) P/U BHA. MW: 8.5 ViS: 0 TD: 110'(0) MOVE RIG. RIG ACCEPTED @ 01:30 HRS, 5/27/93. N/U DIVERTER. TEST SAME. 05/28/93 ( 2) DRLG. MW: 9.2 VIS:200 TD: 1720'(1610) N/U DIVERTER. TEST SAME. P/U BHA. CIRC. DRLG ICE F/ 40'-110'. SPUD WELL @ 12:00 HRS, 5/27/93. DRLG F/ 110'-1720'. 05/29/93 ( 3) R/U TO RUN CSG. MW: 9.3 VIS: 60 TD: 3570'(1850) DRLG F/1720'-1818'. CBU. SHORT TRIP. DRLG F/ 1818'-1720'. CIRC. SHORT TRIPTO HWDP. CIRC. POOH. 05/30/93 ( 4) P/U BHA #2. MW: 8.5 VIS: 0 TD: 3570'( 0) RIH W/10-3/4" CSG. CIRC. CMT CSG. BUMP PLUG W/2000 PSI. N/D DIVERTER. TOP JOB W/250 SX CMT. N/U BOPE. P/U BHA. 05/31/93 ( 5) POOH. MW: 8.8 VIS: 45 TD: 5342'(1772) RIH. CIRC. RIG. TEST CSG. OK. DRLG FC, FS, 10' NEW HOLE. LOT (13.1 PPG EMVV). DRLG F/3580'-4876'. SHORT TRIP TO 3560'. DRLG F/4876'-5342'. CBU. 06/01/93 ( 6) SHORT TRIP. MW: 9.2 VIS: 47 TD: 6844'(1502) POOH. CHANGE BHA. RIH. DRLG F/5342'-6844'. SHORT TRIP. 06/02/93 ( 7) DRLG. MW: 9.6 VIS: 46 TD: 8152'(1308) SHORT TRIP 15 STDS. DRLG F/6844'-8152'. 06/03/93 ( 8) DRILLING MW: 9.6 VIS: 48 TD: 8370'( 218) DRILL F/8152 TO 8252. CIRC LOW/HI SWEEP AROUND. POOH, NO SWABBING, NO TIGHT HOLE. STD BACK DCS, BREAK OFF BIT, L/D MOTOR. SERVICE WEAR BUSHING. BHA - PU LOGGING TOOLS, PU NEW MOTOR & BIT, ORIENT TOOLS PROGRAM LWD & LOAD SOURCE. RIH W/DCS & TEST MWD/LWD, RIH TO SHOE, FILL PIPE, SERVICE TOP DRIVE. RIH TO 6800. MADD RUN F/6800 - 8252. DRILL F/8252 - 8370. 06/04/93 (9) TD: 8984'(614) POOH MW: 9.8 VIS: 50 DRILL F1 8347 TO 8974'. CBU & FINISH WEIGHTING UP TO 10.~ I~ ~'iV ~ ~ .:~laska 0il & Gas Cons. Anchorage WELL : P1-13 OPERATION: RIG : POOL 7 PAGE: 2 06/05/93 (10) DRLG. MW:10.0 ViS: 48 TD: 9320'( 336) POOH. CHANGE BIT. RIH. REAM 90' TO BTM. DRLG F/ 8984'-9100'. CIRC. DRLG F/9100'-9158'. RELOG W/TELECO. DRLG F/9158'-9289'. RELOG W/TELECO. REDRILL HOLE F/ 9229'-9289'. CIRC. DRLG F/9289'-9320'. 06/06/93 (11) RIH. MW:10.2 VIS: 54 TD: 9741'( 421) DRLG F/9320'-9679'. CBU. SHORT TRIP 10 STDS. DRLG F/ 9679'-9741'. CIRC. POOH. CHANGE BIT. RIH. 06/07/93 (12) POOH. MW:10.2 VIS: 55 TD:10275'( 534) RIH. REAM TOBTM. DRLG F/9741'-10275'. CIRC. SHORT TRIP 20 STDS. CIRC. 06/08/93 (13) CIRC. MW:10.2 VIS: 50 TD:10275'( 0) POOH. L/D BHA. CHANGE RAMS ON BOPE. RIH W/7-5/8" CSG. CIRC. 06/09/93 ( 1 TD:10275'( 4) RIH PICKING UP 3 1/2" DP MW:10.2 VIS: 44 0) CIRC AND CONDITION FOR CEMENT. R/U HOWCO. N/D STACK. SET SLIPS. CUT CASG AND DRESS UP STUMP, SET PACKOFF AND TEST. N/U BOPE. CHANGE TOP RAMS TP 3 1/2" DP. CUT DRILLING LINE. P/U BHA ~,. TEST MWD AND MOTOR. RIH P/U 3 1/2" DP. 06/10/93 ( 1 TD:10600'( 5) DRILLING @ 10600' MW:10.1 VIS: 59 325) P/U 3 1/2 DP. STAND 8 STDS IN DERRICK. CHANGE BOTTOM SET OF RAMS TO 3 1/2. P/U 24 JTS. RIH TO 10115'. CLOSED LOWER SET OF RAMS. TEST CASING. DRILLED F/C, CEMENT AND F/S AND 10' NEW HOLE. CIRC HOLE CLEAN. CLEAN PITS. DISPLACE HOLE TO FLO-PRO MUD. RELOG 10239' TO 10290' W/ SPERRY SUN. DRILLED AND SURVEYED 10290 TO 10600'. 06/11/93 (16) RIH W/6 3/4" HOLE OPENER MW:10.0 VIS: 65 TD:11005'( 405) DRILLED AND SURVEYED 10600 TO 11005°. CIRC AND CONDITION HOLE. PUMP DRY JOB. POOH. SLM. L/D MOTOR AND MWD. CLEAN FLOOR, SERVICE TOP DRIVE. P/U HOLE OPENER AND BIT #7. RIH. 06/12/93 (17) SET LNR HGR PKR. MW:10.2 WBM TD:11005 WASH & REAM TO BTM. CIRC. SHORTTRIP TO 10250'. CIRC. PB: 0 POOH. L/D BHA. RIH W/4-1/2" SLOTTED LNR ON DP. CIRC. DROP DART. 06/13/93 (18) RUN 4-1/2" COMP ASS'Y. MW: 9.8 NaCI TD:11005 SET LNR HGR PKR W/3500 PSI. TEST ANNULS W/3000 PSI. PB:11005 TEST TBG TO 4700 PSI. OK. DISP WELL W/9.8 PPG NACL. TEST BOPE. RIH W/4-1/2" COMP. R E E E iV ~ 0 OCi' 1 ! 19§ Alaska Oil & Gas Cons. CornmissiOO ;Anchorage WELL 'P1-13 OPERATION: RIG · POOL 7 PAGE: 3 06/14/93 (19) L/D DP. MW: 9.8 NaCI TD:11005 RIH W/4-1/2" COMP ASS'Y. SET PKR W/4000 PSI. TEST PB:11005 ANNULUS W/3500 PSI. OK. SHEAR DCK-2 VALVE. L/D LAND JT. SET BPV. N/D BOPE. N/U TREE. TEST TREE. SET BPV. INJECT 50 BBLS CRUDE DN ANNULUS. L/D DP. 06/15/93 (20) TD:11005 PB:11005 RIG RELEASED. MW: 9.8 NaCI L/D DP. RIG RELEASED @ 12:00 HRS, 6/14/93. REC. OCT Alaska Oil & Gas Cons. Anchorage PRUDHOE BAY DRILLING GROUP POINT McINTYRE Pl-13/H9 NORTH SLOPE, ALASKA MICI OFIL ED Baker Hughes INTEQ Anchorage, Alaska Well Name Date Surveyed~ Client Survey Performed By : Point McIntyre : No. Pi-13/H9 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E : 7 June 1993 : Prudhoe Bay Drilling Group : Robert McCarthy RECEIVED OCT t 4 ~99~ · aska Oil & Gas C~r~s. Co~r-~o Phis survey is correct to thet~st o~ my knowledge ~nd is supported~iI~i .... '~'" .... ~'~'% ...... '~h' ' COMPANY REPRESENTATIVE Baker Hughes INTEQ Client : Well Name : Point McIntyre Date 7 June 1993 : No. Pl-13/H9 Filename : 1227 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E No Interpolation Plane of Vertical Section : 96.0° 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 :+30.07°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Client Well Name MD ft 0 85 149 220 310 40O 490 581 671 761 ' 855 936 1029 1121 1214 : Point McIntyre : No. Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E CkL INC DIR ft deg deg 0 0.0 0.0 85 0.2 256.8 64 0.2 84.9 71 0.1 148.5 90 0.0 213.9 90 0.1 286.0 90 0.6 142.2 91 1.3 128.2 90 3.3 114.1 90 3.9 124.3 94 3.8 120.8 81 4.0 112.0 93 3.9 115.1 92 3.1 109.5 93 1.4 83.5 1305 91 1.2 65.6 1398 93 1.4 60.7 1490 92 1.5 55.4 1581 91 0.6 359.8 1673 92 1.0 340.5 1766 1793 1860 1952 2043 93 1.1 332.8 27 1.3 335.9 67 1.1 352.8 92 0,9 357.4 91 1.1. 16.0 2136 93 1.2 17.1 2230 94 1.4 24.4 2323 93 1.3 27.1 2418 95 1.3 40.3 2512 94 1.2 40.3 2607 95 1.5 41.7 2701 94 1.8 43.1 2793 92 1.6 41.3 2887 94 1,4 50.8 2977 90 1.4 55.4 3070 93 1.6 58.9 3163 93 1.8 58.2 3257 94 1.3 67.7 3350 93 1.3 100.4 3443 93 1.2 108.5 Baker Hughes 1419 FSL, 809' TVD VS ft ft 0 0 85 -0 149 -0 220 0 310 0 400 0 490 0 581 1 671 5 761 10 855 16 935 21 1028 27 1120 32 1213 36 1304 38 1397 39. 1489 41 1580 42 1672 42 1765 41 1792 41 1859 40 1951 40 2042 40 2135 40 2229 41 2322 41 2417 42 2511 44 2606 45 2700 46 2791 48 2885 50 2975 51 3068 53 3161 55 3255 57 3348 59 3441 61 INTEQ Page 1 of 4 Date 7 June 1993 Filename : 1227 FEL No Interpolation LAT DEP D'LEG BUILD o ft ft °/100 /100 0 0 0.0 0.0 -0 -0 0.2 0.2 -0 -0 0.6 0.0 -0 0 0.3 -0.1 -0 0 0.1 -0.1 -0 -0 0.1 0.1 -0 0 0.8 0.6 -2 1 0.8 0.8 -3 4 2.3 2.2 -6 9 1.0 0.7 -9 15 0.3 -0.1 -12 20 0.8 0.2 -14 25 0.3 -0.1 -17 31 0.9 -0.9 -17 34 2 . 1 -1.8 -17 36 0.5 -0.2 -16 38 0.2 0.2 -15 40 0.2 0,1 -13 41 1.4 -1.0 -12 41 0.5 0.4 -11 40 0.2 0.1 -10 40 0.8 0.7 -9 39 0.6 -0,3 .-7 39 0.2 -0.2 -6 39 0,4 0.2 TURN °/100 0.0 -99.0 -99.0 89.6 72,7 80.1 -99.0 -15.4 -15.7 11.3 -3.7 -10.9 3.3 -6.1 -28.0 -19.7 -5.3 -5.8 -61.1 -21.0 -8.3 11.5 25.2 5.0 20.4 -4 40 0.1 0.1 1.2 -2 41 0.3 0.2 7.8 0 42 0.1 -0.1 2.9 2 43 0.3 0.0 13.9 4 44 0.1 -0.1 0.0 5 46 0.3 0.3 7 47 0.3 0.3 9 49 0.2 -0.2 11 51 0.3 -0.2 12 53 0.1 0.0 14 55 0.2 0.2 15 57 0.2 0.2 16 59 0.6 -0.5 16 61 0.8 0,0 16 63 0.2 -0.1 1.5 1.5 -2.0 10.1 5.1 3.8 -0.8 10.1 35.2 8.7 Client Well Name MD ft 3543 3607 3700 3793 3887 : Point McIntyre : No. Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E CkL INC DIR ft deg deg 100 1.1 110.9 64 1.2 108.1 93 1.1 112.3 93 1.0 115.5 94 3.3 117.6 3980 93 4.0 4073 93 5.2 4168 95 5.3 4262 94 6.9 4353 91 8.3 4447 4540 4634 4726 4820 4914 5007 5100 5192 5286 5379 5473 5567 5661 5753 5846 5937 6031 6124 6217 6310 6404 6498 6592 6685 94 93 94 92 94 94 93 93 92 94 93 94 94 94 92 93 91 94 93 93 6778 6872 6965 7058 7150 119.4 115.1 114.1 113.4 114.4 10 11 13 14 15 .3 .9 .0 .2 .4 Baker Hughes 17 18 20 21 22 .4 .4 .0 .4 .6 1419 FSL, 809' 23 25 26 28 29 .0 .i .5 .2 .9 TVD VS ft ft 3541 63 3605 65 3698 66 3791 68 3885 71 31 32 33 32 32 .5 .6 .6 .5 .3 3978 77 4071 84 4165 92 4259 102 4349 113 93 94 94 94 93 31 31 31 31 3O 113.4 4442 127 115.5 4533 144 109.2 4625 164 109.5 4714 185 104.6 4805 208 93 94 93 93 92 3O 3O 3O 30 32 104.6 103.9 102.1 102.5 102.5 4895 235 4984 263 5072 293 5158 326 5245 361 103.2 5330 396 103.5 5416 434 103.2 5501 475 104.2 5584 518 105.0 5665 562 106.0 5745 609 105.3 5822 656 106.0 5901 707 104.2 5979 757 102.8 6057 806 .8 103.9 6136 855 .5 103.2 6216 904 .2 102.5 6296 953 .2 102.5 6377 1001 .7 102.5 6456 1049 103.2 103.5 104.6 104.6 103.5 .5 .9 .8 .5 .9 6536 1096 6617 1143 6697 1191 6777 1237 6855 1285 INTEQ Page 2 of 4 Date 7 June 1993 Filename : 1227 FEL No Interpolation LAT DEP D'LEG BUILD ft ft °/100 °/100 15 65 0.1 -0.1 15 67 0.2 0.2 14 68 0.1 -0.1 13 70 0.1 -0.1 12 73 2.4 2.4 9 78 0.8 0.8 6 85 1.3 1.3 2 93 0.1 0.1 -2 102 1.7 1.7 -7 113 1.5 1.5 -'13 127 2 · 1 2 · 1 -20 143 1 · 8 1 · 7 -28 162 1 · 9 1.2 -35 182 1.3 1.3 -42 205 1 · 8 1 · 3 TURN °/100 2.4 -4.4 4.5 3.4 2.2 1.9 -4.6 -1.1 -0.7 1.1 -1.1 2.3 -6.7 0.3 -5.2 -49 231 2.1 2.1 0.0 -56 259 1.1 1.1 -0.8 -63 288 1.8 1.7 -1.9 -70 320 1.5 1.5 0.4 -77 354 1.3 1.3 0.0 -85 390 0.5 0.4 0.8 -94 427 2.2 2.2 0.3 -104 467 1.5 1.5 -0.3 -114 509 1.9 1.8 1.1 -125 552 1.9 1.8 0.9 -138 598 1.8 1.7 -151 644 1.3 1.2 -165 694 1.1 1.1 -178 743 1.6 -1.2 -190 791 0.8 -0.2 1.1 -0.8 0.7 -1.9 -1.5 -201 839 0.8 -0.5 1.2 -213 887 0.5 -0.3 -0.7 -223 935 0.5 -0.3 -0.7 -234 982 0.0 0.0 0.0 -244 1029 0.5 -0.5 0.0 -255 1075 0.4 -0.2 -266 1122 0.5 0.4 -278 1168 0.6 -0.1 -289 1214 0.3 -0.3 -301 1261 2.7 2.6 0.8 0.3 1.2 0.0 -1.2 Client Well Name MD ft 7242 7334 7428 7523 7618 7712 7805 7898 7992 8087 8180 8272 8370 8465 8560 8653 8747 8842 8931 9025 9118 9212 9307 9353 9402 9494 9588 9618 9640 9657 9681 9720 9747 9774 9809 9840 9868 9901 9934 9962 : Point McIntyre : No. P1 13/H9 : Surface Location: : Sec. 16-T12N-R14E C~L INC DIR ft deg deg 92 32.7 103.9 92 32.3 105.7- 94 31.6 106.7 95 33.0 104.2 95 32.3 106.4 94 33.0 103.5 93 32.6 105.0 93 31.9 105.7 94 32.5 102.5 95 31.6 104.6 93 31.0 104.2 92 31.0 101.4 98 30.4 101.1 95 30.1 101.8 95 32.3 99.3 93 34.9 93.0 94 37.2 92.6 95 42.2 90.2 89 47.9 86.0 94 53.2 89.1 93 55.1 87.0 94 55.8 86.3 95 59.4 83.2 46 62.8 83.2 49 65.7 80.3 92 71.4 80.3 94 74.3 80.3 30 75.0 81.7 22 75.3 81.7 17 75.4 82.1 24 75.9 83.5 39 78.6 82.1 27 79.5 81.7 27 80.3 83.2 35 81.7 81.4 31 82.2 81.0 28 82.6 83.5 33 83.0 82.5 33 83.5 83.5 28 83.8 82.5 Baker Hughes INTEQ 1419 FSL, 809' Page 3 of 4 Date 7 June 1993 Filename : 1227 FEL No Interpolation TVD VS ft ft 6933 1335 7010 1384 7090 1432 7170 1483 7250 1533 LAT DEP D'LEG BUILD TURN ft ft °/100 °/100 °/100 -313 1309 0.3 -0.2 0.4 -326 1357 1.1 -0.4 2.0 -339 1405 0.9 -0.7 1.1 -353 1454 2.0 1.5 -2.6 -367 1503 1.5 -0.7 2.3 7330 1583 7408 1633 7486 1682 7566 1732 7646 1782 -380 1552 1.8 0.7 -3.1 -392 1601 1.0 -0.4 1.6 -405 1649 0.9 -0.8 0.8 -417 1697 1.9 0.6 -3.4 -429 1746 1.5 -0.9 2.2 7-726 1829 7805 1876 7889 1926 7971 1974 8052 2023 -441 1793 0.7 -0.6 -452 1839 1.6 0.0 -461 1888 0.6 -0.6 -471 1935 0.5 -0.3 -480 1984 2.7 2.3 8130 2074 8206 2130 8279 2190 8342 2252 8401 2324 -485 2035 4.7 2.8 -4'88 2090 2.5 2.4 -489 2151 5.5 5.3 -487 2214 7.2 6.4 -484 2286 6.2 5.6 8456 2399 8509 2475 8560 2554 8582 2593 8604 2636 -482 2361 2.7 2.0 -477 2439 1.0 0.7 -470 2518 4.7 3.8 -465 2558 7.4 7.4 -459 2602 8.0 5.9 8637 2718 8665 2805 8673 2833 8679 2853 8683 2869 -444 2686 6.2 6.2 -429 2775 3.1 3.1 -424 2804 5.1 2.3 -421 2825 1.4 1.4 -419 2841 2.4 0.6 8689 2892 8697 2929 8703 2955 8707 2980 8713 3014 -416 2864 6.0 2.1 -411 2902 7.8 6.9 -408 2928 3.6 3.3 -404 2954 6.2 3.0 -400 2989 6.5 4.0 8717 3044 8721 3071 8725 3102 8729 3134 8732 3162 -395 3019 2.1 1.6 -391 3046 9.0 1.4 -387 3079 3.2 1.2 -383 3111 3.4 1.5 -380 3139 3.7 1.1 -0.4 -3.0 -0.3 0.7 -2.6 -6.8 -0.4 -2.5 -4.7 3.3 -2.3 -0.7 -3.3 0.0 -5.9 0.0 0.0 4.7 0.0 2.4 5.8 -3.6 -1.5 5.6 -5.1 -1.3 8.9 -3.0 3.0 -3.6 Client Nell Name : Point McIntyre : No. Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes 1419 FSL, 809' MD CkL INC DIR TVD VS ft ft deg deg ft ft 9993 31 83.8 81.7 8735 3191 10025 32 84.3 83.9 8739 3222 10054 29 84.6 84.2 8741 3251 10093 39 86.0 83.5 8745 3289 10119 26 88.1 83.9 8746 3314 10144 25 89.6 84.6 8746 3339 10180 36 91.1 83.9 8746 3374 10195 15 91.2 83.2 8746 3388 INTEQ Page 4 of 4 Date 7 June 1993 Filename : 1227 FEL No Interpolation LAT DEP D'LEG BUILD TURN ft ft °/100 °/100 °/100 -375 3170 2.6 0.0 -2.6 -371 3201 7.0 1.6 6.9 -368 3230 1.5 1.0 1.0 -364 3269 4.0 3.6 -1.8 -3'61 3294 8.2 8.1 1.5 -359 3319 6.6 6.0 2.8 -355 3355 4.6 4.2 -1.9 -354 3370 4.7 0.7 -4.7 Drigin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 3388 ft 96.0° Baker Hughes INTEQ Anchorage, Alaska Well Name Date Surveyed Client Survey Performed By : Point McIntyre : No. Pl-13/H9 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E : 7 June 1993 : Prudhoe Bay Drilling Group : Robert McCarthy ?his survey is correct~ ~nd is supported ~ctua,~e of knowledge ...... COMPANY REPRESENTATIVE Baker Hughes INTEQ 31ient : ~ell Name : Point McIntyre : No. Pl-13/H9 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E Date 7 June 1993 Filename : 1227 Interpolated 100 ft of TVD Plane of Vertical Section : 96.0° Latitude & Departure relate to : WELLSITE CENTER Yertical Section Originates at : WELLSITE CENTER ~lot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft ~alculation Method : MINIMUM CURVATURE ~ ~agnetic Declination :+30.07OWELLSiTE North ]rid convergence : +0.0000o +0° 0' 0'' (T) Client ~ell Name : Point McIntyre : No. Pl-t3/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes INTEQ 1419 FSL, 809' FEL Page 1 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of TVD MD ft 0 100 200 30O 4OO 5OO 6OO 700 8OO 901 CkL INC DIR ft deg deg 0 0.0 0.0 100 0.2 216.5 100 0.1 130.6 100 0.0 206.6 100 0.1 286.0 100 0.7 140.7 100 1.7 125.2 100 3.5 117.4 100 3.9 122.8 100 3.9 115.8 1001 100 3.9 114.2 1101 100 3.3 110.7 1201 100 1.6 87.1 1301 100 1.2 66.4 1401 100 1.4 60.5 1501 1601 1701 1801 1901 100 1.4 92.9 100 0.7 355.6 100 1.0 338.2 100 1.3 338.0 100 1.0 354.9 2001 100 1.0 172.5 2101 100 1.2 16.7 2201 100 1.3 22.2 2301 100 1.3 26.5 2401 100 1.3 38.0 2501 100 1.2 40.3 2601 100 1.5 41.6 2701 100 1.8 43.1 2802 100 1.6 42.2 2902 100 1.4 51.5 3002 100 1.5 56.3 3102 100 1.7 58.7 3202 100 1.6 62.1 3302 100 1.3 83.4 3402 100 1.2 104.9 3502 3602 3702 3802 3902 100 1.1 109.9 100 1.2 108.3 100 1.1 112.4 100 1.2 115.7 100 3.4 117.9 TVD VS LAT ft ft ft 0 0 0 100 -0 -0 200 0 -0 300 0 -0 400 0 -0 500 0 -1 600 2 -2 700 6 -4 800 12 -7 900 18 -11 1000 25 -14 1100 31 -16 1200 35 --17 1300 38 -17 1400 39 -16 1500 41 -14 1600 42 -13 1700 41 -12 1800 41 -10 1900 40 -8 2000 40 -6 2100 40 -4 2200 41 -2 2300 41 -0 2400 42 2 2500 43 3 2600 45 5 2700 46 7 2800 48 9 2900 50 11 3000 52 ~13 3100 54 14 3200 56 15 3300 58 16 .3400 61 16 3500 63 16 3600 65 15 3700 66 14 3800 68 13 3900 72 11 DEP D'LEG BUILD TURN ft °/100 o/100 o/100 0 0.0 0.0 0.0 -0 0.2 0.2 -99.0 -0 0.2 -0.1 -85.9 0 0.1 -0.1~ 76.0 -0 0.1 0.1 79.4 0 0.8 0.6 -99.0 2 1.1 1.0 -15.4 6 1.8 1.8 -7.8 12 0.5 0.4 5.4 17 0.5 0.1 -7.0 24 0.1 0.0 -1.7 30 0.7 -0.7 -3.4 34 1.9 -1.6 -23.6 36 0.7 -0.4 -20.7 38 0.2 0.2 -5.8 40 0.8 -0.0 32.4 41 1.6 -0.7 -97.3 40 0.4 0.3 -17.4 40 0.2 0.2 -0.2 39 0.4 -0.3 16.9 39 2.0 -0.0 99.0 40 2.1 0.2 -99.0 40 0.2 0.2 5.5 41 0.1 -0.0 4.3 43 O. 3 -0.0 11.5 44 0.1 -0.1 2.3 46 0.3 0.3 1.3 47 0.3 0.3 1.5 49 0.2 -0.2 -0.9 51 0.3 -0.2 9.4 53 0.1 0.1 4.8 56 0.2 0.2 2.3 58 0.1 -0.1 3.4 60 0.6 -0.3 21.3 63 0.5 -0.1 21.5 65 0.1 -0.1 5.0 66 0.1 0.1 -1.6 68 0.1 -0.1 4.0 70 0.1 0.1 3.3 74 2.2 2.2 2.2 Client Well Name : Point McIntyre : No. Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes INTEQ 1419 FSL, 809' FEL Page 2 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of TVD MD ft 4002 4102 4203 4304 4405 4506 4609 4711 4815 4919 CkL INC DIR ft deg~ deg 100 4.3 118.4 100 5.2 114.8 100 5.9 113.8 101 7.5 113.9 101 9.4 113.8 102 11.3 114.7 102 12.7 110.9 103 14.0 109.5 103 15.3 104.9 104 17.5 104.6 5024 105 18.7 103.6 5130 106 20.5 102.2 5238 107 22.0 102.5 5346 108 22.9 103.0 5455 109 24.7 -103.4 5566 5679 5794 5911 6030 111 26.5 103.2 113 28.5 104.4 115 30.6 105.4 117 32.3 105.5 119 33.6 106.0 6149 119 32.4 103.8 6268 118 32.0 103.4 6385 118 31.6 103.3 6502 117 31.2 102.5 6619 117 31.1 102.5 6736 6852 6968 7085 7203 116 30.6 102.9 116 30.8 103.4 116 30.8 104.6 117 31.2 104.3 118 32.18 103.7 7322 119 32.4 105.5 7440 118 31.8 106.4 7558 118 32.7 105.0 7677 119 32.7 104.6 7796 119 32.6 104.9 7914 118 32.0 105.2 8032 118 32.1 103.4 8150 117 31.2 104.3 8266 117 31.0 101.6 8383 116 30.4 101.2 TVD VS LAT ft ft ft 4000 78 8 4100 86 5 4200 96 1 4300 107 -4 4400 121 -10 4500 138 -'18 4600 159 -26 4700 182 -34 4800 207 -42 4900 236 -49 5000 269 -57 5100 304 -65 5200 343 -73 5300 384 -83 5400 427 -93 5500 475 -104 5600 526 -116 5700 583 -131 5800 643 -147 5900 707 -165 6000 770 -181 6100 833 -196 6200 895 -210 6300 955 -224 6400 1015 -237 6500 1074 -250 6600 1133 -264 6700 1192 -278 6800 1251 -293 6900 1314 -308 7000 1377 -324 7100 1439 -341 7200 1501 -358 7300 '1564 -375 7400 1628 -391 7500 1691 -407 7600 1753 -422 7700 1814 -437 7800 1874 -451 7900 1933 -463 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 80 0.9 0.9 0.5 87 1.0 0.9 -3.6 96 0.7 0.7 -0.9 107 1.6 1.6 0.. 0 121 1.8 1.8 -0.0 137 1.9 1.9 0.9 157 1.6 1.4 -3.8 179 1.3 1.3 -1.4 204 1.7 1.3 -4.4 232 2.0 2.0 -0.3 264 1.2 1.2 -0.9 299 1.7 1.7 -1.3 337 1.4 1.4 0.2 377 0.8 0.8 0.4 420 1.7 1.7 0.5 466 1.6 1.6 -0.2 517 1.9 1.8 1.0 572 1.9 1.8 0.9 631 1.4 1.4 0.1 693 1.1 1.1 0.4 756 1.4 -1.0 -1.8 817 0.4 -0.4 -0.4 877 0.4 -0.4 -0.0 937 0.5 -0.3 -0.7 996 0.1 -0.1 0.0 1054 0.4 -0.4 0.3 1112 0.3 0.2 0.5 1170 0.5 -0.0 1.0 1228 0.4 0.4 -0.3 1289 1.4 1.3 -0.5 1351 0.9 -0.4 1.5 1411 0.6 -0.5 0.8 1472 1.0 0.8 -1.2 1534 0.2 -0.0 -0.4 1596 0.1 -0.1 0.2 1657 0.6 -0.5 0.3 1718 0.8 0.1 -1.5 1778 0.9 -0.8 0.8 1837 1.2 -0.2 -2.4 1895 0.6 -0.6 -0.3 Client Well Name : Point McIntyre : No. Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes INTEQ 1419 FSL, 809' FEL Page 3 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of TVD MD CkL INC DIR TVD VS LAT ft ft deg deg ft ft ft 8499 116 30.9 100.9 8000 1991 -474 8617 118 33.9 95.4 8100 2055 -483 8740 123 37.0 92.6 8200 2125 -488 8872 132 44.1 88.8 8300 2211 -489 9023 151 53.1 89.0 8400 2322 -484 9196 173 55.7 86.4 8500 2462 -478 9393 198 65.2 80.8 8600 2628 -460 9733 340 79.0 81.9 8700 2941 -410 10195 462 91.2 83.2 8746 3388 -354 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 1952 0.5 0.4 -0.2 2015 3.6 2.5 -4.6 2086 2.9 2.5 -2.3 2172 5.7 5.4 -2.9 2284 5.9 5.9 0.2 2425 1.9 1.5 -1.5 2595 5.4 4.8 -2.8 2915 4.1 4.1 0.3 3370 7.7 7.7 0.7 Drigin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 3388 ft 96.0° Baker Hughes INTEQ Anchorage, Alaska Well Name Date Surveyed Client Survey Performed By : Point McIntyre : Pl-13/H9 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E : 7 June 1993 : Prudhoe Bay Drilling Group : Robert McCarthy This survey is corre~ and is supported actual eeee®e ~ee~ee my knowledge ... COMPANY REPREoENTATIVE Baker Hughes INTEQ Client : Well Name : Point McIntyre : Pl-13/H9 : Surface Location: 1419 FSL, 809' FEL : Sec. 16-T12N-R14E Date 7 June 1993 Filename : 1227 Interpolated 100 ft of MD Plane of Vertical Section : 96.0° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.00Oft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.07°WELLSITE North Grid convergence : +0.0000° +0° O' 0'' (T) Client )qell Name : Point McIntyre : Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes INTEQ 1419 FSL, 809' FEL Page 1 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of MD MD ft 0 100 200 300 400 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 CkL INC DIR ft deg deg 0 0.0 0.0 100 0.2 216.5 100 0.1 130.6 100 0.0 206.6 100 0.1 286.0 100 0.7 140.7 100 1.7 125.2 100 3.5 117.4 100 3.9 122.8 100 3.9 115.9 100 3.9 114.1 100 3.3 110.8 100 1.7 87.4 100 1.2 66.6 100 1.4 60.6 1500 100 1.4 88.9 1600 100 0.7 355.8 1700 100 1.0 338.3 1800 100 1.3 337.7 1900 100 1.0 354.8 2000 100 1.0 177.3 2100 100 1.2 16.7 2200 100 1.3 22.1 2300 100 1.3 26.4 2400 100 1.3 37.8 2500 100 1.2 40.3 2600 100 1.5 41.6 2700 100 1.8 43.1 2800 100 1.6 42.0 2900 100 1.4 51.5 3000 100 1.4 56.3 3100 100 1.7 58.7 3200 100 1.6 61.9 3300 100 1.3 82.8 3400 100 1.2 - 104.8 3500 100 1.1 109.9 3600 100 1.2 108.4 3700 100 1.1 112.3 3800 100 1.2 115.7 3900 100 3.4 117.9 TVD VS LAT ft ft ft 0 0 0 100 -0 -0 200 0 -0 300 0 -0 400 0 -0 500 0 -1 600 2 -2 700 6 -4 800 12 -7 899 18 -11 999 25 ~14 1099 31 -16 1199 35 -17 1299 38 -17 1'399 39 -16 1499 41. -14 1599 42 -13 1699 41 -12 1799 41 -10 1899 40 -8 1999 40 -6 2099 40 -4 2199 41 -2 2299 41 -0 2399 42 2 2499 43 3 2599 45 5 2699 46 7 2798 48 9 2898 50 11 2998 52 13 3098 54 14 3198 56 15 3298 58 16 3398 61 16 3498 63 16 3598 65 15 3698 66 14 3798 68 13 3898 72 11 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.2 0.2 -99.0 -0 0.2 -0.1 -85.9 0 0.1 -0.1 76.0 -0 0.1 0.1 79.4 0 0.8 0.6 -99.0 2 1.1 1.0 -15.4 6 1.8 1.8 -7.8 12 0.5 0.4 5.5 17 0 . 5 0 . 1 -6 . 9 24 0.1 0.0 -1.8 29 0.7 -0.6 -3.4 34 1.9 -1.6 -23.4 36 0.7 -0.4 -20.8 38' 0.2 0.2 -6.0 40 0.7 -0.0 28.3 41 1.6 -0.7 -93.0 40 0.4 0.3 -17.5 40 0.3 0.3 -0.6 39 0.4 -0.3 17.1 39 2.0 -0.0 -99.0 40 2 . 1 0 . 2 -99 . 0 40 0.2 0.2 5.4 41 0.1 -0.0 4.4 43 0.3 -0.0 11.4 44 0.1 -0.1 2.5 46 0.3 0.3 1.3 47 0.3 0.3 1.5 49 0.2 -0.2 -1.1 51 0.3 -0.2 9.5 53 0.1 0.0 4.8 56 0.2 0.2 2.4 58 0.1 -0. 1 3.3 60 0.6 -0.3 20.9 63 0.5 -0.1 21.9 65 0.1 -0.1 5.1 66 0.1 0.0 -1.5 68 0.1 -0.1 3.9 70 0.1 0.1 3.4 74 2.2 2.2 2.2 Client Wel 1 Name MD ft 4000 4100 4200 4300 4400 450O 4600 4700 48OO 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 65OO 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 : Point McIntyre : Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E CkL INC DIR ft deg deg 100 4.3 118.5 100 5.2 114.8 100 5.8 113.9 100 7.5 113.8 100 9.3 113.9 100 11.2 114.6 100 12.6 111.5 100 13.9 109.4 100 15.1 105.6 100 17.1 104.6 100 18.3 104.0 100 20.0 102.1 100 21.5 102.5 100 22.7 102.6 100 23.5 103.3 100 25.5 103.4 100 27.1 103.6 100 28.9 104.5 100 30.7 105.5 100 32.2 105.6 100 33.3 105.8 100 32.8 104.7 100 32.3 103.1 100 31.9 103.8 100 31.5 103.2 100 31.2 102.5 100 31.2 102.5 100 30.7 102.6 100' 30.6 103.3 100 30.9 103.8 100 30.7 104.6 100 31.6 104.1 100 32.8 103.7 100 32.4 105.0 100 31.8 !06.4 100 32.7 104.8 100 32.4 106.0 lO0 32.9 103.9 100 32.6 104.9 100 31.9 105.6 Baker Hughes INTEQ 1419 FSL, 809' FEL TVD VS I~AT ft ft ft 3998 78 8 4098 86 5 4197 95 1 4296 106 -4 4395 120 -10 4494 137 -17 4592 157 -25 4689 179 -33 4786 203 -41 4882 231 -48 4977 261 -55 5072 293 .-63 5165 329 -70 5258 366 -79 5350 405 -87 5441 446 -97 5530 490 -107 5619 536 -119 5705 586 -132 5791 637 -146 5875 690 -160 5959 744 -175 6043 797 -187 6127 850 -200 6213 902 -212 6298 954 -224 6384 1005 -235 6469 1056 -246 6555 1107 -257 6641 1158 -269 6727 1208 -282 6813 1259 -295 6897 1312 -308 6982 1365 -321 7066 1418 -335 7151 1470 -350 7235 1524 -364 7319 1577 -378 7404 1630 -391 7488 1683 -405 Page 2 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of MD DEP D'LEG BUILD TURN ft °/100 o/100 o/100 80 0.9 0.9 0.6 87 1.0 1.0 -3.7 96 0.6 0.6 -1..0 106 1.6 1.6 -0.0 120 1.8 1.8 0.1 136 1.9 1.9 0.7 155 1.5 1.4 -3. t 176 1.3 1.3 -2 . 1 200 1.6 1.3 -3.8 227 2.0 2.0 -1.0 256 1.2 1.2 -0.6 288 1.8 1.7 -1.9 323 1.5 1.5 0.4 360 1.2 1.2 0.1 398 0.8 0.8 0.7 438 2.0 2.0 0.1 481 1.6 1.6 0.1 527 1.9 1.8 1.0 575 1.9 1.8 1.0 625 1.4 1.4 0.1 677 1.1 1.1 0.2 730 0.8 -0.5 -1.1 782 1.0 -0.4 -1.6 834 0.6 -0.5 0.7 885 0.4 -0.3 -0.6 936 0.5 -0.3 -0.7 986 0.0 -0.0 0.0 1036 0.5 -0.5 0.1 1086 0.3 -0.1 0.7 1136 0.4 0.3 0.6 1185 0.4 -0.2 0.8 1235 0.9 0.9 -0.5 1287 1.2 1.2 -0.4 1339 0.8 -0.3 1.3 1390 1.0 -0.6 1.4 1442 1.2 0.9 -1.6 1494 0.7 -0.2 1.2 1546 1.2 0.5 -2.1 1598 0.6 -0.3 1.0 1650 0.8 -0.7 0.7 Client Well Name : Point McIntyre : Pl-13/H9 : Surface Location: : Sec. 16-T12N-R14E Baker Hughes INTEQ 1419 FSL, 809' FEL Page 3 of 3 Date 7 June 1993 Filename : 1227 Interpolated 100 ft of MD MD CkL INC DIR TVD VS LAT ft ft deg deg ft ft ft 8000 100 32.4 102.7 7573 1736 -418 8100 100 31.5 104.5 7658 1788 -431 8200 100 31.0 103.6 7743 1840 -443 8300 100 30.8 101.3 7829 1891 -454 8400 100 30.3 101.3 7915 1941 -464 8500 100 30.9 100.9 8001 1992 -474 8600 100 33.4 96.6 8086 2045 -482 8700 100 36.0 92.8 8168 2102 -487 8800 100 40.0 91.3 8247 2163 -489 8900 100 45.9 87.5 8320 2231 -488 9000 100 51.8 88.3 8386 2305 -485 9100 100 54.7 87.4 8445 2384 -482 9200 100 55.7 86.4 8502 2465 -478 9300 100 59.1 83.4 8556 2548 -470 9400 100 65.6 80.4 8'603 2634 -459 9500 100 71.6 80.3 8639 2724. -4.43 9600 100 74.6 80.9 8668 2816 -427 9700 100 77.2 82.8 8693 2910 -414 9800 100 81.3 81.9 8711 3005 -401 9900 100 83.0 82.5 8725 3102 -387 10000 100 83.9 82.2 8736 3198 -375 10100 100 86.6 83.6 8745 3296 -364 10195 95 91.2 83.2 8746 3388 -354 DEP D'LEG BUILD TURN o o o ft /100 /100 /100 1701 1.7 0.5 -3.0 1753 1.3 -0.9 1.9 1803 0.7 -0.5 -1.0 1853 1.2 -0.2 -2.3 1903 0.5 -0.5 0.0 1953 0.6 0.6 -0.4 2006 3.4 2.5 -4.3 2062 3.4 2.6 -3.8 2124 4.1 3.9 -1.5 2192 6.5 5.9 -3.8 2267 5.9 5.9 0.8 2347 3.0 2.9 -0.9 2429 1.3 1.0 -1.0 2513 4.2 3.4 -3.0 2600' 7.0 6.4 -3.0 2692 6.0 6.0 -0.1 2786 3.0 3.0 0.6 2882 3.2 2.6 2.0 2980 4.2 4.1 -1.0 3078 1.8 1.6 0.7 3176 1.0 0.9 -0.3 3275 3.0 2.7 1.4 3370 7.4 7.3 1.0 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 3388 ft 96.0° ERRV-SUN DRiLLiNG SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PT. MCINTYRE/P1-13/H9 500292237200 NORTH SLOPE COMPUTATION DATE: 6/11/93 PAGE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH ~1i~//,.% DATE OF SURVEY' 061193 - MWD SURVEY Q>~/~/~¢~JOB NUMBER' AK-MW-30037 KELLY BUSHING ELEV. = 60.10 FT. OPERATOR' ARCO ALASKA ZNC COURS COURSE DLS TOTAL ZNCLN DIRECTION RECTANGULAR COORDINATES VERT. DG NN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 10195 8745.95 8685.85 91 11 N 83.20 E .00 353.693 3369.89E 3386.57 10229 8745.13 8685.03 91 34 N 83.20 E 1.09 349.673 3403.64E 3419.95 10'265- 8743.98 8683.88 92 5 N 83.20 E 1.47 345.413 3439.37E 3455.28 10300 8742.69 8682.59 92 5 N 83.20 E .00 341.263 3474.10E 3489.62 10332 8741.62 8681.52 91 43 N 85.01 E 5.74 337.963 3506.06E 3521.26 10362 8740,93 8680,83 90 55 N 85,15 E 2,75 335,403 3535,84E 3550,78 10396 8740,4.0 8680,30 90 49 N 86,14 E 2,85 332,753 3570,61E 3585,28 104-28 8739,93 8679,83 90 51 N 85,62 E 1,65 330,483 3602,12E 36!6,54 10454 8739,44 8679,34 91 19 N 84,92 E 3,25 328.363 3627,80E 3642,01 10488 8738,62 8678,52 91 26 N 85,70 E 2,34 325,603 3661,43E 3675,35 10521 8737,83 8677,74 91 17 N'86.58 E 2,71 323.383 3694,33E 3708.01 10549 8737,18 8677,08 91 22 N 86,50 E ,43 321,693 3722,24E 3735,72 10584 8736,67 867'6,57 90 18 N 85,73 E 3,77 319,323 3757,15E 3770,37 10616 8736,49 8676,39 90 18 N 85,91 E ,56 316,983 3789,16E 3802,14 10645 8736,40 8676,30 90 3 N 86,17 E 1,25 314,983 3818,00E 3830,76 10679 8736,40 8676,30 89 56 N 87,42 E 3,69 313,08S 3852,01E 3864,54 10712 8736,55 8676,45 89 32 N 87,33 E 1,23 311.563 3885,22E 3897,56 10741 8736,83 8676,73 89 22 N 86,98 E 1,32 310,113 3914,28E 3926,44 10779 8737,67 8677,58 88 1 N 87,03 E 3,59 308,153 3951,82E 3963,74 10799 8738,36 8678,26 88 5 N 86,66 E 1,85 307,033 3972,04E 3983,83 10810 8738,71 8678,61 88 13 N 86,85 E 2,12 306,423 3982,86E 3994,58 10839 8739,59 8679,49 88 20 N 88,08 E 4,21 305,133 4012,13E 4023,68 10874 8740,58 8680,48 88 27 N 88,87 E 2,25 304,183 4047,59E 4058,98 10905 8741,41 8681,31 88 25 N 88,35 E 1,70 303,443 4078,24E 4089,50 10935 8742,25 8682,15 88 24 N 88,38 E ,'13 302,573 4108.59E 4119,71 11010 8744.32 8684.22 88 24 N 88.38 E .00 300.483 4182.56E 4193.34 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DZHENSZON MINIMUM CURVATURE METHOD, HORIZONTAL DISPLACEMENT = 4193.34 FEET AT SOUTH 85 DEG. 53 MIN. EAST AT MD = 11010 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 94.11 DEG. & Gas Cons. Anchorage t _RR'f-SUN DRiLLi/J~ ,.b~-ix,.VI,..;~b ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT, MCINTYRE/P1-13/H9 500292237200 NORTH SLOPE COMPUTATION DATE: 6/11/93 DATE OF SURVEY: 061193 JOB NUMBER: AK-MW-30037 KELLY BUSHING ELEV, = 60,10 OPERATOR: ARCO ALASKA ZNC FT, INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 10-195. 8745,95 8685,85 353,69 S 3369,89 E 1449.05 11010 8744,32 8684,22 300,48 S 4182.56 E 2265,68 816,63 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF 'THREE-DIMENSION MINIMUM CURVATURE METHOD. t _RR~-SUN DRILLING SER',,;ICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT, MCINTYRE/Pi-13/H9 500292237200 NORTH SLOPE COMPUTATION DATE: 6/11/93 DATE OF SURVEY' 061193 JOB NUMBER' AK-MW-30037 KELLY BUSHING ELEV. = 60.10 OPERATOR' ARCO ALASKA ZNC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10195. 8745,95 8685,85 353,69 S 3369,89 E 1449,05 -11010 8744,32 8684,22 300,48 S 4182.56 E 2265,68 816,63 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ORIGINAL FINAL WELL REPORT pRUDHOE BAY DRILLING GROUP POINT McINTYRE pl-13/H9 NORTH SLOPE, ALASKA JUNE 1993 TO 11 JUNE 1993 OCT 1 ,~ 1999 Alaska 0It & ~as ConS. Commission Anchorage co~t~ ~z~ ~ ~vtso~ o~ o~ o~zo~s , o~s ~o~ ~A~^~ cCURACY °~_~RREC iNCONSIST~m~" A D TO BE sHALL BE DESmE , 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: GARY HAMBURG JOHN MORRIS BILL STEVENS RALPh{ WINKELMAN APPROVED BY: LAf(~Y sHIELDS TABLE OF CONTENTS PAGE INTRODUCTION ' SUMMARY OF DATA ......................................... ~ METHODS OF: .... 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, STUMP ISLAND, HRZ,) LITHOLOGY ............................... 5 DRILL AND GAS DATA ...................... OIL AND GAS SHOWS ....................... 5 KUPARUK APPENDIX LITHOLOGY ............................... 6 DRILL AND GAS DATA ...................... 6 OIL AND GAS SHOWS ....................... 7 I. SAMPLE DISTRIBUTION II. SHOW REPORTS III. BIT RECORD IV. DAILY DRILLING SUMMARY V. INTEGRATED FORMATION LOG (MD), INTEGRATED FORMATION LOG (TVD), DRILLING DATA LOG, AND PRESSURE DATA LOG INTRODUCTION THE Pl-13/H9 WELL IS A HORIZONTAL PRODUCTION WELL, DRILLED ON THE 'PT. MCINTYRE P1 PAD, APPROXIMATELY 13 MILES NORTH WEST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 1419' FSL & 809' FEL, IN SECTION 16, T12N, R14E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE TO THE EAST AT: 1133' FSL & 1962' FEL, IN SECTION 15, T12N, R14EUM. THE MAIN OBJECTIVE OF THIS WELL WAS TO TEST AND PRODUCE THE KUPARUK RIVER L2A, ZONE BELOW THE GAS OIL CONTACT AND ABOVE THE OIL WATER CONTACT, WITH A HORIZONTAL HOLE AND APPROXIMATELY 700' OF PRODUCTION LINER, FOR MAXIMUM PRODUCTION POTENTIAL. LOGGING WAS DONE THROUGH THE USE OF MWD TOOLS. THE WELL PROGRAM CALLED FOR THE 7-5/8" CASING SHOE (TARGET #1) TO BE SET JUST ABOVE THE BASE OF THE L2A PRODUCTION ZONE AT APPROXIMATELY 8685' TVD SS, AND TO DRILL HORIZONTALLY TO THE EAST FROM THE 7-5/8" CASING SHOE TO FINAL WELL TD (TARGET #2) AT THE PROJECTED DEPTH OF 8671' TVD SS. THE PROJECTED COORDINATES OF TARGET #1 WERE: 1050' FSL & 2594' FEL, IN SECTION 15, T12N, R14E UM. THE PROPOSED TARGETS WERE REACHED BY DRILLING A DEVIATED HOLE; THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES. THE WELL PROGRAM WAS DESIGNED FOR THE KICK-OFF TO START AT ABOUT 3751' MD AND TO GRADUALLY BUILD HOLE ANGLE. AT ABOUT 9153' MD (8416' TVD SS), THE BUILD RATE WAS TO BE INCREASED, FROM 1.5 TO 4.0 DEGREES PER 100', TO ATTAIN A HOLE ANGLE OF 90 DEGREES APPROXIMATELY 150 FEET BEFORE TARGET #1. A FINAL WELL BORE ANGLE OF 91 TO 92 DEGREES WAS DESIRED FROM 7-5/8" CASING SHOE TO TD. THE PROGRAM CALLED FOR THE 7-5/8 INCH CASING SHOE TO BE SET JUST ABOVE THE BASE THE KUPARUK L2A ZONE, CHANGE OUT THE LOW SOLIDS LIGHTLY DISPERSED MUD SYSTEM~TO A XANVIS MUD SYSTEM, AND DRILL 6-3/4 INCH HOLE AT A 91 TO 92 DEGREE ANGLE, FROM TRUE VERTICAL, TO FINAL WELL TD. THE PROJECTED STRATIGRAPHIC SEQUENCE PENETRATED BY THIS HOLE INCLUDED THE PERMAFROST, T-8, WEST SAK, K-10, HRZ, KALUBIK, AND KUPARUK RIVER FORMATIONS WITH PROPOSED FINAL WELL T.D. IN THE KUPARUK RIVER L2A ZONE. -1- SUI~Y OF PERTINENT DATA WELL NAME: API NUMBER: OPERATOR: PARTNERS: CONTRACTOR: LOCATION: ELEVATION: CASING: DATE SPUDDED: DATE TOTAL DEPTH REACHED: FINAL TOTAL DEPTH: CONVENTIONAL CORES: FORMATION TESTS: HYDROCARBON SHOWS: COMPANY GEOLOGISTS: EXLOG GEOLOGISTS: FINAL WELL STATUS: POINT MCINTYRE Pl-13/H9 50-029-22372 PRUDHOE BAY DRILLING GROUP ARCO ALASKA, BP EXPLORATION, AND EXXON POOL ARCTIC ALASKA RIG #7, LAND 1419' FSL, 809' FEL SEC 16, T12N, R14E UMIAT MERIDIAN GROUND LEVEL 9' ABOVE SEA LEVEL ROTARY KELLY BUSHING 41' ABOVE GROUND LEVEL 13.50" AT 3570' RKB 9.875" AT 10275' RKB 4.50" AT TD 27 MAY 1993 10 JUNE 1993 11005' MD, 8745' TVD NONE WERE CUT NONE RUN AT THIS TIME SEE SHOW REPORTS - APPENDIX II KEVIN FRANK, ARCO ALASKA GARY HAMBURG, JOHN MORRIS, BILL STEVENS, RALPH WINKELMAN RUN 4.5" LINER TO TD -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. MWD GAMMA RAY AND RESISTIVITY WAS REQUESTED NOT TO BE PRESENTED ON THE MUD LOG FOR THIS WELL. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, AND SHOW QUALITY WHEN PRESENT. TOTAL GAS, RATE OF PENETRATION, AND CUTTINGS GAS 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. THIS DATA WAS PLOTTED ON THE LOGS AS WELL AS BEING DISPLAYED ON REMOTE TERMINALS. THREE H2S STATIONS WERE MONITORED AT ALL TIMES. COMM]JNICATION 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 6900' TO TD. TWO 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- FORMATION EVALUATION COMMENCED LOGGING AT 0825 HOURS, JUNE 1, 1993 AT 6900 FEET MD (6640 (FEET TVD) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE FROM K.B. WHICH WAS 50 FEET ABOVE SEA LEVEL. ALL DEPTHS ARE IN REFERENCE TO RIG KELLY BUSHING. FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE. WEST SAK INTERVAL LITHOLOGY THE WEST SAK INTERVAL 6920' - 8755' MD (6694' - 8212' TVD) CONSISTED OF PREDOMINATE MEDIUM TO DARK GRAY SILTSTONES AND VERY FINE TO FINE LIGHT GRAY TO OCCASSIONAL MULTICOLORED SANDS. GRAY TO GRAY BROWN CLAYS WERE COMMON THROUGHOUT THE SECTION AS WELL AS LOCAL COAL STRINGERS. TRACES OF QUARTZ AND CHERT FRAGMENTS ARE COMMON AND PYRITE IS ENCOUNTERED FREQUENTLY. APPEARANCES OF LIGHT GRAY TUFF, GRAY WHITE CHALKY TUFF, AND FOSSIL FRAGMENTS ARE COMMON. INOCERAMUS FRAGMENTS APPEARED AT ABOUT 7075' TVD AND ARE FREQUENT IN THE REMAINDER OF THE SECTION. THE SILTSTONES ARE MICRO MICACEOUS AND CARBONACEOUS WITH OCCASIONAL DEAD OIL / TAR SPOTS AND DARK BROWN OIL STAIN. THIS SECTION CAN BE CHARACTERIZED BY THE CONTINUAL PRESENCE OF DULL GREEN TO DULL YELLOW SAMPLE FLUORESCENCE WITH ACCOMPANYING WEAK DULL GREEN TO DULL YELLOW FLUORESCING CUTS. LIGHT STAW AND DARK BROWN VISIBLE CUTS OCCUR LOCALLY, BUT ARE NOT VISIBLE FOR MOST OF THE SECTION. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 10 TO 150 FEET PER HOUR IN THE WEST SAK WITH AN AVERAGE DRILL RATE OF ABOUT 50 FEET PER HOUR. THE AVERAGE DECREASED SLIGHTLY TO ABOUT 40 FEET PER HOUR TOWARD THE BOTTOM OF THE SECTION. FREQUENT SLIDING WAS DONE; THROUGHOUT THE SECTION, WHILE GRADUALLY BUILDING HOLE ANGLE FROM 30 DEGREES TO ABOUT 37 DEGREES AT THE BOTTOM OF THE SECTION. DITCH GAS RANGED FROM 10 TO 50 UNITS OVER THE INTERVAL WITH ONE ISOLATED PEAK OF 92 UNITS NEAR THE TOP OF THE SECTION. DITCH GAS ACTIVITY WAS RELATIVELY CONSTANT OVER THE WEST SAK INTERVAL. ALL THE COMPONENTS OF THE PARAFFIN SERIES WERE PRESENT OVER THE MAJORITY OF THE SECTION. RANGED FROM 780 PPM TO 5880 PPM WITH ONE ISOLATED PEAK OF 15.8K PPM NEAR THE TOP OF THE SECTION. C2 AND C3 APPEARED AT ABOUT 7085' MD (6800' TVD) AND RANGED FROM 70 TO 350 PPM OVER THE WEST SAK INTERVAL. IC4 AND NC4 APPEARED AT 7220' MD (6914' TVD) AND RANGED FROM 7 TO 60 PPM OVER THE REST OF THE SECTION. OIL AND GAS SHOWS THE LITHOLOGY WAS CHARACTERIZED BY INTERMITTENT PALE YELLOW TO DULL GOLD SAMPLE FLUORESCENCE WITH OCCASIONAL WEAK PALE YELLOW SOLVENT CUT FLUORESCENCE AND LOCAL FAINT MEDIUM TO DARK BROWN RESIDUAL STAIN NO PARTICULAR GAS SHOWS WERE RECORDED FOR THE WEST SAK INTERVAL. -4- HUE SHALE SECTION (K10, HRZ) LITHOLOGY- THE HUE SHALE, CONTAINING THE K-10, STUMP ISLAND SANDSTONE, AND HRZ, COMMENCED AT APPROXIMATELY 8755' MD (8212' TVD) AND CONTINUED DOWN TO THE BOTTOM OF THE SECTION AT ABOUT 9167' MD (7940' TVD). THE K-10 AND STUMP WERE CHARACTERIZED BY HARD AND WELL CEMENTED SILTSTONES AND SANDSTONES. THE SILTSTONE WAS MEDIUM GRAY TO GRAY BROWN, CARBONACEOUS, TUFFACEOUS, SANDY AND BECAME INCREASINGLY FINE SANDY WITH DEPTH. BY 8800' MD (8247' TVD) THE SILTSTONE GAVE WAY TO LIGHT TO MEDIUM BROWN, VERY FINE WELL CEMENTED SANDSTONE. THE SANDSTONE WAS TIGHT, SILTY, CALCAREOUS, AND WITH LOCAL COARSE ROUNDED QUARTZ FRAGMENTS. SANDSTONE - PREDOMINATED OVER THE REMAINDER OF THE SECTION WHICH MAY HAVE BEEN DUE TO HOLE SLOUGH. THE HRZ WAS ENCOUNTERED AT ABOUT 9062' MI) AND WAS CHARACTERIZED BY THE PRESENCE OF VERY DARK GRAY TO BLACK, PAPERY AND FISSILE, MICACEOUS, AND CARBONACEOUS SHALES. TRACES OF INOCERAMUS AND BROWNISH GRAY TO GRAY WHITE TUFF WAS PRESENT IN THE SAMPLES. DRILL RATE AND GAS DATA THE DRILL RATE WAS INCONSISTENT THROUGHOUT THE INTERVAL AS FREQUENT SLIDING WAS DONE TO INCREASE HOLE ANGLE. PENETRATION RATES VARIED FROM 8 TO 300 FEET PER HOUR WITH AN OVERALL AVERAGE OF ABOUT 60 TO 70 FEET PER HOUR. DITCH GAS RANGED FROM 9 TO 270 UNITS OVER THE SECTION WITH AN AVERAGE OF ABOUT 100 UNITS. C1 THROUGH C4 WAS PRESENT THROUGHOUT THIS INTERVAL. Cl RANGED FROM 873 PPM TO 3§K PPM WHILE C2 AND C3 VARIED FROM 19 TO 2900 PP~. IC4 AND NC4 RANGED FROM § TO 534 PPM. OIL AND GAS SHOWS SCATTERED MEDIUM TO DARK BROWN STAINING WAS OBSERVED ON THE CUTTINGS SAMPLES AND WAS ACCOMPANIED BY A STRONG PETROLEUM ODOR. BRIGHT YELLOW SAMPLE FLUORESCENCE WAS OBSERVED ALONG WITH MODERATE TO STRONG YELLOW TO YELLOW WHITE STREAMING CUT FLUORESCENCE. STRAW VISIBLE CUTS AND MEDIUM TO DARK BROWN RESIDUAL STAINING WAS NOTED. THE SAND APPEARED TO BE VERY WELL CEMENTED, SILTY AND TIGHT MAKING FOR POOR VISIBLE POROSITY. A SHOW RATING OF POOR TO FAIR WAS GIVEN THE INTERVAL DUE TO THE LACK OF APPARENT POROSITY. SEE SHOW REPORT #1 IN THE APPENDIX. -5- LITHOLO~Y KUPARUK SECTION THE KUPARUK SANDSTONE FOP~TION WAS ENCOUNTERED AT ABOUT 9167' bid (7940' TVD) AND CONTINUED ON TO WELL TD AT 11005' MD (8745' TVD). HOLE ANGLE WAS ABOUT 55 DEGREES, FROM TRUE VERTICAL, AND INCREASING RAPIDLY. THE TOP WAS NOTED BY THE PRESENCE OF FINE TO MEDIUM GRAIN, SUB ROUNDED, MODERATELY CEMENTED SANDSTONE. PREDOMINATE COLORS WERE CLEAR TO LIGHT GRAY AND OCASSIONAL MEDIUM BROWN. COMMON TO ABUNDANT GLAUCONITE WAS PRESENT IN THE SAND GRAINS. HARD TANNISH TO REDDISH BROWN SIDERITE WAS LOCALLY ABUNDANT IN THE KUPARUK. BROWN CEMENTING WAS MODERATE TO OCASSIONALLY WELL CEMENTED NEAR THE TOP'AND GAVE WAY TO BECOME FRIABLE TO MODERATELY CEMENTED NEAR WELL TD. GRAIN SIZE GRADUALLY DECREASED FROM FINE TO MEDIUM TO RANGE FROM VERY FINE AND QUARTZITIC SILTY NEAR WELL TD. THE PRESENCE OF WHITE TO LIGHT GRAY CHALKY CLAY WAS NOTED AT ABOUT 10620' MD AND CONTINUED TO INCREASE WITH DEPTH TO ABOUT 10710' W}IERE THE CLAY IN THE SAMPLE RANGED FROM 40 TO 50% OF THE SAMPLE UNTIL WELL TD. THE HIGHER CLAY CONTENT ~L4Y HAVE BEEN DUE TO HOLE SLOUGH. DRILL AND GAS DATA THE DRILL RATES, FROM 9167' TO 7-5/8" CASING POINT AT 10275', RANGED FROM 32 - 464 FEET PER HOUR WITH A GENERAL AVERAGE OF 150 FEET PER HOUR. PENETRATION RATES AFTER 7-5/8" CASING RANGED FROM 9 TO 144 FEET PER HOUR WITH AN AVERAGE OF ABOUT 50 FEET PER HOUR, USING A 6-3/4" BIT. DRILL RATES WERE RATTY OVER THE FIRST SECTION BUT WERE CONSISTENT FOR THE LAST SECTION TO WELL TD. DITCH GAS, OVER THE FIRST SECTION, VARIED FROM A LOW OF 32 TO HIGH OF 900 UNITS OF BACKGROUND GAS. THE TOP OF THE KUPARUK SAND WAS NOTED BY A DRAMATIC INCREASE IN BACKGROUND GAS FROM 40 UNITS TO A HIGH OF 355 UNITS. BACKGROUND GAS, OVER SECTION FROM 7-5/8" CASING SHOE TO TD RANGED FROM 12 TO 47 UNITs~HETHE DRILL RATE WAS CONSIDERABLY SLOWER AND XANVIS MUD WAS USED FOR THE HORIZONTAL SECTION. ALL COMPONENTS OF THE PARAFFIN SERIES WERE PRESENT THROUGHOUT THE SECTION. C1 VARIED FROM 2300 TO 90.3K PPM OVER THE FIRST SECTION AND RANGED FROM 504 TO 5600 PPM OVER THE SECOND SECTION. ALL COMPONENTS WERE PRESENT IN THE NORMAL ORDER, WITH THE LIGHTER METHANE (el) BEING RECORDED AT HIGHER VALUES THAN THE HEAVIER BUTANES (IC4 & NC4) WHICH WERE CONSISTENTLY THE LOWEST VALUES. THE SPECIFIC RANGES CAN BE FOUND IN SHOW REPORTS #Z AND #3 IN THE APPENDIX. -6- OIL AND GAS SHOWS THE SAND WAS SATURATED WITH MEDIUM TO LIGHT BROWN STAIN AND EXHIBITED AN EVEN YELLOW GOLD TO GOLD FLUORESCENCE. STRAW VISIBLE CUTS WERE PREDOMINATE AND MEDIUM BROWN RESIDUAL STAINING WAS PRESENT THROUGHOUT THE SECTION. AT ABOUT 9§10' MD, THE CUT FLUORESCENCE CHANGED FROM YELLOW TO A LIGHT BLUE INDICATING A LIGHTER OIL. A DRAMATIC INCREASE IN BACKGROUND GAS AND CHROMATOGRAPH VALUES WAS NOTED FOR THE ENTIRE SECTION DEPENDENT ON DRILL RATE, SHOW REPORTS #Z AND #3 WERE DONE TO COVER THE FIRST AND SECOND SECTIONS DRILLED AND MAY BE FOUND IN THE APPENDIX. =. APPENDIX I. SAMPLE DISTRIBUTION SAMPLE SHIPMENT FROM PBD PT. MclNTYRE Pl-13/H9 UNIT 242, POOL RIG 7 06/12/93 WET SAMPLES SETS A, B BOX NO. INTERVAL W1A, WlB W2A, W2B W3A, W3B 6900' - 8250' 8250' - 9810' 9810' - 11005' TOTAL 6 BOXES WET SAMPLES DRY SAMPLES SETS A, B, C, D, E (STATE OF AK SET) BOX NO. (SHIPPING) 1D 2D INTERVAL (CARD BOXES) A,B,C,D 6900' - 8800' E 6900' - 8520' E 8520' - 9660' A,B,C,D 8800' - 11005' E 9660' - 11005' TOTAL 2 BOXES DRY SAMPLES SAMPLEX TRAYS (ONE SET) S - 1 6900' - 11005' TOTAL 1 BOX SAMPLEX TRAYS TOTAL 9 BOXES SHIPPED TO: ARCO ALASKA INC. BAYVIEW GEOLOGIC FACILITY 619 SHIPCREEK ANCHORAGE, AK 99510-0360 ATTN: M.V. STANFORD TRANSPORTED TO "C" PAD TO BE SHIPPED OUT ON: FLIGHT # 145, ALASKA AIRLINES, 6/13/93 APPENDIX II. SHOW REPORTS OIL COMPANY: PRUDHOE BAY DRILLING DATE: 6/03/93 TIME: 20:01 - 6/04/93 - 18:41 SHOW REPORT # 1 WELL#: Pl-13/H9 SHOW INTERVAL: LOCATION: POINT MCINTYRE NORTH SLOPE, ALASKA 8755' TO 9062' (MD) 8212' TO 8423' (TVD) BIT SIZE: 9-7/8" l~D WEIGHT: 9.8 - 10.2 ppg WOB: 35 - 70 klb LOGGING COND: GOOD BIT TYPE: #4 SEC MS82F VISCOSITY: 49 - 56 RPM: 134 - 218 SLIDING #5 STC F15CL & HOURS: (#4) 12.6 FILTRATE: 4.6 - 5.2 PUMP PR: 3100 - 3300 ROTATING FEET: (#4) 503 BEFORE DURING AFTER ROP ft/hr 21 -74 8 -300 21 -47 EST. PORE PRES: 9.3 ppg PUMP SPM: 127 - 140 TOT GAS units 8 -18 9 -270 64 -70 C1 ppm 721 -1.6k 873 -35k 6.8k -7.7k C2 ppm 40 -105 54 -2.9k 731 -797 C3 ppm 17 -41 19 -1.8k 395 -421 iC4 0 -228 54 -57 nC4 pp,. 5 -10 5 -534 144 -154 CHL ppm 800 800 750 ----I I I I I I I I I I I I I I LITHOLOGY 50% SHALE 40% SILTSTONE, 10% SANDSTONE 10% SHALE, 10% SILTSTONE 80% SANDSTONE, TR - 10% COARSE SS 40% SHALE 40% SILTSTONE, 20% SANDSTONE OIL IN MUD: SHEEN ON MUD, BROWN OIL POPS SOLVENT CUT FLUOR: YELLOW TO YELLOW WHITE FLUOR: BRIGHT YELLOW INTENSITY: MODERATE TO STRONG UNWASHED CUTT FLUOR: BRIGHT YELLOW WASHED CUTT FLUOR: DULL GOLD-BRIGHT YELLOW TYPE & SPEED: MODERATE TO STRONG STREAMING & DIFFUSION NAT COLOR & RESIDUE: MEDIUM TO DARK BROWN STAIN: SCAT MEDIUM TO DARK BROWN VISUAL POROSITY: TIGHT TO TRACE, SILTY CUTTINGS DESCRIPTION: SS: LT - M BN, W CMT, VF GR, VW SRTD, SBRDD - RDD, SME W/ GCC BLK INCL, W CONS, SL - M CALC, LOC TR LSE PBLS, SLTY & ARC, SCAT M - DK BN STN, STRNG PET ODOR, 50 - 90% BRITE YEL - YEL WI{ SMPL FLOR, INST M - STRNG YEL - YEL WH STRMG CUT FLOR, STRAW VIS STRMG CUT, BRITE YEL RES FLOR - DK GLD RES FLOR W/ DEPTH, BN RES STN SLTST: M GY - GY BN, M - W CMT, SBBLKY & IRREG, CARB LITHS, NON CALC, IRREG VF SDY, PYR, SCAT YEL SMPL FLOR, M - DK BN STN, V SLOW YEL CUT FLOR, M - DK BN RES STN COMMENTS: K-10, STUMP ISLAND SS. GENERALLY TIGHT AND SILTY WITH POOR VISIBLE POROSITY. GO<)D BACKGROUND GAS INCREASE AND ALL HEAVIES PRESENT. RATING: POOR - FAIR ( 4 ) LOGGING GEOLOGIST: R. WINKELMAN, G. HAMBURG OIL COMPANY: PRUDHOE BAY DRILLING i I DATE: 6/04/93 TII~: 23:00 - 6/07/93 - 01:30 SHOW REPORT # 2 ?-~'r'::i'~'!! ..... ""::--~ ":: ?i,": ~. WELL#: Pl-13/H9 LOCATION: POINT MCINTYRE NORTH SLOPE, ALASKA SHOW INTERVAL: 9167' TO 10275' (MD) 8483' TO 8744' (TVD) BIT SIZE: 9-?/8" MUD WEIGHT: 10.0 - 10.3 ppg WOB: 35 - 80 klb LOGGING COND: GOOD BIT TYPE: #5 STC F15CL VISCOSITY: 47 - 49 #6 STC F15CL HOURS: (#5) 4.5 FILTRATE: 4.2 -4.6 RPM: 140 - 250 PUMP PR: 2900 - 3300 SLIDING & ROTATING FEET: (#5) 183 EST. PORE PRES: 9.4 ppg PUMP SPM: 132 - 142 BEFORE DURING @7-5/8" CSG PT ROP ft/hr 19 -27 16 -464 133 -146 TOT GAS units -35 I i Cll C2 ppml ppm -3.5k I 2.4k 1196 -138 26 32 -900 w----mm 2OO -398 2.3k- 90.3k 21.5k, -22k 221- 11.9k 1.7k C3 ppm 107 -138 134 -6.1k 1 .Ok it4 ppm 16 -20 21 -1.6k 140 -1.8kl-l.lk: -190 OIL IN MUD: SHEEN, MEDIUM - DARK BROWN SPOTS FLUOR: BRIGHT YELLOW UNWASHED CUTT FLUOR: BRIGHT YELLOW WASHED CUTT FLUOR: GOLD - YELLOW GOLD STAIN: MEDIUM - LIGHT BROWN nC4 CHL ppm ppm 49 -56 750 61 700 -1.5k -750 333 -399 700 LITHOLOGY 50% SHALE 30% SILTSTONE, 20% SANDSTONE 10% SHALE 10% SILTSTONE, 80% SANDSTONE 10% SHALE, 90% SANDSTONE SOLVENT CUT FLUOR: YELLOW, YELLOW BLUE INTENSITY: MODERATE TYPE & SPEED: INSTANT, SLOW - MODERATE STREAMING & DIFFUSION NAT COLOR & RESIDUE: MEDIUM - DARK BROWN VISUAL POROSITY: TRACE - FAIR CUTTINGS DESCRIPTION: SS: CLR - FRSTD WH - TRNSL LT GY, LT BN W/ DEPTH, VARYING F/ MW CMT - FRIA, OCC W CMT, F - MGR W/ COM CRS QTZ GRDG TO PRED VF - F GR W/ COM MGR W/ DEPTH, VF SS LOC GRDG QTZIC SLTST, SBRDD - SBANG BCMG SBRDD W/ DEPTN, MW - VW SRTD, NON CALC, GLAUC, LOC RD BN - TN BN SIDERITE, LOC WI{ VIT - CHLKY CLY IN MT× W/ DEPTH: DUL YEL GLD SMPL FLOR W/ DUL YEL CUT FLOR & M - DK BN VIS DOWN TO 9510'. OVER REST OF SECTION, SMPL STNG CHANGED FROM M - DK TO M - LT BN W/ EVEN YEL GLD - GLD SMPL FLOR. CUT FLOR CHANGED TO YEL BL - LT BL STRMG CUT W/ STRAW VIS CUTS & M BN RES STN. POROSITY INCR W/ DEPTH COMMENTS: KUPARUK SS. FAIR POROSITY AND GOOD STAINING WITH EVEN FLUORESCENCE. STRAW VISIBLE CUTS WITH MEDIUM BROWN RESIDUAL STAINING TENDS TO INDICATE LIGHTER OIL. RATING: GOOD ( 9 ) LOGGING GEOLOGIST: G. HAMBURG, B. STEVENS, R. WINKELMAN OIL COMPANY: PRUDHOE BAY DRILLING DATE: 6/09/93 - 6/10/93 TIME: 20:37 - 20:21 SHOW REPORT # 3 WELL#: Pl-13/H9 SHOW INTERVAL: LOCATION: POINT MCINTYRE NORTH SLOPE, ALASKA 10275' TO 11005' (MD) 8744' TO 8745' (TVD) BIT SIZE: 6-3/4" BIT TYPE: #7 SMITH F2DL VISCOSITY: 59 - 75 HOURS: 0 FEET: 0 MUD WEIGHT: 10.0 - 10.3 ppg WOB: 20 - 27 klb LOGGING COND: GOOD FILTRATE: 9.2 EST. PORE PRES: 9.4+ ppg RPM: 117 - 177 PUMP PR: 2900 - 3100 ROTATING & SLIDING PUMP SPM: 55 ~7-5/8" CSG PT. DURING @ TD 11005' ROP ft/hr 77 -87 9 -144 30 -46 TOT GAS units 2 -12 12 -47 19 -30 C1 ppm 183 -1.5k 504 -5.6k 2.5k -3.Ok C2 ppm 18 -160 65 -555 261 -320 C3 ppm 11 -91 44 -285 145 -173 iC4 ppm 0 -11 6 -31 18 -20 nC4 ppm 0 -30 16 -81 47 -56 CHL ppm 40k 40k 40k LITHOLOGY 10% SHALE 90% SANDSTONE 20% CLAY 80% SANDSTONE 40% CLAY 60% SANDSTONE OIL IN MUD: TRACE SHEEN FLUOR: FAINT YELLOW CAST UNWASHED CUTT FLUOR: YELLOW WASHED CUTT FLUOR: YELLOW - YELLOW GOLD STAIN: LIGHT - MEDIUM BROWN SOLVENT CUT FLUOR: LIGHT BLUE INTENSITY: WEAK - MODERATE TYPE & SPEED: SLOW - MODERATE STREAMING NAT COLOR & RESIDUE: LIGHT - MEDIUM BROWN VISUAL POROSITY: TRACE - FAIR CUTTINGS DESCRIPTION: SS: CLR - LT GY, EVEN M - LT BN STN ON SD GR, M CMT - FRIA, VF - F GR, VW SRTD, SBRDD, SL - M CALC, VF GRDG QTZIC SLTST IP, LOC ABNT SFT WH CHLKY - GCC VIT CLY IN SMPL BCMG LOC PRED IN SMPLS, COM GLAUC, LOC TR DK MNRL INCL, LOC TR CHT, EVEN LT - M BN STN & INTGRAN STN ON SD GR, TR - FR VIS POR, EVEN YEL GLD FLOR ON SD GR, WK - M LT BL STRMG CUT FLOR, WK - FR STRAW VIS CUT, M BN RES STN COMMENTS: KUPARUK SS, CLAY LOCALLY PREDOMINATE AFTER 1ST APPEARANCE. GOOD STAIN AND EVEN FLUORESCENCE ON SAND GRAINS RATING: GOOD ( 8 ) LOGGING GEOLOGIST: G. HAMBURG, R. WINKELMAN APPENDIX III. BIT RECORD BIT DATA RgCORD ' I ' * * * SI~E ~ DEPTH ~ ~, ~ SSS ~ ROP ~xlO00~ ' PRESS~ ~I:O' D; L:B: G :0: g ~ I I I I t I _..~ ..... ~ ........ ~ .......... ~ ...... ~ ........... ~ ....... ~ ....... ~ ..... ~ ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ........................ ---~ ..... ? ........ ~ .......... ~ ...... ? ..... , ..... ? ....... ~ ....... + ..... + ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ....................... ...~ ..... ~ ........ ~ .......... ~ ...... ~ ........... + ....... ? ....... ~ ..... b ....... + ..... + ..... + ...... ~ ......... + ....................... 31 ~ ISn~T~ ]~lCL ] 9,9]~A:,5798~ 5~42~ 2910~36,5] ~9,~', 40;~18~00~140/59~:4:8T:~:~:~ 'L~:~a .__~ ..... ? ........ ? .......... ~ ...... ~ ........... ? ....... ? ....... ? ..... ~ ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ....................... 4 ] 4 ;S~Og[~~, nS82~J4 .] 9,9 ',~A: ,5798~ 8ZSZ ', ~3~ ~19.0 ] 38,5 ', 40 ] 212 ~ 3200; 140/~93 ]Z:Z:~:~ :~:2/16:~O:Pg ...? ..... ? ........ ~ .......... ~ ...... ~ ........... + ....... ~ ....... ~ ..... + ....... ? ..... ~ ..... + ...... ? ......... ~ ....................... 5~ 5 ~S~[~ ~iSCL ~ 9,9]~A:,5798~ 89841 7~]14,~ ~,9~, 40',~18~200; l~6/5~9~2:~:~:A:~:~/16'8?:Pa _..+ ..... + ........ ~ .......... ~ ...... ~ ........... ~ ....... ~ ....... ~ ..... ~ ....... ~ ..... ? ..... ~ ...... ~ ......... ? ....................... 6 ~ ~ ~SMITR ~ F15CL ] 9,9 ]TFA = ,5~98 9741 ~ 534 ~ 5,6 ] 95,4 ~ 50 ] 248 ', 3400 ] 138/584 ~I:I:~T:A :g:2/16'NO:TD .._+ ..... ~ ........ ? .......... ~ ...... ~ .................... + ....... ~ ..... + ....... ~ ..... ~ ..... ~ ...... ~ ......... ~ ....................... ? ] 7 S~I~S F2X 6,~5~A: ,3~13 10~?~ 730 ~16,~ ~ 44,~ ~ ~? ] 174 ~ 3000 ~ 55/~4 ~Z:2:nA:A :4: I :~O:TO ...I ..... ~ I I I I .I I I ................. I ........................ I ......................... I ..... I ....... I ..... I .... I ......I ......... I ...... 8 ~gg~7 SMITH F2DL 6,?5~TFA = ,3313 I1005 ~IPgg TRIP ~g 4-1/2* LINGS ...~ ..... ? ........ + .......... ~ ...... ? ........... ? ....... ~ ....... + ..... ~ ....... + ..... ? ..... ? ...... ~ ......... ? ....................... APPENDIX IV. DAILY DRILLING SUMMARY DAILY DRILLING SUMMARY May 31, 1993 Rig up logging unit June 1, 1993 6900' - 7872' EXLOG came on line at 08:25 hours on June 1, 1993 while drilling 9-7/8" hole at 6900' MD (6640' TVD). The rig (Pool #7) was drilling with bit #3 (SMITH F1CL, 3x12,1X18), a mud motor, and an mwd tool in the string. A gradual build in angle to the east was being done with hole angle at about 30 degrees and azimuth running at about 104 degrees. A low solids, lightly dispersed mud system was being used and mud weight was 9.2 ppg. Encountered the top of the West Sak at about 6920' and drilled ahead, using the rotary table with occasional sliding, while penetrating sands near the top and then sandy siltstones and claystone. Increased mud weight to 9.4 ppg. Recorded connection gases ranged from 9 to 21 units, starting at about 7500', with 9.4 ppg mud. June 2, 1993 7872' - 8255' Drilled ahead to 8255', through claystone and sandy siltstone, sliding occasionally. Mud weight was increased to 9.5 ppg and the connection gases disappeared. Circulated a low - high vis sweep around at 8255' and pulled out of the hole. Bit #3 made 2910' in 36.5 hours. Layed down the mud motor and picked up a new one. Picked up MWD nuclear tools, new bit #4 (SECURITY MS82FJ4, 3x12, lx18), loaded nuclear sources, oriented ~ tool and run in the hole. Continued running in the hole with drill collars and one stand of heavy weight drill pipe where the ~ tool was tested. Run in the hole to the 10-3/4" casing shoe, at 3559', where the pipe was filled, the MWD tool was tested, and the top drive was serviced. Run in the hole to 6800' where an MWD M.A.D. pass was started. Continued M.A.D. Pass to 7509'. June 3, 1993 8255' - 8879' Continued M.A.D. Pass to bottom at 8255' and drilled ahead. Trip gas of 49 units was recorded. Drilled ahead using frequent sliding to build hole angle and while raising mud weight to 9.8 ppg. Connection gases ranged from 3 to 15 units while background gas varied from 15 to 50 units. Drilled into the K-10 at about 8755' ecountering hard silts and hard silty sandstones. Background gas started to increase, at about 8800', to range from 50 to 170 units. Hole angle at 8842' was 42.2 degrees from true vertical. -1- June 4, 1993 8879' - 9218' Drilled ahead through hard sandstone and sandy siltstone while background gas increased to range from a low of 50 units to a high of 285 units. Connection gases of 60 and 85 units above background were recorded. Continued to drill ahead to 8984' where drilling was stopped while mud weight was raised to 10.0 ppg. Pulled out of the hole with bit #4 which made 732' in 19.0 hours. Down loaded MWD tools and sources, picked up new bit #5 (SMITH FlCL, 3x12, lxlS), loaded MWD tools, loaded sources, and run in the hole to the shoe at 3559'. Filled the pipe, cut 78' of drilling line, tested MWD tool and serviced the rig. Continued to run in the hole, while reaming the last 90' to bottom. Drilled ahead at 8984' where a trip gas of 212 units was recorded. Lithology was predominately hard silty sandstone until the HRZ was drilled into at about 9062', where black carbonaceous shales were encountered. Background gas ranged from 40 to a maximum of 355 units and connection gases were not recorded. Circulated and conditioned the mud system before drilling into the Kuparuk at about 9167'. The lithology changed to friable and moderately cemented sandstones while background gas increased dramatically from an average of 45 units for the HRZ to a maximum of 355 units near the top of the Kuparuk. Continued drilling ahead to 9218'. Hole angle at 9212' was 55.8 degrees from true vertical. June 5, 1993 9218' - 9741' Continued drilling, predominately sliding, to 9289'. Re-logged the hole with the MWD, from 9189' to 9229', where the assembly attempted to sidetrack. Redrilled the hole, from 9229' to 9289', and circulated and conditioned the hole while raising the mud weight to 10.2 ppg. Drilled ahead using frequent sliding to 9679' where a 10 stand short trip was pulled. Background gas ranged from 70 to a maximum of 578 units before the short trip. The hole was in good shape with no problems and a short trip gas of 93 units was recorded while drilling ahead. Drilled ahead to 9741' where it was decided to pull out of the hole. Bottoms up was circulated and a slug was pumped before pulling off bottom. Bit #5 made 757' in 14.3 hours. Hole angle at 9588' had increased to 74.3 degrees from true vertical. -2- June 6, 1993 9741' - 10228' Continued to pull out of the hole. Unloaded MWD sources and down loaded the tools. Serviced the wear bushing and picked up new bit #6 (SMITH F15CL, 3x12, lxlS). Programed the MWD tool, loaded the sources, and run in the hole 35 stands to casing shoe where the pipe was filled and the MWD tool was checked while the rig was serviced. Run in the hole to 8827' and filled the pipe. Run in the hole to 9574 where circulation was broke before surveying and reaming to bottom. A trip gas of 205 units was recorded. Drilled ahead to 9792' where the geolograph line broke and repairs were necessary. Relogged MWD tool for 15' until the geolograph line caught on the wind wall and broke again. Repaired line and continued to drill ahead to 10228'. Ditch gas ranged from 70 to a maximum of 901 units while drilling in sand with a mud weight of 10.2 to 10.3 ppg. Hole angle at 10,198' had increased to 91.2 degrees from true vertical. June 7, 1993 10228' - 10275' Continued to drill ahead to 7-5/8" casing point at 10,275'. Circulated sweep while re-logging Teleco MWD tool from 9912' - 10037'. Bit #6 made 534 feet in 5.6 hours. A short trip of 20 stands was pulled and no problems were encountered. Short trip gas of 58 units was recorded while circulating a sweep around. Pumped dry job and pulled out of hole to heavy weight drill pipe. Rigged up to lay down and laid down 5" heavy weight pipe. Removed sources, down loaded the MWD tool, laid down the MW]), and laid down the mud motor. Changed the top pipe rams to 7-5/8", rigged up to run 7-5/8" casing, and held a pre-job safety meeting. Run 7-5/8" float shoe, collar, and one joint. Rigged up circulating hose on top drive and ran 7-5/8" casing. Circulated 7-5/8" casing at 10-1/2" casing shoe and continued to run casing. June 8, 1993 10275' Circulated casing at 7000' and continued to run 7-5/8" into the hole, to bottom at 10,275', with no problems. Laid down circulating head and rigged up cementing equipment. Casing was circulated and a trip gas of 99 units was recorded. Switched to Halliburton pumps, pumped 5 barrels of water, tested lines to 3500 psi, and cemented as per well plan. Displaced with rig pumps and it took 4682 strokes to bump the plug. Pressured up to 3000 psi before rigging down the cement head. Removed the choke hose and set the slips. Cut 7-5/8" casing, dressed the stump, set pack-off, and tested to 3000 psi. Nippled up B.O.P.'s and changed top pipe rams to 3-1/2". Picked up the test joint and test plug to test the stack. Dressed the top drive for 3-1/2" drill pipe, cut 120' of drilling line, and began to pick up BHA. -3- June 9, 1993 10275' - 10430' Completed picking up BHA, new bit #7 (SMITH F2DL, 3x12) and tested the motor and MWD tool. Picked up 3-1/2" drill pipe and stood 8 stands back. Changed bottom rams to 3-1/2" and picked up 24 joints of 3-1/2" from the pipe shed. Continued to run in the hole to 10115'. Tested 7-5/8" casing to 3000 psi and began drilling cement and float equipment. The float collar was tagged at 10164'. Circulated and cleaned the hole before cleaning the pits. Displaced the hole with Flo-Pro (Xanvis) mud and re-logged the hole from 10239' to 10290', with the MWD tool. Drilled ahead from 10,290' to 10430'. Background gas ran from 20 - 50 units while drilling through fine sand with 10.1 - 10.3 ppg mud in the hole. June 10, 1993 10430' - 11005' Drilled ahead, with occasional sliding through fine sand and clay, to final well TD at 11005'. Bit #7 made 730 feet in 16.5 hours. Circulated bottoms up and pumped the slug before tripping out of the hole. June 11, 1993 11005' Continued to trip out of the hole while measuring drill pipe. Laid down the motor, the MWD, and the bit. Picked up a hole opener with re-run bit #7 and run in the hole to 7-5/8" casing shoe at 10,275'. Filled the pipe, serviced the rig, and serviced the top drive. Washed and reamed to bottom at 11005' with no problems and no hole fill. Circulated and conditioned mud at bottom and maximum trip gas was 10 units. Pulled a short trip back to the shoe with no problems and ran back to botttom. Circulated and conditioned the mud system on bottom and maximum short trip gas was 6 units. Spotted a 3 ppb Xanvis pill with fluid loss additives on bottom before pulling out to run 4-1/2" liner. Exlog was released at the start of the trip out of the hole. -4- ARCO Alaska, Inc. isburne/Point McIntyre Enginee. Date: Subject: To' August 19, 1993 Transmittal #350 ARCO Alaska Inc. Bob Crandall AOGCC 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 Pl-Gl-'Perforating Record Run # 1 Run Date 7/4/93 Company Schlumberger P1-04 'Z-Densitog Compensated Neutron -GR P1-04'Dual Laterolog, GR / SP ,k~ P1-04-- Borehole Profile P1-04-Sub-Sea Vertical Depth (Single Shot Data) P1-04-Cement Bond Log -~ P1-04-'Cement Evaluation Log (CET) [P1-04--Gyro Continuous Survey (GCT) 5/22/93 5/22/93 5/22/93 5/22/93 6/12/93 6/12/93 7/28/93 Altas Atlas Atlas Atlas Schlumberger Schlumberger 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 7/11/93 8/12/93 8/12/93 8/12/93 Atlas Schlumberger Schlumberger Schlumberger P1-13 P1-13 Pl-13 Pl-13 Pl-13 Pl-13 Pl-13 '1Neutron Poro, Density Poro, GR -MD .¥V% 5-7 -Neutron Poro, Density Poro, GR -TVD OA'S" 5-7 --Dual Prop Resis, GR -MD 2-+5 5-7 WDual Prop Resis, GR -TVD 2~" 5-7 6/2-6/93 6/2-6/93 6/2-6/93 6/2-6/93 -Dens Poro, Neu Poro, Dual Prop Resis, GR-MD 5-724'$ 6/2-6/93 ~'Dens Poro, Neu Poro, Dual Prop Resis, GR -TVD 5-7 2..~"6/2-6/93 wBulk Density, Gamma Ray -MD ~" 5-7 6/2-6/93 BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes BakerHughes qb'ltv Pl-14-'Engineering Parameters MD P1-14" Pressure Data Log P1-14--Formation Evaluation MD Pl-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 Pl-16" Engineering Parameters MD P1-16 '~ Pressure Data Log [Pl-16~Formation Evaluation MD ~Pl-16fFormation Evaluation TVD Run-# Run Date - 3/19-28/93 - 3/19-28/93 - 3/19-28/93 - 3/19-28/93 Pl-17- Bulk Density -Gamma Ray -MD 5J' Pl-17--Dual Prop Resis -GR-MD 2'r5" P1-17 .-'Dual Prop Resis -GR -TVD .24% * P1-17.-'Dens Poro, Neutron Poro -GR -MD 2..'k'~~ P1-17., Dens Poro, Neutron Poro -GR -TVD 1.'V5 u 5,5RR 5,5RR 5,5RR 5,5RR 5,5RR Pl-17--E~sPoro, NeuPoro, DualProp, Resis-GR-M-D 2~" 5,5RR P1-17- E~sPoro, NeuPoro, DualProp, ResisGR-TVD 2+~" 5¢T<R 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 Exlog Exlog BakerHughes BakerHughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Diskette/Tape (w/verification) Well Title Run # q%-b~/P1-04 \P1-04 -~_.~~1-13 q~'%~ P1-16 Final MWD Survey blS~- DLL/CN/ZDL/GR in LDWG Format Final MWD Survey bt~:2~ Dual Prop Resis, Neutron, Density, GR~ q%..Sk P1-17 Dual Prop Resis, Neu, Dens, GR-Depth Shifted 5,SRR 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, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN 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: 16 JUNE, 1993 AIRBILL: AIRLAND 646204 AFT#: 03-06-1 6-92 CHARGE CODE: 2C0036 OPERATOR: ARCO SAMPLE TYPE: STATE DRIES SAMPLES SENT: STATE DRY SAMPLES: NAME: PI -13 ~---'~ ~--'7('~ NUMBER OF BOXES: 3 P1-13 Box #1 6900'-8520' Box #2 8520'-9660' Box #3 9660'-11005' l~oN~i RBEY~EIDp;nOFPr~JESkslAMPLES PLEAS ~A SIGNED COPY OF THIS TRANSMITTAL T~ !! ~O~, i E~oL~SEIKOoAoL,306~0Ni ~. F A C i L~~i T y / RECEIVED ARCO Alaska, Inc. is a Subsidiary of Atlantic Richlield Company A~3B-6003.C MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to; David W. Johnst_~,~ date: Commissione~',,,~ file: June 2, 1993 052793-1 .doc thru: Blair E Wondzell subject: Petr Insp Supervisor from: ~oo~n Spaulding Petr Inspector Diverter Function Test- Pool 7 ARCO/PBU/PM 1-13 PTD 93-74 Thursday, May, 27. 1993: ! traveled to ARCO PBU. Pt. Mclntyre to witness a diverter function test on Pool 7. drilling PM 1-13. All valves and accumulator functioned properly. The diverter lines were laid out to take full advantage of the wind direction. There is still a quite a bit of pre start up construction of the pad. The rig had good emergency access and for all the activity, the pad was well organized. Summary: I witnessed the diverter function test on Pool 7; no failures. attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems inspe~ion Report Orlg Contractor: Operator: Well Nome: Location: Sec, Oper~ttion: Development ~'"'- Exploratory: Oper. Rep.: /~ ~-¢-¢¢,¢,./, ~ o MISC. INSPECTIONS: LOcation Gen.' J Well Sign: Housekeeping' ~-- .(Gen.) Drlg. Rig: Reserve Pit: ~..--~ Flare Pit: /v'//, DIVERTER SYSTEM INSPECTION: ACCUMULATOR SYSTEM: Systems Pressure: ',~ [¢ O psig Pressure After CIosure: /~ G"¥.~ . psig ZOO psi Attained After Closure:~min. ,~¢ ¢ sec. Systems Pressure Attained: cC, min. o.~.% sec. Nitrogen Bottles: ~ Diverter Size: /O in. psig Divert V~lve(s) Full Opening: ?E ~ V~lve(s) Auto & Simult~eous: -,.jcl%, MUD SYSTEM INSPECTION: Light AIQrm Vent Line(s) Size: /~ ' in. Trip Tank: 'J .... Vent Line(s) Length: . ~]4) ft. Mud Pits: :.--" line(s) Bifurcated: /,,/~, Flow Monitor: ,,.,- Line(s) Down Wind: line(s) Anchored: ' ,,/~,.~, GAS DETECTORS: Light Aletrm Turns Targeted / Long Radius: :,¢/Z,~¢i-~ ii:i'.~_ ~' s, Methane ' Hydrogen Sulfide: i ...... " /¢ .. ¥£ Distribution orig. - Well File c- 0poi/Rep c- Database c- Trip Rpt File c. Inspector F1-022 MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to; David W. Johnsto_~.c-'~. date: Commissioner ~ file: thru: Blair E Wondzell~J~(~,/~_~ sub)ect: Petr Insp Supervisor from.'~hohn Spaulding Petr Inspector June 2, 1993 052993.doc BOP Test - Pool 7 ARCO Pt. Mctntyre P1-13 Prudhoe Bay Unit PTD 93-74 Saturday, May. '~'.,~, ~1 "'~"u=o: ....... I ' -" ._ ,,,,-,,., .~, PBU to witness '~'"'~' uave~ea [o ,",m~,~, ~t.. Mclntyre PI-I" on Pool 7. All operations of the test were well coordinated by a ve.ry well trained crew. The rig was quite clean and well laid out for any emergency considerations. Summary: Tested BOPE on Pool 7, test time 3 1/2 hours, zero failures. a~achments · . STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Drlg Contractor:. ~ Rig No. ~ Pm # ~,~ ~4// DATE: ~-_ ~.c] _ ~ ._~ , _ - Rig Ph.# ~ ~- ~- '¥'~ / .~ Opemtoc /-~£~--(2 . Rep. ~_'-~/,,~ ~f,/ ~_7,~-Zc~ . WellName: ~/-~/'~ Rep. ~/'~,~,~u/ Casing Size: le ~/¢" ~et~ ~5~-~Feat location:Sec. //~ T. ~/Z~R. l~/~ Merd. ?/.: Test: Initial Weekly ~ , Other ............... ; ....................................... . .............................................. .-..~.:.:;:;....:~: .................... ~.;.:.~;:~<~.=~.;i~i;i:.~.~i~::.~.'::~:-.~;..:--::;.~ ........... :~=~;~.:*:.~:';;:;i."~ ......... .~.~!~'~' ~~.'::--.*~:~.::::~:~.~ .................. ----'-*'": ...... ~'--'.'~:~.;;;:.--;~:.-':~-:-:'::': .......... ::::::::::::::::::::::::~.::::':'.'-:-;-~:'~:;.:::~**'-:::.'r~$T: D~TA~:~..~.~`~.*~'.*.~:~.`~'~:~.¥::~.`.~:~...°~~~~~!.`*~'~*~*``'~.*?.~.''* ..................... ~..-..:' ~':....'.'~.-::'~::r<~.:.~:~:~:::.':.~:::.-'.:x:...::.:.:::~:. ...................................... -.:.:*- .-: .*-*:*:*---*.-:.-*-'*.":-:.:-::.. ....... ::::: ::::: :::::: ::: ::::::: ::::::::::: : : :: : : :::::. .............................................. --:!:'*:.'-.'::~::::*.'-::a-~,--' '- ~.:.~.'.:.*::-'-.*.::.:~:.::*:-:':-'-:..*:..-.-.-.~:.:-:~':*:'-*'*:-*.'.:'~ ~*.-*~.~.:*~.'*.:-' . -:-:.'.*:.-': ......... :~-'~*-:-..::-:.-*:...~*' ..................................................................... Te~ MI5¢. INSPECTIONS: FLOOR SAFETY VALVF.~:, Guan. Pressure P/F I.ncalion Gen.: '~' Well Sign /-~-~** Upper Kelly / ,~, o ~ Housekeeping: ~-~ (Gen) Dd. ~ '-~ Lower Kelly Reserve Pit /~/~, Ball Type Inside BOP / Test BOP STACK: Qua. Pressure ~P~///~ CHOKE MANIFOLD: Ann. Preventer /.-" ~- No. Velves Pipe Rams ~ No. flanges ~ Blind Rams Manuel Chokes Chk/Ln Valves I-lydmulic Chokes HCR Valves ~'~ K~II Une Valves ACCUMULATOR SYSTEM: Check Valve System Pressure ~/~ © ! Pressure After Closure / ~:?~ ~;~I /-~ MUD SYSTEM: Light Alarm 200 psi Attained After Closure minutes ~,/ , Trip Tank -~ ~-' Sys~m Pressure Attained ~,. minutes Pit Level Indicators ~--~- ~ Blind Switch Covers: Master:..,~ Remote: Flow Indicator .~ ~ Nitgn. Btl's: ~ z:~ Gas Detectors ~-- ' ~-~ ~--~ *~d¢l Psig. . ............. . . ~ ......................... ....-........,-...~...-......... . · . .-.:....,.....:,:...:.:.:~.. :.: .... ... ,, ..... ;.: .... ..:::::.-~...~..:.~:.:,--...~ ~.-- . .-... ,.,- .-.-.;..:..-- ...~.> -.. .... i::'. "~':.'.'.~" ........... ~;~;;~¥~!~:~:~i~:~;~:~`~i~i~i~i~!~;:i~:~:~i~:::~;~::~[`~i~i~i~:~:~::~;~¢~;~;~;~;~!~i~: ..-..'. ~ .:.. ~: .~" *. "'d'~";l'l'*'~'""'"""'"";';-'"'l"'''"'"'""*""'"'''" ...... '' ' ""11" '*'' ' ' "'' .... I"'" '*' ............................. T ...... I] ..... Illll'l'"'lllll ........ Number of Failures ~ Test T~rne ~ Hours Number of valves tested ~/ Repair or Replacement of Faded Equipment shall be made within . days. Notify the Inspector on duty and follow with Written or Faxed varffication to the AOGCC Commission Office et: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not ret~med by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - OperJRig c - Database c - Trip Rpt File c - Inspector STATE WITNE~ REQUIRED? YES / _ NO 24 HOUR NO~CE GIVEN YES ~ NO · Waived By:. W~tnessed By:. Fi-O21L. XLT Rev. 1/93 ALASKA OIL AND GAS CONSERVATION COMMISSION May 25, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Prudhoe Bay Unit Pl-13 ARCO Alaska, Inc. Permit No: 93-74 Sur. Loc. 1419'NSL, 809'WEL, Sec. 16, T12N, R14E, UM Btmhole Loc. l133'NSL, 1962'WEL, Sec. 15, T12N, R14E, UM Dear Mr. Zanghi: 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. 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 a. Type of work Drill [] Redrilll-I Re-Entry [] Deepen 2. Name of Operator ARCO Alaska, Inc. 3. Address lb. Type of well. Exploratory[] Stratigraphic Test [] Service [] P, O. Box 196612. Anchorage. Alaska 99519-6612 4. Location of well at surface 1419'NSL, 809' WEL, SEC. 16, T12N, R14E At top of productive interval 1050'NSL, 2594' EWL, SEC. 15, T12N, R14E At total depth 1133'NSL, 1962' WEL, SEC. 15, T12N, R14E 12. Distance to nearest property line ADL 34624-1962' fe et [13. Distanceto nearest ~l~t P1-12-14'@ 50'MD 6. To be completed for deviated wells (ickoff depth 370ofeet Maximum hole angle Development Oil [] Development Gas [] Single Zone [] Multiple Zone [] 5. Datum Elevation (DF or KB) KBE=50'f e e t 6. Property Designation ADL 28297 ?. Unit or property Name Prudhoe Bay Unit 8. Well number P1-13 9. Approximate spud date 6/1/93 4. Number of acres in property 256O 10. Field and Pool Point Mclntyre 1 1. 'l"ype Bond(see 20 AAC 25.025) Number U-630610 Amount $200,000.00 5. Proposed depth (M3 and TVD) 10956' MD/8722' TVDfeet 17. Anticipated pressure (se~ 2o AAC 25.p35 ',e)',2)) Maximum surface 3330psig At total depth (TVD) 8800'/4390Psig 18. Casing program size Hole Casing 3O" 2O" 13-1/2" 10-3/4" 9- 7/8" 7- 5/8, 6-3/4" 4-1/2" Specifications Weight Grade I Coupling 91.5tl H-40 I Weld I 45.5# INT-80j BTC 29. 7# I NT95HSI NSCC Length Setting Depth Top MD I TVD Surface 41 '1 41' MD Surface 80' 41' 3551' 41' 10140' 8637' 1O227' 1O956' Bottom TVD 80' 3550' 8735' 8722' Quantity of cement (include stage data) 281 cu fl Arcitcset 2221 cuft "F"/406 cuft "G"/235 cuft 897 cuft Class "G" Not cemented 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural . Conductor Surface Intermediate t Production Liner Perforation depth: measured true vertical 20. Attachmenis Filing fee [] feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] /14 Drilling fluid program [] Time vs depth plot [] Refraction analysisE] Seabed report[] 20 AAC 25.050 requirements[] 1. I hereby certify, that the foregoing is true and correct to the best of my knowledge I Signed - '. ~.. '-'7'.~.,- i ,_ ' Title. Drilling EnDineer Supervisor Date- t Commission Use Only Permit Number IAPI number IApproval date tSee cover letter 7'-/ 150-o -?- zz_ I ,~--"-~...~7-~ ,~...~ Ifor other requirements Conditions of approval Samples required [] Yes ~No Mud log required ~Yes :~ No Hydrogen sulfide measures [] Yes 1;D No Directional survey required ~ Yes [] NO Required working pressure for BOPE []2M; [-13M; J~5M; [-I10M; E]15M; Other: by order of Approved by Original S;qned l~y Commissioner me commission Date~-~-E Form 10-401 Rev. 12-1-1~,~vid W. Johnston Submi' in t-riplica! WELL PLAN SUMMARY WELL NAME: Pl-13/H9 WELL TYPE: Horizontal, slimhole, Iongstring AFE NUMBER: AFC #2C0036 INITIAL COMPLETION- Producer SURFACE LOCATION: 1419' FSL,809' FEL, SEC 16, T12N, R14E X=674247 Y=5994547 TARGET LOCATION: 1050' FSL,2594' FWL, SEC 15, T12N, R14E X=677659 Y=5994260 BOTTOM HOLE LOCATION: 1133' FSL, 1962' FEL, SEC 15, T12N, R14E X=678380 Y=5994360 TOTAL DEPTH- 10956' md/8722' tvd brt CONTRACTOR: POOL 7 ELEVATION' RTE-SS' 50' RTE-GL' 41' GL-SS' 9' DIRECTIONAL INFORMATION: Kick off at 3751' tvdss, build 1.5°/100ft, to 32° at 5914' tvdss. Start the azimuth change from 103° to 83° at 8590' tvdss. Finish the azimuth change by the top of Kuparuk, 8416' tvdss. Start building angle at 4°/100ft at the top of Kuparuk, 8416' tvdss. Attain approximately 90° at the base of the L2A approximatley 150' before the start of the target #1. It is desirable to tag the base of the L2A to maximize the standoff from the GOC. The 150' of hole before the start of the target will allow some directional adjustments to meet this goal. After setting 7-5/8" casing at the start of the target #1, approximately 2-5" above the base of the L2A, the production hole will be drilled at about a 91° angle to the target point #2, to TD the well about 10'-20' above the base of the L2A. MUD PROGRAM- Surface hole = typical spud mud. Intermediate hole (9-7/8")=3% KCL. Production hole (6-3/4")= Xanvis. MARKERS- NUDGE (CLOSE APPROACH) END NUDGE 10-3/4" CASING T8 START BUILD - 1.5°/100FT END BUILD - 32° HOLE ANGLE WEST SAK START CURVE - 4.5°/100FT K-10 STUMP ISLAND (HIGHEST EXPECTED TOP) K-5/HRZ START BUILD - 4°/100' END CURVE - 83° AZIMUTH KUPARUK (U3)/KALUBIK GOC BASE L2A (TOP L1) MEM P1-13 TVDss MD 462 513 1249 1301 35OO 3551 3528 358O 3699 3751 5748 5914 6605 6929 8006 8590 8186 8813 8200 8832 8361 9O63 8416 9153 8416 9153 8416 9153 8582 9496 869O 1OO77 Page 4 5/10/93 TARGET #1 (KUPARUK)(7-5/8' ,..,~SING) 8685 TARGET #2 (KUPARUK)/TD(4-1/2"LINER) 8671 10227 1O956 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top 30" 20" 91.5 H-40 WELD 80 GL 13-1/2" 10-3/4" 45.5# NT-80 BTC 3510 41 9-7/8" 7-5/8" 29.7# NT95HS NSCC 10186 41 6-3/4" 4-1/2"slotted 12.6 L-80 TDS 816 1 01 40 Tbg Wt Grade Coupling Length Top 4-1/2" 12.6# L-80 TDS 9134 41 Btm 80 " 3551 (3500tvdss) 1O227 1O956 Btm 9175 LOGGING PROGRAM: Open Hole Logs: Surface NONE Final Mud Loas: Top of West Sak to TD. MWD: ~R/Resistivity/Neutron/Density. Top of West Sak to TD Wireline: None (hole angle too high) Cased Hole Logs: None COMPLETION' 4-1/2" L-80 tubing with 5 GLM's (4-1/2" x 1") above top packer. Tubing retrievable sub-surface saftey valve. Sliding sleeve will be installed for future downhole separator application. MEM P1-13 Page 5 5/10/93 P1-13 MUD PROGRAM SURFACE MUD PROPERTIES: TYPICAL Density Marsh Yield (ppg) Viscosity Point Spud 8.7 300 40-60 TD 9.5 100 20-40 Surface 10 sec 10 min pH Fluid gel gel Loss 30-60 60-80 9-10 15-25 15-20 20-30 9-10 15-25 INTERMEDIATE (9-7/8") HOLE MUD PROPERTIES: 3% KCL Density PV YP 10 sec 10 min (ppg) gel gel 1 0-3/4" 9.5 8-15 25-35 5-15 10-20 SHOE pH 9-10 TD 10.0 15-30 25-35 8-12 <25 9-9.5 NOTE: AD,,IU,~T YP FOR HOLE CLEANING. MAINTAIN MINIMI, IM YP 2~i FROM ,~(JRFACE CASING SHOE TO TD. Fluid Loss 10-15 4-15 <15 HTHP PRODUCTION (6-3/4") HOLE MUD PROPERTIES: XANVIS Density PV YP 10 sec 10 min (ppg) gel gel 10-3/4" 10.0 8-15 15-20 5-15 10-20 SHOE pH Fluid Loss 9-10 5-10 APl MEM P1-13 Page 7 5/10/93 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P1-13 Cement Volumes Surface String 3551 10 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1024 (2221 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 2 50 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Intermediate String 10227 7 5/8 29.7 8153 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 7 73 # bbls I 60 ( 0 Cu. Ft.) (897 Cu. Ft.) CASING DESIGN SPECIFICATIONS SURFACE CASING 10-3/4" 45.5#/FT, NT80LHE, BTC BURST COLLAPSE PBYS # TJYS # NT80LH E 551 0 3390 1040000 1063000 I · w 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 = 2.16 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 = 1.96 Tension Tension is based on full string weight in mud. A maximum casing length of 5000' is assumed, and a vertical hole is assumed (for worst case scenario)' Tension = 45.5 * 5000 * .85 = 193375 # Saftey Factor (pipe body) = 5.38 Saftey Factor (joint) = 5.50 PRODUCTION CASING 7-5/8", 29.7 #/FT, NT95HS, NSCC BURST COLLAPSE PBYS # TJYS # NT95HS 81 80 7200 811000 81 3000 I . 1 1 Burst Pressure The worst case scenario is a tubing leak at the surface with no annulus backup. Maximum shut-in tubing pressure= burst pressure= 4360 - (.15 * 8810') = 3038 psi Saftey Factor = 2.69 Collapse Pressure Assume the casing is evacuated to gas lift gas with 10.5 ppg mud in the annulus: Collapse pressure= 8750"10.5'.052 = 4777 psi Saftey Factor = 1.51 Tension Based on a full string weight in 10 ppg mud. A maximum casing length of 16000' is assumed as a worst case scenario: Tension = 29.7'16000'.85= 403920 #. Saftey Factor (pipe) = 2.01 Saftey Factor (joint) = 2.01 . . . . . . . . . 10. 11. 12. P1-13/H9 Operations Summary MIRU drilling rig. Spud well and drill 13-1/2" hole to 3551' md/3550' tvd building angle to 32 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. Drill 9-7/8" hole to 10227' md, 8685' tvd, estimated hole angle 91°, estimated 5' above base of L2A sand. The wellbore will tag the base of the L2A sand, turn up, and TD this section in the L2A. Set 7 5/8" carbon casing and cement same. Test casing to 3500 psi for 30 minutes. Drill out shoe joints. Change mud over to Xanvis mud. Drill 6-3/4" hole to TD 10956'/8671'tvd (about 19' above the base of the L2A). Run 4-1/2" slotted liner with a liner hanger-packer and X-profile DisplaCe the Xanvis mud to kill weight 3% KCL brine. Spot breaker across the open-hole/slotted interval. Run 4-1/2" tubing and permanent-latched packer. Set packer at about 55° hole angle for future wireline access. Displace tubing to diesel and freeze protect well with 2300' of diesel in annulus. Release rig. Prudhoe Bay Drilling Point McIntyre, Alaska Well' Pl-13 File' Pi-13WpHw2 VERTICAL VIEW SCALE 1000 ft.. / DIVISION TV9 REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 05/07/1993 6,48 on ! HALL I BURTON DRILLING SYSIEMS 450 5131 779-- 000 -- 034 -- 300-- . 000-- 3000-- ELEVATION 51.0' START OF NUDGE e 1.50 DEG/I00 FT START HOLD DROP TO VERTICAL~ 1,50 DEG/100 FT END OF NUDOE ~ t0.750 DB, t~ 3551 liD, 3550 3579 T-8 3750 . START D? BUILD 6' [.50 DEG/IOO FT 40004I \\ '~ END DF BUILD ',\ '\ \ \ \ 2041 2173 2350 242~ HORIZONTAL VIEW SCALE 500 ft.. / DIVISION SURVEY REF: IYELLHEAD i 5000J 5799 6000-~ 6656 BHL DATA I 7000-- 8000-- 8057-- 8237 8633 J 8722 9000 TVD 8722.00 MD 10955.98 VS 4136.50 NorLh -284.41 E:~st 4126.71 4000 4500 T~UE ; "-0 500 ! 000 i500 2000 2500 3000 3500 30.07 oe9. Eosl Decilnollm --500 1000 I0 750 1 CASING POINT DATA .':-,c Az; TVD North East 255' 0.00 O.O0 3550 -10 35 [ '~',, ',;EST SAF \, \. t 0 1000 VERTICAL SECTION PLANE: 93.94' CRIIICAL POINT DATA MD Inc R.K.B. ELEVATION 0 0.00 51.0' START DF 513 0.00 NUDGE ~ 1.50 BEG/lO0 FT START HOLD 779 4.00 DROP TO 1034 ,:.00 VERTICAL~ 1.50 DEG/!O0 KT END DF NUDGE 1301 0.00 T-8 3580 0.00 START OF BUILD 3751 0.00 ~ 1.50 DEG/103 FT END DF ~UILD 5914 32.44 WEST SAK 6929 32.44 START DF 8590 ~2.44 CUPVE ~ 4.50 DEG/iO0 F7 K-10 8813 40.63 K-5/HRZ 9063 50.47 START OF 3L'!LD 9153 54.12 @ 4.00 DEG,.'IO0 FT KUPARUK 9153 54.12 GOC 9496 67.84 ~Nrd OF BUILD 10077 91.0~ TARGET 10227 91,08 TOTAL DEPTH 10956 91.08 Az; TVD North East 0 . 00 0 0 0 O.C:S 51: 0 0 105.95 779 -3 9 105.95 10S~ -7 26 0.00 1310 -10 35 0.00 35~? -10 35 0.0... 3750 -10 35 1f;3.22 5799 -146 615 }53.22 6656 -271 1146 !f3.28 8057 -475 2013 93.34 8237 -493 2144 85,68 8412 -490 2322 83.46 8467 -483 ~392 83.46 8467 -483 ~3.46 8633 -449 26?0 83.46 8739 -385 3254 83.46 8736 -367 3403 83.46 8722 -284 4127 TAPOET 3420 Created By Checked By Approved By Dote TCI ~.L DEP l'"l 2000 3000 4000 PK, udhoe Say B iLLin9 Poln- McTn- y e, Akaska Pi- 3 F-lie: Pi- 1 3WpHw?__ TI HALLIBUR ON DRILLING S¥STEHS MURIZDNTAL VEW (TRUE SCAL~ 100 r-l~ ~ DIVISIFJ~ SURVE~ REP ~Lt-~AD 1 t I I t I l- I I I I F ...... 1 .... 1- ..... l--'-'-1---'-I I 1 I I I I ...... T ...... F ..... I ..... 1 I 1 I I I I I I I I I I I I I I 100 ~ ~ 400 ~ ~00 700 ,_,°00 c'400 1000 11Ck] lc--'00 1300 1400 1500 IG00 17CO lcq)] 1~0 80]0 810] 88]0 ~]C~] 84LX} cTCTJ 3600 8700 8800 ~ ~ 3100 3c-'00 33:30 3400 35C0 3600 3700 ~ D"4EI0 4[O3 4100 4L:~0 4300 4400 CRITICAL P1]INT DATA l,~g Inc A~ TVD Nc','th Eost RK B ELEVATIF34 0 003 003 0 0 0 51.0' ST~T ~ 513 O~ O~ 513 0 0 ~G,," ~ Fl ST~'; HLg 779 4.~ 1~ 779 -3 g ~ TO 1034 4.~ 1~.~ I0~ -7 ~1IC~ I.~ END ~ hU~ 1~1 0.~ 0.~ ~ -10 T-8 ~ 0,~ 0.~ ~Tg - 10 ST~T ~ ~]LD 3751 0.~ 0.~ 37~ -10 FT END ~ ~ILD ~14 ~.44 103.~ 57~ -14~ ~SI S~ 69~ ~.44 103.~ ~ -27~ 1146 ST~T ~ ~ ~.44 103~ ~7 -475 ~G/I~ FT K-10 ~13 40.63 9334 ~37 -493 ~144 $T~T ~ ~ILD g153 ~.12 ~346 84~7 -483 ~ 4.~ ~G/I~ FT K~ Ql~3 ~.l~ 83.4~ 8467 -483 ~3 ~ ~ 67.84 83.46 ~33 -449 END ~ ~ItD ~77 91,~ 8346 87~ -~ ~4 T~T 1~7 O1,~ 83.46 87~ -~7 3403 T~ ~P~H 1~ 91.~ 83.46 87~ -~4 4187 Dote Rotted Cneo±ed By Checked By App~'oved By Dote 5/7/93 BHL DATA TVD B7~C~D MD 10955.c~ VS 4136.50 NkD~'t¼ -884.41 Eos± 41L::%.71 0 --1CD --700 Pmudhoe ;Boy gmilli,, q Poin Mcln y e, Alcskc WELL: P - 3 Fire: P - 3WpHw HALL] 3UP, TE]N 624 om T~oveDng Cyllnde~ - Leosl Dist;once ReCe~ence gell - PI- MD 0 - J0956 Ct. ]nle~val, 50 Ft. All Dipections Rel to 330° 559 5O0 <~.. 450 ~'G'~O,/o' 4 O0 , \ t k. \ ., 60° / i / / / / / / / / 217. =JE 65.~G ~ ODD.OD 9~9 ~ 47.5D 49.8: 70 ~ ~.D], 53.03 19.~ 7C;.7~, 103-05 :07 O- 4%.I0 ~E 55.51 J 7~.CC, 16~ 4.gD 2942; 69.3~ 4 ~0.03 453 ~, I 0.60 j 4.57 71.33 59-D3 56.03 13 ~ 4 870.~ 6~.03 649.97 6. ] 0 4 ] .~: 2~.59 753.~ 749.~ 16.3C; 59.97 ~3.97 553.~' ~O.~ 34.40 59.97 ~.g7 559 ~ 550.~ 34.40 ~.~7 870.19 35~ ~48.~ 340 17.~' ~.60 ~ 5~.~ ~ 548.~ ~.53 ~3.~ ~.D] ~.~, ~1 ~.~ ] 8:.S~: 78 71 ~S?_;j.O_9 2048 CRVICCC POIN1 D~IA HE; ]nc Az, ;VD r¢~--.,-. Ess'. P..K.5. ELEVATiD"; 0 O.OD GOD 0 O 5! C:' S~A.~ ET 513 O.OD 0.O3 5:3 0 E' N J D,SE ~ DSO,' i 00 Fi STA~7 FCLD 779 4.00 ]C'~ -'~ 779 -] ~ '~D ]034 4.OD ]~%5 )034 -7 VERTICAL~_ DZG/IO0 F~ END ID- Nj[GE 1}2S O.OD 0.00 139~' -~3 STAP'[ EF BJILD 375] 0.00 0.00 3755 -lO e 1.50 END ET ECJILD 5014 32.44 ]03.22 57.o9 -~6 6:5 ~,C~i' S~-: 6c.z.~ 37.44 ~03.E2 6~5G -~7] ! !45 SIA~.] D- ~:?-.'3 37.44 10322 F-jO~7 ' -475 £LF~.VE E' 4.50 DSG/]O0 FI K-JO 8:'_-'13 4063 03.34 8237 -493 K-5/t-R7 0.~9 ~ 47 ~-'~.68 84 i 2 -4343 £1AP'f EF ~J]LD 9153 54.lk 83.46 8467 -48,3 e 4.00 DEG/] 00 FT KL~A,c~L~, 91 ~3 54.18 60.46 8467 -493 ~ O49: 67.84 83 46 8533 -449 END ID- BUI'.B 1.~77 c)].C.~ U::0.46 8739, - ~575 701AL D]P'¢:-~ ]095,5 91.09 83.46 872~ -E~_.4 ,4127 Printed 5/21 ,'93 Pl-13CMT.XLS State: Well: Field: State Permit P1-13 Pt. Mctntyre 93-74 Engineer. Work Sheet: Date: C. ement Volume £alculation,¢ 5,/21193 Casing Type Casing Size -Inches Casing Length- Fee~ Hole Diameter-Inches Cement- Sacks111 Cement- Yield111 Cement- Cubic R 111 Cement-Cubic It 111 Cement- Sacks112 Cement-Yield 112 Cement- Cubic It 112 Cement- Cubic R 112 Cement- Sacks113 Cement- Yield113 Cement- Cubic R 113 Cement- Cubic f~, 113 Cement- Cubic tt / Vol Cement - Fill Factor Conductor 20.000 80.000 30.000 0.000 0.000 0.000 281.000 0.000 0.000 0.000 0.000 281.000 1.288 Surface 10.750 3,510.000 13.500 0.000 0.000 0.000 2,221.000 0.000 0.000 0.000 408.000 0.000 0.000 0.000 0.000 2,627.000 2.058 Line~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/O! Casing Size -Inches Casing Depth - F~ Hob D~er -!~ Cema- Sa~s Ce~-Y~ ~nt- ~ R Ce~- ~b~ fi C~-S~s ~2 Ceme~ - Y~ ~2 C~- ~ R ~2 C~- C~ ff ~2 ~~- Sa~s ~3 ~~- ~e~ Ce~-~c R ~3 Ce~- Cu~c R ~3 Cema- ~ R / Vol Cement-i~e~val It Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.130 0.00 0.00 0.00 0.00 0.!30 0.00 0.00 0.00 11DIV/O! I~DIV/O! Intermediate 112 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 I~DIV/O! Production 7.625 10,227.000 9.875 0.00 0.00 0.00 897.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 897.00 4,176.89 6,050.1 Ivleasured Depth Rin[ed 5/21/93 State: Alaska Borough: Well: P1-13 Field: Pt. Mclntyre St. Perm It 93-74 P-13.XLS Date 5/21193 Engr: M. Minder Casing Interval Interval Size Bottom Top lA 10.'75 3550 41 2A 7.625 8735 41 3A 0 0 0 4A 0 0 0 5A 0 0 0 6A O O O ?A O 0 O 8A 0 0 0 9A 0 0 0 IOA 0 O 0 Length 3510 10186 0 0 0 0 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 46.5 NT-80 EITC 0 29.7 NT95HS NSCC 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 0 0 0 0 lB 2B 3B 4B 519 6B 7B 8B 919 10t9 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/ft 9,5 0.494 0.394 10.0 0.SZ0 0.420 0.0 0.000 -0.100 O.O O.OOO -0.100 O.O 0.000 -0.1 00 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 O.O O.OOO -O. 1 00 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3330 5210 1.6 3330 8180 2.5 0 0 #DIV/O.I 0 0 #DIV/OI 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIV/O.I 0 0 #DIV/'O! 0 0 # DiV/O.I Tension Strength K/Lbs 1C 159.705 2C 302.5242 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 lOC o K/Lbs 'I'DF 1040 6.51 811 2.68 0 #DiV/O! o #DIV/O! 0 #DIV/O.I 0 #DiV/O! 0 #DiV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 1399 3669 0 0 0 0 0 0 0 0 Resist. CDF 3130 2.238 7150 1.949 0 #DIV/O! o #DIV/O! 0 #DN/O.I 0 #DIV/O! 0 #DIV/O.I 0 #DIVI0! 0 #DIVJO! O #DIViO! ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 Apdl 5, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 30001 Porcupine Dr. Anchorage, AK 99501 RE: Request for Exception to the Provisions of 20 AAC 25.055 (drilling units and well space) Pt. Mclntyre Development Well P1-13 ,.~.._ Prudhoe Bay, Alaska Dear Chairman Johnston' ARCO Alaska, Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC 25.055 for the ddlling and completion of ARCO's Pt. Mclntyre Development Well P1-13 (the "Well"). The Well will be ddlled as a directional hole within 250' of the following locations: · Surface Location' · Target Location: · Bottom Hole: 1418'FSL, 808'FEL of Sec. 16, T12N, R14E, UM; 934'FSL, 2688'FEL of Sec. 15, T12N, R14E, UM; 832'FSL, 1970'FEL of Sec. 15, T12N, R14E, UM. A plat showing the location of the well, leasehold ownership, and all other completed and ddlling wells in the area is attached as Exhibit 1. The names and addresses of all owners and operators of the governmental quarter sections directly and diagonally offsetting the proposed ddlling unit for the well are set forth in Exhibit 2. Included in Exhibit 3 is the verification required by the referenced provisions, a copy of the notice sent to the owners and operators listed in Exhibit 2, and the date such notice was mailed. If you have any questions or require any additional information, please contact the undersigned at (907) 265-6281. Peter L. Goebel Landman :jls Attachments ~ . ARCO Alaska, Inc. Is a Subsidiary o! Atlantic Richfield Company ADL § AAI-EXXON 3-31-77 (COND) ALK 3054 ADL 34623 312809 -f' 15N EXXON 3-31-77 ADL 34622 ~ P? MCINTYRE 7 P! ~T 9 PT ~CINTYR£ 2 I PI-2, I PT MCINTYRE / / MCIN ? P1 AM-EXXON 9-30-75 (corn)) - ALK 2309 ADL 28298 2640' SCALE IN FEET 5280' 2~ AAI-EXXO 9-30-75 ALK 2308 ADL 28; P 1-08 PT tdCINTYRE ,3 PI-IS PT 22 10 ADL 377054 ?~ 1 1-30-95 ADL 365548 PT ~CIN~RE ~ PT MC/ND'RE i AAI-EXXON 3-31-77 ALK 860 ADL 346~4 I 13 PT MCINTYRE $ 25 Pt. Mclntyre Development Well Location Exceptions for Wells; P1-08 & P1-15 BAY ST I AI<'O.~ Nll 1N1 I Exhibit 2 Pt. Mclntyre Development Well Request for Spacing Exception workina Interest Owners Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn: Mr. David E. Steingraeber BP Exploration (Alaska)Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attn' Terry J. Obeney Royalty Owners - State of Alaska Department of Natural Resoumes Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn: James E. Eason, Director Overridin0 Royalty Owners Not Applicable EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation Commission in the Matter of the Request of. ARCO Alaska, Inc. for an Exception to the Provisions of 20 AAC 25.055 for Pt. Mclntyre Development Well P1-13 VERIFICATION OF FACTS AND AFFIDAVIT OF PETER L. GOEBEL STATE OF ALASKA THIRD JUDICIAL DISTRICT Peter L. Goebel, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Peter L. Goebel. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Landman for the well operator, ARCO Alaska, Inc. 3. I am acquainted with the facts associated with the ddlling of Pt. Mclntyre Development Well P-13. 4. I have reviewed the application submitted for the exception to 20 ACC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit I and it correctly portrays pertinent and required data. 6. Pursuant to 20 AAC 25.055 (b), ARCO Alaska, Inc. ("ARCO"), the well operator, prepared a Notice of Request for Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On Apdl 5, 1993 pursuant to 20 AAC 25.055 (b), ARCO sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed locations of ARCO's Pt. Mclntyre Development Well P1-13. These names and addresses are set forth on Exhibit 2 attached to ARCO's Request for Exception to Provisions of 20 AAC 25.055 dated Apdl 5, 1993. Subscribed and sworn to on Apdl 5, 1993~..~~ , Peter L. Goeb'~l STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) The foregoing instrument was acknowledged before me on Apdl 5, 1993, by Peter L. Goebel. STATE OF ALASKA Linda Sellner NOTARY PUBLIC Comm. Expire~ Octo~3er ;3, "1 gg~ N~)tary Publi(~, State of Alaska My Commission Expires: /~ - ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 5, 1993 BP Exploration (Alaska)Inc. P.O. Box196612 Anchorage, AK 99519-6612 Attn' Terry J. Obeney Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn' David Steingreaber Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn' James E. Eason, Director Re: Notice of Request for Exception to the Provisions of 20 ACC 25.055 Pt. Mclntyre Development Well P1-13 Prudhoe Bay, Alaska Pursuant to the provisions of 20 AAC 25.055 (b), ARCO Alaska, Inc. (ARCO) hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission (AOGCC) for an exception to the well spacing requirements of 20 AAC 25.055 for the drilling of the Pt. Mclntyre Development Well P1-13. ARCO's request if approved, will permit the ddlling and completion of the Pt. Mclntyre Development Well P1-13 as a directional hole within 250' of the following locations: · Surface Location: · Target Location: · Bottom Hole: 1418'FSL, 808'FEL of Sec. 16, T12N, R14E, UM; 934'FSL, 2688'FEL of Sec. 15 T12N, R14E, UM; 832'FSL, 1970'FEL of Sec. 15, T12N, R14E, UM. A plat showing the location of the subject well, leasehold ownership, and all other completed and drilling wells in the area is attached as Exhibit 1. Should you have any questions, please call the undersigned at (907) 265-6281. Peter L. Goebel Landman :ils ~ mr~ ~ ADL 312§09 T13N ADL 377054 ,, , (COND) ~~ AVL ~4oaa ,~/ AVL 365548 ;_~:L ::~::. ~ ' 9-30-75 ~ ~ // ,ff ' Developmenf Well . ' ALK ~308~ /~ ,/ Location Exceptions S STATE OF AI.ASKA ALASK& OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) /kI.ASKA, INC. for an order ) granting an exception to ) spacing requirements of ) Title 20 AAC 25.055 to provide ) for the drilling of the ARCO Pt. ) McIntyre Wells No. P1-08 and ) Pl-13. ) IT APPEARING THAT: I · Conservation Order No. 314 ARCO Alaska Inc. Pt. McIntyre Wells No. P1-08 and P1-13 April 27, 1993 ARCO Alaska, Inc. submitted applications dated April 5, 1993 requesting exception to provisions of 20 AAC 25.055(a)(3) to allow drilling the ARCO Pt. McIntyre Wells No. P1-08 and P1-13. Notice of possible hearing was published in the Anchorage Daily News on April 8, 1993 pursuant to 20 AAC 25.540. 3. No substantive protests to the applications were received· FINDINGS: I · 2, · · The ARCO Pt. McIntyre No. P1-08 well as proposed will be directionally drilled from a surface location 1442' from the south line (FSL), 738' from the east line (FEL) of Section 16, T12N, R14E, Umiat Meridian (UM), to a bottom-hole location 2667' from the north line, 2105' FEL of section 15, T12N, R14E, UM. The ARCO Pt. McIntyre No. P1-13 well as proposed will be directionally drilled from a surface location 1418' FSL, 808' FEL of Section 16, T12N, R14E, UM, to a bottom-hole location 832' FSL, 1970' FEL of Section 15, T12N, R14E, UM. Offset operators/owners Exxon Corporation and BP Ex. ploration (Alaska) Inc. have been duly notified. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling each of these wells. Conservation Ordel .~o. 31'4 April 27, 1993 Page 2 CONCLUSION: Granting spacing exceptions to allow drilling of the ARCO Pt. Mclntyre Wells No. P1-08 and Pl-13 as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s applications for exception to 20 AAC 25.055 for the purpose of drilling the Pt. McIntyre Wells No. P1-08 and Pl-13 are approved as proposed. DONE at Anchorage, Alaska and dated April 27, 1993. Alaska~ Conservation Commission Russell A. Douglass, C~nmissioner Alaska Oil and Gas Conservation Commission ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee [2 thru 8] (3) Admin ~_ ~ [9 thru [10 & 13] [14 thru 22] [23 thru 28] Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located'proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Lease & Well YES / NO REMARKS 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nL~nber appropriate .......................................... 13. Does well have a unique name & n~nber ................................ 14. Is conductor string provided ..................................... ;... 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface $ intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 1..9. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wel]bore ................... 21. Is old wellbore abandonment procedure included on 10-403 ............. 22 pment adequate ..... '& BOPE attached .... to ~'C)~) ps i g ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... . Is adequate wellbore separation proposed .......... 23. Is a diverter system required ..................... 24. Is drilling fluid program schematic & list of equi 25. Are necessary diagrams & descriptions of diverter 26. Does BOPE have sufficient pressure rating -- test 27. 28. (6) Other [29 thru 31] (7) Contact x~- [32] (8) Addl ~' geo 1 ogy' eng i nee r i n~L: DWJ MTM .~c?'4! RADS) RP~/°c_~ BEW JD~ LG ' rev 12/92 jo/6.011 29. 30. 31. 32. 33. 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 ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUSAREA SHORE UM MER ID IAhl' SM ,/ remarks' Exp/Dev TYPE' Redri 11 Inj Rev -/3 o -rz Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . ****************************** . ............................ * ....... SCHLUMBERGER ....... * . ............................ * ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : Pl-13 FIELD NAi~E : POINT MCINTYRE BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 500292237200 REFERENCE NO : 96216 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/10/ 9 ORIGIN : FLIC REEL NAM~ : 96216 CONTINUATION # : PREVIOUS REEL : COF~4EJFT : ARCO ALASKA INC, POINT MCINTYRE, Pl-13 , API #50-029-22372-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 96/10/ 9 ORIGIN : FLIC TAPE NAME : 96216 CONTINUATION # : 1 PREVIOUS TAPE : COf4FiF~VT : ARCO ALASKA INC, POINT MCINTYRE, Pl-13 , API #50-029-22372-00 TAPE H~ER POINT MCINTYRE CASED HOLE WIRELINE LOGS WELL NAME: Pl-13 API NUFi~ER: 500292237200 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 9-0CT-96 JOB NUMBER: 96216 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: ROWLAND BURN SURFACE LOCATION SECTION: 16 TOWNSHIP: 12N RANGE: 14 E FNL: FSL : 1419 FEL: 809 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 50. O0 GROUND LEVEL: 9.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 10. 750 3560.0 45.50 2ND STRING 7. 625 10275.0 29.70 3RD STRING 4. 500 11010.0 12.60 PRODUCTION STRING 4. 500 8695. 0 12. 60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUFiBER : DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888 0 9563 0 9561 0 9553 0 9538 0 9533 5 9528 5 9522 0 9503.0 9501.0 9496.5 9495.0 9492.5 9464.5 9447.0 9442.5 9421.0 9411.0 9397.0 9386.0 9381.5 9377.5 9369.0 93 68.0 93 63.5 9361.5 9331.0 9330.5 9326.0 9321.0 9317.0 9310.5 9306.0 9299.0 9289.0 9282.0 9275.5 9273.5 9266.5 9265.5 92 62.0 9257.5 9252.0 9248.5 9246.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88890.5 88886.0 9540.5 9504.5 9503.0 9493.5 9448.5 9443.5 9421.5 9411.5 9398.0 9381.0 9377.0 93 68.0 9329.5 9325.5 9321.0 9316.5 9307.0 9290.0 9277.5 9266.0 9252.0 9248.0 9561.0 9560.0 9551.5 9531.5 9527.5 9521.0 9496.0 9494.5 9464.0 9385.5 93 68.5 9363.5 9361.5 9329.5 9314.5 9310.0 9298.5 9280.0 9271.5 9265.0 9260.5 9257.0 9244.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 9243 5 9238 0 9234 5 9232 0 9228 0 9220 5 9217 5 9208 5 9199 5 9190 5 9182.5 9177.0 9169.0 100.0 $ 9242.5 9237.5 9234.0 9232.0 9228.5 9221.0 9221.5 9217.5 9209.5 9199.5 9191.0 9182.5 9178.5 9171.0 102.0 100.0 CONTAINED HEREIN IS THE LDWG FORMATTED 3 PASS CASED HOLE CNTDDATA ON ARCOALASKA'S Pl-13 WELL. THE DEPTH ADJUSTM~NTS SHOWN ABOVEREFLECT CASED HOLE GR TO OPEN HOLE GR AND CASED HOLE NPHI TO OPEN HOLE GR CARRYING ALL OTHER CNTD CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE H~ER **** FILE NANiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUf4BER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9497.0 9160.0 CNTD 9497.0 9160.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS ~ER : .......... EQUIVALENT UNSHIFTEDDEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: BASELINE DEPTH GRCH CNTD $ REMARKS: THIS FILE CONTAINS CNTD PASS #1. SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA NO PASS TO PASS TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Field Name WN Pl-13 Well Name APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Sec ti on TOWN 12N Town ship RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9. 700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT NPHI N-RAT CRAT NCNT FCNT CFTC CNTC Depth Compensated Neutron Porosity, SS Matrix, cali & dead time corr. Raw Thermal Neutron Ratio Thermal Neutron Ratio Calibrated RAW NEAR CNT COUNTS RAW FAR CNT COUNTS Corrected Far Detector Count Rate Corrected Near Detector Count Rate LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: DEFI GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude GR API-Corrected Gamma Ray ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NARiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100453 NPHI CNTD PU-S 100453 NRAT CNTD 100453 CRAT CNTD 100453 NCNTCNTD CPS 100453 FCNT CNTD CPS 100453 CFTC CNTD CPS 100453 CNTC CNTD CPS 100453 GRCH CNTD GAPI 100453 TENS CNTD LB 100453 CCL CNTD V 100453 GR MWD GAPI 100453 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: ** DATA ** DEPT. 10931.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL. CNTD -999. 250 GR.MWD DEPT. 6760.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 GR.MWD -999. 250 -999.250 28. 910 -999.250 -999.250 84.063 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCRE~F~FP: 0.5000 FILE SD?4FZARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9500.0 9160.0 CNTD 9500.0 9160.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: BASELINE DEPTH .............. 88888.0 9552.5 953 6.0 9534.5 9531.5 9523.0 9495 5 9494 0 9492 5 9484 0 9470 5 9462 0 9451 5 9449 5 9448 0 9443 5 9441.5 9441.0 9439.5 9433.5 9421.5 9413.5 9409.5 9404.5 9396.5 9393.5 9381.0 9380.5 9377.5 9372.5 93 67.5 93 63.0 9355.0 9346.5 9343.0 9341.0 9339.0 9337.5 9334.0 9332.0 9328.5 9327.5 9324.5 9321.0 9319.5 9313.5 9308.0 9300.5 9294.5 9292.5 9284.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. 88888.0 88885.5 9534.5 9495.5 9493.5 9452.0 9446.5 9443.5 9435.0 9422.0 9414.5 9406.5 9398.0 9382.0 9368.0 9348.0 9342.0 9334.5 9330.5 9325.5 9321.0 9318.0 9302.0 9297.5 9550.0 9534.5 9531.5 9527.5 9520.0 9496.5 9485.0 9472.0 9464.5 9452.0 9448.5 9441.5 9440.5 9410.0 9393.0 9381.0 9376.5 9372.5 9363.5 9355.5 9343.0 9341.5 9339.5 9338.5 9333.0 9329.5 9327.0 9313.0 9308.5 9292.5 9284.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 9279.0 9281.0 9269.5 9269.0 9264.0 9265.0 9259.0 9258.5 9251.5 9252.5 9243.0 9242.5 9237.5 9237.5 9236.0 9235.5 9226.0 9227.0 9218.5 9220.0 9217.5 9217.5 9213.0 9213.0 9211.0 9212.5 9209.5 9211.5 9203.5 9207.0 9199.5 9200.0 9197.0 9199.0 9193.5 9194.5 9186.5 9188.0 9185.0 9185.0 9179.5 9179.5 9179.0 9180.0 9176.0 9177.0 9173.5 9175.5 9171.5 9171.0 9167.0 9168.0 9165.0 9168.0 100.0 103.0 101.0 $ REMARKS: THIS FILE CONTAINS CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT GRCH PASS #2 TO GRCH PASS #1 AND NPHI PASS #2 TO NPHI PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON ARCO ALASKA INC. POINT MCINTYRE P1-13 500292237200 1419' FSL & 0809' FEL 16 12N 14E NORTH SLOPE ALASKA USA ROWLAND BURNO 100453 Company Name Field Name Wel 1 Name API Serial Number Field Location Section Township Range Court ty State or Province Nation Wi tness Name Service Order Number LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 9 TUNI VALU DEFI PDAT MSL EPD FT O. LMF DF APD FT 50. EDF FT 50. EGL FT 9.700001 TDD FT 10987. TDL FT 9490. BLI FT 9506. TLI FT 8402. DFT PRODUCED FLUIDS TI=AB 16:45 12-JUL-96 Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. NRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNT COUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 10 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAiViE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100453 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 100453 O0 000 O0 0 2 1 1 4 68 0000000000 Iv-RAT CNTD 100453 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 100453 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 100453 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 100453 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 100453 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 100453 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 100453 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 100453 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 100453 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9500.000 NPHI. CNTD 22.485 NRAT. CNTD 4.037 CRAT. CNTD NCNT. CNTD 3730.500 FCNT. CNTD 914.375 CFTC. CNTD 869.578 CNTC. CNTD GRCH. CNTD 28.352 TENS. CNTD 1224.250 CCL.CNTD 0.016 DEPT. 9160.000 NPHI.CNTD 39.535 NRAT. CNTD 6.385 CRAT. CNTD NCNT. CNTD 2849.785 FCNT. CNTD 454.645 CFTC. CNTD 438.877 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1275.000 CCL.CNTD 0.132 4. 087 3671. 859 6.143 2768.238 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUM~La~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9506.0 8402.0 C~FfD 9506.0 8402.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88890.0 88889.5 9557.0 9558.5 9554.5 9556.0 9550.0 9551.5 9531.5 9531.5 9529.0 9531.0 9528.0 9528.0 9521.5 9524.0 9520.5 9521.5 9518.5 9521.5 9511.5 9512.0 9491.5 9494.0 9484.5 9486.0 9482.0 9483.0 9472.5 9474.5 9470.5 9472.0 9462.5 9465.5 9462.0 9464.5 9450.5 9451.0 9450.0 9452.5 9440.5 9440.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 12 9434 9430 9421 9413 9405 9405 9396. 9380 9378 9370 9369 9365 9359 9351 9347 9330 9327 9321 9318 9315 9305 0 9304 0 9298 5 9296 5 9284 0 9281.5 9278.5 9277.0 9275.0 9266.0 9258.0 9256.5 9253.0 9252.5 9238.0 9237.0 9235.0 9232.5 9228.0 9222.0 9220.5 9219.5 9218.5 9206.5 9199.0 9191.0 9186.0 9184.5 9173.0 9167.5 9165.5 9164.5 9159.0 9153.5 9147.5 0 9435.0 5 5 5 9414.5 5 0 9406.5 0 9398.0 5 9381.5 0 9379.5 0 9371.0 0 5 9366.0 5 5 9353.0 0 9348.0 5 9330.5 5 9328.5 0 9321.5 5 5 9315.5 9305.5 9297.5 9278.0 9276.5 9258.5 9252.0 9237.5 9234.5 9229.0 9223.5 9220.5 9207.0 9199.5 9186.5 9175.5 9169.0 9166.0 9161.0 9154.0 9148.0 9429.5 9421.0 9406.5 9370.5 9359.5 9321.0 9305.5 9298.5 9283.5 9280.0 9277.5 9266.0 9257.0 9253.5 9237.0 9232.0 9221.0 9219.0 9193.0 9186.0 9164.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 13 9132 9131 9127 9122 9120 9115.5 9111.0 9110. 5 9107.0 9106.5 9103 0 9090 5 9089 5 9087 5 9081 5 9080 5 9076.0 9072 5 9070 5 9065 5 9061 5 9060 5 9058 0 9046 0 9041 0 9021 0 8994 0 8975.5 8973.5 8969.5 8968.0 8960.5 8953.5 8949.5 8940.0 8933.0 8928.5 8920.0 8915.5 8909.0 8906.5 8895.0 8892.0 8889.0 8875.0 8871.0 8859.5 8856.0 8853.5 8852.5 8852.0 8846.5 8844.0 8837.5 8834.5 .5 9133.0 .0 · 0 9126.5 .0 .5 9121.5 9112.0 9108.0 9102.5 9089.5 9086.5 9082.5 9078.0 9075.0 9072.0 9067.0 9063.0 9057.0 8992.0 8975.5 8969.0 8960.0 8953.0 8940.0 8932.5 8929.0 8921.0 8891.0 8889.5 8876.0 8861.5 8855.5 8853.0 8847.5 8844.5 9130.5 9121.5 9116.5 9111.5 9108.0 9089.0 9082.5 9071.5 9063.0 9048.0 9043.0 9021.0 8973.5 8969.0 8950.0 8916.5 8910.0 8907.5 8895.5 8871.0 8857.0 8853.5 8839.5 8836.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 14 8833.0 8820.0 8815.5 8811.5 8808.0 8803.5 8794.5 8791.0 8786.0 8784.0 8759.0 8751.5 8749.5 8740.0 8729.0 8724.0 8723.0 8720.0 8707.0 8668.5 8659.5 8658.0 8644.5 8643.0 8631.5 8607.5 8599.5 8596.5 8589.5 8585.5 8585 0 8575 0 8568 5 8543 0 8534 5 8524 5 8519 0 8517 0 8509 0 8494 5 8473 0 8443 0 8436 5 8413 5 100 0 8833.0 8818.0 8808.5 8806.0 8793.0 8790.0 8785.0 8760.5 8751.0 8731.5 8726.0 8721.0 8670.0 8661.5 8647.5 8645.0 8608.5 8601.0 8591.0 8586.5 8576.5 8568.0 8545.5 8537.0 8528.0 8522.0 8497.5 8817.5 8805.0 8785.0 8751.5 8738.5 8723.0 8707.0 8658.5 8645.0 8632.5 8601.0 8597.5 8586.5 8545.0 8520.0 8509.5 8474.5 8448.0 8440.5 8440.0 8418.0 104.5 103.5 REFLARKS: THIS FILE CONTAINS CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT GRCH PASS #3 TO GRCH PASS #1 AND NPHI PASS #3 TO NPHI PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 15 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Fi eld Name WN Pl-13 Well Name APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Se c t i on TOWN 12N Town ship RANG 14E Range COON NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9.700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ArRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNT COUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 PT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MODNUMB SAMP ELI~Vl CODE (HE.X) DEPT FT 100453 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 100453 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 100453 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 100453 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 100453 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 100453 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 100453 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 100453 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 100453 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 100453 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 100453 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9506.000 NPHI. CNTD 22.528 NRAT. CNTD 4.072 CRAT. CNTD NCNT. CNTD 3932.500 FCNT. CNTD 976.500 CFTC. CNTD 924.563 CNTC. CNTD GRCH. CNTD 28.250 TENS. CNTD 1236.125 CCL.CNTD 0.002 DEPT. 8402.000 NPHI. CNTD 46.252 NRAT. CNTD 8.667 CRAT. CNTD NCNT. CNTD 1927.711 FCNT. CNTD 206.009 CFTC. CNTD 269.158 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1260.000 CCL.CNTD 0.028 4.093 3885.563 6.895 1812.920 LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 17 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTD THE ARITHMETIC AVERAGE OF PASSES 1 , 2 , & 3 WAS COMPUTED AFTER ALL DEPTH SHIFTS AND CLIPPING WAS APPLIED. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. POINT MCINTYRE P1-13 Company Name Field Name Well Name LIS' Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 18 TUNI VALU DEFI APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9.700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. NRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNTCOUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 19 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 100453 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 100453 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 100453 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 100453 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 100453 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 100453 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 100453 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 100453 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 100453 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 100453 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9497.000 NPHI. CNAV 22.667 NRAT. CNAV 4.034 CRAT. CNAV NCNT. CNAV 3758.166 FCNT. CNAV 930.417 CFTC. CNAV 874.243 CNTC. CNAV GRCH. CNTD 27.355 TENS. CNTD 1274.406 DEPT. 9160.000 NPHI.CNAV 38.831 NRAT. CNAV 6.381 CRAT. CNAV NCNT. CNAV 2757.942 FCNT. CNAV 439.517 CFTC. CNAV 437.154 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1305.000 4.111 3713.759 6.064 2730.554 ** END OF DATA ** LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 20 * * * * FILE TRAILER * * * * FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER: 1 DEPTH INCREMENT: 0.5000 FILE SUB~HL~Y VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 9490.0 8400.0 CNTD LOG HEADER DATA DATE LOGGED: 12-JUL-96 SOFTWARE VERSION: CP44.2 TI~E LOGGER ON BOTTOM: 1645 12-JUL-96 TD DRILLER (FT) : 10987.0 TD LOGGER (FT) : 9490.0 TOP LOG INTERVAL (FT) : 8402.0 BOTTOM LOG INTERVAL (FT) : 9506.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO) : NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CNTD COMPENSA TED NEUTRON CNC- D- 146 CNTD COMPENSATED NEUTRON CPSC-A-805 GR GAI~fA RAY CGRS-A- 863 $ BOREHOLE AND CASING DATA LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 21 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11010.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) .. GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 ArEAR COUNT RATE HIGH SCALE (CPS): 23000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO INTEQ DPR-MWD DATED 6/6/93. THE PURPOSE OF THIS LOG WAS TO MONITOR CURRENT GAS OIL CON UNABLE TO GET DEEP ENOUGH TO OBSERVE GOC. THIS FILE CONTAINS RAW PASS #1 CNTD. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VAL U DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Field Name WN Pl-13 Well Name APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Section TOWN I2N Township RANG 14E Range COUN NORTH SLOPE County LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 22 TUNI VALU DEFI STAT ALASKA State or Province NA TI USA Nat i on WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9.700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTNR Raw Thermal Neutron Ratio TNRA Thermal Neutron Ratio Calibrated RCNT RAW NEAR CArT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 23 TYPE REPR CODE VALUE 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100453 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 100453 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 100453 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 100453 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 100453 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 100453 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 100453 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 100453 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 100453 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 100453 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 100453 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9581.500 NPHI.PS1 26.626 RTNR.PS1 4.622 TNRA.PS1 RCNT. PS1 4000.000 RCFT. PS1 865.385 CNTC. PS1 3956.252 CFTC. PSI GR.PS1 25.813 TENS.PSI 1095.000 CCL.PS1 0.078 DEPT. 9158.000 NPHI.PS1 40.705 RTNR.PS1 6.000 TNRA.PS1 RCNT. PS1 2832.455 RCFT. PSi 455.696 CNTC. PS1 2747.894 CFTC. PSI GR.PS1 133.750 TENS.PSi 1275.000 CCL.PS1 0.245 4.626 824.603 6.270 423.229 ** END OF DATA ** LiS Tape. Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AK3Y4~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~LARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9490.0 8400.0 CNTD LOG HEADER DATA DATE LOGGED: 12-JUL-96 SOFTWARE VERSION: CP44 . 2 TIME LOGGER ON BOTTOM: 1645 12-JUL-96 TD DRILLER (FT) : 10987.0 TD LOGGER (FT) : 9490.0 TOP LOG INTERVAL (FT): 8402.0 BOTTOM LOG INTERVAL (FT) : 9506.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON GR GAMMA RAY $ BOREHOLE AND CASING DATA TOOL NUMBER ........... CNC-D- 146 CPSC-A- 805 CGRS-A-863 LiS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 25 OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11010.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 ~ COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 23000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO INTEQ DPR-MWD DATED 6/6/93. THE PURPOSE OF THIS LOG WAS TO MONITOR CURRENT GAS OIL CON UNABLE TO GET DEEP ENOUGH TO OBSERVE GOC. THIS FILE CONTAINS RAW PASS #2 CNTD. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Field Name WN Pl-13 Well Name APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County L~S Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 26 TUNI VALU DEFI STAT ALASKA State or Province NAT I USA Nat i o n WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9.700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTArR Raw Thermal Neutron Ratio TNRA Thermal Neutron Ratio Calibrated RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNTCOUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCLAmplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 L~S Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 27 TYPE REPR CODE VALUE 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 6 1 1 4 68 0000000000 DEPT FT 100453 NPHI PS2 PU 100453 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 100453 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 100453 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 100453 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 100453 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 100453 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 100453 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 100453 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 100453 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 100453 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9573. 500 NPHI. PS2 21. 285 RTNR. PS2 3. 922 TNRA. PS2 RCNT. PS2 3773.585 RCFT. PS2 962.264 CNTC. PS2 3732.313 CFTC. PS2 GR. PS2 23. 734 TENS. PS2 1065. 000 CCL. PS2 O. 061 DEPT. 9157.000 NPHI.PS2 36.163 RTNR.PS2 6.000 TNRA.PS2 RCl~f. PS2 2784.103 RCFT. PS2 454.645 CNTC. PS2 2722.892 CFTC. PS2 GR.PS2 134.625 TENS.PS2 1280.000 CCL.PS2 0.620 3. 925 916. 917 5.767 447.154 ** END OF DATA ** L~S Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 28 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUAff~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9490.0 8400.0 CNTD LOG HEADER DATA DATE LOGGED: 12-JUL-96 SOFTWARE VERSION: CP44.2 TIFIE LOGGER ON BOTTOM: 1645 12-JUL-96 TD DRILLER (FT) : 10987.0 TD LOGGER (FT) : 9490.0 TOP LOG INTERVAL (FT) : 8402.0 BOTTOM LOG INTERVAL (FT): 9506.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CNTD COMPENSATED NEUTRON CNC- D- 146 CNTD COMPENSATED NEUTRON CPSC-A-805 GR GAA94A RAY CGR S-A- 8 6 3 $ BOREHOLE AND CASING DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 29 OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11010.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 23000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED IN TO INTEQ DPR-MWD DATED 6/6/93. THE PURPOSE OF THIS LOG WAS TO MONITOR CURRENT GAS OIL CON UNABLE TO GET DEEP ENOUGH TO OBSERVE GOC. THIS FILE CONTAINS RAW PASS #3 CNTD. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Field Name WN Pl-13 Well Name APIN 500292237200 API Serial Number FL 1419' FSL & 0809' FEL Field Location SECT 16 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County LI~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 30 TONI VALU DEFI STAT ALASKA State or Province NATI USA Na ti on WITN ROWLAND BURNO Witness Name SON 100453 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DF Log Measured From APD FT 50. Above Permanent Datum EDF FT 50. Elevation of Derrick Floor EGL FT 9. 700001 Elevation of Ground Level TDD FT 10987. Total Depth - Driller TDL FT 9490. Total Depth - Logger BLI FT 9506. Bottom Log Interval TLI FT 8402. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 16:45 12-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Dep th NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTArR Raw Thermal Neutron Ratio TNRA Thermal Neutron Ratio Calibrated RCNT RAW NEAR CNT COU1FTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 31 TYPE REPR CODE VALUE 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA24~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 7 1 1 4 68 0000000000 DEPT FT 100453 NPHI PS3 PU 100453 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 100453 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 100453 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 100453 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 100453 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 100453 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 100453 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 100453 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 100453 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 100453 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9567.500 NPHI. PS3 22.757 RTNR.PS3 4.120 TNRA.PS3 RCNT. PS3 3882.214 RCFT. PS3 942.285 CNTC. PS3 3839.755 CFTC. PS3 GR.PS3 24.766 TENS.PS3 990.000 CCL.PS3 0.065 DEPT. 8396.500 NPHI.PS3 38.090 RTNR.PS3 5.600 TNRA.PS3 RCNT. PS3 2048.000 RCFT. PS3 343.348 CNTC. PS3 1902.403 CFTC. PS3 GR.PS3 44.000 TENS.PS3 1265.000 CCL.PS3 -0.024 4.123 897.879 5.983 312.372 ** END OF DATA ** LI~S Tape Verification Listing Schlumberger Alaska Computing Center 9-0CT-1996 15:16 PAGE: 32 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/1 O~ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/10/ 9 ORIGIN : FLIC TAPE NAFIE : 96216 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC, POINT MCINTYRE, Pl-13 , API #50-029-22372-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/10/ 9 ORIGIN : FLIC REEL NAME : 96216 CONTINUATION # : PREVIOUS REEL : COf4M-EIVT : ARCO ALASKA INC, POINT MCINTYRE, Pl-13 ,API #50-029-22372-00 CO '. IDEttTIAL LIS VERIFICATION LISTING FOR: ARCO ALASKA P1-13/H-9 POINT MClNTYRE RECEIVED OCT 1 4 19~ ~llasl?a Oil & C~as Cons. Commissio., Anchorage BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA P1-13 /H-9 AZT BDCC BDC2 BDEC BDE2 BDIC BDI2 CADE CAD2 CPDE CPD2 DCCM DCC2 DLAC DLA2 DPEC DPE2 DPLC DPL2 DPSC DPS2 DRHC DRH2 DSAC DSA2 GRAC GRA2 GRS INC LPOM LPO2 NFBM NFB2 NNBM NNB2 NPEM NPE2 NPIM NPI2 NPLM NPL2 NPSM NPS2 NRCM NRC2 PDCM PDC2 PDDC PDD2 PDEM PDE2 PDIM PDI2 RACM Azimuth - True (Posted) Bulk Density Compensated [RWD + R2] Bulk Density Compensated Relog 2 [RWD] Bulk Density Time Since Drilled [RWD + R2] Bulk Density Time Since Drilled Relog 2 [RWD] Bulk Density Data Density Integrated [RWD + R2] Bulk Density Data Density Integrated Relog 2 [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (AT) Corrected for Dielectric Effect Relog 2 [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect Relog 2 [RWD] Calculated Dielectric Constant Calculated Dielectric Constant Relog 2 Density Long Space Apparent [RWD + R2] Density Long Space Apparent Relog 2 [RWD] Photoelectric Cross Section [RWD + R2] Photoelectric Effect Relog 2 [RWD] Density Porosity (LS)[RWD + R2] Density Porosity Limestone Matrix Relog 2 [RWD] Density Porosity (SS) [RWD + R2] Density Porosity Sandstone Matrix Relog 2 [RWD] Delta RHO - Density [RWD + R2] Delta Rho Correction Relog 2 [RWD] Density Short Space Apparent [RWD + R2] Density Short Space Apparent Relog 2 [RWD] Gamma Ray Memory (APl) [RWD + R2] Gamma Ray Memory (APl) Relog 2 [RWD] Gamma Ray Base (Sperry Sun) Inclination - True (Posted) Neutron Porosity (LS) Borehole Corr [RWD] Neutron Porosity (LS) Borehole Corr Relog 2 [RWD] Neutron Far Base [Base] Neutron Far Base Relog 2 [RWD] Neutron Near Base [Base] Neutron Near Base Relog 2 [RWD] Neutron Porosity Time Since Drilled [RWD] Neutron Time Since Drilled Relog 2 [RWD] Neutron Data Density Integrated [RWD] Neutron Data Density Integrated Relog 2 [RWD] Neutron (LS) [RWD] Neutron (LS) Relog 2 [RWD] Neutron (SS) [RWD] Neutron (SS) Relog 2 [RWD] Neutron Ratio Borehole Corr. [RWD] Ratio Borehole Corr. Relog 2 [RWD] Borehole Corrected [RWD] Borehole Corrected Relog 2 [RWD] Data Density [RWD + R2] Data Density Retog 2 [RWD] Elapsed Time [RWD] Elapsed Time Relog 2 [RWD] Data Density Integrated [RWD] Phase Difference Data Density Integrated Relog 2 [RWD] Resistivity (AT) Borehole Corrected [RWD] Porosity Porosity Porosity Porosity Porosity Porosity Porosity Porosity Neutron Porosity Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference deg g/cc g/cc mins mins pts pts mmho/m mmho/m mmho/m mmho/m g/cc g/cc B/e B/e p.u. p.u. p.u. g/cc g/cc g/cc g/cc MWD-API MWD-API deg p.u. p.u. cps cps cps cps mins. mins. pts pts p.u. p.u. p.u. p.u. p.u. deg deg pt/ft pt/ft mins mins pts pts ohm-m RADE RAD2 ROP ROPC RPCM RPC2 RPDE RPD2 SPOM SP02 TCDM TVD Note: Resistivity (AT) Corrected Dielectric Effect [RWD] Resistivity (AT) Corrected Dielectric Effect Relog 2 [RWD] Rate of Penetration (Sperry Sun) Rate of Penetration (Baker Hughes Inteq + Sperry Sun) Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Borehole Corrected Relog 2 [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] Resistivity (PD) Corrected for Dielectric Effect Relog 2 [RWD] Neutron Porosity (SS) Borehole Corr. [RWD] Neutron Porosity (SS) Borehole Corr. Relog 2 [RWD] CD$ Temperature [RWD] True Vertical Depth AT is Attenuation PD is Phase Difference LS is Limestone SS is Sandstone RWD is Recorded While Drilling R2 is Relog 2 ohm-m ohm-m ft/hr ft/hr ohm-m ohm-m ohm-m ohm-m p.u. deg F ff Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 19 AUG 93 4:12p != = ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678,9012345678,90123456789012 1 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, I=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 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , !Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LI$ ... thru 35=Array Accoustic) (see table) ~ 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = 1 , ! WriteTape-lmage File: 0=NO, I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 50, LISTMAX = 0, STATS = 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITUS = 1 , SUBFILES = /0/, INTERPOLATE = 'YES' END oo'6666- = (9/.)S~ll.-lanS 00'6666- = (sz)S~laSns 00'6668- = (i~/.)s~11.-181'1s 00'6666- = (8~)S~qlaSns oo'eec~- = (~z)saq~aens oo'6r~- = (~)s~asns 00'6886- = (0~)san~aan~ 00'6888- -- (69 oo'ec~:~- = (e9)s~ens oo'r~- = (z9)s~ens oo'eeas- = (99)smJaens 00'~- = (s-9)s~aJaens 00'68~- = (t,9)S~laenS 00'66~- = (c9 oo'r>er~- = (~9)saqJaens oo'r>r~- = (~9)s~Jaens oo'er~- = (09)s~Jaens 00'~- = (es)s~aens oo'r¢~- = (es)s~Jaans oo'r>~s- = (zs)s~Jaans oo'r¢~- = (ge)s~aens 00'~- = (ss)s~Jaens 00'~- = (~s)s~Jaens 00'6666- = (es oo'eeee- = (~s)s~uens 00'6666- = (~s)s:~aens 00'6666- = (OS)S~ql.4arl$00'6666-= (6t, 0O'6666- = (e~)sanJaens oo'~- = (z, oo'r¢~- = (9~)saqJaens oo'6666- = (s, 0O'6668- = (t~)S:qJaenS 00'6666- = (~ 00'6668- = (~)S~qlaens oo'6666- = (~t~ oo'eees- = (0~)s~Jaens oo'e66e- = (6e)s~Jaens 0o'6666- = (~)s~laens 00'~- = (zs 00'~- = (~e)S~lae~s oo'~- = (~s ~'~- = (9~)saqJaans oo'~- = (~)S~laens oo'~- = (~)saq~aans oo'~- = (~)s~aans oo'~- = (e~)saquens oo'~- = (z~)s:qJaans oo'~- = (~)s~aens oo'~- = (~)s~qJaens ~'~- = (o~)s~aens oo'~- = (6 oo'~-= (9)saqJaens oo'~- = (s oo'~-= (~)s~Jaans oo'~- = (s oo'~-= (~)sa:Jaens oo+~oooooo'o = (~)s:qJaens St::l:::l.l._-ql/~V~Vcl AYblbl¥--i 00+ =1000000'0 = dOMOM 00+ =1000000'0 =dsAep0M 00+=1000000'0 = ),oqJoM 00+=1000000'0 = dep~,s~ 00+=i000000'0 = dsAelp, 00 + ~000000'0 = depue~4 00 + ~000000'0 = l~OeJuJnu 00 + :~000000'0 = JempLunu 00 + ~000000'0 = sAJn0Lunu 00 + ~000000'0 = SeldLU~SU 00 + ~t000000'0 = UlOeJU!LU 00 + ~1000000'0 = UlOeJXeLU 00 + ]~000000'0 = e^~nu, S!l 00 + 3000000'0 = qCuepp 00000' ~ = eiodp 00000' ~ = jeoodp 00000' [ = clVJ.3J, lblM 00 + =J000000'0 = OSV3J. IblM 00 + B000000'0 = S.LV.LS 00000' ~ = SI-1.LI-lclS 00 + 3000000'0 = J. SBJ_-I'I~S 00 + ~!000000'0 = H.I_-qlAI.LSi-i 00 + ~000000'0 = XVIALL$11 0000'0cj =O31=I=I.LSI'I 00000'~ =SO~IblO=INI 00+~000000'0 =clAJ.~OblO=l 00000' ~ = S.LN~IRRO0 00 + 3000000'0 = ~'II_-IO.LFIV 00 + ~000000'0 TM A~FIOO.LF1V Sbl=l.L_-qlAIVt=lV8 .LNV.LSNO0 --i i ............. 000'0 O.L 000'0 IAIO~=l -IVAI=I=I.LNI CONISS=:lOO~cl --i S~]A ='lOd~l~lJ.NI SI::F::iI:IIAIVI:IYd 9NlalS--i ~ 0O'6666- = 00'6666- = (gg~)S~USrlS 00'6666- = 00'6666- = (~)S~lusns 00'6666- ~'~- = (s~)s~asns ~'~- = (9~)S~lasns ~'~- = (~)s~asns ~'~- = (~ ~ ~)s~asns ~'~- = (o~ ~>s~asns ~'~- = (so~>s~asns ~'~- = ~'~-= ~'~ = (~o~)s~asns ~'~- = ~'~- = (~)s~asns oo'~- = (~)s~asns ~'~- = (~)s~asns ~'~- = (~)s~asns ~'~-.= (~)s~asns ~'~- = (~)s~asns ~'~- = (~)s~asns 00'6666- = (Z8 L)S~-II_-181'IS 00'6666- = (SS L)S~II:ISI'IS 00'6666- = (88 L)S~'II.-181qS oo'6666- = 00'6666- = (6~ oo.66as- = (z~ oo'66r~- = ~'~- = (~)s~asns ~'~-= oo'~- = (6o~)s~asns oo'~- = (so~)s~asns ~'~- ~'~- = ~'~- = (~)s~asns ~'~- = (~ >s~asns ~'~- = (~ >s~asns oo'~- = oo'~- = ~'~- = (ez)s~asns Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:~1227\1227.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= 1) 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 93/8/19 1227 01 **** TAPE HEADER **** MWD 93/8/19 1227 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records.., 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS 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: 1227 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: 16 TOWNSHIP: 12N RANGE: 14D FNL: FSL: 1419 FEL: 809 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 50.00 GROUND LEVEL: 9.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 10.750 130.0 2ND STRING 9.875 7.625 3559.0 3RD STRING 6.500 10270.0 PRODUCTION STRING REMARKS: $ P1-13/H9 5O-O29-22372 Arco Alaska Inc. BAKER HUGHES INTEQ 19-AUG-93 BIT RUN2 BIT RUN3 1227 1227 T. FOSTER R. MCCARTHY V. LIM L. PEAK L. PEAK L. PEAK **** FILE HEADER **** MWD ,001 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678,901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 6746.0 11010.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD $ REMARKS: $ 5 6746.0 8956.0 6 8956.0 9707.0 7 9707.0 11010.0 CN : Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS MERGED EDITED MWD DATA. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcocle(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 1 000 1 RepCode Count Bytes 68 10 40 Sum: fndun a [F 10 40 40 ] 1.00000000 ~ 1./. ~ 8~ ~ 'Ir S-nd I. 8g GMI~ IHdN 01. 9 LZ 0ggs6 1;, 9 I.ZOgg ~ 1;' t I,N~HO I. ~ QMI,N V~I Z 9 I./_ 0gg e6 t 1;, $clo ~ ~ aMI61 .LNON 9 9 I./. 0gg e6 1:, 1~ $clo I. ~ aM~ J. NO.-I g 9 I.Z0gg86 1;, 9 I.ZOC~ ~ t 9 I.Z ogg ~ ~ 9 I.ZOC~ ~ 1:, t C0/9 1. 89 aM~ t~OH~ I. POl/N SlO dt.L dtj. qCue-! ez!s s~un Selclwes epoo IOO.L eWeN /uO/uO 6oq IdV IdV IdV IdV :se/uno 0 ~ =1 :Gl q~,dep edej. =IIAIVbI_-I Id~d H.Ld:IC] =JNO - ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 23 FRAMES * DATA RECORD (TYPE# O) 1018 BYTES * Total Data Records: 371 Tape File Start Depth = 6746.000000 Tape File End Depth = 11010.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13090 datums Tape Subfile: 2 442 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subtile 3 is type: LIS **** FILE HEADER **** MAD .002 1024 LIS COMMENT RECORD(s): 123456789012345678,9012345678901234567890123456789012345678,9012345678901234567890 FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH MAD 9190.0 9246.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD 1 $ REMARKS: $ CN : Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska STOP DEPTH MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 9190.0 9246.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS MERGED EDITED MAD DATA, * 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(68) 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 1 000 1 Rep Code Count Bytes 68 9 36 Sum: 9 36 36 fndun a [F ]' 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 RHOB MAD 68 1 G/C3 4 4 33 821 00 0 2 PEF MAD 68 1 BN/E 4 4 33 821 00 0 3 DRHOMAD 68 1 G/C3 4 4 33 821 00 0 4 GR MAD 68 1 GAPI 4 4 33 821 00 0 5 FCNT MAD 68 1 CPS 4 4 33 821 00 0 6 NCNT MAD 68~ 1 CPS 4 4 33 821 00 0 7 RA MAD 68 1 OHMM 4 4 33 821 00 0 8 RP MAD 68 1 OHMM 4 4 33 821 00 0 9 NPHIMAD 68 1 PU-S 4 4 33 821 00 0 36 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 25 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 5 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 186 datums Tape Subtile: 3 29 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** MAD ,003 1024 LIS COMMENT RECORD(s): 123456789012345678.90123456789012345678901234567890123456789012345678.901234567890 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 1 0,5000 MAD PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH MAD 9190.0 9246,0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ REMARKS: $ CN WN FN COUN STAT STOP DEPTH ....... EQUIVALENT UNSHIFTED DEPTH ......... 'Arco Alaska Inc. · P1-13/H9 'Pt. Mclntyre ' North Slope 'Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MAD PASS DATA. * 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: -999.25~ 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 910111213141516 0001 00000001 0001 _ Rep Code Count Bytes 68 9 36 Sum: 9 36 36 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 RHOBMAD 68 1 G/C3 4 4 33 821 00 0 2 PEF MAD 68 1 BN/E 4 4 33821 00 0 3 DRHOMAD 68 1 G/C3 4 4 33 821 00 0 4 GR MAD 68 1 GAPI 4 4 33821 00 0 5 FCNT MAD 68 1 CPS 4 6 NCNT MAD 68 1 CPS 4 7 RA MAD 68 1 OHMM 4 8 RP MAD 68 1 OHMM 4 9 NPHt MAD 68 1 PU-S 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 ** Routine LEVONE detects data discrepancy: .~. DSB indicates: 1 FRAMES Data Record Length indicates: 25 FRAMES * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 5 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13276 datums Tape Subfile: 4 32 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subtile 5 is type: LIS **** FILE HEADER **** MWD .0O4 1 O24 LIS COMMENT RECORD(s): 12345678.9012345678901234567890123456789012345678.90123456789012345678.901234567890 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 MWD 6746.0 8956.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOq-rOM LOG INTERVAL (F-T): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ BOREHOLE AND CASING DATA STOP DEPTH O4 JUN 93 M1.33 M1.33 MEMORY 0,0 6746,0 8956.0 0 31.0 46,0 TOOL NUMBER 2535-15 OPEN HOLE BIT SIZE (IN)' DRILLER'S CASING DEPTH (FT): 9.875 0,0 BOREHOLE CONDITIONS MUD TYPE: FRESH WATER MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 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 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 0.000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 6740 TO 8253' MD (6503 TO 7789' TVD) WAS LOGGED 41 TO 11.5 HOURS RESPECTIVELY AFTER BEING DRILLED DUE TO A BIT TRIP AND PROVIDING DIRECTIONAL ONLY SERVICE ON THE PREVIOUS RUN. THE LOGGING SPEED FOR THE MAD PASS WAS 400+ FEET PER HOUR. THEREFORE, THE NEUTRON AND DENSITY DATA ARE OF POOR QUALITY. $ .CN : Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678.90123456789012345678.9012345678901234567890123456789012345678.901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. -- * 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 8 910 11 12 13 1415 16 ~ 000 1 0000000 1 000 1 Rep Code Count Bytes ,-_, 68 37 148 Sum: fndun a [F 37 148 148 ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 37 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 AZT MWD 68 1 DEG 4 2 BDCC MWD 68 1 G/CC 4 3 BDEC MWD 68 1 MINS 4 4 BDIC MWD 68 1 PTS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 1 4 8 DLAC MWD 68 1 G/CC 4 9 DPEC MWD 68 1 B/E 4 10 DPLCMWD 68 1 PU 4 11 DPSCMWD 68 1 PU 4 12 DRHC MWD 68 1 G/CC 4 13 DSAC MWD 68 1 G/CC 4 14 GRAC MWD 68 1 GAPI 4 15 GRS MWD 68 I GAPI 4 16 INC MWD 68 1 INC 4 17 LPOMMWD 68 1 PU 4 18 NFBM MWD 68 1 CPS 4 19 NNBM MWD 68 1 CPS 4 20 NPEM MWD 68 1 MINS 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 1 PU 4 23 NPSM MWD 68 1 PU 4 24 NRCM MWD 68 1 RATI 4 25 PDCM MWD 68 1 DEG 4 26 PDDC MWD 68 1 PTFT 4 27 PDEM MWD 68 1 MNS 4 28 PDIM MWD 68 1 PTS 4 29 RACM MWD 68 1 OHMM 4 30 RADE MWD 68 1 OHMM 4 31 ROP MWD 68 1 FPHR 4 32 ROPC MWD 68 1 FPHR 4 33 RPCM MWD 68 1 OHMM 4 34 RPDE MWD 68 1 OHMM 4 35 SPOM MWD 68 1 PU 4 36 TCDM MWD 68 I DEGF 4 37 TVD MWD 68 I FT 4 148 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 4 98660 71 6 4 9866O 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 49866071 6 4 99 789 97 5 4 98 660 71 6 498660 71 6 498660 71 6 498660 71 6 4 59 324 56 5 ** RoLrtine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 6 FRAMES * DATA RECORD (TYPE# O) 918 BYTES * Total Data Records: 1474 Tape File Start Depth = 6746.000000 Tape File End Depth = 8,956.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 5 65305 datums 1544 records... Minimum record length: Maximum record length: 62 bytes 918 bytes 32 Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s)' 123456789012345678,90123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8956.0 9707.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOF'fVVARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (F-T): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH O5 JUN 93 M1.33 M1.33 MEMORY 0.0 8956.0 9707.0 0 46.8 75.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 2535-15 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT)' 9.875 0.0 BOREHOLE CONDITIONS MUD TYPE: FRESH WATER MUD DENSITY (LB/G): 10.30 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 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 0.0 0,0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 0.000 TOOL STANDOFF (IN)' EWR FREQUENCY (HZ)' 0.0 0 REMARKS: INTERVAL FROM 8956 TO 8991' MD (8359 TO 8382' TVD) WAS LOGGED 11.5 HOURS AFTER DRILLED DUE TO BIT TRIP, INTERMITTENT DENSITY FAILURE FROM 9210 TO 9225' MD (6508 TO 8516' TVD). RELOG DATA PLOTTED OVER THIS INTERVAL. INTERMITTENT DENSITY FAILURE FROM 9314 TO 9326' MD (6563 TO 8569' TVD). $ CN : Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 6. * 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 00 000 0 0 1 0 00 1 Rep Code Count Bytes 68 37 148 Sum: fndun a [F 37 148 148 ] ONE DEPTH PER FRAME Tape depth ID: F 37 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 AZT MWD 68 1 DEG 4 2 BDCC MWD 68 1 G/CC 4 3 BDEC MWD 68 1 MINS 4 4 BDIC MWD 68 1 PTS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 1 4 8 DLAC MWD 68 1 G/CC 4 9 DPEC MWB 68 1 B/E 4 10 DPLCMWD 68 1 PU 4 11 DPSC MWD 68 1 PU 4 12 DRHC MWD 68 1 G/CC 4 13 DSAC MWD 68 1 G/CC 4 14 GRAC MWD 68 1 GAPI 4 15 GRS MWD 68 1 GAPI 4 16 INC MWD 68 1 INC 4 17 LPOM MWD 68 1 PU 4 18 NFBM MWD 68 1 CPS 4 19 NNBM MWD 68 1 CPS 4 20 NPEM MWD 68 1 MINS 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 1 PU 4 23 NPSM MWD 68 1 PU 4 24 NRCM MWD 68 1 RATI 4 25 PDCM MWD 68 1 DEG 26 PDDC MWD 68 1 PTFT 27 PDEM MWD 68 1 MNS 28 PDiM MWD 68 1 PTS 29 RACM MWD 68 t OHMM 30 RADE MWD 68 1 OHMM 31 ROP MWD 68 1 FPHR 32 ROPC MWD 68 1 FPHR 33 RPCM MWD 68 1 OHMM 34 RPDE MWD 68 1 OHMM 35 SPOM MWD 68 1 PU 36 TCDM MWD 68 1 DEGF 37 'FVD MWD 68 1 FT 148 4 4 4 4 4 4 4 4 4 4 4 4 498660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98 680 71 6 49866O 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 4 99 789 97 5 498660 71 6 498660 71 6 498660 71 6 498660 71 6 4 59 324 56 5 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 6 FRAMES * DATA RECORD (TYPE# O) 918 BYTES * Total Data Records: 501 Tape File Start Depth = 8956.000000 Tape File End Depth = 9707.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** 32 LIS representation code decoding summary: Rep Code: 68 35448 datums Tape Subfile: 6 574 records... Minimum record length: 62 bytes Maximum record length: 918 bytes Tape Subtile 7 is type: LIS **** FILE HEADER **** MWD .~6 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9707.0 11010.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): DO'FI'OM LOG INTERVAL (P-I'): BIT ROTATING SPEED (RPM): HOLE INCLINATION (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 (03): STOP DEPTH 07 JUN 93 M1.33 M1.33 MEMORY 0.0 9707.0 11010.0 0 75,9 91,2 TOOL NUMBER 2535-15 9.875 0,0 FRESH WATER 10.20 0.0 0.0 8OO 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): 0.000 0.0 0,0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 9708 TO 9743' MD (8695 TO 8702' TVD) WAS LOGGED 13 HOURS AFTER DRILLED DUE TO BIT TRIP. INTERMITTENT DENSITY FAILURE FROM 9773 TO 9981' MD (8707 TO 8728' 'i'VD). RELOG DATA PLO'I-rED OVER THIS INTERVAL. FORMATION RESISTIVITIES EXCEEDING THE MAXIMUM RANGE OF THE LOGGING TOOL. INTERVAL FROM 10240 TO 10275' MD (8745 TO 8744' INVERTED TVD) WAS NOT LOGGED DUE TO SETTING CASING AND CHANGING MWD SERVICE. ALL DATA OVER THE INTERVAL FROM 10240 TO 11010' MD (8744 TO 8746' TVD) WAS PROVIDED BY SPERRY SUN MWD. $ CN :Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 1234567890123456789012345678.90123456789012345678.90123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7. ~_, * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) L_, 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 I 0000000 I 000 I Rep Code Count Bytes 68 37 148 O00000C~' I. [ ,4] ~ unpuj. :wns ONE DEPTH PER FRAME Tape depth ID: F 37 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 AZT MWD 68 1 DEG 4 2 BDCC MWD 68 1 G/CC 4 3 BDEC MWD 68 1 MINS 4 4 BDIC MWD 68 1 PTS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 1 4 8 DLAC MWD 68 1 G/CC 4 9 DPEC MWD 68 1 B/E 4 10 DPLCMWD 68 1 PU 4 11 DPSCMWD 68 1 PU 4 12 DRHCMWD 68 1 G/CC 4 13 DSAC MWD 68 1 G/CC 4 14 GRACMWD 68 1 GAPI 4 15 GRS MWD 68 1 GAPI 4 16 INC MWD 68 1 INC 4 17 LPOMMWD 68 1 PU 4 18 NFBM MWD 68 1 CPS 4 19 NNBM MWD 68 1 CPS 4 20 NPEM MWD 68 1 MINS 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 1 PU 4 23 NPSM MWD 68 1 PU 4 24 NRCM MWD 68 1 RATI 4 25 PDCM MWD 68 1 DEG 4 26 PDDC MWD 68 1 PTF-r 4 27 PDEM MWD 68 1 MNS 4 28 PDIM MWD 68 1 PTS 4 29 RACM MWD 68 1 OHMM 4 30 RADE MWD 68 1 OHMM 4 31 ROP MWD 68 1 FPHR 4 32 ROPC MWD 68 1 FPHR 4 33 RPCM MWD 68 1 OHMM 4 34 RPDE MWD 68 1 OHMM 4 35 SPOM MWD 68 1 PU 4 36 TCDM MWD 68 1 DEGF 4 37 TVD MWD 68 1 FT 4 148 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98 660 71 6 4 98660 71 6 4 98 660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 99 789 97 5 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 59 324 56 5 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 6 FRAMES * DATA RECORD (TYPE# O) 918 BYTES * Total Data Records: 869 Tape File Start Depth = 9707,000000 Tape File End Depth = 11010.000000 Tape File Levet Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 103708 datums Tape Subtile: 7 949 records... Minimum record length: Maximum record length: 62 bytes 918 bytes 32 Tape Subfile 8 is type: LIS **** FILE HEADER **** MAD .007 1024 LIS COMMENT RECORD(s): .... 123456789012345678.90123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 7 ~- RAW MAD Curves and Icg header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MAD 9190.0 9246.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION' DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME)' TD DRILLER (F-r)' TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM)' HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MAD 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 (C,3): STOP DEPTH O7 JUN 93 'M1.33 M1.33 MEMORY 0.0 9190.0 9246.0 0 0.0 0.0 TOOL NUMBER 2535-15 9.875 0.0 FRESH WATER 0.00 0.0 0.0 0 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): 0.000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN : Arco Alaska Inc. WN : P1-13/H9 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska 0.0 0.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MAD 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) 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 29 116 Sum: 29 116 116 fndun a [F ] t.00000000 ONE DEPTH PER FRAME Tape depth ID: F 29 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 BDC2 MAD 68 1 G/CC 4 2 BDE2 MAD 68 1 MINS 4 3 BDI2 MAD 68 1 PTS 4 4 CAD2 MAD 68 1 MMHO 4 5 CPD2 MAD 68 1 MMHO 4 6 DCC2 MAD 68 1 4 7 DI_A2 MAD 68 1 G/CC 4 8 DPE2 MAD 68 1 B/e 4 9 DPIp MAD 68 1 PU 4 10 DPS2MAD 68 1 PU 4 11 DRH2MAD 68 1 G/CC 4 12 DSA2MAD 68 1 G/CC 4 13 GRA2. MAD 68 1 GAPI 4 14 LPO2MAD 68 1 PU 4 15 NFB2 MAD 68 1 CPS 4 16 NNB2MAD 68 1 CPS 4 17 NPE2 MAD 68 1 MINS 4 18 NPi2 MAD 68 1 PTS 4 19 NPlpMAD 68 1 PU 4 20 NPS2 MAD 68 1 PU 4 21 NRC2 MAD 68 1 RATI 4 22 PDC2 MAD 68 1 DEG 4 23 PDD2 MAD 68 1 PTFT 4 24 PDE2 MAD 68 1 MINS 4 25 PDi2 MAD 68 1 PTS 4 26 RAD2 MAD 68 1 OHMM 27 RPC2 MAD 68 1 OHMM 28 RPD2 MAD 68 1 OHMM 29 SPO2 MAD 68 1 PU 4 116 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 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 33821 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 33821 00 0 4 33 821 00 0 4 58 947 15 0 4 33821 00 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 4 33821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 8 FRAMES * DATA RECORD (TYPE# O) 966 BYTES * Total Data Records: 29 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36602 datums Tape Subtile: 8 95 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subtile 9 is type: LIS **** TAPE TRAILER **** MWD 93/8/19 1227 01 **** REEL TRAILER **** MWD 93/8/19 1227 01 Tape Subtile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes _ End of execution: Thu 19 AUG 93 4:15p Elapsed execution time = 3 minutes, 13.7 seconds. ~'~ SYSTEM RETURN CODE = 0 SI-! :ed/q s! I. el!jqns adej. g~O'96 01.06'90'¢ ~t;,Z L'O g~zO'g u'-"88~'8 681.9' I.t gg I.Z'O LZ.g OZ9g'/.. I. ~6Z.~'~ O000'OCjSZ L LO6'90t C06L'O 69,C0'g t,8~9'8~ 6~6'~z~ W.69'8 I. 886;~'~ 0000'00~/. k6~9'~, 09aS'Z9 ZLgg'68~ I.t, Og'Cj t,660'C 9zgz'g I. ZC~ 8;~6 I.'0~ SZl;'~'~ O000'OCj I.Z ~80t~'g t~9LS'8 ~ZZ9'98 I. Z66'o§gs ~ 1.88'6 I. CJl. gl.'a O000'OOLZ /Ogc~'got Z LW.'g 6969'g8 zla~8'~ag9 ~ ~ ~6'6 I. 1.8~ I. 'a 0000' OgO/. ~908'8 9~6ff'Z9~ 8~LL'O 9ZOg'aLZS 6Z~'Oa Zl:;'Sk'a O000'O00Z ZOLO'~ gOgt'Zg 899g'~8 9LLL'O 0099'6a 6Lgt,'906g Laa~'ta 06S8'~ 0000'0~69 6~gO'g ZZ~L'O8 Lgs8'688 6gZO'O Zcjt,9'C ~L69'9Z69 06i:::'g'~ 9t~8'~ 0000'0069 9LO0'S 6~6a'6z 898L'O 866t,' t ~ I. Z66'C'VZCJ .C901:,'gg 01;,~'~ 0000'0989 Ig~90'cj LOlz8'~g i;,8gC'l;,cJ8 ZZ~ 1. '0 8961.'Z O~'Ok'8 g86~'L8 /.. 1.9a'O 1.6cj c~SB~'.C;~ 98a.0';~ O000'OOgg OOCj~'666- 00cj8'666- 00g~'666- 00~'666- OOg~'666- 00g~'666- L t. B"8' 098g 00cj~'666- O000'OCjZ9 005~'666- 00g~'666- 00S~'666- 00g~'668- 00~'666- 00~'666- 0L88'~8 9sgz'~8g 9aZ8'La 00g~'666- O00g'gt;:,Z9 00g~'666- 009~'666- 00g~'666- 00S~'666- 00g~'666- 00~'666- 6gOO'CC O000'k~8g ~L8Z'L~ 00g~'666- O000'g~z9 d~ :iD dOll oHua IHdN J. NON .J. NO-I 80Hi:I H.Ld:IQ S1'1 :ed~ s! 8 el!tqns ed~.L DEPTH FCNT NPHI 7300.0000 19.7163 36.6898 7350.0000 17.6563 41.6075 7400.0000 18.2644 39.1972 7450.0000 19.7187 36.4831 7500.0000 19.6202 35.9112 7550.0000 15.5721 48.7279 7600.0000 18.7139 38.4611 7650.0000 18.9087 38.0350 7700.0000 17.6667 40.8021 7750.0000 19.6827 36.4859 7800.0000 16.1743 44.7965 7850.0000 18.6016 38.6695 7900.0000 17.1641 42.3380 7950.0000 17,5729 41.5141 RHOB NCNT 2.3160 5779.3096 2.2696 5723.4980 2.1961 5626.2305 2.2106 5753.000O 2.1875 5634.9990 2.2284 5664.6914 2.3116 5689.0771 2.1324 5704.61 43 2.2107 5640.0020 2.2620 5740.3O96 2.1825 5550.2285 2.2564 5697.7480 2.1462 5654.0010 2.2206 5697.0010 PEF RA 3.2790 3.8O42 3.3763 3.7212 3.3~2 3.4800 3.1632 3.6212 3.2772 3.8958 3.2364 3.4571 3.2751 3.6830 3.2061 3.5346 3.3058 4.1740 3.2069 4.6751 3.3970 2.8653 3.2966 3.3097 3.3888 2.5636 3.2455 3.0210 DRHO ROP 0.1530 401.6786 0.1646 406.9010 O. 1730 354.3563 0.1278 406.9011 0.1668 367.4926 0.1852 354.3563 0.1813 366.2109 0.0907 413.4291 0.1574 44.0710 O. 1477 365.1624 0.1740 377.7452 0.1445 ~1.3~2 0.1466 383.8727 O. 1454 367.4925 GR RP 100.8972 2.7501 95.4460 2.7885 103.7134 2.6522 100.5031 2.7230 111.6834 2.8367 64.4577 2.6261 96.1781 2.7164 88.6843 2.7049 102.7347 3.2485 105.7745 3.3563 96.6700 2.2227 97.5004 2.4500 103.9807 2.0754 102.8322 2.4599 ./..966'0 I. I. LgLL'O 0000'0999 806cj'~ ~:,~`/8'60 L gSt, cj'8C `/~ L'O cj~`/g'8 80/..6'~ 8&~C'cj/.8cj ~80S' L~ ~.~ t6'~ 0000'0099 Big L6'6~, 6Z~a'O 6699'gaZS za6~'a O~b'"'6'Z~ Zg'86'gL O000'Oggg 6gg9'~ L k 8C68'~cj z~~,a'O 008~'8 &'1;'a9'88 6a~a'La 0000'0098 cjL-'~a.a ZZ8~'`/O ~ 9~g~'0 gt tO'~8`/g 6&'8~'~ `/9t t'~8 8~L8'0~ O000'OCjtg 80~'~ t,~Ot',/..O i, 8868'~g g¢,`/O'O Z696'a g~g'izgZg 006;~'8~ i.&%'6'8 I. O000'OOtg I.`/9cj'a k988'001. 9 ,&':'8 ~'&'9 9t60'0 9`/8~'8 O000'OS,~ ~/..t,6' I. 899t'~0 t Z9LO'6S cji`/t'O 9~9t'~ Og~g'9C Z~36'6L 0000'00-~ 8g~6'9cj C`/8~'0 06c~t,'~'lr`/cj 999a'6L 0000'08~8 O`/ffO'8S 9~'cJI~',/CC 8L6L'O 'H;'06'~ t,O'l;,Cj' 8 L0~8'68 9L~'8L 0000'00~8 898.0'~ 9086'06 8tcj~'Olgg gtc~6'a ~'t69cj O000'OCj L8 8D20'C 9 L9,/'80 k 6066'C ~66C'8 ,/6Ccj'ot I.~8',/I. O000'OOL8 ggg,/' L6 cjcjcjo'99~ gl.;~L'O 0868'8 Og~t'8g~g L9~'Lt O000'OcjOg 8.0,/8'1. gggo'g9~ LCC~'O 9cj09'9~ O000'O00g d~ OH~CI .J. NON 80Hi:! IHdN INO=I Hld::la DEPTH FCNT NPHI FIHOB NCNT PEF RA DRHO ROP GR RP 8700.0000 21.2759 34.2718 8750.OOO0 21.4931 33.1624 2.5384 5878.4863 2.4288 5768.1729 3.3764 3.9639 4.0587 4.3759 0.1516 32.5127 0.2354 35.2126 108.3078 3.0886 109.3163 3.3400 8800.0000 21.5833 33.3916 8850.0000 28.6276 25.0280 8900.0000 19.5330 36.7652 2.4940 5827.8613 2.3904 5995.5010 2.3715 5736.5439 3.9871 5.1008 3.3069 12.4120 2.8928 -999.2500 0.1870 44.6599 0.1577 118.1295 0.0480 101.2538 73.6207 3.5676 101.6151 8.5334 91.9037 19.2471 8950.0000 18.0669 39.5930 2.2715 5644.6953 5.1141 -999.2500 0.1990 171.8334 92.9899 20.0321 9000.0000 24.3668 30.0586 2.3616 5990.9727 3.3539 -999.2500 0.0743 77.4304 83.8749 25.2571 9050.0000 23.0672 31.7482 2.3120 5955.0410 3.8200 -999.2500 0.0932 29.7733 99.2963 20.2485 9100.0000 18.7206 38.0772 9150.0000 19.7738 36.0303 92O0.000O 21.6190 35.0424 2.3165 5663.5264 2.4253 5707.3398 2.8419 6093.9697 4.5541 3.9557 4.3439 5.5550 8.3065 -999.2500 0.0855 34.0571 O. 1787 21.7416 -0.0596 45.1615 197.3931 3.2978 227.5331 4,9442 52.5167 82.7965 9250.0000 19.6290 36.6079 2.7083 5743.6289 5.5561 -999.2500 0.1115 100.7547 59.7134 33.3161 9300.~ 25.9871 26.9125 2.2186 5794.7295 3.6076 -999,2500 0.1894 82.6573 43.5581 63.4626 9350.0000 21.9380 33.1279 2.7112 5882.1416 6.4189 -999.2500 0.1650 54.6584 68.3608 21.3596 DEPTH FCNT NPHI RHOB NCNT PEF RA DRHO ROP GR RP 9400.(X)00 35.0398 19,5202 9450.0000 34.1935 20.3754 2.1534 5990.7373 2.1818 6046.1270 2.9089 -999.2500 2.8270 -999.2500 0,0391 35.7968 0.0479 20.4955 34.0834 137.0663 35.0740 120.5623 9500.0000 38.8809 17.5428 2.2671 6127.4697 3.4988 -999.2500 0.0891 72.9369 41.8374 97.7848 9550.OO0O 26.5202 27.5548 2.2593 6036.9902 3,1165 -999.2500 0,0527 23.7893 36.8880 227.7573 9600.0000 31.2461 22.6486 2.3261 6017.6807 3,0800 -999.2500 0.0680 137.8O97 42,3074 78.6841 9650.0000 19,9380 36.5151 2.2249 5821.3604 4.1151 -999.2500 0.1178 140,0124 30.7576 198.8915 9700.0000 23,6966 30.0835 2,1954 5830,4922 4.5114 -999.2500 0,1238 51.3397 43.1571 76.6187 9750.00OO 33.6057 20.8092 2.4086 6042.5078 2,8884 -999.2500 0.0828 110.8856 60.4349 29.8483 9800.0000 27,0252 27,1629 2.1608 6048,7959 2.9180 -999.2500 0.0886 334.7322 31.6648 616.1434 9850.0000 29.3124 24.2815 2.2099 5983.0039 3.0166 -999.2500 0.0656 189,0167 25.2719 -999.2500 9900,0000 27.5789 26,4834 2.2137 6064.1680 2.7841 -999.2500 -0,0057 246.9368 28.9596 7O36.1904 9950.0000 24.4967 29.8776 2.2382 5989,4004 2.8310 -999.2500 0.0236 236.2709 28.7870 6876,0195 10000.0000 24.8324 29.9281 2.2389 6081.8145 3.2861 -999.2500 0.1073 87.0377 75.7433 7036.1904 10050.0000 30,4870 23.5569 2.2131 6066.293O 2.4275 -999,2500 0,0~7 168.3265 32.8207 6649.6875 DEPTH FCNT NPHI RHOB NCNT 10100.0000 25.4335 28.9496 PEF RA 10150.0000 28.0967 25.8292 DRHO GR ROP RP 10200.0000 26.6977 27.3705 2.2985 3.8813 .0.0117 33.0386 6047.6250 -999.2500 107.3467 5362.5312 10250.0000 -999.2500 -999.2500 2.3156 3.5829 0.0268 32.3377 6045.6387 -999.2500 27.1631 2870.4058 10300.0000 -999.2500 -999.2500 2.1952 3.1935 0.0498 29.5509 6041.6973 -999.2500 185.5771 7085.8555 10350.000O -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.3100 -999.2500 -999.2500 147.6618 -999.2500 1O4O0.000O -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 26.1700 -999.2500 -999.2500 75.4000 -999.2500 10450.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 22,9800 -999,2500 -999.2500 65.2000 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 27.6700 -999.2500 -999.2500 67.0600 -999.2500 10550.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 30.4400 -999.2500 -999.2500 46.8400 -999.2500 10600,0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 31.2500 -999.2500 -999.2500 76.2100 -999.2500 10650.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 30.9900 -999.2500 -999.2500 55,2000 -999.2500 10700.0000 -999.250O -999.25OO -999.2500 -999.2500 -999.2500 32.8000 -999.2500 -999.2500 45.9600 -999.2500 10750.0000 -999.2500 °999.2500 -999.2500 -999.2500 -999.2500 23.0100 -999.2500 -999.2500 46.7600 -999.2500 -999,2500 -999.2500 -999.2500 23,8400 -999.2500 -999.2500 40.2800 -999.2500 -999.2500 -999.2~ -999.2500 23.4500 -999.2~ -999.2500 61.9600 -999.2~ DEPTH RHOB PEF FCNT NCNT RA NPHI 10800.0000 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 10850,0000 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10900.0000 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10950,0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11000.0000 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 11010.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DRHO ROP -999.2500 ~.4600 -999.2500 133.1400 -999.2500 45.4200 -999,2500 53.0400 -999,2500 37.0500 -999.2500 -999,250O GR RP 30.5900 -999.2500 32.8800 -999.2500 31,5300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 6746.000000 Tape File End Depth = 11010.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH RHOB PEF FCNT NCNT RA DRHO RP 9190.0000 2.4918 6.6837 0.1090 19.9479 5965.~ -999.2500 -999.2500 GR NPHI -9cJ9.2500 37.5690 9190.5000 2.4992 6.8015 0.0960 -999.2500 20.1562 5975.9990 -999.2500 -999.2500 37.1940 9200.0000 2.2971 6.5213 0.0274 71.1924 21.1 562 5831.8896 -999.2500 -999.2500 34.2207 9246.0000 -999.2500 -999.2500 -999.2500 54.2907 -999.2500 -999.2500 -999.2500 28.5463 -999.2500 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 4 is type: LIS DEPTH RHOB PEF FCNT NCNT RA DRHO RP GR NPHI 9190.0000 2.4918 6.6837 0.1090 19,9479 5965.9990 -999.2500 -999.2500 9190,5000 2.4992 6,8015 0.0960 20,1562 5975.9990 -999.2500 -999.2500 -999.2500 37.5690 -999.2500 37.1940 9200.0000 2,2971 6,5213 0,0274 71.1924 21.1562 5831.8896 -999.2500 -999.2500 34.2207 9246.0000 -999,2500 -999.2500 -999.2500 54.2907 -999.2500 -999.2500 -999.2500 28.5463 -999.2500 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 5 is type: LIS DEPTH AZT CADE CPDE DPLC DPSC GRS INC NPEM NPIM PDCM PDDC RADE ROP SPOM TCDM BDCC DCCM ~ DRHC LPOM 'NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 6746.0000 102.9052 -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 30.5842 -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 6508.9346 6746.2500 102.9075 -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 30.5835 28,8888 21.7812 5821.0000 -999.2500 2.0000 13.5318 18.1493 264.3085 -999.2500 -999.2500 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17.2116 253.5370 10.4438 10,1724 -999.2500 -999.2~0 9.8217 8,3325 -999.2500 334.4919 4.8005 5.0016 31.4998 102.5681 6598.3877 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM Az'r CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 6900.0000 274.2922 21.9513 -999.2500 -999.2500 14.1649 3.6457 32.5414 103.8312 327.3434 19.1131 30,8699 -999,2500 13.8687 -999,2500 101,6375 2.3346 132,1400 0.0759 28.4478 13.2371 -999.2500 389.8561 6641.3437 -999,2500 2.2587 2,2081 22.6490 17,8603 259.000O 2.9507 54.0000 2,7193 80.1477 5976,6914 260,9980 3.9210 3,0549 6950.0000 430,5867 20.5252 -999,2500 -999.2500 18.1268 2.3224 29.6500 104.4226 497.3368 17.6352 30,8161 -999,2500 17.8159 -999.2500 100.9625 2.3590 160,9487 0,1116 25.7124 11,4363 -999.2500 342.5658 6684.2686 -999.2500 2.2475 2.1731 24.3221 16.0935 358.0000 1.9523 -999.2500 2,8100 57.4305 5905.4619 240.2153 2.4468 2.0107 7000.0000 174,4503 30.7219 -999.2500 -999.2500 12.3880 5,7323 34.8312 1 04.6000 262.7316 28.2027 30.6871 -999.2500 12,1035 -999.2500 99.5188 2,1847 119,2133 0.1158 30.6256 14.7420 -999.2500 367.4926 6727.2568 -999.2500 2.0688 1,9916 20.4279 19.3343 455,0000 3.6669 88.0000 3.1523 72.2987 5712,3076 277,1720 6.4306 3.8O62 7050.0000 174.1636 34.3214 -999,2500 -999.2500 12.t135 5,7417 35.6969 104.6000 253.3O97 31.9331 30.5258 -999.2500 11,8291 -999.2500 99.7250 2,1231 117.2134 0.1463 31,4517 15,3133 -999,2500 406.5807 6770.2725 -999.250O 1.9768 1.8792 19.9111 19.8.935 552.0000 3.8OO6 -999.2500 3.2261 82.4278 5683.8447 283.1693 6.43O2 3,9477 7100.0000 184,9033 30,9088 -999,2500 -999,2500 12.9908 5.4082 36.6771 104,0978 283,9095 28.3963 31.5958 126.0000 12.7034 -999,2500 100.2875 2.1815 123.5O50 O, 1724 32,3888 15.9252 -999.2500 413,4291 6812,8867 -999.2500 2,0091 1,8942 19.2812 20.4931 -999.2500 3.4026 -999.2500 3.3764 93,6942 5650,9971 289.8.589 6,0473 3.5222 DEPTH CADE DPLC GRS NPEM PDCM RADE ' SPOM 7150.0000 172.2918 21.1826 -999.2500 -999.2500 11.1045 5.8041 35.2654 7200.0000 198.5355 24.3668 -999.2500 -999.2500 13.2191 5.0369 38.6184 7250.0000 197.1290 19.3433 -999.2500 -999.2500 13.0510 5.0728 41.6189 7,,'.'.'.'.'.'.'.'.~. 0(X)0 262.8669 23.0397 -999.2500 -999.2500 15.0823 3.8042 36.6898 7350.0000 268.7288 25.7550 -999.2500 -999.2500 14.9603 3.7212 41.6075 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 103.5000 220.3101 18.3165 32.9000 -999.2500 10.8272 -999.2500 99.5519 103.7174 292.0342 21.6165 32.7913 -999.2500 12.9277 -999.2500 99.8375 104.0565 265.9911 16.4103 32.6652 -999.2500 12.7612 -999.2500 99.7906 105.0,.',',',',',',',',~ 363.6263 20.2412 32.4478 -999.2500 14.7842 -999.2500 100.1750 105.8702 358.6129 23.0551 32.1808 -999.2500 14.6604 -999.2500 100.5125 BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD 2.3478 109.8532 0.1834 31.0397 15.0037 -999.2500 389.5677 6855.4248 2.2933 125.2616 0.1903 34.2505 17.2040 -999.2500 406.9011 6897.4531 2.3792 124.0394 0.1742 37.1429 19.1578 -999.2500 406.9010 6939.5039 2.3160 138.8093 0.1530 32.4010 15.9351 -999.2500 401.6786 6981.6738 2.2696 137.9069 0.1646 37.1319 19.1931 -999.2500 406.9010 7023.9258 BDEC DLAC DSAC NFBM NPSM PDIM RPCM -999.2500 2.1644 2.0421 20.1923 19.5911 740.0000 4.3617 -999.2500 2.1031 1.9763 18.6971 21.7435 -999.2500 3.3026 -999.2500 2.2050 2.0889 17.5670 23.6516 930.0000 3.3717 -999.2500 2.1630 2.0610 19.7163 20.5027 1025.0000 2.6606 -999.2500 2.1051 1.9953 17.6563 23.6849 -999.2500 2.6973 BDIC DPEC GRAC NNBM NRCM RACM RPDE 139.0000 3.0994 67.3260 5715.7676 280.1895 6.4622 4.5391 -9cJ9.2500 3.3714 90.3542 5722.9229 302.7385 5.5819 3.4243 -999.2500 3.2385 93.0225 5710.7158 321.5152 5.6220 3.4966 -999.2500 3.2790 100.8972 5779.3096 289.9447 4.1243 2.7501 -999.2500 3.3763 95.4460 5723.498O 321.4468 4.0236 2.7885 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM AZT CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 7400,0000 287.3593 30.0528 -999.2500 -999.2500 15.4127 3.4800 39.1972 106.4021 377,0472 27.5093 31.8065 -999.2500 15.1114 -999.2500 100.9625 2.1961 141,2116 0.1730 34.8O70 17.6663 -999.2500 354,3563 7066.3516 -999.2500 2,0231 1.9078 18.2644 22.1931 1216.0000 2.5666 221,0000 3,3852 103.7134 5626.2305 306.4727 3.746O 2.6522 7450.0000 276.1525 29.2072 -999.2500 -999.2500 15.1738 3.6212 38.4831 106,1210 367.2471 26.6329 31.9242 241.0000 14.8730 -999,2500 101.3000 2.2106 139.4747 0.1278 32.2031 15.7975 -999.2500 406.9011 7108.7061 -999.2500 2.0827 1.9975 19.7187 20,3681 1313.0000 2.6341 -999.2500 3.1632 100.5031 5753.0000 288.5435 3.9085 2.7230 7500.0000 256.6873 30.5576 -999.2500 -999.2500 14.8055 3.8958 35.9112 104,8053 352.5233 28.0324 32.6610 -999.2500 14.5089 -999,2500 101.6844 2,1875 136.7969 0.1668 31.6564 15,4491 -999.2500 367.4926 7150.9697 -999.2500 2.0207 1.9095 19,6202 20.0265 1409.0000 2,7435 -999.2500 3,2772 111,6834 5634.9990 284.6412 4.2285 2.8367 7550,0000 289.2562 28.1646 -999.2500 -999.2500 15.5018 3,4571 48.7279 104.8253 380.7966 25.5524 32.8010 -999.25OO 15,2018 -999.2500 101.975O 2.2284 141,8594 0.1852 44.0706 23,5526 -999,25OO 354,3563 7193.1455 -999,2500 2.0458 1.9223 15.5721 27.9322 1 504.0000 2.542O -999.2500 3,2384 84.4577 5664.6914 360.0042 3.7207 2.6261 7600.0000 271.5168 23.2955 -999.2500 -999.2500 15.1959 3.6830 38.4611 105.9832 368.1312 20.5063 32.4326 -999.2500 14.8947 -999.2500 102.5375 2.3116 139.6352 0.1813 34.0994 17,1451 -999.2500 366.2109 7235,2461 -999.2500 2.1303 2.0094 18.7139 21.6847 1599,0000 2.6277 -999.2500 3,2751 96,1781 5689.0771 301.7148 3.9824 2.7164 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM 765O1OOOO 282.9135 33.7775 -999.2500 -999.2500 15.2315 3.5346 38.0350 7700.0000 239.5769 29.1998 -999.2500 -999.2500 13.6465 4.1740 40.8021 7750.0000 213.9004 26.1989 -999.2500 -999.2500 13.3739 4.6751 7800.0000 349.0071 30.8482 -999.2500 -999.2500 17.0992 2.8653 44.7965 7850.0000 302.1456 26.5251 -999.25(X) -999.2500 16.1503 3.3097 38.6695 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 105.4128 369.7025 31.3694 32.5383 -999.2500 14.9,331 -999.2500 102.7625 103.8702 307.8334 26.6253 32.9106 -999.2500 13.3553 -999.2500 102.7625 104.1129 297.7719 23.5152 32.8366 -999,2500 13.0843 -999.2500 103.6365 104.9194 449.9127 28.3336 32.6215 -999.2500 16.7942 -999.2500 103.8031 105.3387 408.1674 23.8533 32.2613 -999.2500 15,8484 -999.2500 104.3029 BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD 2.1324 139.8942 0.0907 33.6902 16.8461 -999.25O0 413.4291 7277.3467 2.2107 128.3679 0.1574 36.3537 18.6670 -999.2500 44.0710 7319.4482 2.2620 126.3882 0.1477 32.2058 15.8035 -999.2500 365.1624 7361.4951 2.1825 153.4731 0.1740 40.2263 21.1867 -999.2500 377.7452 7403.5234 2.2564 146.5747 0.1 445 34.2995 17.2402 -999.2500 401.3902 7445.7842 BDEC DLAC DSAC NFBM NPSM PDIM RPCM -999.2500 2.0417 1.9812 18.9087 21.3930 1690.0000 2.6175 -999.2500 2.0533 1.9484 17.6667 23.1716 -999.2500 3.1363 -999.2500 2.1143 2.0159 19.6827 20.3739 1879.0000 3.2408 -999.2500 2.0085 1.8925 16.1743 25.6293 1979.0000 2.1561 -999.2500 2.1119 2.0156 18.6016 21.7788 2074.0000 2.3737 BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 3.2061 88.6843 5704.6143 298.9236 3.8080 2.7049 -999.2500 3,3058 102.7347 5640.0020 316.5495 4.5374 3.2485 -999.2500 3.2069 105.7745 5740.3096 288.5626 5.1390 3.3583 -999.2500 3.3970 96.6700 5550.2285 339.7569 3.0530 2.2227 -999.2500 3.2966 97.5004 5697.7480 303.0697 3.5574 2.4500 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM AZT CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 7900.0000 387.0616 32,9730 -999.2500 -999.2500 17, 7974 2.5836 42.338O 105.6319 481,8265 30.5357 31.9128 -999.2500 17,4877 -999,2500 104.4500 2.1462 158.5520 0.14.66 37.8388 19.6197 -999.2500 383.8727 7488.0713 -999.2500 2,0043 1.9078 17,1641 24.1022 2172.0000 2.0144 -999.2500 3,3888 103.9807 5654.0010 325.7938 2.7384 2.0754 7950.0000 331.0175 28.617O -999.2500 -999.2500 16.1120 3.0210 41,5141 103.9298 406.5197 26.0213 32.2319 -999.2500 15.8101 -999.2500 104.9000 2.2206 1 48.2962 O, 1454 37.0416 19.1015 -999.2500 367.4925 753O.3848 -999.2500 2.0752 1.9783 17,5729 23.5963 2275,0000 2.3832 -999.2500 3.2455 102.8322 5697.0010 320.8846 3.2225 2.4599 8000.0000 450.3O48 30,8455 -999.2500 -999.2500 18.8769 2.2207 42.8352 102.6768 533.6877 28.3308 32,4242 -999.2500 18.5663 -999,2500 1 O5,25O0 2,1825 166.4095 0,1331 38.3206 19.9360 -999.2500 266.0555 7572.7080 -999.2500 2,0494 1,9607 16,8056 24.4107 2410.0000 1.8213 432.0000 3.2431 93.6336 5585.~ 328.7009 2,3375 1.8738 8050.0000 307.1747 30.7489 -999.2500 -999.2500 15.6498 3.2555 41,8361 103,7821 386.9764 28.23O7 31,9505 -999.2500 15,3497 -999.2500 1 O5,8OO0 2.1842 142.9034 0.1215 37,3530 19.4543 -999.2500 266.0555 7615,0879 -999.2500 2.0627 1.9817 17.4935 23,9365 -999.2500 2.5O33 451.0000 3.3980 91,7555 5658.4150 322.8169 3.4881 2.5841 8100.0000 250.5683 31.0572 -999,2500 -999.2500 14,1374 3.9909 40.5397 104.5441 326.3882 28.5502 31,5161 -999.2500 13,8439 -999,2500 105.9125 2,1789 131.9400 O. 1037 36.1004 18.4638 -999.2500 354.3563 7657.5566 -999.2500 2.0752 2,0061 17.8221 22.9740 2629,0000 2.9602 -999.2500 3.3992 108.7616 5673,5361 314.9306 4.3286 3.0638 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM 8150.0000 338.4503 26.6454 -999.2500 -999.2500 16.4062 2.9546 40.3079 8200.0000 344.3057 26.5225 -999.2500 -999.2500 16.5311 2.9044 39.3201 8250.0000 378.4202 15.6307 -999.2500 -999.2500 17.5226 2.6426 37.4089 8300.0000 406.0779 15.6335 -999.2500 74.0000 18.4636 2.4626 36.5250 6350.0000 295.1906 14.6431 -999.2500 136.0000 15.7110 3.3876 32.3963 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 104.3290 419.1447 23.9780 31.1935 -999.2500 16.1017 -999.2500 106.3625 103.5913 424.6595 23.8506 31.0000 -999.2500 16.2276 -999.2500 106.7716 102,0696 469.1934 12.5627 31.0000 639.0000 17.2160 -999.2500 107.9375 101,3143 513.5696 12.5656 30.8286 736.0000 18.1543 -999.2500 113.0000 101.1612 389.5383 11.5392 30.5224 -999.2500 15.4107 -999.2500 115.2500 BDCC DCCM DRHC LPOM NPLM PDEM RoPC 'r'VD 2.2544 148.4314 0.1813 35.8769 18.3098 -999.2500 330.4548 7700.2793 2.2565 149.3426 0.1918 34.9263 17.6633 -999.2500 337.4656 7743.0576 2.4427 156.5,532 0.2873 33.0896 16.40 70 -999.2500 56.9188 7785.9189 2.4427 163.4007 0.1725 32.24,33 15.8251 34.5000 59.0167 7828.8535 2.4596 143.3807 0.0946 28.3101 13.1422 101.3667 63.2836 7871.8457 BDEC DLAC DSAC NFBM NPSM PDIM RPCM -999.2500 2.0730 1.9521 17.9665 22.8238 -999.2500 2.3120 -999.2500 2.0588 1.9310 18.2416 22.1923 2885.0000 2.2826 -999.2500 2.1740 1.9824 19.2666 20.9644 3170.0000 2.0684 50.0000 2.2829 2.1680 19.9227 20.3951 3502.5000 1.8918 126.0000 2.3567 2.2936 22.4017 17.7674 3832.0O00 2.4858 BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 3.3657 93.9806 5694.2832 313.4912 3.1494 2.3858 -999.2500 3.5404 88.0470 5667.2227 307.2589 3.0923 2.3548 625.0000 3.3764 94.2230 5742.4590 294.7746 2.8027 2.1313 722.0000 3.4127 103.4568 5818.2422 288.8281 2.6063 1.9472 836.0000 3.3580 100.8361 5888.3516 259.9613 3.6427 2.5671 @06cj'~ O86Cj'8cj~ 8899'cjzsg ~8/.8'601. 80/6'~ 0000'96cJ i. lr80~'3 O00cj'oI. Zg 81. 83'/. I. 881.6'3~ ;~6 t ;~'~ .&'808';~ 0000'1;, 1. L cJ689'g809 98tg'88 ~'6/... 99t9'~ I. 999't',L~ ZS~I.'O 089Z.'~t I. g~Zg'8 09~9'G 1. 00cj~'688- 01.g0'91. 9~ 1.6'6Z~ 0000'0098 Z 1.D9'~ lz1~,~'86~ 6899'cj~zcj O000'Zgl~ 1. gZI~G'~ O00Cj' 1. ~89 Z996'91. 991.0'~ ~cJZ I.'~ 0000'96 881.6'6t~ 00~'99 C L6g'SC 6Z8~'0 l~t, I.Z' I.~ 1. Z~68'~ Z81.Z' 1.~ 1. 009~'666- ~;~8 I. '9 I. O00Cg'Scjt 1. lr890'~8 996g'S I. 9886'6Z8 0~86'Z8 1.696'8 0000'90 I. OOG~'666- 91;,1;,6' I. cj~ O000'OC~gg 81~91~'8 Z1;,69'89~ 81.1~C' 1.ZZCJ 6~gg'~ 1.1. 008~'8 00~'688- 000G'886~, Z809'8 I. 6~1r~' ~ 9~ZO'~ 0000'1:,6 61~0' 1. 009 8868'~cj cjooo't L lr9Zt'6~ Z91~'0 0089'0~ 1. 008~'666- 008~'666- 81~0'0L~ 06Z8'001. 81~b'9'8g 9861.'91. 0000'801. 009~'666- 1.0Z~'9L 0000'0098 cjgg~'~ 91~ ZZScj'zO 1. zggg'8 0000'0~ L L O00S'06gt, 8Zcjo'~ 0000'/.61. '~0~ 1. '8~6Z ~LZ~'Ot, O00t,'6t, 1. 889~'~L g8/.6'6~ 9~cj~'O 8'¢8~' LCj 1. 688~'~ 009~'666- ~Z~Cj'9 O000'89 91.~6'ZSt 96g9' 1.01. Zb"g6'~ 9~b"8'91. O000'cjo~ 00~'666- 60~6'1~ 8Zcj 1.'888 O000'ogt, g 801~';~ 1~1.91.'8 896g'009 G~cj'I~GZCj 00g~'686- O000'Z i;6Z8'i; 68~1~'~ 0000'96 09~6'1~ 1.6Z 8868'~G .8899't~ 0Z86'9 L 0986'89 91;'Z0'0 009~'666- O000'8LOL LZO8'8 0Z9~'91~ 0C)6a'8g Z6g6'a 00Ga'666- 0898 0000'001z8 I610~N I618NN OVa9 OI08 I611CId 16ISDN lNG-tN OVSC] OV-la o~a8 CIA.L OdOU 161'ldN I61Od'l OHi:ICi ~OOC] OOO8 dOU OOOd ~ldN ONI OSda ~OdO .LZV I610dS R=IdN O'ldO Hid=JO DEPTH CADE DPLC GRS" NPEM PDCM RADE SPOM 8650.0000 279.8959 16.5007 -999.2500 113.0000 15.3037 3.5728 33.8412 8700,0000 252.2769 10.0334 -9cJ9,2500 121,0000 14.0689 3.9639 34.2718 8750.0000 228.5256 16.4459 -999.2500 110.0000 13.4188 4.3759 33.1624 8800.~ 196.0482 12.6295 -999.2500 128.0000 12.8884 5.1008 33,3916 8850.0000 80.5674 18.6924 -999.2500 83.0000 7.3601 12.4120 25.0280 CPDE DPSC INC NPIM PDDC ROP TCDM 93.2032 372.6591 13.4643 34.8161 1762,0000 15.0051 -999.2500 125.4875 92.8000 323.7668 6.7619 36.0500 1916.0000 13.7757 -999.2500 126.5000 92.5242 299.3972 13.4076 37.3579 2077.0000 13.1268 -999.2500 129.7625 91.2610 280.2970 9.4524 39.9895 2221.0000 12.6011 -999.2500 127.1750 89.8225 117.1865 15.7357 42.7124 2361.0000 7.1194 -999.2500 128.1875 BDCC DCCM ' DRHC LPOM NPLM PDEM ROPC TVD 2.4278 140.4191 0.1161 29.6828 14.1414 64.8000 40.2430 8127.3447 2.5384 131.4418 0.1516 30.0927 14.4218 80.5000 32.5127 8167,8418 2.4288 126.7146 0.2354 29.0374 13.7018 62.8667 35.2126 8208.1465 2.4940 122.8782 0.1870 29.2552 13.6499 94.7333 44.6599 8248.6074 2.3904 62.2651 0.1577 21.3728 8.8287 57.9000 118,1295 8264.5645 BDEC DLAC DSAC NFBM NPSM PDIM RPCM 98.0000 2.2959 2.2185 21.4198 18.7466 6099.5000 2.597O 106.0000 2.3830 2,2820 21.2759 19.0213 6472.5000 2.9838 92,0000 2.1936 2.0367 21.4931 18.3159 6858.5000 3.2232 119.0000 2.3189 2.1942 21.5833 18.4610 7241.5000 3.4394 77.0000 2.2490 2.1438 28.6276 13.5308 7627.5000 8.1242 BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 3.1237 110.9967 5652.5957 270.2271 3.&539 2.6834 1911.0000 3.3764 108,3078 5878.4863 273.2584 4.2948 3.0886 -999.2500 4.0587 109.3163 5768.1729 265.4208 4.7752 3.3400 2214.0000 3.9871 73.6207 5827.8613 267.0475 5.6503 3.5676 2361.0000 3.3069 101.6151 5995.5010 207,1273 15.4460 8.5334 DEPTH AZT BDCC BDEC BDIC CADE CPDE DCCM DLAC DPEC DPLC DPSC DRHC DSAC GRAC GRS INC LPOM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROP ROPC RPCM RPDE SPOM TCDM TVD 8900.0000 87.4629 2.3715 -999.2500 51.9559 57.3662 19. 7935 16,8769 0.0480 -999.2500 45.91 46 32.4731 145.0(X)O 2492,0000 16.0613 4,1368 3.9.503 71.5167 -999.2500 -999. 2500 101.2538 36.7652 128,6375 8319.8828 8950.(XXX) 86.6266 2.2715 -999.2500 49.9199 56.3878 25.6448 22.9410 0,1990 -999.2500 48.9713 35.1879 819.0000 2601.0000 18.2523 4.0162 3.8319 89.5167 -999.2500 -999.2500 171.8334 39,5930 128.6375 6353,8496 137.0000 2.3235 2.2915 19.5330 20.6262 7967.5000 18.0801 814,0000 2.0790 1.9463 18.0669 22,7676 8308.5000 18.8008 -999,2500 2.8928 91.9037 5736.5439 290.4539 -999.2500 19.2471 2604.0000 5,1141 92,9899 5644.6953 308,9960 -999,2500 20.0321 8956,0000 86,8245 2.3207 801.0000 -999.2500 -999.2500 28.3183 44.3621 2.1318 4.7459 22,7648 19.9563 0.2042 1,9957 84.6392 -999.2500 49,3096 30,9445 20,6786 5843.8564 826,7141 -999.2500 15.2911 19.8726 279.4971 2,5991 2.4534 782.9167 8353.0000 -999,2500 -999.2500 -999.2500 33.0935 32.8000 35.3129 35.1655 130.1000 6357.6602 Tape File Start Depth = 6746.000000 Tape Fi~e End Depth = 8956,000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 6 is type: LIS DEPTH AZT CADE CPDE DPLC DPSC GRS INC NPEM NPIM PDCM PDDC RADE ROP SPOM TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 8956.0000 86.8245 2.3207 801.0000 -999.2500 -999.2500 28.3183 44.3621 2.1318 4.7459 22.7648 19.9563 0.2042 1.9957 84.6392 -999.2500 49.3096 30.9445 20.6786 5843.8564 826.7141 -999.2500 15.2911 19.8726 279.4971 2.5991 2.4534 782.9167 6353.0000 -999.2500 -999.2500 -999.2500 33.0935 32.8000 35.3129 35.1655 130.1000 6357.6602 8956.2500 86.8327 2.3230 800.0000 2613.5000 -999.2500 29.3283 44.9750 2.1356 4.7123 22.6293 19.8158 0.2004 2.0020 86.7249 -999.2500 49.3237 31.0129 20.6696 5851.7139 826.4265 -999.2500 15.3391 19.9195 279.9947 2.6721 2.5242 764.5118 -999.2500 -999.2500 -999.2500 -999.2500 33.0681 31.751 4 34.0968 35.2373 130.1000 8357.8203 9000.0000 88.2755 2.3616 -999.2500 39.5929 51.0585 20.3730 17.4775 0.0743 -999.2500 51.7904 26.0980 77.0000 2684.0000 11.9822 3.3725 3.2040 50.6167 -999.2500 -999.2500 77.4304 30.0586 121.6625 8385.6133 69.0000 2.2966 2.2471 24.3668 16,6295 8576.5000 23.6055 149.0000 2.1996 2.1374 23.0672 17.6775 8950.0000 19.0053 9350.0000 88.5355 2.3120 -999.2500 49.3864 56.1203 23.2748 20.4848 0.0932 -999.2500 53.7108 27.6958 1 63.0000 2846.0000 13.0506 3.9838 3.8009 68.7000 -999.2500 -999.2500 29.7733 31.7482 113.4500 6416.1367 2682.0000 3.3539 83.8749 5990.9727 243.1614 -999.2500 25.2571 2840.0000 3.8200 99.2963 5955.0410 255.3204 -999.2500 20.2485 9100.0000 87.4064 2.3165 218.0000 2991.0000 252.7996 303.2351 127.4859 2.2268 4.5541 23.0091 20.2094 0.0855 2.1698 197.3931 -999.2500 54.7323 33.7307 18.7206 5663.5264 233.00(X) 3(X)7.0000 17.2396 21.7783 299.2008 13.5222 13.2307 193.8000 9322.0000 4.2737 3.9557 -999.2500 34.0571 3.1823 3.2978 38.0772 121.2125 8445,4199 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM AZT CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC 'i'VD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 9150.0000 180.0195 16.6468 -999.2500 94,0000 10,5188 5.5550 36,0303 86.7617 202,2560 13.6158 55.3,.'.'.'.'.'.'.'.'.~ 3109.0000 10,2471 -999.25O0 123.1812 2.4253 105.5923 O. 1787 31,7702 15.8682 56.1333 21,7416 8474.1113 85.0000 2.2662 2.1471 19.7738 20.4373 9676.5OOO 4.7453 -999.2500 4,3439 227.5331 5707.3398 285.4570 6.1224 4,9442 9200.0000 -999,2500 -7.7133 -999,2500 54.0000 1.2939 -999.2500 35.0424 86,3894 12,0778 -11,6302 55.7106 -999.2500 1.1974 -999.2500 124.250O 2,8419 31.6790 -0.0596 30.8270 15.2089 34.0644 45,1615 8502.4668 48.0000 2,8810 2.9407 21.6190 19.7921 9967.5000 75.3666 -999.2500 8,3065 52.5167 5090,9697 278.6418 -999.2500 82.7965 9250.00OO -999.2500 0.1006 -999.2500 298.0000 2.7210 -999.2500 36.6079 85.0600 30.0155 -3.5321 57.2400 -999.2500 2.5717 -999.2500 123.1250 2,7083 45.3951 0,1115 32,3226 16.2550 47.9162 100,7547 8529.6348 286,0000 2.6069 2.5326 19.6290 20.8156 10260.0000 31.0615 -999.25O0 5.5561 59.7134 5743,6289 289,3905 -999.2500 33.3161 93O0.0000 -999.2500 28.7372 -999.2500 96.0000 1,8622 -999.2500 26.9125 83.4284 18.7047 26,1459 59.1347 3381 .O000 1,7421 -999,2500 127,1750 2.2186 37.5054 0,1894 23.1373 10,0901 52.6163 82,6573 8556,4258 87.0000 2,0498 1,9235 25.9871 14.7711 1O593.5OOO 49,2O79 -999,2500 3.6076 43.5581 5794.7295 220,5317 -999,2500 53.4626 9350.0000 -999.2500 -0.0680 -999.2500 137.0000 3.8279 -999.2500 33.1279 83,2O0O 46,8173 -3.7069 62.5783 3526,0000 3,6485 -999.25O0 127.0625 2.7112 54.8405 0.1650 29.O04.6 13,9447 98.4910 54,6584 8580,9551 129.0000 2.5673 2.4573 21.9380 18,5539 -999.25O0 20.0319 -999.2500 6,4189 66.3608 5882,1416 265.1757 -999,25OO 21.3598 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM 9400.~ -999.2500 32.5475 -999.2500 102.0000 0.8393 -999.2500 19.5202 9450.0000 -999.2500 30.8897 -999.2500 100.0000 0.9382 -999.2500 20.3754 9500.0000 -999.2500 25.9014 -999.2500 108.0000 1.1233 -999.2500 17.5428 9550.0000 -999.2500 26.3564 -999.2500 82.0000 0.5367 -999.2500 27.5548 9600.0000 -999.2500 22.4506 -999.2500 60.0000 1.3510 -999.2500 22.6486 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 80.4184 7.2957 30.0946 65.5816 -999.2500 0.7651 -999.2500 128.7781 80.3000 8.2945 28.3766 68.6739 -999.2500 0.8588 -999.2500 127.5125 80.3000 10.2265 23.2069 71.5851 3875.0000 1.0346 -999.2500 129.3125 80.3000 4.3906 23.6784 73.1277 -999.2500 0.4797 -999.2500 131.4500 80.8600 12.7091 19.6306 74.5800 -999.2500 1.2517 -999.2500 133.9625 BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM 2.1534 26.4124 0.0391 16.2533 6.2064 50.2667 35.7968 8602.8242 2.1132 2.0871 35.0398 10.9481 11309.50O0 122.7852 2.1818 27.6239 0.0479 17.0445 6.6168 47.8O00 20.4955 8621.2402 79.0000 2.1532 2.1213 34.1935 11.3526 11641.5000 108.4836 2.2671 29.7853 0.0891 14.4287 5.2917 60.7833 72.9369 8639.0918 94.0000 2.1752 2.1158 38.8809 10.0460 11947.0000 88.5795 2.2593 22.3616 0.0527 23.7401 10.4651 53.6500 23.7893 86,53.8340 63.0000 2.2044 2.1692 26.5202 15.1396 12246.0000 199.6278 2.3261 32.2950 0.0680 19.1543 7.7549 50.8500 137.8097 8668.2148 57.0000 2.2581 2.2128 31.2461 12.4738 12540.0000 71.7083 BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 2.9089 34.0834 5990.7373 169.0889 -999.2500 137.0663 3768.000O 2.8270 35.0740 6046.1270 174.8758 -999.2500 120.5623 3847.0000 3.4988 41.6374 6127.4697 155.8623 -999.2500 97.7848 -999.2500 3.1165 36.8880 6O36.9902 225.1332 -999.2500 227.7573 -999.2500 3.0800 42.3074 6017.6807 190.4713 -999.2500 78.6841 DEPTH AZT BDCC BDEC BDIC CADE CPDE DCCM DLAC DPEC DPLC DPSC DRHC DSAC GRAC GRS INC LPOM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROP ROPC RPCM RPDE SPOM TCDM TVD 9650.0000 81,9353 2.2249 -999.2500 5.0279 23.3362 28.3666 25.7618 0.1178 -999.2500 75.3588 32.2338 215.0000 -999.2500 16.1927 0.6053 0.5442 183.0500 -999.2500 -999.2500 140.0124 36.5151 133.0925 8681,1~ 203.0000 2,0975 2.0190 19.9380 20.7548 12789.0000 175,4460 4065,0000 4.1151 30.7576 5821.3604 288.7609 -999.2500 198.8915 9700.0000 82,8179 2,1954 959,0000 -999,2500 -999,2500 13,0517 32,6411 2.0958 4.5114 30,0917 27,5496 0.1238 2.0133 43,1571 -999.2500 77.2154 26,1215 23,6966 5830,4922 965. O0(:X) -999.2500 12,0424 16,6885 243,3409 1.3814 1,2809 117.1389 -999,2500 -999.2500 -999,2500 -999,2500 51.3397 69,7699 76,6187 30,0835 131.5625 8693.0586 948.0000 2.2225 2.1765 27.7693 14.2293 13134.50O0 39.8801 9707.0000 82.5667 2.3121 -999.2500 23,1 647 40.8815 23.2707 20.4805 0,0689 -999,2500 77.7000 22,1715 961,0000 -999.2500 9.5390 2.2151 2.0820 118.1167 -999.2500 -999.2500 15.9779 25.8819 130.3700 8694.6035 -999.25O0 4.2248 57,5004 5985.7256 213.1807 -999,2500 43,1690 Tape File Start Depth = 8956.000000 Tape File End Depth = 9707.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 7 is type: US DEPTH AZT CADE CPDE DPLC DPSC GR$ INC NPEM NPIM PDCM PDDC RADE ROP SPOM TCDM BDCC DCCM DRHC LPOM. NPLM PDEM ROPC TVD 9707.0000 82.5667 2.3121 -999.2500 23.1647 40.8815 23.2707 20.4805 0.0689 -999.2500 77.7000 22.1715 961.0000 -999.2500 9.5390 2.2151 2.0820 118.1167 -999.2500 -999.2500 15.9779 25.8819 130.3700 8694.6035 9707.2500 82.5577 2.3045 -999.2500 21.7749 39.9544 23.7116 20.9375 0.0688 -999.2500 77.7173 21.8221 960.0000 -999.2500 9.3289 2.1080 1.9780 317.7833 -999.2500 -999.2500 105.8954 25.5086 130.3588 8694.6,582 9750.0000 81.8667 2.4086 ~999.2500 33.5028 47.5969 17.6259 14.6305 0.0828 -999.2500 79.5889 17.4465 106.0000 -999.2500 6.8595 2.9651 2.8083 66.9833 -999.2500 -999.2500 110.8856 20.8092 117.3875 8703.1270 9800.0000 81.8628 2.1608 -999.2500 1.6230 17.1931 32.1187 29.6502 0.0886 -999.2500 81.3400 23.3722 38.0000 -999.2500 10.2996 0.2199 0.1839 20.3500 -999.2500 -999.2500 334.7322 27.1629 118.9400 8711,4043 BDEC DLAC DSAC NFBM NPSM PDIM RPCM 948.0000 2.2225 2.1765 27.7693 14.2293 13134.'5000 39.8801 950.0000 2.2130 2.1671 27.9980 14.0227 13136.5000 42.1562 104.0000 2.3258 2.2707 33.6057 11.5918 13401.5000 27.7901 33.3,333 2.0722 2.0132 27.0252 14.9765 13634.0000 496.7163 BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 4.2248 57.5004 5985.7256 213.1807 -999.2500 43.1690 -999.2500 4.2168 55.8261 5959.9687 210.5295 -999.2500 45.9244 -999.2500 2.8884 60.4349 6042.5078 177.8282 -999.2500 29.8483 -999.2500 2.9180 31.6648 6048.7959 222.3236 -999.2500 616.1434 9850.0000 81.8928 2.2099 42.0000 -999.2500 -999.2500 -999.2500 -999.2500 2.1443 3.0166 29.2443 26.6714 0.0656 2.1006 25.2719 -999.2500 82.3428 20.6756 29.3124 5983.0039 44.0000 -999.2500 8.6530 13.3579 201.8684 -999.2500 -999.2500 24.4,3,33 -999.2500 -999.2500 -999.2500 -999.2500 189.0167 -999.2500 -999.2500 24.2815 122.1875 8718.4766 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM AZT CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC 'I'VD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 9900.(XX)O -999.2500 29.0259 -999.2500 42.0000 0,0149 -999.2500 26.4834 9950.0000 -999.2500 27,5884 -999.2500 270.2500 0.0316 -999.2500 29,8776 10000,0000 -999.2500 27.5494 -999.2500 139.0000 0.0135 -999.2500 29.9281 10050.0000 -999.2500 29.0597 -999.2500 108.0000 0,0326 -999.2500 23.5569 10100.0000 -999.2500 24.0620 -999.2500 119.0000 0.0359 -999.2500 28.9496 82.53O3 -999.2500 26.4450 82.9879 -999.2500 0.0082 -999,2500 123.3500 82.9286 -999,2500 24.9552 83.6714 -999.2500 0.0086 -999.2500 125.3750 82.181'2 -999.2500 24.9148 83.9094 4508.0000 0.0082 -999.2500 126.1906 84.1586 -999.2500 26.4801 84.5586 -999.2500 0,0092 -999.2500 126.9500 83,6077 -999.2500 21.3006 86.5654 4668.0000 0.0139 -999,2500 128.5250 2,2137 13,0095 -0,0057 22.7349 9.8818 20,0667 246.9368 8724.8691 2.2382 13.2046 0.0236 25,9271 11.9153 172.6334 236.2709 8730.6426 2,2389 13,0176 0,1073 25.9747 11,9455 105.0167 87.O377 8736,O43O 2.2131 13,3266 0.0567 19.9999 8.2645 53,0500 166.3285 8741.0527 2.2985 12.8462 -0,0117 25,0521 11.3426 59.7833 107.3467 8744.9961 785.0000 2.2147 2.2204 27.5789 14,5664 -999.2500 4269.6484 716.0000 2,2146 2.1988 24.4967 16,5637 13772.0000 2982.5645 137,0000 2.1316 2.0601 24,8324 16.5934 13981.0000 4183.3701 91.0000 2.1689 2.1311 30,487O 12.9755 14051.5000 2539.3633 1 O4.00OO 2,2959 2.3076 25.4335 16,0015 14182.00OO 9382.9199 -999,2500 2,7841 28.9598 6064.1680 217.4655 -999,2500 7038.1904 4463.~ 2.8310 28.787O 5989.4OO4 241.8563 -999.2500 6876.0195 -999.2500 3.2861 75,7433 6081.8145 242.2201 -999.2500 7036.1904 -999.2500 2,4275 32.8207 6066.293O 196,7906 -999.2500 6649,6875 -999.2500 3.8813 33.0386 6O47.6250 235,1659 -999.2500 5362,5312 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM 10150.0000 -999.2500 23.0615 -999.25O0 73.0000 0.0585 -999.2500 25.8292 10200.0000 -999.2500 30.1043 21.6700 48.0000 0.0147 -999.2500 27.3705 10250.0000 -999.2500 -999.2500 21.3100 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 -999.2500 -999.2500 26.1700 -999.2500 -999.2500 -999.2500 -999.2500 10350.0000 -999.2500 -999.2500 22.9800 -999.2500 -999.2500 -999.2500 -999.2500 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 84.4833 -999.2500 20.2637 89.85(X) -999.2500 0.0340 -999.2500 129.9875 63.2000 -999.2500 27.5626 91.2303 -999.2500 0.0082 -999.2500 132.6875 83.2000 -999.2500 -999.2500 91.5335 -999.2500 -999.2500 178.0700 133.5875 83.2094 -999.2500 -999.2500 91.7392 -999.2500 -999.2500 75.4000 -999.2500 83.2525 -999.2500 -999.2500 91.5994 -999.2500 -999.2500 65.2000 -999.2500 BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD 2.3156 13.8447 0.0268 22.1221 9.5091 61.1167 27.1631 8746.4395 2.1952 13.0085 0.0498 23.5670 10.3971 38.8500 185.5771 8745.8242 -999.2500 -999.25O0 -999.2500 -999.2500 -999.2500 -999.2500 147.6618 8744.5293 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 75.4000 8743.2031 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 65.2000 8741.7715 BDEC DLAC DSAC NFBM NPSM PDIM RPCM 68.0000 2.2889 2.2710 28.0967 14.2000 14372.0(X)0 1645.6279 45.0000 2.1454 2.1122 26.6977 15.0729 -999.2500 4281.6826 -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 -999.2,,-,-,-,-,-,-,-,-,~ BDIC DPEC GRAC NNBM NRCM RACM RPDE -999.2500 3.5829 32.3377 6045.6387 212.8057 -999.2500 2870.4058 -999.2500 3.1935 29.5509 6041.6973 223.8113 -999.2500 7085.8555 -999.2500 -999.2500 21.3100 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 26.1700 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 22.9800 -999.2500 -999.2500 -999.2500 -999.2500 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM AZT CPDE DPSC INC NPIM PDDC ROP TCDM BDCC DCCM DRHC LPOM NPLM PDEM ROPC TVD BDEC DLAC DSAC NFBM NPSM PDIM RPCM BDIC DPEC GRAC NNBM NRCM RACM RPDE 10400.0000 -999,2500 -999.2500 27.6700 -999.2500 -999.2500 -999.2500 -999.2500 83,2645 -999.2500 -999.2500 91,4171 -999,2500 -999.2500 67,0600 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 67,06OO 8740.4570 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 27.6700 -999.2500 -999,2500 -999.25OO -999,2500 10450,0000 -999.2500 -999.2500 30.4400 -999,2500 -999.2500 -999.2500 -999.2500 83.2215 -999,2500 -999.2500 91,1590 -999.2500 -999.2500 46.8400 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 46.8400 8739,3496 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 30.4400 -999.2500 -999.2500 -999.2500 -999,2500 10500,0000 -999.2500 -999.2500 31.2500 -999,2500 -999.2500 -999.2500 -999.2500 83,2000 -999.2500 -999.2500 91,1053 -999.2500 -999.2500 76,2100 -999,25(X) -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 76,21 O0 8738.2852 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 31.2500 -999,2500 -999.2500 -999.2500 -999.2500 1O550.000O -999,2500 -999,2500 30.9900 -999.2500 -999.2500 -999.2500 -999.2500 83,2000 -999.2500 -999.2500 91.2558 -999.2500 -999.2500 55.2000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 55.2000 8737.2637 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 30.9900 -999.2500 -999.2500 -999.2500 -999.2500 106O0.0000 -999.2500 -999.2500 32.8OO0 -999.2500 -999,2500 -999.2500 -999,2500 83.2000 -999.2500 -999.2500 90.9487 -999.2500 -999.2500 45.9600 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 45.9600 8736,4570 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 32.8OOO -999,2500 -999.2500 -999.2500 -999.2500 DEPTH CADE DPLC GRS NPEM PDCM RADE SPOM 10650.0000 -999.2500 -999.2500 23.0100 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 -999.25OO -999.25OO 23.84OO -999.2500 -999.25OO -999.2500 -999.2500 10750.0000 -999.2500 -999.2500 23.4500 -999.2500 -999.2500 -999.2500 -999.2500 10800.0000 -999.2500 -999.2500 30.5900 -999.2500 -999.2500 -999.2500 -999.2500 10850.0000 -999.2500 -999.2500 32.8800 -999.2500 -999.2500 -999.2500 -999.2500 AZT CPDE DPSC INC NPIM PDDC ROP TCDM 83.2000 -999,2500 -999,2500 90.3842 -999,2500 -999.2500 46.7600 -999.2500 83.2000 -999.2500 -999.2500 89.9916 -999.2500 -999.2500 40.2800 -999.2500 83.2000 -999.2500 -999.2500 89.6475 -999.2500 -999.2500 61.9600 -999.2500 83.2000 -999.2500 -999.2500 88.9572 -999.2500 -999.2500 65.4600 -9cJ9.2500 83.2000 -999.2500 -999.2500 88.2048 -999.2500 -999.2500 133.1400 -999.2500 BDCC DCCM DRHC LPOM NPLM PDEM ROPC 'I'VD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 46.76O0 8735.7715 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 40.2800 8735.6621 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 61.9600 8735.7148 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 65.4600 8736.5625 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 133.1400 8737,5762 BDEC DLAC DSAC NFBM NPSM PDIM 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 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25OO -999.2500 -9cJ9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 BDIC DPEC Gl{AC NNBM NRCM RACM RPDE -999.2500 -999.2500 23.0100 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 23.8400 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 23.4500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~.5900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 32.8800 -999.2500 -999.2500 -999.2500 -999.2500 DEPTH AZT BDCC BDEC BDIC CADE CPDE DCCM DLAC DPEC DPLC DPSC DRHC DSAC Gl:LAC GRS INC LPOM NFBM NNBM NPEM NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROP ROPC RPCM RPDE SPOM TCDM 'rVD 10900.0000 83.2000 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 31.5300 31.5300 86.9521 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -gcjg,25(X) -999.2500 -999,2500 -999.2500 45.4200 45,4200 -999.2500 -999.2500 -999.2500 -999,2500 8740,0918 10950.0000 83.2000 -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 85,9500 -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 53.0400 53.0400 -999.2500 -999,2500 -999.2500 -999.2500 8742,8105 11000.0000 83.2000 -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 85,9500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25(X) -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 37.0500 37.0500 -999.2500 -999.2500 -999.2500 -999.2500 8745.3418 11010.0000 83.2000 -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 85.9500 -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 8747.0488 Tape File Start Depth = 9707.000000 Tape File End Depth = 11010.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 8 is type: LIS DEPTH BDC2 BDE2 CPD2 DCC2 DLA2 DPS2 DRH2 DSA2 NFB2 NNB2 NPE2 NPS2 NRC2 PDC2 PDI2 RAD2 RPC2 BDI2 DPE2 GRA2 NPI2 PDD2 ,~ RPD2 CAD2 DPL2 LPO2 NPL2 PDE2 SPO2 9190.0000 -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 33.2432 19.9479 5965.~ 292.7777 -999.2500 16.9010 21.4473 295.8412 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 37.5690 9190.2500 2.4918 294.0000 -999.2500 -999.2500 2.3828 9.5876 0.1090 2.3101 20.0521 5970.9990 292.5555 21.3255 294.5900 -999.2500 -999.2500 -999.2500 -999.2500 2.0000 6.6837 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12.7600 33.0631 16,7765 -999.2500 37.3812 Tape File Start Depth = 9190.000000 Tape File End Depth = 9246.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 9246.0000 -999.2500 -999.2500 -999.2500 -999.2500 35.0308 48.4778 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 54.2907 -999.2500 -999.2500 -999.2500 49.0000 -999.2500 -999.2500 -999.2500 -999.2500 3.0691 2.9088 213.0000 130.0000 -999.2500 26.6251 28.5463 -999.2500 9200.0000 2.2971 266.7778 -999.2500 -999,2500 -999.2500 -999.2500 2.2697 6.5213 24.1452 21.3869 0.0274 2.2514 71.1924 30.0440 21.1562 5831.8896 264.6666 -999,2500 14.6775 19.2715 272.8995 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 34.2207 Tape Subtile 9 is type: US