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190-166
Originated: Delivered to:17-Jan-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 1 2 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 1 3 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 1 4 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 1 5 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 1 6 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 1 7 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 1 8 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1 9 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 1 10 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39991 T39991 T39992 T39993 T39994 T39994 T39995 T39996 T39997 T39998 190-166 190-180 194-064 203-115 217-078 223-056 179-095 199-089 1/23/2025 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 1 2 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 1 190-166 190 180 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8276'feet None feet true vertical 6402' feet None feet Effective Depth measured 8276'feet 7292', 7324', 7385'feet true vertical 6402' feet 5667', 5690', 5734'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" J-55/ L-80 7564' MD 5863' TVD Packers and SSSV (type, measured and true vertical depth) 7292' MD 7324' MD 7385' MD N/A 5667' TVD 5690' TVD 5734' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 129 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: HB Retrvbl Packer SSSV: None Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer 8012-8032' 6202-6217' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 68 Gas-Mcf MD 1100 Size 115' 363 116134 58 155286 151 measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-166 50-029-22115-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025647 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1A-26 Plugs Junk measured Length Production Scab Liner 1970' 6231' 644' Casing 1854' 6370' 5" 2005' 8233' 8145' 6303' 4598' 115'Conductor Surface Prod Tie-Back 16" 9-5/8" 80' 4633' 3738' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:52 am, Dec 12, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.12.12 07:42:29-09'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 10/21/2024 REPAIR WELL BRUSH & FLUSH PATCH SETTING AREA FROM 7300' TO 7100', TAG BOTTOM @ 8010' SLM, CLEAN DRIFT W/ 23' x 2.29" DUMMY PATCH TO 7400' SLM, SET 2.29" P2P @ 7314' RKB (CE) (OAL 3.55" / SN:CPP287080). IN PROGRESS. 10/22/2024 REPAIR WELL SET P2P LOWER MID ELEMENT @ 7314' RKB, UNABLE TO OBTAIN PASSING 2500 PSI CMIT WITH 2 SEPERATE TTS TEST TOOL ATTEMPTS, SAME RESULT FOR D&D HOLE FINDER, PULLED TEST TOOL....IN PROGRESS 10/23/2024 REPAIR WELL PULLER P2P LOWER PACKER FROM 7314' RKB, SET 2-7/8 K3 PACKOFF ON F-STOP @ 7326' RKB (LIH=62"), SET SLIP STOP ON K3 PACKOFF @ 7325' RKB (LIH=18") 10/27/2024 REPAIR WELL (AC EVAL) CMIT T X IA PASSED TO 2500 PSI. 11/14/2024 REPAIR WELL EQUALIZED 2 7/8 K3 PLUG @ 7324' RKB, PULLED 2 7/8 SLIP STOP @ 7323' RKB, PULLED 2 7/8 K-3 PLUG @ 7324' RKB, BRUSH & FLUSH PATCH AREA FROM 7400' TO 7200', SET 2.29" LOWER P2P @ 7326' RKB (CE) (OAL 3.55' / SN:CPP287091), SET 2 7/8 TTS TEST TOOL IN 2.29" LOWER PACKER @ 7326' RKB CMIT TBG x IA 2500 PSI (FAILED). WING VLV APPEARED TO BE POINT OF FAILING TEST. IN PROGRESS 11/15/2024 REPAIR WELL CMIT TBG x IA 2500 PSI (PASS), PULLED 2 7/8 TTS TEST TOOL @ 7326' RKB, SET 2.29" P2P SPACER ANCHOR LATCH @ 7294' RKB (CE) TOP @ 7291.86' RKB, SET 2 7/8 TTS TEST TOOL IN UPPER 2.29" P2P @ 7292' RKB, MIT TBG 2500 PSI (PASS), CMIT TBG x IA 2500 PSI TEST INCONCLUSIVE, PRESSURE KEEPS LEAKING BY WING VALVE TO FLOWLINE, DECISION MADE TO FOREGO PRESSURE TEST, PULLED 2 7/8 TTS TEST TOOL @ 7291' RKB. JOB COMPLETE, WELL READY TO BOL FOR RE-TIFL 11/17/2024 MAINTAIN WELL HOT DIESEL FLUSH FLOWLINE PUMPED 25 BBLS 180* DSL DWN FL 11/21/2024 REPAIR WELL (AC EVAL) RE-TIFL (PASSED) 1A-26 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,017.0 1A-26 5/22/2024 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Tbg Patch 1A-26 11/15/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER - old tubing component depths questionable 8/16/1993 osborl NOTE: Junk was cemented in hole 8/15/1993 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulatead 24" 16 15.06 36.0 80.0 80.0 65.00 H-40 WELDED SURFACE 9 5/8 8.76 35.0 4,632.8 3,738.4 36.00 J-55 BTC PROD TIE-BACK 7 6.28 35.0 2,004.8 1,854.5 26.00 L-80 TCII PRODUCTION 7 6.28 2,002.6 8,233.4 6,369.8 26.00 J-55 BTC SCAB LINER 5 4.15 7,500.5 8,145.0 6,302.8 18.00 N-80 FL4S Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.7 Set Depth 7,354.1 Set Depth 5,711.9 String Max No 2 7/8 Tubing Description TUBING - WO 2013 - 3 1/2" x 2 7/8" x 3 1/2" Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-m ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.7 26.7 0.00 HANGER 7.063 McEVOY TUBING HANGER GEN 4 McKevo y Gen 4 Type: DP-1-D- S-3-NL 2.950 62.2 62.2 1.20 XO Reducing 4.520 X-over 3 1/2" x 2 7/8" (4.52" OD) 2.441 508.7 508.6 2.77 NIPPLE 3.703 CAMCO DS NIPPLE Camco T- 091157 2.312 3,036.2 2,585.3 45.13 GAS LIFT 4.750 Camco KBMG 2.347 4,695.3 3,783.9 43.05 GAS LIFT 4.750 Camco KBMG 2.347 5,885.7 4,632.5 46.31 GAS LIFT 4.750 Camco KBMG 2.347 6,695.2 5,229.1 41.65 GAS LIFT 4.750 Camco KBMG 2.347 7,281.6 5,660.2 44.48 GAS LIFT 4.750 Camco KBMG 2.347 7,330.5 5,695.1 44.51 XO Enlarging 3.500 Crossover 2 7/8" x 3 1/2" 2.441 7,338.3 5,700.7 44.50 LOCATOR 4.500 BAKER LOCATOR Baker Oil Tools PN: 450- 01-4081, Control #:Unrea dable 2.990 7,341.6 5,703.0 44.50 SEAL ASSY 3.750 BAKER 80-40 SEAL ASSEMBLY Baker Oil Tools PN: 450- 01-4081, Control #:Unrea dable 2.990 Top (ftKB) 7,371.4 Set Depth 7,564.2 Set Depth 5,863.5 String Max No 3 1/2 Tubing Description TUBING - WO 1993 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,371.4 5,724.2 44.47 PBR 5.125 GBH-22 PBR Baker 3.000 7,385.1 5,734.0 44.46 PACKER 6.063 HB RETRIEVABLE PACKER Baker 2.890 7,399.3 5,744.2 44.45 NIPPLE 4.500 'D' NIPPLE NO GO PROFILE Camco 2.750 7,563.2 5,862.8 41.99 SOS 3.865 SHEAR OUT SUB Baker 3.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,291.9 5,667.5 44.51 PACKER - PATCH - UPR 2-7/8" P2P UPR PATCH PKR MID-ELEMENT AT 7294' RKB WITH ANCHOR LATCH AND SPACER PIPE, OAL 32' TTS P2P CPP2 87039 / CPAL 28702 6 11/15/2024 1.375 7,295.1 5,669.8 44.52 SPACER PIPE 2-1/16" P-110 SPACER PIPE 11/15/2024 1.600 7,302.0 5,674.7 44.53 LEAK LEAK AT 7302' RKB IDENTIFIED VIA LDL 7/18/2024 2.441 7,323.9 5,690.3 44.51 PACKER - PATCH - LWR 2-7/8" P2P LWR PATCH PKR MID-ELEMENT AT 7326' RKB, OAL 3.55' TTS P2P CPP2 87091 11/14/2024 1.375 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,036.2 2,585.3 45.13 1 GAS LIFT GLV BK 1 1,225.0 9/25/2024 0.188 4,695.3 3,783.9 43.05 2 GAS LIFT DMY BK 1 0.0 5/23/2024 0.000 5,885.7 4,632.5 46.31 3 GAS LIFT GLV BK 1 1,210.0 9/25/2024 0.250 6,695.2 5,229.1 41.65 4 GAS LIFT OV BK 1 0.0 9/24/2024 0.313 7,281.6 5,660.2 44.48 5 GAS LIFT DMY BK 1 0.0 9/24/2024 0.000 1A-26, 12/10/2024 2:40:52 PM Vertical schematic (actual) PRODUCTION; 2,002.6-8,233.4 SCAB LINER; 7,500.5-8,145.0 APERF; 8,012.0-8,032.0 CMT SQZ; 7,998.0-8,032.0 RPERF; 7,998.0-8,032.0 RPERF; 7,978.0-7,985.0 CMT SQZ; 7,978.0-7,985.0 CMT SQZ; 7,700.0-7,725.0 NIPPLE; 7,399.3 PACKER; 7,385.1 PACKER - PATCH - LWR; 7,323.9 SPACER PIPE; 7,295.1 LEAK; 7,302.0 PACKER - PATCH - UPR; 7,291.9 GAS LIFT; 7,281.6 GAS LIFT; 6,695.2 GAS LIFT; 5,885.7 GAS LIFT; 4,695.3 SURFACE; 35.0-4,632.8 GAS LIFT; 3,036.2 PROD TIE-BACK; 35.0-2,004.8 CMT PLUG (plug); 1,985.0 ftKB CMT PLUG; 41.0 ftKB NIPPLE; 508.7 CONDUCTOR Insulatead 24"; 36.0-80.0 7" TIE-BACK; 35.0 ftKB HANGER; 26.7 KUP PROD KB-Grd (ft) 35.01 RR Date 1/10/1991 Other Elev 1A-26 ... TD Act Btm (ftKB) 8,276.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292211500 Wellbore Status PROD Max Angle & MD Incl (°) 47.36 MD (ftKB) 6,000.00 WELLNAME WELLBORE1A-26 Annotation Last WO: End Date 10/10/2013 H2S (ppm) 50 Date 8/10/2016 Comment SSSV: Nipple Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 1,988.5 1,843.1 45.58 Collar 7.000 HES 7", Type "H" ES Cementer with 6 shear pins ( 3300 PSI to open) bakerlocked Halliburto n Type "H", CPAI part # 13517843 6.171 7,500.5 5,816.9 43.69 SLEEVE 5.750 BAKER SETTING SLEEVE 5.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,700.0 7,725.0 5,965.8 5,984.7 C-4, 1A-26 6/3/1992 6.0 CMT SQZ Squeezed 7,978.0 7,985.0 6,176.4 6,181.7 A-5, 1A-26 8/16/1993 4.0 RPERF 180° Phasing' SWS 3 3/8" HSD on WO Rig 7,978.0 7,985.0 6,176.4 6,181.7 A-5, 1A-26 5/31/1991 4.0 CMT SQZ Squeezed; HLS 4.5" Casing Guns 7,998.0 8,032.0 6,191.5 6,217.2 A-4, 1A-26 5/31/1991 4.0 CMT SQZ Squeezed; HLS 4.5" Casing Guns 7,998.0 8,032.0 6,191.5 6,217.2 A-4, 1A-26 8/16/1993 4.0 RPERF 180° Phasing' SWS 3 3/8" HSD on WO Rig 8,012.0 8,032.0 6,202.1 6,217.2 A-4, 1A-26 8/16/1993 4.0 APERF 180° Phasing' SWS 3 3/8" HSD on WO Rig Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 35.0 41.0 35.0 41.0 7" TIE-BACK Pump out BOP Stack. Blow down circulating lines. Lift Stack. Observe top of Cement 5.5-ft from surface. Mix 1 1/2, 5 gal buckets of cement and bring the top of cement to just below the annulus valve outlet. 10/3/2013 41.0 1,988.5 41.0 1,843.1 CMT PLUG Rig down top drive, blow down lines. Remove HT38 x 7" TCII crossover. Install 7" BTC x TCII crossover and Dowell cement head w/ plug loaded. Rig up 2" hoses, etc. Schlumberger Cementers on location and rig up. Circulate and condition well bore with 8.6 lb/gal Brine using the Rig Pump at 5.0 bpm/170 psi. Total fluid pumped = 344 bbls. Pre-Job Safety Meeting with all. Cementers prime up. Pump 5 bbls of fresh water. Pressure test lines at 4,100 psi. Good test. Batch up Cement. Pump 10.0 bbls of 15.5 lb/gal Neat Cement (yield .93 cuft/sx) at 4.0 bpm/150 psi. Pump 71 bbls of Pressureseal Cement (yield .96 cuft/sx, Water 3.516 gal/sx, 4.295 lb/sx aggregate, 2 ppb LCM) with an average rate of 4.0 bpm, average pressure 100 psi, Density 15.7 lb/gal. Pump 10 bbls of 15.7 lb/gal Neat Cement (yield .93 cuft/sx, Water 3.541 gal/sx) at 3.8 bpm/50 psi. Shut down. Launch Plug. Cementer pump an additional 2.0 bbls of Neat Cement on top of the Plug. Shut down. Close 7" Pipe Rams, open OA. Bring Rig Pump on line to displace Plug. Cementers wash up and rig down. Displaced Plug as follows: 10 bbls away, rate 4.1 bpm/120 psi. 20 bbls away, rate 3.2 bpm/400 psi. 30 bbls away, rate 3.0 bpm/590 psi. 40 bbls away, rate 2.8 bpm/665 psi. 46 bbls away, rate 2.6 bpm/735 psi Neat Cement returns to surface. 55 bbls away, rate 2.6 bpm/935 psi. Good Pressureseal Cement to surface. Shut down. Close Annulus Valve. Bring Pump back on line and squeeze away 5.5 bbls of Cement at 1.0 bpm/880 psi. 60.5 total pumped. Open Annulus Valve for the remainder of the displacement at 1.0 bpm/910 psi. Plug bumped at 20:00 hrs with a total of 65 bbls pumped with a final pressure 910 psi. Slowly ramp up the final closing pressure up to 2,400 psi. Shut down. Monitor at 2,400 psi. Release pressure and monitor no flow back. CIP 2000 hrs 10/3/2013. 10/3/2013 1A-26, 12/10/2024 2:40:52 PM Vertical schematic (actual) PRODUCTION; 2,002.6-8,233.4 SCAB LINER; 7,500.5-8,145.0 APERF; 8,012.0-8,032.0 CMT SQZ; 7,998.0-8,032.0 RPERF; 7,998.0-8,032.0 RPERF; 7,978.0-7,985.0 CMT SQZ; 7,978.0-7,985.0 CMT SQZ; 7,700.0-7,725.0 NIPPLE; 7,399.3 PACKER; 7,385.1 PACKER - PATCH - LWR; 7,323.9 SPACER PIPE; 7,295.1 LEAK; 7,302.0 PACKER - PATCH - UPR; 7,291.9 GAS LIFT; 7,281.6 GAS LIFT; 6,695.2 GAS LIFT; 5,885.7 GAS LIFT; 4,695.3 SURFACE; 35.0-4,632.8 GAS LIFT; 3,036.2 PROD TIE-BACK; 35.0-2,004.8 CMT PLUG (plug); 1,985.0 ftKB CMT PLUG; 41.0 ftKB NIPPLE; 508.7 CONDUCTOR Insulatead 24"; 36.0-80.0 7" TIE-BACK; 35.0 ftKB HANGER; 26.7 KUP PROD 1A-26 ... WELLNAME WELLBORE1A-26 Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1 2 1A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1 3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1 4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1 6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1 7 1G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1 8 1G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1 9 1G-07A 50-029-20872-01 909383029 Kuparuk River Leak Detect Log Field- Final 2-Jul-24 0 1 10 1G-07A 50-029-20872-01 909383029 Kuparuk River Multi Finger Caliper Field & Processed 11-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39431 T39431 T39432 T39432 T39433 T39434 T39435 T39435 T39436 T39436 190-166 199-084 200-183 196-096 182-130 218-051 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:29:49 -08'00' 11A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1 21A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1 190-166 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED -El' Logs 'of various kinds . n Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell n TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl STATE OF ALASKA RECEIVED r ALA.OIL AND GAS CONSERVATION COMMS ION REPORT OF SUNDRY WELL OPERATIONS NOV 0 5 201 1.Operations Performed: Abandon r Repair w ell ri Rug Perforations r Perforate r Other sj , Alter Casing IV Pull Tubing y, Stimulate-Frac r Waiver fl Time Extension ( 3 Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r A. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 190-166 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-22115-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 • 1A-26 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CCL,CBL,CAST-M Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8276 feet Plugs(measured) 7426 true vertical 6402 feet Junk(measured) none Effective Depth measured 8153 feet Packer(measured) 7368 true vertical 6307 feet (true vertical) 5722 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN: 44 16 80 80 SURFACE 4598 9.625 4633 4110 . SCAB LINER 644 5 8145 • 03 PRODUCTION 8198 7 8233 6370 N� D r 8 2O ' Perforation depth: Measured depth: 7978-7985, 7998-8032 SC O True Vertical Depth: 6176-6182,6192-6217 �•n�` Tubing(size,grade,MD,and TVD) 2.875", L-80, 7354 MD, 5712 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER'HB'RETRIEVABLE PACKER @ 7368 MD and 5722 TVD NIPPLE-CAMCO DS NIPPLE @ 509 MD and 509 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory ('° Development W. Service r Stratigraphic r 16.Well Status after work: Oil 170 - Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG `, 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-471 ./ Contact Jake Voss t 265-6935 Email Jake.Vossconocophillips.com Printed Name J ke Voss / Title Wells Engineer Signature '/�--- Phone:265-6935 Date i'/Li/1.3- RBDMS NOV - 5 ,ri Form 10-404 Revised 10/2012 / Submit Original Only [� a KUP PROD • 1A-26 F Conoco hillips t' Well Attributes Max Angle&MD TD Alaska file Wel!bore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Wm(ftKB) car.30,eps 500292211500 KUPARUK RIVER UNIT PROD 47.36 6,000.00 8,276.0 ... Comment H2S(ppm) 'Date Annotation 'End Date KB-Grd(ft) 1 Rig Release Date 1A-26,10/29/2013759.40 AM SSSV:Nipple 196 8/14/2012 Last WO: 10/10/2013 35.011 1/10/1991 Vertical schematic(actual) Annotation 'Depth(MOB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,364.0 10/25/2013 Rev Reason:TAG,GLV C/O osborl 10/29/2013 HANGER,267. 7-- III Casing Strings ,,.. ■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(IUD)... WtlLen(I...Grade Top Thread jTF�I CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H-40 WELDED .. j Insulatead 24' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 7 TIE-BACK;35.0 SURFACE 9 5/8 8.765 35.0 4,632.8 3,738.4 36.00 J-55 BTC IIIE. Casing Description OD(in) 10(In) Top(ftKB) Set Depth(ftKB) Set Depth(Noy.. Wt/Len p...Grade Top Thread PROD TIE-BACK 7 6.276 35.0 2,004.8 26.00 L-80 TCII Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread al : PRODUCTION 7 6.276 2,002.6 8,233.4 6,369.8 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR Insulatead 24.; >. ■ SCAB LINER 5 4.151 7,500.5 8,145.0 6,302.8 18.00 N-80 FL4S 36.0-80.0 ';.i i Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc'(°) Item Des Com (in) NIPPLE;509.7 7,500.5 5,816.9 43.69 SLEEVE BAKER SETTING SLEEVE 5.250 7,507.8 5,822.2 43.49,HANGER BAKER LINER HANGER 4.437 Tubing Strings Tubing Description 'String Ma...'ID(in) ITop(ftKB) 'Set Depth R./Set Depth(ND)(...I Wt(lb/ft) 'Grade 'Top Connection TUBING WO 2013 27/8 2.441 267 7,35411 5,711.9 650 L-80 EUE-m Auto cement plug;1,930.0 Completion Details CMT PLUG;41.0 P Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc](°) Item Des Com (in) 26.7 26.7 0.00 HANGER McEvoy TUBING HANGER 2.950 II 622 62.2 1.20 XO Reducing Crossover 3-1/2"EUE-m box x 2-7/8""EUE pin 2.875 • 508.7 508.6 2.77 NIPPLE CAMCO DS NIPPLE 2.312 B 7,330.5 5,695.1 44.51 XO Enlarging CROSSOVER 2 7/8"x3.5" 2.441 GAS LIFT;3,036.2 :: • 7,338.3 5,700.7. 44.50 LOCATOR BAKER LOCATOR 2.990 ill 7,341.6 5,703.0 44.50 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 Tubing Description 'String Ma...'ID(in) 'Top(ftKB) 'Set Depth(ft..'Set Depth(ND)(...I Wt(Ib/ft) 'Grade 'Top Connection TUBING WO 1993 31/2 2.992 7,3541 7,546.9 5,850.8 930 J-55 EUESrdMOD Completion Details Nominal ID SURFACE;350-4.632.8- Ak Top(ftKB) Top(TVD)(ftKB) Top Inc!(°) Item Des Com (in) 7,354.1 5,711.9 44.49 PBR BAKER GBH-22 PBR 3.000 GAS LIFT;4,695.3 7,367.8 5,721.7 44.48 PACKER BAKER HB RETRIEVABLE PACKER 2.890 II 7,382.1 5,731.8 44.46 NIPPLE CAMCO'D'NIPPLE NO GO PROFILE 2.750 7,546.0 5,850.1 42.46 SOS BAKER SHEAR OUT SUB 3.500 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5,885.7 Top(ND) Top Inc! ■ Top(ftKB) (ftKB) 0) Des Com I Run Data ID(in) El 7,426.0 5,763.2 44.26 PLUG INFLATABLE BRIDGE PLUG 9/18/2013 0.000 Perforations&Slots GAS LIFT;6,695.2 tat Shot aDens IR Top(ND) Mrs(TVD) (shotslf Top(ftKB) Btm(ftKB) TVD) (ftKB) Zone Date it Type Com 7,700.0 7,725.0 5,965.8 5,984.7 C-4,1A-26 6/3/1992 6.0 CMT Squeezed GAS LIFT;7,281.6 4 SQZ B 7,978.0 7,985.0 6,176.4 6,181.7 A-5,1A-26 8/16/1993 4.0 RPERF 180 deg.Phasing'SWS B 3 3/8'HSD on WO Rig a 7,978.0 7,985.0 6,176.4 6,181.7 A-5,1A-26 5/31/1991 4.0 CMT Squeezed;HLS 4.5" • SQZ Casing Guns LOCATOR;7,338.3 7,998.0 8,032.0 6,191.5 6,217.2 A-4,1A-26 8/16/1993 4.0 RPERF 180 deg.Phasing'SWS 33/8"HSD on WO Rig SEAL ASSY;7,341.6 = 7,998.0 8,032.0 6,191.5 6,217.2 A-4,1A-26 5/31/1991 4.0 CMT Squeezed;HLS 4.5" PBR;7,354.1 SQZ Casing Guns NMI J . 8,012.0 8,032.0 6,202.1 6,217.2 A-4,1A-26 '8/16/1993 4.0 APERF 180 deg.Phasing'SWS PACKER;7,367.8 3 3/8"HSD on WO Rig Mandrel Inserts NIPPLE;7,382.1 ' St ati C on Top(ND) Valve Latch Port Size TRO Run PLUG;7,426.0 on Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 3,036.2 2,585.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/8/2013 2 4,695.3 3,783.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/8/2013 I.-'.' 1 3 5,885.7 4,632.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/8/2013 4 6,695.2 5,229.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/8/2013 SOS;ZSas.o _ 5 7,281.6 5,660.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/26/2013 Notes:General&Safety CMT 502;7,700.0-7,725.0 End Date Annotation 8/15/1993 NOTE:Junk was cemented in hole 8/16/1993 NOTE:WORKOVER-old tubing component depths questionable 6/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 RPERF;7,978.0-7,985.0 CMT SOZ;7,978.0-7,985.0 I CMT SOZ;7,9900-8,032.0 RPERF;7,9980-8,032.04 APERF;8,012.08,032.0- SCAB LINER;7,500.5-8,145.0 di I PRODUCTION;2,002.6.8,233.4 A Amk1A-26 Pre and Post Rig Well Work Sum Pre-Rig Well Work DATE SUMMARY 9/2/2013 (PRE-RWO): FT T& IC LDS (ALL FUNCTIONED). RE-TORQUED TO 450 FT/LBS. T-POT PASSED. T-PPPOT PASSED. IC-POT PASSED. IC-PPPOT PASSED. 9/15/2013 DRIFTED TBG WITH 11'x 1.7"&7'x 1.69" (20.19') DUMMY IBP. TAGGED @ 7994' SLM. MEASURED BHP @ 7934'SLM: 2498 PSI. SET 3-1/2 ER TEST TOOL IN PATCH @ 7181' RKB. PULLED OV @ 7119', GLV @ 6235' RKB. IN PROGRESS. 9/16/2013 PULLED GLVs @ 4490'&3045' RKB. SET DVs @ 6235', 4990' &3045' RKB. PULLED 3-1/2 ER TEST TOOL @ 7181' RKB. READY FOR E-LINE. 9/18/2013 SET IBP MID-ELEMENT AT 7426'. CCL TO MID-ELEMENT OFFSET: 17.7', CCL STOP DEPTH: 7408.3'. LOG CORRELATED TO TUBING-WI-1Y RECORD DATED 16-SEPT-1993. JOB IN PROGRESS. 9/18/2013 FLUID PACKED TBG & IA WITH DIESEL. CMIT T X IA(PASS), DRAW DOWN TEST GOOD, DUMP BAIL i/ CaCO3—7'ON IBP @ 7426' RKB. TBG OPEN 3.36"TO 1808' RKB. SET ISO SLEEVE IN SSSV @ SAME ( 2.70" ID). SET BPV. COMPLETE. Post-Rig Well Work 10/19/2013 TAGGED @ 7354' SLM EST. 13'OF FILL ON IBP @ 7426' RKB; BAIL DEBRIS DOWN TO 7434' RKB. IN PROGRESS 10/19/2013 (MISC)VERIFIED VR PLUG BEHIND IA COMPANION FLANGE. VERIFIED NO VR PLUG HAS BEEN INSTALLED IN OA COMPANION. REPLACED API NEEDLE VALVE WITH AN ALEMITE FITTING OA IA COMPANION FLANGE. REPLACE OA NIPPLE WITH A BULL PLUG AND ALEMITE FITTING. OA TOC @ 3' 10". 10/20/2013 BAILED 2' OF DEBRIS FROM TOP OF IBP @ 7426' RKB. TAGGED TOP OF DEBRIS @ 7364' SLM IMPRESSION BLOCK SHOWS METAL. IN PROGRESS. 10/21/2013 BAIL 1' OF DEBRIS ON TOP OF IBP @ 7426' RKB. IN PROGRESS. 10/22/2013 BAILED 1' OF DEBRIS ON TOP OF IBP @ 7426' RKB. IN PROGRESS. 10/23/2013 BAIL DEBRIS ON TOP OF IBP @ 7426' RKB. IN PROGRESS. 10/24/2013 CHISEL& BAIL(1 GALLON) HARD CALCIUM CARBONATE FROM TOP IBP @ 7426' RKB. IN PROGRESS. 10/25/2013 TAG FILL ON IBP @ 7364' SLM; SET SLIP STOP CATCHER @ 7287'SLM; BENT LATCH OF SOV @ 7281' RKB; PULLED & DROPPED SOV; ATTEMPTED TO RECOVER VALVE FROM TOP OF CATCHER. IN PROGRESS. 10/26/2013 RECOVERED SOV FROM TOP OF CATCHER; SET DV @ 7281' RKB (PT TBG TO 1000 PSI). PULLED CATCHER @ 7284' SLM. READY FOR CTU. • • Conoco iIIips Time Log & Summary WelNiew Web Reporting Report Well Name: 1A-26 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 9/20/2013 11:00:00 AM Rig Release: 10/9/2013 11:59:00 PM Time logs„' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/20/2013 24 hr Summary Perform prep to move in and RU over well. Pull pits back and move rig off 1A-25. Spot on 1A-26. Move sub over well Spot pits and RU interconnect and berm all modules. MU hardlines to choke shack and cellar to kill well. Pull BPV with initial pressures;Tbg=0 psi, IA=0 psi, OA=84 psi. Rig acccepted at 11:00 am. PT lines 500/3500 psi,connect to tree and kill well. Reverse circulate 150 BBL of Seawater with returns from tubing to Tiger Tanks at 4 BPM with 250 psi. Circulate 297 BBL 8.6 seawater down tubing at 4 BPM with 740 psi. Pumped 84 BBLs more to get 8.6 ppg returns to TT. Blow down lines and line up to circulate through rig choke. Circulate S to S with 8.6 seawater. AOGCC waived witness to BOP test 9/20/2013;Jim Regg. 00:00 04:30 4.50 MIRU MOVE MOB P RD pits,steam, interconnect to prep for move. 04:30 07:30 3.00 MIRU MOVE MOB P Pull pits back and move sub off of 1A-25 and spot out of the way for site prep for 1A-26. Spot mats, herculite and plywood. Stage equipment in cellar and spot sub over well. 07:30 11:00 3.50 MIRU MOVE MOB P Spot pits and MU interconnect, berm up all modules. Accept Rig at 11:00 am,over well and taking on fluids to the pits. 11:00 12:00 1.00 MIRU MOVE RURD P MU hardlines from choke house to cellar and RU to kill well. 12:00 14:00 2.00 MIRU MOVE RURD P RU to kill well;test hardlines to Tiger Tanks with air to insure clear. 14:00 15:00 1.00 MIRU WELCTL RURD P Open SSV per Cameron rep. RU lubricator and pull BPV. Initial pressures on well;Tbg=0 psi, IA=0 psi, OA=84 psi. 15:00 17:00 2.00 MIRU WELCTL PRTS P PT all surface lines 500/3500 psi Good test. connect lines to tree for kill well operations. 17:00 18:30 1.50 MIRU WELCTL CIRC P Reverse circulate 150 BBLs 8.6 PPG seawater at 4 BPM with 250 psi; stop pump;Tbg=400 psi, IA=0 psi. Test Sierra alarm system Good. 18:30 20:00 1.50 MIRU WELCTL CIRC P Pump down tubing 297 BBL 8.6 PPG seawater at 4 BPM with 750 psi; shut in;Tbg=0 psi, IA=50 psi. 20:00 21:00 1.00 MIRU WELCTL COND P Move seawater to pits and pump off TT;290 BBL. 21:00 22:00 1.00 MIRU WELCTL CIRC P Circulate 8.6 PPG 84 BBL until 8.6 seen at choke house. Pump at 6 BPM with 195 psi;Tbg=0 psi, IA= 30 psi. Blow down hardlines to TT. 22:00 23:30 1.50 MIRU WELCTL CIRC P RU and circulate through choke manifold taking returns to pits. Circulate 260 BBL 8.6 PPG seawater at 6 BPM with 970 psi. Page 1of31 Time Logs. ` Date From '10 Dui- S.Depth E.Depth Phase Code=,,, Subcode T Comment 23:30 00:00 0.50 MIRU WELCTL OWFF P Monitor well;tubing and IA while bleeding OA to atmosphere. OA=4 psi at end of monitoring. 39/21/2013 ND tree and NU BOPE. MU secondary Ann valve and torque all bolts, Measure RKB and dress rams to BVBR 2-7/8"x5",TVBR 3-1/2"x6". Prep cellar and wellhead; per Cameron rep and pull BPV, install TWC. Test BOPE;Witness waived AOGCC,Jim Regg,9/20/2013. Test 250/3000 psi with 3.5"and 4"Test joints. Good tests. RD, blow down and RU for pulling tubing. MU 3 1/2"DP pup joints with DSS-HTC crossover and engage tubing hanger. 00:00 00:30 0.50 MIRU WELCTL OWFF P Monitor well for 30 minutes for 8.6 seawater barrier test=No flow. OA= 4 psi at end of monitoring. 00:30 01:30 1.00 MIRU WELCTL RURD P Secure well, blow down all lines and clear cellar. 01:30 02:30 1.00 MIRU WHDBO PRTS P Install BPV,test from below with 500 psi for 10 minutes- Good. 02:30 05:30 3.00 MIRU WHDBO NUND P ND tree and remove adapter, exercise all lock-down screws. Check XO to hanger engages-Good 4.25 turns. 05:30 11:00 5.50 MIRU WHDBO NUND P Install adapter flange and secure, place stack and secure. Install secondary Ann valve,torque all connections. Align and secure stack in place with turnbuckles. Measure RKB's. 11:00 12:00 1.00 MIRU WHDBO NUND P Change bottom rams to 2-7/8"x5". 12:00 13:00 1.00 MIRU WHDBO RURD P Prep cellar and wellhead;CIW rep pull BPV and install T\NC. 13:00 15:00 2.00 MIRU WHDBO PRTS P PU test tools, PU 3.5"teest joint, MU FOSV and IBOP,fill stack. 15:00 18:00 3.00 MIRU WHDBO PRTS P AOGCC witness waived by Jim Regg, 9/20/2013 Test BOPwith 3.5"TJ; UVBR and /of LVBR and Ann, Kill, Stnad pipe. HCR and Manual Kill,ch 1-9 and 16, Air BOP, Lower Kelly valve, HT-38 FOS and IBOP,250/3000 psi for 5 minutes each-Good tests. 18:00 18:30 0.50 MIRU WHDBO PRTS P LD 3.5"TJ and FOSV, PU 4"TJ. 18:30 20:00 1.50 MIRU WHDBO PRTS P With 4"TJ; UVBR, LVBR,Ann, CH 10, 11, 14, 15, Manual and HC choke. 250/3000 psi for 5 minutes- all Good tests. 20:00 20:30 0.50 MIRU WHDBO PRTS P Koomey draw down test; Initial=3050 psi,closing=1750;200 si build up= 17 sec, Full recovery=96 sec. 5 bottles avg= 1980 psi. Pump efficiency 1 PR and HCR: Electric pump=22 sec.Air=195 sec.Closing times:Ann=17 sec, UVBR, LVBR and SIM, Blinds=5 sec. Each HCR, CH and Kill= 1 sec each— Good. 20:30 21:00 0.50 MIRU WHDBO PRTS P LD 4"TJ Page 2of31 Time Logs Date t `' From To Dur. S.Depth E.Depth Phase Code Subcotle T' Comment 21:00 22:00 1.00 MIRU WHDBO PRTS P Test Blinds,CH 12, 13, inner and outer test ports;250/3000 psi for 5 minutes each--Good tests 22:00 22:30 0.50 MIRU WHDBO PRTS P LD test tools and blow down lines and equipment. CIW rep pull TWC. 22:30 23:00 0.50 MIRU RPCOM RURD P Install bales and 3.5"elevators. 23:00 00:00 1.00 COMPZ RPCOM RURD P MU XO and 3 1/2"drill pipe pup joints with TIW for landing joint. MU landing joint to tubing hanger with 4-3/4 RH turns. 09/22/2013 Attempt to pull tubing with no success. Tubing growth of 18'noted after pulling attempts.We could not re-land tbg hanger. RU Eline with stringshot run and 1-3/4"RCT and make cut at 7144'WLM. Pull tubing and all control line to surface with SSSV. Recover 24 SS bands of 26. 00:00 01:00 1.00 COMPZ RPCOM PULL P Pulled up to 135K on tbg with repeated attempts to free the string without success. Observed 5.4'of movement in string to get to 135K. Set Tbg in slips with tension of 25K over pull. 01:00 03:00 2.00 COMPZ RPEQP1 EQRP P Call out for Halliburton unit and prep for E-line operations. Clear floor and stage equipment. 03:00 05:30 2.50 COMPZ RPEQP1 RURD P Spot E-line trucks and stage equipment and tools. RU wireline equipment. 05:30 08:30 3.00 COMPZ RPCOM RURD P Work pipe to reposition for E-line operations,Attempt to reposition pup joints;observe 18"of tubing growth, unable to seat tubing hanger;verify at wellhead with LDS. With 135K indicated pull could not break pups, Install XO and MU to top drive to increase PU to 150K to set slips to reconfigure pups. MU pups to get good working height for E-line operations. 08:30 09:30 1.00 COMPZ RPEQP1 ELOG P PJSM for E-line operations. PU sheave and RU, RU XO TIW,and pump-in sub to E-line equipment. MU E-line tools on the rigfloor and hoist. 09:30 11:00 1.50 COMPZ RPEQP1 ELOG P Run in hole with 160 grrain string shot to 7144'WLM and fire. 11:00 12:00 1.00 COMPZ RPEQP1 ELOG P POOH with E-;line; pump 2 BPM with 120 psi to assist pulling E-line through SSSV;successful. 12:00 13:30 1.50 COMPZ RPEQP1ELOG P Pull out string shot to floor and confirm fired-Good fire confirmed. RU PBA, 1-3/4"RCT, EMA and CCL. 13:30 15:00 1.50 COMPZ RPEQP1 ELOG P RIH with E-line string correlate and fire RCT at 7144'WLM. 15:00 16:30 1.50 COMPZ RPEQP1ELOG P POOH with E-line string and RD same. Page 3 of 31 • • S Time Logs} Date From ;To Dur S.'Death E. Death Phase Code Subcode T °;Comment 16:30 17:30 1.00 COMPZ RPCOM CIRC P Pull tubing free with PU=95K, pull from 7144'to 7130'and circulate 270 BBLs 8.6 seawater at 6 BPM with 560 psi. RDE-line and RU GBR and Camco spooler. 17:30 18:30 1.00 COMPZ RPCOM RURD P LD landing joint,XO and hangerwith 3.59'pup joint. Blow down topdrive and change elevators. 18:30 21:00 2.50 COMPZ RPCOM PULL P Pull tubing laying down, PU=95K. At 18 joints out(706')control line was parted and pulled 60 more feet of control line. Drained stack and pulled tubing and control line was recovered on joint 21 out of the hole. No overpull; PU=87K 21:00 00:00 3.00 COMPZ RPCOM PULL P Reacquire spooling of control line and continue pulling 4"tubing. Pulled to joint 36 at crew change with 18 SS bands recovered. PU=83K, SO= 59K. 39/23/2013 Continue to pull 4"tubing, LD 123 joints of 4"and continue to pull 3-1/2"tubing; LD 70 joints and 18.11'on cut joint with 7 GLM. RD tubing handling equipment,clean and clear floor. MU Baker 7"casing scraper with DC,jars and bumper sub. RIH to 216'with PU=40K, S0=32K;took all down weight to slack down from 194' to 210'. PU 3-1/2"DP and push in the hole with 3K down weight from topdrive fro 216'to 342'. After 342'the string would slack down without assist from TD. PU=45K, SO=32K. Single in DP to 7120 with PU= 165K, S0=85K._Taq tubing stump at 7120'with 4K down weight. Pick up to 7118'; Circulate and condition at 6 BPM with 1140 psi. 00:00 02:00 2.00 COMPZ RPCOM PULL P Pull 4"tubing with control line to SSSV. Recover all control line and 24 of 26 SS bands.Observed that when the SSSV was coming through 300'-260', 7K drag on string. Maintained all string weight and continued POOH. 02:00 06:00 4.00 COMPZ RPCOM PULL P Pull out and LD 123 joints of 4"total. 06:00 06:30 0.50 COMPZ RPCOM RURD P Change out handling equipment for 3-1/2"tubing. MU up rig floor well control crossovers and TIW. Check equipment measures and stage on floor. 06:30 11:00 4.50 COMPZ RPCOM PULL P Pull 3-1/2"9.3#8 rnd Mod tubing. LS 70 joints and 18.11'of cut joint with 5 GLMs. 11:00 12:00 1.00 COMPZ RPCOM RURD P RD GBR casing handling equipment, clean and clear floor. Change to short bales 12:00 13:30 1.50 COMPZ RPCOM RURD P Clean and clear rigfloor; BD floor safety valves and XOs. Set 6-3/8" _ wear ring. 13:30 15:30 2.00 0 216 COMPZ WELLPF PULD P PU and MU BHA as per Baker rep; MU up 7"casing scraper assembly and RIH to 216'. From 194'to 216' DP had to be pushed with topdrive assist of 3K down weight to progress. PU=40K, SO=32K. Total length of BHA=215.94' Page 4of31 Time Logs Date From To ! Dur S. Depth E.Depth Phase Code Subcode T Comment 15:30 16:30 1.00 216 342 COMPZ WELLPF PULD P Continue to PU DP and employ TD to push in the hole from 216'to 342' with 3K down weight from TD. 16:30 21:45 5.25 342 5,400 COMPZ WELLPF PULD P Continue to single in the hole from 342'; PU=45K, SO=32K,to 5400'; PU= 130K, SO=75K. 21:45 22:00 0.25 5,400 5,400 COMPZ WELCTL SFTY P BOP drill; un-announced. Perform Kick while tripping drill with well secured in 60 seconds. 22:00 23:30 1.50 5,400 7,120 COMPZ WELLPF PULD P Continue to single in;from 5400'to 7120'; PU= 165K, S0=86K. Slack off and tag tubing cut stump at 7120' with 4K down weight. 23:30 00:00 0.50 7,120 7,120 COMPZ WELCTL CIRC P Pick up to 7115'and establish circulation with 6 BPM, 1140 psi. Slack down and tag stump at 7120' with 4K down weight. Pick up to 7118'and circulate. Crew change. 09/24/2013 '�a' Circulate hole clean with 10 BPM ,2850 psi and Deep KLEEN 30 BBL pill. POOH with Scraper assembly and LD same. PU and stand back 3 stands of DP. PJSM for wire line operations and rig up. RIH with Triple L✓ TCU, CBL and CAST-M to log casing and evaluate cement top. Run logs and determine TOC=2130'WLM. Confer with town Engineer; Perform string shot at 1993'WLM, Place RBP at 2650'DPM. String shot placed and fired successfully. RBP was set at 2650i5nd tested with 30K overpull and 30K down weight,verified set. RU for pressure test or rttsr. 00:00 01:30 1.50 7,120 7,120 COMPZ WELLPF CIRC P Circulate and condition hole with 10 BPM with 2850 psi. Pump Deep Kleen sweep around with circulations. Take SPR's. Monitor well-Static. 01:30 05:00 3.50 7,120 216 COMPZ WELLPF PULD P POOH from 7120'to 216'with Baker 7"casing scraper. Call out Halliburton E-line for casing evaluation and string shot. Observed 5-10K drag on assembly from 342'-195'while POOH. 05:00 06:00 1.00 216 0 COMPZ WELLPF PULD P Breakout and lay down 7"casing scraper assembly per Baker rep. 06:00 07:00 1.00 0 0 COMPZ WELLPF PULD P PU 15 joints of DP and RIH,then stand back in derrick. 07:00 07:15 0.25 0 COMPZ EVALWE SFTY P PJSM for RU E-line and E-line operations. 07:15 09:30 2.25 COMPZ EVALWE RURD P RU E-line for casing evaluation. Build tool assembly. 09:30 17:00 7.50 COMPZ EVALWE QEVL P RIH with E-line;TTTCU, CBL, CAST-M tools to depth. Crew change at noon. POOH performing logging run. 17:00 17:30 0.50 COMPZ EVALWE PULD P LD E-line tool assembly;TTTCU, CBL,and CAST-M. Recover 1 SS band on assembly;25 of 26. 17:30 19:30 2.00 COMPZ EVALWE QEVL P Confer with town Engineer and evaluate TOC and determine string shot location and RBP setting depth. TOC=2130'; String shot depth= 1993'WLM and RBP setting depth of 2650' DPM. IPage 6of31 Time,Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 COMPZ EVALWE ELOG P MU E-line string shot; 5'240 grain/ft, RIH, correlate depth and fire string shot at 1993'WLM,top of joint#147. POOH. 20:30 21:00 0.50 0 0 COMPZ EVALWE RURD P RU string shot and confirm good fire. RD HES E-line. 21:00 23:30 2.50 0 2,650 COMPZ WELLPF PULD P PJSM for Baker packer assembly. MU RBP assembly per Baker rep. RIH to 2650' PU=74K, SO=57K. 23:30 00:00 0.50 2,650 2,473 COMPZ WELLPF PLUG P Place RBP 2650'COE,set and test with overpull of 30K up and down; Successful set. Top 2645.25', bottom 2656.40'DPM. Release and pull up to 2473'; PU=74K, SO=57K. Crew change. X9/25/2013 PT RBP 2500 psi for 30 min. Monitor well-static. Dump 44 sacks of sands on RBP for 100'. Tag top of sand at 2547'with 5K down weight. POOH from 2547'to 961'; PU=72K,SO=55K. Kick while tripping drill; it CRT= 110 sec,well secure 60 sec. Good Drill and AAR. POOH to surface and LD RBP running tool. ` �vracdj Change Upper rams to 7"and ND stack and rack back on peg. RU HydraTite; Calculate 312,000#force, after 3 cycles force reduced to 296,400#by releasing 3"travel. Continue to control travel with HydraTite for a total of 37-1/2"of movement. Remove tubing spool, MU 7"casing spear and engage casing. Pull 75K tension with 16"of stretch for a total casing growth+stretch of 53-1/2". RU WACHS cutter and cut 4.37'(52.44"). NU BOP stack,spool and annulus valves. PU 7"test Joint and attempt to test 7"rams and annular; both failed PT. 00:00 00:30 0.50 2,437 2,437 COMPZ WELLPF PRTS P RU cement line for pressure test on RBP to 2500 psi for 30 minutes- Good test. 00:30 01:30 1.00 2,437 2,437 COMPZ WELLPF PRTS P Pressure test on RBP to 2500 psi for 30 minutes-Good test. RD and blow down lines. 01:30 02:00 0.50 2,437 2,437 COMPZ WHDBO OWFF P Monitor well for for 30 minutes- Static. Monitor OA for activity-No flow no activity; OA=0 psi 02:00 04:00 2.00 2,437 2,437 COMPZ WELLPF OTHR P Load 44 sacks of 20-40 sand in well for 100 feet of coverage on the RBP. 04:00 05:00 1.00 2,437 2,547 COMPZ WELLPF OTHR P Wait on sand to settle. RIH and tag top of sand at 2547'with 5K down weight. Monitor well=Static. 05:00 05:30 0.50 2,547 961 COMPZ WELLPF PULL P POOH from 2437'to 961'; PU=72K, SO=55K 05:30 05:45 0.25 961 961 COMPZ WELCTL SFTY P Kick while tripping drill; secure well= 60 sec, CRT= 110 sec. Good drill and Good AAR for drill. 05:45 06:30 0.75 961 0 COMPZ WELLPF PULL P POOH 961'to surface and LD RBP running tool. 06:30 07:00 0.50 0 0 COMPZ WELLPF RURD P Remove wear bushing and blow down all lines. 07:00 08:30 1.50 COMPZ WHDBO RURD P Change upper rams to 7". 08:30 11:00 2.50 COMPZ WHDBO NUND P NU BOP; remove riser,turnbuckles, and stand back stack on peg. Secure stack and remove adapter. 11:00 12:00 1.00 COMPZ WHDBO CUTP P RU HydraTite: Calculate intitial pressure at 312,000#up force. Perform three cycles to reduce force to 296,400 calculated with 3"growth. Page 6of31 Time Logs, Date From To Dur° S. Depth E. Depth Phase Code Subcode T Comment ' 12:00 14:00 2.00 COMPZ WHDBO CUTP P Continue casing growth with HydraTite to 37-1/2"to relaxed state. RD HydraTite. 14:00 16:00 2.00 COMPZ WHDBO PULD P Pull tubing spool free from 7"casing. 16:00 17:00 1.00 COMPZ WHDBO PULL P RU Baker casing spear and engage 7"casing. Pull and stretch casing releasing slips and pulling 75K overpull to re-set slips with 16"of stretch measured. For a total growth+stretch of 53-1/2". 17:00 18:00 1.00 COMPZ WHDBO CUTP P RU WACHS cutter per CIW rep and cut 4.37'(52.44")of 7"casing. 18:00 20:30 2.50 COMPZ WHDBO NUND P NU BOP; Nu tubing spool, annular valves,adapter, and place BOP stack. Secure stack. 20:30 21:30 1.00 COMPZ WHDBO RURD P Fill stack and PU 7"test joint 21:30 00:00 2.50 COMPZ WHDBO PRTS P Attempt to test 7"rams and annular: test failed. 39/26/2013 Continue to attempt PT on rams and annular without success. Remove and replace 7"rams and annular element. Test 7"rams in top cavity,TIW and annular to 250/3000 for 5 minutes each; Good tests. ND BOPs and set stack back on peg and secure. ND tubing spool and adapter CIW rep dress packoff in tubing spool. NU DSA, adapter and BOP stack, install cement lines and test hardlines to Tiger Tank. 00:00 01:00 1.00 COMPZ WHDBO BOPE T Attempt to test 7"rams and annular to 250 psi low and 3000 psi high: Top pipe and annular test failed. 01:00 13:30 12.50 COMPZ WHDBO RGRP T Change elements and seals on 7" rams. Change packer element in the Hydril 13-5/8"GK annular(Natural rubber, manufactured in 2011). 13:30 14:30 1.00 COMPZ WHDBO RURD T Rig up test 7"test joint,fill stack with water. 14:30 15:30 1.00 COMPZ WHDBO BOPE T Test top pipe rams(7"fixed/solid body)with 7"test joint and TIW valve. Test Annular w/7"test joint and TIW floor safety valve. Both tests to 250 psi low and 3000 psi high. Good tests. Charted test. 15:30 16:00 0.50 COMPZ WHDBO RURD T Rig down testing equipment. Blow down choke and kill lines. 16:00 18:00 2.00 COMPZ WHDBO NUND P Nipple down tubing spool,adapter and BOP set back on pedestal. 18:00 23:00 5.00 COMPZ WHDBO NUND P NU DSA,adapter and BOP stack. 23:00 23:30 0.50 COMPZ RPCOM RURD P RU and test hardlines to TT and open-top tank. 23:30 00:00 0.50 COMPZ RPCOM PULD P MU 5-1/2"Multi string cutter with stabilizer and XOs per Baker rep. 39/27/2013 PU Multi-cutter and RIH. Locate collar 48 at 2038.34'DPM.pulled to top of collar 48 and located at 1997.25' DPM. Positioned cutter at 1977'and made cut. time 03:48 to 03:58 cut time. Employed 78 RPM;Torque= 1700,with 53 strokes @ 400 psi; initial pressure. When cut was made pumps at 73 SPM with 300 psi and Torque dropped to 1450. Shut pump down and verified cut with 300 psi pump pressure. Located cut at 1977 with a 200 psi drop across cut. Continue with circulations and AP displacement with heated seawater. Pull 7"casing from 1975'to 1306'. Page 7 of 31 ° i► • Time4Logs .:. . Date— From "7To Our S.Depth E.Depth Phase Code Subcade`l'T Comment 00:00 01:30 1.50 9 2,038 COMPZ WELLPF TRIP P Trip in the hole w/Baker Oil Tools 5-1/2"Multi string cutter with stabilizer and XOs per Baker rep, from 9'to 2038'. Install blower hose f/ the top drive. PU wt 57k, SO wt 52k. 01:30 02:30 1.00 2,038 1,977 COMPZ WELLPF CPBO P Locate collars of 7"26 ppf J-55 BTC-m casing f/cut. Collar of 7" jt# 146 @ 2038.34'. Pulled up to find collar of jt#147 @ 1997.25'dpm. Space out to make a cut @ 1977' DPM(Jt#148). 02:30 02:45 0.25 1,977 1,977 COMPZ WELLPF SFTY P Pre job safety meeting on pumping heated seawater f/APC vac trucks. 02:45 03:30 0.75 1,977 1,977 COMPZ WELLPF CIRC P Circulate heated seawater surface to surface. 03:30 04:45 1.25 1,977 1,977 COMPZ WELLPF CPBO P Cut 7"casing @ 1977'(jt#148). Rotate 78 rpm w/1700 ft lbs of torque.lnitial pumping 128 gpm w/ 400 psi to cut 7"casing @ 1977' DPM. Final pump rate of 177 gpm w/ 300 psi,torque dropped f/1700 to 1450 ft lbs. Shut down,Verify cut w/ 300 psi of pump pressure. Located cut @ 1977'dpm. Cut made in 10 minutes. 04:45 05:00 0.25 1,977 1,977 COMPZ WELLPF OWFF P Monitor well-static. 05:00 05:15 0.25 1,977 1,977 COMPZ WELLPF RURD P Rig up w/2"hose and cement line. Close annular. Pressure test Llittle Red to 2500 psi-good. 05:15 06:30 1.25 1,977 1,977 COMPZ WELLPFCIRC P Little Red start heating(110 deg) and pumping 100 bbls of diesel @ 1.4 bpm w/400 psi. Pumping down 3-1/2"dp,taking returns f/the 9-5/8" x 7"annulus to open top tank(Arctic pack). 06:30 07:15 0.75 1,977 1,977 COMPZ WELLPFCIRC P With rig pumps, pump 35 bbls of deepClean pill, follow w/19 bbls heated(130 deg) seawater. Pumping 63 gpm w/75 psi. Shut down. 07:15 08:15 1.00 1,977 1,977 COMPZ WELLPF OTHR P Let warm fluids soak to loosen up the arctic pack in the 9-5/8"x 7" annulus. 08:15 09:15 1.00 1,977 1,977 COMPZ WELLPFCIRC P Line back up on Little Red. Pump 70 bbls of hot(170 deg)seawater @ 1.4 bpm w/400 psi to flush arctic pack f/ the annulus. 09:15 09:45 0.50 1,977 1,977 COMPZ WELLPF CIRC P With rig pumps, pump 110 deg seawater. Pump 100 bbls @ 210 gpm w/1250 psi to flush out the annulus of arctic pak. 09:45 10:30 0.75 1,977 1,977 COMPZ WELLPF RURD P Rig down, blow down lines. 10:30 11:00 0.50 1,977 1,977 COMPZ WELLPF OWFF P Monitor well-slight flow slowing over time to static. 11:00 11:15 0.25 1,977 1,977 COMPZ WELLPF PULD P Pick up single f/pipe shed to get back on even stands. Page8of31 • I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode` T Comment :, 11:15 12:00 0.75 1,977 1,145 COMPZ WELLPF TRIP P Trip out of the hole f 1977'to 1145' w/Baker 5-1/2"multi string cutter. PU wt 45k, SO wt 45k. 12:00 12:30 0.50 1,145 8 COMPZ WELLPF TRIP P Continue to trip out of the hole f 1145' to 8' w/Baker 5-1/2"multi string cutter. 12:30 13:00 0.50 8 0 COMPZ WELLPF PULD P Lay down Baker BHA#3(Multi string cutter). 13:00 13:15 0.25 0 18 COMPZ WELLPF PULD P Pick up/MU Baker BHA#4(7" spear). 13:15 13:45 0.50 18 1,977 COMPZ WELLPF FISH P Slack off and engage 7"casing w/ spear per Baker rep. 13:45 14:00 0.25 1,977 1,977 COMPZ WELLPF SFTY P Pre job safety meeting on nipple down operation and spear casing and removing Cameron SB-3 7"casing slips. 14:00 14:30 0.50 1,977 1,977 COMPZ WHDBO NUND P Nipple down BOPE. Raise stack. 14:30 14:45 0.25 1,977 1,975 COMPZ WELLPF FISH P Pick up on the 7"casing, broke free w/130k on weight indicator(Block weight 30k). Continue to pick up w/ 100k till slips were free of casing head. Cameron Iron Works Rep Travis then removed the Camron SB-3 7"casing slips. 14:45 15:30 0.75 1,975 1,975 COMPZ WHDBO NUND P Set 13-5/8"BOP stack back down. Then NU BOPE to 7"casing spool. 15:30 16:15 0.75 1,975 1,975 COMPZ WELLPF RURD P Rig up to circulate to clean the 9-5/8" x 7"annulus. 16:15 16:45 0.50 1,975 1,975 COMPZ WELLPF CIRC P Circulate down the 7"casing,taking returns f/the annulus to shaker and out to the cuttings tank,circulating 500 gpm w/320-290 psi.After pumping 53 bbls,shut annular and divert returns through the gas buster to the pits to the cuttings tank. Circ @ 208 gpm w/120 psi. Circulated a total of 130 bbls of dirtyseawater from pit 4. 16:45 17:30 0.75 1,975 1,975 COMPZ WELLPF OTHR P Load pit 4 with 140 bbls of hot clean seawater(8.6 ppg) from vac truck to be able to pump @ 12 bpm rate to clean up arctic pack in the annulus of the 9-5/8"x 7". Monitor well-a little gas breaking out,fluid level fell about 6'. 17:30 18:00 0.50 1,975 1,975 COMPZ WELLPF CIRC P Load string w/35 bbls of deep clean, pumping 172 gpm w/50 psi.Then pump hot seawater out of pit#4, pumping 581 gpm w/370 psi to flush arctic pack from the 9-5/8"x 7" annulus. 18:00 18:30 0.50 1,975 1,975 COMPZ WELCTL OWFF P Monitor well for flow-Static. Empty cuttings tank with Guzzler. 18:30 20:30 2.00 1,975 1,975 COMPZ WELLPF OTHR P Continue to empty tanks and stage trucks, hook up and prep for circulation. Page 9ef31 Time Logs Date From To Dur S.Depth E. Death Phase Code S Subcode T Comment 20:30 21:00 0.50 1,975 1,975 COMPZ WELLPF CIRC P Circulate 150 BBLs of 110°8.6 PPG seawater @ 13.6 BPM with 340 psi 21:00 21:30 0.50 1,975 1,975 COMPZ WELLPF OWFF P Monitor well for flow-Static with some gas break out, but now fluid movement or loss to well. 21:30 22:00 0.50 1,975 1,975 COMPZ WELLPF CIRC P Circulate 30 BBLs heated seawater to flush Choke and Gasbuster of Arctic Pac. Blow down and observe well-Static. 22:00 00:00 2.00 1,975 1,306 COMPZ WELLPF PULL P Pull 7"casing with spear to floor; PU=78K, Break over at 120K- Loose. Pull&'casing with GBR from 1975'to 1306', LD and strap. Joints number out of the hole;jts 1-9 badly bent with 4,7, and 17 spiralled. Centering guides found on top cut joint and on every 5th joints after. 39/28/2013 Pull 7"casing from 1306'to surface. 46 joints; 1914.35',2 cut joints; 9.93'(top),21.68'(Bottom).Centering Guides recovered with the last on point#45 out of the hole:Total Centering guides= 10. Joints 1-18 badly Pbe�`,; fie( bent, Joints 1,4, 7, 17, 31 and 35 buckled and spiraled. RD GBR casing equipment.Set plug and pressure t-1 4 test Flange break above casing head;250/3000 psi-Good test. MU BHA#5; 9-5/8"casing scraper and RIH with Bull nose, magnet and jars. Tao 324',attempt to work though with 20 RPM; unable to work through. Break circulation with 13 BPM at 725 psi to circulate out Arctic Pac. MU BHA#6;Tandem string melon mills; 8-3/8"and 8-1/2". TIH to tag and mill from 318'to 351'. POOH to clean magnet of 23.6#metal from magnet and ditch magnets. RIH with same BHA and encounter drag at 972'. Mill from 972 to 1109' check free movement with no rotary or pumps. Went through area without problem or drag. Monitor well-Static. POOH to perform BOP test. Recovered 6.5#metal from magnet and ditch magnets. RU and PU test joint to test BOPE. 00:00 02:00 2.00 1,306 0 COMPZ WELLPF PULL P Pull 7"casing from 1306'to surface. 46 joints; 1914.35',2 cut joints; 9.93' (top), 21.68'(Bottom). Centering Guides recovered with the last on joint#45 out of the hole:Total Centering guides= 10. Joints 1-18 badly bent,Joints 1,4, 7, 17, 31 and 35 buckled and spiralled. Bottom cut on joint had a good cut. Calculated displacement 19.51 bbls, actual 21.5 bbls. 02:00 02:30 0.50 0 0 COMPZ WELLPF RURD P RD casing GBR equipment and clear floor. 02:30 03:30 1.00 0 0 COMPZ WHDBO RURD P PU test joint to set lower test plug to test stack flange breaks. Fill stack w/water. 03:30 04:30 1.00 0 0 COMPZ WHDBO PRTS P Test flange break on 7"casing spool to 250/3000 psi. Each test held f/5 minutes. Charted test. 04:30 05:00 0.50 0 0 COMPZ WHDBO RURD P Lay down Cameron lower test plug. Install 9-1/16"ID wear bushing. 05:00 07:30 2.50 0 223 COMPZ WELLPF PULD P PU/MU Baker BHA#5 to 223':5"OD bull nose, bouble pin sub,9-5/8" casing scraper, bit sub, bumper sub, oil jar,x-o, (6)6-1/4"drill collars,x-o. Page,10of31 S Tirane Logs Date '` From To ' Dur S.Depth "E Depth'Phase Code Subcode T Comment 07:30 08:00 0.50 223 324 COMPZ WELLPF TRIP P Trip in the hole w/BHA#5(9-5/8" scraper)f/223'to tag up @ 324.4'. PU wt 50k,SO wt 44k. Set down 25k-no go.Attempt to rotate through.20 rpm free torque= 1500 ft lbs. Slacked off to 324.4'and stalled out w/8k ft lbs of torque. Unable to work past. Note: Blocks on the scraper can collapse to 8.328'. Depth of scraper '318'. 08:00 08:30 0.50 324 324 COMPZ WELLPF CIRC P Circulate to remove arctic pack f/ well. Pumping 546 gpm w/725 psi. Blow down top drive. 08:30 09:15 0.75 324 11 COMPZ WELLPF TRIP P POOH w/BHA#5(scraper)f/324'to 11'. 09:15 09:30 0.25 11 0 COMPZ WELLPF PULD P Lay down 9-5/8"scraper and bullnose. 09:30 10:30 1.00 0 0 COMPZ WELLPF OTHR P Attempt to remove 7"cut jt f/spear, unable to do so. 10:30 11:30 1.00 0 256 COMPZ WELLPF PULD P PU/MU BHA#6(Tandem mills): 4-1/2"IF bull nose,4-1/2"IF pup jt (4.56'),double pin sub, 8-3/8"lower watermelon mill,4-1/2"IF flex jt (9.04'),8-1/2"upper watermelon mill, x-o, string magnet,x-o,bumper sub, oil jar,x-o,(6)6-1/4"DC's,x-o to 256.75'. 11:30 11:45 0.25 256 256 COMPZ WELCT[SFTY P BOP drill while making up BHA;AAR good, response time good. 11:45 12:00 0.25 256 318 COMPZ WELLPF TRIP P Trip in the hole w/BHA#6(Tandem mills, 8-3/8"lower,8-1/2"upper)f/ 256'to tag up @ 318'. 12:00 15:45 3.75 318 351 COMPZ WELLPF REAM P Ream w/tandem mill assembly f/ 318'to 351'until clean(no more than 2k weight loss). Rotate w/60 rpm and 1500-4800 ft lbs of torque. Pumping 420 gpm w/230 psi. Note:depths of 8-3/8"mill taking weight @ 314', 318',336'. Subtract 15.13'to obtain depth of 8-1/2"mill. 15:45 16:45 1.00 351 30 COMPZ WELLPF TRIP P POOH to clean magnet, pull from 351'to surface. 16:45 17:00 0.25 30 30 COMPZ WELLPF OTHR P Clean magnet. Recovered 5.6 pounds on magnet. Recovered 17 pounds on 6 magnets in the pits. 17:00 17:30 0.50 30 256 COMPZ WELLPF TRIP P Trip in the hole w/BHA#6 to continue reaming in the 9-5/8"casing w/tandem mills(8-3/8"&8-1/2"). 17:30 18:30 1.00 256 972 COMPZ WELLPF TRIP P Trip in on drill pipe f/256'to 972'. Drag at 972'of 4K. PU=57K, SO= 54K. Page 11 of 31 S Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 18:30 19:30 1.00 972 1,109 COMPZ WELLPF REAM P Ream w/tandem mill assembly f/ 972'to 1109' until clean, shut down pumps and rotary and slack through area without problem after reaming. Rotated w/60 rpm and 1300-1800 ft lbs of torque. Pumping 378 gpm w/ 400 psi. Note:depths of 8-3/8"mill taking weight @ 961.71', 1061.08'. Subtract 15.13'to obtain depth of 8-1/2"mill. Milled 6'on each area until free. 19:30 20:00 0.50 1,109 256 COMPZ WELLPF TRIP P Monitor well= Static. POOH from 1109'to BHA,256'. PU=50K, SO= 45K. 20:00 21:30 1.50 256 0 COMPZ WELLPF OTHR P Pull out and rack back DC and clean magnet and ditch magnets;2.8#of metal from string magnet and 3.7# from ditch magnets. 21:30 23:00 1.50 0 0 COMPZ WELLPF RURD P Pull wear bushing, MU J Whacker with magnet and flush the stack 2X. Recovered 10.2#metal from string magnet and ditch magnets. 23:00 00:00 1.00 0 0 COMPZ WHDBO RURD P MU test plug, TIW and test dart for testing. Set test plug and fill stack with water. 09/29/2013 Continue to test BOPE equipment.Weekly witness of test waived by AOGCC; Chuck Scheve.Tested w/ ✓ 3-1/2"and 7"test joints.Tested and charted to 250 psi low and 3000 psi high.All tests held for 5 minutes. Top pipe rams are 7", Lower pipe rams are 3-1/2"x 6"VBR. LD test tools,set 9-1/16"wear ring. ■ 5 MU BHA#7 with tandem mills 8-3/8"x 8-1/2"and TIH to 1977 and tag casing cut joint. No problems ®e encountered. Pull to 1972'; PU=72K, SO=62K. C&C 4X BU with 13 BPM at 1150 psi also with 30 BBL High Vis pill around during circulations. Well Static on monitor, POOH with good displacements. LD BHA#7 and MU BHA#8 with 8-1/2"x 8-3/4"mill assembly. RIH with mills to 118'and mill to 139'with 1K WOM, 10 BPM at 400 psi;65 RPM with Torque of 3-4.5K during milling operations,free torque 850 ft-lbs. POOH and clean string magnet and ditch magnets recovering 48.6#of metal. TIH with assembly and tagged at 325'and milled to 330'with 10 BPM at 180 psi,60 RPM with 3-4K torque. PU=45K, SO=45K, ROT= 48K. Page 12 of 31 Time togs Date From To 'Dur S. Depth E.,Depth`Phase Code Subcode T Comment ' r s' 00:00 05:00 5.00 0 0 COMPZ WHDBO PRTS P Continue to test BOPE equipment. Weekly witness of test waived by AOGCC rep Chuck Scheve. Tested w/3-1/2"and 7"test joints.Tests were to 250 psi low and 3000 psi high.All tests charted.All tests held for 5 minutes.Top pipe rams are 7", Lower pipe rams are 3-1/2"x 6" VBR.Tested floor safety valves, choke manifold,top drive IBOP's. Koomey test: Initial 3025 psi, after closure 1800 psi,200 psi build up in 16 seconds,final pressure in 90 seconds. Closing times:Annular 13 seconds, Top pipe: 7 seconds, Blinds: 7 seconds, Bottom pipe 7 seconds. Choke and kill HCR valves 1 seconds each. Nitrogen backup: 5 bottles 2000 psi. Pump performance: Electric:22 seconds,Air: 247 seconds.Test w/ one ram and one HCR. 05:00 06:00 1.00 0 0 COMPZ WHDBO RURD P Rig down testing equipment, Pull Cameron lower test plug. Set 9-1/16" ID Cameron wear bushing. Blow down choke and kill lines,choke manifold and top drive. 06:00 07:00 1.00 0 256 COMPZ WELLPF PULD P PU/MU Baker BHA#7(Tandem mills: 8-3/8"lower&8-1/2"upper): 4-1/2"IF bull nose,4-1/2"IF pup jt (4.56'),double pin sub, 8-3/8"lower watermelon mill,4-1/2"IF flex jt (9.04'),8-1/2"upper watermelon mill, x-o, string magnet,x-o, bumper sub, oil jar,x-o,(6)6-1/4"DC's,x-o to 256.75'. 07:00 08:15 1.25 256 1,977 COMPZ WELLPF TRIP P Trip in the hole w/3-1/2"dp f/256'to lightly tag top of cut jt @ 1977'. 08:15 09:45 1.50 1,977 1,977 COMPZ WELLPF CIRC P Circulate 562 gpm w/330 psi(9-5/8" x 3-1/2"AV=204.5 ft/min). Pumped a 30 bbl 35 funnel vis sweep after hole cleaned up. Results: hole cleaned up well. Obtain slow pump rates: Pump#1;30 strk=65 psi, Pump#2; 30 strk=70 psi. 09:45 10:45 1.00 1,977 256 COMPZ WELLPF TRIP P POOH w/Baker BHA#7(Tandem mills)f/1977'to 256'. 10:45 11:45 1.00 256 0 COMPZ WELLPF PULD P Stand back 2 stands of 6-1/4"drill collars. Lay down 8-3/8"mill and install 8-1/2"mill on bottom w/8-3/4" mill on top for tandem mill run w/ Baker BHA#8. 11:45 12:00 0.25 0 0 COMPZ WELCT[SFTY P BOP drill; CRT=95 sec,MR held to review and discuss drill performance. Page 13 of 31 Time Logs . Date , From J,To Dur S. Depth E.Death Phase Code Subcode T Comment y= u 12:00 13:00 1.00 0 129 COMPZ WELLPF PULD P MU BHA#8; 8-1/2"mill on bottom w/8-3/4"mill on top for tandem mill run as per Baker rep. Stack out with 10K at 129', LD top single,change elevators and MU to mill. 13:00 16:00 3.00 129 224 COMPZ WELLPF REAM P Ream with mills from 118'to 224' (Bullnose depths'7'to lower mill, 17' to uppper mill). 1-3K WOM, 10 BPM with 170 psi,2-5K torque on, 1.3K torque off with 60 RPM, 16:00 19:00 3.00 224 181 COMPZ WELLPF REAM P Back-ream from 224'to 120',then slack down through without pumps or rotation. Stacked out at 177' BN depth. Pick up to 160'then ream from 160'to 224', Back-ream to 120'. Slack through120'to 162' encountered 10K drag. Slack to 181' BN depth. 19:00 20:30 1.50 181 224 COMPZ WELLPF REAM P Work mills through 120'to 224'with 10 BPM at 170 psi,60 RPM with 2-5K torque. PU/SO/ROT=40K. Pick up to 120'and slack off to 224' with 3-8K drag. 20:30 21:00 0.50 0 0 COMPZ WELLPF TRIP P Trip string magnet to surface and clean 7.5#of metal and 41.1#of metal from ditch magnets. 21:00 21:30 0.50 0 299 COMPZ WELLPF SVRG P Trip in to 224'and service rig;grease wash pipe and continue in the hole to 299'with 10K drag at 299'. 21:30 22:00 0.50 299 319 COMPZ WELLPF REAM P Ream casing from 297'to 319'with 10 BPM at 170 psi,Torque 1.1K off, 4K on,60 RPM. Pick up and slack through 295'to 319'. 22:00 22:30 0.50 319 129 COMPZ WELLPF TRIP P POOH to 129'and PU 2 stands of drill collars for weight. 22:30 23:00 0.50 129 328 COMPZ WELLPF TRIP P TIH making up drill collars,then drill pipe to 328'BN depth. Tag with 10 K drag. 23:00 00:00 1.00 328 330 COMPZ WELLPF REAM P Work mills through 325'to 330'; 1-2K WOM,10 BPM at 180 psi,60 RPM with 3-4K torque. PU/SO=45K, ROT=48K. Crew change. 09/30/2013 Continue to mill 9 5/8"casing and pump 20 High Vis(100)sweeps. Mill from 330'to 344'work through free. Trip from 344'to 1976'; PU=55, SO=55. cleaned up tight spots at 703'to 706',770'to 778',816'to 820'. Tag casing stub with 1K down weight. C&C 1X BU at 13 BBL with 890 psi. Pump 20 BBL High Vis sweep and circulate clean. Perform SPR's on both pumps:#1=30/60 psi,#2=30/60 psi. Monitor well: Static. POOH and clean string magnet and ditch magnets;28.8#of metal total. Service rig. PU and MU BHA#9 Back-Off assembly. TIH and back off 7"casing cut joint 3 3/4 turns with 9 strokes of the BO tool. Initial break of 6900 ft-lbs torque. Drop ball n rod, open Pump-out sub with 2650 psi. Reverse circ out diesel. POOH to 500'. 00:00 04:30 4.50 330 344 COMPZ WELLPF REAM P Continue milling from 330'to 337'; 1-3K WOM,10 BPM at 180 psi,60 RPM with 3-4K torque. PU/SO= 45K, ROT=48K. Ream to 344' without drag. Pump 20 bbl sweep @ 332'and 334'. Page 14 of 31 ' • 0 Time Logs ',L, , Date H From To Dur S. Depth E.Depth Phase .,Code Subcode T Comment '#' '. 04:30 08:00 3.50 344 1,976 COMPZ WELLPF TRIP P Trip in the hole f/344'to 1976'. PU wt 55k,SO wt 55k. Clean up tight spots @ 703'-706',770'-778',and 816'-820'. Light tag @ 1976'w/1k wt. PU wt 72k, SO wt 62k. 08:00 08:45 0.75 1,976 1,976 COMPZ WELLPF CIRC P Circulate BU, pumping 546 gpm w/ 890 psi.Then pump 20 bbl sweep, circulate till clean.Obtain slow pump rates: mp#1: 35 spm w/30 psi,52 spm w/60 psi. mp#2: 35 spm w/30 psi, 52 spm w/60 psi. 08:45 09:00 0.25 1,976 1,976 COMPZ WELLPF OWFF P Monitor well-static. Blow down the top drive. 09:00 09:30 0.50 1,976 249 COMPZ WELLPF TRIP P Trip out w/Baker BHA#8(Tandem mills: 8-1/2"&8-3/4")f/1976'to 249' 09:30 10:00 0.50 249 65 COMPZ WELLPF TRIP P Stand back(2)stands of 6-1/4"drill collars to 65'. 10:00 10:30 0.50 65 0 COMPZ WELLPF PULD P Lay down BHA. Clean magnets(8# from string magnet&20.8#f/ditch magnets in the pits. 10:30 11:00 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. 11:00 11:30 0.50 0 0 COMPZ RIGMN7 SVRG P Service rig,crown, blocks and top drive. 11:30 12:00 0.50 0 0 COMPZ WELLPF PULD P PU/MU Baker BHA#9(Backoff 7" stub). Crew change. 12:00 14:00 2.00 0 409 COMPZ WELLPF PULD P MU Baker Back-off assembly BHA #9 per Baker rep to 405'. Fill BHA with diesel. 14:00 17:30 3.50 409 2,203 COMPZ WELLPF TRIP P Trip in the hole with assembly to 1977'(top of 7"cut jt. Slack down to position center of power section at 1996'(bottom of BHA @ 2203'); PU= 68K, SO=60K. Fill pipe with diesel. 17:30 18:30 1.00 2,203 2,203 COMPZ WELLPF RURD P RU to circulate, RU test lines and pump. 18:30 18:45 0.25 2,203 2,203 COMPZ WELLPF FISH P Set lower anchor on casing stub. 18:45 21:30 2.75 2,203 2,203 COMPZ WELLPF BKOF P Employ back-off to pressure cycles to back-off 7"casing stub. 9 cycles were done with 3 3/4 turns total; Initial torque=6600 ft-lbs(break), final torque=6900 ft-lbs. 21:30 22:30 1.00 2,203 2,203 COMPZ WELLPF PULD P Break pipe and drop ball and rod. Open pump-out sub with 2650 psi. Reverse circulate out diesel;3 BPM with 230 psi. 22:30 23:30 1.00 2,203 2,203 COMPZ WELLPF RURD P RD circulating equipment; blow down test pump,choke lines and choke manifold. 23:30 00:00 0.50 2,203 500 COMPZ WELLPF TRIP P POOH with Back-off assembly from 2203'to 500'. Crew change. I 1 10/01/2013 3 Continue to POOH with BHA#9 and LD same. MU Triple connect 7"casing,TIH and tag at 122'with 10K. . downweight; No Go. POOH and LD Dummy run assembly. KU casing equipment. PU/MU 8 1/2"x 8 3/4" milling assembl . 00:00 00:15 0.25 500 405 COMPZ WELLPF TRIP P Continue to POOH with Baker BHA #9(Backoff assembly)from 500'to 405' Page 16of31 Time Logs. , . Hate ,: 'From To Dur S.Devitt' E.Depth Phase Cede"' Subcode T Comment :. 00:15 01:00 0.75 405 220 COMPZ WELLPF PULD P Stand back(2)stands of 6-1/4"DC's. 01:00 02:00 1.00 220 0 COMPZ WELLPF PULD P Lay down BHA#9(Backoff assembly)f/220'. 02:00 02:30 0.50 0 0 COMPZ WELLPF RURD P Rig up GBR casing tools. 02:30 02:45 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting on running triple connection w/HES cementer dummy drift assembly(Baker BHA #10). 02:45 03:30 0.75 0 122 COMPZ WELLPF PULD P PU/MU Baker BHA#10:Triple connect, pup jt, HES cementer, Pup jt, (1)jt of 7"26 ppf L-80 TCII casing, (2)x-o's,string magnet,4-3/4" bumper sub,4-3/4"jar,tag up @ 122'w/first 6-1/4"drill collar. PU wt 36k, SO wt 36k. Set down 6k. Picked up, rotated 180 deg, slack off-no go @ 122'. 03:30 04:00 0.50 122 0 COMPZ WELLPF RURD P Lay down Baker BHA#10(Triple connect drift) 04:00 04:30 0.50 0 0 COMPZ WELLPF RURD P Rig down GBR casing tools. 04:30 06:30 2.00 0 118 COMPZ WELLPF PULD P PU/MU BHA#11 (Tandem mills- 8-1/2"& 8-3/4").Tag @ 118'bull nose depth, 112'lower mill depth (8-1/2"), 103'upper mill depth (8-3/4"), PU wt 40k, SO wt 40k. 06:30 12:00 5.50 118 172 COMPZ WELLPF REAM P Reaming w/Baker BHA#11(tandem mills)f/118'(lower mill depth 112', upper mill depth 103')to 138'(lower mill depth 132', upper mill depth 123). PU wt 40k, SO wt 40k, Rot wt 40k. Rotate 60 rpm w/1k ft lbs of torque off bottom, 1.5-4k ft lbs on bottom. Pumping 420 gpm w/110 psi.WOB 0-2k. Reaming w/Baker BHA#11(tandem mills)f/171.5'(lower mill depth 1165.5', upper mill depth 156.5')to 173'(lower mill depth 167', upper mill depth 158). PU wt 40k, SO wt 40k, Rot wt 40k. Rotate 60 rpm w/1 k ft lbs of torque off bottom, 1.5-4k ft lbs on bottom. Pumping 420 gpm w/110 psi.WOB 0-2k. A total of 22 pounds of metal recovered from the(6)ditch magnets in the pits. Page 16 of 31' Time Lugs Dare From To bur S.Depth E.,Depth Phase Code- Subcode T 'Comment 12:00 18:00 6.00 118 172 COMPZ WELLPF REAM P Continue to Ream tight sections with BHA#11 as follows: Upper Section Bull Nose depth= 118'-145'. Lower Section Bull Nose depth= 166'- 190'. The 8 1/2"String Mill is 7-ft above the Bull Nose and the 8 3/4" String MIII is 17-ft above the Bull Nose. PUW=38K. SOW=35K, RTW=37K. RPMs=60,Torque= 1,500 ft/lbs-4,000 ft/Ibs, 10.0 bpm/130 psi. 18:00 00:00 6.00 118 172 COMPZ WELLPF REAM P Continue Milling/Reaming tight sections with BHA#11 as follows: Upper Section Bull Nose depth 118'- 145'. The lower section Bull Nose depth 166'-190' The 8 1/2"String Mill is 7-ft above the Bull Nose and the Upper String Mill is 17-ft above the Bull Nose. PUW=38K, SOW= 35K, RTW=37K, RPMs=60,TQ off btm= 1K,TQ on btm= 1.5K-4K. 10.0 bpm/130 psi. Metal recovered from Ditch Magnets this tour=48.6 lbs. Total mete)recovered in the last 24 hours=70.6 lbs. Presently is still takes 2K-4K in the Upper section for the Mills to pass through in both directions and 2K-6K in the Lower section for both Mills to pass through in both directions. 10/02/2013 Continue Mill/Reaming through tight sections in the 9 5/8"Casing from 101-ft- 188.5-ft. Continu in hole and found a tight sections at • -- - 1.-- an. a •- - - , 30-ft-333-ft. Continue down to 851-ft with no further problems.TOOH and LD BHA#12. MU and start to RIH with BHA#13...7"Dummy Drift Assembly. 00:00 03:30 3.50 172 0 COMPZ WELLPF REAM P Continue Milling/Reaming the tight sections with BHA#11 as follows: Upper Mill depth=101-ft-173-ft. PUW=38K, SOW=35K, RTW= 37K, RPMs=85, 10.0 bpm/130 ps, TQ off btm=875 ft/lbs. TQ on btm= 1 -3K. POOH to inspect Upper 8 3/4"Mill and to clean String Magnet. 03:30 04:00 0.50 0 101 COMPZ WELLPF PULD P Lay down the 8 3/4 String Mill (condition=cutting section 85% gone)and replace with new 8 3/4" String MITI. Clean String Magnet and recovered 6.5 lbs of metal cuttings. Run back in hole to 101'. 04:00 11:00 7.00 101 188 COMPZ WELLPF REAM P Continue Milling/Reaming tight sections of 9-5/8"36 ppf J-55 BTC casing w/Baker BHA#12(Tandem mills: 8-1/2"lower&new 8-3/4" upper). Reaming f/101'to 188.5'. PU wt 40k,38k SO wt, Rot wt 39k. Rotate 80 rpm w/1 to 1.5k ft lbs of torque. Pumping 420 gpm w/130 psi. Page 17 of 31 Time Logs Date'" From T'o Dur S. Depth E.Depth Phase Code Subcode T Comment 11:00 11:15 0.25 188 301 COMPZ WELLPF TRIP P Trip in hole f/188'to 301'. Set down w/5k weight @ 301'. 11:15 12:00 0.75 301 327 COMPZ WELLPF REAM P Continue Milling/Reaming tight sections of 9-5/8"36 ppf J-55 BTC casing w/Baker BHA#12(Tandem mills:8-1/2"lower&new 8-3/4" upper). Reaming f/301'to 306'. PU wt 40k, 38k SO wt, Rot wt 39k. Rotate 80 rpm w/1k ft lbs off bottom, to 1.5k ft lbs of torque while milling. Pumping 420 gpm w/130 psi. Trip in the holef/306'and found a tight spot @ 327'. Recovered 84.6#'s of metal since 0400 hrs. Recovered 91.1 #'s of metal total on this tour from the(6)ditch magnets in the pits. 12:00 14:30 2.50 327 333 COMPZ WELLPF REAM P Continue Milling/Reaming tight sections of 9-5/8"36 ppf J-55 BTC casing w/Baker BHA#12(Tandem mills:8-1/2"lower&new 8-3/4" upper). Reaming tight spots f/324'to 327',330'-333'bullnose depths. Work through all tight spots w/less than 2k drag or overpull. PU wt 40k,40k SO wt, Rot wt 40k. Rotate 80 rpm w/1k ft lbs off bottom, to 2k ft lbs of torque while milling. Pumping 420 gpm w/150 psi. 14:30 15:00 0.50 333 851 COMPZ WELLPF TRIP P Trip in the hole w/Baker BHA#12 Tandem mills:8-1/2"lower&new 8-3/4"upper)f/333'to 851'.No drag noticed. PU wt 45k, SO wt 45k. 15:00 15:30 0.50 851 851 COMPZ WELLPF CIRC P Circulate w/reciproacting f/851'to 800'. Pumping 504 gpm w/350 psi. Pumped 86 bbls. Obtain slow pump rates: mp#1:35 spm=30 psi, 52 spm=40 psi. mp #2: 35 spm=40 psi,52 spm=40 psi. 15:30 15:45 0.25 851 851 COMPZ WELLPF OWFF P Monitor well-static. Blow down the top drive. 15:45 16:15 0.50 851 93 COMPZ WELLPF TRIP P Trip out w/Baker BHA#12(tandem mills)f/851'to 93'. 16:15 17:30 1.25 93 0 COMPZ WELLPF PULD P Lay down Baker BHA#12. Clean magnet. Recovered 9.9#'s of iron f/ magnet. Recovered 10.7#'s of iron f/ (6)ditch magnets. Monitor Well. 17:30 19:00 1.50 0 0 COMPZ RIGMNT SVRG P Service Rig. Grease Blocks. Repair Top Drive hose leak. Service Top Drive. Page 18 of 31 Time Logs 1 'Date 1 From'„To Our S. Deofh E. Depth Phase Code Subcode T {Comment „u , bate '`� 19:00 22:00 3.00 0 0 COMPZ WELLPF CIRC P Flush stack x 3. CleanString Magnet each time. Pull Wear Bushing. Blow down lines. Flush Stack x 2 again. Recovered 16.1 lb of metal from the String Magnet and 18.7 lbs of metal cuttings from the Ditch Magnets during the Stack Flushes. Reinstall Wear Bushing. Blow down Top Drive. Lay down Jetting Tool Assembly. 22:00 23:30 1.50 0 285 COMPZ WELLPF PULD P Rig up GBR Casing Tongs. Make-up BHA#13, 7"Dummy Drift Assembly (OAL=63.63-ft). 23:30 00:00 0.50 285 380 COMPZ WELLPF TRIP P Start to trip in with the 7"Dummy Drift Assembly to 385-ft. 10/03/2013 Drift 9 5/8"Csg. Spear 7"Csg and back off stub. LD 7"stub. Run new 7"Tie-Back Casing, Cement 7" I ie-Back Csg. Lift Stack.Set Slips. Cut-off Csg. Install Pack-Off. 00:00 01:00 1.00 380 1,975 COMPZ WELLPF TRIP P Finish running in with the 7"Dummy Drift Assembly on 3 1/2"Drill Plpe from the derrick with no problems. PUW=62K. SOW=57K. 01:00 02:00 1.00 1,975 63 COMPZ WELLPF TRIP P Trip out with 3 1/2"Drill Plpe standing back in the Derrick to BHA #13. 02:00 03:00 1.00 63 0 COMPZ WELLPF PULD P Lay down BHA#13,7"Dummy Drift Assembly. Rig down GBR Casing Tongs. Clean and clean Floor. Prep for the next BHA. 03:00 03:30 0.50 0 24 COMPZ WELLPF PULD P Make-up BHA#14 5 3/4"ITCO Casing Spear. 03:30 04:30 1.00 24 1,977 COMPZ WELLPF TRIP P Trip in with BHA#14 to 1,977-ft. PUW=62K. SOW=57K. 04:30 05:00 0.50 1,977 1,976 COMPZ WELLPF FISH P Plant Spear per Baker fisherman (Note: had some trouble planting Spear...most likely due to metal trash on top of the 7"Csg Stump). Back-off 7"Casing Stub at 1,977-ft with 5 turns(2500 ft lbs of torque to break connection). Pull up holel-ft. No over-pull. Fish free. 05:00 05:45 0.75 1,976 1,976 COMPZ WELLPFCIRC P Circulate and condition hole. Pumping 420 gpm w/625 psi. Pumped 230 bbls of heated 8.6 ppg seawater(140 deg). Returns were clean. 05:45 06:00 0.25 1,976 1,976 COMPZ WELLPF OWFF P Monitor well-static. Blow down the top drive. 06:00 07:00 1.00 1,976 24 COMPZ WELLPF TRIP P Pull out of the hole w/fish f/1976'to 24'. 07:00 08:00 1.00 24 0 COMPZ WELLPF PULD P Lay down Baker BHA#14(ITCO Spear)and fish 19.21'long to MU diamond on pin end of jt. 08:00 09:00 1.00 0 0 COMPZ WELLPF CIRC P Pull Cameron 9-1/16"ID wear bushing. Flush stack w/magnet assembly. Pumping 567 gpm w/130 psi. Rotate 50 rpm. Less than a pound of metal recovered. Page 19 of 31 Time Log8 ' Date r From To bur S.Depth E.beoth Phase Code SUbcode I't, Comment F. t! 09:00 11:00 2.00 0 0 COMPZ WELLPF RURD P Rig up to run 7"26 ppf L-80 TCII casing tieback string. Remove cutlip guide f/Baker triple connect, clean and inspect threads-good. Retorque the cutlip guide. Inspect HES cementer on the dummy drift assembly-OK. 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting on running order of the 7"casing. Safety issues discussed. 11:15 12:00 0.75 0 353 COMPZ WELLPF RNCS P PU/MU/RIH w/7"26 ppf L-80 TCI casing as follows: Baker triple connect,9.78'TCII x TCII pup, HES Type"H"ES cementer w/6 shear pins(3300 psi to open),5.07'TCII x TCII pup, One jt of 7"with pin baker locked,solid body centralizer on pipe body. Every thing f/pin of jt#1 to the triple connect is baker locked. Run centralizers every 5th jt. Ran a total of 8 jts prior to crew change to 353'. Torqued casing to 10,000 ft lbs of torque. PU wt 40k, SO wt 35k, block weight 30k. 12:00 12:15 0.25 353 353 COMPZ WELLPF SFTY P Pre jobs safety meeting with crew on running order and safety issues while running 7"26 ppf L-80 TCII casing. 12:15 14:30 2.25 353 1,994 COMPZ WELLPF RNCS P Continue to run 7"26 ppf L-80 TCII tieback casing string. Install solid body weatherford centralizers every 5th jt. After jt#45,went ahead and installed a centralzier on jt#47(last full jt that will be left in the hole. Made up jt#48,slacked off to install a crossover(HT 38 box x TCII pin).A total of 11 centralizers were run. Used Jet lube SealGuard thread lubricant.Torqued connections to 10000 ft lbs of torque. PU wt 77k, SO wt 67k, Rotating weight 73k. 14:30 15:00 0.50 1,994 1,999 COMPZ WELLPF OTHR P Screw top drive into crossover,slack off to locate top of jt in the hole 1997' Nabors 7ES RKB. Rotate while slacking off w/5rpm(2100 ft lbs of torque). PU wt 77k, SO wt 67k, Rot wt 73k. Torque connection to 10000 ft lbs of torque.Work up to 25k over,then 50k over and finally 75k over. 15:00 15:30 0.50 1,999 1,999 COMPZ WELLPF PRTS P Pressure test 7"string to 2080 psi f/ 10 min. Lost 25 psi in 10 min. No flow at surface-good test. Page 20 of 31 S• ljme Logs „ date From To Dur S. Depth E.Depth Phase Code Sub'code' T Comment " `'' 15:30 15:45 0.25 1,999 1,999 COMPZ WELLPF OTHR P Continue to pressure up on 7"casing to open HES cementer. Pumping 9 spm. Cementer opened @ 3200 psi. Pumped at 2 bpm(36 spm)w/40 psi,3 bpm(52 spm)w/35 psi,and 5 bpm(87 spm w/55 psi. 15:45 16:45 1.00 1,999 1,999 COMPZ CEMEN-RURD P Rig down top drive, blow down lines. Remove HT38 x 7"TCII crossover. Install 7"BTC x TCII crossover and Dowell cement head w/plug loaded. Rig up 2"hoses,etc. Schlumberger Cementers on location and rig up. 16:45 18:00 1.25 1,999 1,999 COMPZ CEMEN-CIRC P Circulate and condition well bore with 8.6 lb/gal Brine using the Rig Pump at 5.0 bpm/170 psi. Total fluid pumped=344 bbls. Page<21 of 31 Time Logs 4110 Date .. From To Dur S. Death E t:Death Phase Code . Subcode ?f' Comment 18:00 20:00 2.00 1,999 1,999 COMPZ CEMEN"CMNT P Pre-Job Safety Meeting with all. Cementers prime up. Pump 5 bbls of fresh water. Pressure test lines at 4,100 psi. Good test. Batch up Cement. Pump 10.0 bbls of 15.5 lb/gal Neat Cement (yield.93 cuft/sx)at 4.0 bpm/150 psi. Pump 71 bbls of Pressureseal Cement (yield .96 cuft/sx,Water 3.516 gal/sx,4.295 lb/sx aggregate,2 ppb LCM)with an average rate of 4.0 bpm, average pressure 100 psi, Density 15.7 lb/gal. Pump 10 bbls of 15.7 lb/gal Neat Cement(yield .93 cuft/sx,Water 3.541 gal/sx)at 3.8 bpm/50 psi. Shut down. Launch Plug. Cementer pump an additional l 2.0 bbls of Neat Cement on top of the Plug. Shut down. Close 7"Pipe Rams,open OA. Bring Rig Pump on line to displace Plug. Cementers wash up and rig down. Displaced Plug as follows: 10 bbls away, rate 4.1 bpm/120 psi. 20 bbls away, rate 3.2 bpm/400 psi. 30 bbls away, rate 3.0 bpm/590 psi. 40 bbls away, rate 2.8 bpm/665 psi. 46 bbls away, rate 2.6 bpm/735 psi Neat Cement returns to surface. 55 bbls away, rate 2.6 bpm/935 psi. Good Pressureseal Cement to surface. Shut down. Close Annulus Valve. Bring Pump back on line and squeeze away 5.5 bbls of Cement at 1.0 bpm/880 psi. 60.5 total pumped. Open Annulus Valve for the remainder of the displacement at 1.0 bpm/910 psi. Plug bumped at 20:00 hrs with a total of 65 bbls pumped with a final pressure 910 psi. Slowly ramp up the final closing pressure up to 2,400 psi. Shut down. Monitor at 2,400 psi. Release pressure and monitor no flow back. CIP 2000 hrs 10/3/2013. 20:00 22:30 2.50 0 0 COMPZ CEMEN NUND P Pump out BOP Stack. Blow down circulating lines. Lift Stack. Observe top of Cement 5.5-ft from surface. Mix 1 1/2, 5 gal buckets of cement and bring the top of cement to just below the annulus valve outlet. 22:30 23:30 1.00 0 0 COMPZ CEMEN"NUND P Cameron Service Hand install emergency Slips with the 7"Casing in 75K tension(weight indicator @ 155k, 30k block weight). RILDS. 23:30 00:00 0.50 0 0 COMPZ CEMEN'NUND P Cameron Service Hand rig up Wachs Cutter. Page;22 of 3'1 Time Lags ' Date From To Dar S.'Deoth E. Depth Phase Code :,.=Subcode T Comment „' s s`, 10/04/2013 24 hr Summary Cut-off 7"Csg. Install and test pack-off. NU Tbg Spool and BOP Stack. Change Pipe Rams in the top BOP Gate and test.. PU BHA#15 and drill Cement and ES-Cementer. 00:00 02:30 2.50 0 0 COMPZ CEMEN'NUND P Cut the 7"Casing with the Wach Cutter. Lay down the cut-off joint (OAL=30.33-ft). Set Stack back on stump. Install pack-off. Nipple up 7 1/16"x 5K tubing Spool. 02:30 03:00 0.50 0 COMPZ WELLPF PRTS P Test of Cameron Iron Works 7" packoff to 250 psi low and 3000 psi high.Witness of test by Rig Supervisor Lee Hinkel. 03:00 06:00 3.00 COMPZ WHDBO NUND P Nipple up Adapter and 13-5/8"BOP stack. Install turnbuckles. 06:00 07:00 1.00 COMPZ WHDBO OTHR P Change top pipe rams f/7"to 2-7/8" x 5"VBR's. 07:00 08:00 1.00 COMPZ WHDBO NUND P Install riser and flowline. Measure rig floor to upper Lockdown screws= 26.91'. Charge accumulator. Function test BOPE. 08:00 08:30 0.50 COMPZ WHDBO OTHR P Flush stack, pumping 13546 gpm w/ 100 psi. Rotate 50 rpm. 08:30 09:00 0.50 COMPZ WHDBO RURD P Rig up to test top pipe rams. Set Cameron upper test plug. Fill stack with water. 09:00 09:30 0.50 COMPZ WHDBO BOPE P Test top pipe rams(2-7/8"x 5")w/ 3-1/2"test joint,against choke and kill line HCR valves.Tested w/3-1/2" TIW valve.Tested all breaks on stack from nipple up.Tested to 250 psi low and 3000 psi high,5 minutes each test,charted tests. 09:30 10:30 1.00 COMPZ WHDBO RURD P Rig down testing equipment. Pull test plug. Install 6-3/8"ID Cameron wear bushing. Lay down 3-1/2"test joint. 10:30 11:30 1.00 COMPZ RIGMNT SVRG P Service top drive. 11:30 13:30 2.00 COMPZ RIGMNT RGRP T Work on top drive. Replace oil line with a grease zert on seal carrier, then grease same.Cleaned top drive w/citasolve,then used pressure washer to remove residual oil. Adjusted compensator valve f/ counterbalance. 13:30 15:00 1.50 0 231 COMPZ WELLPF PULD P PU/MU Baker BHA#15(6-1/8"bit drilling assembly)to 231' 15:00 16:00 1.00 231 1,744 COMPZ WELLPF TRIP P Trip in the hole w/Baker BHA#15 f/ 231'to 1744'. 16:00 16:45 0.75 1,744 1,744 COMPZ WELLPF CIRC P Make a top drive connection,then circulate surface to surface to clear air f/pipe. 16:45 17:15 0.50 1,744 1,744 COMPZ WELLPF DHEQ P Test casing to 1525 psi prior to drilling out HES cementer.Good test- Lost 20 psi in 10 min. Page 23 of 31 • Date " From To Dur S. Depth E.°Death Phase Code Subcode To, Comment 17:15 22:00 4.75 1,744 2,403 COMPZ WELLPF WASH P Make a top drive connection.Wash in the hole f/1744'to1,877-ft. Drilled through interment stringers to the top of harder cement at 1,930-ft. Continue to drill through cement down to the ES-Cementer at 1,982-ft. Parameters as follows: RPMs=80, Pump rate=7.0 bpm/612 psi,WOB =3-5K. Drill up the Closing Plug and drill through the ES Cementer to 1,985-ft(drill-out time=2 hrs 45 min). Continue down to 2,023-ft. Pull back up to 1,974-ft. Wash and rotate back down to 2,023-ft. Pull back up to 1,974-ft. Wash back down to 2,026-ft. Continue down to 2,406-ft. 22:00 00:00 2.00 2,403 2,403 COMPZ WELLPF PRTS P Circulate and condition the well bore from 2,403-ft. Rig up test equipment. Pressure test the 7"Casing at 2,500 psi x 30 minutes. Also tested the Annulus Valve on the Tubing Spool at the same time(note:the Annulus Valve was tested open-ended on the downstream side). Good test. Test recorded on a chart. 10/05/2013 Dry drill junk on top of the sand column with a Concave Mill.Wash junk and debris off of the sand column. Dry drill with Concave Mill again to continue to mill up junk. 00:00 01:00 1.00 2,403 230 COMPZ WELLPF TRIP P Trip out with BHA#15,standing 3 1/2"Drill Pipe standing back in the Derrick 01:00 03:00 2.00 0 2,495 COMPZ WELLPF TRIP P Stand Back the Drill Collars. Pull BHA#15 to surface. Clean Magnet(recovered 3.6 lbs of metal). Empty Boot Baskets(empty). Change the 6 1/8"Roller Cone Bit. Install the 6 1/8"Concave Mill. Trip back in hole. 03:00 04:30 1.50 2,495 2,495 COMPZ WELLPF CIRC P Tagged up on junk at 2,495-ft. Mill plugged up with trash. Work to regain circulations Circulate bottoms up. Heavy amount of Cement additive that was in the cement blend that came across the Shaker. Circulate bottoms up. 04:30 06:30 2.00 2,495 2,552 COMPZ WELLPF DRLG P Continue in hole. Tagged top of Sand at 2,547-ft. Pick-up 40-ft to 2,507-ft. Circulate Well clean at 6.0 bpm/500 psi. Recovered more Cemnet in the returns. Wash into Sand 5-ft. Dry drill on junk with the 6 1/8"Concave Mill at 2,552-ft. 60 RPMs. Torque=2-ft/lbs. Page 24 of 31 ,lime Logs V atv Date From To Dur S Depth E.'bepth Phase Code Subcode T Commen In . 06:30 08:00 1.50 2,552 0 COMPZ WELLPF TRIP P PUW=70K. Trip out with BHA#16 standing 3 1/2" Drill Pipe in the Derrick. Lay down BHA. Clean Magnet and recovered 9.0 lbs of metal. Empty Boot Baskets and recovered 12.1 bls of metal 08:00 08:30 0.50 0 240 COMPZ WELLPF PULD P Make-up BHA#17, RCJB. 08:30 09:30 1.00 240 2,552 COMPZ WELLPF TRIP P Trip in with BHA#17 on 3 1/2"Drill Pipe. Tag top of Sand at 2,552-ft. PUW=72K. SOW=62K. 09:30 10:30 1.00 2,552 2,562 COMPZ WELLPF WASH P Drop Ball and open RCJB. Pump Rate=9.0 bpm/1,800 psi. Wash and ream into the sand column from 2,552-ft down to 2,562-ft. RPMs= 60,TQ=2-3.5K WOB=0-5K. 10:30 11:30 1.00 2,562 240 COMPZ WELLPF TRIP P Trip out with BHA#17,standing 3 1/2"Drill Pipe in the Derrick. PUW= 72K. 11:30 12:00 0.50 240 0 COMPZ WELLPF PULD P Lay down BHA#17. Recovered ! 1/2 gallon of rubber and metal in the RCJB. Boot Baskets empty. Recovered 1.5 lbs of metal from the String Magnet. 12:00 12:30 0.50 0 240 COMPZ WELLPF PULD P MU BHA#18(re-run of BHA#17). 12:30 13:30 1.00 240 2,562 COMPZ WELLPF TRIP P Trip in with BHA#18 on 3 1/2"Drill Plpe from the Derrick. Tag sand top at 2,562-ft. 13:30 14:30 1.00 2,562 2,600 COMPZ WELLPF WASH P Wash and ream into the sand column from 2,562-ft to 2,600-ft. 9.0 bpm/1,820 psi, RPMs=80,TQ=2.0 -3.7K,WOB=5K. Pick up to 2,590-ft and circulate bottoms up at 9.0 bpm/1,800 psi. 14:30 15:30 1.00 2,590 240 COMPZ WELLPF TRIP P Trip out with BHA#18 standing 3 1/2"Drill Pipe back in the Derrick. PUW=68K. 15:30 16:30 1.00 240 0 COMPZ WELLPF PULD P Lay down BHA#18. No Junk recovery. 16:30 17:30 1.00 0 0 COMPZ WELLPF CIRC P Flush BOP Stack at 10.0 bpm/1,280 psi, RPM=30. 17:30 18:00 0.50 0 240 COMPZ WELLPF PULD P Make-up BHA#19(re-run of BHA #17, 18). 18:00 19:00 1.00 240 2,606 COMPZ WELLPF TRIP P Trip in with BHA#19 on 3 1/2"Drill Pipe from the Derrick. Tag sand top at 2,606-ft. 19:00 20:00 1.00 2,606 2,616 COMPZ WELLPF WASH P Wash and ream into the sand column from 2,606-ft to 2,616-ft. However, acts like there is still junk iron causing torque spikes. 9.0 bpm/1,820 psi, RPMs=60,WOB= 5- 10K,Torque= 1.9-3.2 kFt/lbs, 20:00 21:00 1.00 2,616 240 COMPZ WELLPF TRIP P Trip out with BHA#19 standing back the 3 1/2"Drill Pipe in the Derrick. PUW=68K. 21:00 22:00 1.00 240 0 COMPZ WELLPF PULD P Lay down BHA#19. Clean Magnet and recovered 19.6 lbs of metal Page 25 of 31 Time Legs Hr° ,# {; Date, I From To Dur S.rDeoth E.Deoth Phase Code ,Subcode u,T,, Comment` 22:00 22:30 0.50 0 235 COMPZ WELLPF PULD P Make-up BHA#20. 6 1/8"Concave MITI. 22:30 23:30 1.00 235 2,616 COMPZ WELLPF TRIP P Trip in with BHA#20 on 3 1/2"Drill Pipe from the Derrick. Tag top of sand at 2,616-ft 23:30 00:00 0.50 2,616 2,618 COMPZ WELLPF DRLG P Dry drill remaining junk on top of the sand column. 10/06/2013 Dry drill on junk on top of the sand column.Wash into sand with a RCJB. Perform weekly BOPE test. Circulate remaining sand. Release and pull Baker RBP. RIH with next BHA to fish the remaining 3 1/2" Completion. 00:00 01:00 1.00 2,618 2,619 COMPZ WELLPF DRLG P Continue to dry drill from 2,618-ft to 2,619-ft. RPMs=80,TQ=2-3 kft/lbs,WOB=0-5K, PUW=72K, SOW=62K, RTW=70K. 01:00 02:00 1.00 2,619 235 COMPZ WELLPF TRIP P Trip out with BHA#20 on 3 1/2"Drill Pipe,standing back in the Derrick. 02:00 02:30 0.50 235 0 COMPZ WELLPF PULD P Lay down BHA#20,6 1/8"Concave Mill. Upper Boot Basket empty, Lower Boot Basket full of Sand. Recovered-1 lb of metal on the String Magnet. Make-up RCJB. 02:30 03:30 1.00 0 2,619 COMPZ WELLPF TRIP P Trip in with BHA#21 with 3 1/2"Drill Pipe from the Derrick. PUW=72K. SOW=62K. Tag sand top at 2,619-ft. 03:30 04:00 0.50 2,619 2,635 COMPZ WELLPF WASH P Wash through Sand from 2,619 to 2,635-ft with no problems this time. Note: 10-ft of Sand remains on top of the Baker RBP at 2,645-ft. PUW= 72K. 04:00 05:15 1.25 2,635 240 COMPZ WELLPF TRIP P Trip out with BHA#21 on 3 1/2"Drill Pipe f/2635'to 240',standing back in the Derrick. 05:15 06:15 1.00 240 0 COMPZ WELLPF PULD P Lay down BHA#21. Clean String Magnet. Recovered-2 lbs of metal. Empty Boot Baskets. Recovered Sand in both Boot Baskets. Clear RCJB and recovered 3 small pieces of metal. (Remaining sand left on top of the RPB appears clean for the final sand clean-out and RBP retrieval). 06:15 06:30 0.25 0 0 COMPZ WHDBO BOPE P Pull Cameron 6-3/8"ID wear bushing. 06:30 07:00 0.50 0 0 COMPZ WHDBO CIRC P Flush stack w/stack washing tool. Pumping 564 gpm w/155 psi. Rotate 40 rpm. LID stack flushing tool. 07:00 08:00 1.00 0 0 COMPZ WHDBO RURD P Rig up to test BOPE w/3-1/2"testjt. Witness of test waived by AOGCC insp Bob Noble. Page 26 of 31 • • • Time,Logs ' ii iii, Date Pi From To Dur r,'r S.„Depth E. Depth Phase Code ■Subcode °T Comment I 08:00 14:00 6.00 0 0 COMPZ WHDBO BOPE P Weekly BOPE test.Witness of test waived by AOGCC inspector Bob Noble.Test w/both 3-1/2”&2-7/8" test joints. Main test done w/3-1/2" test joint.Test top, bottom and annular w/both sizes.Test to 250 psi low and 3000 psi high, hold each test f/5 minutes. Chart tests.Test all valves in choke manifold, mud line valve,floor safety valves,top drive manual and automatic.Test both kill line valves and both choke line valves.Test blind rams. Perform Koomey test:Annular closed in 14 seconds,top pipe in 6 seconds, lower pipe rams in 7 bCe seconds, both HCR valves less than eS' 1 second ea, blinds ramsl3 seconds. 5 nitrogen bottles w/avg 2000 psi. Closed on 2-7/8"test jt:Annular,top pipe, bottom pipe and both NCR's, opened top pipe rams to simulate the blinds. Pressure after closure was 1800 psi,200 psi build up was 16 seconds,full charge was 98 seconds. Conocophillips pump performance test:Closed top and bottom pipe and one HCR while the accumulator bottles were isolated. Electric pump took 49 seconds to full charge of 3000 psi. Repressured up system, then closed top and bottom and a HCR again with bottles isolated. Took 94 seconds for the air pump system to pump up to 2125 psi when pumps shut off. Manual valve on the choke line failed,greased valve and then held. All other tests were good. 14:00 15:15 1.25 0 0 COMPZ WHDBO RURD P Rig down 2-7/8"test joint and testing equipment. Blow down kill and choke lines,top drive. Pull Cameron upper test plug. Set Cameron 6-3/8"OD wear bushing. 15:15 15:30 0.25 0 0 COMPZ WELLPF SFTY P PJSM on PU/MU Baker BHA#22 (Retrieve RBP). 15:30 16:15 0.75 0 13 COMPZ WELLPF PULD P PU/MU Baker BHA#22 to 13'. 16:15 17:30 1.25 13 2,637 COMPZ WELLPF TRIP P Trip in the hole w/BHA#22 f/13'to 2,637-ft,top of Sand. PUW=69K. SOW=60K. Page 27 of 31 Time Logs;`:,. le 40 Date From To Dur S. Depth E. Deoth..Phase Code Subcode T Comment i-- 17:30 18:30 1.00 2,637 2,660 COMPZ WELLPF CIRC P Wash sand from 2,637'-2,645'. Engage Baker RBP. PUll 15K over to confirm latch. Circulate bottoms up at 10 bpm/1000 psi. Release RBP. Allow elements to relax. Run down to 2,660-ft to confirm release. 18:30 20:00 1.50 2,660 13 COMPZ CEMEN-TRIP P Monitor Well. PUW=69K. SOW= 60K. Trip out with RBP,standing back 3 1/2"Drill Pipe in the Derrick. 20:00 20:30 0.50 13 0 COMPZ WELLPF PULD P Lay down Retrieving Head and the Baker Model"G"Lock-Set RBP. Recovered complete. Clear and clean Rig Floor. 20:30 22:00 1.50 0 227 COMPZ WELLPF PULD P Make-up BHA#23,5 3/4"Overshot with 3 1/2"Grapple. 22:00 00:00 2.00 227 5,435 COMPZ WELLPF TRIP P Trip in with BHA#23 on 3 1/2"Drill Pipe from the Derrick to 5,435-ft. PUW= 122K. SOW=80K. 10/07/2013 Fish remaining 3 1/2"Completion..Make-up and trip in hole with 3 1/2"Mule Shoe Joint. Clean-out inside of the PBR. Pump Sweep and circulate wellbore clean with Sea Water. Start to single down the 3 1/2"Drill Pipe. 00:00 00:15 0.25 5,435 5,435 COMPZ WELLPF SFTY P BOP Drill. CRT=55 Sec. 00:15 01:00 0.75 5,435 6,854 COMPZ WELLPF TRIP P Continue to trip in with BHA#23 with 3 1/2"Drill Pipe from the Derrick. 01:00 02:00 1.00 6,854 6,854 COMPZ RIGMNT RGRP P Cut and Slip Drilling Line(95-ft). 02:00 02:30 0.50 6,854 7,120 COMPZ WELLPF TRIP P Contine to trip in with BHA#23 with 3 1/2"Drill Pipe from the Derrick to 7,120-ft. PUW= 160K. SOW= 92K. SPRs=Pump#1 34 stks/150 psi and 52 stks/300 psi. Pump#2 34 stks/157 psi and 51 stks/315 psi. RPMs=30, RTW= 115K,TQ=7.8 Kft/Ibs. 02:30 05:00 2.50 7,120 7,120 COMPZ WELLPF FISH P Work to completely plant Overshot. Grapple letting go with 20K over string weight. Finally swallowed the 3 1/2"Tubing Stump. Now jarring at 210K(50K over string weight). Fish free after 20 Jar cycles. 05:00 05:45 0.75 7,120 7,097 COMPZ WELLPF CIRC P Pull up to 7,097-ft,(BHA depth). PU wt 165k. Pump a 20 bbl Hi-Vis Sweep and chase back to surface at 10.0 bpm/2,275 psi. 05:45 06:00 0.25 7,335 7,335 COMPZ WELLPF OWFF P Monitor well-static. End of seal assembly @ 7335' 06:00 07:30 1.50 7,335 6,208 COMPZ WELLPF TRIP P POOH f/7097'to 5970'(BHA depth), laying down 3-1/2"dp. 07:30 10:00 2.50 6,208 465 COMPZ WELLPF TRIP P Continue to trip out of the hole f/ 5970'to 227'(BHA depth). 10:00 11:00 1.00 465 238 COMPZ WELLPF PULD P Lay down BHA#23 F/227'to 15' (BHA depth). 11:00 12:45 1.75 238 223 COMPZ WELLPF OTHR P Back off top sub,extension, cutlip guide f/cut jt of 3-1/2"EUE tubing. Attempting to release overshot from the fish. Did not get overshot off of fish.Approx length of cut jt= 14.99'. Page 28 of 31 Time)Logs, ;� Date From To Our. S, Depth'E.Depth Phase Code Subcode j2''T Comment 12:45 13:00 0.25 223 223 COMPZ WELLPF RURD P Rig up GBR to lay down the rest of fish. 13:00 13:45 0.75 223 0 COMPZ WELLPF PULD P Break and lay down the rest of the fish: 1 jt of 3-1/2"9.3 ppf J-55 w/csg patch hanging out the end of it, (4) more jts of same tubing, pup with holes in it, Camco MMG2 3-1/2"x 1-1/2"w/valve in it, pup below, another jt,then pup w/Baker seal assembly. Note:Total length of all of fish recovered 10/7/2013 was 238.57'. 13:45 14:45 1.00 0 251 COMPZ WELLPF PULD P Make-up BHA#24, 3 1/2"Mule Shoe Joint and Casing Scraper. 14:45 17:45 3.00 251 6,501 COMPZ WELLPF TRIP P Trip in with BHA#24 with 3 1/2"Drill Pipe from the Derrick to 6,501-ft. 17:45 19:00 1.25 6,501 7,288 COMPZ WELLPF TRIP P Continue to single in BHA#24 with 3 1/2"Drill Pipe from the Pipe Shed. 19:00 19:30 0.50 7,288 7,358 COMPZ WELLPF WASH P PUW= 160K, SOW=90K, Free TQ =8.0Kft/Ibs, RTW= 115K. Wash down at 6.0 bpm/1,099 psi from 7,288-ft to 7,345-ft,top of the PBD. Enter the PBR with no problems. Continue down inside the PBR and "No-Go"with the 3 1/2"Mule Shoe Collar at 7,345-ft. Mule Shoe at 7,358-ft. Pull Mule Shoe Joint back out of the PBR. Repeat entry to confirm with the same depths. 19:30 21:00 1.50 7,358 7,356 COMPZ WELLPF CIRC P Plck up 2-ft.Pump a 40 bbl Hi-Vis Sweep. Chase back to surface with clean Sea Water at 6.0 bpm/1,000 psi. 21:00 00:00 3.00 7,356 4,733 COMPZ WELLPF PULD P Start to Pull out with BHA#24. Single down 3 1/2"Drill Pipe to the Pipe Shed to 4,733-ft. 10/08/2013 Finish laying down drill pipe, LID BHA, Pull wear ring,Clear&clean rig floor, R/U to run 2-7/8"tbg completion string, PJSM and run completion as per-program to 7324'MD, R/U to circ, Establish circulation at 1 bpm and locate top of PBR at 7345'MD, Saw 130 psi increase,bleed off and slack off to 7353'MD,with 25K picked up and rig down circ lines, Space out, Pick up x-over and 3.5"tbg jt, M/U hanger and landing jt, M/U circ equipment. 00:00 03:30 3.50 4,733 251 COMPZ WELLPF PULD P PUW= 110K. Continue to single down 3 1/2"Drill Pipe to BHA#24. 03:30 05:00 1.50 251 0 COMPZ WELLPF PULD P Lay down 4 3/4"Drill Collars and the remainder of BHA#24. Pull Wear Bushing. 05:00 08:30 3.50 0 0 COMPZ RPCOM RURD P Clear and clean Floor. Rig up handling equipment to run the 2 7/8" Gas Lift Completion. Perform final Jewelry inspection and review running order. 08:30 09:00 0.50 0 0 COMPZ RPCOM SFTY P Hold safety and pre operations meeting with Crew and third party support service hands. Page 29 of 31 JI ! Tittle t_og$ �ES`o. II Date From To 'bur ,S.''Depth E.VDeoth Phase A Code Subcode T Comment 09:00 12:00 3.00 0 1,666 COMPZ RPCOM RCST P Pick-up Baker 80/40 Seal Assembly. Pick-up 2 7/8", L-80,6.5 lb/ft, EUE 8rd-Mod Tubing from the Pipe Shed and run the 2 7/8"Gas Life Completion as designed. Make-up torque= 1,600 ft/lbs. Jet Lube Run-N-Seal pipe dope used. PUW= 42K, SOW=40K. 12:00 19:30 7.50 1,666 7,324 COMPZ RPCOM RCST P Continue running 2-7/8"6.5 lb/ft, EUE 8rd-Mod tubing completion F/ 1660'T/7324'MD, PUW=73K, SOW=52K, 19:30 20:30 1.00 7,324 7,324 COMPZ RPCOM CIRC P R/U circulating equipment 20:30 21:30 1.00 7,324 7,324 COMPZ RPCOM CIRC P Establish circulation @ 1 bpm and 70 psi,enter PBR @ 7341'MD, slack off till pressure increased to 130 psi, bleed pressure off, slacked off to 7353'MD and set down 25K on no go, P/U and rig down circ equipment. 21:30 23:30 2.00 7,324 7,324 COMPZ RPCOM PULD P UD jts#229,#228ã, M/U space out pups, lengths=2.25', 6.32',6.28'& 10.30' P/U jt of 3.5"tbg and make up hanger and landing jt 23:30 00:00 0.50 7,324 7,324 COMPZ RPCOM CIRC P Rig up to circulate corrosion inhibitor 10/09/2013 Reverse in w/Corr Inhib Sea Watej Land Tbg Hanger. RILDS.Test Tbg and Csg. Shear SOV. Install TWCV and test. ND BOP Stack. NU Tree and test. Pull TWCV. Freeze Protect Well. Install BPV. Secure Cellar. Rig released at Midnight, 10/09/2013 00:00 02:00 2.00 7,324 7,324 COMPZ RPCOM CIRC P Finish rigging up and Reverse circ 190 bbl's of corrosion inhibitor followed by 42 bbl's sea water.3 bpm 490 psi. 02:00 02:30 0.50 7,324 7,354 COMPZ RPCOM RCST P Land tbg hanger and RILDS, Unable to run three of the lock downs in. 02:30 04:30 2.00 7,354 7,354 COMPZ RPCOM OTHR T Repair lock downs, pulled them out and chase with thread die, replace with new lock down screws,threads had gaulded. 04:30 06:00 1.50 7,354 7,354 COMPZ RPCOM PRTS P Test down tbg with 3000 psi for 15 mins, Bleed down to 1500 psi and block in, Pressure the 2-7/8"X 7"to 2500 psi for 30 min and chart both tests. Bleed Tubing and Casing pressure to"0"psi. Pressure up on the 7"x 2 7/8"Annulus to 2,050 psi and shear open the SOV. 06:00 07:00 1.00 7,354 7,354 COMPZ WHDBO OTHR P Monitor Well for 30 minutes. Fluid at surface and remains,static. Blow down lines. Lay down the Landing Joint. 07:00 07:30 0.50 0 0 COMPZ WHDBO PRTS P Set the TWCV. Pressure up the 7"x 2 7/8"Annulus to 1000 psi x 5 minutes and monitor the Tubing side for"no-flow"through the TWCV. Good. Record test on a chart. Page',30 of 31 0 Date From To Du, S. Depth E.Depth ph ase Code Subcode$ T Comment ! " 07:30 10:00 2.50 0 0 COMPZ WHDBO NUND P Blow down Choke, Kill,Top Drive, Mud Manifold,and Hole Fill Lines. Suck out BOP Stack. Nipple down BOP Stack and set back on stump. Nipple down Adaptor Spool. 10:00 12:30 2.50 0 0 COMPZ WHDBO NUND P Nipple up Production Tree(Note: Pad Operator verified tree alignment). 12:30 15:00 2.50 0 0 COMPZ WHDBO PRTS P Test Tubing Hanger void at 250/5,000 psi x 10 minutes. Good. Test Production Tree at 250/5,000 x 5 minutes. Good. 15:00 15:30 0.50 0 0 COMPZ WHDBO OTHR P Pull TWCV per Cameron Serviceman. 15:30 20:30 5.00 0 0 COMPZ RPCOM FRZP P Spot Lil' Red Services. Hold PJSM. Rig up circulating lines. Pressure test line at 2,000 psi. Pump 90 bbls of diesel down the 7"x 2 7/8" Annulus at 2.0 bpm/1,100 psi. Rig down Lil'Red. Hook up hose and allow the diesel to"U-tube". Rig down circulating lines. 20:30 21:30 1.00 0 0 COMPZ WHDBO OTHR P Final Wellhead pressures as follows: Tubing=0 psi,7 x 2 7/8"Annulus 0 psi, 9 5/8"x 7"Annulus = Cemented back to surface ...0 psi. Install BP per Cameron Serviceman. Secure Cellar. 21:30 00:00 2.50 0 0 COMPZ MOVE RURD P Finish cleaning Pits. Prep to lay down the Derrick and rig down. Rig released at Midnight, 10/09/2013. IPage 310f 31 , 190-\roc • 2201-t WELL LOG TRANSMITTAL DATA LOGGED \OAP/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 30, 2013 Attn.: Makana Bender RECEWED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 I)c i 1 0 1013 RE: CAST-M, CBL, String Shot Record: 1A-26 AOGOC Run Date: 9/24/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook@halliburton.com 1A-26 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50-029-22115-00 CAST-M/CBL Log 1 Color Log 50-029-22115-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook mato al 6900 Arctic Blvd. Sun" Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: \0 N o �'S Signed: l r ' b 2 5.S% DATA LOGGED \C/40/2013 WELL LOG TRANSMITTAL M K BENDER To: Alaska Oil and Gas Conservation Comm. September 26,2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 `. L , 1 ; �. 0 2O1:, RE: String Shot,RCT: 1A-26 Run Date: 9/22/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook,Halliburton Wireline&Perforating,6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook @halliburton.com 1A-26 Digital Data in LAS format,Digital Log Image file 1 CD Rom 50-029-22115-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook SCWEV 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: ‘O \a 1 Signed: 1.1 o)‘ )1_ee4 • • .‘+ OF TFl. � � � THE STATE Alaska Oil Gas .s ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF Q. Anchorage, Alaska 99501-3572 AL . Main: 907.279.1 433 Fax: 907.276.7542 Jake Voss kico ' i J Wells Engineer �,N A ConocoPhillips Alaska, Inc. A — I (G� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-26 Sundry Number: 313-471 Dear Mr. Voss: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P./Foerster Chair DATED this ay of September, 2013. Encl. . STATE OF• A OIL AND GAS CONSERVATION ON COMION r‘l AUG 29201;3 APPLICATION FOR SUNDRY APPROVALS ors 1 191 13 20 AAC 25.280 1.Type of Request: Abandon fl Rug for Redrill fl Perforate New Pool r Repair well fri Change A..ro Suspend r Rug Perforations r Perf orate r Pull Tubing 1 Time Extension r 1 Operational Shutdown r Re-enter Susp.Well r Stimulate fl Alter casing 1 Other: E; 2.Operator Name: 4.Current Well Class: .fi+D 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17/ Exploratory r 190-166• 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-22115-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No Pr 1A-26• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25647• Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8276• 6402 • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 16 80' 80' SURFACE 4598 9.625 4633' 3738' SCAB LINER 644 5 8145' 6303' PRODUCTION 8198 7 8233' 6370' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7700-7725,7978-7985,7998-8032 5966-5985,6176-6182,6192-6217 3.5 J-55 7563 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER'HB'RETRIEVABLE PACKER MD=7385 ND=5734. SSSV-CAMCO TRDP-4A MD=1808 TVD=1711 . 12.Attachments: Description Summary of Proposal ' 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory fl Stratigraphic r Development p'• Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/21/2013 Oil 17• Gas r WDSPL Suspended r 16.Verbal Approval: Date: WINJ r- GINJ fl WAG r Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jake Voss @ 265-6935 Email: Jake.Vossaconocophillips.com Printed Name J ke oss Title: Wells Engineer Signature r/,' Phone:265-6935 Date ?WI 3 Commission Use Only Sundry Number: �j„�' Conditions of approval: Notify Commission so that a representative may witness v►v Plug Integrity r BOP Test mechanical Integrity Test r Location Clearance r i i)* RBC MS OCT 10 2 Other: 5.67 R 17-S! 117 ,3-C c2L2j)5 i Spacing Exception Required? Yes 0 No d Subsequent Form Required: i& —4/a 4 ytt? ) APPROVED BY 9--c- - -_ Approved by: X1.44--•--- COMMISSIONER THE COMMISSION Date: Vi--'' q/51/3 Approved a MR ArEnths from the date of approval. 11°)\,e Form 10-403(Revised 10/2012) P R� Submit Form and Attachments in Duplicate • • RED 1✓ AUG 2 9 2013 ConocoPhillips AOGCC August 28, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 1A-26 (PTD: 190-166). Well 1A-26 was originally completed in 1991 as a Kuparuk A-sand producer. In 1992 the C-sand was perforated; however soon after it was brought online, the well began producing rocks. Well 1A-26 was shut-in for suspected casing damage and in 1993 a 5" liner was cemented across the A-sand and C-sand perforations. The A-sand was re- perforated on rig and the C-sand left unperforated. In 2004, a leak was found in the tubing at 7,194' RKB and a retrievable patch was set. In November of 2009, well 1A-26 failed an outer annulus low pressure test and a surface casing leak was detected at 288' RKB. In December of 2012, the well failed a TIFL and was shut in. The objective of this workover is to pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement, tie-in and cement a new 7" TC-II threaded production casing from the back-off and run a new 3 '/2" gas lift completion. If you have any questions or require any further information, please contact me at 265- 6935 or Jake.Voss @conocophillips.com. Sincerely, Jacob Voss Wells Engineer CPAI Drilling and Wells • • • 1A-26 Rig Workover, Subsidence Repair (PTD #: 190-166) Current Status: The well is currently shut in. It has leaks in the tubing and surface casing. Scope of Work: Pull the existing gas lift completion,cut and pull the 7"production casing above the top of cement, tie-in and cement a new 7"TC-II threaded production casing from the back-off,and run a new 3 V2"gas lift completion. General Well info: MASP: 1,662 psi(using 0.1 psi/ft gas gradient) t-'" Reservoir pressure/TVD: Kuparuk A-Sands—2,281 psi/6,197' TVD(7.1 ppg EMW)measured 2/07/2011. Have requested an updated SBHP before RWO. Wellhead type/pressure rating: McEvoy Gen IV,7 1/16" 5M Top x 11"3M Bottom Nabors 7ES BOP Config: Annular/7"Pipe Rams/Blind Rams/Mud Cross/Variable Pipe Ram MIT results: CMIT TxIA—Passed 12/13/2010 TIFL—Failed 11/24/2012 Well Type: Producer Estimated Start Date: September 21,2013 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Jacob Voss(265-6935/Jake.Voss @conocophillips.com) Proposed Pre-Rig Work: 1. RU Slickline 2. RIH w/Dual Panex Gauges and get updated A/C-Sand SBHP. 3. RIH and dummy drift for slim setting tool+IBP(1.69", 10' Long)to D-Nipple(2.75"ID)at 7,399'MD. a. If drift successful:RIH and set IBP to D-nipple at 7,399' MD. 4. RIH and pull OV from GLM#7 at 7,120' MD.Leave pocket open for circulating. 5. Set BPV 6. RDMO Slickline. Proposed Procedure: 1. MIRU. 2. Pull BPV. Circulate KWF to kill well. 3. Install BPV. ND tree. 4. Install the blanking plug. NU BOPE. Test BOPE to 250/3,000 psi. 5. Pull the blanking plug. Pull the BPV. 6. BOLDS,un-land tubing hanger,and pull to the floor. 7. POOH laying down tubing. 8. RIH on DP and casing scraper to the PBR. POOH standing back DP. LD casing scraper assembly. 9. RU E-Line. Log w/CAST-M. Locate TOC. RIH and fire string shot. POOH. RDMO E-line. 10. Set 1st 7"RBP above PBR. PT/DDT the RBP. 11. Set 2nd 7"RBP below TOC. PT/DDT the RBP. Dump sand. POOH with DP. 12. Monitor OA for flow. ND BOPE. Remove tubing head using Hydratight Tensioners to safely allow the 7" to grow. Spear the 7" casing and re-land it in the slips. Cut off excess casing with Wachs cutter. Tack weld slips to casing if permissible. • i 13. NU the BOPE to the casing head. (With 2 barriers in the well,BOP stack will be considered a diverter at this point. Testing BOP's would test against the 9-5/8" casing and cement shoe which we typically do not test our surface casing to>1800 psi.) 14. Cut the 7"casing above TOC. POOH with DP. 15. Reverse circulate out the Arctic Pack from the OA with heated diesel. 16. Spear the 7"casing. POOH laying down the 7"casing. 17. RIH with 9%"casing scraper to the cut 7"casing. POOH with DP. 18. Gauge the 9%"casing for the ES cementer with tandem string mills. POOH with DP. 19. Dummy drift the ES cementer. POOH with DP. 20. Backoff the top 7"casing joint. POOH with DP. 21. Engage spear on casing stub to retrieve fish. POOH with DP. 22. Run new 7" casing. PT the 7" casing and Halliburton ES cementer. Screw into top of 7" casing, Pressure test casing. 23. RU SLB cementers. Pressure up the casing to open the ES cementer. Cement the 7" casing to surface. Close cementer 24. While waiting on cement,ND BOPE. Land 7"casing in the slips. Cut excess casing off. Install packoff. NU new tubing head 25. NU BOPE and shell test break. 26. Mill up cement,and ES cementer. POOH with DP. 27. PT the casing to 3500 psi. Record test on chart for 30 minutes. 28. Mill remaining debris from the top of the sand. Circulate well clean.POOH with DP. 29. RIH with wash string,boot basket,magnets.etc and circulate sand out from on top of the RBP.POOH with DP. 30. RIH with RBP retrieving assembly. Retrieve top RBP. 31. RIH with RBP retrieving assembly. Retrieve bottom RBP. POOH laying down DP. 32. Run new 3 '/2"gas lift completion. 33. Sting into PBR. Space out for subsidence,mark the pipe,and POOH two joints. Space out with pups. 34. MU tubing hanger. Swap the well over to corrosion inhibited seawater. Land the hanger and RILDS. 35. PT tubing to 3,000 psi. Pressure test the IA to 3,500 psi for 30 minutes and record casing pressure test on chart recorder. 36. Bleed T and IA. Shear the SOV.Bleed tubing and IA pressures to zero. Monitor for flow. 37. Pull landing joint. Install BPV. 38. ND BOP stack,NU tree,pull BPV,install test plug and pressure test tree.Pull tree test plug. 39. Freeze protect w/diesel to 2,000' TVD. Set BPV. 40. RDMO. Proposed Post-Rig Work: 1. Pull BPV. 2. RU Slickline.Pull catcher. Run new gas lift design. 3. Reset well house(s)and flowlines of adjacent wells. 4. Handoff to operations. 1A-26 ConocoPhillips Subsidence RWO Planned Schematic U 4 DS Nipple, 2.313" @ 500' MD/500'TVD • Cemented OA from TOC -Surface • Casing–7"26#, L-80 TC-II @ –2,000' MD/1,851'TVD .4— Casing–9-5/8" 36#, J-55 BTC @ 4,633' MD/3,738'TVD Gas Lift Mandrels: Type MD TVD MMG, 1.5" XXXX XXXX MMG, 1.5" XXXX XXXX MMG, 1.5" XXXX XXXX MMG, 1.5" XXXX XXXX 41,1'7,4 MMG, 1.5" XXXX XXXX MMG, 1.5" XXXX XXXX 'MD/TVD of GLM to be determined - -4-- PBR @ 7,371' MD/5,724' TVD Jil_ 4 Baker HB Retrievable Packer @ 7,385'MD/5,734'TVD CQ n . -41--- Baker Liner Hanger @ 7,500'MD/5,815'TVD Tubing–3-'/2" 9.3#, L-80, 8rd EUE @ 7,564 MD/5,683'TVD E • 3.5" Shear Out Sub @ 7,563' MD/5,863'TVD C-4 Cement Squeeze @ 7,700,-7,725'MD—► A-5 Reperf @ 7,978'-7,985'MD IA-4 Reperf@ 7,998'-8,032' MD ►—: • Liner-5" 18#, N-80 FL4S: Top-7,500' MD, Set @ 8,145' MD/6,303'TVD Casing–7" 26#, J-55 G • @ 8,233' MD/6,370'TVD Date: August 28,2013 I Drawn By:Jacob Voss r KU P 1A-26 • ConocoPhillips 014 Well Attributes Max Angle&MD TD r- Inc. Wellbore API/UWI Field Name Well Status Intl(°) MD(RKB) Act Btm MB) 500292211500 KUPARUK RIVER UNIT PROD 47.36 6,000.00 8,276.0 ------ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP 83 8/14/2012 Last WO: 8/16/1993 35.01 1/10/1991 Well Conriq:-1A-26,2f28/2013 1 23:00 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,002.0 l 12/2/2010 Rev Reason:WELL REVIEW osborl 2/28/2013 „ANGER,31 ; N.^ Casing Strings ®.;., Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H-40 WELDED Casing tead rtp Casing Deacriptlon String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)...String Wt...String...String lop Thrd 1;11 SURFACE 95/8 8.765 35.0 4,632.8 3,738.4 36.00 J-55 BTC CONDUCTOR I Casing Description String 0... String ID...Top(RKB) Set Depth(l...Set Depth(ND)...String Wt...String...String Top Thrd InsuWlea324•, PRODUCTION 7 6.276 35.0 8,233.4 6,369.8 26.00 J-55 ABMODBTC 36-80 Casing Description string 0... String ID...Top(RKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd SCAB LINER 5 4.151 7,500.6 8,145.0 6,302.8 18.00 N-80 FL4S SAFETY VLV, - 1,808 Liner Details Top Depth (ND) Top Intl Nomi... --_- Top(RKB) (RKB) (°) Item Deacriptlon Comment ID(in) Or 7,500.6 5,815.3 40.96 SLEEVE BAKER SETTING SLEEVE 5.250 GAS LIFT, 7,507.8 5,820.8 40.96 HANGER BAKER LINER HANGER 4.437 3.046 IL Tubing Strings NM Tubing Description String 0... String ID...Top(RKB) Set Depth(1...ISet Depth(TVD)..String Wt...String... String Top Thrd TUBING WO 4"x3.5" 4 3.476 31.0 7,564.2 l 5,863.3 11.00 J-55 DSSHTC Completion Details GAS LIFT, ' 4,127 ToP Depth Bond... „_- (ND) Top Intl ID(In) Top(RKB) (RKB) (°I Item Description Comment 31.0 31.0 -0.22 HANGER McEVOY TUBING HANGER 4.000 1,808.3 1,711.2 40.06 SAFETY VLV CAMCO TRDP-4A-R0 3.312 4,927.3 3,952.1 44.17 XO CROSSOVER 4"x3.5"(ID 2.992",J-55,9.3#) 3.500 REDUCING SURFACE, J �j i 7,371.4 5,724.3 44.66 PBR BAKER PBR 3.000 7,385.1 5,734.0 44.56 PACKER BAKER'HB'RETRIEVABLE PACKER 2.890 35-4,633 7,399.3 5,744.2 44.46 NIPPLE CAMCO'D'NIPPLE NO GO PROFILE 2.750 7,563.2 5,862.6 40.99 SOS BAKER SHEAR OUT SUB 3.500 GAS LIFT, Other In Hole(Wireline retrievable plugs,valves,pumpay,ih,etc.) 4.990 ` . Top Depth i (ND) Top Inc! Top(RKB) (RKB) (°) Description Comment Run Date ID(in) cns51 5,675 _. 7,181.0 5,588.2 44.21 PATCH WEATHERFORD ECLIPSE PATCH(TOL 25.58')set 11/5/2004 1.750 11/5/2004 GAS LIFT, 6,235 - Perforations&Slots NI Shot GAS LIFT, Top(ND) Btm(ND) Dens 6,798 Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date Oh- Type Comment L 7,700.0 7,725.0 5,965.8 5,984.7 C-4,1A-26 6/3/1992 6.0 CMT Squeezed GAS LIFT, SQZ 7,120 7,978.0 7,985.0 6,176.4 6,181.7 A-5,1A-26 8/16/1993 4.0 RPERF 180 deg.Phasing'SWS 33/8"HSD on WO Rig PATCH,7,181 7,978.0 7,985.0 6,176.4 6,181.7 A-5,1A-26 5/31/1991 4.0 CMT Squeezed;HLS 4.5"Casing Guns SQZ 7,998.0 8,032.0 6,191.5 6,217.2 A-0,1A-26 5/31/1991 4.0 CMT Squeezed;HLS 4.5"Casing Guns GAS LIFT, SQZ 7,321 alli 7,998.0 8,032.0 6,191.5 6,217.2 A-4,1A-26 8/16/1993 4.0 RPERF 180 deg.Phasing'SWS 3 3/8"HSD ill on WO Rig 8,012.0 8,032.0 6,202.1 6,217.2 A-4,1A-26 8!16/1993 4.0 APERF 180 deg.Phasing'SWS 3 3/8"HSD on WO Rig PBR,7.371 .. Notes:General&Safety PACKER,7,385 -- End Date Annotation 8/15/1993 NOTE:Junk was cemented in hole NIPPLE,7,399 - 9/17/2004 NOTE:TBG LEAK @ 7194' III 6/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 I SOS,7,563 y, CMT SOZ, 7,700.7,725 RPERF, 7,978-7,985 CMr soz. r- Mandrel Details 7,978-7,985 - Port Top Depth Top CMT SOZ, 1 5... (TVD) Intl OD Valve Latch Size TRO Run 7,098-8.032 _ N...Top(RKB) (RKB) (°) Make Model (in) Sere Type Type (in) (par) Run Date Com... RPERF, 1 3,045.8 2,592.1 45.55 OTIS WBX 1 GAS LIFT GLV BK 0.156 1,332.0 11/30/2012 7,9 RPER2 - _ .__ 8.01'17M ° APERF' =_ 2 4,127.4 3,374.7 43.86 MERLA TMPD 1 GAS LIFT DMY BK2 0.000 0.0 8/16/1993 _-= 3 4,990.4 3,997.6 43.86 MACCO SPM-1A 1 GAS LIFT GLV BK 0.156 1,304.0 11/30/2012 4 5,675.4 4,485.8 44.75 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 8/29/2004 5 6,235.0 4,884.0 41.34 MACCO SPM-1A 1 GAS LIFT GLV BK 0.188 1,320.0 11/30/2012 SCAB LINER, J 6 6,798.2 5,307.1 40.96 MACCO SPM-1A 1 GAS LIFT DMY INT 0.000 0.0 12/1/2012 750141'145 7 7,119.7 5,544.1 42.68 MACCO SPM-1A 1 GAS LIFT OV BK 0.250 0.0 12/1/2012 8 7,321.0 5,688.8 45.04 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 9272004 PRODUCTION, 35-5233 TD,8,276 • • WELL LOG TRANSMITTAL Ia. PRoAci1VE DIAC SEItwicES, INc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 MAR 0 3 2011 [907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 30- Jan -11 1A-26 1 Report / EDE 50 - 029 - 22115 - 00 2) Caliper Report 05- t -11 1D-10 1 Report / EDE 50-029 - 22870 -00 Eb q04'g a0 X90 - /Co & 06"7 REcE rtim igned : ( Date : FEB E 1111 Print Name: 6 e nisi 6r' son f PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PH0NE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : adsanchoraueCanmemorvloa.com WESSITE : www.memorvloa.com C:\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.docx • • IP/ Multi- Finger Caliper Log Results Summary ' Company: ConocoPhillips Alaska, Inc. Well: 1A -26 Log Date: January 30, 2011 Field: Kuparuk Log No.: SO# 10261934 ZX70 State: Alaska Run No.: 2 API No.: 50-029-22115-00 Pipet Desc.: 4" 11 Ib. J-55 Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 4,950 Ft. (MD) Pipe2 Desc.: 3.5" 9.3 Ib. J -55 Top Log Intvl: 4,950 Ft. (MD) Pipe2 Use: Tubing Bot. Log Intvl: 7,163 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection ' COMMENTS : This caliper data is correlated to the Tubing Detail dated August 16, 1993. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 4" tubing appears to be in good condition, with no significant wall penetrations, areas of cross- sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 3.5" tubing logged appears to be in good to fair condition, with a ' maximum recorded wall penetration of 37% in joint 69 (7,078 ft.). Recorded damage appears as isolated pitting, shallow pitting and a shallow line of pits. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a caliper has been run in this well, the first time the 4" tubing has been logged, and the second time the 3.5" tubing has been logged from 6,288 ft. to 7,163 ft.. A comparison of the current and previous log (September 20, 2004) indicates a slight increase in corrosive damage throughout this interval during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint by joint basis between logs is included in this report. This summary report is interpretation of data provided by Halliburton Well Services. 1 4" TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 14 %) are recorded. ' 4" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 4 %) are recorded. 4" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 1 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS : Isolated Pitting ( 37 %) Jt. 69 @ 7,078 Ft. (MD) Isolated Pitting ( 36%) Jt. 71 @ 7,146 Ft. (MD) Line of Pits (20 %) Jt. 27 @ 5,794 Ft. (MD) 1 No other significant wall penetrations (> 19 %) are recorded throughout the tubing logged. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS�amemorylog.com ' Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 190 --r6,6 act 36 • • 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the tubing logged. I 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 1 1 I 1 1 1 1 1 1 1 1 Field Engineer: J. Conrad Analyst: C. Lucasan Witness: M. Walters I I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 I • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 4 in (65.2' - 4949.6') Well: 1 A -26 I Pipe 2 3.5 in (4949.6' - 7159.1') Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 30, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 68 1 I 25 I 1008 II 1 50 1 2009 I GLM 1 75 2989 7 0 I GLM2 _ 100 ` 3988 , ,i c Z s C i n GLM 3 ° 1 4950 0 I GLM 4 25 5703 I GLM 5 50 6472 GLM 6 I GLM 7 72 7159 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) I I Bottom of Survey = 72 I I . • I PDS Report Overview ti Body Region Analysis 1 Well: 1A -26 Survey Date: January 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 4 ins 11 ppf J -55 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4 ins 11 ppf J -55 3.476 ins 4 ins 6 ins 6 ins I Penetration(% wall) Damage Profile (% wall) I 150 =NI Penetration body MINI Metal loss body 0 50 100 0 100 ' 50 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 130) 130 0 0 0 48 I Damage Configuration ( body ) 10 I GLM 1 g g 5 I g 96 GLM 2 0 I Isolated General Line Other Hole/ � Pitting Corrosion Corrosion Damage Pos. Hole = = I Number of joints damaged (total = 2) 2 0 0 0 0 Bottom of Survey = 123.1 I I I I I • PDS REPORT JOINT TABULATION SHEET I Pipe: 4 in 11.0 ppf J -55 Well: 1A-26 Body Wall: 0.262 in Field: Kuparuk 1 Upset Wall: 0.262 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.476 in USA Survey Date: January 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 65 0 0.01 3 1 1 68 0 0.02 8 2 3.45 3.37 Pup Lt. Deposits. iii 2 107 0 0.02 7 1 3.44 3 146 0 0.01 6 2 3.44 1 I 4 5 185 0 0.02 8 1 3.42 225 0 0.02 6 2 3.44 6 264 0 0.01 6 2 3.45 1 7 303 0 0.02 8 2 3.44 II 8 342 0 0.02 6 2 3.44 i I 9 381 0 0.02 8 2 3.44 10 420 0 0.01 6 2 3.45 II 11 459 0 0.02 7 2 3.44 12 499 0 0.02 7 2 3.43 I 13 538 0 0.03 10 2 3.43 • 14 577 0 0.02 6 2 3.43 15 616 0 0.02 9 2 3.43 • 16 656 0 0.03 10 2 3.42 IN 17 695 0 0.02 9 2 3.43 a 1 ' 18 734 0 0.02 8 2 3.45 19 774 0 0.02 7 1 3.45 20 813 0 0.02 7 2 3.43 X 21 852 0 0.02 7 2 3.45 11 I 22 891 0 0.02 8 2 3.45 23 930 O 0.02 8 2 3.45 Iii 24 969 0 0.01 6 2 3.44 1 25 1008 0 0.02 6 2 3.40 X I 26 1048 0 0.02 7 1 3.44 27 1087 0 0.01 6 2 3.44 s 28 1126 0 0.01 5 2 3.44 29 1165 0 0.02 6 2 3.43 a I 30 1204 0 0.02 8 2 3.43 31 1244 0 0.02 8 1 3.43 • 32 1283 0 0.01 6 2 3.45 • 33 1322 0 0.01 6 1 3.43 II I 34 1361 0 0.01 5 2 3.45 35 1400 0 0.02 6 2 3.43 36 1440 0 0.02 7 2 3.42 C 37 1479 0 0.01 6 2 3.44 38 1518 0 0.02 7 1 3.45 0 I 39 1557 0 0.01 6 1 3.43 40 1596 0 0.02 6 2 3.44 1 41 1635 0 0.01 6 2 3.44 42 1674 0 0.02 7 2 3.40 I 43 1714 0 0.02 7 2 3.43 44 1753 0 0.02 8 2 3.44 45 1792 0 0.02 6 1 3.44 45.1 1831 0 0.01 6 3 3.39 Pup I' I 45.2 1840 0 0 0 0 3.30 Camco TRDP 4A -R0 SSSV 45.3 1845 0 0.01 6 3 3.38 Pup 46 1853 0 0.02 8 2 3.42 Penetrat Metal Loss ion Body Page 1 I 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4 in 11.0 ppf J -55 Well: 1A -26 Body Wall: 0.262 in Field: Kuparuk I Upset Wall: 0.262 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.476 in Country: USA Survey Date: January 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I li 47 1892 48 1931 0 0.02 6 2 3.42 0 0.02 9 2 3.43 49 1970 0 0.02 8 3 3.43 50 2009 0 0.02 6 2 3.43 51 2048 0 0.02 7 1 3.42 • I 52 2088 0 0.02 7 2 3.43 53 2127 0 0.02 7 2 3.43 i 54 2166 0 0.02 8 2 3.42 55 2205 0 0.02 7 2 3.41 • 56 2244 0 0.02 8 2 3.44 , 57 2284 0 0.02 6 2 3.43 . 58 2323 0 0.02 7 2 3.42 59 2362 0 0.02 7 1 3.43 1 60 2401 0 0.01 6 2 3.42 1 61 2440 0 0.02 6 1 3.42 1 62 2479 0 0.02 8 2 3.40 • 63 2519 0 0.02 8 2 3.43 • 64 2558 0 0.02 7 2 3.43 1 1 65 2598 0 0.02 6 2 3.42 1 66 2637 0 0.02 6 2 3.44 1 67 2676 0 0.02 7 2 3.42 1 68 2715 0 0.02 7 2 3.42 1 I 69 2754 0 0.01 5 1 3.43 70 2794 0 0.02 8 2 3.43 • • 71 2833 0 0.02 8 2 3.41 72 2872 0 0.01 6 1 3.42 I 73 2911 0 0.02 7 2 3.43 74 2950 0 0.02 8 2 3.41 • 75 2989 0 0.02 8 2 3.40 • 76 3029 0 0.02 7 2 3.43 • I 76.1 3067 0 0.03 10 3 3.34 Pup Lt. Deposits. P 76.2 3074 0 0 0 0 3.13 GLM 1 (Latch @ 7:00) 76.3 3080 0 0.03 12 3 3.35 Pup Shallow Pitting. Lt. Deposits. 77 3089 0 0.02 7 2 3.42 78 3127 0 0.02 8 2 3.41 I 79 3166 0 0.03 10 2 3.42 80 3206 0 0.02 9 2 3.42 • 81 3245 0 0.02 7 2 3.42 1 82 3284 0 0.02 7 2 3.42 II I 83 3323 0 0.03 11 2 3.42 84 3362 0 0.02 6 1 3.42 II 85 3401 0 0.02 9 1 3.42 • 86 3440 0 0.02 9 2 3.39 • I 87 3480 88 3519 0 0.02 8 2 3.42 0 0.03 11 2 3.43 • • 89 3558 0 0.03 10 2 3.43 • 90 3597 0 0.03 11 2 3.42 • I 91 3636 0 0.03 11 2 3.41 • 92 3675 0 0.02 7 2 3.42 93 3715 0 0.02 7 2 3.41 Lt. Deposits. Bo II Metal Loss Body I Page 2 Penetration I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4 in 11.0 ppf J -55 Well: 1A-26 Body Wall: 0.262 in Field: Kuparuk I Upset Wall: 0.262 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.476 in USA Survey Date: January 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Iris.) (Ins.) %) (Ins.) 0 50 100 94 3754 0 0.02 9 2 3.41 Lt. Deposits. 95 3793 0 0.03 10 2 3.41 Lt. Deposits. • 96 3832 0 0.04 14 2 3.41 Shallow Pitting. Lt. Deposits. 97 3871 U 0.01 5 1 3.39 Lt. Deposits. 98 3911 0 0.02 7 1 3.41 Lt. Deposits. 99 3950 0 0.02 6 2 3.40 Lt. Deposits. 100 3988 0 0.02 9 2 3.38 Lt. Deposits. 101 4028 0 0.02 8 2 3.37 Lt. Deposits. 102 4067 0 0.02 7 2 3.38 Lt. Deposits. ' 103 4106 0 0.03 10 2 3.36 Lt. Deposits. 103.1 4145 0 0.02 8 2 3.32 Pup Lt. Deposits. 103.2 4152 0 0 0 0 3.09 GLM 2 (Latch To 1:00) 103.3 4159 0 0.03 10 2 3.34 Pup Lt. Deposits. • I 104 4166 (? 0.03 11 2 3.39 Lt. Deposits. 105 4205 0 0.02 9 2 3.38 Lt. Deposits. 106 4244 0 0.03 12 2 3.36 Lt. Deposits. ■ 107 4283 0 0.03 10 3 3.35 Lt. Deposits. I 108 4323 0 0.02 9 3 3.39 Lt. Deposits. 109 4362 0 0.02 9 2 3.38 Lt. Deposits. • 110 4401 U 0.03 10 2 3.39 Lt. Deposits. ■ 111 4440 0 0.03 10 2 3.38 Lt. Deposits. 112 4479 U 0.02 8 2 3.35 Lt. Deposits. I 113 4518 0 0.03 11 2 3.38 Lt. Deposits. IN 114 4558 0 0.03 11 2 3.38 Lt. Deposits. ■ 115 4597 0 0.03 12 2 3.36 Lt. Deposits. 116 4636 0 0.02 8 2 3.40 Lt. Deposits. I 117 4675 , 0 0.03 11 2 3.37 Lt. Deposits. • 118 4714 0 0.03 10 2 3.35 Lt. Deposits. • 119 4754 0 0.02 9 2 3.38 Lt. Deposits. • 120 4793 0 0.03 10 2 3.38 Lt. Deposits. • I 121 4832 0 0.03 10 3 3.39 Lt. Deposits. • 122 4871 0 0.03 10 2 3.38 Lt. Deposits. el 4910 (1 0.03 10 2 3.36 Lt. Deposits. 123.1 4950 0 0 0 0 2.91 4" x 3.5" Cross -over rt ' Penetration BoBody dy I I I I Page 3 I I I Maximum Recorded Penetration I `" i Comparison Well: 1 A -26 To Previous Survey Date: January 30, 2011 Field: Kuparuk Prey. Date: September 20, 2004 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 10000428 HAL I C ountry: USA Tubing: 3.5" 9.3 lb 1-55 Overlay Difference Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0 50 100 150 200 250 -50 0 50 100 44 44 -- 1 'I -` t ■ — . 111111. II I Or _IMF MI ■ 54 ` 54 • r _! _1 _NI .ii i E 1 I z ` z •a ! ` • 1 I )11101 ■ 63 !ll 63 • IIII _IM - 1 I MI ■ IllM -� !m IN ) 1=W . 72 IS 72 1 I -16 -8 0 8 16 • January 30, 2011 ■ September 20, 2004 Approx. Corrosion Rate (mpy) I I I 1 • • I PDS Report Overview Body Region Analysis I Well: 1A -26 Survey Date: January 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J -55 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 2.992 ins 3.5 ins 6 ins 6 ins I Penetration(% wall) Damage Profile (% wall) it 80 P body Metal loss body 0 50 100 ' 1 60 GLM 3 40 12: 1 1 I 0 to 20% 20 to 40% 40 to 85% over 85% 21 GLM 4 Number of joints analysed (total = 72) I 69 3 0 0 31 I Damage Configuration ( body ) 41 60 I GLM 5 I 40 1 51 20 GLM 6 61 0 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole GLM 7 7T I Number of joints damaged (total = 54) 54 0 0 0 0 Bottom of Survey = 72 I I I 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 Well: 1A-26 Body Wall: 0.254 in Field: Kuparuk 1 Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: January 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 1 4950 0 0.03 11 2 2.92 ■ 2 4981 0 0.03 12 2 2.95 Slight Buckling 2.1 5012 0 0 0 0 2.92 GLM 3 (Latch @ 1:00) 3 5019 0.03 0.05 19 2 2.93 Shallow Line of Pits. • I 4 5050 0 0.03 13 5 2.93 Shallow Pitting. ■ 5 5082 0 0.03 12 3 2.94 Shallow Pitting. • 6 5113 () 0.03 13 2 2.94 Shallow Pitting. ■ 7 5144 0.04 0.04 17 2 2.96 Shallow Line of Pits. • 8 5174 0 0.04 17 4 2.92 Shallow Line of Pits. Lt. Deposits. • I 9 5205 0 0.04 18 4 2.93 Shallow Line of Pits. Lt. Deposits. • 10 5237 0 0.04 16 3 2.93 Shallow Line of Pits. ■ 11 5265 0 0.04 15 3 2.92 Shallow Pitting. Lt. Deposits. ■ 12 5296 0 0.05 19 3 2.90 Shallow Line of Pits. Lt. Deposits. • I 13 5328 14 5358 0 0.04 14 2 2.94 Shallow Pitting. • 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. • 15 5390 0.04 0.04 14 4 2.90 Shallow Line of Pits. Lt. Deposits. ■ 16 5421 0.05 0.05 19 4 2.91 Shallow Line of Pits. Lt. Deposits. • I 17 5452 0 0.03 12 2 2.89 Lt. Deposits. • 18 5482 0 0.04 15 4 2.93 Shallow Pitting. Lt. Deposits. • ■ 19 5513 0 0.03 11 3 2.94 Slight Buckling • 20 5544 0.03 0.04 17 4 2.93 Shallow Line of Pits. ■ 21 5573 0.04 0.04 14 3 2.94 Shallow Pitting. Slight Buckling ■ I 22 5604 0 0.03 11 3 2.88 Lt. Deposits. Slight Buckling • 23 5634 0 0.04 15 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 24 5666 0 0.04 18 4 2.90 Shallow Line of Pits. Lt. Deposits. 24.1 5697 0 0 0 0 2.92 GLM 4 (Latch @ 11:30) I 25 5703 0 0.03 11 3 2.95 Slight Buckling • 26 5734 0 0.03 12 2 2.95 Shallow Pitting. • ■ 27 5765 0 0.05 20 4 2.91 Line of Pits. Lt. Deposits. • 28 5797 0.04 0.04 14 2 2.94 Shallow Line of Pits. • I 29 5826 0 0.04 14 2 2.94 Shallow Line of Pits. • 30 5855 0 0.04 14 5 2.93 Shallow Pitting. Lt. Deposits. • ■ 31 5887 0 0.05 19 4 2.94 Shallow Line of Pits. Slight Buckling • 32 5918 0 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. • 1 33 5947 0 0.05 19 5 2.92 Shallow Line of Pits. Lt. Deposits. II 34 5977 0 0.05 19 3 2.93 Shallow Line of Pits. Lt. Deposits. ■ 35 6009 0.06 0.04 14 3 2.91 Shallow Line of Pits. Lt. Deposits. ■ 36 6040 0 0.03 13 4 2.88 Shallow Pitting. Lt. Deposits. ■ 37 6071 0 0.03 11 6 2.94 Slight Buckling ■ 1 38 6102 0 0.03 10 3 2.92 Lt. Deposits. Slight Buckling • 39 6133 0 0.03 10 2 2.91 Lt. Deposits. Slight Buckling • 40 6161 0 0.04 15 3 2.91 Shallow Line of Pits. Lt. Deposits. • 41 6192 0 0.03 13 3 2.89 Shallow Pitting. Lt. Deposits. • I 42 6221 0 0.03 13 4 2.90 _ Shallow Pitting. Lt. Deposits. 42.1 6252 0 0 0 0 2.92 GLM 5 (Latch @ 3:00) 43 6259 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. • 44 6289 0 0.05 19 2 2.93 Shallow Line of Pits. Lt. Deposits. • I 45 6320 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. in 6349 0 0.03 12 2 2.93 Lt. Deposits. Slight Buckling • ■ 47 6380 0 _ 0.04 17 6 2.91 Shallow Pitting. Lt. Deposits. Penetrat I Metal Loss ion Body Page 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 Well: 1 A -26 Body Wall: 0.254 in Field: Kuparuk 1 Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: January 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 48 6409 0 0.04 18 4 2.92 Shallow Line of Pits. Lt. Deposits. • 49 6440 0 0.04 15 4 2.91 Shallow Pitting. Lt. Deposits. • ■ 50 6472 0 0.03 10 3 2.92 Lt. Deposits. Slight Buckling • 51 6503 0 0.04 15 3 2.89 Shallow Line of Pits. Lt. Deposits. • 52 6535 0 0.04 15 3 2.91 Shallow Line of Pits. Lt. Deposits. • I 53 6565 0 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. In 54 6596 0 0.03 10 2 2.93 Lt. Deposits. ■ 55 6626 0 0.04 14 3 2.90 Shallow Line of Pits. Lt. Deposits. • 56 6658 0 0.04 14 3 2.89 Shallow Line of Pits. Lt. Deposits. ■ I 57 6688 0 0.03 10 3 2.91 Lt. Deposits. • 58 6719 0 0.03 11 2 2.92 Lt. Deposits. Slight Buckling • ■ 59 6750 0 0.03 10 2 2.90 Lt. Deposits. Slight Buckling ■ 60 6778 0 0.03 11 2 2.90 Lt. Deposits. I 60.1 6806 0 0 0 0 2.90 GLM 6 (Latch @ 9:00) I 61 6813 0 0.04 17 4 2.92 Shallow Line of Pits. Lt. Deposits. • 62 6845 0 0.04 15 4 2.93 Shallow Pitting. Lt. Deposits. • 63 6876 0 0.04 18 2 2.90 Shallow Line of Pits. Lt. Deposits. • I 64 6908 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. • 65 6939 0 0.03 11 2 2.88 Lt. Deposits. • 66 6970 0 0.04 16 3 2.91 Shallow Pitting. Lt. Deposits. ■ 67 7001 0 0.04 17 2 2.92 Shallow Line of Pits. Lt. Deposits. • 68 7032 0 0.03 1 1 4 2.91 Lt. Deposits. Slight Buckling • I 69 7064 70 7091 0 0.09 37 3 2.91 Isolated Pitting. Lt. Deposits. • 0 0.04 16 4 2.91 Shallow Line of Pits. Lt. Deposits. 70.1 7121 0 0 0 0 2.93 GLM 7 (Latch @ 8:30) 71 7128 0 0.09 36 5 2.94 Isolated Pitting. I 72 7159 0 0.03 13 6 2.87 Shallow Pitting. Lt. Deposits. ■ Penetration Body Metal Loss Body I 11 i 1 I I I Page 2 I I I • r I PDS Report Cross Sections I Well: 1A -26 Survey Date: Tool Type: January 30, 2011 Field: Kuparuk UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf J -55 Analyst: C. Lucasan I I Cross Section for Joint 69 at depth 7078.390 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 98% Tool deviation = 43° / I / i 1 I 1 � 1 ,,"/ �� I Finger = 12 Penetration = 0.094 ins Isolated Pitting 0.09 ins = 37% Wall Penetration HIGH SIDE = UP I I I I I I i • I s PDS Report Cross Sections ti ,,. I Well: 1A -26 Survey Date: Tool Type: January 30, 2011 Field: Kuparuk UW MFC 24 No. 10000428 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf J -55 Analyst: C. Lucasan I I Cross Section for Joint 71 at depth 7145.550 ft Tool speed = 39 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 97% Tool deviation = 44° I / I \\ I \ I 1 111 1 I Finger = 4 Penetration = 0.091 ins Isollated Pitting 0.09 ins = 36% Wall Penetration HIGH SIDE = UP I I I I i KUP Conoco Phillips ell Attributes ngle & MD TD 1A -26 'W'elbore ApIllsteI I R ht°t 1 111 18NY1e 'W'ee Stet31 Ed cl MDiBF: B? I1 id. Act Bhn(1tNEdtt Cs.inn iUin / 500292211500 IKUPARUK RIVER UNIT PROD 47.36 6,000.00 8,276 I ... Comment IEdd SV: TRDP H2SiPPm ) Cob 8lG20 EdIt La WO j� 8l16F799 N B Pt) pig 1 9 Edit - ° _trT,ulc - -:rte Annotaton Depth ( 085) Rid Da I dry Annohton La it Mod By Bid We Edit Last Tag: SLM 8,002.0 12 Rev Reason: GLV CFO, TAG Imasbor 1!11201 IAIGEe. Casing Strings Casing Dettripton Siring on_ Sting ID... Top (10(EN Set Depth (1... net Depth iTr D)... Sting WY.. Sting... String Top 11 1)111121 III Ill '1 IV 111 CONDUCTOR 16 15.062 36.0 80.0 80.0 65.00 H-10 WELDED I (S ting Deseripton Sting CO.. Sting ID... Top MP B) Set Depth (0.. Set Depth (Tien_ String Wt... Sting... Sting Top TtI SURFACE 95/8 8.765 35.0 4,632.8 3,738.4 36.00 J-55 BTC Cling De oeipton Sting OD.. String ID.,. Top (Tte B) Set Dept IT... Sot Copal WO)... Sting WY.. String... S ting Top 1 1 1 ) call PecTO P, • PRODUCTION 7 6.151 35.0 8,233.4 6,369.8 26.00 J55 ABMOD IL 3690 Catnip De.eripton Sting 00.. String ID... Top (/tli B) let Depth (t... Set Min CND)... Sting WY.. Sting... Sting Top Ill SCAB LINER 5 4.151 _ 7 ,500.5 8,145.0 6,302.8 18.00 N -80 FL4S Liner Details 1 a °.f ETr'v �,l Top Dept, 1 Top (TWO) Top 116l 11010 I (TM 01 (101081 ( °i tem Deecipt Comment omment ID(ini 7,500.5 5,815.3 40.96 SLEEVE BAKER SETTING SLEEVE 5.250 7.507.8 5,820.8 40.96 HANGER BAKER LINER HANGER 4.438 I G•^ Mr 3pW { ilii. Tubing Strings Tubing Deicipton Sting OD... String ID... Top irti B) Set Dept) it.. Set Cepin iTvm)._'Sting Wt.. Sting... String Top TV riff TUBING 4 4 3.476 31.0 7 5,863.3 I 11.00 J-55 DSSHT Completion Details t dff Top Dept) I G 0 FT I Top I T/D Top 1001 11001... 7 4 .. +.I i t5t01 ittI: E1 i' tem Delorlpton Comm 101101 31.0 31.0 -022 HANGER McEVOY TUBING HANGER 4.000 } 1,808.3 1,711.2 40.06 SAFETY VLV CAMCO TRDP-4A -R O 3.312 r 4,927.3 3,952.1 44.17 X0 403.5 CROSSOVER 4 "03.5" (ID 2.992°, JS5, 9.30 3.500 7,371.4 5,724.3 44.66 PBR BAKER PBR 3.000 7,385.1 5,734.0 44.56 PACKER BAKER 'HB' RETRIEVABLE PACKER 2.890 J l 7,399.3 5,744.2 44.46 NIPPLE CAMCO'D NIPPLE NOGO 2.750 35-4633 7,5632 5,862.6 40.99 SOS BAKER SHEAR OUT SUB 3.500 P Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) I I Top Depth Top (Twin) Top NI G•3 ufr, lItE el ittP:61 nil De mnptan •_amment nun Cote 1G(ln - 1 + 7,181.0 5,58$2 4421 PATCH WEATHERFORD ECLIPSE PATCH (TOL25.58)set 11152004 1.750 G° : LIFT, _ 1115{2004 6,675 DA. Perforations & Slots I shot G• LIiT, 6�ys BY Top (TVD) Bh/ (TPD) Den 1 Ton Eats 1+ B) (ROB) MR B) 000 Cats w T,ye , Com ment 7,700.0 7,725.9 5,965.8 5,984.7 6/3/1992 6.0 APERF Squeezed G•A LIFT• 6.1 7,978.0 7,9$5.0 6,176.4 6,181.7 5/31/1991 4.0 IPERF Squeezed; HLS 4.5" Casing Guns I 7,978.0 7,985.0 6,176.4 6,181.7 8/16/1993 4.0 RPERF 180 deg. Fhasing; "HSDon G °.^, LI, Tom, WO Rig 7,998.0 $,032.0 6,191.5 6,217.2 5!31/1991 4.0 IPERF Squeezed; HLS 4.5" Casing Guns PATCP,7,18I I I 7,998.9 8,032.9 6,191.5 6,2172 8!1611993 4.0 RPERF 180 deg. Phasing' SWS33/ff'HSDon WO Rig Cement Squeezes �Ed1t Top Depth 51m Witt G•..^, LIfT, B1011 (TX) (TvD) 7.v i Top itt6B) i ttI'Bi ittI' Eli iRP:.B. ()wanton Start Cate Comment 7,700.0 7,725.0 5,965.8 5,984.7 Cement Squeeze 8/15/1993 7,978.0 7,985.0 6,176.4 6,181.7 Cement Squeeze 8/15/1993 ■ 7,998.0 8.032.0 6,191.5 6,2172 Cement Squeeze 8/15/1993 i P0P,7,3:, 1 - Notes: General & Safety EdR Bid Cate rAC. EP, 8/15/1993 NOTE: Junk was cemented in hole annotation 9/1720(14 NOTE: TOG LEAK@ 7194' PIFFLE, 7,390 ��M 6202010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 I IG I 00 .0, 7, %3 OP EP F, 7 7c0-7,7;-"-- .4 Cement, 7,700 PPEP F. =. '''' ,A', IP EPf, • tae. 7.3 9-7,905 � - Cement, 7,3E • I 9 PEI !PEP',� � Cement 7,993 �� e i a•AI Lm EP. I Mandrel Details t drr 7,X14,146 Top Depth Port Top (TOD) Top OD LIton SImi TRO Run I 5th ME B1 ittP'.Bi 1001 i Meee Model (In) Sery 'verve TAB Tore fin (pd] Run Cate corn... 1 3,045.8 2,592.1 45.55 OTIS WBX I GAS LIFT GLV BK 0.156 1,345.0 0/292004 PPV VVGTAP, 35e�33� TO 03;176 2 4,127.4 3,374.7 43.06 MERIA TMPD 1 GAS LIFT DM? BK2 0.000 0.0 8!16!1993 3 4,990.4 3,997.6 43.$6 MAC... SPM-1A 1 GAS LIFT GLV BK 0.1$8 1,372.0 8292004 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 8, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1A-26 Run Date: 12/5/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -26 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22115-00 AMNED FEB ( ZU1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ;90 _ /Go 6 Anchorage, Alaska 99518 Office: 907 - 273 -3527 066;6 Fax: 907 - 273 -3535 klinton.woo ► iitoi ca Date: Signed: C , Msto -3a5 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 3, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~qo, 1~0~ ~-~ _ :~~~ ~at~(-~ tl ~ 2Q~~ ~,~~SS~on ~. ~-_:_ ~~ i~'.~1 ~~+3~~ ;. p~~L.: ii-: ~ r' . ~~. .~. l Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 1st & 2"d 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/03/10 A A A A A I D A A ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ~., .., Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ff al 1A-26 50029221150000 1901660 SF Na 12" Na 2.6 8/112010 1A-27 50029221240000 1901800 SF n/a 27" n/a 4.3 8/1/2010 1 D-03 50029204080000 1790840 17" n/a 17" n/a 1 8/2/2010 1 D-06 50029204180000 1790960 16" n/a 16" n/a 1.7 8/2/2010 1D-07 50029204300000 1791120 17" n/a 17" n/a 4.3 8/2/2010 1L-05 50029211550000 1841230 17" n/a 17" n/a 3.4 8/1/2010 1L-21 50029220439000 1910060 17" n/a 17" n/a 4.3 8/1/2010 1L-24 50029221700000 1910660 32" n/a 32" n/a 7.5 8/1/2010 ~~ °~~~', '" I~ ~Y~1~~~(i~fi~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~,~i Log Description >_ I ~-r , N0. 4861 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite f 00 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 1J-127 12096529 INJECTION PROFILE ~ - ~ ~- 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17!08 1 1 iJ-122 12066542 MEM INJECTION PROFILE J 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE fit{- (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE ~f - ~ (p 08/19/08 1 1 1J-105 12066543 MEM INJECTION PROFILE gip'}- I(p 08/19/08 1 1 2E-12 11996653 SBHP SURVEY 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -/ 08/22!08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-OS 12080422 INJ PROF/LDL ~ ~(- .rtp 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 2B-03A 11996656 PRODUCTION PROFILE ~ 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ p~- ~(p 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / =- ~ $Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '- O~ ~~~ 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~ - `aG 08/31/08 1 1 2E-14 12080432 SBHP SURVEY L(-- 08/31/08 1 1 1 B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 iH-18 11996666 INJECTION PROFILE - ~/ 09/03/08 1 1 9 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 1G-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • Œ 04/05/07 Sc~lUnlÞel'gep RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ 011 & Gas Cons. Commission Anchorage scANNED APR 1 () 1.007 tC¡O -lbG Field: Kuparuk Weill Log Description BL Date Color CD Job# 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-f2 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1 H-04 11632682 INJECTION PROFILE 03/30107 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02' 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331' N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t'6 . . ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing D Operat. ShutdownD Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 102' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Exploratory D Service D Other ""'. !~~~"j ~? ~5i~ ~(r. ~11 š \ Time 'EXtension Re-enter Suspended Well 5. Permit to Drill Number: 190-166 6. API Number: 50-029-22115-00 9. Well Name and Number: 1 A-26 10. Field/Pool(s): Kuparuk Oil Pool measured 8276' feet true vertical 6400' feet measured feet true vertical 6276' feet Length Size MD 80' 16" 80' 4531' 9-5/8" 4633' 8135' 7" 8237' 644' 5" 8145' Plugs (measured) Junk (measured) TVD Burst Collapse Measured depth: 7700-7725; 7978-7985; 7998-8032 SCANNED NO" J 5 2004 true vertical depth: 5964-5983; 6175-6180; 6190-6215 Tubing (size, grade, and measured depth) 3-1/2" ,J-55, 7564' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 7385' SSSV= SSSV SSSV= 1808' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFL NOV 1 I) 2004 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 942 406 0 61 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 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: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Contact Printed Name Signature Oil-Bbl 349 173 Casinq Pressure 870 960 Tubinq Pressure 164 155 WDSPLD Brad Gathman/MJ Loveland @ 659-7224 BrndG~hman TWe r-~ Phone Problem Wells Supervisor 907-659-7224 Date 11//;/0 '1 Form 10-404 Revised 04/2004 Submit Original Only ) ConocoPhillips Alaska, Inc. Kuparuk WelllA-26 (PTD 1901660) SUNDRY NOTICE 10-404 REPORT OF SUNDRY o~~WÄffd~~¡,::, . NOV I 2004 November 11, 2004 This Report Of Sundry Operations is a summary of completed well operations that repaired ConocoPhillips (CPA) Kuparuk WelllA-26 with a tubing patch. On November 5,2004, a retrievable 3-1/2", 23-foot patch was set in the tubing from 7183'-7206' MD (25.5-feet including packers). The patch was set to cover a leak at 7194' MD. The minimum ID on the patch is 1.75". A TIFL passed post patch. SCANNED, NO\! 1 5 2004 NSK Problem Well Supervisor k3..¡;;:...-""~- ¡ C r8i"c" u '-='\j - -,- II- ".,l=LL LOG TRANSMITTAL /râ-!tP{¿; ~ OCT 1 2 2004, ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S] REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH 1 Ä-26 9-20-04 Caliper Survey 1 Rpt or 2 Color Signed~ I ~a¿J Print Name: 1fJ;f!:r á/tVlt1áJU Date: If) I u> It) f SCANNI=O NnV 0 8 2004 PRoACTivE OiAGNOSTic SERVicES, INC., PO Box 1 lW'9"'5TÄ1foR(I"'U( 7'1417 . Phone:(28l) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com Schlumberger NO. 3213 Schlumberger -DCS 2525 Gam bell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 9(¿7 09/24/04 Com pany: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color ~'f -Ot{2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 =tS-OS' 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 1t{-e38 2B-12 10802934 INJECTION PROFILE 09/10/04 1 ~ tf- I b 4 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 '~l- ~5 1B-10 10922467 PRODUCTION PROFILE 09/21/04 1 () .,. "5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 rtf-Of. ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 ~'f - {( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 ~ f - J~ 1 H-19 10802940 INJECTION PROFILE 09/14/04 1 Î 2.- lf1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2 -Dfo 1A-14 10802938 INJECTION PROFILE 09/13/04 1 t '1~ 070 2H-03 10802945 INJECTION PROFILE 09/18/04 1 Iß?J-05" 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 '~~ olf'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H'2. _3H-09 10922468 INJECTION PROFILE 09/22/04 1 , ';l{,-/'II 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 ~9()- ,(,~1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~ ~ sl€~l.kl'~ sçANNEDNO\líl82004 DATE: /f~¿ Pléase sign and returLe copy of this transm ¡Ita I to Beth at the above address or fax to (907) 561.8317. Thank you. 1ft) - /(, ra Memory Multi-Finger Caliper log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLIPS (ALASKA) INC. September 20, 2004 5580 1 3.5" 9.3 lb. J-55 EUE 8RD Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 1A-26 Kupurak Alaska 50-029-22115-00 6,288 Ft. (MD) 7,464 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the 0 Nipple @ 7,399' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 61 % in Joint 241 @ 7,281'. 7 of the 39 joints logged have recorded wall penetrations in excess of 20% wall thickness. The damage recorded appears mostly in the form of Isolated Pitting. There are no areas of significant Cross Sectional Wan loss or 1.0. restrictions recorded throughout the interval of tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The joint numbering used in this report is an estimation based upon the average joint length. During logging operations, the tool appears to have hung up in GLM 8. The data analyzed is a composite of multiple runs: from 7,464' to GLM 8 and just above GLM 8 to 6,288'. MAXIMUM RECORDED WAll PENETRATIONS: Isolated Pitting ( 61%) Jt. 241 @ 7,281 Ft. (MD) Isolated Pitting ( 58%) Jt. 244 @ 7,444 Ft. (MD) Isolated Pitting ( 56%) Jt. 239 @ 7,245 Ft. (MD) Isolated Pitting (41%) Jt. 243 @ 7,420 Ft. (MD) Isolated Pitting ( 31%) Jt. 234 @ 7,077 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional wall loss (>10%) are recorded in the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded in the interval logged. I Field Engineer: W. McCrossan Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 <Ids. PDS Report Overview Body Region Analysis Well: Field: Company: Country: Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread J-55 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins September 20, 2004 MFC 24 No. 99628 1.69 24 J. Thompson 1A-26 KUPARUK CONOCOPHllLiPS USA Nom. Upset 3.5 ins Upper len. 1.2 ins lower len. 1.2 ins Penetration and Metal Loss (% wall) Damage Profile (% wall) - penetration body 40 - metal loss body - penetration body 0 209 - metal loss body 50 100 239 30 20 10 219 0 0 GlM3 Damage Configuration ( body) 229 30 10 GlM2 20 GlM 1 0 isolated pitting general line ring hole / poss corrosion corrosion corrosion ihle hole 0 Bottom of Survey = 244 Analysis Overview page 2 î u ,§. .l: ¡. 0.14 Q .. i£: Q. PDS Caliper Statistical Evaluation Report Well: Field: Company: Country: Survey Date: Tool: Tool Size: Tubing 1.0.: Tubing 0.0.: Wall Thickness: MFC 24 No. 99628 1.69 inches 2.992 inches 3.5 ìnches 0.254 inches lA-26 KUPARUK CONOCOPHILLIPS USA September 20, 2004 10 Percent Probability of Hole 20 50 100 0.24 " Standard Deviation '\. np"O .. .11 ,. '- of 0.018 - - - -- - '~- -- 1-- - - - - - - - - - '\. '\. . , I '... I I 'I. " , , 'I. " "" " "" " " " " " . -,' '-': "'::- 0.19 0.09 0.04 0.1 10 Average Rank Maximum Probable Penetration* 0.175 inches (69.1 % Walllbickness) Percent Probability of Recording a Hole* 23.1% . Oerived tram data with average rank value less rhan or equal to 20. 100 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf J-SS EUE 8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 A-26 KUPARUK CONOCOPHllliPS USA September 20, 2004 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % loss LD. Comments (%wall) (Ins.) (Ins.) (Yo (Ins.) 0 50 100 209 6288 () 0 0 0 0.00 210 6317 0 0.04 14 2 2.80 Buckled Tubing 211 6345 0 0.04 15 2 2.82 Shallow Ditting. Buckling. III 212 6377 0 0.03 13 10 2.84 Buckled Tubing 213 6406 0 0.03 12 7 2.81 Burklen Tuhing: 214 6437 0.0] 0.04 15 3 2.80 Isolated Pitting 215 6469 0 0.04 14 3 2.84 Buckled Tubing:. 216 6500 0.12 0.04 18 2 2.82 Shallow corrosion. Buckling:. . 217 6532 0 0.02 9 2 2.83 Buckled Tubing 218 6562 0 0.03 10 4 2.79 Buckled Tubing 219 6594 0 0.04 14 4 2.85 Shallow corrosion. Buckling. 220 6624 0 0.03 12 ] 2.82 Buckled Tubing 221 6656 0 0.04 14 2 2.82 Shallow pitting. Buckling. 222 6686 0 0.02 9 1 2.79 Buckled Tubing 223 6718 0 0.03 13 2 2.80 Shallow pitting. Buckling. .. 224 6748 () 0.04 16 4 2.78 Shallow nitting Buckling. .. 225 6777 0 0.02 9 ] 2.79 Buckled Tubing: .. 225.1 6804 0 0 0 0 N/A GlM 6 {latch @ 9:00\ 226 6811 0 0.04 17 2 2.87 Shallow Ditting. ,.. 227 6843 0 0.03 10 1 2.79 Buckled Tubing ,. 228 6875 0 0.03 13 1 2.79 Shallow Ditting. Buckling. III 229 6907 0 O.at 4 2 2.89 Buckled Tubing 230 6937 () 0.03 1 I 2 2.85 ,. 231 6970 0 0.04 14 2 2.85 Shallow nitting:. ,. 232 7001 0 0.03 12 1 2.84 Buckled Tubing: ,. 233 7031 0 0.04 15 4 2.84 Buckled Tubing .. 234 7064 0 0.08 31 1 2.85 Isolated Ditting. Buckling. . 235 7091 () 0.02 9 2 2.76 Buckling. .. 235.1 7120 0 0 0 0 N/A GlM 7 (latch @ 8:30) 236 7127 0 0.06 25 ] 2.82 Isolated Pitting Buckling. ... 237 7158 0 0.04 15 5 2.77 Shallow corrosion. Buckling. r 238 7191 0 0.07 27 1 2.82 Isolated Ditting. III. 239 7220 0 0.14 56 5 2.88 Isolated Ditting. Bucklin\!. 240 7250 0 0.03 13 1 2.82 Buckled Tubing '" 241 7280 0 0.16 61 2 2.89 Isolated Dittim!. 241.2 7322 0 0 0 0 N/A GlM 8 (latch @ 12:00) 241.3 Z3~'l - __0 0.03 10 1 2.88 eJJP Buckling. III . - ..-.- 242 7338 0 0.03 12 2 2.89 ,. 242.1 7365 0 0 0 0 3.00 PBR 242.2 7371 0 0.02 6 2 2.92 PUP ~ 242.3 7384 0 0 0 0 2.89 PACKER 242.4 7391 0 0.02 9 2 2.89 PUP ,. 242.5 7398 0 0 0 0 2.75 D NIPPLE 242.6 7401 0 0.05 19 2 2.92 PUP Shallow Ditting. 243 7412 0 0.11 41 2 2.90 Isolated nittin\!. It. Deposits. ... 244 7440 () 0.15 58 2 2.88 Isolated nitting:. I Penetration Body Metal loss Body Page 1 ~~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1A-26 KUPARUK CONOCOPHllllPS USA 3.5 ins 9..3 2pf J-55 EUE 8RD Survey Date: September 20, 2004 Tool Type: MFC 24 No. 99628 Tool Size: 1.69 No. of Fingers: 24 Analyst: J. Thompson Cross Section for Joint 241 at depth 7280.75 ft Tool speed", 58 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 46 0 Finger 12 Penetration = 0.156 ins Isolated Pit 0.16 ins = 61 % WalJ Penetration HIGH SIDE = UP Cross Sections page 1 <la.~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 11\-26 Survey Date: KUPARUK Tool Type: CONOCOPHILLIPS Tool Size: USA No. of Fingers: 3.5 ins 9.3 ppf J-55 EUE 8RD -____ðn<llyst: September 20, 2004 MFC 24 No. 99628 1.69 24 J. Thompson Cross Section for joint 244 at depth 7444.02 ft Tool speed = 58 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 470 Finger 13 Penetration = 0.148 ins Isolated Pit 0.15 ins = 58% Wall Penetration HIGH SIDE = UP Cross Sections page 2 . ConocoPhllllps Alaska, Inc. KRU 1 A-26 1A-26 API: 500292211500 Well Type: PROD Anale (â) TS: 41 dea (â) 7700 SSSV Type: TRDP Ori!:! Completion: 1/10/1991 An!:!le @ TD: 41 deg (â) 8276 sssv Annular Fluid: LastW/O: Rev Reason: TAGFILL,GLV (1808-1809. desi!:!n 00:4.000) Reference Loa: Ref Loa Date: Last Update: 8/31/2004 Last Taa: 8006 TD: 8276 ftKB Last Ta!:! Date: 8/27/2004 Max Hole An!:!le: 46 de!:! @ 5900 Gas lift CasinG StrinG - ALL STRINGS andrel/Valve Description Size Top Bottom TVD Wt Grade Thread 1 SUR. CASING 9.625 0 4633 3737 36.00 J-55 (3046-3047. PROD. CASING 7.000 0 8237 6371 26.00 J-55 CONDUCTOR 16.000 0 80 80 65.00 H-40 LINER 5.000 7501 8145 6301 18.00 N-80 Tublna StrinG - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 4.000 I 0 I 4928 I 3950 I 11.00 I J-55 I DSSHTC 3.500 I 4928 I 7564 I 5862 I 9.30 I J-55 I EUE 8RD Gas Lift Perforations Summary andreVValve Interval TVD Zone Status Ft SPF Date Type Comment 3 7700 - 7725 5964 - 5983 C-4 C 25 0 8/15/1993 Saz (4990-4991. 7978 - 7985 6175 - 6180 A-5 7 4 8/16/1993 RPERF 180 deg. Phasing; SWS 3 3/8" HSD on WO Ri!:! 7998 - 8032 6190-6215 A-4 34 4 8/16/1993 RPERF 180 deg. Phasing' SWS 3 3/8" HSD on WO Ria Stimulations & Treatments Interval Date Type Comment 7700 - 7725 8/15/1993 Cement Cemented in durina 1993 workover when Liner was in Gas Lift 7978 - 7985 8/15/1993 Cement Cemented in during 1993 workover when Liner was in andrel/Valve RE-PERFORA TED ON RIG AFTER WORKOVER ON 8/16/1993 5 7998 - 8032 8/15/1993 Cement Cemented in during 1993 workover when Liner was in (6235-6236. RE-PERFORATED ON RIG AFTER WORKOVER ON 8/16/1993 Gas Lift MandrelsNalyes St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Run Vly Cmnt 1 3046 2590 Otis WBX' GLV 1.0 BK 0.156 1345 8/29/2004 2 4127 3373 Merla TMPD DMY 1.0 BK2 0.000 0 8/16/1993 3 4990 3995 Macco SPM-1A' GLV 1.0 BK 0.188 1372 8/29/2004 4 5675 4483 Macco SPM-1A' DMY 1.0 BK 0.000 0 8/29/2004 5 6235 4881 Macco SPM-1A' GLV 1.0 BK 0.188 1360 8/29/2004 6 6798 5305 Macco SPM-1A' DMY 1.0 BK 0.000 0 8/29/2004 7 7120 5543 Macco SPM-1A' DMY 1.0 BK2 0.000 0 8/16/1993 8 7321 5686 Cameo MMG-2 OV 1.5 RK 0.188 0 8/29/2004 Gas lift Other II lUGs. e lUin.. etc.\. JEWELRY andreVValve Depth TVD Type DescriPtion ID 8 1808 1709 SSSV Cameo TRDP-4A-RO 3.313 (7321-7322. 7371 5722 PBR Baker 3.000 7385 5732 PKR Baker'HB' 2.891 7399 5742 NIP Cameo 'D' Nipple NO GO. 9/9/99 - set Dual Spartek Gauges on 2.79" bomb 2.750 PBR hanller 76" totallenllth. (7371-7372. 00:3.500) r----- 7563 5861 SOS Baker 2.992 7564 5862 TTL 2.992 General Notes Date INote PKR IJunk was cemented in hole (7385-7386. 00:6.156) NIP -=- (7399-7400. 00:3.500) TUBING _I (4928-7564. 00:3.500. 10:2.992) Cement I I (7700-7725) Perf (7978-7985) Perf (7998-8032) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE. NOVEMBER 2, 2000 E PL E W M A TE R IA L U N D E TH IS M ARK ER R C:LO~.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: ',Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 635' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2396' FSL, 2427' FWL, Sec. 7, T11N, R10E, UM At effective depth 2152' FSL, 2259' FWL, Sec. 7, T11N, R10E, UM At total depth 2086' FSL, 2215' FWL, Sec. 7, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8276 feet 6400 feet 6. Datum elevation (DF or KB) RKB 102 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-26 9. Permit number/approval number 90-166 10. APl number 5o-029-2211 5-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 81 5 3 true vertical 6307 feet feet Junk (measured) Junk cemented in hole between 8153' & 8276 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4602' 10-3/4" 8206' 644' measured 7700'-7725', true vertical 5964'-5983', Cemented 11 222 Sx AS II 1070 Sx AS III & 450 Sx Class G 300 Sx Class G 16 Bbls Class G 7978'-7985', 7998'-8032' 6175'-6180', 6190'-6215' Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4928', 3.5", 9.3#/ft., J-55 @ 4928'-7564 Packers and SSSV (type and measured depth) Packer: Baker HB @ 7385'; SSSV: Camco TRDP-4A-RO @ 1808' Measured depth True vertical depth 115' 115' 4633' 3713' 8237' 6371 ' 7501'-8145' 5815'-6301' 13. 14. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 10/24/96 ORIGINAL Intervals treated (measured) ' 7978'-7985', 7998'-8032' Treatment description including volumes used and final pressure Pumped 85.1 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 6200 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4 5 8 465 198 1045 198 Subsequent to operation 8 3 4 808 600 1056 283 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Form ,~4"'R(~'"'~157~ ~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate __ Plugging Perforate X Pull tubing X Alter casing Repair well Other __ 5. Type of Well: 6. Datum elevation (DF or KB) Development X ~t~ 102' RKB, 67' PAD GL fe 2. Name of Operator ARCO Alaska, I..nc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 4. Location of well at surface 635' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 2396' FSL, 2427' FWL, Sec. 7, T11N, R10E, UM At effective depth 2152' FSL, 2259' FWL, Sec. 7, T11N, R10E, UM At total depth 2086' FSL, 2215' FWL, Sec. 7, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8276' feet 6400' feet Exploratory Stratigraphic Service 7. Unit or Property name Kuparuk River Unit 8. Well number 1 A-26 9. Permit number/approval number 90-166(Conserv Order # 261) 10. APl number 50-029-22115 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured ' 8153' feet true vertical 6307' feet Junk (measured) Casing Length Size Cemented Structural 80' 16" 222 Sx AS II Conductor Surface 4602' 10-3/4" 1070 SX AS III & 450 SX Class G Measured depth True vertical depth 115' MD 115' TVD 4633 'MD 3713' TVD Intermediate Production 8206' 7" 300 SX Class G 8237' MD Liner 5" Scsb Liner 7501'-8145' MD 6371' TVD Perforation depth: measured 7978'-7985'. 7998'-8032' MD true vertical 6174'-6180', 6189'-6216' TVD Tubing (size, grade, and measured depth) 4" X 31/2", 11#/9.3#, J-55 @ 7564' MD Packers and SSSV (type and measured depth) Baker 'HB' Ret Pkr @ 7385' MD, Camco "TRDP-4A-RO" SSSV @ 1808' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) RECEIVED S E P 3 0 199, Oil ~. ~-oo r,,,.,. ,.,..,. V ~ V~,L~ I i Il I '~ ~IFI~I'4V V Il I Anchorage Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1"0-'404 Rev 05/17/89 Title Area Drilling Engineer D at es U ~B~iT~i/D~U~p LiCATE ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1A-26 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-029-22115 DAILY OPERATIONS PAGE: 1 ACCEPT: 01/01/91 06:01 SPUD: 01/01/91 11:01 RELEASE: 08/17/93 12:00 OPERATION: DRLG RIG: DOYON 14 WO/C RIG: NORDIC 1 01/02/91 ( 1) DOYON 14 TD: 831'( 831) 01/03/91 (2) DOYON 14 TD: 4226' (3395) 01/04/91 ( 3) DOYON 14 TD: 4665' ( 439) 01/05/91 ( 4) DOYON 14 TD: 6078' (1413) 01/06/91 (5) DOYON 14 TD: 7785' (1707) 01/07/91 (6) DOYON 14 TD: 8250'( 465) 01/08/91 ( 7) DOYON 14 TD: 8250'( o) DRILLING AT 831' 9-5/8"@ 4633' MW: 8.9 VIS: 67 MOVE RIG FROM 1A-25 TO 1A-26. ACCEPT RIG AT 18:30 HRS 1/1/91. NU DIVERTER, TEST SAME, SPUD AT 23:00 HRS 1/1/90. DRILL TO 831'. DRILLING AT 4226' 9-5/8"@ 4633' MW: 9.7 VIS: 51 DRILL FROM 831' TO 4226' = 3395' IN 17.9 ADT HRS. (197 FT/HR) RIG DOWN CEMENTERS 9-5/8"@ 4633' MW: 9.9 VIS: 42 DRILL TO 4665', SHORT TRIP TO HWT DRILL PIPE, HOLE TITE AT BASE OF PERMAFROST. CIRC CLEAN, POOH. RUN 111 JTS OF 9-5/8" J-55 36# BTC CASING TO 4633'. CIRC AND RIG UP DOWELL. CEMENT WITH: 80 BBL FRESH WATER SPACER, 1070 SX ASIII, 450 SX CLASS G AT 15.8 PPG. DISPLACE WITH 352 BBL MUD, BUMP PLUG, 12.1 PPG CEMENT RETURNS TO SURFACE, INJECT SPUD MUD INTO 1A-25. DRILLING AT 6078' 9-5/8"@ 4633' MW: 8.9 VIS: 38 RD DIVERTER, RU AND TEST BOPE. RIH WITH DBS BIT AND TURBINE, DRILL FLOAT COL- LAR AND TEST CASING TO 2500 PSI. DRILL FLOAT SHOE AND 10' OF NEw FORMATION, RUN FORMATION INTEGRITY TEST TO 12.7 PPG EMW. DRILL FROM 4665 TO 6078'. DRILLING AT 7785' 9-5/8"@ 4633' MW:10.9 VIS: 44 DRILL FROM 6078' TO 7450'. POH TO SHOE AND PERFORM FORMATION COMPETENCY TEST TO 11.6 PPG EMW. RBIH AND DRILL TO 7785 WITH DBS BIT AND TURBINE. POOH FOR LOGS 9-5/8"@ 4633' MW:10.9 VIS: 38 DRILL TO 7785', POOH FOR WASHOUT IN 21ST STAND. DRILL TO 8250' TD. CBU, SHORT TRIP, CIRC AND CONDITION FOR LOGS, POOH. RUNNING RFTS 9-5/8"@ 4633' MW:ll.0 VIS: 44 FINISH POOH. RU HLS, ATTEMPT TO LOG TRIPLE COMBO, HIT BRIDGE AT 5800', CHANGE TOOL CONFIGURATION BY ADDING KNUCKLE JOINT, STILL CAN'T GO BELOW 5800'. POOH WITH LOGGING TOOLS, RIH FOR WIPER TRIP, CIRC HOLE CLEAN, POOH. LOG WITH TRIPLE COMBO, SUCCESS. CHANGE TOOLS, RUN RFTS. .RECEIVED S E P 0 Alaska Oil & Gas Cons. Anchorage WELL': lA-26 API: 50-029-22115 -PERMIT: PAGE: 2 01/09/91 (8) DOYON 14 TD: 8276'( 26) 01/10/91 ( 9) DOYON 14 TD: 8276' ( o) 01/11/91 (10) DOYON 14 TD: 8276'( o) 06/01/91 (11) TD: 8276 PB: 8152 POOH LDDP 9-5/8"@ 4633' MW:ll.0 VIS: 42 RFT SURVEYS COMPLETED. RIH AND DRILL 26' TO 8276', CBU AND SPOT DIESEL PILL. POOH LDDP IN PREP TO RUN CASING. TEST TREE 7"@ 8237' MW:ll.0 VIS: 54 POOH LDDP. RUN 196 JTS 7" 26# J-55 BTC CASING. HIT BRIDGE AT 8190', CIRC CASING DOWN TO 8237'. CIRC AND CONDITION MUD FOR 2 HRS. PUMP 10 BBL PRE- WASH, 35 BBL ARCO SPACER, 57 BBL (300 SX) CLASS G AT 15.8 PPG W/ 2 GPS D-600 GAS BLOCK CEMENT. DISPLACE WITH 313 BBL 11.0 PPG BRINE. BUMP PLUG TO 3000 PSI, FLOATS HELD. RECIPROCATE PIPE 25' DURING LAST 50 BBL OF DISPLACEMENT HAD FULL RETURNS PRIOR TO RECIP, BUT LOST 41 BBLS OF MUD AFTER RECIP. ND BOPE SET SLIPS WITH 175K SLACKOFF WEIGHT. NU TREE AND TEST TO 3000 PSI. RR AT 07:00 1/10/91 7"@ 8237' MW: 0.0 VIS: 0 SKID RIG AND PREPARE TO MOVE TO 1A-28. RELEASE RIG AT 07:00 HRS 1/10/91. PERFORATING 7"@ 8237' MW:ll.0 NaCl/Br NU AND TEST BOP'S. ACCEPT RIG @ 1800 HRS 5-31-91. RU HLS AND MADE 3 PERF GUN RUNS. 06/02/91 (12) TD: 8276 PB: 8152 08/04/93 (13) TD: 0 PB: 0 RELEASED RIG 7"@ 8237' MW:ll.0 NaCl/Br RAN 4" X 3-1/2" COMPLETION ASS'Y. SET PKR @ 7492'. SHEAR PBR. TEST ANNULUS AND SSSV. OK. ND BOP AND NU TREE. FREEZE PROTECT AND RR @ 0130 HRS 6-2-91. 7"@ 8237' MW:12.5 NaCl/Br MOVE RIG F/lC PAD TO lA PAD. ACCEPT RIG @ 0900 HRS 08/03/93. LEVEL RIG. RU HARD LINE FOR KILL OPERATION. MU LUB & PULL VR PLUG. TAKE 12.5 PPG MUD INTO PITS. RUN MUD OVER THE SHAKERS, CIRC & COND MUD. ATTEMPT TO INJ DN TBG, PRESS UP W/MININAL INJ. CIRC WELL TO MUD HOLDING BACK PRESS. RU FLOOR TO PULL TBG. CONT CIRC UNTIL RETURNS ARE 12.5 PPG. SET BPV. ND 4" TREE. NU 7-1/16" STACK, FLOW RISER, CHOKE & KILL LINES. LOU GRIMADI WITH AOGCC INFORMED US THAT WE HAD TO HAVE A SET OF 4" RAMS OR VARIABLE RAMS. NONE AVAILABLE FOR THIS STACK. SET BPV. ND STACK. REMOVE FLOW LINE FROM NEXT WELL TO ALLOW FORKLIFT ACCESS. REMOVE TREE & 7-1/16" STACK. NU 7-1/16" 5K X 13-5/8" 5K DSA. NU 13-5/8" BOP. RECEIVED '~aska OU & t~as Cons. Commissll~, Anchorage WELL: API: -PERMIT: 1A-26 50-029-22115 PAGE: 3 08/05/93 (14) TD: 8276 PB: 8152 08/06/93 (15) TD: 8276 PB: 8152 08/07/93 (16) TD: 8278 PB: 8152 08/08/93 (17) TD: 8276 PB: 8152 POH W/3-1/2" TBG 7"@ 8237' MW:12.3 NaCl NU 13-5/8" BOP. MU KILL LINE & HYDRAULIC HOSES. RU FLOW RISER. LUBE MUD CROSS VALVE. FUNCTION MANUAL VALVES. FUNCTION TEST PIPE & BLIND RAMS, HCR, & ANNULAR. FLUSH VALVES. PULL BPV. SET TEST PLUG. TEST BOP. TEST WITNESSED BY LOU GRIMALDI W/AOGCC. PULL TEST PLUG. MU LANDING JT. BOLDS. PULL HGR TO FLOOR. CBU. CONT TO CIRC & COND THICK MUD. WELL STABLE. POH & LD 4" TBG & CHANGE SEAL RINGS. RECOVERED 20 SS BANDS. POH & STAND BACK 3-1/2" TBG. STRAP, DRIFT, & CHANGE SEAL RINGS. CIRC 12.8 PPG MUD 7"@ 8237' MW: 0.0 NaCl FIN POH W/TBG'. LOAD 3-1/2" DP IN PIPE SHED. RU FLOOR TO RIH W/DP. SET WEAR RING. MU BAKER RETRIEVING TOOL & RIH, PU DP. MU KELLY, LATCH ONTO PKR @ 7464'. ROTATE & RELEASE PKR. PKR APPEARED TO BE RELEASED BUT WOULD NOT MOVE. WORK PKR. COULD NOT CIRC. PRESS UP ON DP TO 1700 PSI & PKR MOVED. STILL COULD NOT CIRC, PKR ELEMENTS PACKING OFF. WORK PACKER THROUGH CSG COLLAR TO REMOVE ELEMENTS. HOLE SWABBING. COULD NOT CIRC. STAND BACK KELLY, & CONT WORKING PKR. FINALLY ABLE TO CIRC. CBU. DECIDED TO CIRC FULL WELLBORE VOLUME. CIRC OUT GAS CUT MUD. MONTITOR WELL, WELL FLOWING. WT UP MUD TO 12.8 PPG. - CIRC AROUND NEW MUD. DE-GAS MUD. RIH W/MILL 7"@ 8237' MW:12.8 NaCl/Br MONITOR WELL. WELL STABLE. PMP DRY JOB. POH SLOWLY TO AVOID PACKING OFF & SWABBING. RECOVER PKR & LD. BREAK OUT 3-1/2" TBG, CHANGE SEALS, DRIFT, & STAND BACK. LOAD BHA IN PIPE SHED & STRAP. MU 6.125" BIT. RIH. PU KELLY. TEST TO 3000 PSI. WASH F/7654'-7696'. HARD SPOT @ 7662'. HARD F/7696'-7726'. UNABLE TO DRILL PAST 7727'. CBU THROUGH THE CHOKE. LOTS OF GAS. CIRC OUT GAS. PMP DRY JOB. STAND BACK KELLY. POH W/DP. PU BAKER 6.125" MILL & RIH. POH 7"@ 8237' MW:12.8 NaCl/Br SERV RIG POOH W/3-1/2" DP PU KELLY TAG UP @ 7708' CORRECTED DEPTH. MILL TO 7713'. MAKING VERY LITTLE PROGRESS. PREP TO POH. CIRC & COND MUD. POH W/3-1/2" DP. LOAD 2-7/8" & MU 3-5/8" MILL. RIH W/2-7/8" DP. BREAK CIRC. CONT RIH W/3-1/2" DP. PU KELLY. BREAK CIRC. CHECK TORQUE F/2-7/8" DP. MILL ON TIGHT SPOT @ 7708' MILL TO 7725'. CANNOT SLACK OFF THROUGH TIGHT SPOT @ 7%08' BUT CAN ROTATE THROUGH IT. CBU. PMP DRY JOB. POH. RECEIVED SEP 0 199,t. AJaska Oil & Gas Cons. L;omrniss~ol'~ Anchorage WELL: API: ~ERMIT: 1A-26 50-029-22115 PAGE: 4 08/09/93 (18) TD: 8276 PB: 8152 08/10/93 (19) TD: 8276 PB: 8152 08/11/93 (20) TD: 8276 PB: 8152 MILLING @ 7999 7"@ 8237' MW:12.8 NaCl/Br SERV RIG. POH W/3-1/2" DP. POH & LD 2-7/8" DP. LOAD & EVAL MILLS. MU 3-5/8" MILL & TAPERED STRING MILL.. RIH W/3-1/8" DC & 3-1/2" DP. PU KELLY & TAGGED UP @ 7708'. MILL F/7708'-7711'. TIGHT SPOT AT THIS INTERVAL CLEARED UP. BEGAN WASHING THROUGH INTERMITTENT FILL BELOW. TAGGED UP ON SOMETHING HARD @ 7999'. TORQUE CAME UP, COULD NOT WORK THROUGH EASILY. CBU. PMP DRY JOB. POH. STAND BACK 3-1/8" DC. EVALUATE MILLS. THE 3-5/8" MILL HAD ABOUT 1" GONE OFF IT, THE STRING MILL WAS WORN BUT NOT SEVERELY. RD 3-1/8" DC EQUIP. MU NEW 5-5/8" JUNK MILL & STRING MILL. RIH W/3-1/2" DP. BREAK CIRC. BEGIN MILLING @ 7999'. MILLING THROUGH TIGHT CSG 7"@ 8237' MW:12.8 NaCl/Br MILL THROUGH TIGHT AREA TO 7737'. COULD MAKE HOLE BUT SLOWLY. DECIDED TO PU ASSY THAT WOULD BE BETTER @ CLEANING FILL. PMP DRY JOB. POOH. MU STC 6.125" ECONOMILL & BOOT BASKETS. RIH. PU KELLY & BREAK CIRC. MILL & WORK THROUGH TIGHT SPOT @ 7708' TO 7721'. CAN ROTATE THROUGH BUT CAN'T SLACK OFF & GET THROUGHT IT, CAN'T MAKE A CONNECTION. PMP DRY JOB. POH. THE 6.125" ECONOMILL HAD DAMAGE ON ALL BUT ONE FIN. THE LARGEST PIECE MISSING WAS ABOUT 1" SQUARE. WAIT ON MILL. PU BAKER 5-3/4" FLAT BTM BLADED JUNK MILL. RIH. PU KELLY & BREAK CIRC. WORK THROUGH TIGHT SPOT @ 7708' TO 7721'. EVENTUALLY ABLE TO SLACK OFF THROUGH THIS INTERVAL. BEGIN RIH TO CHECK REMAINDER OF CSG & TO BEGIN CLEANING HARD SPOT @ 7999'. REAMING THROUGH TIGHT SPOT 7"@ 8237' MW:12.8 NaC1/Br MILL 7736'-7753' ROP DROPPED TO 0 FPH. PMP DRY JOB. BLOW DN & S/B KELLY. POH W/5-3/4" MILL. LD 5-3/4" MILLING ASSY, MU 3-5/8" X 4-3/4" X 6" ASSY. RIH. TAG UP W/6" STRING MILL @ 7710'. MILL TIGHT CSG 7710'-7713' RIH TO 7944' TO ENSURE BEING PAST COLLAPSED CSG. PMP D~Y JOB. BLOW DOWN & S/B KELLY. LD 7 JTS DP. POOH W/3-5/8" X 4-3/4" X 6" MILLING ASSY. BREAK & LD BHA. STRAP, PU & MU DRILLING BHA. RIH TO 7730'. BIT BEGAN TO TAKE WT. MU KELLY & REAM THROUGH TIGHT SPOT(7752'). RECEIV[D S E P ,:t 0 199,t Alaska Oil & Gas Cons. (;ommiss~o~ Anchorage WELL: API: -PERMIT: 1A-26 50-029-22115 PAGE: 5 08/12/93 (21) TD: 8276 PB: 8148 08/13/93 (22) TD: 8276 PB: 8148 08/14/93 (23) TD: 8276 PB: 8098 08/15/93 (24) TD: 8276 PB: 8092 WAITING ON 5" LINER 7"@ 8237' MW:12.8 NaCl/Br REAM THROUGH TIGHT SPOT 7052'-7080'. CONT RIH W/SINGLES. TAG UP @ 7995'. WASH & REAM & FISH TO FC @ 8153' DRILL ON FC. COULD NOT GET PAST 8154'. CIRC HOLE CLEA~. PMP DRY JOB, BLOW DN & S/B KELLY. POH. DRIFT DP ON WAY OUT OF HOLE IN PREP F/LINER CMT JOB. LEFT BIT & 2 JB IN HOLE. TOTAL LENGTH OF FISH=6.12'. NEW PBTD IS 8148'. PERFORM BOPE TEST. TEST WITNESS WAIVED BY AOGCC'S JERRY HERRING. WAIT FOR 5" LINER, LINER JEWELRY & LINER RUNNING TOOLS. MEANWHILE, BRING IN COMP JEWELRY & STRAP, BRING IN BAKER LINER HGR & STRAP. RU CSG FILL-UP LINE, PERFORM RIG MAINTENANCE. RIH W/5" LINER ON DP 7"@ 8237' MW:12.8 NaCl/Br SERV RIG. LOAD, PU & MU BHA & RIH. RIGHT @ 7710'. LD SINGLE & PU KELLY. REAM TIGHT SPOT @ 7710' W/6" STRING MILL. REAM & CIRC SINGLES TO 8147'. TAG FISH. PMP SLUG, BLOW DOWN & SB KELLY. DROP 2" DRIFT & POH. LD 9 SINGES & BHA. RU TO RIH W/5" LINER. LOAD & STRAP PIPE. MU FLOAT SHOE & INSERT-TYPE FC & LANDING COLLAR ON 5",18#, N-80, FL4S PIPE. DRIFT PIPE & RIH. MU BAKER LINER HGR & SETTING SLEEVE ON JT #16. RU CIRC VALVE & HOSE. FILL LINER & CIRC. SLIP & CUT 50' OF DRILLING LINE. RD CIRC VALVE & HOSE. RIH W/5" LINER ON DP. POH W/7" CSG SCRAPER 7"@ 8237' MW:12.8 NaCl/Br CONT RIH W/5" LINER ON DP. CBU. PRESS TEST CMT LINES TO 5000 PSI. PMP 20 BBLS ARCO SPACER @ 13.8 PPG FOLLOWED BY 16 ,BBLS CLASS G CMT. DISPLACED W/MUD. BMP PLUG & CHECK FLOATS. CIP @ 1015 HRS 08/13/93. POH 3-1/2 STDS & PMP SLUG. FLUSH & RD CMT LINES & CLEAR FLOOR. POH. MU C/O BHA. RIH W/6.125" BIT & 7" SCAPER. WOC. RIH. TAG CMT @ 7421'. DRILL CMT TO TOP OF LINER. C & C MUD TO CLEAN UP HOLE WHILE ROTATING & RECIP DP. MIX & PMP SLUG. BLOW DN & S/B KELLY. POH. POH, LD DP 7"@ 8237' MW:12.8 NaCl/Br CONT POH. LD 4-3/4" DC'S, 7" CSG SCRAPER, & 6.125" BIT. MU LINER C/O BHA & RIH. TAG LINER TOP @ 7501'. MU KELLY & BREAK CIRC. DRILL FIRM CMT F/7501'-7545'. CIRC OUT THICK MUD. TAG PBTD @ 8092'. CIRC & COND MUD UNTIL RETURNS CLEAN & MUD PROPERTIES AS DESIRED. TEST LINER LAP TO 1500 PSI-OK. PMP SLUG. LD KELLY. POH. WELL: API: -PERMIT: 1A-26 50-029-22115 PAGE: 6 08/16/93 (25) TD: 8276 PB: 8092 LAND OUT TBG 7"@ 8237' MW:12.8 NaCl/Br CONT POH. LD DP & BHA. RU SCHLUMBERGER, TEST LUB. RIH. PERF F/8012'-8032' @ 4 SPF, 180 DEG PHASING W/3-3/8" HSD. POH. ASF. RD GUN #1, PU GUN #2. RIH, ORIENT & PERF F/7978'-7985' PULL UP. ORIENT & PERF F/7998'-8012' -- POH. ASF. SWS, CLEAR FLOOR, au TO RUN TBG. RUN 3-1/2" X 4" COMPLETION. STEAM CLEAN ALL 4" TBG. 08/17/93 (26) TD: 8276 PB: 8092 RIG RELEASED 7"@ 8237' MW:12.8 NaCl/Br MU TBG HGR. MU & TEST SSSV CONTROL LINE. LAND HGR IN WELLHEAD. RILDS. PRESS TBG TO 2500 PSI & ANN TO 1000 PSI TO SET PKR. BOLDS. PU & SHEAR PBR W/ll4K LBS. RE-LAND TBG. RILDS. TEST SSSV W/1000 PSI ON BTM, 500 PSI ON TOP. TEST ANN & TBG W/2500 PSI ON BOTH. INCREASE TBG PRESS TO 3000 PSI-SHEAR-OUT SUB SHEARED AFTER 15 MIN. SET BPV. ND 13-5/8" BOP STACK. NU TREE. PULL BPV, INSTALL TEST PLUG. TEST TREE TO 5000 PSI. PMP SW DN ANN, TAKING RETURNS FROM TBG VIA CV @ 7325' REPLACE POP-OFF RUBBER ON PMP. DISPLACE WELL TO S~. CLEAN PITS WHILE DISPLACING. DISPLACE WELL TO DIESEL. CV HOLDING. RD LANDING JT W/CIRC HEAD. SECURE WELL. RELEASED RIG @ 2400 HRS 08/16/93. SIGNATURE: (drill~~ou~~nt) DATE: RECEIVE£ SEP 0 199,] & 6as C;ons. (,urnrnis~u,~ Anchorage MEMORANDUM $ TA TE Ol A LA ALAS~ OIL AND GAS CONSER VA TION COMMISSION TO: David Joh~ Chairma~ DA TE: August 4 1993 FILE NO.: AAUJHDAB.DOC THRU: Blair Wondzell P.I. Supervisor FROM: ~ou Grimaldi Petroleum Inspector PHONE NO.' 279-1433 SUBJECT: BOP test Nordic rig #1 Arco well #1A-26 Kuparuk River Field PTD# 90-166 Tuesday August 3 1993 i traveled to Arco's lA pad in the Kuparuk river field to witness the initial BOP test on Nordic rig #1 which was preparing to perform a workover on well # 1A-26. When I arrived/the rig crew had just finished rigging up the BOP stack. I was informed that the BOP stack did not have the proper sized rams to accommodate the tubing that was to be pulled from the well. As there were no properly sized rams available, the stack was rigged down and a different stack brought over that had variable rams installed. This was rigged up and we tested the following day. Wednesday August 4 1993 When I returned this day the crew was ready to test the replacement stack. The test went well with two failures observed, these being the check valve that isolates the choke line from the mud manifold and the gas detectors which would indicate a Iow alarm but failed to register the high alarm. The check valve was repaired and retested before I left and the gas detectors will be calibrated when their electrician comes on tour. The accumulator., although functioning adequately, was slow on it's recharge time and Lance Johnson (Nordic toolpusher) will attempt to shorten this time. SUMMARY; I witnessed the initial BOP test on Nordic rig #1 with two failures observed. Attachment · AAUJHDAB.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nordic Rig No. ONE PTD # Operator: Arco Rep.: Well Name: 1A-26 Rig Rep.: Casing Size: Set @ Location: Sec. Test: Initial X Weekly Other DATE: 8/4/93 90-166 Rig Ph.# 659-7115 Karla Lenz Lance Johnson 5 T. 1 1N R. IOE Meridian Umiat Test MISC. INSPECTIONS: Quan. Pressure P/F Location Gen.: OK Well Sign OK I 300~3000 P Housekeeping: FAIR (Gen) Drl. Rig FAIR I 300~3000 P Reserve Pit N/A 2 300/3000 P I 300/3000 P BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F Test I 300/2500 P Pressure 12 300/3000 I 300/3000 P N/A N/A N/A 1 300/3000 P 1 300/3000 P I 300/3000 P 2 300/3000 P I N/A F MUD SYSTEM: Visual Alarm Trip Tank X NrA Pit Level Indicators X NrA Flow Indicator X NrA Gas Detectors X F #2 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes P/F P 33 300/3000 P 1 P FUNCTION FUNCTION ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: TWO BOTTLES 3,000 P 1,550 P minutes 45 sec. minutes 8 sec. X Remote: X 2450 Psig. Number of Failures: 2 ,Test Time: 4 1/2 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Check valve failed. Gas detectors would not signal high gas alarm. Accumulator time too slow Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO YES 24 HOUR NOTICE GIVEN X NO Waived By: Witnessed By: FI-021L (Rev. 2/93) AAUJHDAB.XLS ..~-'~--~, STATE OF ALASKA A! .A OIL AND GAS CONSERVATION C~, ,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~'~ GAS [--"] SUSPENDED r--] ABANDONED r'~ SERVICE r--'] 2 Name of operator 7 Permit Number ARCO Alaska, Inc 90-166 3 Address 8 APl Numbe~ P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22115 4 Location of well et surface F-~_~~ ~~ 9 Unit or Lease Name 635' FSL, 310' FWL, SEC 5, T11N, R10E, UM~ ~.'0~ !~.~~~! KUPARUK RIVER At Total Depth 11 Field and Pool 2086' FSL, 2215' FWL, SEC 7, T11N, R10E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. KUPARUK RIVER OIL POOL RKB 102', PAD 67' ADL 25647 ALK 465 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 1/1/91. 1/8/91. 6/2/91.I NA feet MSLI 1 17 Total Depth (MD+'rVD) 18 Plug Back Depth (MD+TVD) 19 DireclJonal Survey 120 Depth where SSSV set 21 Thickness of permafrost 8276' MD, 6400' TVD 8153' MD, 6307' TVD YES [~ NO r-] 1816, feat MD 1500' APPROX 22 Type Electric or Other Logs Run D IL/SFL/ML/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 222 SX AS I 9-5/8" 36~ - J-55 SURF 4633' 12-1/4" 1070 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 8236' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI 3ACKER SET (MDI ... 4', 3-1/2' 7605' 7492' 7978'-7985' W/4-1/2" CSG GUN 6174'-6180' TVD 7998'-8032" W/4-1/2" CSG GUN 6189'-6216' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMelhod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE =~ 28 CORE DATA ~ '~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. :- . .... ~ _ Form 10-407 Submit in duplicate Rev. 7-1-80 ~ED ON REVERSE SIDE GEOLOGIC IVlN:IKERS FORMATION TESTS ~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and l~me of each phase. KUPARUK C TOP 7700' 5964' NA KUPARUK C Bo'FrOM 7840' 6070' KUPARUK A TOP 7967' 6166' KUPARUK A Bo'I'TOM 8098' i6265' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ , . Title AREA DRILLING .F_NGINEER 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 ARCO ALASKA INC. DAILY OPERATIONS WELL: 1A-26 BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER UNIT ADL 25647 ALK 465 50-029-22115 90-166 AK5563 55.252072 SPUD: 01/01/91 RELEASE:01/10/91 OPERATION: DRILLING RIG: DOYON 14 PAGE: 1 01/02/91 (1) TD: 831' ( 831) SUPV: PDW 01/03/91 (2) TD: 4226'(3395) SUPV:PDW 01/04/91 (3) TD: 4665' ( 439) SUPV:PDW 01/05/91 ( 4) TD: 6078'(1413) SUPV:PDW 01/06/91 (5) TD: 7785'(1707) SUPV:PDW 01/07/91 (6) TD: 8250'( 465) SUPV:PDW 01/08/91 (7) TD: 8250'( SUPV:PDW o) DRILLING AT 831' 9-5/8"@ 4633' MW: 8.9 VIS: 67 MOVE RIG FROM 1A-25 TO 1A-26. ACCEPT RIG AT 18:30 HRS 1/1/91. NU DIVERTER, TEST SAME, SPUD AT 23:00 HRS 1/1/90. DRILL TO 831' · DAILY:S54,338 CUM:$54,338 ETD:S54,338 EFC:$1,770,000 DRILLING AT 4226' 9-5/8"@ 4633' MW: 9.7 VIS: 51 DRILL FROM 831' TO 4226' = 3395' IN 17.9 ADT HRS. (197 FT/HR) DAILY:S65,294 CUM:$119,632 ETD:S119,682 EFC:$1,770,000 RIG DOWN CEMENTERS 9-5/8"@ 4633' MW: 9.9 VIS: 42 DRILL TO 4665', SHORT TRIP TO HWT DRILL PIPE, HOLE TITE AT BASE OF PERMAFROST. CIRC CLEAN, POOH. RUN 111 JTS OF 9-5/8" J-55 36# BTC CASING TO 4633' CIRC AND RIG UP DOWELL. CEMENT WITH: 80 BBL FRESH WA~ER SPACER, 1070 SX ASIII, 450 SX CLASS G AT 15.8 PPG. DISPLACE WITH 352 BBL MUD, BUMP PLUG, 12.1 PPG CEMENT RETURNS TO 'SURFACE, INJECT SPUD MUD INTO 1A-25. DAILY:S134,707 CUM:$254,339 ETD:S254,339 EFC:$1,770.000 DRILLING AT 6078' 9-5/8"@ 4633' MW: 8.9 VIS: 38 RD DIVERTER, RU AND TEST BOPE. RIH WITH DBS BIT AND TURBINE DRILL FLOAT COL- LAR AND TEST CASING TO 2500 PSI. DRILL FLOAT SHOE AND 10' OF NEW FORMATION, RUN FORMATION INTEGRITY TEST TO 12.7 PPG EMW. DRILL FROM 4665 TO 6078' o DAILY:S117,410 CUM:$371,749 ETD:S371,749 EFC:$1,770,000 DRILLING AT 7785' 9-5/8"@ 4633' MW:10.9 VIS: 44 DRILL FROM 6078' TO 7450'. POH TO SHOE AND PERFORM FORMATION COMPETENCY TEST TO 11.6 PPG EMW. RBIH AND DRILL TO 7785 WITH DBS BIT AND TURBINE. DAILY:S90,596 CUM:$462,345 ETD:S462,345 EFC:$1,770,000 POOH FOR LOGS 9-5/8"@ 4633' MW:10.9 VIS: 38 DRILL TO 7785', POOH FOR WASHOUT IN 21ST STAND. DRILL TO 8250' TD. CBU, SHORT TRIP, CIRC 'AND CONDITION FOR LOGS, POOH. DAILY:S55,983 CUM:$518,328 ETD:S518,328 EFC:$1,770,000 · RUNNING RFTS 9-5/8"@ 4633' MW:ll.0 VIS: 44 FINISH POOH. RU HLS, ATTEMPT TO LOG TRIPLE COMBO, HIT BRIDGE AT 5800' CHANGE TOOL CONFIGURATION BY ADDING KNUCKLE , JOINT, STILL CAN'T GO BELOW 5800'. POOH WITH LOGGING TOOLS, RIH FOR WIPER TRIP, CIRC HOLE CLEAN, POOH. LOG WITH TRIPLE COMBO, SUCCESS. CHANGE TOOLS, RUN RFTS. DAILY:S51,063 CUM:$569,391 ETD:S569,391 EFC:$1,770,000 WELL: 1A-26 OPERATION: DRILLING RIG: DOYON 14 PAGE: 01/09/91 (8) TD: 8276' ( 26) SUPV:PDW 01/10/91 (9) TD: 8276' ( SUPV: JMM 0) 01/11/91 (10) TD: 8276'( SUPV:JMM o) POOH LDDP 9-5/8"@ 4633' MW:ll.0 VIS: 42 RFT SURVEYS COMPLETED. RIH AND DRILL 26' TO 8276', CBU AND SPOT DIESEL PILL. POOH LDDP IN PREP TO RUN CASING. DAILY:S140,055 CUM:$709,446 ETD:S709,446 EFC:$1,770,000 TEST TREE 7"@ 8237' MW:ll.0 VIS: 0 POOH LDDP. RUN 196 JTS 7" 26# J-55 BTC CASING. HIT BRIDGE AT 8190', CIRC CASING DOWN TO 8237' CIRC AND CONDITION MUD FOR 2 HRS. PUMP 10 BBL PRE- WASH, ~5 BBL ARCO SPACER, 57 BBL (300 SX) CLASS G AT 15.8 PPG W/ 2 GPS D-600 GAS BLOCK CEMENT. DISPLACE WITH 313 BBL 11.0 PPG BRINE. BUMP PLUG TO 3000 PSI, FLOATS HELD. RECIPROCATE PIPE 25' DURING LAST 50 BBL OF DISPLACEMENT HAD FULL RETURNS PRIOR TO RECIP, BUT LOST 41 BBLS OF MUD AFTER RECIP. ND BOPE SET SLIPS WITH 175K SLACKOFF WEIGHT. NU TREE AND TEST TO 3000 PSI. DAILY:S117,745 CUM:$827,191 ETD:S827,191 EFC:$1,770,000 RR AT 07:00 1/10/91 7"@ 8237' MW: 0.0 VIS: 0 SKID RIG AND PREPARE TO MOVE TO 1A-28. RELEASE RIG AT 07:00 ~RS 1/10/91. DAILY:S168,753 CUM:$995,944 ETD:S995,944 EFC:$1,770,000 DATE: ARCO ALASKA INC. DAILY OPERATIONS WELL: 1A-26 BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER UNIT ADL 25647 ALK 465 50-029-22115 90-166 AK5563 55.252072 ACCEPT: 05/31/91 RELEASE: 06/02/91 OPERATION: COMPLETION RIG: NORDIC PAGE: 1 06/01/91 (11) TD: 8276 PB: 8152 SUPV:GB 06/02/91 (12) TD: 8276 PB: 8152 SUPV:\B NORDIC 1 PERFORATING 7"@ 8237' MW:ll.0 NaCl/Br Nil AND TEST BOP'S. ACCEPT RIG @ 1800 HRS 5-31-91. RU HLS AND MADE 3 PERF GUN RUNS. DAILY: $28,073 CUM:$1,024,017 ETD:S1,024,017 EFC:$1,770,00 RELEASED RIG 7"@ 8237' MW:ll.0 NaCl/Br RAN 4" X 3-1/2" COMPLETION ASS'Y. SET PKR @ 7492'. SHEAR PBR. TEST ANNULUS AND SSSV. OK. ND BOP AND Nil TREE. FREEZE PROTECT AND RR @ 0130 HRS. 6-2-91. DAILY:S253,547 CUM:$1,277,564 ETD:S1,277,564 EFC:$1,770,000 DATE: DS 1H 171., o 2 6 o · 2~C 7 ~ 26J NOTES: 18 VlCINI'r~ MAP 1. BASIS OF LOCATION AND ELEVATION IS D.S. MONUMENTATION PER LOUNSBURY & ASSOCIATES. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 3. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 4. LOCATED WITHIN PROTRACTED SECTION 5, T 11 N, R 10 E, UMIA T MERIDIAN, ALASKA. NO. Y X LAT. LONG. F.S.L. F. W.L. O.G. PAD 17L 5971370.96 540180.24 . 70' 19'57. 794" 149' 40'26.634" 1283' 315' 59.6' 18A 5971251.02 540180.20 70' 19'56.614" 149' 40'26.654" 7163' 314' 61.0' 79H 5971203.06 540180.24 70'19'56.143" 149'40'26.660" 1115' 314' 61.7' 20M 5971179.05 540180.77 70'19'55.906" 149'40'26.666" 1091' 314.' 62.0' 21C 5971155.00 540180.25 70' 19'55.670" 149' 40"26.667" 1067' .314' 62.4' 22B 59711.30.99 540180.19 70'19'55.¥54" 149' 40'26.675" 104.7' 515' 62.8' 251 59 71011.10 540180.26 70' 19'54.255" 149" 40'26. 689" 923' 512' 65. $' 24F 5970915.06 540780.25 70' 19'53.310" 749' 40'26. 705" 827' 311' 64. O' 25C 5970819.08 540180.28 70' 19'52.366" 749' 40'26. 719" 731' 511' 65.3' 26J 5970723.13 540180.21 70" 19'51.422" 149' 40'26. 736" 635' 310' 62. 7' 27E 5970699.09 540180.20 70 ° 19'51.186" 149' 40'26. 740" 611' 310' 62.5' 28D 5970675.10 540180.27 70'19'50.9,,~:~,'~~. "~.0'26.742' 587' 309' 62.4' 67.2' ~.~.~..o-- °...,~_~,, ARCO ALASKA, INC. DWG# "Y' ** ** ~::~,,~& NSDK-1AOO-CEA-D1AX-6101D10 ARCO Alaska,Inc. , · 49'-" SURVEYOR S C£RTIFICA TE ,..........'......... REGISTERED AND LICENSED TO PRACTICE "~ ~,~ ALAI~'J. ROOKUS ~ ~. · LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A ~'~'**.. ' .*** SURVEY DONE BY ME OR UNDER MY DIRECT SUPERP1SION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 2,:7, 1990. 10/30/90 Chonge F.N.L. fo F.S.L. Dete 67.0' 66.5' 66.$' 67.0' 66.9' 67.0' 66. J' 66.7' 67.0' 67.2' 67.,3' Descril~tion DRILL SITE 1-A WELL CONDUCTORS #I7-t/28 S- UfL T LOUNSBURY & ASSOC. 5URI~'~RS Dr. DCS Chk: A,/.; REV. / Dote: 10/26/901Dwg: NSK 6.10Td~O ORIGINAL A Gy~data Dir~ctiona! Supv~y ,',~,rn ALASKA NORTH SLOPE 9QROUGH, .''~ "~'"a Date Run: 20-JAN-91 i0:07:20 Survey Latitude: 70de9 !gal,..-, 58sec N Bearings are Relative to YRUE NORYH F'roocsed i,~. ~, · :-=.~.t ui.,"ec~ion: S ]~,4e,-; 4?m~n 56sec W Closure Cab:u:ated fro:'.~ Well Hemal Location KUPARUK RIVER UNIT, NELL ~ iA-28 NORTH SLOPE BOROUGH, ALASKA Job NumbEr: AKOI916207 MEAS iNCL BORE HOLE DEPTH BEARING ft dmg min deg .,", 0 0 .~: 0 0 E !00., 0 0 9 200,0 0 12 300,0 0 i4 400,, 0 9 18 ~"¢'" "'" 2 41 600,0 4 28 ~.'¢¥'i f5 .~ 7 900,0 ltl, 6 100010 i8 i i 00, 0 .... 12 !200.. 0 20 i6 !300,0 22 55 N i0 57 W N 44 37 W S 7- ~:, S525! S 4859 S 48 2(:" S47 OW S 45 47 !500,0 26 i5 S 46 54 14 ~'"r, "" .-r.~ 4-8 S 46 5 W 1700,0 3.3 i4 S -'45 .59 ~ ._ ~ ~:, 23 ~.~°'"':':,v,,-, 0.. 43 i9 S 40 5 N 2000.0 45 43 S 57 3 W 21F::O,n 45 ~i S ~'''' .14 ~ ?~nn 0 45 5i S ~" 27 Fi A Gyrodata Di rec t i ona i Survey SUB-SEA nn~-: ~ VERT ............. b~gSURE n-~,, DEPTH ~r :~ q~U~PTTV DISTANCE BEARING *~,, deo/tO0' ft .0 : OC,. , O: , 0 · SYRODATA ..... ~:=v RUN TN 7" CASING -rn 8i42' ~ n ALL SURVEY COORDINATES REFERENCED TO ORIGINAL i00,0 ,15 !O,'J,O -.i ,i N ! 55 N 200, c,, ,06 2c~0,.. 0 -..T ,4 N ,.,= ,.,:~"' W .... '" -~ ,B N i5=~ 300, 0 ,, i,:. ..:,o:.;, 0 , ¢ .~.~ mw.~ c: ,26 400,0 - 5 I I N ............ ~ 29 W 797,4 = ~ 797,4 X7; Sa'~ ~-~0 i8 W 894,0 2,61 894,0 62, 5 65,7 S 48 45 W 9~e 6 ~.e? 989,8 ~!:A 97,0 q 47 46 W i':'~8~ 4. , i. ~ ~ i084.4 123~! ~24, 9 S 47 22 .;a ~i78,5 i !0 ~7o ~ 156,4 158.6 S 47 19 W 1454.~ '~ ~-' ~""-= ..... 277,0 q 47 ?-~ W .-5 ~A , :' = 325.= e 47 17 W !541.5 .... 154i,: 32i.0 : ~, . i0,'.%5 4.45 1624,~ 576,5 581.4 S ,47 5 W ~7P'-.' 8 ~ 9? I7...']? cc 4TM .~,,; ~ ...:," -'""-' '" 4,'. i.,'~ 1777, 3 504. ,, 3 509, 8 ,.,q 46 .,'~ I W ~o~o ~ - ~' 1848,6 57" ~. 5~o.4 S ~'= I~ W ..... = : ~ 1918.6 645, 8 '9= ' 7~ 45 47 W 2058-7 i6 ?n~a ? ~?~ e ~,', ?~?~ o 8~e 7 865 3 ~ ~2 ~ W H 0 R I : 0 N T,~ L C rj 0 F:D feet ,0 N ,0 E , I ?] ,0 ,A ,4 N ,0 g; ,9 N ,6 kJ ,6 S 2,7 N 24,4 S 29,4 W 42.0 S ¢7.9 W i87.7 S 204,, 220, 8 S 239,, 259, 7 S 279.- 505.6 S 407,8 S 41:,5 ~'4 464,.5 S 455, 0 ;U :?'"' 7 S 40"': c:, W ~_.~.,.~ ~ . .,'7~ ,., 57a, 5 S 54.T:, 5 ~J ~32. ! S 588.(: W ARCO ALASKA um~xu~,.. F:ZVER UNIT, [,ELL ~ iA-z~ Job Number: AKO'iglG207 A ~q data uyPo Directional !lEAS iNCL BORE HOLE DEPTH BEARING ~t ~, min d=~, ~ 2500.0 44 42 S 39 45 W 2600,0 44 ';: q 40 4 W 2700.0 43 50 S 4i 38 W 2800.0 ~'5 i2 S 42 23 W 3000,0 45 i6 S 42 .38 W 3i00.0 44 53 S 43 28 W XXO0 n ~i ~ S 43 == W 3400.0 44 ! S 41 39 ~ 3500.0 4~ 29 S 41 40 W 3600.0 .42 50 S 42 37 W 380,:)=0 41 56 S 44 24 W 4i00.0 44 25 S 40 2W 4200.0 43 54 S 40 8 W 4ano n 44 ~n S 35 43 W .4600,0 4.3 48 S 36 i9 !4 4700.0 43 28 S 36 7 W ~90n n 43 45 S 36 '~ ~ W SUB-SEA DOS-LEG ft de9/!O0' ~.~ o~ ~ 93 2342~ 7 !~ 19 2827.9 ,72 2699,1 .67 2770, 8 ,26 2842, 7 58 29!4.9 ,54 2987.9 ,92 w~A~.~ I. 02 3i 35= 9 . oz~' 3209, 3 z. ~, 3281.5 .80 ~ ~ ~ 96 :,*V/..3 . , 3640.9 .08 5857, 6 , i2 3930.0 ,29 VERT l].~pTU SECTION ~, ~.... Iii f~ ! 2199.6 930.4 ~; ~ ~ ~ ..~.,~,~ ~ 234.2, 7 I069, 9 2415,2 1i38,6 2486, 9 i 208.2 2699. i !419.3 2770.8 i488.6 2842.7 1557.8 2914.9 i626.8 2987.9 1695.0 30~i. 6 1762.2 3!35.9 1828.7 3209.3 i 896~ 3 3281.5 !965.4. 3424, 9 2 ~,:)4, 8 3569, 3 2242.9 ~4a o 2512.7 ~'~ ~ 2382. = ~57 ~ ~:~'. 0 DISTANCE BEAR!NS ¢~, ~ de9 rain o .'"':r 4':', ,< .... 9 c. "'~' !003.9 S 42 28 1 A"/.':f ~ ....... ~ S 1212,1 S 42 !.285.! S 42 18 !424. i 1493.8 S ,~ 29W t563.~ S 42 30 161~..S !700.8 S 42 27 1768.5 S 42 29 I87= ~ c. 42 ..*".2 !905.1 S 42 54 ""'"' ~'~ q 42 ,...,'-~z.. ,. S 28 "":" ' 42 ziii.5 S 23 ~80.6 S 42 i9 2249.7 S 42 ii 25i9.2 S 4i 59 · ::&.~ S 41 4~ 4.~/. i S 4.1 ?.,o 2525.~ S 4! 3C' 2594.3 S 41 22 feet 686.8 S 632. 740. ",_. S 577. 793.2 S 723., · g44.4 S .*"69.. 8%.2 S 81.~, 0 948:9 S 563~ !000.7 S 912.(: 2)51.4 S 960. 110'1.~ a S i:}08,9 i ! 52.6 S i 056. 1 .--:,)4.3 81 i::12.: i 3(4.3 S i ! 94. I ...... ..~ c ! 240. S ~401,8 S i287:2 !506.5 ':' i''::'-:c.' = 1559,6 i612.4 S 1468.2 · ~/'6'~., . 0 S 1780. " !891, ARCO ALASKA.. !NC. KLPARUK RIVER ~3,ill, NELL ~ iA-26 NLqRTH ~ OF® ~n~,n! ~ ALASf<A HEAS DEF% iNCL BORE HOLE BEARiNB des ~in deg min F.,ono 0 ax 47 S -'= 55 U 5!0{).0 44 8 S 36 14 N 5500.0 44 54 S 35 6 W 5400.0 44 29 S ~5 46 N 5500.'" ~ ~t~ ~ ~ i i N 5600,0 45 13 S 35 22 W 57{)0, 0 45 29 S 35 13 ~.,J 5~cx'~..:'~ 45 59 S 34 40 W 6000.0 4.6 16 S 34 56 W 6!00.0 4! 32 S 37 6 W 6300.0 4i 38 S 36 52 W 6400.0 41 34 S 36 i! W 6600. Ci -4! 0 S 35 52 W 67{}0.0 40 40 S 55 56 W ~80f~ 0 ~n 59 c. 35 8 W 6900.0 40 56 S 35 11 W qU~-q~A nn~-;~m ft deg/100' 4002.2 4074.2 ~42 4145.8 4217.2 .45 4288.5 ~46 4500, 6 ~ 28 4E7fi ~ 4639,6 .47{)8.6 4780~6 4.97 4855,4 ~!7 5004. ? ~ 45 5079.8 X~ 155. i z~ 5230.8 ~ 5506.4 .61 5600~i .65 =ATM ~ D i r.ec t i ona i U~T ~ECTION f~ ~LirVmy r; OSUR~ DISTANCE BEARIN. P: ft deg ~n:]? ? ?A~n ? 266.5-.2 S 4.1 ~ W · , ,_...., ,,, ~8 ..... 8 ,,c. 40 ..~8 ~'~ 4~I'; '- ?~ 40 5,Z. ,' ,,2 285/.3 ..... 6 S W 44n8 5 ..... '1 '- .... ,-¥.-.,',,, 2':,-'4!.4 S 40 ~L." !~ ~sS? A 3007.6 30ii.4 S 40 55 W 4430.3 .5.078.3 3081.8 4500.6 .5149. ,t ~. =', . , ..-.~,~,7~ 40 2(! W 4.:/u.4 ...=..,.~'"'. u.. 3224.0 S 4!]t i.i, W 4639.6 5293.0 3295.9 S 40 6 4780,5 3434,6 4930, i 3567,5 5004.9 3633.8 5079.8 3700.0 5306.4 ~896.4 5456.0 4029.0 5528.3 4097.9 5600.! 4167.3 567!.5 ~? '~ ~.J/ , '.., 5742.9 4306.9 ~68 0 ~ 4!) OW 350~.5 S 39 52 W 5569.8 S 59 48 W 3656~I~c 39 45 W 4030.6 S 39 i9 W 4099.4 S 59 i4 W 4.168.6 S 59 8 W 4238.2 S: 39 2 W -',"? n W · -,.,, .~ S 38 56 H 0 E I Z rj N T ;i, L i.¢~L. 20(i.3. ! S 1755.0 W 2059.2 S ./.,.Y~-': .... ~ 2!72,3 S i~77:5 W 2250,0 S i~iB~i k~ 2287.2 S 1958.9 254.4.9 S '~999.7 2461.7 S 208i~8 2580.2 S 2i64.7 2656.5 S 2205.5 2742.4 S 2285.~ z84-'?..' c " 'u '..'1 = '-,'~Fr-, ~, i,i .-'90~. ~ S 3008,7 S >-!7~,8 W · " ,.J l ..., · --, 3i17 9 o ~==~ -, 3175,6 S 2592.~. N 355i.2 S 2706~9 W Di ~'ect i onal MEAS INCL ~u,~n~"c,~. HOLE DEPTH BEARING 7500 0 .- 7 ' Al':- .. ..- - ,,~ ...... 0 4! n .5 34 50 W 77:]'"~' 4 ....... 0 3 S 34 54 W 7800.'.0 40 46 S 35 5 W 7900, 0 *,', ~..~ ,.,..,... .... ~ .~ 8000.0 40 53 S .3.-4 i9 ~ 8100.C. 40 48 S 33 54. W 81.42,0 ,zr., 4] S ~ ~'~ :' 4797~6 feet SUB-SEA DOG-LEG ~PTW c~U~TTV ~,~ deg/iO0' 58!4,7 5888.6 3.08 5964. ! ,06 6039, ~ 61i5.5 6i9i 3 6266,9 ,28 South 38 dec 26 min VERT VERT CLOSURE HORIZONTAL DISTANCE BEARING r. 0 ''~ R n ft deg min feet 5814,7 4376,2 4377,0 S 38 50 W 5888.6 4443.3 4444,1 S 38 45 W 5964.i 4508,9 4509.6 S 38 42 W 6039=6 4574,3 4574.9 S 38 39 W ,¢,~ 4639,4 ~ ~.¢ 6i9i 3 4~r'4 ~ 6~'A 4769.8 6298,7 4797.2 4770,2 S 38 28 W ~7~7 6 S 38 om ~ 3409,8 S 2744.4 3465,8 S 278!,7 X~ A S 28i~,~ 3573.3 S 2856.~ 3626,8~c 2894.r~... 3680,5 S ~w' 9 ~7 · ~,'~..5 S 2?82.9 /V ARCO ALASKA, INC. Harker Identification ~D N/S E/H A) KB 0 0 H 0 B] 9 5/B' CASING 4633 ~798 S ~BOB C) PBTO 8t53 3763 S 2988 D) 7' CASINS 8237 3808 S 3018 ~ EXTRAPOLATED TO 8276 3829 S 3032 _~A-26 API50-029-22~_ ~15 PLAN V!EH CLOSURE .....: 4885 ft S 38,37 DECLINATION,: 0.00 E SCALE .......: ! inch = 600 feet DRAWN .......: 05/0~/9! Land Directional 1BO( 24t 3000- 3000 ! ! ! ! ! ! ! ! ! ! ! ! 2400 ! ! ! ! ! ! ! ! ! t800 1200 600 0 <- WEST ' EAST -> <KB> 3o! 7000 8000- 9000 - ' ARCO ALASKA, INC. :IA-26 API50-029-22:1:15 VERT~[CAL SECTION VIEH Section al:: S 37.7t I~ TVD Scale.' ! inch = 1000 feet: Dep Scale.' ! inch = 1000 feel: Drawn '05/01/9t Great Lend Directional Drillin# ' ' Harker ]~dent. if~ca~.ion i ........ .. B) g 5/8' CAS/NG D) 7' CASING ' ' F.J EXTRAPOLATED TD MD TVD SECTN INCLN 0 0 0 0.00 4633 3736 2405 43.70 8t53 6307 4804 40.72 8237 637t 4859 40.72 8276 6400 4884 40.72 4000 0 t000 2000 3000 Section Departure BASE ..607.0 k 6265 5000 05/08/91 by GREAT LAND DIRECTIONAL DRILLING, INC. for GyroData Incorporated Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : 1A-26 API50-029-22115 Section at: S,37.71,W Engineer..: BUSH/STODDARD Computation...: RADIUS OF CURVATURE Survey Date...: 05/01/91 RKB Elevation.: 102.00 ft Reference ..... : 0191G207 INTERPOLATED MARKERS REPORT Surface Location: 123 SNL 456 WEL S22 T22N R22E MARKER IDENTIFICATION KB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUKA BASE KUPARUK A PBTD 7" CASING EXTRAPOLATED TD MEAS INCLN DEPTH ANGLE 0 0.00 4633 43.70 7700 41.04 7840 40.69 7967 40.78 8098 40.80 8153 40.72 8237 40.72 8276 40.72 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -102 3736 3634 5964 5862 6070 5968 6166 6064 0 N 0.00 E 2405 S 36.25 W 4509 S 34.90 W 4600 S 34.87 W 4683 S 34.39 W 0 N 0 E 1798 S 1606 W 3519 S 2820 W' 3594 S 2872 W 3662 S 2919 W 6265 6163 6307 6205 6371 6269 6400 6298 4768 S 33.92 W 4804 S 33.99 W 4859 S 33.99 W 4884 S 33.99 W 3733 S 2968 W 3763 S 2988 W 3808 S 3018 W 3829 S 3032 W GREAT LAND Client .... : Field ..... : Well ...... : Section at: Engineer..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. KUPARUK RIVER UNIT 1A-26 API50-029-22115 S,37.71,W BUSH/STODDARD S MEAS INCLN C DEPTH ANGLE 7 100 0.15 7 200 0.21 7 300 0.23 7 400 0.29 7 500 2.68 VERTICAL-DEPTHS BKB SUB-SEA INC. SECTION DISTNCE 100.0 -2.0 -0.1 200.0 98.0 -0.3 300.0 198.0 -0.5 400.0 298.0 -0.3 500.0 398.0 2.0 7 600 4.47 599.8 497.8 7 700 7.99 699.2 597.2 7 800 13.51 797.4 695.4 7 900 16.10 894.0 792.0 7 1000 18.02 989.6 887.6 8.0 18.7 37.0 62.3 91.4 7 1100 19.20 1084.4 982.4 122.9 7 1200 20.27 1178.5 1076.5 156.2 7 1300 22.92 1271.5 1169.5 192.4 7 1400 23.58 1363.4 1261.4 231.3 7 1500 26.24 1454.1 1352.1 272.8 7 1600 31.80 1541.5 1439.5 320.8 7 1700 36.23 1624.3 1522.3 376.1 7 1800 40.37 1702.8 1600.8 437.6 7 1900 43.32 1777.3 1675.3 504.1 7 2000 45.72 1848.6 1746.6 574.2 7 2100 45.52 1918.5 1816.5 645.7 7 / GYRO ^Survey Codes: (1A26 Sl. 20) 05/01/91 Computation...: RADIUS OF CURVATURE Survey Date...: 01/20/91 RKB Elevation.: 102.00 ft Reference ..... : 0191G207 RECORD OF SURVEY DIRECTION BEARING N 1.58 W N 10.94 W N 44.62 W S 77.82 W S 52.86 W S 48.65 W S 48.33 W S 47.00 W S 45.79 W S 45.60 W RELATIVE-COORDINATES FROM-WELL-HEAD 0.1N 0.0W 0.4N 0.0W 0.8N 0.2W 0.9N 0.6W 0.2S 3.0W 4.1S 7.8W ll.3S 15.9W 23.9S 29.7W 41.5S 48.2W 62.0S 69.2W S 46.80 W 84.1 S 92.2 W S 47.49 W 107.0 S 117.0 W S 48.91 W 131.6 S 144.4 W S 47.13 W 158.0 S 173.8 W S 46.57 W 186.8 S 204.5 W S46.05W S45.65W S44.38W S40.09W S37.05W 220.3 S 239.6' W 259.2 S 279.7 W 303.0 S 323.5 W 352.4 S 368.3 W 407.2 S 412.0 W S 37.77 W 464.0 S 455.5 W CLOSURE DL DI STNCE BEARING / 100 0.1 N 1.58 W 0.15 0.4 N 4.88 W 0.06 0.8 N 15.40 W 0.02 1.1 N 34.98 W 0.06 3.0 S 86.70 W 2.39 8.8 S 62.17 W 1.79 19.5 S 54.61 W 3.52 -38.1 S 51.22 W 5.52 63.6 S 49.28 W 2.59 92.9 S 48.15 W 1.92 124.8 S 47.65 W 1.19 158.6 S 47.54 W 1.07 195.4 S 47.66 W 2.66 234.8 S 47.72 W 0.72 276.9 S 47.59 W 2.66 325.4 S 47.40 W 5.56 381.3 S 47.17 W 4.43 443.3 S 46.87 W 4.17 509.8 S 46.26 W 3.57 579.3 S 45.33 W 2.86 650.2 S 44.46 W 0.42 1A-26 API50-029-22115 Page 2 05/01/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 2200 45~51 7 2300 45.52 7 2400 45.35 7 2500 44.70 7 2600 44.31 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 1988.6 1886.6 717.0 S 38.45 W 520.1 S 499.5 W 2058.7 1956.7 788.3 S 38.67 W 575.9 S 544.0 W 2128.8 2026.8 859.6 S 38.81 W 631.5 S 588.5 W 2199.5 2097.5 930.3 S 39.75 W 686.2 S 633.3 W 2270.8 2168.8 1000.3 S 40.07 W 740.0 S 678.3 W CLOSURE DL DISTNCE BEARING / 100 721.1 S 43.84 W 0.35 792.2 S 43.36 W 0.11 863.'2 S 42.98 W 0.18 933.8 S 42.70 W 0.80 1003.8 S 42.50 W 0.42 7 2700 43.84 7 2800 43.19 7 2900 45.28 7 3000 45.27 7 3100 44.88 7 3200 44.32 7 3300 44.06 7 3400 44.02 7 3500 43.48 7 3600 42.83 2342.7 2240.7 1069.8 S 41.64 W 792.6 S 723.8 W 2415.2 2313.2 1138.4 S 42.38 W 843.8 S 769.9 W 2486.8 2384.8 1208.0 S 41.63 W 895.6 S 816.6 W 2557.2 2455.2 1278.8 S 42.61 W 948.3 S 864.2 W 2627.8 2525.8 1349.3 S 43.46 W 1000.0 S 912.5 W 2699.0 2597.0 1419.2 S 43.98 W 1050.8 S 961.1 W 2770.7 2668.7 1488.5 S 43.92 W 1101.0 S 1009.4 W 2842.6 2740.6 1557.7 S 41.65 W 1152.0 S 1056.7 W 2914.9 2812.9 1626.7 S 41.67 W 1203.7 S 1102.6 W 2987.8 2885.8 1694.9 S 42.62 W 1254.4 S 1148.5 W 1073.4 S 42.40 W 0.89 1142.2 S 42.37 W 0.74 1212.0 S 42.35 W 2.12 1283.0 S 42.34 W 0.49 1353.8 S 42.38 W 0.58 1424.0 S 42.44 W 0.61 1493.7 S 42.51 W 0.26 1563.2 S 42.52 W 1.10 1632.3 S 42.49 W 0.54 1700.7 S 42.47 W 0.78 7 3700 42.09 7 3800 41.93 7 3900 43.64 7 4000 43.98 7 4100 44.42 3061.6 2959.6 1762.1 S 43.66 W 1303.6 S 1194.7 W 3135.9 3033.9 1828.6 S 44.40 W 1351.7 S 1241.2 W 3209.3 3107.3 1896.2 S 42.30 W 1401.1 S 1287.8 W 3281.4 3179.4 1965.2 S 41.25 W 1452.8 S 1333.9 W 3353.1 3251.1 2034.9 S 40.03 W 1505.7 S 1379.3 W 1768.2 S 42.50 W 0.88 1835.1 S 42.55 W 0.37 1903.1 S 42.58 W 1.98 1972.3 S 42.55 W 0.61 2042.0 S 42.49 W 0.74 7 4200 43.90 7 4300 43.45 7 4400 44.33 7 4500 44.34 7 4600 43.81 7 4700 43.47 3424.9 3322.9 2104.5 S 40.13 W 1559.0 S 1424.2 W 3497.2 3395.2 2173.5 S 40.18 W 1611.7 S 1468.7 W 3569.3 3467.3 2242.8 S 35.72 W 1666.4 S 1511.3 W 3640.8 3538.8 2312.6 S 35.61 W 1723.2 S 1552.1 W 3712.6 3610.6 2382.1 S 36.31 W 1779.5 S 1592.9 W 3785.0 3683.0 2451.1 S 36.12 W 1835.2 S 1633.7 W 2111.6 S 42.41 W 0.52 2180.6 S 42.34 W 0.45 2249.7 S 42.20 W 2.35 2319.1 S 42.01 W 0.05 2388.3 S 41.83 W 0.63 2457.0 S 41.67 W 0.35 ^Survey Codes: 7/GYRO 1A-26 API50-029-22115 ~ Page 3 05/01/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 4800 43.52 7 4900 43.75 7 5000 43.78 7 5100 44.13 7 5200 44.40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 3857.5 3755.5 2519.9 S 35.97 W 1890.8 S 1674.2 W 2525.5 S 41.52 W 0.09 3929.9 3827.9 2588.9 S 36.21 W 1946.6 S 1714.9 W 2594.2 S 41.37 W 0.26 4002.1 3900.1 2658.1 S 35.91 W 2002.5 S 1755.6 W 2663.1 S 41.24 W 0.15 4074.1 3972.1 2727.4 S 36.24 W 2058.6 S 1796.5 W 2732.2 S 41.11 W 0.38 4145.7 4043.7 2797.2 S 35.71 W 2115.1 S 1837.5 W 2801.7 S 40.98 W 0.37 7 5300 44.56 4217.1 4115.1 2867.2 S 35.11 W 2172.2 S 1878.0 W 2871.5 S 40.84 W 0.34 7 5400 44.48 4288.4 4186.4 2937.3 S 35.76 W 2229.3 S 1918.7 W 2941.3 S 40.71 W 0.33 7 5500 44.82 4359.5 4257.5 3007.5 S 35.18 W 2286.5 S 1959.5 W 3011.3 S 40.59 W 0.45 7 '5600 45.22 4430.2 4328.2 3078.2 S 35.36 W 2344.3 S 2000.3 W 3081.7 S 40.47 W 0.41 7 5700 45.48 4500.5 4398.5 3149.2 S 35.22 W 2402.4 S 2041.4 W 3152.6 S 40.35 W 0.27 7 5800 45.98 4570.3 4468.3 3220.8 S 34.67 W 2461.1 S 2082.4 W 3223.9 S 40.23 W 0.58 7 5900 46.48 4639.5 4537.5 3292.9 S 35.15 W 2520.3 S 2123.8 W 3295.8 S 40.12 W 0.56 7 6000 46.27 4708.5 4606.5 3365.2 S 34.94 W 2579.5 S 2165.3 W 3367.9 S 40.01 W 0.24 7 6100 41.54 4780.5 4678.5 3434.5 S 37.10 W 2635.6 S 2206.1 W 3437.0 S 39.93 W 4.82 7 6200 41.69 4855.3 4753.3 3500.9 S 36.99 W 2688.6 S 2246.1 W 3503.4 S 39.87 W 0.16 7 6300 41.63 4930.0 4828.0 3567.4 S 36.86 W 2741.8 S 2286.0 W 3569.8 S 39.82 W 0.08 7 6400 41.57 5004.7 4902.7 3633.7 S 36.19 W 2795.1 S 2325.6 W 3636.0 S 39.76 W 0.30 7 6500 41.30 5079.7 4977.7 3699.9 S 35.94 W 2848.6 S 2364.5 W 3702.1 S 39.69 W 0.29 7 6600 41.00 5155.0 5053.0 3765.7 S 35.87 W 2901.9 S 2403.1 W 3767.8 S 39.62 W 0.30 7 6700 40.67 5230.7 5128.7 3831.0 S 35.93 W 2954.9 S 2441.4 W 3833.0 S 39.56 W 0.33 7 6800 40.98 5306.3 5204.3 3896.3 S 35.13 W 3008.1 S 2479.4 W 3898.2 S 39.49 W 0.46 7 6900 40.93 5381.9 5279.9 3961.8 S 35.18 W 3061.7 S 2517.2 W 3963.6 S 39.42 W 0.05 7 7000 43.55 5455.9 5353.9 4028.9 S 33.14 W 3117.3 S 2554.9 W 4030.5 S 39.33 W 2.79 7 7100 43.92 5528.2 5426.2 4097.8 S 33.84 W 3174.9 S 2593.1 W 4099.3 S 39.24 W 0.50 7 7200 44.26 5600.0 5498.0 4167.2 S 33.05 W 3233.0 S 2631.4 W 4168.5 S 39.14 W 0.51 7 7300 44.53 5671.4 5569.4 4237.0 S 33.06 W 3291.6 S 2669.6 W 4238.1 S 39.04 W 0.27 ^Survey Codes: 7/GYRO 1A-26 API50-029-22115 S MEAS C DEPTH 7 7400 7 7500 7 7600 7 7700 7 7800 INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 44.45 5742.8 5640.8 4306.8 43.70 5814.6 5712.6 4376.1 41.00 5888.5 5786.5 4443.3 41.04 5964.0 5862.0 4508.8 40.77 6039.5 5937.5 4574.2 7900 40.58 6115.4 6.013.4 8000 40.88 6191.2. 6089.2 8100 40.80 6266.8 6164.8 8142 40.72 6298.6 6196.6 8276 40.72 6400.2 6298.2 4639.3 4704.5 4769.7 4797.1 4884.3 ^Survey Codes: 7/GYRO X/EXTRAPOLATED RECORD OF SURVEY DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD S 32.61 W 3350.5 S 2707.6 W S 32.62 W 3409.1 S 2745.1 W S 34.83 W. 3465.1 S 2782.5 W S 34.90 W 3519.0 S 2820.0 W S 35.08 W 3572.6 S 2857.5 W S 34.55 W 3626.1 S 2894.7 W S 34.32 W 3679.9 S 2931.6 W S 33.91 W 3734.1 S 2968.3 W S 33.99 W 3756.8 S 2983.6 W S 33~99 W 3829.3 S 3032.5 W Page 4 05/01/91 CLOSURE DiSTNCE BEARING 4307.8 S 38.94 W 4376.9 S 38.84 W 4444.0 S 38.76 W 4509.5 S 38.70 W 4574.8 S 38.65 W 4639.9 S 38.60 W 4704.9 S 38.54 W 4770.1 S 38.48 W 4797.5 S 38.45 W 4884.6 S 38.37 W DL /lOO 0.23 0.75 2.86 0.05 0.28 0.29 0.32 0.19 0.21 0.00 1A-26 API50-029-22115 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/01/91 SUBSEA MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD 100 202 0.21 202 0 0 N 11.61 'W 0.45 N 200 302 0.23 302 0 0 N 45.77 W 0'.78 N 300 402 0.34 402 0 0 S 77.32 W 0.90 N 400 502 2.72 502 0 0 S 52.77 W 0.23 S 500 602 4.55 602 0 0 S 48.64 W 4.23 S 600 703 8.15 702 1 1 S 48.29 W 11.57 S 700 805 13.63 802 3 2 S 46.94 W 24.63 S 800 908 16.26 902 6 4 S 45.77 W 43.10 S 900 1013 18.17 1002 11 5 S 45.75 W 64.80 S 1000 1119 19.40 1102 17 6 S 46.93 W 88.28 S 1100 1225 20.93 1202 23 6 S 47.84 W 112.97 S 1200 1333 23.14 1302 31 8 S 48.32 W 140.13 S 1300 1442 24.70 1402 40 9 S 46.89 W 169.76 S 1400 1554 29.25 1502 52 12 S 46.29 W 204.14 S 1500, 1673 35.01 1602 71 18 S 45.76 W 248.04 S 1600 1799 40.32 1702 97 26 S 44.39 W 302.53 S 1700 1934 44.14 1802 132 35 S 39.05 W 370.62 S 1800 2076 45.56 1902 174 42 S 37.60 W 450.64 S 1900 2219 45.51 2002 217 43 S 38.49 W 530.79 S 2000 2362 45.41 2102 260 43 S 38.75 W 610.26 S 2100 2503 44.68 2202 301 42 S 39.76 W 688.11 S 2200 2643 44.10 2302 341 40 S 40.75 W 763.07 S 2300 2782 43.31 2402 380 38 S 42.24 W 834.58 S 2400 2922 45.28 2502 420 40 S 41.84 W 907.02 S 2500 3063 45.02 2602 461 42 S 43.15 W 981.28 S 0.04 W 0.22 W 0.64 W 3.04 W 7.93 W 16.22 W 30.52 W 49.86 W 72.09 W 96.73'W 123.51 W 154.15 W 186.43 W 222.76 W 268.22 W 323.03 W 383.39 W 445.16 W 507.98 W 571.51 W 634.90 W 697.95 W 761.53 W 826.75 W 894.85 W 2600 3204 44.31 2702 502 41 S 43.98 W 1052.88 S 963.07 W 1A-26 API50-029-22115 Page 6 05/01/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 2700 3343 44.04 2800 3482 43.57 2900 3619 42.68 3000 3754 42.00 3100 3890 43.47 TVD BKB 2802 2902 3002 3102 3202 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD '541 39 S 42.93 W 1122.94 S 1030.23 W 580 39 S 41.66 W 1194,53 S 1094.50 W 617 37 S 42.82 W 1264.01 S 1157.42 W 652 35 S 44.06 W 1329.91 S 1219.93 W 688 36 S 42.51 W 1396.02 S 1283.15 W 3200 4029 44.10 3302 3300 4168 44.06 3402 3400 4307 43.51 3502 3500 4446 44.33 3602 3600 4585 43.89 3702 727 39 S 40.90 W 1467.75 S 1347.00 W 766 40 S 40.10 W 1542.08 S 1409.97 W 805 38 S 39.88 W 1615.23 S 1471.65 W 844 39 S 35.67 W 1692.37 S 1530.01 W 883 39 S 36.20 W 1771.24 S 1586.90 W 3700 4723 43.48 3802 3800 4861 43.66 3902 3900 5000 43.78 4002 4000 5139 44.23 4102 4100, 5279 44.52 4202 921 38 S 36.08 W 1848.18 S 1643.21 W 959 38 S 36.12 W 1925.03 S 1699.12 W 998 38 S 35.91 W 2002.38 S 1755.50 W 1037 39 S 36.03 W 2080.47 S 1812.43 W 1077 40 S 35.24 W 2160.04 S 1869.50 W 4200 5419 44.54 4302 4300 5560 45.06 4402 4400 5702 45.49 4502 4500 5846 46.21 4602 4600 5991 46.29 4702 1117 40 S 35.65 W 2240.18 S 1926.51 W 1158 41 S 35.29 W 2321.16 S 1983.93 W 1200 42 S 35.21 W 2403.62 S 2042.31 W 1244 44 S 34.89 W 2488.11 S 2101.23 W 1289 45 S 34.96 W 2574.00 S 2161.46 W 4700 6129 41.58 4802 1327 38 S 37.07 W 2650.82 S 2217.60 W 4800 6263 41.65 4902 1361 34 S 36.91 W 2721.86 S 2271.12 W 4900 6396 41.57 5002 1394 34 S 36.21 W 2793.14 S 2324.12 W 5000 6530 41.21 5102 1428 33 S 35.92 W 2864.43 S 2375.98 W 5100 6662 40.79 5202 1460 33 S 35.91 W 2934.87 S 2426.96 W 5200 6794 40.96 5302 1492 32 S 35.17 W 3004.98 S 2477.26 W 1A-26 API50-029-22115 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/01/91 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5300 6927 41.63.. 5402 1525 33 S 34.63 W 3076.15 S 5400 7064 43.78 5502 1562 37 S 33.58 W 3154.03 S 5500 7203 44.27 5602 1601 39 S 33.05 W 3234.64 S 5600 7343 44.49 5702 1641 40 S 32.87 W 3316.84 S 5700 7483 43.83 5802 1681 40 S 32.62 W 3398.93 S 5800 7618 41.00 5902 1716 35 S 34.84 W 3474.75 S 5900 7750 40.90 6002 1748 33 S 34.99 W 3546.05 S 6000 7882 40.61 6102 1780 32 S 34.64 W 3616.69 S 6100 8014 40.87 6202 1812 32 S 34.26 W 3687.70 S 6200 8146 40.72 6302 1844 32 S 33.99 W 3759.24 S 2527.29 W 2579.12 W 2632.49'W 2685.93 W 2738.56 W 2789.16 W 2838.90 W 2888.23 W 2936.92 W 2985.25 W 1A-26 API50-029-22115 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL o51o1191 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 18.02 990 888 91 S 45.60 W 62 S 2000 45.72 1849 1747 574 S 37.05 W 407 S 3000 45.27 2557 2455 1279 S 42.61 W 948 S 4000 43.98 3281 3179 1965 S 41.25 W 1453 S 5000 43.78 4002 3900 2658 S 35.91 W 2002 S DL/ 100 69 W 93 S 48.15 W 1.9 412 W 579 S 45.33 W 2.9 864 W 1283 S 42.34 W 0.5 1334 W 1972 S 42.55 W 0.6 1756 W 2663 S 41.24 W 0.1 6000 46.27 4708 4606 3365 S 34.94 W 2580 S 7000 43.55 5456 5354 4029 S 33.14 W 3117 S 8000 40.88 6191 6089 4704 S 34.32 W 3680 S 2165 W 3368 S 40.01 W 0.2 2555 W 4031 S 39.33 W 2.8 2932 W 4705 S 38.54 W · 0.3 AOGCC GEOLOGICAL MATERIALS INVENTORY LiST PERMIT # C/_t) - t (~ WELL NAME ~K.t'~ b'~ ) F~ "- =,~ COMPLETION DATE,~ t,, , c'q' lc[t CO. CONTACT ,, ~ check Off or list data as it' is recei~'~d.*liSt received date for 407. if n~,~iuire,d Ii,st as NR '"~0z' I* '7/m/~ ...... drillin9 hi, st°~ ~' "SuweYl ~ ~.. test;' ~1 ,core descriptiod~ cored int~w~(s , ,core analysis,, d~,ditch intewal~ digita,~ data , .......... ~' .... ~77Z ~ ,, ................ ~UTS o~ ,, LOG 'IYPE "~N INTERVALS ' SCALE ...... NO. , ..... [to thc nearest foot] .... [inch~l 0WI iii ii i i ii i i in! ........................... "i~i ........ : ................................... i~l ........ ~q ............... 18) ' 1' ~:1:11 I ~ .................... ' I I 11 IIll I I i i ii i iiii i i i i i ii ] I i i i i i i ARCO Alaska, Inc. Date: June 7, 1991 Transmittal #: 8126 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log After Squeeze Please acknowledge receipt and 4-8-91 4-5-91 1-19-91 4-6-91 4-8-91 1-19-91 4-24-91 4529-7334 72-3430 5700-8140 27-3431 4424-7333 5700-8116 7000-8375 Receipt Drilling Acknowledge: State¥of~'~,Naska(+sepia) ARCO Alaska, Inc. Date: January 25, 1991 Transmittal #: 7993 RETURN TO:. ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. '""'1A-26 -.-1 A-26 '--.1A-26 ~--1 A-26 '"--,IA- 26 '---1A-26 ~-..1 A-26 ~1 A-26 'X1A-28 ~- 1 A-28 Receipt Please acknowledge receipt Formation Test Log 1 - 8 - 9 1 High Resolution Induction DFL 1- 7-91 5"/100' High Resolution Induction DFL 1-7-91 2"/100' High Resolution Induction DFL 1- 1 7-91 Raw X and Raw R Microlog 1 - 7 - 9 1 Spectral Density Dual Spaced 1 - 7- 9 1 Neutron Raw Data Spectral Density Dual Spaced 1 - 7- 9 1 Neutron Porosity Spectral Density Dual Spaced 1-7-91 Neutron High Resolution Pass Dual Gamma Ray-Compensated 1 - 1 9- 91 Neutron Porosity-Simultaneous Formation Density Dual Gamma Ray-Electromagnetic 1 - 1 9- 91 Wave Resistivity j[j Acknowledged: -'~-~~ ........ 4632-8250 0-8124 0-8124 0-8124 0-8090 0-8091 0-8091 0-8091 8994-9915 8994-9915 Date: .......... DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnslon) NSK State of Alaska(+Sepia) RECEIVED JAN 2 9 1991 ........ Alaska Oil & Gas Cons. Commission Anchorage · ARCO Alaska, Inc. Date: January 25, 1991 Transmittal #: 7992 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 1A-26 1A-26 1A-28 Please acknowledge receipt and return Receipt LIS Tape and Usting I - 8 - 9 1 LIS Tape and Usting I - 7 - 9 1 LISTape and U~~~~j~ 22- 91 Acknowledged' - ....... 7631.70-8047 141.75-8140 AK R B910103~-- c~.-"T-7 L.~ Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska TO: MEMORANuUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~'~ DATE: January 18, 1991 Commissioner FILE NO: JT. HH. 11891.6 TELEPHONE NO: THRU: SUBJECT: RIG/BOPE Inspection AAI KRU 1A-26 Permit No. 90-166 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector ~Januarv 6. 1991: I performed a RIG/BOPE inspection on Doyon ~-~-AA~~~~.I found no infractions. I went from cellar to rig floor and checked the location. The company man for AAI was Paul White. The toolpusher was Mark Egholm. The last BOP test was on 1/4/91. There were no failures. In summary: The RIG/BOPE inspection was satisfactorily performed with no infractions I could find. At t achment o 02-001A (Rev. 6/89) 20/ll/MEMO1.PM3 December 18, 1990 Telecopy~ (907)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk River Unit 1A-26 ARCO Alaska, Inc, ' Permit No. 90-166 Sur. Loc. 635'FSL, 310'~L, Sec. 5, TllN, R10E, UM. Btmhole LOc. 2088'FSL, 2271'F%U~, Sec. 7, TllN, R10E, UM. Dear Mr. McBride Enclosed is the approved application for permit to drill the above referenced well. The pemit 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. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, _~_ ~ David W. Johnston Chai~an Alaska Oil and Gas Conservation Commission BY E ~E 09D R OF COmmISSION dlf Enclosure cc: ~ii Department of Fish & Game, Habitat Section w/o encl. ? Department of Environmental Conservation w/o encl. STATE OF ALASKA AI_A~KA OIL AND GAS CONSERVATION COMMIS,~iON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill ~ ~ lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~. Re-Entry _ Deepen --I Service _ Development Gas w Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ..... ARCO Alaska, Inc. RKB 102', Pad 67' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25647 ALK 465 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 635' FSL, 310' FWL, Sec. 5, T11N, R10E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 2855' FNL, 2530' FWL, Sec. 7, T11N, R10E, UM 1A-26 #U630610 At total depth 9. Approximate spud date Amount 2088' FSL, 2271' FWL, Sec 7, T11N, R10E, UM 25-DEC-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1A-7A 8272' MD 2088' @ TD feet 17' at 520' MD feet 2469 6438' TVD feet "1'6. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500' feet Maximum hole an~lle 43° Maximum surface 2240 psig At total depth (TVD) 3690psi~ @ 6438' 18. casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Wet,iht Grade Couplin~l Length lVD TVD IVD TVD (include slavic dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 4598' 35' 35' 4633 3777' 2330 Cu. Ft. AS III & HF-ERW 520 Cu. Ft. Class G ~'.5 7" 26.0# J-55 AB-MO[ 4598' 35' 35' 4633' 3777' 250 Cu. Ft. Class G , 8.5 7" 26.0# J-55 BTC 3639' 4633' 3777' 8272' 6438' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. R. cu... REi EIVED Intermediate Production Liner DEC 1 1 199( Perforation depth: measured true verticalAlaska 0il & Gas Cons. C0mmlSsi0a A.-.ch0re..e 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch X Drilling program X D, dlling fluid program X Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Z~~~~ Title Area Drilling Engineer Date' / Commission Use Only Permit Number I APInumber I Approval date 12/18/901 sM cover letter for ¢o --/'~'~; so- o ~ ? - ~ ~ 1/_.4' other recluirements Conditions of approval Samples required ~Y es .~ N o Mud Icg required~ Yes .~ N o Hydrogen sulfide measuresm Yes ~ N o Directional survey required ~ Yes __ N o Required working pressure for BOPE __ 2M; .~ 3 M' __ 5 M' ~ I 0 M' m I 5 M Other: ,¢'~ ._ by order of Form 10-401 Rev. 7-2~ ,~.,~ t in triplicate DRILLING FLUID PROGRAM (1A-26) Spud to 9-5/8" Drill out to Weight up surface casing weight uo to TD Density 8.6-1 0.0 8.6-9.6 1 1.0 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 1 5-40 4 - 8 4 - 8 APl Filtrate 1 O- 1 2 8- 1 0 4- 5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4- 7 1 O- 1 2 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED DEC 1 1 1990 Alaska Oil & Gas Cons. Comm[ssiOa Anchorage Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2240 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 1A-26 will be 1A-7A. As designed, the minimum distance between the two wells would be 17' at 520' MD. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, !ne · Pad lA, I~ell Not 26 Propoeed Kuparuk Field, North Slope, Alaeka 1000 2000 RKB ELEVATIONs 102° KOP TVD-500 TMD-500 DEP-O 3 9 BUILD :3 DEG PER I00 FT 15 21 RECEIVED DEC 1 1 199~ Alaska Oil & 6as Cons. Commission Anchorage B/ PERHAFROST TVD=1502 THD=1555 DEP-284 ~3 39 EOC TVD=1803 TMD=1934 DEP=513 3000 4000 5000 T/ UGNU SNDS TVD=2577 Tl'IDm2gg2 DEP=1235 T/ 14 SAK SNDS TVD=3172 TI"ID=3806 DEP=lTgO AVERAGE ANGLE 43 DEG B/ 14 SAK SNDS TVD=3577 TPID-4360 DEP-2168 9 5/8' CSG PT TVD=3777 TI'ID=4633 DEP-2355 K-lO TVD=3982 Tt'ID=4914 DEP-2546 K-5 TVD-5047 TPID=6370 DEP-3539 6OOO 7000 TARGET - TI ZONE C TVD=Sg82 TMD=7649 DEP=4411 TI ZONE A TVD-6190 TMD-7933 DEP-4605 B/ KUP SNDS TVD-6292 T~D-8072 DEP-4700 TD / LOGGING PT TVD-6438 THD-8272 DEP-4837 I I I 0 1 000 2000 3000 VERTICAL SECTION % I I 4000 5000 HORI,~qNTAL PROJECTION S"'.,~.E I IN. = 1000 FEET ARCO ALASKA. lno. Pad lA, Well No, 26 Proposed Kuparuk Field, North Slope, Alaska 1000 ~000 WEST-EAST 2000 1000 0 I I I SURFACE 1000 I SURFACE LOCAT I ON t 635' FSL, 310' FWI. SEC. 5, T11#, RIOE 1000 2000 DEC 1 1 199G Alaska Oil & Gas Cons. C;ommissJoJl Anchorage 3000 TARGET TVD-5982 THD=?649 DEP-4411 SOUTH 3490 WEST 2698 4000 TARGET LOCATIONt 2855' FNL, 2530' FWL SEC. T, T11N, RIOE TD LOCATION~ 2088' FSL, 2271' Fkl. SEC. ?, T11#, RIOE S 37 DE(; 42 MIN W 4411' [TO TARGET] RE(EiVED 0 11 19~ Gas Cons. Commissio~ ~nchorago 5O ! 800 1 750 7OO ~650 600 ~50 I ! ~500 1 450 :350 NO0 50 200 I / / / 300 5 O0 !,, I I . gOO 1500 1105 %, 1300 500 ?*GO / / / / ,p / I gOO iseo ,1 ?oo 13oo -t GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD lA PAD I . , . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. RECEIVED DEC .~laska Oil & Gas Cons. Oommissio~ Anchorage K,JPARUK RIVER UNll 20" DIVERTER SCHEMATIC 5 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) RECEIVED DEC 1 1 1990 Alaska Oil & 6as Cons. 6ommissio[~ 1. 16" CONDUCTOR Anchorage 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 1(7' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE ~6~0 7 13 5/8" 5000 Poi BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED DEC 1 i 1990 Alaska Oil & Gas Cons. 6ommissio~ Anchorage SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fe--7 1. ( 2 )' L o c ~ 8f~_~~ " ~ 2 ihru (8) (3) Admin ~ (9~t~ru 13) (10 and 13).. (14 th~ 22) (23 thru 28) (6) OTHER (29 thru 31) (6) Add: Geology: Engineering: DWJ .~LCS rev: 01/30/89 6.011 Company /~_~ Lease & Well No. YES NO · Is the permit fee attached .......................................... . .... 2. Is well t~ 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 and is wellbore plat included ................ ~ . 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~ . . 10. 11. 12. 13. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... ~_ Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is conductor string provided ........................................ _ ,, Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface .......... Will cement tie in surface and intermediate or production strings .... Will cement cover all known productive horizons ..................... ,,~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~ psig .. -~ . Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ... ~ exploratory and stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,., Additional Remarks: 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 APPENDIXi ., No special 'effort has been made to chronologically organize this category of information. GR SFT TEMP SFT LOAD SFT TSPD SFT FTPC SFT THRS SFT FTP SFT HYDP SFT VOLP SFT HPRP SFT FTPR SFT HPQ SFT MTF SFT HPFQ SFT STSW SFT 492239 API 030310010 23 4 1 68 492239 DEGF 080660020 23 4 1 68 492239 LBS 000000000 23 2 1 79 492239 F/MI 000636000 23 4 1 68 492239 PSI 095000000 23 4 1 68 492239 HRS 000000000 23 4 1 68 492239 PSI 095000000 23 4 1 68 492239 PSI 095000000 23 4 1 73 492239 095000000 23 2 1 79 492239 PSI 000000000 23 4 1 68 492239 CPS 095000000 23 4 1 68 492239 PSI 000000000 23 4 1 68 492239 HZ 080660000 23 4 1 68 492239 KHZ 000000000 23 4 1 68 492239 095000000 23 4 1 68 DATA RECORD TYPE 0 DEPT = 7710.000 TENS = 3496 SP = -19.990 GR = 69.500 TEMP = 149.170 LOAD = -236 _ TSPD = .000 FTPC = 3409.900 THRS = 33.700 FTP = 3447.000 HYDP = 3354 VOLP = 0 HPRP = 3272.410 FTPR = 3447.000 HPQ = 3435.170 MTF = 14917.240 HPFQ = 929.420 STSW = 8.143 DEPT = 7710.000 TENS = 3498 SP = -19.990 GR = 71.900 TEMP 147.540 LOAD = -3840 TSPD = .000 FTPC = 3497.400 THRS = 33.728 FTP = 3533.700 HYDP = 4953 VOLP = 0 ~HPRP = 3379.270 FTPR = 3533.700 HPQ = 3512.840 MTF = 14754.380 HPFQ = 937.380 STSW = 8.029 DEPT = 7710.000 TENS = 3495 SP = -19.990 GR = 59.400 TEMP = 148.710 LOAD = -224 TSPD = .000 FTPC = 3517.000 THRS = 33.756 FTP = 3553.200 HYDP = 4599 VOLP = 0 HPRP = 3364.590 FTPR = 3553.200 HPQ = 3538.670 MTF = 14870.870 HPFQ = 940.059 STSW = 9.157 DEPT = 7710.000 TENS = 3495 SP = -19.990 GR = 64.300 TEMP = 145.450 LOAD = -118 TSPD = .000 FTPC = 3408.000 THRS = 33.784 FTp = 3444.700 HYDP = 3387 VOLP = 0 HPRP = 32-69.380 FTPR = 3444.700 HPQ = 3432.840 MTF = 14544.690 HPFQ = 929.107 STSW = 8.146 FILE TRAILER RECORD ~ ' TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION 'MAX. 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CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 ~66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS .DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP $FT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 49223,9 PSI THRS SFT 492239 HR$ FTP SFT 492239 PSI HYDP SFT '492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW $FT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 24 4 1 68 000635000 24 2 1 79 001010010 24 4 1 68 030310010 24 4 1 68 080660020 24 4 1 68 000000000 24 2 1 79 000636000 24 4 1 68 095000000 24 4 1 68 000000000 24 ~ 4 1 68 095000000 24 4 1 68 095000000 24 .4 1 73 095000000 24 2 1 79 000000000 24 4 1 68 095000000 24 4 1 68 000000000 24 4 1 68 080660000 24 4 1 68 000000000 24 4 1 68 095000000 24 4 1 68 DATA RECORD TYPE 0 DEPT = 7710.000 TENS = GR = 68.900 TEMP = TSPD = .000 FTPC = FTP = 3445.300' HYDP = HPRP = 3269.640 FTPR = MTF = 14919.580 HPFQ = 3510 SP = 149.200 LOAD = 3408.200 THRS = .3387 VOLP = 3445.300 - HPQ = 929.121 · STSW = -19.990 -239 33.830 0 3432.260 8. 149 DEPT = 7710.000 TENS = 3495 SP = -19.990 GR = 64.800 TEMP = 150.120 LOAD = -244 TSPD = .000 FTPC = 3491.800 THRS = 33.858 FTP = 3528.300 HYDP = 4845 VOLP = 0 HPRP = 3365.590 FTPR = 3528.300 HPQ = 3526.070 MTF = 15011.670. HPFQ = 938.790 STSW = 8.146 DEPT = 7710.000 TENS = 3494 SP = -19.990 GR = 67.100 TEMP = 148.630 LOAD = -58 TSPD = .000 FTPC = 1947.000 THRS = 33.886 FTP = 1990.600 HYDP = 4489 VOLP = -1 HPRP = 3354.730 FTPR = 1990.600 HPQ = 3340.240 MTF = 14862.570 HPFQ = 919.639 STSW = 9.153 FILE TRAILER RECORD .............................. TYPE 129 FILE'NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATEOF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.004 --- 1024 --- LO --- LOGIN2.005 FILE HEADER RECORD ..... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OFGENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.005 --- 310 --- 96 --- LOGIN2 .... 1024 --- LO --- LOGIN2.004 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 .1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT TENS SP GR TEMP SERVID SERVICE# UNITS SFT 492239 F SFT 492239 LBS SFT 492239 MV SFT 492239 API SFT 492239 DEGF API CODE FILE# 000000000 25 000635000 25 001010010 25 030310010 25 080660020 25 SIZE 4 2 4 4 4 #SAMP REPR. 1 68 1 79 1 68 1 68 1 68 LOAD SFT 492239 LBS 000000000 25 2 1 79 TSPD SFT 492239 F/MI 000636000 25 4 1 68 FTPC SFT 492239 PSI 095000000 25 4 1 68 THRS SFT 492239 HRS 000000000 25 4 1 68 FTP SFT 492239 PSI 095000000 25 4 1 68 HYDP SFT 492239 PSI 095000000 25 4 1 73 VOLP SFT 492239 095000000 25 2 1 79 HPRP SFT 492239 PSI 000000000 25 4 1 68 FTPR SFT 492239 CPS 095000000 25 4 1 68 HPQ SFT 492239 PSI 000000000 25 4 1 68 MTF SFT 492239 HZ 080660000 25 4 1 68 HPFQ SFT 492239 KHZ 000000000 25 4 1 68 STSW SFT 492239 095000000 25 4 1 68 DATA RECORD TYPE 0 DEPT = 7710.500 TENS = 3469 SP = -19.990 GR = 77.300 TEMP = 149.270 LOAD = -241 TSPD = .000 FTPC = 3409.500 THRS = 33.950 FTP = 3446.600 HYDP = 3356 VOLP = 0 HPRP = 3271.100 FTPR = 3446.600 HPQ = 3433.790 MTF = 14926.740 HPFQ = 929.280 STSW = 8.149 DEPT = 7710.500 TENS = 3465 SP = -19.990 GR = 60.900 TEM~ = 151.320 LOAD = -454 TSPD = .000 FTPC = 3524.100 THRS = 33.977 FTP = 3560.400 HYDP = 4950 VOLP = 0 HPRP = 3384.410 '~FTPR = 3560.400 HPQ = 3531.800 MTF = 15131.820 HPFQ = 939.403 STSW = 8.938 DEPT = 7710.500 TENS = 3467 SP = -19.990 GR = 62.200 TEMP = 146.960 LOAD = -144 TSPD = .000 FTPC = 3408.800 THRS = 34.005 FTP = 3445.700 HYDP = 3411 VOLP = 0 HPRP = 3270.350 FTPR = 3445.700 HPQ = 3433.470 MTF = 14696.080 HPFQ = 929.202 STSW = 8.145 FILE TRAILER RECORD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER/ DATE OF GENERATION MAX. 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DEPT SFT 492239 F 000000000 26 4 1 68 TENS SFT 492239 LBS 000635000 26 2 1 79 SP SFT 492239 MV 001010010 26 4 1 68 GR SFT 492239 API 030310010 26 4 1 68 TEMP SFT 492239 DEGF 080660020 26 4 1 68 LOAD SFT 492239 LBS 000000000 26 2 1 79 TSPD SFT 492239 F/MI 000636000 26 4 1 68 FTPC SFT 492239 PSI 095000000 26' 4 1 68 THRS SFT 492239 HRS 000000000 26 4 1 68 FTP SFT 492239 PSI 095000000 26 4 1 68 HYDP SFT 492239 PSI 095000000 26 4 1 73 VOLP SFT 492239 095000000 26 2 1 79 HPRP SFT 492239 PSI 000000000 26 4 1 68 FTPR SFT 492239 CPS 095000000 26 4 1 68 HPQ SFT 492239 PSI 000000000 26 4 1 68 MTF SFT 492239 HZ 080660000 26 ~4 1 68 HPFQ SFT 492239 KHZ 000000000 26 4 1 68 STSW SFT 492239 095000000 26 4 1 68 DATA RECORD TYPE 0 DEPT = 7713.000 TENS = 3579 SP = -19.990 GR = 62.700 TEMP = 14'9.350 LOAD = -232 TSPD = .000 FTPC,= 3411.200 THRS = 34.057 FTP = 3448.300 HYDP = 3356 'VOLP = 0 HPRP = 3273.150 FTPR = 3448.300 HPQ = 3435.890 MTF = 14934.730 HPFQ = 929.498 STSW = 9.150 DEPT = 7713.0'00 TENS = 3578 SP = -19.990 GR = 59.300 TEMP = 153.170 LOAD = 1136 TSPD = .000 FTPC = 3447.000 THRS = 34.085 FTP- = 3483.900 HYDP = 4734 VOLP = 0 HPRP = 3356.450 FTPR = 3483 90'0 HPQ = 3484.110 MTF = 15316.660 HPFQ = 934.531 STSW = 8.076 DEPT = 7713.000 TENS = 3578 SP = -19.990 GR = 68.000 TEMP = 149.260 LOAD = -6 TSPD = .000 FTPC = 2414.100 THRS = 34.113 FTP = 2456.900 HYDP = 4486 VOLP = -1 HPRP = 3361.840 FTPR = 2456.900 HPQ = 3492.140 MTF = 14925.670 HPFQ = 935.283 STSW = 9.150 FILE TRAILER RECORD ......... 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CODE 1 66 1 66 2 ~ 79 1 66 1 66 4 68 4 65 2 7'9 4 68 4 65 1 66 1 66 1 66 ENTRY 0 0 66 0 .500 S 15 -999.250 FT 68 1 0 DATUM SPECIFICATION BLOCKS: DEPT TENS SP GR TEMP LOAD .TSPD FTPC THR$ FTP HYDP VOLP SERVID SERVICE# UNITS SFT 492239 F SFT 492239 LBS SFT 492239 MV SFT 492239 API SFT 492239 DEGF SFT 492239 LBS SFT. 492239 F/MI SFT 492239 PSI SFT 492239 ERS SFT 492239 PSI' SFT 492239 PSI SFT 492239 API CODE FILE# 000000000 27 000635000 27 001010010 27 030310010 27 080660020 27 000000000 27 000636000 27 095000000 27 000000000 27 095000000 27 '095000000 27 095000000 27 SIZE #SAMP REPR. 4 1 68 2 1 79 4 1 68 4 1 68 4 1 68 2 1 79 4 1 68 4 1 68 4 1 68 4 1 68 4 1 73 2 1 79 HPRP SFT 492239 PSI 000000000 27 4 1 68 FTPR SFT 492239 CPS 095000000 27 4 1 68 HPQ SFT 492239 PSI 000000000 27 4 1 68 MTF SFT 492239 HZ 080660000 27 4 1 68 HPFQ SFT 492239 K~Z 000000000 27 4 1 68 STSW SFT 492239 095000000 27 4 1 68 DATA RECORD TYPE 0 DEPT = 7713.500 TENS = 3538 SP = -19.990 GR = 70.200 TEMP = 149.450 LOAD = -236 TSPD = .000 FTPC = 3408.000 THRS = 34.176 FTP = 3445.100 HYDP = 3374 VOLP = 0 HPRP = 3271.030 FTPR = 3445.100 HPQ = 3433.680 MTF = 14944.720 HPFQ = 929.272 STSW = 8,144 DEPT = 7713.500 TENS = 3518 SP = -19.990 GR = 64.300 TEMP = 144.470 LOAD = -319 TSPD = .000 FTPC = 3541.100 THRS = 34,203 FTP = 3576.700 HYDP = 5130 VOLP = 0 HPRP = 3396.240 FTPR = 3576.700 HPQ = 3567.390 MTF = 14447.330 HPFQ = 942.930 STSW = 9.133 DEPT = 7713.500, TENS = 3518 SP = -19,990 GR = 73.900 TEMP = 146.250 LOAD = -154 TSPD = .000 FTPC = 3408.100 THRS = 34,231 FTP = 3444.900 HYDP = 3413 VOLP = 0 HPRP = 3270.100 FTPR = 3444.900 HPQ = 3433.230 MTF = 14625.180- HPFQ = 929.163 STSW = 8.141 FILE TRAILER RECORD .............................. 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CODE ENTRY 1 66 0 1 66 0 2 79 66 1 66 0 1 66 0 4 68 .500 4 65 S 2 79 15 4 68 -999.250 4 65 FT 1 66 68 1 66 1 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT ' 492239 LBS SP SFT 492239 MV GR SFT ~ 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 29 4 1 68 000635000 29 2 1 79 001010010 29 4 1 68 030310010 29 4 1 68 080660020 29 4 1 68 000000000 29 2 1 79 000636000 29 4 1 68 095000000 29 4 1 68 000000000 29 4 1 68 095000000 29 4 1 68 095000000 29 4 1 73' 095000000 29 2 1 79 000000000 29 4 1 68 095000000 29 4 1 68 0000'00000 29 4 1 68 080660000 29 4 1 68 000000000 29 4 1 68 095000000 29 4 1 68 DATA RECORD TYPE 0 DEPT = 7718.500 TENS = 3592 SP = -19.990 GR - 57.100 TEMP = 149.660 LOAD = -265 TSPD = .000 FTPC = 3411.900 THRS = 34.416 FTP = 3449.000 HYDP = 3402 VOLP = 0 HPRP = 3273.310 FTPR = 3449.000 HPQ = 3436.030 MTF = 14965.700 HPFQ = 929.518 STSW = 8.135 DEPT = 7718.500 TENS = 3591 SP = -19.990 GR = 66.600 TEMP = 153.980 LOAD = -341 TSPD = .000 FTPC = 3180.700 THRS = 34.444 FTP = 3219.700 HYDP = 4910 VOLP = 0 .HPRP = 3375.870 FTPR = 3219.700 HPQ = 3509.880 MTF = 15397.720 HPFQ = 937.197 STSW = 2.013 DEPT = 7718.500 TENS = 3591 SP = -19.990 GR = 73.000 TEMP = 150.800 LOAD = -175 TSPD = .000 FTPC = 3455.000 THRS = 34.471 FTP = 3491.800 HYDP = 3447 VOLP = 0 HPRP = 3272.140 FTPR = 3491.800 HPQ = 3436.230 MTF = 15079.980 HPFQ = 929.560 STSW = 8.135 FILE TRAILER RECORD .............................. 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TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.011 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.010 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE#' SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 31 4 1 68 TENS SFT 492239 LBS 000635000 31 2 1 79 SP SFT 492239 MV 001010010 31 4 1 68 GR SFT 492239 API 030310010 31 ' 4 1 68 TEMP SFT 492239 DEGF 080660020 31 4 1 68 LOAD SFT 492239 LBS 000000000 31 2 1 79 TSPD SFT 492239 F/MI 000636000 31 4 1 68 FTPC SFT 492239 . PSI 095000000 31 4 1 68 THRS SFT 492239 HRS 000000000 31 4 1 68 FTP SFT 492239 PSI 095000000 ' 31 4 1 68 HYDP SFT 492239 PSI 095000000 31 4 1 73 VOLP SFT 492239 095000000 31 2 1 79 HPRP SFT 492239 PSI 000000000 31 4 1 68 FTPR SFT 492239 CPS 095000000 31 4 1 68 HPQ SFT 492239 PSI 000000000 31 4 1 68 MTF SFT 492239 HZ 080660000 31 4 1 68 HPFQ SFT 492239 KHZ 000000000 31 4 1 68 STSW SFT 492239~ 095000000 31 4 1 68 DATA RECORD TYPE 0 DEPT = 7721.000 ~TENS = 3636 SP = -19.990 GR = 65. 600 TEMP = 149. 930 LOAD = -256 TSPD = .000 FTPC = 3481.000 THRS = 34.715 FTP = 3517.600 HYDP = 4170 VOLP = 0 HPRP = 3341.200 FTPR = 3517.600 HPQ = 3507.280 MTF = 14993.160 HPFQ = 936.854 STSW = 8.128 DEPT = 7721.000 TENS = 3640 SP = -19.990 GR = 54.300 TEMP = 141.980 LOAD = -224 TSPD = .000 FTPC = 223.000 THRS = 34.743 FTP = 254.200 HYDP = 4813 VOLP = 0 HPRP = 39.460 FTPR = 254.200 HPQ = 101.080 MTF = 14198.060 HPFQ = 583.803 STSW = 9.125 DEPT = 7721~000 TENS = 3637 SP = -19.990 GR = 63.700 TEMP = 145.860 LOAD = -155 TSPD = .000 FTPC = 3408.300 THRS = 34.771 FTP = 3445.100 HYDP = - 3386 VOLP = 0 HPRP = 3269.600 FTPR = 3445.100 HPQ = 3432.930 MTF = 14586.340 HPFQ = 929.125 STSW = 8.127 FILE TRAILER RECORD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ................... TYPE 129 --- LOGIN2.011 --- 1024 --- LO --- LOGIN2.012 FILE HEADER RECORD .......... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.012 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.011 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE 1 1 2 1 3 2 4 1 5 1 8 4 9 4 11 2 12 4 14 4 15 1 16 1 0 1 REPR. CODE 66 66 79 66 66 68 65 79 68 65 66. 66 66 ENTRY 0 0 66 0 0 .500 S 15 -999.250 FT 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 49'2239 F 000000000 32 4 1 68 TENS SFT. 492239 LBS 000635000 32 2 1 79 SP SFT 492239 MV 001010010 32 4 1 68 GR SFT 492239 API 030310010 32 4 1 68 TEMP SFT 492239 DEGF 080660020 32 4 1 68 LOAD SFT 492239 LBS 000000000 32 2 1 79 TSPD SFT 492239 F/MI 000636000 32 4 1 68 FTPC SFT 492239 PSI 0R5000000 32 4 1 68 THRS SFT 492239 HRS 000000000 32 4 1 68 FTP SFT 492239 PSI 095000000 32 4 1 68 HYDP SFT 492239 PSI 095000000 32 4 1 73 VOLP SFT 492239 095000000 32 2 1 79 HPRP SFT 492239 PSI 000000000 32 4 1 68 FTPR SFT 492239 CPS 095000000 32 4 1 68 HPQ SFT 492239 PSI 000000000 32 4 1 68 MTF SFT 492239 HZ 080660000 32 4 1 68 HPFQ SFT 492239 KHZ 000000000 32 4 1 68 STSW SFT 492239 095000000 32 4 1 68 DATA RECORD TYPE 0 DEPT = 7724.000 TENS = 3684 SP = -19.990 GR = 60.700 TEMP = 150.020 LOAD = -253 TSPD = .000 FTPC = 3408.700 THRS = 34.821 FTP = 3445.800 HYDP = 3405 VOLP = 0 HPRP = 3270.730 FTPR = 3445.800 HPQ = 3433.220 MTF = 15002.020 HPFQ = 929.236 STSW = 8.127 DEPT = 7724.000 TENS = 358'2 SP = -19.990 GR = 54.200 TEMP = 154.730 LOAD = -331 TSPD = .000 FTPC = 3470.400 THRS = 34.849 FTP = 3507.100 HYDP = 4495 VOLP = 1 HPRP = 3157.520 FTPR = 3507.100 HPQ = 3457.710 MTF = 15473.150 HPFQ = 931.844 STSW = 9.131 DEPT = 7724.000 TENS = 3579 SP = -19.990 GR = 56.200 TEMP = 146.640 LOAD = -143 TSPD = .000 FTPC = 3~407.900 THRS = 34.877 FTP = 3444.800 HYDP = 3393 VOLP = 0 HPRP = 3269.440 FTPR = 3444.800 HPQ = 3432.650 MTF = 14.664.220 HPFQ = 929.111 STSW = 8.127 FILE TRAILER RECORD ................... - .......... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.012 --- 1024 --- LO --- LOGIN2.013 FILE HEADER RECORD TYPE ,128 FILE NAME SERVICE SUB LEVEL NAME --- LOGIN2.013 --- 310 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE~TYPE OPTIONAL PREVIOUS FILE NAME --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.012 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 $ 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP ~SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HR$ FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 33 4 1 68 000635000 33 2 1 79 001010010 33 4 1 68 030310010 33 4 1 68 080660020 33 4 1 68 000000000 33 2 1 79 000636000 33 4 1 68 095000000 33 4 1 68 000000000 33 4 1 68 095000000 33 4 1 68 095000000 33 4 1 73 095000000 33 2 1 79 000000000 33 4 1 68 095000000 33 4 1 68 000000000 33 4 1 68 080660000 33 4 1 68 000000000 33 4 1 68 095000000 33 4 1 68 DATA RECORD- TYPE 0 DEPT = .7727.000 GR = ,62.500 TSPD = .000 FTP ' = 3447.400 HPRP = 3272.480 MTF = 15010.990 TENS = TEMP = FTPC. = HYDP = FTPR = HPFQ = 3523 SP = -19.990 150.110 LOAD = -214 3410.300 THRS = 34.924 3403 VOLP = 0 3447.400 HPQ = 3435.060 929.427 STSW = 8.125 DEPT = 7727.000 GR = 64.800 TSPD= .000 . TENS = TEMP = FTPC 3508 SP = -19.990 155.550 LOAD = -3634 3473.300 THRS = 34.952 FTP = 3510.000 HYDP = 4776 VOLP = 0 HPRP = 3348.850 FTPR = 3510.000 HPQ = 3477.930 MTF = 15554.890 HPFQ = '933.939 STSW = 8.083 DEPT = 7727.000 TENS = 3508 SP = -19.990 GR = 58.200 TEMP = 150.510 LOAD = -219 TSPD = .000 FTPC = 3136.500 THRS = 34.980 FTP = 3175.600 HYDP = 4546 VOLP = 1 HPRP = 3081.680 FTPR = 3175.600 HPQ = 3211.430 MTF = 15051.450 HPFQ = 906.412 STSW = 9.129 DEPT = 7727.000 TENS = 3509 SP = -19.990 GR = 62.600 TEMP = 150.200 LOAD = -216 TSPD = .000 FTPC = 3210.500 THRS = 35.007 FTP = 3249.100 HYDP = 4537 VOLP = 1 HPRP = 3082.940 FTPR = 3249.100 HPQ = 3236.160 MTF = 15019.590 HPFQ = 908.953 STSW = 9.128 DEPT = 7727.000 TENS = 3508 SP = -19.990 GR = 68.100 TEMP = 150.220 LOAD = -218 TSPD = .000 FTPC = 3210.600 THRS = 35.035 FTP = 3249.200 HYDP = 4527 VOLP = 1 HPRP = 3083.050 FTPR = 3249.200 HPQ = 3236.270 MTF = 15022.500 HPFQ = 9~8.965 STSW = 9.128 FILE TRAILER RECORD ....................... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX.. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.013 --- 1024 --- LO --- LOGIN2.014 · FILE HEADER RECORD .............. - ............... TYPE 128 FILENAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.014 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.013 DATUM FORMAT SPECIFICATION RECORD~ - .............. TYPE 64 ENTRY BLOCKS: TYPE 1 2 3 4 5 8 SIZE REPR. CODE ENTRY 1 66 0 1 66 0 2 79 66 1 66 0 1 66 0 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM' SERVID SERVICE# UNITS API CODE FILE# DEPT SFT 492239 F 000000000 34 TENS SFT 492239 LBS 000635000 34 SP SFT 492239 MV 001010010 34 GR SFT 492239 API 030310010 34 TEMP SFT 492239 DEGF 080660020 34 LOAD SFT 492239 LBS 000000000 34 TSPD SFT 492239 F/MI 000636000 34 FTPC SFT 492239 PSI 095000000 34 THRS SFT 492239 HRS 000000000 34 FTP SFT 492239 PSI 095000000 34 HYDP SFT 492239 PSI 095000000 34 VOLP SFT 492239 095000000 34 HPRP SFT 492239 PSI 000000000 34 FTPR SFT 492239 CPS 095000000 34 HPQ SFT 492239 PSI 000000000 34 MTF SFT 492239 HZ 080660000 34 HPFQ SFT 492239 KHZ 000000000 34 STSW SFT 492239 095000000 34 DATA RECORD TYPE 0 SIZE #SAMP REPR. 4 1 68 2 1 79 4 1 68 4 1 68 4 1 68 2 1 79 4 1 68 4 1 68 4 1 68 4 1 68 4 1 73 2 1 79 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 DEPT = 7735.000 GR = 69.000 TSPD = .000 FTP = 3450.000 HPRP = 3276.230 MTF = 15030.360 TENS = 3357 SP = -19.990 TEMP = 150.300 LOAD = -211 FTPC = 3412.900 THRS = 35.112 HYDP = 3394 VOLP = 0 .FTPR = 3450.000 HPQ = 3438.940 HPFQ = 929.830 STSW = 8.118 DEPT = 7735.000 GR = 61.200 TSPD = .000 FTP = 3505.600 HPRP = 3344.180 MTF = 15335.190 TENS = 3357 SP = -19.990 TEMP = 153.350 LOAD = -213 FTPC = 3468.800 THRS = 35.140 HYDP = 4840 VOLP = 0 FTPR = 3505.600 HPQ = 3492.130 HPFQ = 935.360 STSW = 8.125 DEPT = 7735.000 GR = 65.900 TSPD = .000 FTP = 3252.000~ HPRPTM 3084.360 MTF = 15037.000 TENS = 3355 SP = -19.990 TEMP = 150.370 LOAD = -202 FTPC = 3213.400 THRS = 35.168 HYDP = 4837 VOLP = 0 FTPR = 3252.000 HPQ = 3237.650 HPFQ = 909.110 STSW = 9.127 DEPT = 7735.000 GR = 71.100 TSPD.= .000 · FTP = 3449.200 HPRP = 32742030 MTF = 14463.820 TENS = 3354 SP = -19.990 TEMP = 144.640 LOAD = -202 FTPC = 3412.600 'THRS = 35.196 HYDP = 3307 VOLP = 0 FTPR = 3449.200 HPQ = 3437.980 HPFQ = 929.620 STSW = 8.120 FILE TRAILER RECORD ·TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. 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CODE ENTRY 1 66 0 1 66 0 2 79 66 1 66 0 1 66 0 4 68 .500 4 65 S 2 79 15 4 68 -999.250 4 65 FT 1 66 68 1 66 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE#~ UNITS DEPT'' SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT- 492239 PSI~ MTF SFT 492239 HZ HPFQ SFT 492239 KHZ API CODE FILE# SIZE #SAMP REPR. 000000000 35 4 1 68 000635000 35 2 1 79 001010010 35 4 1 68 030310010 35 4 1 68 080660020 35 4 1 68 000000000 35 2 1 79 000636000 35 4 1 68 095000000 35 4 1 68 000000000 35 4 1 68 095000000 35 4 1 68 095000000 35 4 1 73 0950'00000 35 2 1 79 000000000 35 4 1 68 095000000 35 4 1 68 000000000 35 4 1 68 080660000 35 4 1 68 000000000 35 4 1 68 STSW SFT 492239 095000000 35 4 1 68 DATA RECORD TYPE 0 DEPT = 7738.000 TENS = 3523 SP = -19.990 GR = 70.400 TEMP = 150.480 LOAD = -214 TSPD = .000 FTPC = 3412.800 THRS = 35.239 FTP = 3449.900 HYDP = 3390 VOLP = 0 HPRP = 3275.890 FTPR = 3449.900 HPQ = 3438.530 MTF = 15047.990 HPFQ = 929.791 STSW = 8.118 DEPT = GR = TSPD = FTP = HPRP = MTF = 7738.000 TENS = 3504 SP = -19.990 48.400 TEMP = 154.450 LOAD = -200 .000 FTPC = 3517.100 THRS = 35.267 3553.500 HYDP = 4826 VOLP = 0 3364.710 FTPR = 3553.500 HPQ = 3501.100 15444.580 HPFQ = 936.303 STSW = 7.106 DEPT = 7738.000 GR = 61,300 TSPD = .000 FTP = 2737.800 HPRP = 2629.120 MTF = 15055.490 TENS = 3498 SP = -19.990 TEMP = 150.550 LOAD = -204 FTPC = 2696.000 THRS = 35.295 HYDP = 4586 VOLP = '0 FTPR = 2737.800 HPQ = 2742.620 HPFQ = 858.080 STSW = 9.124 DEPT = GR = TSPD = FTP = HPRP = MTF = 77 8.ooo 62.200 .000 3139.700 2981.860 15059.490 TENS = 3494 SP = -19.990 TEMP = 150.590 LOAD = -208 FTPC = 3100.300 THRS = 35.323 HYDP = 4586 VOLP = 0 FTPR = 3139.700 HPQ = 3127.370 HPFQ = 897.754 ~ STSW = 9.123 DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD =- FTP = HPRP= MTF = 7738.000 56.300 .000 3222.800 3057.320 15063.280 7738.000 55.200 .000 3253.300 3085.210 15066.680 TENS = 3490 SP = -19.990 TEMP = 150.630 LOAD = -209 FTPC = 3184.000 THRS = 35.350 HYDP = 4583 VOLP = 0 FTPR = 3222.800 HPQ = 3208.380 HPFQ = 906.100 STSW = 9.123 TENS = 3489 SP = -19.990 TEMP = 150.670 LOAD = -213 FTPC = 3214.700 THRS = 35.378 HYDP = 4581 VOLP = 0 FTPR = 3253.300 HPQ = 3238.130 HPFQ = 909.165 STSW = 9.123 DEPT = GR = TSPD.= FTP = HPRP = MTF = DEPT = GR = TSPD = 7738.000 55.000 .000 3264.600 3095.380 15069.980 7738.000 60.800 .000 TENS = 3489 SP = -19.990 TEMP = 150.700 LOAD = -211 FTPC = 3226.100 THRS = 35.406 HYDP = 4578 VOLP = 0 FTPR = 3264.600 HPQ = 3248.970 HPFQ = 910.282 STSW = 9.122 TENS = 3486 SP = -19.990 TEM2P = 150.-730 LOAD = -208 FTPC = 3232.700 THRS = 35.434 FTP = 3271.200 HYDP = 4576 VOLP = 0 HPRP = 3101.220 FTPR = 3271.200 HPQ = 3255.190 MTF = 15072.680 HPFQ = 910.923 STSW = 9.123 DEPT = 7738.000 TENS = 3484 SP = -19.990 GR = 63.500 TEMP = 150.750 LOAD = -216 TSPD = .000 FTPC = 3235.800 THRS = 35.461 FTP = 3274.300 HYDP = 4575 VOLP = 0 HPRP = 3103.960 FTPR = 3274.300 HPQ = 3258.110 MTF = 15075.290 HPFQ = 911.224 STSW = 9.124 DEPT = 7738.000 TENS = 3490 SP = -19.990 GR = 55.600 TEMP = 150.780 LOAD = -211 TSPD = .000 FTPC = 3237.800 THRS = 35.489 FTP = 3276.200 HYDP = 4573 VOLP = 0 HPRP = 3105.660 FTPR = 3276.200 HPQ = 3259.900 MTF = 15077.590 HPFQ = 911.409 STSW = 9.123 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.015 --- 1024 --- LO '--- LOGIN2.016 ******************************************************************************* FILE HEADER RECORD --- ........................... TYPE 128 FILE NAME SERVICESUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.016 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.015 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRy BLOCKS: TYPE 1 2 3 4 5 8 9 12 14 15 16 0 SIZE 1 1 2 1 1 4 4 2. 4 4 1 1 1 REPR. CODE 66 66 79 66 66 68 65 79 68 65 66 66 66 ENTRY 0 0 66 0 0 .5O0 S 15 -999.250 FT 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 38 4 1 68 000635000 38 2 1 79 001010010 38 4 1 68 030310010 38 4 1 68 080660020 38 4 1 68 000000000 38 2 1 79 000636000 38 4 1 68 095000000 38 4 1 68 000000000 38 4 1 68 095000000 38 4 1 68 095000000 38 4 1 73 095000000 38 2 1 79 000000000 38 4 1 68 095000000 38 4 1 68 000000000 38 4 1 68 080660000 38 4 1 68 000000000 38 4 1 68 095000000 38 4 1 68 DATA RECORD TYPE 0 DEPT = GR ' TSPD = FTP = HPRP = MTF = 7743.000 TENS= 65.100 TEMP = .000 FTPC = 3451.900 -HYDP = 3278.930 FTPR = 15102.810 HPFQ = 3537 SP = -19.990 151,030 LOAD = -251 3414.800 THRS = 35.805 3411 VOLP = 0 3451,900 HPQ = 3441.670 930,125 STSW = 8.117 DEPT = 7743.000 TENS = GR = 58.200 TEMP = TSPD = .000 FTPC = FTP = 3532.100 HYDP = HPRP = 3360.390' FTPR = MTF= 15533.330 HPFQ = 3523 SP = -19.990 155,330 LOAD = -258 3495.600 THRS = 35,833 4644 VOLP = 0 3532.100 HPQ. = 3510.810 937,318 STSW = 9.115 DEPT = GR = TSPD = FTP = HPRP = MTF = 7743.000 TENS = 62.600 TEMP = .000 FTPC= 3224.400 HYDP = 3057.780 FTPR = 15109.710 HPFQ = ~3523 SP = -19.990 151,100 LOAD = -256 3185.600 THRS = 35.861 4545 VOLP = 1 3224.400 HPQ = 3209.190 906,193 STSW = 9.131 DEPT = GR = TSPD = FTP = HPRP = MTF =- 7743.000 TENS 63.900 TEMP .000 FTPC 3240.100 HYDP 3071.620 FTPR 15112,.130 HPFQ 3514 SP = -19.990 151.120 LOAD = -255 3201.400 THRS = 35.888 4533 VOLP = 1 3240.100 HPQ = 3223.980 907,716 STSW = 9.130 DEPT = 7743.000 TENS GR = 63.500 TEMP TSPD = .000 FTPC FTP = 3246.800 HYDP HPRP = 3077.770 FTPR MTF = 15114.530 HPFQ 3510 SP = -19.990 151,150 LOAD = -257 3208,100 THRS = 35.916 4526 VOLP = 1 3246.800 HPQ = 3230.520 908.3'90 STSW = 9.128 DEPT = 7743.000 TENS = GR = 57.600 TEMP = TSPD = .000 FTPC = FTP = 3250.500 HYDP = HPRP = 3080.940 FTPR = MTF = 15116.820 HPFQ = DEPT = 7743.000 TENS = GR = 57.500 TEMP = TSPD = .000 FTPC = FTP = 3252.000 HYDP = HPRP = 3082.480 FTPR = MTF = 15118.820 HPFQ = 3508 SP = -19.990 151.170 LOAD = -252 3211.800 THRS = 35.944 4522 VOLP = 1 3250.500 HPQ = 3233.870 908.736 STSW = 9.126 3503 SP = -19.990 151.190 LOAD = -258 3213.400 THRS = 35.972 4518 VOLP = 1 3252.000 HPQ = 3235.530 908.907 STSW = 9.130 DEPT = 7743.~000 TENS GR' = 61.500 TEMP TSPD = .000 FTPC FTP = 3252.600 HYDP HPRP = 3083.310 FTPR MTF = 15120.820 HPFQ DEPT = 7743.000 GR = 63.300 TSPD = .000 FTP = 3253.000 HPRP = 3084.030 MTF = 15122.710 3502 SP = -19.990 151.210 LOAD = -256 3214.000 THRS = 36.000 4515 VOLP = 1 3252.600 HPQ = 3236.390 908.996 STSW = 9.128 TENS = 3498 SP = -19.990 TEMP = 151.230 LOAD = -255 FTPC = 3214.400 THRS = 36.027 HYDP = 4513 VOLP = 1 FTPR = 3253.000 HPQ = 3237.130 HPFQ = 909.073 STSW = 9.125 DEPT = 7743.000 GR = 59.100 TSPD = .000 FTP = 3253.300 HPRP = 3084.680 MTF = 15124.300 TENS'= 3498 SP = -19.990 TEMP = 151.240 LOAD = -151 FTPC = 3214.700 THRS = 36.055 HYDP = 4510 VOLP = 1 FTPR = 3253.300 HPQ = 3237.820 HPFQ = 909.144 STSW = 9.124 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.016 --- 1024 --- LO --- LOGIN2.O17 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.017 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.016 I = ~HOA 0COS 89~'9C = SHH~ 00S'960~ Cg~- = ~VOH 066'6I- = ~S I69E = ~GAH 000'9~I[ = 6~ = Da~& 000' = a~S~ = ~H& 00.9'8~ = HO = SNH~, 000'99LA = ~H~ 8II'8 = MS~S 0S~'C~6 00~'ELg~ = ~H 00~'SLg~ 0 = ~HOA' SIOS I~E'9[ = SHH~ 889- = ~VOH 019'89I 066'6I- = ~S 66~ = O~H 009'I989I = = H~ 098'SE~Z = = ~QAH 00E'SLgZ = = O~& 000' =' = ~H~ 000't9 = HD = SNH& 000'99LL = 8II'8 = MS~S I9I'0C6 0L6'I9~£ = ~H 008'ISgZ 0 = ~HOA 9SZ~ CIE'9[ = SHH& 00L'919~ 9~E- = (~OH 0Z~'ISI 066'6I- = 6S COSC = O~H 0CC'CCISI = = H~ 0S~'6Lgg = = ~GAH 008'ISgg = ~& - = O~& 000' = ~S~ = ~H~ 008'9L = HD = SNH& 000*99LL = 0 H~XA fRtODHH ~A~G :SHDOH~ NOI~¥DI~IDH~S ~flA~O 0 -99 I '0 I 99 I 9I 89 99 I SI 0S~'666- 89 9 SI 6L ~ II S S9 9 6 OOS' 89 9 8 0 99 I 0 99 I 99 6L ~ 0 99 I 0 99 I I AH~NH HGOD 'H~HH HZIS :SHDOH~ AHANH 99 HdA~ ............... GHODHH NOI~DI~IDH~S ~{HO~ ~qlA~G HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = 'FTP = HPRP = 2976.880 15135.480 FTPR = HPFQ = 7746.000 59.200 .000 3197.900 3032.520 15137.280 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 51.600 .000 3220.700 3053.450 15139.270 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 62.600 .000 3232.800 3064.430 15141.170 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 56.900 .000 3240.400 3071.4.00 15143.070 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 56.200 .000 3245.500 3076.080 15144.770 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 54.100 .000 32'49.400 3079.370 15146.470 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 7746.000 ~. TENS 55.500 TEMP .000 FTPC 3251.600 HYDP 3081.510 FTPR 15147.970 HPFQ 7746.000 59.000 .000 3252.400 3082.490 TENS = TEMP= FTPC = HYDP = FTPR = 3136.000 897.~272 HPQ = STSW = 3488 SP = 151.370 LOAD = 3158.900 THRS = 5013 VOLP = 3197.900 HPQ = 903..446 STSW = 3487 SP = 151.390 LOAD = 3181.800 THRS = 5001 VOLP = 3220.700 HPQ = 905.741 STSW = 3485 SP = 151.410 LOAD = 3194.000 THRS = 4993 VOLP = 3232.800 HPQ = 906.940 STSW = 3484 151.430 3201.700 4988 3240.400 907.698 SP = LOAD = THRS = VOLP = HPQ = STSW = 3488 SP = 151..450 LOAD = 3206.800 THRS = 4984 VOLP = 3245.500 HPQ = 908.208 STSW = 3488 SP = 151.460 LOAD = 3210.700 THRS = 4980 VOLP = 3249.400 HPQ = ~908.566 $TSW = 3489 SP = 151.'480 LOAD = 3212.900 THRS = 4976 VOLP = 3251.600 HPQ = 908.801 STSW = 3494 151.490 3213.700 4974 3252.400 $p = LOAD = THRS = VOLP = HPQ = 3122.550 9.120 -19.990 -272 36.296 1 3182.470 9.117 -19.990 -263 36.324 1 3204.750 9.116 -19.990 -263 36.352 1 3216.390 9.116 -19.990 -263 36.380 1 3223.740 9.116 -19.990 -262 36.407 1 3228.690 9.116 -19.990 -263 36.435 1 3232.170 9.116 -19.990 -263 36.463 1 3234.450 9.116 -19.990 -258 36.491 1 3235.480 89 I ~ 6/- I E 89 I ~ 89 I ~ 89 I ~ 6/- I E 89 I ~ 'H~HH 6~S# HZIS 0009C9000 000000000 0~0099080 0100IC0~0 010010100 000~9000 -000000000 I~ 6C~6~ ~S HD A~ 6~ZE69 ~S ~S S~IN/1 #HDIAHHS GIAHHS ~HN]4 :SHD,O~ NOI~VDI~IDH~S Nfl~VG 0 99 I 0 I 99 I 9I 89 99 I 0~E'666- 89 ~ gI 6/- E II S ~9 ~ 6 00S' 89 ~ 8 0 99 I 0 99 I 99 6L E 0 99 ~ 0 99 I XH~NH H~OD 'H~HH HZIS :SHDO~ AHANH 99 H6A~ ............... GHODHH NOI~DI~IDH~S ~XS~HO~ ~qZ¥G /-I0'ENIDOH --- Oq --- ~EOI ENIOO~ --- 96 --- 0IC --- 810'ENIDO~ --- H~N H~I~ S~OIAHH~ ~NOIA~O H~OITH~ ~HODHH T~DISAH~ 'X~ NOI~¥HHNHD ~0 H~G HH~/1N NOISHHA H~fN ~HAH~ ~/IS HDIAHHS HkSfN H~I~ .............................. GHOOHH HHGYHH H~I~ 810'ENIDO~ --- O~ --- ~EOI --- LI0'ENIDO~ --- ........................ = ..... ~HODHH HH~Ik~H~ H~I~ ZtI'8 = MS~S ~89'E£6 = O&~H 089'I/-8~I 0E0'N9~g = O~H 009'9ENO' = H~& 089'I/-EZ 0 = ~OA ~gz[ = ~GAH 009'9E~£ 8I~'9C = SHH~ 00E'06~ = O~ 000' 9EI- = (/~0~ 0E/-'89I = ~[H~ 00/-'9~ 066'6I- = ~S 06~ = SNH~ 000'9~/-/- = = 8HclH = = = HD = 9II'6 = MSAS 806'806 = ~,.,IclH OL~' 6~I~I = FTPC SFT 492239 PSI 095000000 41 4 1 68 THRS SFT 492239 HRS 000000000 41 4 1 68 FTP SFT 492239 PSI 095000000 41 4 1 68 HYDP SFT 492239 PSI 095000000 41 4 1 73 VOLP SFT 492239 095000000 41 2 1 79 HPRP SFT 492239 PSI 000000000 41 4 1 68 FTPR SFT 492239 CPS 095000000 41 4 1 68 HPQ SFT 492239 PSI 000000000 41 4 1 68 MTF SFT 492239 HZ 080660000 41 4 1 68 HPFQ SFT 492239 KHZ 000000000 41 4 1 68 STSW SFT 492239 095000000 41 4 1 68 DATA RECORD TYPE 0 DEPT = 7750.000 TENS = GR = 60.800 TEMP = TSPD = .000 FTPC = FTP = 3449.600 HYDP = HPRP = 3277.220 FTPR = MTF = 15156.140 HPFQ = 3489 SP = -19.990 151.560 LOAD = -283 3412.400 THRS = 36.624 3452 VOLP = 0 3449.600 HPQ = 3439.780 929.940 STSW = 8.111 DEPT = 7750.000 TENS = 'GR = 51.200 TEMP = TSPD = .000 FTPC = FTP = 3587.500 HYDP = HPRP = 3372.190 FTPR = MTF = 14327.900 HPFQ = 3469 SP = -19.990 143.280 LOAD = -408 3552.100 THRS = 36.651 5187 VOLP = 1 3587.500 HPQ = 3566.280 942.792 STSW = 9.115 DEPT = 7750.000 GR = 67.900 TSPD = .000 FTP = 3574.800 HPRP = 3393.820 MTF = 15160.280 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 3467 SP = -19.990 151.600 LOAD = -326 3538.600 THRS = 36.679 5072 VOLP = 0 3574.800 HPQ = 3562.450 942.560 STSW = 9.115 DEPT = 7750.000 GR = 65.000 TSPD = .000 FTP. = 3448.900 HPRP = 3272.930 MTF = 15162.680 TENS TEMP FTPC HYDP FTPR HPFQ 3466 SP = -19.990 151.630 LOAD = -256 3411.700 THRS = 36.707 3387 VOLP = 0 3448.900 HPQ = 3435.300 929.481 STSW = 8.113 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME .VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.018 --- 1024 --- LO LOGIN2.019 FILE HEADER RECORD -- TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER --- LOGIN2.019 --- 310 --- 96 0 = ~HOA ~89~ = ~AH 00I'6~ = 08t'9~ = SHH~ 00I'~I~£ = D~ 000' = 0~- = ~0~ 018'8~I = ~N]t~- 00~'~9 = 066'6I- = SS 69~ = SN~,~ 0,00'0~LL = III'8 = MS~S 89S'6E6 = ~&6H 0~9'£9ISI .= 0~I'9~ = ~H 000'8~Z = H6~ 0E8'£LE~ = ~H6H 0 = ~OA 009Z = ~GAH 000'8~Z = · E~&'9~ = SHH~ 008'0I~ - O~ 000' = 6EE- = ~0~ 089'IgI = ~I~H~ 00~'9~ = HD 066'6I- = SS £L9£ = SNH~ 000'0~££ = :SHDO~ NOI~DI~IDH4S $~i1A~G 0 99 I I 99 I 89 99 0S~'666- 89 00S' 89 0 99 0 .99 99 6L 0 99 0 99 AH~NH HOOD 'H~HH HZIS 0 9I II 6- 8 I :SHDO~ XHANH. 99 H~X~ ............... ~HODHH NOI~DI~IDH~S ~AHO& ~/1A~G 810'ENIDO~ --- O~ --- · ~EOI --- ENIDOq --- HPRP = 3274.480 FTPR = 3449.100 HPQ = 3435.590 MTF = 15881.030 HPFQ = 929.642 STSW = 8.112 DEPT = 7750.000 TENS = 3465 SP = -19.990 GR = 58.500 TEMP = 150.760 LOAD = -265 TSPD = .000 FTPC = 3559.700 THRS = 36.808 FTP = 3595.700 HYDP = 5169 VOLP = 0 HPRP = 3415.040 FTPR = 3595.700 HPQ = 3587.500 MTF = 15076.410 HPFQ = 945.121 STSW = 8.088 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.019 --- 1024 --- LO --- LOGIN2.02.0 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE.NAME --- LOGIN2.020 --- 310 --- 96. --- LOGIN2 --- 1024 --- LO --- LOGIN2.019 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE 1. 1 2 1 3 2 4 1 5 _ 1 8 4 9 ' 4 11 2 12 4' 14 4 15 1 16 1 0 1- REPR. CODE 66 66 79 66 66 68 65 79 68 65 66' 66 66 ENTRY 0 0 66 0 · 0 ~ .500 S 15 -999.250 FT 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT· TENS SP-- GR TEMP SERVID .SERVICE# UNITS SFT 492239 F SFT 492239 LBS SFT 492239 MV SFT 492239 API. SFT' 492239 DEGF ApI:CODE FILE# 000000000 43 000635000 43 001010010 43 030310010 43 080660020 43 SIZE 4 2 4 4 4 #SAMP REPR. 1 68 1 79 1 68 1 68 1 68 LOAD SFT 492239 LBS 000000000 43 2 1 79 TSPD $FT 492239 F/MI 000636000 43 4 1 68 FTPC SFT 492239 PSI 095000000 43 4 1 68 THRS SFT 492239 HRS 000000000 43 4 1 68 FTP SFT 492239 PSI 095000000 43 4 1 68 HYDP $FT 492239 PSI 095000000 43 4 1 73 VOLP $FT 492239 095000000 43 2 1 79 HPRP SFT 492239 PSI 000000000 43 4 1 68 FTPR SFT 492239 CPS 095000000 43 4 1 68 HPQ SFT 492239 PSI 000000000 43 4 1 68 MTF $FT 492239 HZ 080660000 43 4 1 68 HPFQ SFT 492239 KHZ .000000000 43 4 1 68 STSW SFT 492239 095000000 43 4 1 68 DATA RECORD TYPE 0 DEPT = 7758.000 GR = 60.600 TSPD = .000 FTP = 3452.400 HPRP = 3277.520 MTF = 15174.940 TENS = 3509 $P = -19.990 TEMP = 151.750 LOAD = -253 FTPC = 3415.200 THRS = 36.855 HYDP = 3416 VOLP = 0 FTPR = 3452.400 HPQ = 3440.030 HPFQ = 929.969 STSW = 8.112 DEPT = 7758.000 GR = 59.200 TSPD = .000 FTP = 3542.400 HPRP = 3383.400 MTF = 15108.350 TENS = 3501 SP = -19.990 TEMP = 151.080 LOAD = -3737 FTPC = 3506.000 THRS = 36.882 HYDP = 5028 VOLP = 0 FTPR = 3542.400 HPQ = 3522.910 HPFQ = 938.484 STSW = 8.071 DEPT = 7758.000 TENS = GR = 55.500 TEMP = TSPD = .000 FTPC = FTP = 3257.800 HYDP = HPRP = 3089.320 FTPR = MTF = 15179.750 HPFQ = 3496 SP = -19.990 151.800 LOAD = -248 3219.200 THRS = 36.910 4902 VOLP = 0 3257.800 HPQ = 3242.580 909.645 STSW = 9.113 DEPT = GR = TSPD = FTP = HPRP = MTF = 7758.000 56.100 .000 3257.900 3090.310 '15182.160 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 3491 SP = -19.990 151.820 LOAD = -248 3219.300 THRS = 36.938 4888 VOLP = 0 3257.900 HPQ = 3243.610 909.751 STSW = 9.111 DEPT GR = TSPD = FTP = HPRP = MTF = DEPT = GR = TSPD = FTP. = HPRP = MTF= 7758.000 58.500 .000 3257.900 3091.260 15184.550 7758.000 59.700 .000 3448.800 3274.010 15132.960 TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = TENS = TEMP = FTPC = HYDP = FTPR = HPFQ = 3489 SP = -19.990 151.850 LOAD = -250 3219.300 THRS = 36.966 4878 VOLP = 0 3257.900. HPQ = 3244.610 909.855 STSW = 9.113 3486 151.330 3411.600 3364 3448.800 929.594 $P = -19.990 LOAD = -253 THRS = 36.993 VOLP = 0 HPQ =. 3436.460 STSW = 8.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE- OPTIONAL NEXT FILE NAME --- LOGIN2.020 --- 1024 --- LO --- LOGIN2.021 FILE HEADER~RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION~ MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.021 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.020 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY, 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 1 5 1 66 1 8 4 '68 .500 9 4 65 FT 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1' 66 '68 16 1 66, 1 ~ 0 1 66 0 DATUM SPECIFICATION BLOCKS: DEPT SFT 492239 TENS SFT 492239 SP SFT 492239 GR SFT 492239 ,TEMP SFT 492239 LOAD SFT 492239 TSPD SFT 492239 FTPC SFT 492239 THRs SFT 492239 FTP SFT 492239 HYDP SFT 492239 VOLP SFT '492239 HPRP S FT 492239 FTPR SFT 492239- HPQ SFT 492239 MTF · SFT 492239 HPFQ SFT 492239 SERVID SERVICE# UNITS F MV 'API DEGF LBS F/MI PSI HRS PSI PSI PSI CPS PSI. HZ KHZ API CODE FILE# SIZE #SAMP REPR. 000000000 45 4 1 68 000635000 45 2 1 79 001010010 45 4 1 68 030310010 45 4 1 68 080660020 45 4 1 68 000000000 45 2 1 79 000636000 45 4 1 68 095000000 45 4 1 68 000000000 45 4 1 68 095000000 45 4 1 68 095000000 45 4 ,1 73 095000000 45 2 1 79 000000000 45 4 1 68 0950000010 45. 4 1 68 000000000 45 4 1 68' 080660000 45 4 1 68 000000000 45 4 1 68 98C'£g = SHH~ 009'S~0E 6E' = GHO~ 00E'~I 066'6I- = SS ~LC 610'- = MS~S 06g'g~ 000' = 06H 008'9I 0 = ~OA 6I ~gg'tC = SHH~ 00g'8~E 99 = GHO~ 009'~ 066'6I- = SS 9ELC = - = cIH~ = SNH&~ = HcI.~.& = clflXH = D~,~.& = ~& 00~'9E 006 '0EI -00/.'969/- 000" 008'9I OOS OOE'SS 00/-' 9~/.t = = HD = = . cl%tclH = = = HD = 610'- = MS~S 000' = 0~H 008'~I 0 = ~OA ti CEC'£g = SHH~ 006'~89E ~9 = GHO~ 09I'C 066'6I- = ~S 0~9'I8E .000' 008'~I 000'LE 00~'09 O0/-'96Lt = = ~H~[H = ~,~.& = = HD = 610'- = MS~S 919'9CS 000' = ~aH 00~'~I 0 = ~OA ~I E6g'£g = SHH~ 006'IELE EE = G~O~ OOS'E 066'6I- = ~S 969[ 000' 009'9I OOS'9E OOL'08 OOL'998L = = clHclH = = = HD = 6t0'- = MS~S E88'99S 000' = O~H 008'~I 0 = d~OA 6I I9g'£C = SHH~ 009'0S9E £9 = QHO~ OSL'C 066'6I- = ~S 6LAC = 0~tclH = HEEL& = cI(IXH = = = 0~I'ESC 000' 00/.'~I 00S'9E 000'IA 00A'968A = = clHaH = = = HD = 610'- = MS~S 9SO'ISS 000' = ~aH 00S'~I 0 = ~OA EE 0£E'L£ = SHH~ 00L'LI9E 8E = QHO~ 09g'~ 066'6I- = ~S 698~ = 0&clH = = = = = 000' = ~H6H 00g'~I = ~A~ 000'£E = Q~SA 00/-'/-8 = HD 00L'9~6L = A~HO 610'- = MS~S 999'LZS 000' = ~H 00E'gI 0 = ~OA 9I 86I'LC = SHH~ O09'L~LE 9- = GHO~ 090'E 066'6I- = 6S E08E 000' = clHaH 00~'~I = 000'SE = 000'98 = HD 00L'966£ = 000' = MS~S 000' 000' = O~H 009'SI 0 = ~HOA 0 S9I'LC = SHH~ 000' 0 = GHO~ 000' 000' = SS COSC 000'86SLgIE = 000' = clH~H 000' = 00S'LI = Q~SA 000' = HO 00/-'9~08 = 0 H~A~ GHODHH HA~G 89 I 9 S9 000000S60 6gEE69 ~S MS~S 89 ~ ~ 89 I ~ 89 I ~ 89 I ~ 6£ I E 89 I ~ '~4~ ~knfS# ~ZIS 000000000 000000~60 000000~60 000000~60 000000000 000000~60 0009~9000 000000000 0~0099080 OIOOI£O~O 010010100 O00~g9000 000000000 #H~I~ HGOD I~ 6C~6~ 6Z~E6~ & 6CE~6~ ~S S~IN/1 #HDIAHHS GIAHHS clHclH ~7OA dGKH SHH,I, G~S,L G~07 ~I4H,I, HD ~S SNH,T,. :SHDO~ NOI~DI&IDH~S 0 ~99 I 0 I 99 I 9I 89 99 I SI 0S~'666- 89 ~ ~I 6L E II S ~9 ~ 6 00~' 89 ~ 8 0 99 I 0 99 I 99 6L E 0 99 I 0 99 I I AH~NH HGOD 'H~HH HZIS :SHDO~ XHANH 99 H~A~ ............... GHODHH NOI~DI~IDH~S AY~F60~ N/1AYG IE0'ENIDO~ --- O~ --- ~0I --- ENIDO~ --- 96 --- 0Ig --- EE0'ENIDO~ --- HN%fN H~I~ 'S~OIAHH~ ~¥NOIA60 H6A~ H~I~ HADNH~ GHODHH T~DISAH~ 'Xhq4 NOI~fHHNH9 ~O H~¥G HH~N/1N NOISHHA HR-~N ~HAH~ ~LGS' HDIAHHS HN~fN H%I~ .............................. GHOOHH HHfrk~H H~IM EE0'ENIDO~ --- Oq --- ~Z0I --- mmm IE0'ENIDO~ --- .............................. GHODHH HH~Ik~t~ 610'- = MS~S 0IL'I9N = 0~H 0g0'NECI = ~H 000' = ~H 00L'gI = H~ 000' = ~H~H 0 = E~OA 6E = &GAH 008'CI = d~ FTPR SFT 492239 CPS 095000000 47 4 1 68 HPQ SFT 492239 PSI 000000000 47 4 1 68 MTF SFT 492239 HZ 080660000 47 4 1 68 HPFQ SFT 492239 KHZ 000000000 47 4 1 68 STSW SFT 492239 095000000 47 4 1 68 DATA RECORD TYPE 0 DEPT = 7765.000 TENS = 3360 SP = -19.990 GR = 58.400 TEMP = 153.280 LOAD = -268 TSPD = .000 FTPC = 3419.400 THRS = 37.552 FTP = 3456.600 HYDP = 3428 VOLP = 0 HPRP = 3280.810 FTPR = 3456.600 HPQ = 3443.230 MTF = 15327.650 HPFQ = 930.327 STSW = 8.123 DEPT = 7765.000 TENS = 3357 SP = -19.990 GR = 67.400 TEMP = 154.690 LOAD = -2649 TSPD = .000 FTPC = 3506.900 THRS = 37.580 FTP = 3543.300 HYDP = 5047 VOLP = 0 HPRP = 3386.320 FTPR = 3543.300 HPQ = 3522.190 MTF = 15469.480 HPFQ = 938.477 STSW = 7.154 DEPT = 7765.000 TENS = 3354 SP = -19.990 GR = 61.200 TEMP = 154.420 LOAD = 53 TSPD = .000 FTPC = 3541.300 THRS = 37.607 FTP = 3577.500 HYDP = 4955 VOLP = -1 HPRP = 3394.220 FTPR = 3577.500 HPQ = 3572.310 MTF = 15442.380 HPFQ = 943.627 STSW = 9.124 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.022 --- 1024 --- LO --- LOGIN2.023 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ---~LOGIN2.023 --- 310 --- 96 -'- LOGIN2 --- 1024 --- LO --- LOGIN2.022 DATUM FORMAT' SPECIFICATION RECORD- .... - ......... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 48 4 1 68 TENS SFT 492239 LBS 000635000 48 2 1 79 SP SFT 492239 MV 001010010 48 4 1 68 GR SFT 492239 API 030310010 48 4 1 68 TEMP SFT 492239 DEGF 080660020 48 4 1 68 LOAD SFT 492239 LBS 000000000 48 2 1 79 TSPD SFT 492239 F/MI 000636000 48 4 1 68 FTPC SFT 492239 PSI 095000000 48 4 1 68 THRS SFT 492239 HRS 000000000 48 4 1 68 FTP SFT 492239 PSI 095000000 48 4 1 68 HYDP SFT 492239 PSI 095000000 48 4 1 73 VOLP SFT 492239 095000000 48 2 1 79 HPRP SFT 492239 PSI 000000000 48 4 1 68 FTPR SFT 492239 CPS 095000000 48 4 1 68 HPQ SFT 492239 PSI 000000000 48 4 1 68 MTF SFT 492239 HZ 080660000 48 4 1 68 HPFQ SFT 492239 KHZ 000000000 48 4 1 68 STSW SFT 4922.39 095000000 48 4 1 68 DATA RECORD TYPE 0 DEPT = 7770.000 TENS = 3418 SP = -19.990 GR = 84.600 TEMP = 153.000 LOAD = -316 TSPD = .000 FTPC = 3415.600 THRS = 37.701 FTP = 3452.800 HYDP = 3426 VOLP = 0 HPRP = 3279.150 FTPR = 3452.800 HPQ = 3441.530 MTF = 15300.480 'HPFQ = 930'.147 STSW = 8.116 DEPT = 7770.000 TENS = 3408 SP = -19.990 GR = 65.700 TEMP = 148.750 LOAD = -306 TSPD = .000 FTPC = 3512.300 THRS = 37.729 FTP = 3548.500 HYDP = 5044 VOLP = 0 HPRP = 3373.670 FTPR = 3548.500 HPQ = 3541.680 MTF = 14874.900 HPFQ = 940.370 STSW = 8.117 DEPT = 7770.000 TENS = 3406' SP = -19.990 GR' = 61.100 TEMP = 152.620 LOAD = -87 TSPD = .000 FTPC'= 3405.800 THRS = 37.757 FTP = 3443.100· HYDP = 4941 VOLP = 0 HPRP = 3340.690 FTPR = 3443.100 HPQ '= 3519.550 MTF = 15261.690 HPFQ = 938.167 STSW = 9.122 FILE TRAILER RECORD -w---- ........................ TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.023 --- 1024 --- LO --- LOGIN2.024 ****************************************************************************** FILE HEADER RECORD ....... - ...................... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.024 m_- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.023 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .~500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1' 66 68 16. 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: HNEM DEPT TENS SP GR TEMP LOAD TSPD FTPC THRS 'FTP HYDP VOLP HPRP FTPR HPQ MTF HPFQ STSW SERVID SERVICE# UNITS SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 4'92239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 SFT 492239 API CODE FILE# SIZE #SAMP REPR. F '000000000 49 4 1 68 LBS 000635000 49 2 1 79 MV 001010010 49 4 1 68 API 030310010 49 4 1 68 DEGF 080660020 49 4 1 68 LBS 000000000 49 2 I 79 F/MI 000636000 49 4 i 68 PSI 095000000 49 4 1 68 HRS 000000000 49 4 i 68 PSI 095000000 49 4 1 68 PSI 095000000 49 4 1 73 095000000 49 2 1 79 PSI .000000000 49 4 1 68 CPS 095000000 49 4 1 68 PSI 000000000 49 4 1 68 HZ 080660000 49 4 1 68 KHZ 000000000 49 4 i 68 095000000 49 4 1 68 ******************************************************************************* DATA RECORD TYPE 0 DEPT = 7776.000 TENS = 3431 SP = -19.990 GR = 69.400 TEMP = 152.920 LOAD = -253 TSPD = .000 FTPC = 3419.600 THRS = 37.834 FTP = 3456.800 HYDP = 3472 VOLP = 0 HPRP = 3281.620 FTPR = 3456.800 HPQ = 3444.130 MTF = 15292.470 HPFQ = 930.413 . STSW = 8.115 DEPT = 7776.000 TENS = 3426 SP = -19.990 GR = 54.300 TEMP = 144.870 LOAD = -723 TSPD = .000 FTPC = 1256.900 THRS = 37.861 FTP = 1298.700 HYDP = 4499 VOLP = 0 HPRP = 133.840 FTPR = 1298.700 HPQ = 758.630 MTF = 14486.610 HPFQ = 652.376 STSW = 9.117 DEPT = 7776.000 TENS = 3418 SP = -19.990 GR = 57.300 TEMP = 146.950 LOAD = -260 TSPD = .000 FTPC = 3419.000 THRS = 37.889 FTP = 3455.800 HYDP = 3346 VOLP = 0 HPRP = 3279.420 FTPR = 3455.800 HPQ = 3443.030 MTF = 14694.600 HPFQ = 930.186 STSW = 8.115 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.024 --- 1024 --- LO --- LOGIN2.025 FILE HEADER RECORD ................... - .......... TYPE 128 FILE NAME SERVICE-SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. 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CODE ENTRY 1 66 0 1 66 0 2 79 66 1 66 0 1 66 0 4 68 .500 4 65 S 2 79 15 4 68 -999.250 08I'8C = SEM& 00~'£££Z = DdA~- 000' = QdS& 66I- = QVO~ 0ZL'ENI = ~k~I~ 00L'EN = HD 066'6I- = dS 9~C = SNH~ 00S'9AAA = ~HQ 0EI'6 = MS~S ~LL'~I6 = ~dH' 08I'NOZNI = ~N 09I'E6E~ = ~dH '009'N0~ = Hd~ 0~6'9~IC = ~F~dH · 0 = d~OA 86N~ = dGXM 009'N0~C - d~& ENI'SC = S~H~ 00~'L9gC = Od~ 000' = GdS~ 6I~- = QVO~ 0N0'~§I = ~N~ 00E'0~ = ~D 066'61- = ~S Lg~Z = SN~ 00N'9LLA = ~d~G 0EI'6 = MSZS ~EE'II6 =.0~dH 08N'£0CNI = &AN 089'ANE~ = 0dH 006'L9EZ = Hd~ 080'90Ig = c~IdH 0 = dqOA N09~ = dGXH 006'~9E~ = d~ ~EI'8C = SHH~ 00C'6EEC = Od~& 000' = GdS~ ~g~- = G~O~ 0~0'ZNI = ~ 009'I9 = HD 066'6I- = dS L~Z = SN~ OON'9LL£ = ~d~G NII'8 = MS~S 006'EZ6 = 0&dH 098'LLSNI = ~N 09E'A9~ = 0~M 006'IL~g = Hd~& 0AN'0g~ = ~F~dM 0 = d~OA EEC~ = dQXH 006'IL~ = d~ 960'8~ = Shq4~ 000'N~ = DdZ~ 000' = GdS~ 066'6I- = dS 9N~C = SN~ 00N'9L££ = ~dHO NII'8 = MS~S N9Z'0~6 = O~dH 0L6'66ENI = ~N 0N9'£~ = OdH 009'NN~g = ~d~ 0~I'ISE~ = d%tdH 0 = d~OA 90~C = dGXH 009'NN~ = d~ 890'8C = SH]{~ 00~'8I~g = DE~ 000' = OdS~ L6~- = fU~O~ 000'ENI = ~t~ 00N'EN = ~D 066'6I- = dS 6N~E = SN~ OON'9LLL = ~d~G :SHDO~ NOI~DI~IDHdS 0 99 I 0 I 99 I 9I 89 99 I FTP = 3375.100 HYDP = 4606 VOLP = 0 HPRP = 3362.760 FTPR = 3375.100 HPQ = 3428.110 MTF = 15272.880 HPFQ = 928.761 STSW = 9.116 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.025 --- 1024 --- LO --- LOGIN2.026 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.026 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.025 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3' 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16. 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT SFT TENS SFT 'SERVID SERVICE# UNITS SP SFT GR SFT TEMP SFT LOAD' SFT TSPD SFT FTPC SFT THRS SFT FTP SFT HYDP. SFT VOLP SFT HPRP SFT 492239 F 492239 LBS 492239 MV 492239 API 492239 DEGF 492239 LBS 492239 F/MI 492239 PSI 492239 HRS 492239 PSI 492239 PSI 492239 492239 .PSI API CODE FILE# SIZE #SAMP REPR. 000000000 52 4 1 68 000635000 52 2 1 79 001010010 52 4 1 68 030310010 52 4 1 68 080660020 52 4 1 68 000000000 52 2 1 79 000636000 52 4 1 68 095000000 52 4 1 68 000000000 52 4 1 68 095000000 52 4 1 68 095000000 52 4 1 73 095000000 52 2 1 79 000000000 52 4 1 68 --- aax&.- ...................... (moaau Ua H aTTa t E 0 ' ENIDO~i --- O~i --- ~g0I --- 9E0'ENIO0~I --- 6EI H~A~ .............................. GHODHH~HH~I~fH~ H~I.~ gII'6 = MS~S' SIE'0~6 = O~H 086'SIESI 0~S'6CSC = 0~H 00S'8E~C ='H~&~ 06E'IS~E 0 = ~OA I88~ = ~GAH 00N'SE~g ~9~'8C = SHH~ 00I'I6CC = DE~ 000' ~6I- = GVO~ 09I'EgI = ~k~H~ 0'08'Cg 066'61- = ~S ~9~ = SNH& O0~'9tLt = dH~H = = HD glI'6 = MS~S I~9'~I6 = 0~H 0tS'~I~I 0§8'06E~ = 0~H 000'Z0~Z = H~ 069'g~I~ I = E~OA CLS~ = EGXH 000'g0C~ LCC'8~ = SHH~ 00L'~9EC = D~&~ 000' g9£- = GVO~ 0~I'ZgI = ~I4H~ 00~'I9 066'6I- = ~S Eg~[ = SNH~ O0g'gLL£ = = 6H~H = = = HO = 9II'6 = MS~S 06N'EI6 = O~EH 08C'ClCgI 0~6'0LE£ = 0EH 009'I8E£ = HErE 099'LIIC I = E~OA I889 = EGAH 009'I8EC 0I£'8~ = SHH~ 00I'C~E~ = DE~& 000' 99£- = G~O~ 0EI'EgI = 6[N~ 00I'Sg 066'6I- = ~S E~E = SNH~ O0~'9ttt = 6H~H = GES~ = HD EgE'£ = MS~S E69'I~6 = OEEH 008'I~C~I 0 = E~OA CSgg = ~GAH 00~'t9gC gSg'8~ = SHH~ 006'I~ = D~ 000' 898E- = G~O~ 0E~'~I = ~I4H~ 009'09 066'6I- = ~S 099g = SNH~ 00~'gLt£ = EHEH = GES~ = HD 9II'8 = MS~S 8~E'0~6 = 0&~H 08~'0I~NI 06~'E~9C = OEH 006'C~ = HE&~ 080'08E£ 0 = E~OA tEaC = EGAH 006'~£ ~SE'SC = SHH~ 00L'9I~ = O~&~ 000' ~- = G~O~ 00I'~gI = ~& 00g'~9 066'6I- = ~S L~Z = SNH& 00~'9LLL = HD 0 HEX~ GHODHH ~AVG 89 I ~ EN 000000960 6CEE6~ ~S MSAS 89 I ~ E~ 000000000 ZHH 6CEE6~ ~S ~&H 89 I ~ Eg 000099080 ZH 6CEE6~ ~S ~A~ 89 I 9 Eg 000000000 IS~ 6gEE6~ ~S ~H 89 I 9 E§ 000000960 S~D 6~EE6~ ~S H~ SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. 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CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT~ 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 53 4 1 68 000635000 53 2 1 79 001010010 53 4 1 68 030310010 53 4 1 68 080660020 53 4 1 68 000000000 53 2 1 79 000636000 53 4 1 68 095000000. 53 4 1 68 000000000 53 4 1 68 095000000 53 4 1 68 095000000 53 4 1 73 095000000 53 2 1 79 000000000 53 4 1 68 095000000 53 4 1 68 000000000 53 4 1 68 ~080660000 53 4 1 68 000000000 53 4 1 68 095000000 53 4 1 68 DATA RECORD TYPE 0 DEPT = 7782.000 TENS = 3426 SP = -19.990 GR = 56.300 TEMP = 153.210 LOAD = -514 TSPD = .000 FTPC = 3420.700 THRS = 38.452 FTP = 3457.800 HYDP = 3415 VOLP = 0 HPRP = 3282.920 FTPR = 3457.800 HPQ = 3445.450 MTF =. 15320.940 HPFQ = 930.555 STSW = 8.111 DEPT = 7782.000 TENS = 3425 SP = -19.990 GR = 54.100 TEMP = 153.220 LOAD = -531 TSPD = .000 FTPC = 3419.400 THRS = 38.480 FTP = 3456.600 HYDP = 3415 VOLP = 0 HPRP = 3282.130 FTPR = 3456.600 HPQ = 3444.660 MTF = 15322.070 HPFQ = 930.473 STSW = 8.111 DEPT = 7782.000 TENS = 3421 SP = -19.990 GR = 52.000 TEMP = 153.240 LOAD = -441 TSPD = .000 FTPC = 2716.900 THRS = 38.507 FTP = 2758.700 HYDP = 4903 VOLP = 0 HPRP = 2912.440 FTPR = 2758.700 HPQ = 2966.550 MTF = 15323.570 HPFQ = 881.230 STSW = 9.113 DEPT = 7782.000 TENS = 3423 SP = -19.990 GR = 54.700 TEMP = 153.250 LOAD = -433 TSPD = .000 FTPC = 3241.000 THRS = 38.535 FTP = 3279.500 HYDP = 4889 VOLP = 0 HPRP = 3109.990 FTPR = 3279.500 HPQ = 3264.000 MTF = 15325.270 HPFQ = 911.878 STSW = 9.115 FILE TRAILER'RECORD~ - ............... . .............. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.027 --- 1024 --- LO --- LOGIN2.028 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.028 --- 310 --- 96 --- LOGIN2 .... 1024 --- LO --- LOGIN2.027 DATUM FORMAT SPECIFICATION RECORD ---~ ........... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1~ 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4- 65 FT 15 1 66- 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 54 4 1 68 TENS SFT 492239 LBS 000635000 54 2 1 79 SP SFT 492239 MV 001010010 54 4 1 68 GR SFT 492239 API 030310010 54 4 1 68 TEMP SFT 492239 DEGF 080660020 54 4 1 68 LOAD SFT 492239 LBS 000000000 54 2 1 79 TSPD SFT 492239 F/MI 000636000 54 4 1 68 FTPC SFT 492239 PSI 095000000 54 4 1 68 THRS SFT 492239 HRS 000000000 54 4 1 68 FTP SFT 492239 PSI 095000000 54 4 1 68 HYDP SFT 492239 PSI 095000000 54 4 1 73 VOLP SFT 492239 095000000 54 2 1 79 HPRP SFT 492239 PSI 000000000 54 4 1 68 FTPR SFT 492239 CPS 095000000 54 4 1 68 HPQ SFT 492239 PSI 000000000 54 4 1 68 MTF 'SFT 492239 HZ 080660000 54 4 1 68 HPFQ SFT 492239 KHZ 000000000 54 4 1 68 STSW SFT 492239 095000000 54 4 1 68 DATA RECORD TYPE 0 DEPT = 7785.000 TENS = 3452 SP = -19.990 GR = 43.400 TEMP = 153.300 LOAD = -304 TSPD = .000' FTPC = 3418.800 THRS = 38.611 FTP = 3456.000 HYDP = 3395 VOLP = 0 HPRP = 3282.550 FTPR = 3456.000 HPQ = 3445.060 MTF = 15330.420 HPFQ = 930..516 STSW = 8.110 DEPT = 7785.000 TENS = 3450 SP = -19.990 GR = 53.700 TEMP = 157.490 LOAD = 498 TSPD = .000 FTPC = 3497.800 THRS = 38.639 FTP = 3534.200 HYDP = 4632 VOLP = 0 HPRP = 3358.960 FTPR = 3534.200 HPQ = 3489.420 MTF = 15749.400 HPFQ = 935.156 'STSW = 5.870 DEPT = 7785.000 TENS = 3450 SP = -19.990 GR = 70.900 TEMP = 147.010 LOAD = -161 TSPD = · .000 FTPC = 341'8.200 THRS = 38.666 FTP = 3455.000 HYDP = 3396 VOLP = 0 HPRP = 3279.560 FTPR = 3455.000 HPQ = 3443.300 MTF = 14700.680 HPFQ = 930.215 STSW = 8.112 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.028 --- 1024 --- LO --- LOGIN2.029 FILE HEADER'RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.029 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.028 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 55 4 1 68 TENS SFT 492239 LBS 000635000 55 2 1 79 SP SFT 492239 MV 001010010 55 4 1 68 GR SFT 492239 API 030310010 55 4 1 68 TEMP SFT 492239 DEGF 080660020 55 4 1 68 LOAD SFT 492239 LBS 000000000 55 2 1 79 TSPD SFT 492239 F/MI 000636000 55 4 1 .68 FTPC SFT 492239 PSI 095000000 55 4 1 68 THRS SFT 492239 HRS 000000000 55 4 1 68 FTP SFT 492239 PSI 095000000 55 4 1 68 HYDP SFT 492239 · ,PSI 095000000 55 4 1 73 VOLP SFT 492239 095000000 55 2 1 79 HPRP SFT 492239 PSI~ 000000000 55 4 1 68 FTPR SFT 492239 CPS 095000000 55 4 1 68 HPQ SFT 492239 PSI 000000000 55 4 1 68 MTF SFT 492239 HZ 080660000 55 4 1 68 HPFQ SFT 492239 KHZ 000000000 55 4 1 68 STSW SFT 492239 095000000 55 4 1 68 DATA RECORD TYPE 0 DEPT = 7786.000 TENS = 3482 SP = -19.990 GR = 84.000 TEMP = 153.390 LOAD = -319 TSPD = .000 FTPC = 3420.000 THRS = 38.722 FTP = 3457.200 HYDP = 3402 VOLP = 0 HPRP = 3284.350 FTPR = 3457.200 HPQ = 3446.980 MTF = 15339.450 HPFQ = 930.715 STSW = 8.110 DEPT = -7786.000 TENS = 3474 SP = -19.990 GR = 49.800 TEMP = 154.490 LOAD = -760 TSPD = .000 FTPC = 3321.700 THRS = 38.750 FTP = 3359.600 HYDP = 4519 VOLP = 1 HPRP = 2345.470 FTPR = 3359.600 HPQ = 3180.920 MTF = 15449.410 HPFQ = 903.345 STSW = 9.106 DEPT = 7786.000 TENS = 3467 SP = -19.990 GR = 64.600 TEMP = 146.960 LOAD = -195 TSPD = .000 FTPC = 3417.900 THRS = 38.777 FTP = 3454.700 HYDP = 3389 VOLP = 0 HPRP = 3153.320 FTPR = 3454.700 HPQ = 3311.090 MTF = 14696.290 HPFQ = 916.605 STSW = 8.108 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.029 --- 1024 --- LO --- LOGIN2.030 FILE HEADER RECORD .............................. TYPE 128 FILE NAME --- LOGIN2.030 SERVICE SUB LEVEL NAME --- 310 VERSION NUMBER --- 96 DATE OF GENERATION --- LOGIN2 MAX. PHYSICAL RECORD LENGTH --- 1024 FILE TYPE --- LO OPTIONAL PREVIOUS FILE NAME --- LOGIN2.029 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 ~ 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV API CODE FILE# SIZE 000000000 56 4 000635000 56 2 001010010 56 ~ 4 #SAMP REPR. 1 68 1 79 1 68 GR SFT 492239 API 030310010 56 4 1 68 TEMP SFT 492239 DEGF 080660020 56 4 1 68 LOAD SFT 492239 LBS 000000000 56 2 1 79 TSPD SFT 492239 F/MI 000636000 56 4 1 68 FTPC SFT 492239 PSI 095000000 56 4 1 68 THRS SFT 492239 HRS 000000000 56 4 1 68 FTP SFT 492239 PSI 095000000 56 4 1 68 HYDP SFT 492239 PSI 095000000 56 4 1 73 VOLP SFT 492239 095000000 56 2 1 79 HPRP SFT 492239 PSI 000000000 56 4 1 68 FTPR SFT 492239 CPS 095000000 56 4 1 68 HPQ SFT 492239 PSI 000000000 56 4 1 68 MTF SFT 492239 HZ 080660000 56 4 . 1 68 HPFQ SFT 492239 ~ KHZ 000000000 56 4 1 68 STSW SFT 492239 095000000 56 4 1 68 DATA RECORD TYPE 0 DEPT = 7786.500 TENS = 3487 SP = -19.990 GR = 61.900 TEMP = 153.490 LOAD = -305 TSPD = .000 FTPC = 3417.300 THRS = 38.845 FTP = 3454.500 HYDP = 3390 VOLP = 0 HPRP = 3153'730 FTPR = 3454.500 HPQ = 3309.850 MTF = 15349.480 HPFQ = 916.603 STSW = 8.110 DEPT = 7786.500 TENS = 3462 SP = -19.990 GR = 53.300 TEMP = 157.660 LOAD = 185 TSPD = .000 FTPC = 3448.600 THRS = 38.873 FTP = 3485.400 HYDP = 4503 VOLP = 0 HPRP = 3158.030 FTPR = 3485.400 HPQ = 3313.490 MTF = 15766.250 HPFQ = 917.055 STSW = 8.063 DEPT = 7786.500 TENS = 3459 SP = -19.990 GR = 67.100 TEMP = 147.910 LOAD = -190 TSPD = .000 FTPC 3417.40'0 THRS = 38.901 FTP = 3454.300 HYDP = 3394 VOLP = 0 HPRP = 3279.170 FTPR = 3454.300 HPQ = 3442.530 MTF =~ 14791.100 HPFQ = 930.153 STSW = 8.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME .... LOGIN2.030 --- 1024 --- LO --- LOGIN2.031 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATEOF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.031 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.030 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS APi CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 57 4 1 68 TENS SFT 492239 LBS 000635000 57 2 1 79 SP SFT 492239 MV 001010010 57 4 1 68 GR SFT 492239 API 030310010 57 4 1 68 TEMP SFT 492239 DEGF 080660020 57 4 1 68 LOAD SFT 492239 LBS 000000000 57 2 1 79 TSPD SFT 492239 F/MI 000636000 57 4 1 68 FTPC SFT 492239 PSI 095000000 57 4 1 68 THRS SFT 492239 }{RS 000000000 57 4 1 68 FTP SFT 492239 PSI 095000000 57 4 1 68 HYDP SFT 492239' PSI 095000000 57 4 1 73 VOLP SFT 492239 095000000 57 2 1 79 HPRP SFT 492239 PSI 000000000 57 4 1 68 FTPR SFT 492239 CPS 095000000 57 4 1 68 HPQ SFT 492239 PSI 000000000 57 4 1 68 MTF SFT 492239 HZ 080660000 57 4 1 68 HPFQ SFT 492239 KHZ 000000000 57 4 1 68 STSW SFT 492239 095000000 57 4 1 68 DATA RECORD TYPE 0 DEPT = GR = TSPD = FTP = HPRP = MTF = 7792.000 TENS.= 3518 SP = -19.990 61'.400 TEMP = 153.570 LOAD = -279 .000 FTPC = · 3420.100 THRS = 38.967 3457.300 HYDP = 3394 VOLP = 0 3283.230 FTPR = 3457.300 HPQ = 3445.700 15356.990 HPFQ = 930.587 STSW = 8.108 DEPT = GR = TSPD = FTP =. HPRP = MTF = 7792,.000 TENS = 3518 SP = -19.990 59.000 TEMP = 153.530 LOAD = 1971 .000 FTPC = 3483.700 THRS = 38.995 3520.300 HYDP = 4962 VOLP = 0 3361.280 FTPR = 3520.300 HpQ = 3501.230 15352.620 HPFQ = 936.299 STSW = 7.535 DEPT = 7792.000 TENS = 3504 SP = -19'990 GR = 61.300 TEMP = 153.610 LOAD = -274 TSPD = .000 FTPC = 3233.700 THRS = 39.022 FTP = 3272.300 HYDP = 4770 VOLP = 0 HPRP = 3105.370 FTPR = 3272.300 HPQ = 3258.470 MTF = 15.361.470 HPFQ = 911.315 STSW = 9.112 DEPT = 7792.000 TENS = 3509 SP = -19.990 GR = 54.300 TEMP = 153.630 LOAD = -272 TSPD = .000 FTPC = 3243.900 THRS = 39.050 FTP = 3282.400 HYDP = 4759 VOLP = 0 HPRP = 3113.380 FTPR = 3282.400 HPQ = 3267.490 MTF = 15363.270 HPFQ = 912.245 STSW = 9.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. 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(]HODHH'HHO~HH E~0'ENIOOq --- H]4%fN H~I~ HXHN T~NOIH~O HHDNH~ QHODHH T~DISAH~ 'X~q4 NOIHYHHNHD dO HHSW/1N NOISHHA HN%fN qHAH~ ~S HDIAHHS Hk~fN H~I~ 6EI H6AH .............................. GHODHH HH~IYHH H~I~ gII'8 = MSHS 618'08L = O~4H 06A'L~Z~I 00~'966I = 06H 00E'~9~ = H4H& 08g'968I 0 = ~OA ~I~ = 4GAH 00E'~9~ N0~'65 = SHHH 00I'LE~g = D~H& 000' 8~E- = Q¥O~ 08S'~SI = ~NHH 00£'6S 066'6I- = ~S 08Z~ = SNHH 000'86££ = = 4H~H = = Q~SH = HD. = £II'6 = MSHS 80t'6LA = ~4H- 08N'09g~I 0££'~86I = O~H 00~'69E~ = H~H~ 06~'988I 0 = ~OA 8It~ = ~QAH 00~'69E~ £LE'6~ = SHH~ 008'0£E£ = D~HA 000' 89E- = O%fO~ 019'~NI = ~IH~ 008'0~ 066'6I- = ~S ~SgZ = SNH~ 000'86L£ I60'9 = MSHS 6EI'E$6 = 0~H 0~N'9EIgI 0Eg'8GG~ = 06H 009'I8§~ = H~ 0~9'I0~Z 0 = ~OA 0E0~ = ~QAH 009'I8~ 0GE'6~ = SHH~ .00g'~C = D~A 000' 89E- = O~O~ 0tE'IgI = d]4H~ 00~'Ig 066'6I- = ~S 68~ = SNH~ 000'86LL = = 4H6H = = = HD = = = ~H~H = = = HD = 0II'8 = MS~S 6E6'E£6 = ~H 0Lg'69£NI 099'899~ = 0~H 006'SL~E = H~ 0LS'~0E[ 0 = ~OA 8E~ = ~QAH 006'8L~. EEE'6~ = SHHH 006'I~ = D~H~ 000' N9E- = G~O~ 069'~I = ~H 00N'8~ 066'6I- = 6S E6gZ = SNH~ 000'86£A = &mN = ~HdH = ~H& = Q~SH = HD = H~HQ 0 H~X~ GHODHH ~G 89 I 9 8g 000000~60 6~EE6~ H~S MSAS 89 I ~ 8~ 000000000 ZHH 6ZEE6~ 89 I ~ 8~ 000099080 ZH 6~EE6~ 89 I ~ 8~ 000000000 IS~ 6£EE6~ 89 I ~ 8g 000000960 SdD 6~EE6~ H~S 'H~ 89 I 9 8~ 000000000 IS4 6ZEE6~ H~S d[H4H 6£ I E 8~ 000000~60 6~6~ H~S 4~OA ~£ I ~ 8~ 000000960 IS4 6~6~ 89 I ~ 8g 000000960 IS4 6~EE6~ 89 I 9 8g 000000000 SHH 6~E~6~ H~S SHH~' 89 I 9 8~ 000000~60 ISd 6~EE6~ 89 I 9 8~ 0009Z9000 I~/~ 6£EE6~ 6£ I ~ 8~ 000000000 S~% 6~E6~ ~S ~¥0~ 89 I 9 8~ 0E0099080 89 I 9 8g 0100I~0~0 IdSf 6~EE6~ H~S HD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.033 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.032 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUMSPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR $FT 492239' API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 59 4 1 68 000635000 59 2 1 79 001010010 59 4 1 68 030310010 59 4 1 68' 080660020 59 4 1 68 000000000 59 2 1 79 000636000 , 59 4 1 68 095000000 59 4 1 68 000000000 59 4 1 68 095000000 59 4 1 68 095000000 59 4 1 73 095000000 59 2 1 79 000000000 59 4 1 68 095000000 59 4 1 68 000000000 59 4 1 68 080660000 59 4 1 68 000000000 59 4 1 68 095000000 59 4 1 68 DATA RECORD TYPE 0 DEPT = GR = TSPD. = FTP - HPRP'= MTF = 7798.000 TENS = 3350 SP = -19.990 58.'900 TEMP = 153.560 LOAD = -258 .000 FTPC = 3422.900 THRS = 39.342 3460.000 HYDP = 3419 VOLP = 0 1902.550 FTPR = 3460.000 HPQ = 2000.840 15356'.000 HPFQ = 781.474 STSW = 8.115 DEPT = 7798.000 TENS = 3343 SP = -19.990 GR = 69.100 TEMP = 150.520 LOAD = -261 TSPD = .000 FTPC = 3510.500 THRS = 39.370 FTP = 3546.800 HYDP = 5087 VOLP = 0 HPRP = 1905.790 FTPR = 3546.800 HPQ = 2004.750 MTF = 15052.490 HPFQ = 781.818 STSW = 8.110 DEPT = 7798.000 TENS = 3339 SP = -19.990 GR = 63.600 TEMP = 153.570 LOAD = -255 TSPD = .000 FTPC = 3219.100 THRS = 39.398 FTP = 3257.800 HYDP = 4813 VOLP = 0 HPRP = 2656.450 FTPR = 3257.800 HPQ = 2788.850 MTF = 15356.780 HPFQ = 862.909 STSW = 9.113 DEPT = 7798.000 TENS = 3335 SP = -19.990 GR = 59.700 TEMP = 153.580 LOAD = -252 TSPD = .000 FTPC = 3446.900 THRS = 39.425 FTP = 3483.800 HYDP = 4088 VOLP = 0 HPRP = 3222.930 FTPR = 3483.800 HPQ = 3382.630 MTF = 15357.880 HPFQ = 924.097 STSW = 8.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT' FILE NAME --- LOGIN2.033 --- 1024 --- LO --- LOGIN2.034 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE-OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUSFILE NAME --- LOGIN2.034 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.033 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR, CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 60 4 1 68 TENS SFT 492239 LBS 000635000 60 2 1 79 SP SFT 492239 MV 001010010 60 4 1 68 GR SFT 492239 API ~ 030310010 60 4 1 68 TEMP SFT 492239 DEGF 080660020 60 4 1 68 LOAD SFT 492239 LBS 000000000 60 2 1 79 TSPD SFT 492239' F/MI 000636000 60 4 1 68 FTPC SFT 492239 PSI 095000000 60 4 1 68 THRS SFT 492239 }{RS 000000000 60 4 1 68 FTP SFT 492239 PSI 095000000 60 4 1 68 HYDP SFT 492239 PSI 095000000 60 4 1 73 VOLP SFT 492239 095000000 60 2 1 79 'HPRP SFT 492239 PSI 000000000 60 4 1 68 FTPR SFT 492239 CPS 095000000 60 4 1 68 HPQ SFT 492239 PSI 000000000 60 4 1 68 MTF SFT 492239 HZ 080660000 60 4 1 68 HPFQ SFT 492239 KHZ 000000000 60 4 1 68 STSW SFT 492239 095000000 60 4 1 68 DATA RECORD TYPE 0 DEPT = 7803.500 TENS = 3374 SP = -19.990 GR = 65.800 TEMP = 153.670 LOAD = -370 TSPD = .000 FTPC = 3429.000 THRS = 39.560 FTP = 3466.100 HYDP = 3387 VOLP = 0 HPRP = 3219.630 FTPR = 3466.100 HPQ = 3379.010 MTF = 15366.650 HPFQ = 923.726 STSW = 8.110 DEPT = 7803.500 TENS = 3359 SP = -19.990 GR = 72.000 TEMP = 145.940 LOAD = -569 TSPD = .000, FTPC = 3550.800 THRS = 39.588 FTP = 3586.500 HYDP = 5177 VOLP = 0 HPRP = 3220.130 FTPR = 3586.500 HPQ = 3380.860 MTF = 14593.840 HPFQ = 923.767 STSW = 8.840 DEPT = 7'803.500 TENS = 3350 SP = -19.990 GR = 72.800 TEMP = 149.230 LOAD = -169 TSPD = .000 FTPC = 3421.400 THRS = 39.616 FTP = 3458.400- HYDP = 3421 VOLP = 0 HPRP = 3282.790' FTPR = 3458.400 HPQ = 3446.300 MTF = 14922.590 HPFQ'= 930.567 STSW = 8.110 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL'NEXT FILE NAME LOGIN2.034 --- 1024 --- LO --- LOGIN2.035 FILE HEADER RECORD -- FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.035 --- 310 ---,96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.034 TYPE 128 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1- 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239' DEGF LOAD SFT 4922'39 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 61 4 1 68 000635000 61 2 1 79 001010010 61 4 1 68 030310010 61 4 1 68 080660020 61 4 1 68 000000000 61 2 1 79 000636000 61 4 1 68 095000000 , 61 4 1 68 000000000 61 4 1 68 095000000 61 4 1 68 095000000 61 4 1 73 095000000 61 2 1 79 000000000 61 4 1 68 095000000 61 4 1 68 000000000 61 4 1 68 080660000 61 4 1 68 000000000 61 4 1 68 095000000 61 4 1 68 DATA RECORD~ TYPE 0 DEPT = 7808.000 TENS = 3461 SP = -19.990 GR = 64.500 TEMP = 153.71'0 LOAD = -253 TSPD = ~,000 FTPC = 3422.300 THRS = 39.684 FTP = 3459.400 HYDP = 34310 VOLP = 0 HPRP = 3286.830 FTPR = 3459.400 HPQ = 3449.490 MTF = 15370.980 HPFQ = 930.980 STSW = 8.110 DEPT = 7808.000 TENS = 3399 SP = -19.990 GR = 53.800 TEMP = 152.270 LOAD = -209 TSPD = .000 FTPC ' 3537.900 THRS = 39.711 FTP = 3574.100 HYDP = 5031 VOLP = 0 HPRP = 3377.160 FTPR = 3574.100 HPQ = 3541.870 MTF = 15227.270 HPFQ = 940.456 STSW = 9.074 DEPT = 7808.000 TENS = 3394 SP = -19.990 GR = 61.900 TEMP = 153.750 LOAD = -247 TSPD = .000 FTPC = 3422.200 THRS = 39.739 FTP = 3459.300 HYDP = 3368 VOLP = 0 HPRP = 3080.910 FTPR = 3459.300 HPQ = 3233.560 MTF = 15374.670 HPFQ = 908.753 STSW = 8.108 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.035 --- 1024 --- LO --- LOGIN2.036 FILE HEADER-RECORD .............................. TYPE 128 FILE NAME- SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.036 --- 310 --- 96 --- LOGIN2 --- 1024 m~ LO --- LOGIN2.035 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE 1 2 3 4 5 8 9 11 12 14 15 .16~ 0 SIZE REPR. CODE ENTRY if 66 0 1 66 2 79 66 1 66 0 1 66 0 4 68 .500 4 65 S 2~ 79 15 4 68 -999.250 4 65 FT 1 66 68 I 66 1 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F API CODE FILE# 000000000 62 SIZE #SAMP REPR. 4 1 68 TENS SFT 492239 LBS 000635000 62 2 1 79 SP SFT 492239 MV 001010010 62 4 1 68 GR SFT 492239 API. 030310010 62 4 1 68 TEMP SFT 492239 DEGF 080660020 62 4 1 68 LOAD SFT 492239 LBS 000000000 62 2 1 79 TSPD SFT 492239 F/MI 000636000 62 4 1 68 FTPC SFT 492239 PSI 095000000 62 4 1 68 THRS SFT 492239 HRS 000000000 62 4 1 68 FTP SFT 492239 PSI 095000000 62 4 1 68 HYDP SFT 492239 PSI 095000000 62 4 1 73 VOLP SFT 492239 095000000 62 2 1 79 HPRP SFT 492239 PSI 000000000 62 4 1 68 FTPR SFT 492239 CPS 095000000 62 4 1 68 HPQ SFT 492239 PSI 000000000 62 4 1 68 MTF SFT 492239 HZ 080660000 62 4 1 68 HPFQ SFT 492239 KHZ 000000000 62 4 1 68 STSW SFT 492239 095000000 62 4 1 68 DATA RECORD TYPE 0 DEPT = 7832.000 TENS = 3446 SP = -19.990 GR = 66.200 TEMP = 153.800 LOAD = -348 TSPD = .000 FTPC = 3437.200 THRS = 39.805 'FTP = 3474.200 HYDP = 3430 VOLP = 0 HPRP = 3086.710 FTPR = 3474.200 HPQ = 3239.510 MTF = 15379.970 HPFQ = 909.366 STSW = 8.109 DEPT = 7832.000 TENS = 3423 SP = -19.990 GR = 62.700 TEMP = 154.170 LOAD = -315 TSPD = .000 FTPC = 3520.200 THRS = 39.833 FTP = 3556.500 HYDP = 5009 VOLP = 0 HPRP = 3089.650 FTPR = 3556.500 HPQ = 3242.330 MTF = 15417.270 HPFQ = 909.664 STSW = 2.025 DEPT = 7832.000 TENS = 3426 SP = -19.990 GR = 79.300 TEMP = 153.850 LOAD = -312 TSPD = .000 FTPC = 3242.100 THRS = 39.861 FTP = 3280.600 HYDP = 4883 VOLP = 0 HPRP = 3110.760 FTPR = 3280.600 HPQ = 3264.720 MTF = 15385.080 HPFQ = 911.963 STSW = 9.113 DEPT = 7832.000 TENS = 3423 SP = -19.990 GR = 59.000 TEMP = 153.880 LOAD = -279 TSPD = ~ .000~ FTPC = 3431.200 THRS = 39.888 FTP = 34'68.300 HYDP = 3403 VOLP = 0 HPRP = 3292.850 FTPR = 3468.300 HPQ = 3455.780 MTF = 15387.680 HPFQ = 931.630 STSW = 8.109 FILE TRAILER RECORD ......................... - .... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.036 --- 1024 --- LO --- LOGIN2.037 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSIONNUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.037 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.036 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE S~ZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 63 4 1 68 TENS SFT 492239 LBS 000635000 63 2 1 79 SP SFT 492239 MV 001010010 63 4 1 68 GR SFT 492239 API 030310010 63 4 1 68 TEMP SFT 492239 DEGF 0806600'20 63 4 1 68 LOAD SFT 492239 LBS 000000000 63 2 1 79 TSPD SFT 492239 F/MI 000636000 63 4 1 68 FTPC SFT 492239 PSI 095000000 63 4 1 68 THRS SFT 492239 }{RS 000000000 63 4 1 68 FTP SFT 492239 PSI 095000000 63 4 1 68 HYDP SFT 492239 PSI 095000000 63 4 1 73 VOLP SFT 492239 095000000 63 2 1 79 HPRP SFT 492239 PSI 000000000 63 · 4 1 68 FTPR SFT 492239 CPS 095000000 63 4 1 68 HPQ SFT 492239 PSI 000000000 63 4 1 68 MTF SFT 492239 HZ 080660000 63 4 1 68 HPFQ SFT 492239 KHZ 000000000 63 4 1 68 STSW SFT 492239 095000000 63 4 1 68 DATA RECORD TYPE 0 DEPT = 7836.000 TENS = 3504 SP = -19.990 GR = 78.400 'TEMP = 153.910 LOAD = -329 TSPD = .000 FTPC~= 3430.800 THRS = 39.921 FTP = 3467.900 HYDP = 3549 VOLP = 0 HPRP = 3294.200 FTPR = 3467.900 HPQ = 3457.130 MTF = 15391.460 HPFQ = 931.769 STSW = 8.108 DEPT = 7836.000 TENS = 3501 SP = -19.990 GR = 79.800 TEMP = 153.930 LOAD = -319 TSPD = .000 FTPC = 2363.300 THRS = 39.949 FTP = 2406.500 HYDP = 4934 VOLP = 1 HPRP = 2345.770 FTPR = 2406.500 HPQ = 2422.370 MTF = 15393.470 HPFQ = 825.076 STSW = 9.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.037 --- 1024 ~--~ LO --- LOGIN2.038 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.038 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.037 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI API CODE FILE# SIZE 000000000 64 4 000635000 64 2 001010010 64 4 030310010 64 4 080660020 64 4 000000000 64 2 000636000 64 4 '095000000 64 4 #SAMP REPR. 1 68 1 79 1 68 1 68 1 68 1 79 1 68 1 68 THRS SFT 492239 HRS 000000000 64 4 1 68 FTP SFT 492239 PSI 095000000 64 4 1 68 HYDP SFT 492239 PSI 095000000 64 4 1 73 VOLP SFT 492239 095000000 64 2 1 79 HPRP SFT 492239 PSI 000000000 64 4 1 68 FTPR SFT 492239 CPS 095000000 64 4 1 68 HPQ SFT 492239 PSI 000000000 64 4 1 68 MTF SFT 492239 HZ 080660000 64 4 1 68 HPFQ SFT 492239 KHZ 000000000 64 4 1 68 STSW SFT 492239 095000000 64 4 1 68 DATA RECORD TYPE 0 DEPT = 7835.500 TENS = 3489 SP = -19.990 GR = 69.600 TEMP = 153.990 LOAD = -273 TSPD = .000 FTPC = 3427.900 THRS = 40.005 FTP = 3465.000 HYDP = 3433 VOLP = 0 HPRP = 3293.790 FTPR = 3465.000 HPQ = 3456.730 MTF = 15398.950 HPFQ = 931.730 STSW = 8.108 DEPT = 7835.500 TENS = 3474 SP = -19.990 GR = 53.200 TEMP = 149.990 LOAD = -331 TSPD = .000 FTPC = 3520.100 THRS = 40.033 FTP = 3556.300 HYDP = 5128 VOLP = 1 HPRP = 3308.160 FTPR = 3556.300 HPQ = 3520.190 MTF = 14998.870 HPFQ = 938.183 STSW = 9.109 DEPT = 7835.500 TENS = 3472 SP = -19.990 GR = 72.100 TEMP = 148.240 LOAD = -157 TSPD = .000 FTPC = 3429.900 THRS = 40.060 FTP = 3466.700 HYDP = 3430 VOLP = 0 HPRP = 3288.470 FTPR = 3466.700 HPQ = 3452.370 MTF = 14823.780 HPFQ = 931.172 STSW = 8.108 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.038 --- 1024 --- LO --- LOGIN2.039 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.039 --- 310 ---96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.038 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE 1 1 66 2 1 66 3 2 79 4 1 66 5 1 66 8 4 68 9 4 65 11 2 79 12 4 68 14 4 65 15 1 66 16 1 66 0 1 66 ENTRY 0 0 66 0 0 .500 S 15 -999.250 FT 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 67 4 1 68 000635000 67 2 1 79 001010010 67 4 1 68 030310010 67 4 1 68 080660020 67 4 1 68 000000000 67 2 1 79 000636000 67 4 1 68 095000000 67 4 1 68 000000000 67 4 1 68 095000000 67 4 1 68 095000000 67 4 1 73 095000000 67 2 1 79 000000000 67 4 1 68 095000000 67 4 1 68 000000000 67 4 1 68 080660000 67 4 1 68 000000000 67 4 1 68 095000000 67 4 1 68 DATA RECORD TYPE 0 DEPT = 8000.500 TENS = GR = - 52.300 TEMP = TSPD = .000 FTPC = FTP = 3557.300 HYDP = HPRP = 3386.330 FTPR = MTF = 15586.600 HPFQ = 3633 SP = -19.990 155.870 LOAD = -222 3521.000 THRS = 40.836 3573 VOLP = 0 3557.300 HPQ = 3553.550 941.724 STSW = 7.112 DEPT = 8000.500 TENS = GR = 52.400 TEMP = TSPD = .000 FTPC = FTP = 3614.900 HYDP = HPRP = 3434.390 FTPR = MTF = 15535.200 HPFQ = 3628 SP = -19.990 155.350 LOAD = -187 3579.100 THRS = 40.863 4713 VOLP = 0 3614.900 HPQ = 3588.560 945.315 STSW = 9.023 DEPT = 8000.500 TENS = GR = 53.700 TEMP = TSPD = .000 FTPC = FTP = 3258.400 HYDP = HPRP = 3089.690 FTPR = 3635 SP = -19.990 155.950 LOAD = -220 3219.700 THRS = 40.891 4517 VOLP = 0 3258.400 HPQ = 3242.150 MTF = 15594.850 HPFQ = 909.678 STSW = 9.116 DEPT = 8000.500 TENS = 3635 SP = -19.990 GR = 58.300 TEMP = 148.640 LOAD = -115 TSPD = .000 FTPC = 3505.400 THRS = 40.919 FTP = 3541.700 HYDP = 3374 VOLP = 0 HPRP = 3361.350 FTPR = 3541.700 HPQ = 3528.670 MTF = 14863.880 HPFQ = 939.029 STSW = 8.110 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.039 --- 1024 --- LO --- LOGIN2.040 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.040 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.039 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT SFT 492239 TENS SFT 492239 SP SFT 492239 GR SFT 492239 TEMP SFT 492239 LOAD SFT 492239 TSPD SFT 492239 SERVID SERVICE# UNITS F LBS MV API DEGF LBS F/MI API CODE FILE# SIZE 000000000 68 4. 000635000 68 2 001010010 68 4 030310010 68 4 080660020 68 4 000000000 68 2 000636000 6.8 4 #SAMP REPR. 1 68 1 79 1 68 1 68 1 68 1 79 1 68 FTPC SFT 492239 PSI 095000000 68 4 1 68 THRS SFT 492239 HRS 000000000 68 4 1 68 FTP SFT 492239 PSI 095000000 68 4 1 68 HYDP SFT 492239 PSI 095000000 68 4 1 73 VOLP SFT 492239 095000000 68 2 1 79 HPRP SFT 492239 PSI 000000000 68 4 1 68 FTPR SFT 492239 CPS 095000000 68 4 1 68 HPQ SFT 492239 PSI 000000000 68 4 1 68 MTF SFT 492239 HZ 080660000 68 4 1 68 HPFQ SFT 492239 KI{Z 000000000 68 4 1 68 STSW SFT 492239 095000000 68 4 1 68 DATA RECORD TYPE 0 DEPT = 8002.500 TENS = 3493 SP = -19,990 GR = 76,400 TEMP = 156,100 LOAD = -233 TSPD = ,000 FTPC = 3499,400 THRS = 40.977 FTP = 3535,900 HYDP = 3530 VOLP = 0 HPRP = 3361,700 FTPR = 3535,900 HPQ = 3527.620 MTF = 15609,980 HPFQ = 939,061 STSW = 8.112 DEPT = 8002,500 TENS = 3491 SP = -19.990 GR = 62,100 TEMP = 157,710 LOAD = -497 TSPD = ,000 FTPC = 3533,200 THRS = 41.005 FTP = 3569,300 HYDP = 4556 VOLP = 0 HPRP = 3411,600 FTPR = 3569,300 HPQ = 3561,320 MTF = 15770,860 HPFQ = 942,556 STSW = 8.110 DEPT = 8002,500 TENS = 3487 SP = -19,990 GR = 63,800 TEMP = 156,180 LOAD = -231 TSPD = ,000 FTPC = 3217,300 THRS = 41.032 FTP = 3256,000 HYDP = 4529 VOLP = 1 HPRP = 3090,310 FTPR = 3256,000 HPQ = 3242.760 MTF = 15618,470 HPFQ = 909,745 STSW = 9.115 DEPT = 8002,500 TENS = .3485 SP = -19.990 GR = 52,300 TEMP'= 156,230 LOAD = -227 TSPD = ,000 FTPC = 3546,000 THRS = 41,060 FTP = 3582,100 HYDP = 4532 VOLP = 0 HPRP = 3406,090 FTPR = 3582,100 HPQ = 3574.310 MTF = 15623,170 HPFQ = 943,865 STSW = 9,115 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX, PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LoGIN2,040 --- 1024 --- LO --- LOGIN2.041 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER --- LOGIN2,041 ~--- 310 --- 96 DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2 --- 1024 --- LO --- LOGIN2.040 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 1 5 1 66 1 8 4 68 .500 9 4 65 FT 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 70 4 1 68 000635000 70 2 1 79 001010010 70 4 1 68 030310010 70 4 1 68 080660020 70 4 1 68 000000000 70 2 1 79 000636000 70 4 1 68 095000000 70 4 1 68 000000000 70 4 1 68 095000000 70 4 1 68 095000000 70 4 1 73 095000000 70 2 1 79 000000000 70 4 1 68 095000000 70 4 1 68 000000000 70 4 1 68 080660000 70 4 1 68 000000000 70 4 1 68 095000000 70 4 1 68 DATA RECORD TYPE 0 DEPT = 8056.200 TENS = 3611 SP = .000 GR = .000 TEMP = .000 LOAD = 0 TSPD = 22.000 FTPC = .000 THRS = 41.221 FTP = .000 HYDP = 0 VOLP = 0 HPRP = .000 FTPR = 14.700 HPQ = .000 MTF = 431.000 HPFQ = .000 STSW = .000 DEPT = 8006.200 TENS = 3750 SP = -19.990 GR = 38.500 TEMP = 5.220 LOAD = 27 TSPD = 21.500 FTPC = 2568.300 THRS = 41.259 FTP = 14.900 HYDP = 28 VOLP = 0 HPRP = .000 FTPR = 14.900 HPQ = .000 MTF = 512.510 HPFQ = 563.281 STSW = -.019 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.041 --- 1024 --- LO --- LOGIN2.042 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.042 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.041 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THR$ SFT 492239 }{RS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS API CODE FILE# SIZE #SAMP REPR. 000000000 71 4 1 68 000635000 71 2 1 79 001010010 71 4 1 68 030310010 71 4 1 68 080660020 71 4 1 68 000000000 71 2 1 79 000636000 71 4 1 68 095000000 71 4 1 68 000000000 71 4 1 68 095000000 71 4 1 68 095000000 71 4 1 73 095000000 71 2 1 79 000000000 71 4 1 68 095000000 71 4 1 68 HPQ SFT 492239 PSI 000000000 71 4 1 68 MTF SFT 492239 HZ 080660000 71 4 1 68 HPFQ SFT 492239 KHZ 000000000 71 4 1 68 STSW SFT 492239 095000000 71 4 1 68 DATA RECORD TYPE 0 DEPT = 8006.000 TENS = 3616 SP = -19.990 GR = 44.200 TEMP = 156.720 LOAD = -224 TSPD = .000 FTPC = 3499.300 THRS = 41.368 FTP = 3535.800 HYDP = 3538 VOLP = 0 HPRP = 3361.530 FTPR = 3535.800 HPQ = 3527.390 MTF = 15672.470 HPFQ = 939.048 STSW = 7.113 DEPT = 8006.000 TENS = 3613 SP = -19.990 GR = 61.200 TEMP = 154.740 LOAD = -3799 TSPD = .000 FTPC = 3582.300 THRS = 41.396 FTP = 3618.100 HYDP = 4762 VOLP = 0 HPRP = 3452.500 FTPR = 3618.100 HPQ = 3597.200 MTF = 15474.370 HPFQ = 946.192 STSW = 7.660 DEPT = 8006.000 TENS = 3609 SP = -19.990 GR = 50.200 TEMP = 156.820 LOAD = -224 TSPD = .000 FTPC = 3225.300 THRS = 41.424 FTP = 3263.900 HYDP = 4547 VOLP = 0 HPRP = 3091.170 FTPR = 3263.900 HPQ = 3243.540 MTF = 15681.970 HPFQ = 909.837 STSW = 9.118 DEPT = 8006.000 TENS = 3602 SP = -19.990 GR = 53.400 TEMP = 156.860 LOAD = -221 TSPD = .000 FTPC = 3230.600 THRS = 41.451 FTP = 3269.200 HYDP = 4537 VOLP = 0 HPRP = 3094.260 FTPR = 3269.200 HPQ = 3246.820 MTF = 15685.860 HPFQ = 910.176 STSW = 9.116 DEPT = 8006.000 TENS = 3601 SP = -19.990 GR = 59.900 TEMP = 153.510 LOAD = -97 TSPD = .000 FTPC = 3535.100 THRS = 41.479 FTP = 3571.300 HYDP = 3423 VOLP = 0 HPRP = 3151.750 FTPR = 3571.300 HPQ = 3307.500 MTF = 15350.630 HPFQ = 916.362 STSW = 8.112 FILE TRAILER RECORD --- ........................... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.042 --- 1024 --- LO --- LOGIN2.043 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME --- LOGIN2.043 --- 310 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.042 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP $FT 492239 PSI VOLP $FT 492239 HPRP SFT 492239 PSI FTPR $FT 492239 CPS HPQ SFT 492239 PSI MTF $FT 492239 HZ HPFQ SFT 492239 KHZ STSW $FT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 72 4 1 68 000635000 72 2 1 79 001010010 72 4 1 68 030310010 72 4 1 68 080660020 72 4 1 68 000000000 72 2 1 79 000636000 72 4 1 68 095000000 72 4 1 68 000000000 72 4 1 68 095000000 72 4 1 68 095000000 72 4 1 73 095000000 72 2 1 79 000000000 72 4 1 68 095000000 72 4 1 68 000000000 72 4 1 68 080660000 72 4 1 68 000000000 72 4 1 68 095000000 72 4 1 68 DATA RECORD TYPE 0 DEPT = 8009.000 TENS = GR = 52.400 TEMP = TSPD = .000 FTPC = FTP = 3530.600 HYDP = HPRP = 3160.930 FTPR = MTF = 15694.460 HPFQ = 3504 SP = -19.990 156.940 LOAD = -227 3494.100 THRS = 41.532 3516 VOLP = 0 3530.600 HPQ = 3316.810 917.383 STSW = 8.112 DEPT = 8009.000 TENS = GR = 53.000 TEMP = TSPD = .000 FTPC = 3500 SP = -19.990 153.590 LOAD = -2453 3572.400 THRS = 41.560 FTP = 3608.300 HYDP = 5121 VOLP = 0 HPRP = 3165.250 FTPR = 3608.300 HPQ = 3321.800 MTF = 15358.670 HPFQ = 917.836 STSW = 7.354 DEPT = 8009.000 TENS = 3499 SP = -19.990 GR = 52.500 TEMP = 156.990 LOAD = -224 TSPD = .000 FTPC = 3494.300 THRS = 41.588 FTP = 3530.800 HYDP = 3375 VOLP = 0 HPRP = 3347.880 FTPR = 3530.800 HPQ = 3513.100 MTF = 15699.060 HPFQ = 937.583 STSW = 8.111 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.043 --- 1024 t~ LO --- LOGIN2.044 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.044 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.043 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 I 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API ' TEMP SFT 492239 DEGF API CODE FILE# 000000000 73 000635000 73 001010010 73 030310010 73 080660020 73 SIZE 4 2 4 4 4 ~SAMP REPR. 1 68 1 79 1 68 1 68 1 68 LOAD SFT 492239 LBS 000000000 73 2 1 79 TSPD SFT 492239 F/MI 000636000 73 4 1 68 FTPC SFT 492239 PSI 095000000 73 4 1 68 THRS SFT 492239 HRS 000000000 73 4 1 68 FTP SFT 492239 PSI 095000000 73 4 1 68 HYDP SFT 492239 PSI 095000000 73 4 1 73 VOLP SFT 492239 095000000 73 2 1 79 HPRP SFT 492239 PSI 000000000 73 4 1 68 FTPR SFT 492239 CPS 095000000 73 4 1 68 HPQ SFT 492239 PSI 000000000 73 4 1 68 MTF SFT 492239 HZ 080660000 73 4 1 68 HPFQ SFT 492239 KHZ 000000000 73 4 1 68 STSW SFT 492239 095000000 73 4 1 68 DATA RECORD TYPE 0 DEPT = 8012.000 TENS = 3656 SP = -19.990 GR = 70.600 TEMP = 157.040 LOAD = -231 TSPD = .000 FTPC = 3494.800 THRS = 41.646 FTP = 3531.300 HYDP = 3471 VOLP = 0 HPRP = 3357.510 FTPR = 3531.300 HPQ = 3523.120 MTF = 15704.300 HPFQ = 938.615 STSW = 8.110 DEPT = 8012.000 TENS = 3606 SP = -19.990 GR = 48.300 TEMP = 150.160 LOAD = -285 TSPD = .000 FTPC = 3585.200 THRS = 41.674 FTP = 3620.900 HYDP = 5223 VOLP = 1 HPRP = 3434.050 FTPR = 3620.900 HPQ = 3601.510 MTF = 15015.690 HPFQ = 946.550 STSW = 9.115 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.044 --- 1024 --- LO --- LOGIN2.045 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSIONNUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.045 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.044 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REpR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 74 4 1 68 TENS SFT 492239 LBS 000635000 74 2 1 79 SP SFT 492239 MV 001010010 74 4 1 68 GR SFT 492239 API 030310010 74 4 1 68 TEMP SFT 492239 DEGF 080660020 74 4 1 68 LOAD SFT 492239 LBS 000000000 74 2 1 79 TSPD SFT 492239 F/MI 000636000 74 4 1 68 FTPC SFT 492239 PSI 095000000 74 4 1 68 THRS SFT 492239 HRS 000000000 74 4 1 68 FTP SFT 492239 PSI 095000000 74 4 1 68 HYDP SFT 492239 PSI 095000000 74 4 1 73 VOLP SFT 492239 095000000 74 2 1 79 HPRP SFT 492239 PSI 000000000 74 4 1 68 FTPR SFT 492239 CPS 095000000 74 4 1 68 HPQ SFT 492239 PSI 000000000 74 4 1 68 MTF SFT 492239 HZ 080660000 74 4 1 68 HPFQ SFT 492239 KHZ 000000000 74 4 1 68 STSW SFT 492239 095000000 74 4 1 68 DATA RECORD TYPE 0 DEPT = 8016.000 TENS = 3590 SP = -19.990 GR = 67.000 TEMP = 157.110 LOAD = -230 TSPD = .000 FTPC = 3496.800 THRS = 41.746 FTP = 3533.300 HYDP = 3507 VOLP = 0 HPRP = 3361.010 FTPR = 3533.300 HPQ = 3526.790 MTF = 15711.340 HPFQ = 938.994 STSW = 8.115 DEPT = 8016.000 TENS = 3584 SP = -19.990 GR = 54.600 TEMP = 146.930 LOAD = -230 TSPD = .000 FTPC = 3634.000 THRS = 41.774 FTP = 3669.100 HYDP = 5101 VOLP = 0 HPRP = 3490.340 FTPR = 3669.100 HPQ = 3647.880 MTF = 14693.010 HPFQ = 951.255 STSW = 9.115 DEPT = 8016.000 TENS = 3584 SP = -19.990 GR = 53.500 TEMP = 157.160 LOAD = -228 TSPD = .000 FTPC = 3220.800 THRS = 41.801 FTP = 3259.400 HYDP = 4894 VOLP = 1 HPRP = 3093.310 FTPR = 3259.400 HPQ = 3245.760 MTF = 15716.470 HPFQ = 910.072 STSW = 9.115 DEPT = 8016.000 TENS = 3581 $P = -19.990 GR = 60.600 TEMP = 153.550 LOAD = -107 TSPD = .000 FTPC = 3556.000 THRS = 41.829 FTP = 3592.000 HYDP = 3449 VOLP = 0 HPRP = 3358.360 FTPR = 3592.000 HPQ = 3549.150 MTF = 15355.270 HPFQ = 941.229 STSW = 8.110 DEPT = 8016.000 TENS = 3577 SP = -19.990 GR = 56.200 TEMP = 157.210 LOAD = -221 TSPD = .000 FTPC = 3493.600 THRS = 41.857 FTP = 3530.100 HYDP = 3352 VOLP = 0 HPRP = 3357.920 FTPR = 3530.100 HPQ = 3523.490 MTF = 15721.170 HPFQ = 938.656 STSW = 8.110 FILE TRAILER RECORD ..... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.045 --- 1024 --- LO --- LOGIN2.046 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.046 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.045 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM sPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API API CODE FILE# 000000000 75 000635000 75 001010010 75 030310010 75 SIZE 4 2 4 4 #SAMP REPR. 1 68 1 79 1 68 1 68 TEMP SFT 492239 DEGF 080660020 75 4 1 68 LOAD SFT 492239 LBS 000000000 75 2 1 79 TSPD SFT 492239 F/MI 000636000 75 4 1 68 FTPC SFT 492239 PSI 095000000 75 4 1 68 THR$ SFT 492239 HRS 000000000 75 4 1 68 FTP SFT 492239 PSI 095000000 75 4 1 68 HYDP SFT 492239 PSI 095000000 75 4 1 73 VOLP SFT 492239 095000000 75 2 1 79 HPRP SFT 492239 PSI 000000000 75 4 1 68 FTPR SFT 492239 CPS 095000000 75 4 1 68 HPQ SFT 492239 PSI 000000000 75 4 1 68 MTF SFT 492239 HZ 080660000 75 4 1 68 HPFQ SFT 492239 K~Z 000000000 75 4 1 68 STSW SFT 492239 095000000 75 4 1 68 DATA RECORD TYPE 0 DEPT = 8020.000 TENS = 3609 SP = -19.990 GR = 48.100 TEMP = 157.270 LOAD = -225 TSPD = .000 FTPC = 3495.400 THRS = 41.928 FTP = 3531.900 HYDP = 3528 VOLP = 0 HPRP = 3361.560 FTPR = 3531.900 HPQ = 3527.330 MTF = 15727.140 HPFQ = 939.052 STSW = 8.110 DEPT = 8020.000 TENS = 3552 SP = -19.990 GR = 44.400 TEMP = 157.290 LOAD = -224 TSPD = .000 FTPC = 3496.800 THRS = 41.956 FTP = 3533.200 HYDP = 3528 VOLP = 0 HPRP = 3362.600 FTPR = 3533.200 HPQ = 3528.380 MTF = 15729.360 HPFQ = 939.160 STSW = 8.110 DEPT = 8020.000 TENS = 3552 SP = -19.990 GR = 61.000 TEMP = 157.260 LOAD = -465 TSPD = .000 FTPC = 3521.300 THRS = 41.984 FTP = 3557.500 HYDP = 4443 VOLP = 0 HPRP = 3381.440 FTPR = 3557.500 HPQ = 3538.790 MTF = 15725.550 HPFQ = 940.231 STSW = 8.110 DEPT = 8020.000 TENS = 3550 SP = -19.990 GR = 57.200 TEMP = 157.340 LOAD = -221 TSPD = .000 FTPC = 3220.200 THRS = 42.011 FTP = 3258.800 HYDP = 5249 VOLP = 1 HPRP = 3091.980 FTPR = 3258.800 HPQ = 3244.290 MTF = 15733.850 HPFQ = 909.924 STSW = 9.087 DEPT = 8020.000 TENS = 3548 SP = -19.990 GR = 49.300 TEMP = 147.240 LOAD = 45 TSPD = .000 FTPC = 3616.800 THRS = 42.039 FTP = 3652.100 HYDP = 5245 VOLP = -1 HPRP = 3476.440 FTPR = 3652.100 HPQ = 3642.080 MTF = 14724.190 HPFQ = 950.665 STSW = 9.091 DEPT = 8020.000 TENS = 3549 SP = -19.990 GR = 60.500 TEMP = 157.390 LOAD = -219 TSPD = .000 FTPC = 3493.500 THRS = 42.067 FTP = 3530.000 HYDP = 3369 VOLP = 0 HPRP = 3353.740 FTPR = 3530.000 HPQ = 3519.080 MTF = 15738.550 HPFQ = 938.206 STSW = 8.110 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL'RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.046 --- 1024 --- LO --- LOGIN2.047 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.047 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.046 ****************************************************************************** ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 }{RS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ API CODE FILE# SIZE #SAMP REPR. 000000000 76 4 1 68 000635000 76 2 1 79 001010010 76 4 1 68 030310010 76 4 1 68 080660020 76 4 1 68 000000000 76 2 1 79 000636000 76 4 1 68 095000000 76 4 1 68 000000000 76 4 1 68 0'95000000 76 4 1 68 095000000 76 4 1 73 095000000 76 2 1 79 000000000 76 4 1 68 095000000 76 4 1 68 000000000 76 4 1 68 080660000 76 4 1 68 HPFQ SFT 492239 KHZ 000000000 76 4 1 68 STSW SFT 492239 095000000 76 4 1 68 DATA RECORD TYPE 0 DEPT = 8025.000 TENS = 3679 SP = -19.990 GR = 52.300 TEMP = 157.480 LOAD = -275 TSPD = .000 FTPC = 3503.100 TI{RS = 42.180 FTP = 3539.500 HYDP = 3539 VOLP = 0 HPRP = 3365.680 FTPR = 3539.500 HPQ = 3531.580 MTF = 15747.590 HPFQ = 939.493 STSW = 8.110 DEPT = 8025.000 TENS = 3677 SP = -19.990 GR = 46.900 TEMP = 157.490 LOAD = -272 TSPD = .000 FTPC = 3501.800 THRS = 42.207 FTP = 3538.200 HYDP = 3537 VOLP = 0 HPRP = 3364.270 FTPR = 3538.200 HPQ = 3530.170 MTF = 15749.140 HPFQ = 939.348 STSW = 8.107 DEPT = 8025.000 TENS = 3675 SP = -19.990 GR = 50.000 TEMP = 154.500 LOAD = -469 TSPD = .000 FTPC = 2327.100 THRS = 42.235 FTP = 2370.400 HYDP = 5318 VOLP = 1 HPRP = 2127.490 FTPR = 2370.400 HPQ = 2272.640 MTF = 15450.450 HPFQ = 809.611 STSW = 9.091 DEPT = 8025.000 TENS = 3675 SP = -19.990 GR = 59.400 TEMP = 157.530 LOAD = -275 TSPD = .000 FTPC = 3216.900 THRS = 42.263 FTP = 3255.500 HYDP = 5300 VOLP = 1 HPRP = 3089.190 FTPR = 3255.500 HPQ = 3241.120 MTF = 15753.140 HPFQ = 909.601 STSW = 9.093 DEPT = 8025.000 TENS = 3674 SP = -19.990 GR = 54.900 TEMP = 157.550 LOAD = -272 TSPD = .000 FTPC = 3224.800 THRS = 42.291 FTP = 3263.400 HYDP = 5287 VOLP = 1 HPRP = 3096.230 FTPR = 3263.400 HPQ = 3248.750 MTF = 15755.140 HPFQ = 910.387 STSW = 9.092 DEPT = 8025.000 TENS = 3674 SP = -19.990 GR = 53.500 TEMP = 157.570 LOAD = -272 TSPD = .000 FTPC = 3227.800 THRS = 42.318 FTP = 3266.400 HYDP = 5279 VOLP = 1 HPRP = 3098.720 FTPR = 3266.400 HPQ = 3251.400 MTF = 15756.840 HPFQ = 910.660 STSW = 9.091 DEPT = 8025.000 TENS = 3674 SP = -19.990 GR = 61.000 TEMP = 150.080 LOAD = -4 TSPD = .000 FTPC = 3683.300 THRS = 42.346 FTP = 3718.200 HYDP = 5284 VOLP = -1 HPRP = 3550.830 FTPR = 3718.200 HPQ = 3723.700 MTF = 15008.460 HPFQ = 959.110 STSW = 9.094 DEPT = 8025.000 TENS = 3675 SP = -19.990 GR = 52.700 TEMP = 157.600 LOAD = -268 TSPD = .000 FTPC = 3493.500 THRS = 42.374 FTP = 3530.000 HYDP = 3319 VOLP = 0 HPRP = 3352.760 FTPR = 3530.000 HPQ = 3518.010 MTF = 15760.250 HPFQ = 938.099 STSW 8.108 FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.047 --- 1024 ~ LO --- LOGIN2.048 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.048 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.047 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 78 4 1 68 000635000 78 2 1 79 001010010 78 4 1 68 030310010 78 4 1 68 080660020 78 4 1 68 000000000 78 2 1 79 000636000 78 4 1 68 095000000 78 4 1 68 000000000 78 4 1 68 095000000 78 4 1 68 095000000 78 4 1 73 095000000 78 2 1 79 HPRP SFT 492239 PSI 000000000 78 4 1 68 FTPR SFT 492239 CPS 095000000 78 4 1 68 HPQ SFT 492239 PSI 000000000 78 4 1 68 MTF SFT 492239 HZ 080660000 78 4 1 68 HPFQ SFT 492239 KHZ 000000000 78 4 1 68 STSW SFT 492239 095000000 78 4 1 68 DATA RECORD TYPE 0 DEPT = 8028.000 TENS = 3501 SP = -19.990 GR = 52.600 TEMP = 157.750 LOAD = -272 TSPD = .000 .FTPC = 3494.500 THRS = 42.636 FTP = 3530.900 HYDP = 3538 VOLP = 0 HPRP = 3354.950 FTPR = 3530.900 HPQ = 3520.170 MTF = 15774.940 HPFQ = 938.324 STSW = 8.106 DEPT = 8028.000 TENS = 3496 SP = -19.990 GR = 64.000 TEMP = 160.490 LOAD = -392 TSPD = .000 FTPC = 3497.600 THRS = 42.664 FTP = 3533.800 HYDP = 3678 VOLP = 0 HPRP = 3356.710 FTPR = 3533.800 HPQ = 3521.860 MTF = 16049.480 HPFQ = 938.546 STSW = 8.105 DEPT = 8028.000 TENS = 3494 SP = -19.990 GR = 49.900 TEMP = 157.780 LOAD = -268 TSPD = .000 FTPC = 3223.800 TI{RS = 42.692 FTP = 3262.400 HYDP = 5150 VOLP = 1 HPRP = 3096.780 FTPR = 3262.400 HPQ = 3249.260 MTF = 15778.140 HPFQ = 910.444 $TSW = 9.094 DEPT = 8028.000 TENS = 3492 SP = -19.990 GR = 52.500 TEMP = 157.790 LOAD = -263 TSPD = .000 FTPC = 3224.700 THRS = 42.720 FTP = 3263.300 HYDP = 5131 VOLP = 1 HPRP = 3097.860 FTPR = 3263.300 HPQ = 3250.480 MTF = 15779.340 HPFQ = 910.570 $TSW = 9.093 DEPT = 8028.000 TENS = 3494 SP = -19.990 GR = 60.600 TEMP = 157.050 LOAD = -257 TSPD = .000 FTPC = 3494.200 TI{RS = 42.748 FTP = 3530.700 HYDP = 3333 VOLP = 0 HPRP = 3354.070 FTPR = 3530.700 HPQ = 3519.520 MTF = 15704.940 HPFQ = 938.245 $TSW = 8.105 DEPT = 8028.000 TENS = 3491 SP = -19.990 GR = 58.400 TEMP = 157.820 LOAD = -256 TSPD = .000 FTPC = 3492.200 TI{RS = 42.775 FTP = 3528.700 HYDP = 3353 VOLP = 0 HPRP = 3352.360 FTPR = 3528.700 HPQ = 3517.580 MTF = 15781.940 HPFQ = 938.059 $TSW = 8.105 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- LOGIN2.048 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 1024 --- LO --- LOGIN2.049 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.049 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.048 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 79 4 1 68 000635000 79 2 1 79 001010010 79 4 1 68 030310010 79 4 1 68 080660020 79 4 1 68 000000000 79 2 1 79 000636000 79 4 1 68 095000000 79 4 1 68 000000000 79 4 1 68 095000000 79 4 1 68 095000000 79 4 1 73 095000000 79 2 1 79 000000000 79 4 1 68 095000000 79 4 1 68 000000000 79 4 1 68 080660000 79 4 1 68 000000000 79 4 1 68 095000000 79 4 1 68 DATA RECORD TYPE 0 DEPT = 7983.000 TENS = 3620 SP = -19.990 GR = 53.600 TEMP = 157.830 LOAD = -285 TSPD = .000 FTPC = 3475.000 THRS = 42.850 FTP = 3511.600 HYDP = 3490 VOLP = 0 HPRP = 3336.300 FTPR = 3511.600 HPQ = 3500.650 MTF = 15782.910 HPFQ = 936.318 STSW = 8.105 DEPT = 7983.000 TENS = 3626 SP = -19.990 GR = 52.600 TEMP = 157.840 LOAD = -269 TSPD = .000 FTPC = 3477.500 THRS = 42.878 FTP = 3514.100 HYDP = 3490 VOLP = 0 HPRP = 3337.610 FTPR = 3514.100 HPQ = 3502.060 MTF = 15784.130 HPFQ = 936.463 STSW = 8.105 DEPT = 7983.000 TENS = 3632 SP = -19.990 GR = 50.100 TEMP = 156.860 LOAD = -380 TSPD = .000 FTPC = 3016.500 THRS = 42.905 FTP = 3056.600 HYDP = 5096 VOLP = 1 HPRP = 2891.890 FTPR = 3056.600 HPQ = 3035.410 MTF = 15686.030 HPFQ = 888.396 STSW = 9.092 DEPT = 7983.000 TENS = 3633 SP = -19.990 GR = 62.000 TEMP = 152.620 LOAD = -106 TSPD = .000 FTPC = 3616.700 THRS = 42.933 FTP = 3652.200 HYDP = 5092 VOLP = -1 HPRP = 3492.390 FTPR = 3652.200 HPQ = 3667.960 MTF = 15261.550 HPFQ = 953.428 STSW = 9.093 DEPT = 7983.000 TENS = 3635 SP = -19.990 GR = 63.300 TEMP = 157.830 LOAD = -275 TSPD = .000 FTPC = 3478.800 THRS = 42.961 FTP = 3515.400 HYDP = 3339 VOLP = 0 HPRP = 3339.49.0 FTPR = 3515.400 HPQ = 3504.060 MTF = 15783.130 HPFQ = 936.668 STSW = 8.103 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.049 --- 1024 --- LO --- LOGIN2.050 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.050 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.049 ****************************************************************************** ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT SFT 492239 F 000000000 80 4 1 68 TENS SFT 492239 LBS 000635000 80 2 1 79 SP SFT 492239 MV 001010010 80 4 1 68 GR SFT 492239 API 030310010 80 . 4 1 68 TEMP SFT 492239 DEGF 080660020 80 4 1 68 LOAD SFT 492239 LBS 000000000 80 2 1 79 TSPD SFT 492239 F/MI 000636000 80 4 1 68 FTPC SFT 492239 PSI 095000000 80 4 1 68 THRS SFT 492239 HRS 000000000 80 4 1 68 FTP SFT 492239 PSI 095000000 80 4 1 68 HYDP SFT 492239 PSI 095000000 80 4 1 73 VOLP SFT 492239 095000000 80 2 1 79 HPRP SFT 492239 PSI 000000000 80 4 1 68 FTPR SFT 492239 CPS 095000000 80 4 1 68 HPQ SFT 492239 PSI 000000000 80 4 1 68 MTF SFT 492239 HZ 080660000 80 4 1 68 HPFQ SFT 492239 KHZ 000000000 80 4 1 68 STSW $FT 492239 095000000 80 4 1 68 DATA RECORD TYPE 0 DEPT = 7983.000 TENS = 3597 SP = -19.990 GR = 58.300 TEMP = 157.760 LOAD = -261 TSPD = .000 FTPC = 3479.300 THRS = 43.027 FTP = 3515.900 HYDP = 3496 VOLP = 0 HPRP = 3339.900 FTPR = 3515.900 HPQ = 3504.490 MTF = 15775.600 HPFQ = 936.711 STSW = 8.105 DEPT = 7983.000 TENS = 3594 SP = -19.990 GR = 59.700 TEMP = 157.730 LOAD = -257 TSPD = .000 FTPC = 3479.700 THRS = 43.055 FTP = 3516.300 HYDP = 3497 VOLP = 0 HPRP = 3340.040 FTPR = 3516.300 HPQ = 3504.660 MTF = 15773.230 HPFQ = 936.728 STSW = 8.103 DEPT = 7983.000 TENS = 3596 SP = -19.990 GR = 65.000 TEMP = 157.510 LOAD = -357 TSPD = .000 FTPC = 3420.800 THRS = 43.083 FTP = 3457.900 HYDP = 5031 VOLP = 1 HPRP = 3079.790 FTPR = 3457.900 HPQ = 3365.320 MTF = 15751.230 HPFQ = 922.387 STSW = 9.089 DEPT = 7983.000 TENS = 3593 SP = -19.990 GR = 64.000 TEMP = 157.670 LOAD = -253 TSPD = .000 FTPC = 3218.400 THRS = 43.110 FTP = 3257.000 HYDP = 4972 VOLP = 0 HPRP = 3090.470 FTPR = 3257.000 HPQ = 3242.760 MTF = 15767.230 HPFQ = 909.772 STSW = 9.089 DEPT = 7983.000 TENS = 3594 SP = -19.990 GR = 64.500 TEMP = 147.680 LOAD = -438 TSPD = .000 FTPC = 3475.200 THRS = 43.138 FTP = 3511.600 HYDP = 3353 VOLP = 0 HPRP = 3335.670 FTPR = 3511.600 HPQ = 3502.110 MTF = 14768.160 HPFQ = 936.279 STSW = 8.103 DEPT = 7983.000 TENS = 3597 SP = -19.990 GR = 59.000 TEMP = 157.620 LOAD = -256 TSPD = .000 FTPC = 3473.600 THRS = 43.166 FTP = 3510.200 HYDP = 3388 VOLP = 0 HPRP = 3334.350 FTPR = 3510.200 HPQ = 3498.710 MTF = 15761.630 HPFQ = 936.114 STSW = 8.103 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- LOGIN2.050 --- 1024 --- LO --- LOGIN2.051 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- LOGIN2.051 --- 310 --- 96 --- LOGIN2 --- 1024 --- LO --- LOGIN2.050 ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 66 4 1 66 0 5 1 66 0 8 4 68 .500 9 4 65 S 11 2 79 15 12 4 68 -999.250 14 4 65 FT 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT SFT 492239 F TENS SFT 492239 LBS SP SFT 492239 MV GR SFT 492239 API TEMP SFT 492239 DEGF LOAD SFT 492239 LBS TSPD SFT 492239 F/MI FTPC SFT 492239 PSI THRS SFT 492239 HRS FTP SFT 492239 PSI HYDP SFT 492239 PSI VOLP SFT 492239 HPRP SFT 492239 PSI FTPR SFT 492239 CPS HPQ SFT 492239 PSI MTF SFT 492239 HZ HPFQ SFT 492239 KHZ STSW SFT 492239 API CODE FILE# SIZE #SAMP REPR. 000000000 83 4 1 68 000635000 83 2 1 79 001010010 83 4 1 68 030310010 83 4 1 68 080660020 83 4 1 68 000000000 83 2 1 79 000636000 83 4 1 68 095000000 83 4 1 68 000000000 83 4 1 68 095000000 83 4 1 68 095000000 83 4 1 73 095000000 83 2 1 79 000000000 83 4 1 68 095000000 83 4 1 68 000000000 83 4 1 68 08.0660000 83 4 1 68 000000000 83 4 1 68 095000000 83 4 1 68 DATA RECORD TYPE 0 DEPT = 7981.000 TENS = GR = 53.500 TEMP = TSPD = .000 FTPC = FTP = 3510.800 HYDP = HPRP = 3369.840 FTPR = MTF = 15740.960 HPFQ = 3609 SP = -19.990 157.410 LOAD = -269 3474.200 THRS = 43.531 3473 VOLP = 0 3510.800 HPQ = 3535.990 939.945 STSW = 8.102 DEPT = 7981.000 TENS = GR = 51.500 TEMP = TSPD = .000 FTPC = FTP = 3562.700 HYDP = HPRP = 3369.220 FTPR = MTF = 15205.060 HPFQ = 3613 SP = -19.990 152.050 LOAD = -594 3526.400 THRS = 43.559 4807 VOLP = 0 3562.700 HPQ = 3536.270 939.876 STSW = 8.102 DEPT = 7981.000 TENS = GR = 51.700 TEMP = TSPD = .000 FTPC = FTP = 3254.200 HYDP = HPRP = 3035.600 FTPR = MTF = 15739.930 HPFQ = 3612 SP = -19.990 157.400 LOAD = -270 3215.500 THRS = 43.587 4967 VOLP = 1 3254.200 HPQ = 3185.200 903.840 STSW = 9.086 DEPT = 7981.000 TENS = GR = 62.900 TEMP = TSPD = .000 FTPC = FTP = 3462.100 HYDP = HPRP = 3387.010 FTPR = MTF = 15502.340 HPFQ = 3611 SP = -19.990 155.020 LOAD = -117 3425.000 THRS = 43.615 4961 VOLP = 0 3462.100 HPQ = 3519.480 938.204 STSW = 9.086 DEPT = 7981.000 TENS = GR = 53.200 TEMP = 3612 SP = -19.990 157.390 LOAD = -258 met 6CE~6~ --- 'S 'R --- aa/os --- Hk~N ~HHH ~XHN HH~NflN NOI~D_NI~NOD ~HHH ~¥G ~0 NIDIHO H~T~R HDIAHHS E£I H6A~ GHODHH HH~I~fH~ ~HHH 6C~E6~, --- 80/I0/Z6 --- 6C~69 = aaqmnN qo£ :S~NHNNOD HN%fN H~ ~XHN HH~NI1N NOI~NI~NOD H~A Hk~N H~ ¥~¥G &O NIDIHO Hk~R HDIAHHS ICI H~A~ ........... - .................. GHODHH HH~I~fH~ H~ Oq --- ~g0I --- gHIO(YI --- 96 --- 0IE --- IN0'gNIO0~ --- .............................. GHODHH HH~I~fH~ H~I~ .GOI'8 = MS~S ~9~'E96 = O&6H 0~'6CL~I = 0~'I9Gg = 0~H 000't0~g = H~ 0E0'~6EC = 0 = ~OA 6~E~ = ~GAH 000't0Ng = E~9'E~ = SHH~ 00C'0L~C = DE~ 000' = GES~ J I III Iiii .£1MUt 7"OH DIRECT. DIGITAL LOGGING RECEIVED dAN 2 9 1991 Alaska 0ii & Gas COns. Commission Anchorage COMPUTER PROCESSED ANALYSIS .LLLLLLLLL .LLLLLLLLL IIIIIIIIII IIIIIIIIII II II II II II II II II IIIIIIIIII IIIIIIIIII SSSSSSSS SS SSSSSSSSS SSSSSSSSS SSSSSSSSSS SSSSSSSS DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU NM NN PPPPPPPPPPP PPPPPPPPPPP! PP Pi PP Pi PP Pi PPPPPPPPPPPt PPPPPPPPPPPt PP PP PP PP PP 'l I ti i l 1111 i ::1 I 11 l i l .i i i I'lll I i 1 Il. ll 11 11 11 11 11 I1 ii t I 1 1 1 I 1 1 l 1 I I i llil ilii ' 1111 00000000 0000000000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0000000000 00000000 666666666666 00000000 0000000000 ::: 00' O0 ::: O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 ::: O0 O0 ::: O0 O0 JJ JJ JJ JJ JJ JJ dj. JJ JJ JJ JJ JJdJdJJddJdJ JdJJJddddd 0000000000 000,00000 AA AAAA AA AA AA AA AA AA AA 'AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA A,A AA AA 444 4444 44 44 44 44 44 44 - 44444444444 444444444444 44 44 44 44 44 AA AAAA AA AA AA AA AA AA AA AA AAAAAAAAARAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 MM MI MMM MMMM MMMI MM MM MM Mt MM MMMM MI Mil MM Mt MM Mt NH Mt MH hit bit'i lit HH HI' MM Mt ii iii ii li ii ii ii ii ii lliiiiiiii iiiiiiiiii ********************** REEL HEADER Service name: &G5FO! Previous reel: Date: 91/01/16 Comments: HEADER Origin: RECORDS name: 492239 Pagm Continuation #: Oi TAPE HEADER ********************** Service name: &G5F01 Previous tape: ~** FILE HEADER **** File name: ,001 Maximum length-: 1'024 Date: 91701/IG Comments: Service name: File type: LO origin: Vcrsi on #: Previous 'Pile: Tape name: 492239 Continuation #: Ol Date: MHEM CH WH FH COUN STAT CTRY APIN LATI EONG SECT TOWN RANG EKB EDF EGL PD LHF bi'IF RUN TIHE. DATE LCC SON LUN FL LUt. iENG I 'WI TN DL · CBD 1 CBL1 TLI' 8LI TCS TL~B 8HT ~T DFD DFPH DFL RH RHF HFST HFSS RHtC IHFORMATIOH CONTENTS ARCO ALASKA INC. 1A-26 KUPARUK NORTH SLOPE ....... ALASKA ....... USA ....... 22115.000.... ............ o. 0 Deg, 0 Hin, O. 0 Sec O.Oeg. O Min. O. 0 Sec 05,,,,,,,,,, ,,,,,.,,,. ,,, lIN ...................... tOE ...................... 1 02. 000 ................... I Ol . 000 ........ ~ ......... ~7.0 O0 ................... 1~,,,,,,,,,,,,,,,,,,,, ,,, 2140~.0oo ............... ... 7/ ~/~1 ......... ' ......... 492239 .............. 51939 ............. NORTH SLOP~ .... NORTH SLOPE .... HcKAY .... BEAL .... 8250,000 .............. 8133,000 .............. 4632,000 .............. 4630,000,' ............. 141,000 ............ ', ,. 8124,000 .............. t640,000; ............. 2,140,000 .... .......... 143,000 ................ 143,.000 ............... NEWDRILL .... CZRCULATED .... 10.900 ................. 38.000 ................ 8,.500 ................. 5.9'00 ................. 2,510 ................. 2.420 ................. 73.000, ............... HERS ........... 3.230 ................. API HUH: 50-029-22115 DATE LOGGED: 01-07-91 . · . · . m m m · m . · · I . · · N . W . . · m · · · . m ! · m i . m m m . . m m m m m m m ~ m m m. i m m ~ m . m m m · · · m . m . . m m m . m m · · . . m RECORDS UNIT mlmml . · m. m . l . m . m I I . I . I m . . . m .iisi mm.I mill ! ' . m FT- FT FT FT FT FT FT FT FT HR HR DEGF DEGF CP OHHH OHHH DEGF OHHM TYPE 0 O 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CATG 0 0 0 O 0 0 0 0 0 0 0 0 3 3 3 3 ,3, 3 0 .0 ,0 0 0 0 O .0 0 0 3 3 3 3 3 2 4 2 2 2 2 2 2 2 2 2 2 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 8 2 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 65 65 65 65 65 65 65 65 65 79 65 79 65 65 65 65 65 65 65 6,9 Page ERROR MNEM MCST MCSS CS BS INFORMATION RECORDS COHTEHTS NE~IS ............ ~ ................................ 9.625 ................................................... 8.500 ................................................... UNIT DEGF TYPE C~TG SIZE 4 4 4 CODE 65 ~8 Page ERROR COMMENT RECORDS Well Locat Well Locat Well Locat Well LoCat Well File Well File Well File Well File ion Comment 1: ion Comment 2: ion Comment 3: ion Comment Comment I: Comment 2: Comment 3: SURFACE: 635' FSL & 310~ FWL HRI, ML, SDL/DSH RUH 'IN COHBINATION TD NoT LOGGED DUE TO HOLE CONDITIONS,* HEAD TENSIOH'AND LINE TENSION ARE RECORDED 46.25' DEEP TO BOTTOM DUE TO SOFTWARE ERROR. Comment 4: .DXCO = +2.0 MMHOS & MXCO '= -1.? MMHOS. LIS tape written bp: AHCHORAGE COMPUTIHG CENTER All curve and tool mnemonics used are those which most closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 4550,00 8140.00 GR SDL GAPI GR SDL GAPI 4550.00 8139,75 FDSN DSH2 CPS FDSH DSN2 CPS 4550.00 8139.75 NDSH DSH2 Cps NDSN DSN2 CPS 4550.00 8139.75 NPHI DSN2 DECP NPHI DSN2 DECP 4550.00 8139,75 NRAT DSN2 C/C NEAT DSN2 C?C 4550,00 8139.75 DPHI SDL DECP [)PHI SDL DECP 4550,00 8139.75 DRHO SDL G/C3 DRHO SDL G?CJ 4550,00 8139.75 FSDL SDL CPS FSDL SDL CPS 4550,00 - 8139,75 NSDL SDL CPS NSDL SDL CPS 4550.00 8139.75 Pag~ PE PELC QL RHOB CALI HINV HNOR HDR HDX HHR HDRS H~RS HDCN HHCN DFL SP TENS DLOD SDL SDL SDL SDL SDL SDL HL HR! HRI HR! HR! HR! HRI Sl)L SDL G/C3 IN OHHM OHHI'"I OHHM OHHI'I HHHO OHHM H¥ LBS LBS PE SDL PELC' SDL QL SDL QS SDL RHOB SDL CRLI SDL HIHV HL HHOR HL HDR HRI HDX HRI HHR- HRI HHX HRI HDRS HRI HHRS HRI HDCN NRI HHCH HRI DFL HRI SP HRI TENS SDL .DLOD SDL G?C3 IN OHMH OHHH OHHH OHMH HMHO HHHO OHHH LBS LBS 4550,00 4550.00 4550.00 4550.00 4550.80 4550.88 4550.88 · 4550.08 4550.00 '4550.00 4550.00 4550.00 4550.00 4550,00 4550.00 4550,00 4550.00 4550.00 4550.00 4550.00 8139.75 8139.75 8139.75 8139.75 8139.75 8139.75 8139.75 8339.75 8139.75 8139,'75 8139,75 8139,75 8139.75 8139.75 8139.75 8139.'75 8139.75 8139.75 8'~39.75 DATA ENTRY BLOCKS EHTRY FORMAT TYPE · SIZE 1 SPECIFICATIONS CODE Page 5 e~ ENTRY BLOCK LEGEND **~ TYPE DESCRIPTION mm m~ mm mmwm--mmm m Datum ~peci¢ication block subltype 0 Terminator (no more entries DATA FORMAT SPECIFICATIONS DATUM SPECIFICATION BLOCKS SER¥ICE SER¥1CE AP1 AP1 MNEM ID ORDER # UNIT LO~ TYPE CLASS MOD DEPT 492.239 GR -SDL 492239 FDSH DSN2 492239 'HDSH DSM2. 492239 HPHI' D~H2 492239 HRAT. DSH2 DPHI SDL DRHO SDL FSDL SDL HS~L GDL PE SDL PELC SDL GL SDL QS SDL RNOB SDL CALI SDL MIN¥ ML MNOR HL HDR HRI 'HDX HRI HMR HRI HM~ HRI. ~'HDRS ,HMRS HRi 'HDCH HRI HMCH HR'I DFL HRI SP HRI TEHS SDL DLOD SDL 492239 492239 492239 492239 492239 492239 492239 492239 FT 0 GAPI 94 CPS 94 CPS OECP 94 C/C 94 DECP 94' "G/C3 CPS 94 CPS 94 94 94 94 492239 94 492239 ' G/C3 94 492239 492239 492239 492239 492239 492239 492239 492'239 492239 492239 492239 492239 492239 492239 492239 API API FILE # 0 0 0 0 0 1 0 0 1 0 0 0 0 0 0 1 .0 ~:! '0 1 0 1 0 1 0 · 1 0 0 1 0 1 O' 1 0 1 0 1 0 '1 0 0 I 0 1 0 0 0 0 1 0 0 0 0 1 O. 0 0 0 0 0 0 0 0 0 IH 94 0 OHMM 94 0 OHMM 94 0 94 0 94 .0 94' 0 94 0 OH.HM 94 0 OHMH 94- 0 MHHO 94 0 MMHO 94 0 OHMH 94 0 HV 94 0 LBS 94 0 LBS 94 0 o 0 0 0 0 ~0 0 0 0 0 0 0 0 0 0 0 0 0 O. o 0 0 0 0 0 0 0 0 0 PRC # SIZE LYL SMPL RC PROCESS INDICATORS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 .4 4 4 4 4 4 4 4 4 4 4 4 r4 4 4 4, 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 o o 0 0 0 0 0 0 0 o 0 0 0 0 1 68 1 68 I 68 1 68 1 68 ! 68 1 68 I 68 1 68 1 68 1 68 ! 68 ! 68 1 68 68 000000 080000 000000 000000 000000 00'0000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O000OO 000000 000000-000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 1 68' 000000 000000 000000 J 68 000000 000000 000000 1 68 000000 000000 000000 I 68 000000 000000 000000 1 68 000000 000000 000000 1 68 000000 000000 000000 1 68 000000 000000 000000 1 68 OOO000 000000 000000 1 68 000000 000000 000000 1 68 000000 000000 000000 I 68 000.000 000000 000000 Pag~ 6 DATA RECORDS DEPT GR FDSH NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB C~LI MINV HNOR HDR HDX HMR HH~ HDRS HHRS HDCN HHCN DFL SP TENS DLOD Page ? 8139. 7391. i. -12345. 8100, 7391. -1, 386. 8000, 9253, 5. 31. 7900. 6609. 4. 183. 7800, 747l , 5. 1 08, 7700, 2922. 12, 49. 491 518 000 000 4'91 518 953 ,000 -O90 668 · 09 0 000 091 ?9? 792 000 490 923 684 .000 690 332 39? 7600,000 7321.29! 2.274 425.084 I 02.4?4 16018.951 2. 157 -12345.000 102.474 16018.951 2.157 389.405 15669.. 6.528 36.258 91.891 14827.379 3.9?2 176.905 65.407 15233.95! ?.418 1088.756 78.686 124'03.521 9.0.03 44.860 125.236 15154.523 2.053 448.056 t978.256 3.945 0.000 5.104 1978.256 3.945 255.538 2.454 2834.524 2.5188 64.754 18'.699 2317.032 2.650 .142.694.. 5.711 3364. 8824 2. 057 90,175 9.8815 2314 ..7'24 5. 778 1 09. 276 88.607 1497,172 2.494 290,446 2.199 15402.8824 3.846 O,O00 123450000. 154.02.824 3,846 50,550 1 09. 329 18 026,168 3,139 14.315 73,971 158874.049 2.858 27.110 117.551 188339.465 2,359 13,632 106.8885 16284. 533 9.051 27.784 I 05.71 6 13567.516 2.969 76.4'00 114.199 .3887 -.1i9 O.OOO 5 027. 322 · 387 -.119 319. 121 5012. 751 ,308 ,04'1 64,913 51 00,1883 ,327 -, 045 164,302 488 088,744 .249 .022 I O1 . 054 48881 .604 .337 -, 035 1 05,494 4823,315 .455 .147 375. 074 505&.467 7500,000 128,373 1416,355 13574,967 ,479 8405.291 15847,094 3,3884 3,702 ,030 2.679 2.145 304.144 77.8825 366.599 407,132 407.571 2,255, 130,249 4590,164 88,407 ,137 O,OOO $~.4. 436 8,407 .137 17,850 858,956 6,8867 -.019 4,124 935.676 ?,3988 -, 024 9,575 820.260 5.885 -.024 2.086 886.356 7,597 ,038 9,229 885,808 9. 785 ., 036 34.286 991 .572 10,349 -,023 28,693 829,364 ,145 2,411 -12345.000 .145 2.411 2.504 '.281 2,1886 32,165 .147 2,407. 5,441 , IEl? 2.342 9.201 -. 1 03 2,819 20,244 .1885 2,345 2.352 .221 2.286 2.456 ,109 8.500 -12345.000 .109 8.5'00 2.5688 ,017 8.2884 27,580 .030 8,972 5,653 ,034. 9,035 9,195 -.004 9.042 22.292 ,031 8.979 2. 232 ,059 9.347 2.454 DEPT FSbL- HINV HDCN. GR NSDL HHCN FDSN PE HDR .DFL DATA NDSN PELC HDX SP RECORDS NPHI QL HHR TENS NRAT HHI< PLOD DPHI RH08 HDRS DRHO CALl HMR$ Page 7400,0.00 -999,250 -999.250 369,101 7300,000 -999,250 -999,250 307,25.8 7200,000 -999,250 -999,250 302,013 710.0,000 -99.9,250 -999.250 299.756 7000,000 -999,250 -999.250 326.625 6900. 000 -999.250 -999.250 61.7,945 6800,000 -999 250 -999;250 309 .'61 t .6700,000 -999,250 -999,250 316;434 388,655 -999,250 -999.250 359.892 '150,636 -999,250 -999o250 303,455 i63.764 =99.9,250 -999,250 287,867 118,023 -999,250 -999,250 318,274 112,919 -999.250 -999,258 322,i16 117.770 -999.25.0 -999,250 672.516 141,214 -999,250 -999.25.0 306,11! 123.170 -999.250 -999.250 319,638 -999.250 -999,250 284,957 2,455 -999,250 '-999.250 244.488 3,555 -999,250 -999.250 262,643 3,023 -999,250 -999.250 216,707. 4,809 -999,250 -999,250 261 ,905 3. 738 -999,250 -999,250 374,336 1.675 -999,250' -999 ,.250 248,57-8 3,147 -999,250 -999,250 250.988 3.122 · -999.250 -999,250 65.132 127.372 · -999.25 0 -999.250 56,501 114,509 '-999,250 -999,250 65.263 115,058 -999.258 -999,250 42.645 119.373 -999,250 -999,250 70.ilO i12.276 -999.25.0 -999,250 1 07,242 116,107 -999,250 -999,250 60,257 10! ,742 -999,250 -999,250 53,906 102,730 -999.250 -999.250 334. 586 4517. 305 -999.250 -999.250 292.120 4400.729 -999,'250 -999.250 292,733 4444.445 -999.250 -999,250 264.41i 44?3.58.9 -999,250 -999,250 304.557 4400.729 -999,250 -999,250 506,033 55,81,057 -999,250 -999',250 292,073 4342.44! -999,250 -999,250 302.866 4357.014 -999.250' -999,250 2i .844 792,648 -999.250 -999.250 22.051 767,988 '999.250 -999.250 17.303 784,976 -999,250 -999,250 13.792 786,072 -999,250 -999,250 26,203 767,988 -999,250 -999.250 53.324 1267,216 -999,250 -999',250 21,967 784.428 -999,250 -999,250 16,846 832,1 04 -999.250 -999,250 2,789 -999.250 -999.250 3.255 -999.25.0 -999.25'0 3,3il -999,250 '-999,250 3.336 -999,250 -999,250 3,062 '999,250 -999,250 1,618 -999,250 -999,250 3,230 -999,250 -999,250 3,160 -999.250 8,905 2.779 -999,250 9.499 3.295 -999.250 9.395 3.474 -999.250 9.138 3.142 -999.250. 9,186 3,104 -999,250 · 8,550 1 ,487 -999.250 9.424 3,267 -999,250 9.768 3,129 DATA RECORDS DEPT GR FDSH HDSN NPHI HRAT DPHI DRHO FSDL HSDL PE PELC QL QS RHOB CALi HIH¥ HHOR HDR HDX HMR HHX HDR$ HHRS HDCH HNCH DFL SP TEHS DLOD Pag~ -999. 250 -999.250 720,953 6500. 000 -999,250 -999.250 646,402 6400,000 -999.250 -999.250 621 , 134 6300.000 -999,250 -999,250 315,951 6200.000 -999,250 -999,250 .368,418 i75.?74 -999,256 -999,250 -999,250 -999.256 -999.256 -999,256 -999.256 -999.256 -99-9.250 -999.25.0 435,8i! 139,799 572,092 67.789 758,163 1,218 i25,828 4211,294 763,604 't56,429 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,258 424,627 132,440 565,907 63,465 684,091 1,264 127,997 4080,146 744,424 -999.25~ -999.250 -999.250 8.889 i.367 i.3i9 -999,250 -999,2.50 -999,250 8.8=99 ! .547 1 .462 127.,.608 -999.250 '999,250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 9. 088 -999,250 430.513 138.6,01 566,997 65,785 I. 61 0 I, 565 638. 796 1,669 .. 126.573 3992.715 712,092 152,635 -999,250 -999,250 -999,25.0 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 9,427 -999,250 251,950 62,496 299,293 24,536 3,165 3.i08 321,744 2.922 116,557 4153,0'06 780.044 96,895 -999,250 -999,25.0 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 9,296 -999,250 275,466 75.397 336,876 34,034 2.714 2,727 366,680 2,453 121,353 4225.865 820,596 6100,000 98.209 -999,250 -999.250 -999,250 -999.250 -999,250 -999...~0'~ -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999.250 9.345 -999,250 -999.250 226.696 55.590 .251,949 21,593 4.143 4.107 241,362 243,493 5.176 1'18.575 3861,567 752.096 6000.000 150,983 -999,25'0 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.,250 -999.250 -999.250 -999,250 10.393 -999,250 -999,250 247,t53 61.679 285.640 22',059 3,287 3.15i 304,225 317,.400 3,194 115.233 3788.708 748.260 5900,000 94.765 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250' -999,250 -999.250 9,202 -999.250. -999.250 297,269 79.331 366,922 31,260 2,557 2.484 391,129 402,641 2,157 121,841 38t7,852 748,260 DEPT FSDL HIN¥ HDCH GR NSDL HNOR HHCN FDSN PIE HDR DFL DATA NDSN PELC HDX SP RECORDS NPHI QL HHR TENS NRAT QS HHX DLOD DPHI RHOB HDRS DRHO ~ALi HHRS Paga iO s -oo. OoO -999,250 -999,250 402.361 5700,000 -999,250 -999,250 41.3. 249 5600. 000 -999,250 -999,250 374. 734 5500.000 -999,250 -999.250 369.837 5400,-00'0 -999.250 -999,250 335.348 530'0,000 -999,250 -999.250 338.820 5200,000 -999.25.0 -999,250 318,227 5100,000 9631,490 3,962 249,458 92,509 -999,250 -999,250 418,044 83,834 -999,25.6 -999,250 429,637 103,591 -999,250 -999,250 391.887 .94,044 -999,250 -999.250 306.664 81,829 -999,2.50 -999,250 354.735 t09.87! -999.250 -999.250 355.429 I00.00! -999.250 -999,250 341,765 83,'025 15995,521 3,498 252',226 -999,250 -999.250 296o605 1.996 -999,250 -999,250 298,885 2,014 -999,250 -999,250 28i,950 2,144 -999.250 -999,25'0 275,36! 2.202 -999,250 -999.250 268,509 2.257 -999,250 -999,250 264,826 2,363 -999.250 -999,250 244,866 2.504 1899.546 2.550 203,723 3.439 -999,250 -999.250 78.585 -999,250 -999,250 79.317 li8,233 -999.250 -999,250 73,403 112,522 -999.250 -999,250 71,29.5 111,482 -999,250 -999,250 69,029 110.321 -999.,250 -999,250 67,144 lI0.396 -999,250 -999,250 56,432 1 i 3,579 15560.252 2,780 45.450 .108,402 -999,250 -999.250 373.330 3832.423 -999.250 -999.250 385.776 4123.862 -999,250 .-999,250 351,820 3701,276 -999,250 -999.,250 343,740 3686,704 -999,250 -999,250 336,203 3.686,704 -999,250 -999,250' 328,674 3511,840 -999,250 -999,250 307,097 3453,553 ,394 -,076 23S,714 3453,553 -999,25o -999,258 35.330 725.792 -999.250 -999.250 36,4 09 806,896 -999,250 -999.250 32,087 676.472 -999.250 -999,250 31.306 651.264 -999,250 -999.250 30,633 667.704 -999,250 -999,250 28,891, 609,616 -999,250 -999,258 23,297 628,796 8.'845 ,087' 16. 043 609.616 '999,250 -999.250 2.485 -999,250 -999.250 2.420 -999.25'0 -999.250 2,669 -999.250 -999,250 2,704 -999,250 -999,250 2,982 -999.250' -999,250 2.951 -999,250 -999,250 3,142 .278 2,192 4,009 -999,250 9,306 2,392 -999.250 9,260 2,328 -999,250 9,640 2,552 -999.250 9,611 2,586 -999,250 9.388 2,819 -999.250 9,451 2,814 -999,250 9,374 2,926 036 9,434 .965 DEPT FSDL HINV HDCN NSDL MNOR. FDSN PE HDR DFL DATR NDSN PELC- HDX SP RECORDS NPHI QL HMR TEHS NRAT QS HMX DLOD DPHI RHO8 HDRS DRHO CALI HHR$ Pag~ 11 SO00 294 4900 8236 2 27.5 4800 8365 2 280 4700 8799 2 278 4600 5724 -99'9 -999 .000 ,691 ,329 ,227 ,000 .090 ,503 .184 , 'gO0 .090 .345 .509 ,000 .490 .292 .931 .O00 ,690 ,250 .250 90, 1541 I. 3, 313, '114, 15673, 2. 289. I 03, 15557, 2, 3'12, 101 . 15769, 2, 302., 58, 7167, -999. -999, 792 521. 036 308 019 094 515 012 148 809 492. 666 237 O94 423 424 991 094 250 250 2069,201 3,288 199,991 2.603 1778,607 2,867 218. 595 2. 836 1827.819 2.726 217;362 2.645 1658.797 2,683 219,934 2,753 988.556 11,569 -999.250 -999.250 16221,121 3.613 41.442 107.489 1'4733.016 3,403 48.370 101.632 15135,795 3,203 43.320 116,836 14560.273 3, 028 48.04 0 1 08. 586 10633.2.07 12,680 -999.250 -999.250 .371 -.101 249.299 3118.398 .393 -,007 269.839 3234.973 ,396 · 034 279.556 3234,973 ,421 -,031 278.999 3162,114 .576 ,042 -999.250 3045.538 8.4-65 .008 14.594 431.516 8,944 .019 21,003 434.804 8.942 .016 17,763 392.060 9.478 ,044 22,339 409,596 11,615 -.008 -999,250 359.180 .196 2,326 3.399 ,219 2.288 3,634 ,231 2.268 3.565 .245 2.246 3,585 ,75'6 1,403 -999,250 .040 9.814 3,192 .047 i O. 342 3.460 · 034 10,192 3,19:3 ,040 10,100 3,307 -1,052 8.889 -999,250 FILE TRAILER ~m~~~~~~ File name: &GSFOI.O01 Maximum - length: 1 024 TRAILER RECORDS Service name.: Versio File tppe: LO Next file: Date: Page 12 File name: ,002 Maximum length: 1024 Service name: File tppe: LO Version #: Previous file: Date: CH WN COUN STRT CTRY APIN LATI LONG .SECT TOWN RANG EKB £DF EGI. LHF DHF RUN TIHE ~DATE .LCC: ~ SON LUN FL .LUL ENGI WITH DL CBDI ' CBL. I TLI BL.I ·'TCS TLAB BHT HRT hiT MSS DFD H¥IS DFPH HFST HFSS RMC. I NFORMAT I ON RECORDS CONTENTS ARCO ALASKA INC. 1A-26 KUPARUK NORTH SLOPE ....... . ......... ALASKA ................ USA . ........... ' .... 22115.000.,.~', ...................... 0 Deg.' 0 Hin. 0. 0 Sec. N .. , '0 Deg, 0 Hin, O, 0 Sec, W ,, , 051. e'll'll.llIllllll IIIIt I lin .................... · .IOE ................... i02.000 ............... 101.000 ............... 67,00'0 ................ lllllllllIlIIllII IIIII 2140.000 .............. 7/ I/gl ............... 492239 ............ 51939 ....... . .... NORTH SLOP~ ... NORTH SLOPE .... HcKAY ,,, BEAL ... 8250,0.00 ............... 8,133.000 ............... 463~,000 ............... ..... : 000 141 ............ 8124,000 ............... 1640,000 ............... 2t40,000 ............... 143,000 ................ 143,000 ................ NEWDRILL ,,, CIRCULATED .......... '10,900 ....................... 38,000 ........................ 8.. 5'00 ........................ 5,900 ........................ 2.5t 0 ........................ 2,420 ........................ 73,000 .................. HERS ..................... 3.230 ........................... API NUN= 50-029-22115 .... :: :.'' DATE LOCCED: 0i-07-91 ......... i · Iiiiii · i iiiill i i i i i i I I | Illll I lllll · IIlII II i iliiI tl i lille ii i tllll I IIIlI I IIIII · Ilill II · '11111 t 11¢11 II I {1111 i Iiiii ii i Iiiii ii i IiliI Ii i iIlii ii I iiiii i iiiii ii I iiiii i Iiiii ii i iiiii Ii I Illll i iilii ii I IlIii i1 I IIiii ii i ilIIliiI i iIiiiili iiIiilliIi iiIlIilili iIiIiIliIl ii ii I i I · ii I I i d i · · i i i I i · i i i i I ilelll iiiiii i i I iilIii · iiiiii illill ii iiiiiilllll iillllllll iliiliiiii iiiIliiill iiiliiliii IIIIiiiIli illliiiiiIi illllllllll iSili|lll|liillllll i i i ·i · i i I · I · | · | i · e ii i ii i i I ie I i i i I ! ! ! · · UNIT TYPE CATG 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 0 3 0 3 0 3 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT .0 3 HR 0 2 HR 0 4 DEGF 0 11 DEGF O 1 0 ~ 0 2 LB?G 0 2 CP 0 2 0 2 0 2 OHHN O 2 OHHN 0 '2 DEGF 0 2 0 2 OHHN 0 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 .2 2 10 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 ~5 65 65 65 ~5 65 65 65 ~5 -65 ~5 79 68 65 79 65 65 65' 65 65 ~S 68 65 Page ERROR 13 'MNEM ~CST MCSS BS. I NFORMAT I ON RECORDS CONTENTS UNIT ee.ooo .................................................. HEAS ' · IlIIIllIlI·lIIIlllliIIIlIIIlIiIIliIIilIiilII 625 ' IIleletII,elllIeWlIIlIIIIeIWeIIemwIIIIIIllIllIIIWIII 500' ' IIIIIIIIJllllIIIIIIIIllllllllllalllllllllillll&lill DEGF TYPE CATG 2 2 -3 3 SIZE 4 12 4 4 CODE 6,8 65 Page i4 ERROR Well Location Comment I: Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well File Comment 1: HRI, COMMENT SURFACE: 635, FSL & 310' FWL RECORDS ML, SDL?DSN RUN IN COMBINATION. TD NOT LOGGED DUE TO .Well File Comment 2: HOLE CONDITIONS, HEAD TEHSIoN AND LINE TENSION ARE RECORDED Well File Comment 3: 46,25' DEEP TO BOTTOM DUE TO SOFTWARE ERROR, 'Well File Comment 4: DxCo = +2,0 MHHOS & MXCO = -1.7 MMHOS, ********************************************************************************* ** LIS tape written by: AHCHORAGE COMPUTING CENTER ** All curve and tool mnemonics .used are those which most closely match ** Halliburton curve and tool mnemonics. / HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 4550,00 8~40.00 GR'I SDL GAPI GR SDL GAPI 7492.00 8140,00 FDSHI DSN2 CPS FDSH DSN2 CPS 7492,00 8140,00 NDSHI DSN2 CPS. NDSN DSN2 CPS 7492,00' 8'140,00 HPHI! DSN2 DECP NPHI DSN2 DECP ?492,00 NEAT1 DSN2 C/C NEAT DSN2 C?C 7492,00 8140.00 DPHI1 SOL DECP DPHI SDL DECP 7492,00 0140,00 DRH01 SDL G/C3 DRHO SDL G?C3 7492,00 8140,00 FS.DL! SDL CPS FSDL SDL CPS 7492,00 8140,00 HSDL1 SDL CPS NSDL SDL CPS ~492,00 8140,00 Page 15 PELC~ RHOB! CALI~ MINV! MNOR! HDR! HDX1 HNR1 HMX1 HDRSl HMRS i HDCH 1 HHCN I DFL! TEHSl DLOD! SDL ~DL ~DL SDL ~DL SDL 'ML 'ML HRI HR! HR! SDL .SDL G,,'C3 IN OHNM OHMM OHMM OHMM NMHO OHMH L~S PE PELC QL QS RHOB CALI NIHV MHOR HDR HDX HHR HHX HDRS HHRS HDCN HHCN DFL SP TENS DLOD SDL SDL SDL SDL SDL SDL NL HL HRI HRI HRI. HRI HRI HRI HR I HRI HRI HRI ~L G?C3 IN OHMM OHNH OHMM OHMM HMHO,' MMHO OHHM NV LBS LBS 7492,00 7492.00 7492.00 7492.00 7492.00 7492.00 7492.00 7492.00 7492.00 7492.00 .7492,00 7492,00 7492,00 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 8140.00 8140.00 8140.00 8140.00 el4o.oo 8140,00 8140.00 8140.00 8140.00 8140.00 8140.00 8140.00 8140.00 ~140.00 ~140,00 8140,00 8140'.00 8140,00 $140,00 DATA ENTRY BLOCKS ENTRY . FORMAT TYPE 0 SIZE SPECIFICATIONS CODE 66 16 · ,~ EHTRY BLOCK LEGEND ****. TYPE DESCRJPTJON 16 Datum speciCtca~ion block sub-~pe 0 Teeminator (., no moee en~rles ) DATA ,~* DATUH SPECIFICATION BLOCKS *~* SER¥ICE SERVICE -AP1 APl HHEH ID mm~ FORMAT API API. FILE ORDER # UHIT LOG TYPE CLASS MOD # SPEC I F I CAT I,ONS PRC # SIZE LYL SHPL RC ii PROCESS iNDICATORS DEPT GR SDL FDSN DSN2 'NDSH DSN2 NPH! DSN2 NRAT DSH2 DPHI. SDL DRHO SDL FSDL SOL :HSDL SDL PE. SDL' PELC SDL QL SDL QS. SDL RHOB SDL CALI SDL HINV HL' HNOR HL HDR HRI ,' HDg HR! 'HHR HRI HHX ~HDRS HRI HHRS 'HRI HDCN HRI HMC.H HRI 492239' DFL HRI 492239 8P - H. Ri 492239 TENS SDL 492239 DLOD SDI. 492239 492239 FT 0 492239 GAPI 94 492239 CPS 94 492239 CPS 94 492239' DECP 94 492239 C/C 94 492239 DECP 94 492239 G/C3 94 492239 CPS 94' 492239. CPS 94 492239 492239 492239 492239 492239 492239 492239 492239 492239 4,92239 492239 492239 492239 492239 492239. .94 94 94 94 G/C3 94, IN 94 'OHHH 94' OHHH .94 94 94 94 9,4 OHHH 94 OHHH 94' HHHO 94 HHHO' 94 OHHH 94 HV 94 LBS 94 LBS 94 0 0 0 0 '0 3 0 0 3 0 0 3 0 -0 3. 0 0 3 0 0 3 '0 0 3 0 0 3 O. 0 3 0 0 3 0 0 3 0 0 3 0 0 3 0 0 3 0 0 3 0 0 3 0 0 3 O' 0 3 0 O' 3 0 0 3 0 0 3 0 0 3' 0 0 3 ~0 0 3 0 0 3 O 0 3 0 0 3 0 0 3 ~0 0 3 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68' 68 68 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 0000~0 000000 000000 OOOOOO O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000. 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ! 68' 000000 000000 000000 1 68 000.000 000000 000000 1 68 000000 000000 000000 I 68 000000 000000 '000000 ! 68 000000 000000 000000 Paga 17 DEPT , FSDL MINV HDCN GR NSDL MNOR HHCN FDSN PE HDR DFL DATA NDSN PELC HDX SP RECO'RDS NPHI QL HHR TEHS NRAT QS HHX DLOD DPHI RHOB HDRS DRHO CALI HMRS Page 18 e14o.ooO 7343,491 I .571 -12345. OOO 8100.:000 7343.49~ 1,571 375.598 8000.000 9099'.090 5.887 35.451' · 7900. 000 6563,491 3,874 181 ,904 7800.000 8049.-091 6.353 105.859 7700, .000 3052,091 12,077 75,320 7600.000 728.0.291 2.283 428,249 7500,000 84'96,691 2.714 408.049 150.095 15480.951' 2,1.91 -12345.000 150. 095 15480,951 2,191 368,27'6 55,206 15770,809 6.944 41 ,585 92,046 14868,379 3,845 176,436 65.862 15311,236 7,534 105,136 12705, 8.263 79. 284 129,370 15320,666 2,041 468,539 123,197 15901,951 2.191 413,443 2023 3 0 2 2023 3 256 2 2600 3 64 18 2314 2 143 5 3298 1 89 10 2329 5 112 8 1512 2 290 2 1449 3 304 2 .081 ,678 ,000 .574 · 081 ,678 · 009 ,546 .732 ,27'3 .816 · 123 ,514 .824 ,771 .524 ,197 ,993 ,253 .647 .625 .286 .416 ,741 · 443 ,539 .456 .16.8 ,119 ,515 ,460 .318 15378.344 3.642 0.000 123450000. 15378.344 3'.642 52.463 129.287 1 7518. 027 3. 769 13.758 I 08,44 0 16037,748 2,971 24,527 108,599 18101.863 2,201 12.949 84.596 16294.674 8.5'12 28.762 100.303 13590.598 2,884 75.898 I10,121 13555,541 4,023 77,787 97. i 05 ,376 · 083 0.000 4954.463 ,376 · 083 322,007 4808.744 ,329 -. 036 65.278 5041 ,895 ,329 ,044 164.778 46 04,736 ,250 -, 020 99,533 4677,596 · 332 ,008 1 i O, 837 5027,322 .448 .024 375,725 4837.888 ,474 -, 055 369.197 4765. 028 8.208 -.085 0.000 885.260 8,208 -, 085 21,067 801 ,416 7,273 -.010 3,986 915.400 7.402 -,024 7.369 787,168 5,926 .003 2,431 784.976 7.553 -,016 10.412 922,524 9,703 ,010 34..401 907,180 lO.iOl ,005 29.890 857,312 .i71 2.368 -12345.000 ,171 2.368 2.662 .266 2.211 28,208 ,141 2,418 5,497 ,217 2.292 9.447 -.108 2.828 13.277 ,172 2.366 2,335 ,223 2,282 2,451 ,062 8.500 -12345. 000 · 062 8.500 2.715 .032 8.23i 24. 047 ,037 9. 093 5.668 .023 9. 147 9.512 ,016 9,251 12.613 ,048 9, 062 2, 134 .061 9,102 2.419 DEPT. FSDL HINV HD.CN GR NSDL HNOR HHCN FDSN PE HDR DFL 'DATA HDSH PELC HDX SP RECORDS NPHI QL HHR TENS HRAT QS DL. OD DPHI RHOB HDRS DRHO CALI HHRS Pag~ i9 FILE TRAILER .File nam~ &GSFOI,~2 H-aximum length: 1024 TRAILER RECORDS Service name: Version #: File type: LO Next file: Date: Pag~ 2O ********************** FILE HEADER *********************** File name: .'003 Maximum length: 1024 Sepvice name: File'type: LO Version #: Previous ?ile: Date: MHEM CH. WH FN 'COUN STAT CTRY APIN LATI LONG SECT TOWH RANG EKB .EDF EGL PD LMF DMF. RUN TIHE DATE ,LCC LUll FL LUL ENGI W'ITN DD DL CBDt CBL ! TLI ~BL! TCS TLAB BHT NAT NT HSS DFD HVIS DFPH DFL RH RMF HFST MFSS R.HC INFORHATION CONTENTS 'ARCO i~LASKA INC. lA-26 API HUM KUPRRUK DATE LOGC NORTH SLOPE ....... 'ALASKA ....... USA ....... 22115. 000 ................... 0 De~. . Sec 05,e.,s,e e 11H ........................ ! OE ........................ t02. 080 .................... I O!. 000 .................... ~7. 000 .................. .... KB ! I ! e a · . .2140. 000 7/ 1/91 ................... 492239 ................ 5 e39 ............... NORTH SLOP.~' ...... NORTH SLOPE ...... HCKAV ...... BEAL ...... 8250. 000 .................. 8133. 000 .................. o o o ..... ,,. ....... . o.o o o ................: : , .ooo ................... 8124. 000 .................. 16.40. 000 .................. 2.140. 000 ..........' ........ 143. 000 .................. 143.0.00 .................. NEWDRILL ..... CIRCULATED ..... 10.900; ......... - ......... 38, O0.O ................... 8,5'00 .................... 5.900 .................. ,, 2.5t0 .................... 2. 420 .................... 73. O'O0, .. ................. MEAS .............. 3.230 .................. . . 50-829-22115 ED: 01-07-9 I · s s · i · ~ I . s a e s i · , · s I · s W ia ea Ie I I II II II d e II I Ia ail.lllll Illlliill iililSi lellelI l III,lit IlllII, I ItIIdII · IIlIIl, IIlllll I1,1111 I iii. .. e iisi iiii .i i till i$ i Illl II I Ills $. Illl '1 ll'l ,, S llll i1 elis II , · tl s Ill els ss · Iii ill s RECORDS UN I T ,i . · e . . e . . . s · d l i l i s i II II I . . II . ,it · s . II i i . i · e I ! s i I e s , , . . s s i s I I , 1 , l s . I 1 s l i i . * $ i , II i i , i i $ i , . l s I TYPE .CATG SIZE CODE 0 O 40 65 0 , O 40 65 0 O 40 65 0 0 20 65 O 0 20 65 0 O 20 65 0 O 4 68 0 O 34 65 '0 0 34 65 '0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 .0 2 79 0 O 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT O 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 ~8 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 1 4 68 O 2 20 65 0 2 20 '65 LB?G 0 2 4 68 CP 0 2 4 68 · 0 2 4 68 0 2 4 68 OHHM 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 O 2 12 65 OHHH 0 2 4 68 Pag~ ERROR 2i lINEN NCST I NFORMAT I ON RECORDS CONTENTS UHIT 66.000 .................................................. ME~S .............................................. 9.6~5 ................. , ................................. 8.500 ................................................... DEGF TYPE CATG 2 2 3 3 SIZE 4 i2 4 4 CODE ERROR 22 COMMENT RECORDS Wel Wel Wel Wel -' Wel I Location comment 1: 'SURFACE: 1 Location comment 2: I Location Comment 3: 1 Location Comment 4: I File Comment I File Comment 1 File Comment 1 Fil'e Comment. 635' FSL & 310' FWL HRI, ML, SDL/DSN RUN IN COMBINATION. TD NOT LOGGED DUE TO HOLE CONDITIONS. HEAD TENSION AND LINE TENSION ARE RECORDED 46,25' DEEP TO BOTTOM DUE TO SOFTWARE ERROR.. DXCO = +2.0 MMHOS & MXCO = -1.7 MMHOS. , LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOH ~NEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FT DEPT FT GA2 SDL GAPI GR SDL GAPI FDSH2 DSM2 CPS FDSN DSM2 CPS NDSN2 DSN2 CPS HDSN DSM2 CPS NPHI2 DSM2 DECP NPH! DSN2 DECP NEAT2 DSM2 C?C NEAT DSM2 C?C: DPHI2 SDL DECP .DPHI SDL DECP DRH02 SDL G?C3 DRHO SDL G?C3 FSDL2 SDL CPS FSDL SDL CPS NSDL2 SDL CPS NSDL SD[_ CPS DEPTH DEPTH 4550,00 7489,75 7489.75 7489 75 7489 75 7489 75 7489 75 7489 75 7489 75 7489 75 8140,00 8140,00 814o.oo 8140,00 8140.00 8140,00 8140,00 8140,00 8140,00 8140.00. Page 23 PE2 SDL PELC2 SDL QL2 SDL QS2 SDL RHO'B2 CRLI2 SDL HDR2' HRI HDX2 HRI HMR2 HR! HMX2 HR! HDRS2 HR! HHRS2 HRI HDCN2 HRI HHCN2 HRI DFL2 HRI $P2 HRI TENS2 SDL DLOD2 SDL G/C3 IH OHMM OHMM MHHO NHHO OHMM fly LBS LBS PE SDL PELC SDL QL SDL QS SDL RHOB SDL CRLI SDL HDR HRI HDX HRI HNR- HRI HMX HRI HDR$ HRI HMRS HRI HDCH HRI HNCH HRI DFL HRI SP HRI TEHS DLOD SDL G?C3 IN OHHN OHHH HHHO HHHO OHHH LBS LBS 7489.75 7489,75 7489.75 7489,75 7489.75 7489,75 7489,75 7489,75 7489,75 7489.,?5 7489,75 7489,75 7489.75 7489.75 7489,75 7.4S9.75 7489,75 7489,75 8140.08 8140,00 8140,00 8140,00 8i40,00 8140,00 8140.00 8140.00 8140,00 8140.00 8140.00 8140,00 8'140,00 8~40.00 8140.00 8140.00 8J40,00 .8140,00 DATA FORMAT SPEC'I F I CAT IONS ~*******************~ ENTRY BLOCKS ENTRY TYPE SIZE CODE 0 I 6G, P~g~ 24 ENTRY BLOCK LEGEND **** TYPE DESCRIPTION. 16' Datum ~peci'¢ication block ~ub-type 0 Terminatop ( no mope ent~itz ) DATA FORHAT SPEC I F I CAT IONS DATUM SPECIFICATION BLOCKS ************************************** HHEM SERVICE SERVICE AP1 APl APl APl FILE ID ORDER # UNIT LOG TYPE CLASS HOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT CR SOL FDSN DSH2 HDSH DSM2 NPHI .DSH2 HRAT DSH2 OPHI SDL DRHO. SDL ',FSDL SDL HSDL .SDL PE SDL PELC SDL aL 'SDL QS SDL RHOB SDL CALI SDL 492239 FT 0 492239 GAPI 94 492239 CPS 94 492239 CPS 94 492239 DECP' 94 492239 C/C 94 492239. DECP, 94 492239 G/C3 94 492239 CPS 94 492239. CPS 94 492239 94 492239 94 492239 94 492239 94 492239 -G/C3 94 492239 HDR HRI ' 492239 HD% HR! 49.2239 HMR HRI 492239 HMX HRI 492239 HDRS HRI. 492239 HHRS HRI 492239 HDCN HRI 492.239 HMCN HRI 492239 DFL HRI 492239 SP HRI 492239 ,MV TENS SDL 492239 LBS DLOD S'DL 492239 LBS IH 94 94 94 94 94 OHMM 94 OHMM 94 MMHO 94 94 MM~oH 94 94 94 94 0 0 0 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 '0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 '.0 0 4 0 0 4 0 0 4 3 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 , 2 2 2 2 2 2 2 2 2 4 0 4 0 ,4 0 4 0 4 0 4 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 O 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 4 0 4 0 4 0 1 68 1 68 I 68 1 68 I 68 I 68 I 68 1 68 ! 68 1 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000' 000000 000000 000000 000000 000000 1 68 · O0000O 000000 000000 1 68 I 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 000000 000000 000'000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page 25 DEPT FSDL HDR DFL 8140 '8147 0 2 8100 8147 254 2 0000 9096 74 16 7900 6850 143 5 ,000 ,49! ,000 ,392 :000 ,491' ,326 .240 ,O00 ,490 ,572 · 957 ,000 .690 ,183 ,602 DATA RECORDS GE FDSN NDSN HPHI NRAT DPHI HSDL PE PELC QL QS RHOB HDX HMR HHX HDRS HHRS HDCN SP TENS DLOD ....... _-__... _ ~ _ ..... _--. _ _ - ~ _ _ _ :-.~-., . . - _ ...... _ :~ ~ _.,~ _~ ..... _.. . 97,652 1'995,972 15382,422 ,382 8.322 ,163 16649,949 4,188 4,255 -,097 -.090 2,382 0.000 O.O00 O.O00 -12345.000 -12345.000 -12345 'O00 123450'000. 4852.460 817.308 97,652 1995,972 15382,422 ,382 8,322 ,163 16649,949 4,188 4,255 -,097 -,090 2,382 51.672 315.760 1-8.734 2.519 2.413 397.003 117,569 4765,028 789,360 66,437 2722,672 17601.215 .313 7.012 ,258 15979.379 3.224 3.764 -.077 .003 2.224 13,683 71.780 1.662 i8.572 i7,232 53.844 100.764 5114.755 93t,840 ' 88. 159 2302,344 16036,6719 ,338 7,521 , 151 15133,521 2,951 3,409 -, 004 -, 029 2,401 28,043 164,499. 1 I ,422 5,338 5,440 187. 334 121 . 026 4.896,175 873,204 7000. 000 65. 056 3339. 320 18258. 027 8570.490 15948. 094 2,638 2,602 89. 181 13. 040 99.298 I ,872 1 O, 775 I 03,421 48 08,744 856,764 DRHO CALl HNCN .138 8.5.00 -12345,000 .138 8.500 414.494 .046 8.500 58. 032 ,049 8,500 183,820 , 258 5,904 , 215 , 065 , 1 07 -, 066 2,295 8,500 9,561 9,763 1'04,595 1 02,428 7700. 000 100, 050 2407,981 16459,801 , 337 3289.0.91 13845.951 6,468 8,720 -. 0i2 117,669 32 , 601 118. 772 13.'776 14 . 1 04 8,632 92,979 5216,758 986,64 0 117,394 1498,616 1'3629,1 5849. 951 3,255 3,40.'3 76.440 375,5191 34,623 !23,305 48 08,744 915,4'00 ,000 091 066 ,.185 7,381 -.142 .113 ,004 2,885 8,500 15,622 70.903 64.011 ,464 9,820 ..166 .086 ,016 .016 2,376 8.500 2,360 2,237 423,672 447,077 ,486 I O. 194 ,241 . 154 -, 01 0 -, 026 2,252 8,500 2,446 2. 421 408,832 4! 3,020 .000 ,891 ,716 .350 Page 7600 7596 290 2 7500 I 0559 304 2 12,0,231 1441,699 13611,205. 17686,234 5,757 5,364 78.244 369.024 30,100 79,798 4648,452 864,436 26 DEPT FSDL HDR DFL GR NSDL HDX SP FDSN PE HNR TENS DRTR NDSN PELC D.LOD RECORDS NPHI QL HDRS NRAT QS HI'IRS DPHI RHOB HDCN DRHO CALI HNCN Page 27 FILE TRAILER File name: &GSFOI.003 Naximum length: 1Q24 TRAILER RECORDS Verzion #: File type: LO m~ Next f'ile: Date: Page 28 TAPE HEADER Service name: &GSF01 Previous tape: Date: 91/01/16 Comments: Origin: Tape name: 492239 Continuation #: 01 ********************** ~** FILE HEADER **** File name: ,001 Maximum length: 1024 Service name: File tppe: LO Version Previous ~ile: Date: MHEN CH WH FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DNF RUN TIME DATE LCC SON I. UN LUL ENGI WITH DD DL CBD i CBL! TLI BLI TCS TLAB BHT NAT liT li$S DFD liVlS DFPH DFL RN .RNF liFST liFSS RliC. I NFORMAT I ON RECORDS COHTEHTS UHIT ARCO ALASKA 'IHC. 1A-26 KUPARUK NORTH SLOPE ..... · ........ '. ALASKA .............. USA .............. 22115. 000 ......................... O Deg. 0 Min. O. 0 Sec. H .. 0 Deg 0 Min. O. 0 Sec. W., lin .............. 10E ............... 1 02,000 .......... 101.000 .......... ~7. 000, . . ........ I , ii i Ii ~ i , e , i i i e a i e ?/ 1/91 .......... 492239 ....... 5~939 ...... NORTH SLOP~ NORTH SLOPE licKAY BEAL 825 O. 0 O0 ........ 8133. 000 ........ 4632. O 00 ........ 4630. 000 ........ 14] .000, ........ 8124. 000 ........ ~ 640. 000 ........ 2~40.000 ........ 143. 000 ......... 143.00~ ......... NEWDRILL CI~CULRTED 1 0,90'0 ........... 38. 000 ........... 8,500 ............. 5.900 ............ 2,5~0 ............ 2,420 ............ 73,000 ........... NERS ...... 3,230 ............ lllIllIIlllIIIlI API NUN: 50-029-22115 ................ DATE LOGGED: 01-07-91 ........... ..... IeII IIII IIlI IIII IIlI IIlI IIlI IIIl IIll ~e ii e . I I I I III, lies iii, eelI Bill III, IllI Iii i , Ill I,· e , e , II . e II I e ! , , · ! , , , II I , 'ii , · ii e , I · i Ii e e · · e I. , . , , · · , , · ... · , , , .i e 4 e · , , e , · , .I , , , e , II·lie, i1111 illll |1111 I-lei ell, IIii III III Itl Il II . · , I I , II I I I I I I I · I '1 I I , . · I 1 I I TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 FT 0 3 FT 0 FT 0 3 0 3 0 3 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 FT 0 3 FT 0 3 FT 0 3 FT O 3 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 DEGF 0 i o 0 LB/G 0 2 CP 0 2 0 2 0 2 0 H H H 0 2 OHHH 0 2 DEGF 0 2 o 2 OHHH 0 2 SIZE ~Ii CODE 40 65 40 65 40 65 20 65 20 ' 65 20 65 4 68 34 65 34 65 2 65 3 65 3 65 4 68 4 68 4 68 2 65 2 65 2 65 2 79 4 68 8 65 2 79 10 65 10 65 20 65 20 65 20 65 20 65 4 68 · 4 68 4 68 4 68 4 68 '4 ~8 4 68 20 65 20 ,65 4 6@ 4 68 4 6@ 12 65 4 ~8 Pag~ ERROR 29 MHEM MCST CS BS I NFORMAT I ON RECORDS CONTENTS UNIT &&,O'O0 .................................................. ~E~ .............................................. 9.625... .......................... ~ ..................... 8.500 ................................................... DEGF TYPE CATG SIZE 4 12 4 4 CODE 65 68 ~8 Page ERROR COMMENT RECORDS Well Location Comment 1: suRFACE: 635' FSL & 310' FWL Well Loca%ion Comment 2: Well Location Comment 3': Well Location Comment 4: Well File Comment 1: HRI, ML, SDL/DSN RUN IN COMBINATION. TD NOT LOGGED DUE TO Well File Comment 2: HOLE CONDITIONS. HEAD TENSION AND LIHE TENSION ARE RECORDED Well File Comment 3: 46°25' DEEP TO BOTTOM DUE TO SOFTWARE ERROR. Well File Comment 4: DXCO = *2.0 NNHOS & MXCO = -1.? MMHOS. ** LIS tape written b~: ANCHORAGE OOMPUTING CENTER *~ *m All curve and tool mnemonic~ u~ed are thoz~ which mozt clo~lp match ~m ~ Halliburton curve and tool mnemonics. ~m HALLIBURTON TO SCHLUmBERgER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT GR3 SDL GAPI GR SDL GAPI FDSN3 DSN2 CPS FDSN DSH2 CPS NDSN3 DBN2 CPS NDSN DSN2 CPS' NPHI3 DSH2 DECP HPHI DSN2 DECP NEAT3 DSN2 C?C NRAT DSN2 C?C DPHI3 SDL. 'DECP DPHI SDL DECP DRH03 SDL G/C3 DRHO SDL FBDL3 SDL CPS FSDL SDL CPS NSDL3 SDL CPS NSDL SDL CPS 140.00 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 7492 O0 $1 40 O0 8140 O0 8140 O0 814.0 O0 8140 O0 8140 O0 8140.00 8140.00 8140.00 8140.00 Pag~ 31 PE3 PELC3 QL~ RHOBJ CA[I~ TENS3 -DLOD3 SDL SDL SDL SDL SDL SDL SDL SDL G?C3 IN LBS LBS PE SDL PELC. 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Maximum length: 1024 TRAILER RECORDS Version File type: LO Next File: Date: Page 35 FILE HE~DER **** File name: Service name: File type: LO Version #: Date: Maximum length: 1024 Previous ?ile: I FORM TIO RECORDS Page 36 MNEM CH WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF., EGL PD LNF DMF RUN TINE DATE LCC LUN FL LUL ENGI WITN DL CBD! :CBL1 TL! BL! :TCS .TLAB BHT HRT HT. HSS DFD MVIS DFPH DFL RM RMF fl. FST HF$S CONTENTS 'RRCO ALASKA INC, 1A-26 KUPARUK NORTH SLOPE ALASKA USA 22115. 000 .......... 0 Deg, 0 Hin, 0 0 Dag' 0 Hin, 0 llN ........... ' ..... i OE ................ 102.0:00~ . . . , .... · . , . I0! ,000 ............ 67,000 ...... , ...... IlS 2't 40, O00 ........... 7/ 1/91 ................ 30 ..................... 492239 ............. s 3,9 ............ .o T. SLOPi .... NORTH SLOPE .... HcKAY ..... BEAL .... 8250, 000 ............... 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Il·il leal It·l ,I · · il I I il il I i il l 41 i llill Il*il II11 *fill iii/ dill iiii illlf il*il 14111 iiii ii·il IIi1 iii ij41 i1· III iii Iii iii iii III ·111 · 11141 41111 ·1411 · i i · Iiii il 411 il .· I · · · · * ! · · · i · · i il · m · I 41 41 I I I · · I · · · I · il il il · · I I t 41 · m · I · I · · m il · I , I m m UNIT FT FT FT FT FT FT FT FT FT HR HR DEGF DEGF LB/G CP OHMH OHMM DEGF OHMM TYPE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 O. 0 O 0 0 0 0 0 0 0 .0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 CATG 0 0 0 0 0 0 0 0 0 0 0 0 3 3 3 3 3 3 0 O 0 0 0 0 0 0 0 0 3 3 3 3 3 3 2 4 1 1 2 2 2 2 2 2 2 2 2 2 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 2 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 CODE 65 65 65 65 65 65 65 65 65 65 65 68 65 65 65 79 79 65 65 65 65 68 68 6@ ERROR MNEN MCST MCSS BS I NFORNAT I ON RECORDS CONTENTS 66. 000 .................................................. NE~S ............................................. 9. 625 ....................... ~ ........................... 8.,500 ................................................... UNIT DEGF TYPE CATG Pag~ SIZE CODE ERROR 0 2: 4 68 0 2 12 65 0 3 4 68 0 3 4 68 ~? COMMENT RECORDS Well Location Comment 1: Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: · Well File Comment i: HRI, -Well. File Comment 2: Well File Comment 3: SURFACE: 635~ FSL & 310' FWL ML, SDL/DSN RUN IN COMBINATION. TD NOT LOGGED DUE TO HOLE.CONDITIONS, HEAD TENSION AND LINE TENSION ARE RECORDED 46.25' DEEP TO BOTTOM DUE TO SOFTWARE ERROR. Well File Comment 4: DXCO = +2,0 MMHOS & NXCO = -1.? MMHOS, ** LIS tape written'bp: ANCHORAGE CONPUTING CENTER ** All cup.ye and tool mnemonics used are tho$t ~hich most closel~ match · *.* Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER . TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 140. O0 814'0, O0 GR4 HR! GAP! GR HR! 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Ooo · 40.0. 000 300,000 200. ~0.00. TENS , i .. _ 41,371 1719.491 39.330 1690.347 41,121 1675,775 38,961 1617,487 44.431 1544,627 42,817 1421,768 59,455 1413.479 18,.077 1369,764 32.134 1340,620 42,132 1282,332 55,920 1253,188- 5.1,14.0 1238,616 DATA RECORDS Page DLOD . .... ~ .... ,, J , ....... ~ __ - _ - ~ :_ _- : _ _ - _ _ , _. , , =_~...__.,., _ ........ 312. 052 272.596 253.416 267,664 309,312 347.125 350.4'12 394,8~00 421, t 04 479.740 578.30 0 686,884 43 File name= Maximum length: !024 TRAILER RECORDS Ser¥ice name: File t~pe: LO Version Next ¢ile: Date: Page 44 REEL TRAILER .em. Service name: &GSF0! Date: 91/01/16 Origin: Hext reelj Comments: Reel name: 492239 Continuation ti: 01 ,. mmm · O~ ~0I'--- ENI.DO~ --- 96 --- 0I~ .... I00"ENIDO~ --- 8~I H~A~ -- (IHODHH HHfU~HH I m,m,m mmm 80/1:.0/1:6--- ~NIDO~ --- 0~I H6A~ - GHODHH HHG~/HH H~Y~ .SSOTAaSS 6UTB6O~ uo~anqTII~H Ag paonpoa6 mmm 6 C g:g:6'~, --- '-S 'N --- "zaa/o --- HI4~N ~HHH SQOIAHH~ HI. IN ~HHH ~G ~0 NIDIH0 HkSIN H~IAHHS ~CI H6A~ ........ - ..................... QHODHH HHG~/HH ~HHH 9NI&SI~ NOI~DI&IHHA H~ SI~ TYoPE REPR 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 ' 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 0 65 SIZE 30 30 30 30 30. 30 30 30 30 30 1.0 15 4 -25 10 22 22 25 4 4 4 20 4 4 4 4 20 4 4 20 4 4 20. 4 4 4 4 CATEGORY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 1 1 1 2 '2 2 2 2 2 2 2 2 2 2 '2 2 2 3 3 UNITS MNEM COMPONENT CN ARCO ALASKA INC. FN 1A-26 FL KUPARUK SECT '05 TOWN 11N RANG 10E COUN N. S · STAT ALASKA CTRY USA CONT NORTH AMERICA LUN 7612 LUL N. S · RUN 1 JTYP SFT / GR APIN 5002922115 ENGI HUCKFELDT WITN BEAL TLAB 0910.00 BHT DEGF 157 · MRT DEGF 157 · ST DEGF 4 · 0 DFT NEWDRILL DFD LB/G 10.8 DFV 38.0 DFPH 8 · 5 DFL F3 5.9 MSS CIRCULATED MST DEGF 72 · 0 RMS OHMM 2 · 51' MFSS CIRCULATED MFST DEGF 73 · 0 RMF oHMM 2.42 MCSS CIRCULATED MCST DEGF .66.0 RMC - OHMM 3 · 23 EKB F 102 · EDF F 101 · INFORMATION'RECORD ************************************************************* · TYPE 34 TYPE REPR SIZE CATEGORY MNEM UNITS COMPONENT 0 65 4 3 EPD F 0.0 0 65 4 3 BS IN 8.5 0 65 4 3 CS IN 9.62 0 6,5 4 3 CBD1 F 4632 0- 65 4 3 CBL1 F 4630 0 65 4 3 DD F 8250 0 65 4 3 DL F 8133 0 65 4 3 DMF F KB 0 65 4 3 LMF F KB 0 65 4' .3 BLI F 8047 ******************************************************************************* DATUM FORMAT SPECIFICATION RECORD ....... 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IH& 000' = ~S ~L6~ = S~H& 000'£~6;£0I = A&~ 000' = ~4H 000' = ~&& 000';~ = OdS& 000' = H~ 00L'L~08 = &EHQ :SHDO~ NOI&~DIAIDH~S Nl'l&¥O 0 99 I 99 89 99 0S~'666- 89 00~' 89 I 99 I 99 99 6L 0 9I II 6 8 FTP = HPRP = MTF = DEPT = GR = TSPD = FTP = HPRP .= MTF = 14.600 HYDP = 13 .000 FTPR = 14.600 290.280 HPFQ = 544.831 7847.700 TENS = 3655- 80.800 TEMP = 1.940 22.500 FTPC = 2754.000 14.800 HYDP = 1.4 .000 FTPR = 14.700 244.570 HPFQ = 540.620 VOLP = 0 HPQ = .000 STSW = -.019 SP = -19.990 LOAD = 49 THRS = 33.016 VOLP = 0 HPQ = .000 STSW = -.019 DEPT GR = TSPD = FTP = HPRP = MTF = 7797.700 53.800 23.000 14.700 .000 247.750 TENs = 3474 TEMP = 2.560 FTPC = 2718.300 HYDP = 15~ FTPR = 14.600 HPFQ = 542.884 SP = -19.990 LOAD = 48 THRS = 33.053 VOLP = 0 HPQ = .000 STSW = -.019 DEPT = GR = TSPD = FTP = HPRP = MTF = 7747.700 54.300 22.500 15.100 .000 388.000' TENS = 3506 SP = -19.990 TEMP. = 3.520 LOAD = 61 FTPC = 2663.200 THRS = 33.090 HYDP = 1'6' VOLP = 0 . 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