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Home My WebLink About190-0421. 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: Re-run cap string Development Exploratory 3. Address: 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 6,448' feet 5,978' feet true vertical 6,154' feet N/A feet Effective Depth measured 6,020' feet See Schematic feet true vertical 5,751' feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap string 3/8" 3,036' MD 2,953' TVD Tubing (size, grade, measured and true vertical depth) 5.5" 15.5# / L-80 2,940' MD 2,860' TVD Bkr, Iso, Iso, Iso, 2939, 3684, 4320, 2860, 3574, 4171, Packers and SSSV (type, measured and true vertical depth) Bkr, Camco SSSV 5055, 5921 MD 4852, 5458 TVD 282 MD / 282 TVD 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: 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: Chad Helgeson, Operations Engineer N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1185 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 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) 0 Gas-Mcf MD 228 Size 221' 804 2281327 0 22984 24 measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-042 50-283-20083-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029657 Beluga River - Undefinded Gas/Undefined WDSP Beluga River Unit (BRU) 214-26 Plugs Junk measured Length Production Liner 6,443' Casing Structural 6,146'6,443' 221'Conductor Surface Intermediate 30" 13-3/4" 221' 2,977' 5,600psi 3,450psi 7,510psi 2,977' 2,896' Burst Collapse 1,950psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Gavin Gluyas at 3:55 pm, Aug 14, 2025 BJM 10/3/25 Page 1/1 Well Name: BRU 214-26 Report Printed: 8/11/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-283-20083-00-00 Field Name:Beluga River State/Province:ALASKA Permit to Drill (PTD) #:190-042 Sundry #:325-254 Rig Name/No: Jobs Actual Start Date:4/23/2025 End Date: Report Number 3 Report Start Date 7/14/2025 Report End Date 7/15/2025 Last 24hr Summary PTW, JSA. MIRU capillary tubing truck. Test new foot valve opening pressure. 1500 psi opening. Pull soap skid offline. Install wooden spool and make up 3/8" SS tubing into injector head. Pull 3243' of cap string to surface. Remove foot valve and bench test. Opening pressure 1400 psi. Blank off 3/8" spool. Pressure test 3/8" tubing on spool to 3100 psi for 1 hr. Good test. Install new foot valve with opening pressure at 1500 psi. Stab on well. PT pack off and wellhead adapter 250/3500 psi. RIH and set cap string at 3036' RKB. RDMO & turn over to operations. _____________________________________________________________________________________ Updated by CAH 08-09-25 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00-00 30 13-3/8 9-5/8 RKB to MSL = 104.5 RKB to GL = 21.15 TD = 6,443 TVD = 6,154 PBTD = 6,020 ETVD = 5,751 Max Angle = 23 deg @ 4,900 Tubing Min ID = 4.562 TOC @2,985 4 5 8 9 10 11 12 13 14 16 18 19 20 20.b 21 22 24 25 Sterling Sands A B C 1 2 Beluga Sands D E F G H CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 310#X-52 BTC 221' 13-3/8"Surface 68#K-55 BTC 12.415''2,977' 9-5/8"Prod Casing 43.5#S-95 BTC 8.755''6,443' TUBING DETAILS 5.5''Production Tubing 15.5#L-80 BTC 4.95"2,940' 3/8 Capillary string 0.08# 0.049 2205 duplex Swagelok 1500 psi foot valve 0.0895 3,234 JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 282 4.562 TR-SSSV - Camco TRM-4E SSSV w/ 4.562" X" profile (locked open as Surface when Cap string is in well) 2 2,872 4.562 Sliding Sleeve - Baker CMU -Closed 4 2,939 6 Baker SC-2 Pkr, PBR 5 2,955 5.3 Sliding Sleeve 190-47 - Closed 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Packer - SC1-L 10 3,693 5.3 Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Packer - SC1-L 13 4,329 5.3 Sliding Sleeve 190-47 - Closed 14 4,424 4.892 Screen - Excluder 2000 Med (197 ft.) 16 4,630 4.892 Screen - Excluder 2000 Med (187 ft.) 18 4,827 4.892 Screen - Excluder 2000 Med (224 ft.) 19 5,055 6 Packer - SC1-L 20 5,064 5.3 Sliding Sleeve 190-47 - Closed 20.b 5,060 FISH: WRP, unset from 4400, unable to pull, left at ~5060 on 10/08/2018 21 5,105 4.892 Screen - Excluder 2000 Med (805 ft.) 22 5,921 6 Packer - Baker 192-60 9-5/8" Model "F" Permanent 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Sterling A 3,245' 3,369' 3,153' 3,272' 64'* 12 11/17/2005 Grvl Pkd/Open Sterling B 3,386' 3,510' 3,288' 3,407' 28'* 12 11/17/2005 Grvl Pkd/Open Sterling C 3,536' 3,676' 3,432' 3,566' 58'* 12 11/17/2005 Grvl Pkd/Open Beluga D 3,700' 3,942' 3,589' 3,817' 166'* 12 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161' 65'* 12 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577' 76'* 12 11/17/2005 Grvl Pkd/Open Beluga G 4,929' 5,332' 4,735' 5,108' 56'* 12 11/17/2005 Grvl Pkd/Open Beluga H 5,392' 5,908' 5,164' 5,646' 143'* 12 11/17/2005 Grvl Pkd/Open *Partially Perforated Interval PLEASE SEE ATTACHED PAGE FOR COMPLETE PERF LIST Cap String @ 3,036 (7/14/25) A _____________________________________________________________________________________ Updated by CAH 08-09-25 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 4/5/1986 PTD: 190-042 API: 50-283-20083-00-00 Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status ST A3 3,245' 3,250' 3,152' 3,157' 5' 1/11/2005 Grl Pkd/Open ST A4B 3,286' 3,288' 3,191' 3,193' 2' 9/24/1990 Grl Pkd/Open ST A4B 3,288' 3,325' 3,193' 3,230' 37' 1/11/2005 Grl Pkd/Open ST A5 3,349' 3,369' 3,252' 3,272' 20' 1/11/2005 Grl Pkd/Open ST B1 3,386' 3,394' 3,287' 3,295' 8' 1/11/2005 Grl Pkd/Open ST B2 3,424' 3,428' 3,324' 3,328' 4' 1/11/2005 Grl Pkd/Open ST B2 3,436' 3,448' 3,337' 3,349' 12' 1/11/2005 Grl Pkd/Open ST B4 3,506' 3,510' 3,403' 3,407' 4' 9/23/1986 Grl Pkd/Open ST C1 3,536' 3,566' 3,432' 3,462' 30' 9/23/1986 Grl Pkd/Open ST C2 3,579' 3,598' 3,473' 3,492' 19' 9/23/1986 Grl Pkd/Open ST C4 3,667' 3,676' 3,557' 3,566' 9' 1/11/2005 Grl Pkd/Open ST C5 - BEL D4 3,700' 3,846' 3,589' 3,726' 146' 9/23/1986 Grl Pkd/Open BEL D4 3,846' 3,851' 3,726' 3,731' 5' 1/11/2005 Grl Pkd/Open BEL D6 3,910' 3,916' 3,787' 3,793' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,922' 3,928' 3,798' 3,804' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,939' 3,942' 3,814' 3,817' 3' 1/11/2005 Grl Pkd/Open BEL E1 3,999' 4,006' 3,870' 3,877' 7' 9/23/1986 Grl Pkd/Open BEL E3 4,076' 4,077' 3,942' 3,943' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,077' 4,084' 3,943' 3,950' 7' 1/11/2005 Grl Pkd/Open BEL E3 4,084' 4,085' 3,950' 3,951' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,107' 4,113' 3,971' 3,977' 6' 1/11/2005 Grl Pkd/Open BEL E3 4,151' 4,156' 4,013' 4,018' 5' 1/11/2005 Grl Pkd/Open BEL E4 4,170' 4,175' 4,030' 4,035' 5' 1/11/2005 Grl Pkd/Open BEL E5 4,182' 4,183' 4,041' 4,042' 1' 9/23/1986 Grl Pkd/Open BEL E5 4,183' 4,188' 4,042' 4,047' 5' 1/11/2005 Grl Pkd/Open BEL E6 4,268' 4,270' 4,122' 4,124' 2' 9/23/1986 Grl Pkd/Open BEL E6 4,270' 4,281' 4,124' 4,135' 11' 1/11/2005 Grl Pkd/Open BEL E6 4,281' 4,290' 4,135' 4,144' 9' 1/11/2005 Grl Pkd/Open BEL E6 4,304' 4,309' 4,155' 4,160' 5' 1/11/2005 Grl Pkd/Open BEL F4 4,431' 4,432' 4,274' 4,275' 1' 9/23/1986 Grl Pkd/Open BEL F4 4,432' 4,437' 4,275' 4,280' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,502' 4,507' 4,340' 4,345' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,507' 4,515' 4,345' 4,353' 8' 1/11/2005 Grl Pkd/Open BEL F5 4,515' 4,520' 4,353' 4,358' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,520' 4,524' 4,358' 4,362' 4' 1/11/2005 Grl Pkd/Open BEL F5 4,524' 4,533' 4,362' 4,371' 9' 1/11/2005 Grl Pkd/Open BEL F6 4,552' 4,557' 4,386' 4,391' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,557' 4,558' 4,391' 4,392' 1' 9/23/1986 Grl Pkd/Open BEL F6 4,593' 4,598' 4,424' 4,429' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,605' 4,610' 4,436' 4,441' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,718' 4,723' 4,540' 4,545' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,739' 4,744' 4,559' 4,564' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,744' 4,752' 4,564' 4,572' 8' 1/11/2005 Grl Pkd/Open BEL F7 4,752' 4,757' 4,572' 4,577' 5' 1/11/2005 Grl Pkd/Open BEL G1 4,929' 4,934' 4,735' 4,740' 5' 1/11/2005 Grl Pkd/Open BEL G3 4,998' 5,003' 4,798' 4,803' 5' 1/11/2005 Grl Pkd/Open BEL G3 5,013' 5,018' 4,813' 4,818' 5' 1/11/2005 Grl Pkd/Open BEL G4 5,032' 5,042' 4,830' 4,840' 10' 1/11/2005 Grl Pkd/Open BEL G4 5,042' 5,043' 4,840' 4,841' 1' 9/23/1986 Grl Pkd/Open BEL G6 5,110' 5,122' 4,902' 4,914' 12' 1/11/2005 Grl Pkd/Open BEL G6 5,122' 5,125' 4,914' 4,917' 3' 1/11/2005 Grl Pkd/Open BEL G6 5,125' 5,130' 4,917' 4,922' 5' 1/11/2005 Grl Pkd/Open BEL H 5,322' 5,332' 5,099' 5,109' 10' 1/11/2005 Grl Pkd/Open BEL H2 5,392' 5,412' 5,164' 5,184' 20' 9/23/1986 Grl Pkd/Open BEL H7 / BEL H8 5,586' 5,652' 5,345' 5,407' 66' 9/23/1986 Grl Pkd/Open BEL H10 5,744' 5,764' 5,492' 5,512' 20' 1/11/2005 Grl Pkd/Open BEL H12 5,795' 5,796' 5,540' 5,541' 1' 1/11/2005 Grl Pkd/Open BEL H12 5,796' 5,810' 5,541' 5,555' 14' 9/23/1986 Grl Pkd/Open BEL H12 5,810' 5,812' 5,555' 5,557' 2' 1/11/2005 Grl Pkd/Open BEL H13 5,858' 5,872' 5,599' 5,613' 14' 1/11/2005 Grl Pkd/Open BEL H14 5,902' 5,908' 5,640' 5,646' 6' 1/11/2005 Grl Pkd/Open BEL I 6,088' 6,100' 5,815' 5,827' 12' 9/13/1990 Isolated 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: Instal cap string Development Exploratory 3. Address: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 6,448' feet 5,978' feet true vertical 6,154' feet N/A feet Effective Depth measured 6,020' feet See Schematic feet true vertical 5,751' feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap string 3/8" 3,234' MD 3,142' TVD Tubing (size, grade, measured and true vertical depth)5.5" 15.5# / L-80 2,940' MD 2,860' TVD Bkr, Iso, Iso, Iso, 2939, 3684, 4320, 2860, 3574, 4171, Packers and SSSV (type, measured and true vertical depth)Bkr, Camco SSSV 5055, 5921 MD 4852, 5458 TVD 282 MD / 282 TVD 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: 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: Chad Helgeson, Operations Engineer 325-254 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1335 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 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) 0 Gas-Mcf MD 220 Size 221' 755 2271436 0 28796 23 measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-042 50-283-20083-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029657 Beluga River - Undefinded Gas/Undefined WDSP Beluga River Unit (BRU) 214-26 Plugs Junk measured Length Production Liner 6,443' Casing Structural 6,146'6,443' 221'Conductor Surface Intermediate 30" 13-3/4" 221' 2,977' 5,600psi 3,450psi 7,510psi 2,977'2,896' Burst Collapse 1,950psi p k ft t Fra O s 6. A G L PG , 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 10:36 am, Jun 05, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.04 19:34:52 - 08'00' Noel Nocas (4361) DSR-6/18/25BJM 9/23/25 RBDMS JSB 061325 Page 1/1 Well Name: BRU 214-26 Report Printed: 5/21/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-283-20083-00-00 Field Name:Beluga River State/Province:ALASKA Permit to Drill (PTD) #:190-042 Sundry #:325-254 Rig Name/No: Jobs Actual Start Date:4/23/2025 End Date: Report Number 2 Report Start Date 5/13/2025 Report End Date 5/14/2025 Last 24hr Summary MIRU Hak Capillary Unit with 3/8" tubing. PT pack off assembly 250/2000 psi. Ran cap string to 3234' RKB. Install hanger assembly. Rig down. _____________________________________________________________________________________ Updated by DMA 05-30-25 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00-00 30” 13-3/8” 9-5/8” RKB to MSL = 104.5’ RKB to GL = 21.15’ TD = 6,443’ TVD = 6,154’ PBTD = 6,020’ ETVD = 5,751’ Max Angle = 23 deg @ 4,900’ Tubing Min ID = 4.562” TOC @2,985” 4 5 8 9 10 11 12 13 14 16 18 19 20 20.b 21 22 24 25 Sterling Sands A B C 1 2 Beluga Sands D E F G H CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 310#X-52 BTC 221' 13-3/8"Surface 68#K-55 BTC 12.415''2,977' 9-5/8"Prod Casing 43.5#S-95 BTC 8.755''6,443' TUBING DETAILS 5.5''Production Tubing 15.5#L-80 BTC 4.95"2,940' 3/8” Capillary string 0.08# 0.049 2205 duplex Swagelok 0.0895”3,234’ JEWELRY DETAIL Production String ID.Depth MD (ft.)ID (in.)Description 1 282 4.562 TR-SSSV - Camco TRM-4E SSSV w/ 4.562" X" profile (locked open as Surface when Cap string is in well) 2 2,872 4.562 Sliding Sleeve - Baker CMU -Closed 4 2,939 6 Baker SC-2 Pkr, PBR 5 2,955 5.3 Sliding Sleeve 190-47 - Closed 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Packer - SC1-L 10 3,693 5.3 Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Packer - SC1-L 13 4,329 5.3 Sliding Sleeve 190-47 - Closed 14 4,424 4.892 Screen - Excluder 2000 Med (197 ft.) 16 4,630 4.892 Screen - Excluder 2000 Med (187 ft.) 18 4,827 4.892 Screen - Excluder 2000 Med (224 ft.) 19 5,055 6 Packer - SC1-L 20 5,064 5.3 Sliding Sleeve 190-47 - Closed 20.b 5,060 FISH: WRP, unset from 4400’, unable to pull, left at ~5060’ on 10/08/2018 21 5,105 4.892 Screen - Excluder 2000 Med (805 ft.) 22 5,921 6 Packer - Baker 192-60 9-5/8" Model "F" Permanent 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status Sterling A 3,245'3,369'3,153'3,272'64'*12 11/17/2005 Grvl Pkd/Open Sterling B 3,386'3,510'3,288'3,407'28'*12 11/17/2005 Grvl Pkd/Open Sterling C 3,536'3,676'3,432'3,566'58'*12 11/17/2005 Grvl Pkd/Open Beluga D 3,700'3,942'3,589'3,817'166'*12 11/17/2005 Grvl Pkd/Open Beluga E 3,999'4,309'3,871'4,161'65'*12 11/17/2005 Grvl Pkd/Open Beluga F 4,431'4,757'4,274'4,577'76'*12 11/17/2005 Grvl Pkd/Open Beluga G 4,929'5,332'4,735'5,108'56'*12 11/17/2005 Grvl Pkd/Open Beluga H 5,392'5,908'5,164'5,646'143'*12 11/17/2005 Grvl Pkd/Open *Partially Perforated Interval PLEASE SEE ATTACHED PAGE FOR COMPLETE PERF LIST Cap String @ 3,234’ (5/13/25) A _____________________________________________________________________________________ Updated by DMA 05-30-25 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 4/5/1986 PTD: 190-042 API: 50-283-20083-00-00 Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status ST A3 3,245' 3,250' 3,152' 3,157' 5' 1/11/2005 Grl Pkd/Open ST A4B 3,286' 3,288' 3,191' 3,193' 2' 9/24/1990 Grl Pkd/Open ST A4B 3,288' 3,325' 3,193' 3,230' 37' 1/11/2005 Grl Pkd/Open ST A5 3,349' 3,369' 3,252' 3,272' 20' 1/11/2005 Grl Pkd/Open ST B1 3,386' 3,394' 3,287' 3,295' 8' 1/11/2005 Grl Pkd/Open ST B2 3,424' 3,428' 3,324' 3,328' 4' 1/11/2005 Grl Pkd/Open ST B2 3,436' 3,448' 3,337' 3,349' 12' 1/11/2005 Grl Pkd/Open ST B4 3,506' 3,510' 3,403' 3,407' 4' 9/23/1986 Grl Pkd/Open ST C1 3,536' 3,566' 3,432' 3,462' 30' 9/23/1986 Grl Pkd/Open ST C2 3,579' 3,598' 3,473' 3,492' 19' 9/23/1986 Grl Pkd/Open ST C4 3,667' 3,676' 3,557' 3,566' 9' 1/11/2005 Grl Pkd/Open ST C5 - BEL D4 3,700' 3,846' 3,589' 3,726' 146' 9/23/1986 Grl Pkd/Open BEL D4 3,846' 3,851' 3,726' 3,731' 5' 1/11/2005 Grl Pkd/Open BEL D6 3,910' 3,916' 3,787' 3,793' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,922' 3,928' 3,798' 3,804' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,939' 3,942' 3,814' 3,817' 3' 1/11/2005 Grl Pkd/Open BEL E1 3,999' 4,006' 3,870' 3,877' 7' 9/23/1986 Grl Pkd/Open BEL E3 4,076' 4,077' 3,942' 3,943' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,077' 4,084' 3,943' 3,950' 7' 1/11/2005 Grl Pkd/Open BEL E3 4,084' 4,085' 3,950' 3,951' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,107' 4,113' 3,971' 3,977' 6' 1/11/2005 Grl Pkd/Open BEL E3 4,151' 4,156' 4,013' 4,018' 5' 1/11/2005 Grl Pkd/Open BEL E4 4,170' 4,175' 4,030' 4,035' 5' 1/11/2005 Grl Pkd/Open BEL E5 4,182' 4,183' 4,041' 4,042' 1' 9/23/1986 Grl Pkd/Open BEL E5 4,183' 4,188' 4,042' 4,047' 5' 1/11/2005 Grl Pkd/Open BEL E6 4,268' 4,270' 4,122' 4,124' 2' 9/23/1986 Grl Pkd/Open BEL E6 4,270' 4,281' 4,124' 4,135' 11' 1/11/2005 Grl Pkd/Open BEL E6 4,281' 4,290' 4,135' 4,144' 9' 1/11/2005 Grl Pkd/Open BEL E6 4,304' 4,309' 4,155' 4,160' 5' 1/11/2005 Grl Pkd/Open BEL F4 4,431' 4,432' 4,274' 4,275' 1' 9/23/1986 Grl Pkd/Open BEL F4 4,432' 4,437' 4,275' 4,280' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,502' 4,507' 4,340' 4,345' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,507' 4,515' 4,345' 4,353' 8' 1/11/2005 Grl Pkd/Open BEL F5 4,515' 4,520' 4,353' 4,358' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,520' 4,524' 4,358' 4,362' 4' 1/11/2005 Grl Pkd/Open BEL F5 4,524' 4,533' 4,362' 4,371' 9' 1/11/2005 Grl Pkd/Open BEL F6 4,552' 4,557' 4,386' 4,391' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,557' 4,558' 4,391' 4,392' 1' 9/23/1986 Grl Pkd/Open BEL F6 4,593' 4,598' 4,424' 4,429' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,605' 4,610' 4,436' 4,441' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,718' 4,723' 4,540' 4,545' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,739' 4,744' 4,559' 4,564' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,744' 4,752' 4,564' 4,572' 8' 1/11/2005 Grl Pkd/Open BEL F7 4,752' 4,757' 4,572' 4,577' 5' 1/11/2005 Grl Pkd/Open BEL G1 4,929' 4,934' 4,735' 4,740' 5' 1/11/2005 Grl Pkd/Open BEL G3 4,998' 5,003' 4,798' 4,803' 5' 1/11/2005 Grl Pkd/Open BEL G3 5,013' 5,018' 4,813' 4,818' 5' 1/11/2005 Grl Pkd/Open BEL G4 5,032' 5,042' 4,830' 4,840' 10' 1/11/2005 Grl Pkd/Open BEL G4 5,042' 5,043' 4,840' 4,841' 1' 9/23/1986 Grl Pkd/Open BEL G6 5,110' 5,122' 4,902' 4,914' 12' 1/11/2005 Grl Pkd/Open BEL G6 5,122' 5,125' 4,914' 4,917' 3' 1/11/2005 Grl Pkd/Open BEL G6 5,125' 5,130' 4,917' 4,922' 5' 1/11/2005 Grl Pkd/Open BEL H 5,322' 5,332' 5,099' 5,109' 10' 1/11/2005 Grl Pkd/Open BEL H2 5,392' 5,412' 5,164' 5,184' 20' 9/23/1986 Grl Pkd/Open BEL H7 / BEL H8 5,586' 5,652' 5,345' 5,407' 66' 9/23/1986 Grl Pkd/Open BEL H10 5,744' 5,764' 5,492' 5,512' 20' 1/11/2005 Grl Pkd/Open BEL H12 5,795' 5,796' 5,540' 5,541' 1' 1/11/2005 Grl Pkd/Open BEL H12 5,796' 5,810' 5,541' 5,555' 14' 9/23/1986 Grl Pkd/Open BEL H12 5,810' 5,812' 5,555' 5,557' 2' 1/11/2005 Grl Pkd/Open BEL H13 5,858' 5,872' 5,599' 5,613' 14' 1/11/2005 Grl Pkd/Open BEL H14 5,902' 5,908' 5,640' 5,646' 6' 1/11/2005 Grl Pkd/Open BEL I 6,088' 6,100' 5,815' 5,827' 12' 9/13/1990 Isolated 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install cap string 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,443'N/A Casing Collapse Structural Conductor Surface 1,950psi Intermediate Production 5,600psi Liner Packers and SSSV Type: Camco SSSV; Packers and SSSV MD (ft) and TVD (ft):SSSV 282'MD/TVD; 2,939'MD/2,860'TVD; 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker SC2 Pkr; 3 Baker SC1-L Iso Packers; 1 Baker F Perm Pkr 3,684' 4,320' 5,055' MD - 3,574' 4,171' 4,852' TVD; 5,921'MD/5,658'TVD 6,145'6,020'5,751' Beluga :River Sterling-Beluga Gas 30" 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 214-26CO 802A Same 6,148'9-5/8" ~384psi 6,443' 5,978' Length May 6, 2025 5-1/2" 6,443' Perforation Depth MD (ft): See Attached Schematic 3,450psi 221'221' 2,977' Size 221' 2, 977' MD Hilcorp Alaska, LLC Proposed Pools: 15.5# / L-80 TVD Burst 2,940' 7,510psi 2,896' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 190-042 50-283-20083-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2025.04.24 14:06:29 -08'00' 325-254 By Grace Christianson at 2:49 pm, Apr 24, 2025 DSR-4/29/25A.Dewhurst 29APR25BJM 4/28/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.30 14:56:35 -08'00'04/30/25 RBDMS JSB 050125 Well Prognosis Well Name: BRU 214-26 API Number: 50-283-20083-00-00 Current Status: Gas Producer Permit to Drill Number: 190-042 First Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (M) Maximum Expected BHP: ~582 psi @ 5600’ TVD (Based on 2018 Survey) Max. Potential Surface Pressure: ~384 psi (Based on 0.035 psi/ft gas gradient to surface) Applicable Frac Gradient: NA Cap string only, no new perforations Shallowest Allowable Perf TVD: NA – No perforations to be added Well Status: Gas producer making ~1200 mcfd, ~750 bwpd @ 15psi, dropping 1 soap stick every 15-20 minutes. Brief Well Summary: Originally drilled in 1990 as a dual string infill development well. After drilling to 4602' MD the BHA stuck during a short trip - no luck fishing and the well was sidetracked from 3331' MD. Completed from the Sterling A thru the Beluga H. The well came online making 17-21 MMCFD. In 2005 the well was re-completed to a single string gravel pack completion. The well returned to production making 23 MMscfd and lots of water. This is the largest water producer in the field. The purpose of this work/sundry is to set a 3/8” stainless steel capillary string to inject liquid soap downhole and keep the well from slugging every time a soap stick is dropped. This well has a SSSV as it is within 660ft radius of the offices/camp. Per 20AAC25.265(d)(4) the tubing retrievable SCSSSV will be bypassed while there is a capillary string installed in this well. Notes Regarding Wellbore Condition x 5.5” gravel pack completion x Well flows 700-1000 bwpd x Inclination o Max deviation of 17.4° @ 1400’ MD Procedure: 1. Lockout/defeat SCSSSV (tag per 20AAC25.265) 2. Ensure cap string is prefilled with liquid foamer in string 3. RU Cap String Truck 4. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Remove soap launcher. Install pack-off and pressure test against swab valve to 1500 psi. 5. RIH with 3/8” capillary string to ±3250’ MD. 6. Install slips and connect tubing to chemical injection pump. 7. Set spool of remaining line near well 8. RD cap string unit, and turn well over to production. 9. Monitor results for a day, if soaping does not meet flow requirements, adjust depth of injection point and adjust rates of foamer injection to optimize rate. 10. Pump defoamer as needed into flowline downstream of wing valve. Well Prognosis Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. 660 ft Radius Map _____________________________________________________________________________________ Updated by JMF 05-31-23 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 30” 13-3/8” 9-5/8” RKB to MSL = 104.5’ RKB to GL = 21.15’ TD = 6,443’ TVD = 6,154’ PBTD = 6,020’ ETVD = 5,751’ Max Angle = 23 deg @ 4,900’ Tubing Min ID = 4.562” TOC @2,985” 4 5 8 9 10 11 12 13 14 16 18 19 20 20.b 21 22 24 25 Sterling Sands A B C 1 2 Beluga Sands D E F G H CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 310#X-52 BTC 221' 13-3/8"Surface 68#K-55 BTC 12.415''2,977' 9-5/8"Prod Casing 43.5#S-95 BTC 8.755''6,443' TUBING DETAILS 5.5''Production Tubing 15.5#L-80 BTC 4.95"2,940' JEWELRY DETAIL Production String ID.Depth MD (ft.)ID (in.)Description 1 282 4.562 TR-SSSV - Camco TRM-4E SSSV w/ 4.562" X" profile 2 2,872 4.562 Sliding Sleeve - Baker CMU -Closed 4 2,939 6 Baker SC-2 Pkr, PBR 5 2,955 5.3 Sliding Sleeve 190-47 - Closed 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Packer - SC1-L 10 3,693 5.3 Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Packer - SC1-L 13 4,329 5.3 Sliding Sleeve 190-47 - Closed 14 4,424 4.892 Screen - Excluder 2000 Med (197 ft.) 16 4,630 4.892 Screen - Excluder 2000 Med (187 ft.) 18 4,827 4.892 Screen - Excluder 2000 Med (224 ft.) 19 5,055 6 Packer - SC1-L 20 5,064 5.3 Sliding Sleeve 190-47 - Closed 20.b 5,060 FISH: WRP, unset from 4400’, unable to pull, left at ~5060’ on 10/08/2018 21 5,105 4.892 Screen - Excluder 2000 Med (805 ft.) 22 5,921 6 Packer - Baker 192-60 9-5/8" Model "F" Permanent 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status Sterling A 3,245'3,369'3,153'3,272'64'*12 11/17/2005 Grvl Pkd/Open Sterling B 3,386'3,510'3,288'3,407'28'*12 11/17/2005 Grvl Pkd/Open Sterling C 3,536'3,676'3,432'3,566'58'*12 11/17/2005 Grvl Pkd/Open Beluga D 3,700'3,942'3,589'3,817'166'*12 11/17/2005 Grvl Pkd/Open Beluga E 3,999'4,309'3,871'4,161'65'*12 11/17/2005 Grvl Pkd/Open Beluga F 4,431'4,757'4,274'4,577'76'*12 11/17/2005 Grvl Pkd/Open Beluga G 4,929'5,332'4,735'5,108'56'*12 11/17/2005 Grvl Pkd/Open Beluga H 5,392'5,908'5,164'5,646'143'*12 11/17/2005 Grvl Pkd/Open ///p 11/17/2005 Grvl Pkd/Open 11/17/2005 GlPkd/O *Partially Perforated Interval PLEASE SEE ATTACHED PAGE FOR COMPLETE PERF LIST Squeezed perfs not listed from 3188.5' - 3192' @ 4 spf, part of a cement squeeze. -bjm _____________________________________________________________________________________ Updated by DMA 05-25-23 SCHEMATIC Beluga River Unit Well: BRU 214-26 Last Completed: 4/5/1986 PTD: 186-010 API: 50-283-20079-00 Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status ST A3 3,245' 3,250' 3,152' 3,157' 5' 1/11/2005 Grl Pkd/Open ST A4B 3,286' 3,288' 3,191' 3,193' 2' 9/24/1990 Grl Pkd/Open ST A4B 3,288' 3,325' 3,193' 3,230' 37' 1/11/2005 Grl Pkd/Open ST A5 3,349' 3,369' 3,252' 3,272' 20' 1/11/2005 Grl Pkd/Open ST B1 3,386' 3,394' 3,287' 3,295' 8' 1/11/2005 Grl Pkd/Open ST B2 3,424' 3,428' 3,324' 3,328' 4' 1/11/2005 Grl Pkd/Open ST B2 3,436' 3,448' 3,337' 3,349' 12' 1/11/2005 Grl Pkd/Open ST B4 3,506' 3,510' 3,403' 3,407' 4' 9/23/1986 Grl Pkd/Open ST C1 3,536' 3,566' 3,432' 3,462' 30' 9/23/1986 Grl Pkd/Open ST C2 3,579' 3,598' 3,473' 3,492' 19' 9/23/1986 Grl Pkd/Open ST C4 3,667' 3,676' 3,557' 3,566' 9' 1/11/2005 Grl Pkd/Open ST C5 - BEL D4 3,700' 3,846' 3,589' 3,726' 146' 9/23/1986 Grl Pkd/Open BEL D4 3,846' 3,851' 3,726' 3,731' 5' 1/11/2005 Grl Pkd/Open BEL D6 3,910' 3,916' 3,787' 3,793' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,922' 3,928' 3,798' 3,804' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,939' 3,942' 3,814' 3,817' 3' 1/11/2005 Grl Pkd/Open BEL E1 3,999' 4,006' 3,870' 3,877' 7' 9/23/1986 Grl Pkd/Open BEL E3 4,076' 4,077' 3,942' 3,943' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,077' 4,084' 3,943' 3,950' 7' 1/11/2005 Grl Pkd/Open BEL E3 4,084' 4,085' 3,950' 3,951' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,107' 4,113' 3,971' 3,977' 6' 1/11/2005 Grl Pkd/Open BEL E3 4,151' 4,156' 4,013' 4,018' 5' 1/11/2005 Grl Pkd/Open BEL E4 4,170' 4,175' 4,030' 4,035' 5' 1/11/2005 Grl Pkd/Open BEL E5 4,182' 4,183' 4,041' 4,042' 1' 9/23/1986 Grl Pkd/Open BEL E5 4,183' 4,188' 4,042' 4,047' 5' 1/11/2005 Grl Pkd/Open BEL E6 4,268' 4,270' 4,122' 4,124' 2' 9/23/1986 Grl Pkd/Open BEL E6 4,270' 4,281' 4,124' 4,135' 11' 1/11/2005 Grl Pkd/Open BEL E6 4,281' 4,290' 4,135' 4,144' 9' 1/11/2005 Grl Pkd/Open BEL E6 4,304' 4,309' 4,155' 4,160' 5' 1/11/2005 Grl Pkd/Open BEL F4 4,431' 4,432' 4,274' 4,275' 1' 9/23/1986 Grl Pkd/Open BEL F4 4,432' 4,437' 4,275' 4,280' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,502' 4,507' 4,340' 4,345' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,507' 4,515' 4,345' 4,353' 8' 1/11/2005 Grl Pkd/Open BEL F5 4,515' 4,520' 4,353' 4,358' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,520' 4,524' 4,358' 4,362' 4' 1/11/2005 Grl Pkd/Open BEL F5 4,524' 4,533' 4,362' 4,371' 9' 1/11/2005 Grl Pkd/Open BEL F6 4,552' 4,557' 4,386' 4,391' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,557' 4,558' 4,391' 4,392' 1' 9/23/1986 Grl Pkd/Open BEL F6 4,593' 4,598' 4,424' 4,429' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,605' 4,610' 4,436' 4,441' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,718' 4,723' 4,540' 4,545' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,739' 4,744' 4,559' 4,564' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,744' 4,752' 4,564' 4,572' 8' 1/11/2005 Grl Pkd/Open BEL F7 4,752' 4,757' 4,572' 4,577' 5' 1/11/2005 Grl Pkd/Open BEL G1 4,929' 4,934' 4,735' 4,740' 5' 1/11/2005 Grl Pkd/Open BEL G3 4,998' 5,003' 4,798' 4,803' 5' 1/11/2005 Grl Pkd/Open BEL G3 5,013' 5,018' 4,813' 4,818' 5' 1/11/2005 Grl Pkd/Open BEL G4 5,032' 5,042' 4,830' 4,840' 10' 1/11/2005 Grl Pkd/Open BEL G4 5,042' 5,043' 4,840' 4,841' 1' 9/23/1986 Grl Pkd/Open BEL G6 5,110' 5,122' 4,902' 4,914' 12' 1/11/2005 Grl Pkd/Open BEL G6 5,122' 5,125' 4,914' 4,917' 3' 1/11/2005 Grl Pkd/Open BEL G6 5,125' 5,130' 4,917' 4,922' 5' 1/11/2005 Grl Pkd/Open BEL H 5,322' 5,332' 5,099' 5,109' 10' 1/11/2005 Grl Pkd/Open BEL H2 5,392' 5,412' 5,164' 5,184' 20' 9/23/1986 Grl Pkd/Open BEL H7 / BEL H8 5,586' 5,652' 5,345' 5,407' 66' 9/23/1986 Grl Pkd/Open BEL H10 5,744' 5,764' 5,492' 5,512' 20' 1/11/2005 Grl Pkd/Open BEL H12 5,795' 5,796' 5,540' 5,541' 1' 1/11/2005 Grl Pkd/Open BEL H12 5,796' 5,810' 5,541' 5,555' 14' 9/23/1986 Grl Pkd/Open BEL H12 5,810' 5,812' 5,555' 5,557' 2' 1/11/2005 Grl Pkd/Open BEL H13 5,858' 5,872' 5,599' 5,613' 14' 1/11/2005 Grl Pkd/Open BEL H14 5,902' 5,908' 5,640' 5,646' 6' 1/11/2005 Grl Pkd/Open BEL I 6,088' 6,100' 5,815' 5,827' 12' 9/13/1990 Isolated _____________________________________________________________________________________ Updated by CAH 4-14-25 PROPOSED Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 30” 13-3/8” 9-5/8” RKB to MSL = 104.5’ RKB to GL = 21.15’ TD = 6,443’ TVD = 6,154’ PBTD = 6,020’ ETVD = 5,751’ Max Angle = 23 deg @ 4,900’ Tubing Min ID = 4.562” TOC @2,985” 4 5 8 9 10 11 12 13 14 16 18 19 20 20.b 21 22 24 25 Sterling Sands A B C 1 2 Beluga Sands D E F G H CASING DETAIL Size Type WT Grade Conn ID Btm 30''Conductor 310#X-52 BTC 221' 13-3/8"Surface 68#K-55 BTC 12.415''2,977' 9-5/8"Prod Casing 43.5#S-95 BTC 8.755''6,443' TUBING DETAILS 5.5''Production Tubing 15.5#L-80 BTC 4.95"2,940' 3/8” Capillary string 0.08# 0.049 2205 duplex Swagelok 0.0895”±3250’ JEWELRY DETAIL Production String ID.Depth MD (ft.)ID (in.)Description 1 282 4.562 TR-SSSV - Camco TRM-4E SSSV w/ 4.562" X" profile (locked open as Surface when Cap string is in well) 2 2,872 4.562 Sliding Sleeve - Baker CMU -Closed 4 2,939 6 Baker SC-2 Pkr, PBR 5 2,955 5.3 Sliding Sleeve 190-47 - Closed 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Packer - SC1-L 10 3,693 5.3 Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Packer - SC1-L 13 4,329 5.3 Sliding Sleeve 190-47 - Closed 14 4,424 4.892 Screen - Excluder 2000 Med (197 ft.) 16 4,630 4.892 Screen - Excluder 2000 Med (187 ft.) 18 4,827 4.892 Screen - Excluder 2000 Med (224 ft.) 19 5,055 6 Packer - SC1-L 20 5,064 5.3 Sliding Sleeve 190-47 - Closed 20.b 5,060 FISH: WRP, unset from 4400’, unable to pull, left at ~5060’ on 10/08/2018 21 5,105 4.892 Screen - Excluder 2000 Med (805 ft.) 22 5,921 6 Packer - Baker 192-60 9-5/8" Model "F" Permanent 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status Sterling A 3,245'3,369'3,153'3,272'64'*12 11/17/2005 Grvl Pkd/Open Sterling B 3,386'3,510'3,288'3,407'28'*12 11/17/2005 Grvl Pkd/Open Sterling C 3,536'3,676'3,432'3,566'58'*12 11/17/2005 Grvl Pkd/Open Beluga D 3,700'3,942'3,589'3,817'166'*12 11/17/2005 Grvl Pkd/Open Beluga E 3,999'4,309'3,871'4,161'65'*12 11/17/2005 Grvl Pkd/Open Beluga F 4,431'4,757'4,274'4,577'76'*12 11/17/2005 Grvl Pkd/Open Beluga G 4,929'5,332'4,735'5,108'56'*12 11/17/2005 Grvl Pkd/Open Beluga H 5,392'5,908'5,164'5,646'143'*12 11/17/2005 Grvl Pkd/Open ///p 11/17/2005 Grvl Pkd/Open 11/17/2005 GlPkd/O *Partially Perforated Interval PLEASE SEE ATTACHED PAGE FOR COMPLETE PERF LIST _____________________________________________________________________________________ Updated by CAH 4-14-25 PROPOSED Beluga River Unit Well: BRU 214-26 Last Completed: 4/5/1986 PTD: 186-010 API: 50-283-20079-00 Sands Top MD Btm MD Top TVD Btm TVD Amt Date Status ST A3 3,245' 3,250' 3,152' 3,157' 5' 1/11/2005 Grl Pkd/Open ST A4B 3,286' 3,288' 3,191' 3,193' 2' 9/24/1990 Grl Pkd/Open ST A4B 3,288' 3,325' 3,193' 3,230' 37' 1/11/2005 Grl Pkd/Open ST A5 3,349' 3,369' 3,252' 3,272' 20' 1/11/2005 Grl Pkd/Open ST B1 3,386' 3,394' 3,287' 3,295' 8' 1/11/2005 Grl Pkd/Open ST B2 3,424' 3,428' 3,324' 3,328' 4' 1/11/2005 Grl Pkd/Open ST B2 3,436' 3,448' 3,337' 3,349' 12' 1/11/2005 Grl Pkd/Open ST B4 3,506' 3,510' 3,403' 3,407' 4' 9/23/1986 Grl Pkd/Open ST C1 3,536' 3,566' 3,432' 3,462' 30' 9/23/1986 Grl Pkd/Open ST C2 3,579' 3,598' 3,473' 3,492' 19' 9/23/1986 Grl Pkd/Open ST C4 3,667' 3,676' 3,557' 3,566' 9' 1/11/2005 Grl Pkd/Open ST C5 - BEL D4 3,700' 3,846' 3,589' 3,726' 146' 9/23/1986 Grl Pkd/Open BEL D4 3,846' 3,851' 3,726' 3,731' 5' 1/11/2005 Grl Pkd/Open BEL D6 3,910' 3,916' 3,787' 3,793' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,922' 3,928' 3,798' 3,804' 6' 1/11/2005 Grl Pkd/Open BEL D6 3,939' 3,942' 3,814' 3,817' 3' 1/11/2005 Grl Pkd/Open BEL E1 3,999' 4,006' 3,870' 3,877' 7' 9/23/1986 Grl Pkd/Open BEL E3 4,076' 4,077' 3,942' 3,943' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,077' 4,084' 3,943' 3,950' 7' 1/11/2005 Grl Pkd/Open BEL E3 4,084' 4,085' 3,950' 3,951' 1' 9/23/1986 Grl Pkd/Open BEL E3 4,107' 4,113' 3,971' 3,977' 6' 1/11/2005 Grl Pkd/Open BEL E3 4,151' 4,156' 4,013' 4,018' 5' 1/11/2005 Grl Pkd/Open BEL E4 4,170' 4,175' 4,030' 4,035' 5' 1/11/2005 Grl Pkd/Open BEL E5 4,182' 4,183' 4,041' 4,042' 1' 9/23/1986 Grl Pkd/Open BEL E5 4,183' 4,188' 4,042' 4,047' 5' 1/11/2005 Grl Pkd/Open BEL E6 4,268' 4,270' 4,122' 4,124' 2' 9/23/1986 Grl Pkd/Open BEL E6 4,270' 4,281' 4,124' 4,135' 11' 1/11/2005 Grl Pkd/Open BEL E6 4,281' 4,290' 4,135' 4,144' 9' 1/11/2005 Grl Pkd/Open BEL E6 4,304' 4,309' 4,155' 4,160' 5' 1/11/2005 Grl Pkd/Open BEL F4 4,431' 4,432' 4,274' 4,275' 1' 9/23/1986 Grl Pkd/Open BEL F4 4,432' 4,437' 4,275' 4,280' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,502' 4,507' 4,340' 4,345' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,507' 4,515' 4,345' 4,353' 8' 1/11/2005 Grl Pkd/Open BEL F5 4,515' 4,520' 4,353' 4,358' 5' 1/11/2005 Grl Pkd/Open BEL F5 4,520' 4,524' 4,358' 4,362' 4' 1/11/2005 Grl Pkd/Open BEL F5 4,524' 4,533' 4,362' 4,371' 9' 1/11/2005 Grl Pkd/Open BEL F6 4,552' 4,557' 4,386' 4,391' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,557' 4,558' 4,391' 4,392' 1' 9/23/1986 Grl Pkd/Open BEL F6 4,593' 4,598' 4,424' 4,429' 5' 1/11/2005 Grl Pkd/Open BEL F6 4,605' 4,610' 4,436' 4,441' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,718' 4,723' 4,540' 4,545' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,739' 4,744' 4,559' 4,564' 5' 1/11/2005 Grl Pkd/Open BEL F7 4,744' 4,752' 4,564' 4,572' 8' 1/11/2005 Grl Pkd/Open BEL F7 4,752' 4,757' 4,572' 4,577' 5' 1/11/2005 Grl Pkd/Open BEL G1 4,929' 4,934' 4,735' 4,740' 5' 1/11/2005 Grl Pkd/Open BEL G3 4,998' 5,003' 4,798' 4,803' 5' 1/11/2005 Grl Pkd/Open BEL G3 5,013' 5,018' 4,813' 4,818' 5' 1/11/2005 Grl Pkd/Open BEL G4 5,032' 5,042' 4,830' 4,840' 10' 1/11/2005 Grl Pkd/Open BEL G4 5,042' 5,043' 4,840' 4,841' 1' 9/23/1986 Grl Pkd/Open BEL G6 5,110' 5,122' 4,902' 4,914' 12' 1/11/2005 Grl Pkd/Open BEL G6 5,122' 5,125' 4,914' 4,917' 3' 1/11/2005 Grl Pkd/Open BEL G6 5,125' 5,130' 4,917' 4,922' 5' 1/11/2005 Grl Pkd/Open BEL H 5,322' 5,332' 5,099' 5,109' 10' 1/11/2005 Grl Pkd/Open BEL H2 5,392' 5,412' 5,164' 5,184' 20' 9/23/1986 Grl Pkd/Open BEL H7 / BEL H8 5,586' 5,652' 5,345' 5,407' 66' 9/23/1986 Grl Pkd/Open BEL H10 5,744' 5,764' 5,492' 5,512' 20' 1/11/2005 Grl Pkd/Open BEL H12 5,795' 5,796' 5,540' 5,541' 1' 1/11/2005 Grl Pkd/Open BEL H12 5,796' 5,810' 5,541' 5,555' 14' 9/23/1986 Grl Pkd/Open BEL H12 5,810' 5,812' 5,555' 5,557' 2' 1/11/2005 Grl Pkd/Open BEL H13 5,858' 5,872' 5,599' 5,613' 14' 1/11/2005 Grl Pkd/Open BEL H14 5,902' 5,908' 5,640' 5,646' 6' 1/11/2005 Grl Pkd/Open BEL I 6,088' 6,100' 5,815' 5,827' 12' 9/13/1990 Isolated BRU 214-26 SHL BRU 212-26 SHL SEC. 26 SEC. 27 SEC. 35SEC. 34 13N10W BELUGA HWYBELUGA RIVER UNIT ALASKA PIPELINE CO CHUGACH ELECTRIC ASSN INC COOK INLET REGION INC CHUGACH ELECTRIC ASSN INC CHUGACH ELECTRIC ASSN INC H PAD 151°1'40"W151°1'50"W151°2'0"W151°2'10"W151°2'20"W 61°11'15"N61°11'15"N61°11'10"N61°11'10"N61°11'5"N61°11'5"N61°11'0"N61°11'0"N61°10'55"N61°10'55"N61°10'50"N61°10'50"N0 100 200 300 400 Feet 1 inch = 200 feet @ 11x17 Page Size Map Date: 11/4/2021 Document Path: O:\Alaska\GIS\cook_inlet\fields\All_Fields\SSSV_TWellman\mxds\All_Fields_Pad_SHL_660ftBuffer_11x17_BRU_H-PAD_v03.mxdBRU H PAD 660 ft Buffer from Well Surface Hole Location Legend Water Well Location Surface Hole Well Location Existing Gas Pipelines 660 ft Radius Buffer from Well SHL KPB Parcels Cook Inlet Oil and Gas Units This pad contains one or more wells that meet the criteria listed in 20 AAC 25.265(d). See accompanying docu- mentation for current SSSV status of these wells. Wells Meeting Criteria: BELUGA RIV UNIT 212-26 BELUGA RIV UNIT 214-26 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230422 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF BRU 222-34 50283201860000 222039 6/14/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Paxton 12 50133207100000 223014 6/7/2023 AK E-LINE Perf PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Pearl 11 50133207120000 223032 6/8/2023 AK E-LINE Perf Please include current contact information if different from above. PTD: 190-042 T37810 T37811 T37812 T37813 T37814 T37815 T37816 T37817 BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 13:32:37 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Ipstnll l7�-etrergg ❑v 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Per to Drill Number: u� P Develo ment Exploratory P ❑ P ry❑ 190-042 Ai 3. Address: AK 0 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: 503 CId) 50-232-20083-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA029657 Beluga River Unit (BRU) 214-26 9. Logs (List logs and submit electronic and printed data per20AAC25.071): 10. Field/Pool(s): N/A Beluga River - Undefnded Gas/Undefined WDSP 11. Present Well Condition Summary: Total Depth measured 6448 feet Plugs measured 5978 feet true vertical 6154 feet Junk measured N/A feet 2939, 3684, 4320 Effective Depth measured 6020 feet Packer measured 5055, 5921 feet true vertical 5751 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 30" 221' 221, Surface 2,977' 13-3/' 2,977' 2,896' 3,450psi 1,950psi Intermediate Production 6,443' 9-5/8" 6,443' 6,148' 7,510psi 5,600psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 5.5" 15.5# / L-80 2,940' MD 2,860' TVD Bkr, Iso, Iso, Iso, 2939, 3684, 4320, 2860, 3574, 4171, Packers and SSSV (type, measured and true vertical depth) Bkr, Carrico SSSV 5055, 5921 MD 4852, 5458 TVD 282 MD / 282 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2880 329 245 20 Subsequent to operation: 0 2735 596 238 19 14. Attachments (required per 20 AAC 25.070, 25.071, &T5 283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas � WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ st-SP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-231 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: lkramerGDhilcoro.com Authorized Signature: Date: q O LILL60 Contact Phone: 777-8420 Form 10-404 Revised 412017 A X((� ts,/�_ jp. 1 ./5 1BDMSL-' OCT 0 7 2019 Submit Original Only q Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-26 50-283-20083-00 190-042 7/10/19 9/30/19 Daily Operations: 07/10/2019- Wednesday PTW/JSA. Mobilize equipment to H pad. Lay pit liner. Spot in Stelkraft spooler. Install 2.375" CT. Move in CTU Unit, Pump, N2 pump, return tank . Rig up hard line choke. Swap BOPE's. Swap injector pack offs and gripper blocks, Swap gooseneck rollers. Stab pipe in injector head. 07/11/2019 - Thursday PTW/JSA Fire equipment. Location walk around. Close in well. Bleed off stack. Nipple down 5" tree stack and SSV. Nipple up 4" 5M stack. Rotate all valves 180. Install 2x SSV valves. Start BOPE test. 250/4,000 psi. 24 hr BOPE test witness notification sent 7/10/19 @ 3:08 PM. Witness waived by Jim Regg 7/10/19 @ 4:10 PM. No failures to report. 07/12/2019 - Friday PTW/JSA. Fire equipment. Use crane to assist with flow line installation. Break apart blow out plug to check shear pins. Blow out plug fully pinned from factory. 5200 psi shear value. Remove required pins. Pinned to shear at 1,950 psi. Assembly Blow out plug. Pick injector head. Dress coil. Install Pump out plug assembly. 3.06" OD x 1.81' long. 1.875" ID. Pull test to 25k. Stab 2x 11' lubricators. Stab on well. PT stack. 250/4,000 psi. Bleed down PT. Open well. WHP 390 psi. Trip in hole. Parked at 4,550'. Pick up coil 23.5' from 4,550' to 4,526.5'. Close pipe rams and slip rams. Push pull test. Bleed of 390 psi WHP. Start injector stripping procedure. Install surface coil connector x 2-3/8" 8rd pipe. 3.08" OD x 1.61' long x 1.99" Id, 2.375" pup joint 2.06', 1.99" ID, 4.06" Hanger. 3' of coil above BOPE. 17' from original coil zero to lower hanger bolts. Total distance from hanger shoulder to hanger bolt 23.5'. Make up 2.375" dimple connector. Pull test 25k. Dimple connector is loose inside CT. Cut off connector and make up spare. 25k pull test. Connector is tight. Make up remaining bha. 2.5" DFCV, 2.5" Hyd disco, 3" Hydraulic GS spear. Pick injector head. Latch into CT velocity string above BOPE stack with GS spear. Strip down and make up lubricator to BOPE stack. Pull test Hanger assembly 25k. Open BOPE EQ port. Pressure equalized 360 psi above and below rams. Open Pipe and slip rams. RIH 23.2' and set down 5k on lower hanger bolts. Tighten upper hanger bolts. PT Hanger void 500 psi. Increase to 3,000 psi. Hanger void held 3000 psi for 10 minutes. N2 unit fired up and cooled down. PT N2 lines 250/4,200 psi. Previously installed Blank sub into GS spear changing it from flow release to pressure release. Online with N2 down 2.375" CT reel. While pressuring up made a few attempts to release GS spear. Stacked 4k down and pressured up to 3,280 psi before spear released. CT velocity string set from surface to 4,550'. Pick up to surface. Dump CT pressure from surface reel down CT velocity string. 1,700 psi. Online down velocity string with N2 at 1,000 scf/min. Pressure increased to 1,900 psi and broke over. Burst disks blown. Shut down N2. Let well pressure stabilize. Shut in master and swab with 521 psi SITP. Bleed down CT to open top. Pop off well and rig back injector head. Turn well over to production. Location walk around complete. Wellsite secure. SDFN. No fluid pumped during V string operation. 33,200 scf pumped or 357 gallons. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 214-26 50-283-20083-00 1 190-042 7/10/19 1 9/30/19 Daily Operations: 07/18/2019 - Thursday Fly from Otter hanger in Kenai to Beluga. PJSM, PTW. Rig up SLB CTU 13 with 2.375" CT. BOPE test. Test all Rams and valves 250/4,000 psi. 24 hr BOPE Test witness notification sent 7/18/19 @ 0740. Witness waived by Matt Herrera 7/18/19 @ 0900. BOPE test finished. No failures to report. Location secure. Location walk around complete. SDFN. 07/19/2019 - Friday PTW/JSA. Pick injector head. Stab 2x 11' lubricators. Make up Fishing BHA. dimple coil connector, DFCV, HYDRO disconnect, 3" GS spear. Stab on well. Pressure test lubricator. Stripper to lubricator O-ring leaking. Pop off well. Break down tools and stack down lubricator. Change 0 -ring and repeat. PT 250/4,000 psi. Open swab. V string pressure 0 psi. Pump 10 bbls of produced water down V string well on Vac. RIH latch GS spear at 17.2'. Pull test 5k over string weight. Slack off. Wellhead hand loosen hanger bolts. Pick V string up 25' and set pipe and slip rams. Perform SLB pipe stripping procedure. Cut off hanger assembly. Swing crane over and break down. Dress V string for double dimple spoolable connector. Make up spoolable connector to Injector head side and then on v string. Strip over connector and stab lubricator. Pull test 25k. Connection good. Equalize rams. Spool OOH 1350' from 4,550' to 3,200'. PU to 3,176'. Close pipe and slip rams. Perform pipe stripping procedure. Make up inverted coil connector, 2'2.375" pup joint. Hanger with bell guide (soap launch assist). Make up Landing BHA on injector head side. Dimple connector, DFCV, Hydro disco, 3" GS spear. Bring injector head to well and latch GS profiles. Slip chains and land lubricator and make up to BOP's. Pull test 30k. Equalize BOPS Open pipes and slips. RIH 17' and stack 5k down on hanger. Secure lock down screws. Pressure test hanger seals to 3,200 psi for 10 minutes. Good PT. Online down v string with produced water at 2.4 bbls/min Release from GS spear. Pick up and close master and swab valve. Total fluid pumped 50 bbls of produced water. V string final length 3,196.3'. Cool down N2 pump. Blow reel dry. Pop off well. Break down BHA. Stack down lubricator and set injector on stand. Remove Return iron from tree. Remove BOPE stack and install night cap. CTU unit rigged back. Turn well over to production. 08/04/2019 -Sunday Travel from Otter Hanger to Beluga. Rlg up CTU 13. Install BOPE's. BOPE test all rams and valves 250/3,000 psi. 08/05/2019 - Monday PJSM. PTW. Fire equipment. Pick injector head . Stab 20' of lubricator. make up 2.375" dimple connector, DFCV, DISCO, 3" GS spear. Stab on well. PT stack 250/3,500. Pump 14 bbls of produced water down v string to land dart. RIH 15.2' and tag hanger. Pull test to 8k to confirm latched. Slack off. Back off top hanger bolts. Pick up to see coil travel. Back out lower hanger bolts. PU 25'. Close pipe and slip rams. Start SLB stripping pipe procedure. Make up 2.375" spoolable connector. Strip down over coil. Spin on lubricator and perform 12k pull test. Good test. Equalize BOPE rams and open pipe and slips. POOH with 3200' of 2.375" V string. Tagged up at surface. Close master and swab valve. Cool down N2 . Blow down reel to confirm no fluid. Rig down CTU unit. Load spooler and 2.375" work reel on low boys for barge. Location secure. SDFN. 08/30/2019 - Friday Swabbed well on line flowing 500 mcfd rate. 09/30/2019 - Monday Met with Reservoir Engineer and decided that since the well was back,&n line to not run the velocity string. IDlcoru Aleaka. LLC RKB to MSL=104.5' RKB to GL= 30" I 2 13-3/8" " 4 5 6 7 8 9 10 11 12 13 14/15 16/17 18 19 20 21 22 23/24 25 Tubing Min ID = 4.562" TOC @2,985" Sterling Sands :A B iC Beluga Sands D F L 9-5/8" iMMMOMOL To 6,443' TVD =6,154' PBTD=6,020' END=5,751' Max Angle = 23 deg @ 4,900' Beluga River Unit Well: BRU 214-26 SCHEMATIC Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 CASINO: DFTAII Size Type WT Grade Conn ID Btm 30" Conductor 1 310# 1 X-52 I BTC 221' 13-3/8" Surface 68# I K-55 L BTC1 32.415" 2,977' 9-5/8" Prod Casing 43.5# S-95 BTC 8.755 6,443' I USING DETAILS 5.5" Production Tubing 15.5# L-80 BTC 4.95" 2,940' JEWELRY DETAIL ID. Depth MD (ft.) ID (in.ffi'fft8O V Descrip1 Btm (TVIV 282 4.562RM-4E 55SV w/ 4.562" X" selective2 Status 2,872 4.562U Sliding Sleeve -Closed 3 2,923 4.7560-60 PBR#683-19-602M4 11/17/2005 2,939 6-2 Pkr 96G60 w/ 7-3/" 461 ppHyd 523 eox 5 2,955 5.3ack Sliding Sleeve 190 -47 -Closed 6 3,028 5 KOIV w/ Protection Sleeve 6.625" SLHT 7 3,044 4.892b/k L-80 blank pipe (205 ft.) 8 3,241 4.892 5.5" 17lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Upper Middle Iso Packer 96A4-60 SCI -L Packer 30 3,693 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed it 3,716 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Lower Middle Iso Packer 96A4-60 SC1A Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 14 4,424 4.892 5.5" 1716/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17lb/ft L-80 blank pipe (10 ft.) 16 4,630 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 17 4,817 4.892 5.5" 17 lb/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (224 ft.) 19 5,055 6 Lower Iso Packer 96A4-60 SCI -L Packer 20 5,064 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 105 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (805 ft.) 921 6 Baker 192-60 9-5/8" Model" " Permanent Packer 966 L 3.958 XO Sub 5.5" LTC Box x 4.5" 12.6ppf IBT-M BXP 978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 987 3.937 Wireline Entry Guide 4.5" 15.5 bl/ftX 1/2 Mule Shoe DFDFr1DAT1n K1 n[TAu Sands Top (MD) Btm (MD) Top (TVD) Btm (TVIV PF Date Status Sterling 3,245' 3,369' 3,153' 3,272'12 11/17/2005 Grvl Pkd/Open Sterling B 3,386' 3,510' 3,288' 3,407'12 11/17/2005 Grvl Pkd/Open SterlingC 3536' 3676' 3,432' 3,566'2 11/17/2005 Grvl Pkd/Open Beluga D 3,700' 3,942'3,589' 3,817'2 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161'2 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577'2 11/17/2005 Grvl Pkd/Open Beluga G 4,929' 5,332' 4735' 5,108'2 11/17/2005 Grvl Pkd/Open Beluga H 5,392' 5,908' 5,164' 5.646' tt/nnnnv I r-1 DLA/n..e.. *Partially Perforated Interval Updated by: DMA 09-25-19 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276 7542 www.cogcc.alaska.gov Re: Beluga River Field, Undefined Gas/Undefined WDSP Pool, BRU 214-26 Permit to Drill Number: 190-042 Sundry Number: 319-231 Dear Mr. York: Enclosed is the approved application for the 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, 4V�� Daniel T. Seamount, Jr. Commissioner DATED this / ( q d1� May, 2019, RBDMSMAY 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 0 7 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Velocity String 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 190-042 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-232-20083-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Undefined Will planned perforations require a spacing exception? Yes ❑ No Beluga River Unit (BRU) 214-26 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA029657 BELUGA RIVER - UNDEFINED GAS/UNDEFINED WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD ): Total Depth TVD,(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): GA43' 6,020' 5,751' —2,800 psi 5,978' N/A Casing Length Size MD TVD Burst Collapse Structural ' y Conductor 221' 30" 221' 221' Surface 2,977 13-3/8" 2,977' 2,896' 3,450psi 1,950psi Intermediate Production 6,443' 9-518" 6,443' 6,148' 1 ,510psi 5,600psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 5-1/2" 15,.5# / L-80 2,940' Packers and SSSV Type: Carrico TRM-4E; Packers and SSSV MD (ft) and TVD (ft): 282'MD/TVD; 2,939'MD/2,860'TVD; Baker SC2 Pkr; 3 Baker SC1-L Iso Packers; 1 Baker F Perm Pkr 3,684' 4,320' 5,055' MD - 3,574' 4,171' 4,852' TVD; 5,921'MD/5,658'TVD 12. Attachments: Proposal Summary v Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development ❑Q ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: May 25, 2019 O P OIL WINJ WDSPL ❑ ❑ ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerrrDhlcoro com )•-r Contact Phone: 777-8420 � °� Authorized Signature: Date: 1 `a` 161 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31G - C��/ ( Plug Integrity El Test OCJ Mechanical Integrity Test ❑ Location Clearance El / -'fT OO Z? f S : `. 0 r� 5 7l \ C. T L� ) G Post Initial Injection Req'd? RBDMS !� MAY 15 2019 MIT Yes No � / Spacing Exception Required? Yes No Subsequent Form Required: — 4/0 El Ird I APPROVED BY �• Approved by: COMMISSIONER THE COMMISSION Date: r/•' I/ C�.•! L rm 0-403 �evise & 7 Approved pplQc rRS &J I" L. the date of approval. Submit Form and s�g1A achments in Duplicate �/ '1;52!y 5717.47 U Hil.ro Alaska, LL Well Prognosis Well: BRU 214-26 Date: 5/2/2019 Well Name: BRU 214-26 API Number: 50-283-20083-00 Current Status: Gas Producer leg: N/A Estimated Start Date: 05/25/2019 Rig: CTU #13 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 190-042 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Surface Pressure: — 165 psi Maximum Expected BHP: — 1,699 psi @ 3,888' TVD (Calc'd W/.437 psi/ft gradient) Max. Predicted Surface Pressure: — 2,800 psi (While Pumping Nitrogen) Brief Well Summary Originally drilled in 1990 as a dual string infill development well. After drilling to 4602' MD the BHA stuck during a short trip - no luck fishing and the well was sidetracked from3331' MD. Completed from the Sterling A thru the Beluga H. The well came online making 17-21 MMCFD. In 2005 the well was re -completed to a single string gravel pack completion. The well returned to production making 23 MMscfd and is currently producing 3.3 MMcfd, 550 BWPD at 25 psi flowing tubing pressure. A camera ran in the fall of 2018 identified a water influx zone in the well. I The purpose of this work is to install a 2" velocity string to allow the well to more easily unload water. Note: Nitrogen will be used to blow the plug out of the coil tubing. Notes Regarding Wellbore Condition • Min ID is 3.725" ("BG" Nipple @ 5,978'MD) Last tag was @ 5,953' WLM, W/ camera 7/21/2018 Coiled Tubing Proced e: 3 A,41,,.A,41,,. 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. 2. PU 2" Coil velocity string W/ pump out plug on bottom. 3. RIH to 4,550'. 4. Hang off coil tubing according to coil tubing companies hang off procedures. yt S. Rig up Nitrogen. Pressure up on coil tubing and blow out blow out plug. (L,,/ tj r o 6. RDMO Coil tubing unit. 7. Turn well over to production. Attachments: L� 1. Current Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Current Well Head Diagram 5. Proposed Well Head Diagram H llik.m Alaska, LL, 6. Standard Well Procedure- Nitrogen Well Prognosis Well: BRU 214-26 Date: 5/2/2019 n 1lilcarp Alaska, LLC 12 Depth MD (ft.) J 13 Conn ID Btm 30" Conductor 310# 14/15 % 221' 16/17 Surface F 18 .•"}: .�.aM 12.415" 2,977' 9-5/8" Prod Casing 43.5# 19 BTC 6 20 ' 3,028 5 21 V 3,044 4.892 5.5" 17lb/ft L-80 blank pipe (205 ft.) 8 22 23/24 i 25 i Tubing Min ID = 4.562' . 9-5/8" To 6,443' TVD 6,154' PBTD = 6,020' END = 5,751' Max Angle = 23 deg @ 4,900' SCHEMATIC CASING DETAIL Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 SizeType Depth MD (ft.) WT Grade Conn ID Btm 30" Conductor 310# X-52 I BTC 221' 13-3/8" Surface 684 K-55 BTC 12.415" 2,977' 9-5/8" Prod Casing 43.5# 5-95 BTC 8.755" 6,443' TUBING DETAILS 5.5" 1 Production Tubing 1 15.5# 1 L-80 I BTC 4.95" 2,940' JEWELRY DETAIL Production Strine ID. Depth MD (ft.) ID (in.) Description 1 282 4.562 Camco TRM-4E SSSV w/4.562" X" selective profile 2 2,872 4.562 Baker CMU Sliding Sleeve -Closed 3 2,923 4.756 Baker 190-60 PBR#683-19-602M (19.6 ft.) 4 2,939 6 Baker SC -2 Pkr 96C-60 w/7-3/4" 46.1 ppf Hyd 523 Box 5 2,955 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 6 3,028 5 Model C KOIV w/ Protection Sleeve 6.625" SLHT 7 3,044 4.892 5.5" 17lb/ft L-80 blank pipe (205 ft.) 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 1 6 Upper Middle Iso Packer 96A4-60 SC3-L Packer 10 3,693 5.3 Gravel Pack Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 171b/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Lower Middle Iso Packer 96A4-60 SCI -L Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 14 4,424 4.892 5.5" 17lb/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17lb/ft L-80 blank pipe (10 ft.) 16 4,630 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 17 4,817 4.892 5.5" 17lb/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (224 ft.) 19 5,055 6 Lower Iso Packer 96A4-60 SCl-L Packer 20 5,064 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 21 5,105 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (805 ft.) 22 5,921 6 Baker 192-609-5/8" Model "F" Permanent Packer 23 5,966 3.958 XO Sub 5.5" LTC Box x 4.5" 12.6ppf IBT-M BXP 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide 4.5" 15.5 bl/ft X 1/2 Mule Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Sterling 3,245' 3,369' 3,153' 3,272' 64" 12 11/17/2005 Grvl Pkd/Open Sterling B 3,386' 3,510' 3,288' 3,407' 28'* 12 11/17/2005 Grvl Pkd/Open Sterling 3,536' 3,676' 3,432' 3,566' 581* 12 11/17/2005 Grvl Pkd/Open Beluga D 3,700' 3,942' 3,589' 3,817' 1661* 12 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161' 65'* 12 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577' 76'* 12 11/17/2005 Grvl Pkd/Open Beluga G 4,929' 5,332' 4,735' 5,108' 56'* 12 11/17/2005 Grvl Pkd/Open Beluga H 5,392' 5,908' 5,164' 5,646' 143'* 12 11/17/2005 Grvl Pkd/O en *Partially Perforated Interval Updated by. DMA 04-23-19 n Ifilmm Alaska, LLC PROPOSED SCHEMATIC RKBto MSL=104.5' RKBto GL=21.15' 30" 12 " 13 4/15 16/17 18 19 20 21 H 22 ' 23/24 25 Tubing Min ID=4.562" - 9-5/8" I IL TD 6,443' TVD=6,154' PBTD=6,020' ETVD=5,751' Max Angle = 23 deg @ 4,900' CASING DETAIL Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 Size Type Wi Grade Conn ID Btm 30" Conductor 310# X-52 eTC 221' 13-3/8" Surface 68# K-55 BTC 12.415" 2,977- 9-5/8', Prod Casing 43.5# 5-95 BTC 8.755" 6,443' JEWELRY DETAIL Production StrinB ID. Depth MD (ft.) ID (in.) Description 1 282 4.562 Carrico TRM-4E SSSV w/4.562" X" selective profile 2 2,872 4.562 Baker CMU Sliding Sleeve -Closed 3 2,923 4.756 Baker 190-60 PBR #683-19-602M (19.6 ft.) 4 2,939 6 Baker SC -2 Pkr 96C-60 w/ 7-3/4" 46.1 ppf Hyd 523 Box 5 2,955 5.3 Gravel Pack Sliding Sleeve 190-47- Closed 6 3,028 5 Model C KOIV w/ Protection Sleeve 6.625" SLHT 7 3,044 4.892 5.5" 17 lb/ft L-80 blank pipe (205 ft.) 8 3,241 4.892 1 5.5" 17 Ib/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 6 Upper Middle lso Packer 96A4-60 SCI -L Packer 10 3,693 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 11 3,716 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Lower Middle Iso Packer 96A4 -605C3 -L Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 14 4,424 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17 lb/ft L-80 blank pipe (10 ft.) 16 4,630 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 17 4,817 4.892 5.5" 17 Ib/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17lb/ft L-80 Excluder 2000 Med (224 ft.) 19 5,055 6 Lower Iso Packer 96A4-60 SCI -L Packer 20 5,064 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 21 5,105 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (805 ft.) 22 5,921 6 Baker 192-60 9-5/8" Model "F" Permanent Packer 23 5,966 3.958 XO Sub 5.5" LTC Box x 4.5" 12.6ppf IBT-M BXP 245,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide 4.5" 15.5 bl/ft X I/2 Mule Shoe U4.171111.7i'd111111dn11y101 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Sterling 3,245' 3,369' 3,153' 3,272' 64'* 12 11/17/2005 Grvl Pkd/Open Sterling B 3,386' 3,510' 3,288' 3,407' 28'* 12 11/17/2005 Grvl Pkd/Open Sterling C 3,536' 3,676' 3,432' 3,566' 581* 12 11/17/2005 Grvl Pkd/Open Beluga D 3,700' 3,942' 3,589' 3,817' 166'* 12 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161' 65'* 12 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577' 76'* 12 11/17/2005 Grvl Pkd/Open Beluga G 4,929' 5,332' 4,735' 5,108' 56'* 12 11/17/2005 GNI Pkd/Open Beluga H 5,392' 5,908' 5,164' 5,646' 143'* 12 1 11/17/2005 Grvl Pkd/O en *Partially Perforated Interval s Updated by: DMA 05-03-19 2-1502 Flan 0 2.1/1 10K Beluga River Unit BRU 214-26 4/23/2019 Coiled Tubing HRSBO Injector Head &Gooseneck Weight =12,850 lbs 4-1116" 1OK Conventional Stripper 6K C062 Lubricator 5K C062 x 4.1116" 1 OK Flange 4-1/16" 10K Combi BOP TW Se P. BIiNi6h.er Slc dSN Pipe'Sl, 4.1116" 10K Flow Cross Md W 2x2 Valve 1: 2' 1602 x 2-1116" 1OK R.M. Manua 2X1 Valve 2:2-1116" IOK x2-1116" 10K nary. Mmua 2X1 Valve 12-1116" 1OK x 2-1116'10K H.I. Mmael 2x2 Ve We4: 7-15M x 2-1116'10K nerye 4-1116" 1OK x Wellhead Adapter Flange Wellhead H Hilmrp A4uka, I.Id Beluga River BRU 214-26 133/8 x 95/8 x 51/2 Tree cap, Otis, 5 1/8 SM FE X 9 %Otis Quick Union Valve, Swab, VG -200,5 1/8 5M FE, H WO, DD trim Valve, upper master, VG -200,5 1/8 5M FE, H WO, DD trim Valve, master, VG -200, 5 1/8 5M FE, H W 0, DD trim Tubing head, FMC -TC -60 -BG, 13 5/8 3M x 11 3M, w/ 2- 2 1/16 5M 550 Starting head, OCT -C22, 13 5/8 3M x 13 3/8" SOW, W/ 2- 2 1/16 SM EFO Beluga River 214-26 Current 05/04/2019 Tubing hanger, FMC -TC -EN - CCL, 11 x 5 Y. BTC lift and cusp, w/ 5" type H-BPV profile, 1- Xnpt control line port < � C 7— [low ed, 95/81, 5%" Adapter, FMC -ASP -CCL, 113M stdd x 5 1/8 5M, w/ 1 - control line e>ut 3/8" 11 Pes. 4" 11 P 1'Dy�\ O.t� � ryOp �,2, JG�\soc ,Gtipo e> < � C 7— [low ed, 95/81, 5%" Adapter, FMC -ASP -CCL, 113M stdd x 5 1/8 5M, w/ 1 - control line e>ut 3/8" H trlr—p Ma.k.'. l.f.t Beluga River 214-26 Proposed 05/04/2019 Beluga River Tubing hanger, FMC-TC-EN- BRU 214-26 CCL, 11 x 5 X BTC lift and 13 3/8 x 9 5/8 x 5 H x 2" susp, w/ 5" type H-BPV profile, I. Snpt control line part BHTA, Otis, 41/16 SM FE x 6.5" Otis quick union top Lr L3 Va Ne, swab, ClW-FLS, �ftri' axos' 41/165M FE, TWO, DD trim 011kf,l O'' cg SS 's'o�t opet Jago eE e Valve, master, CIW-FLS, 41/165M FE, HWO, DO trim Coiled tubing hanger, VG - CIM, 4" nominal X 2 3/8 EUE susp X 3" GS Baker Fish Neck Lift, w/ 2" Type H BPV and grapple for 2" coil DSA, 5 1/8 5M x 41/16 SM Valve, master, VG -200, 51/8 SM FE, HWO, DD trim Tubing head, FMC -TC -60 -BG, 135/83M x 113M, w/ 2- 21/16 SM $50 Starting head, OCT -C22, 13 5/8 3M x 13 3/8" SOW, w/ 2- 21/16 SM EFO 2' EIM 21/16 5M Wing section w/ Pneumatic 55V J/ ® C -7 -tip Ko e kr Adapter, FMC -ASP -CCL, 113M stdd x 5 1/8 SM, w/ 1 - control line exit STANDARD WELL PROCEDURE ❑ncorp Alaska, LLC. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 Carlisle, Samantha J (DOA) I q0 -OqZ From: Sent: To: Subject: Did we approve this yet? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office Schwartz, Guy L (DOA) Thursday, May 2, 2019 9:07 AM Carlisle, Samantha J (DOA) FW: Sundry Submission for BRU 214-26 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipienf(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. if you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.aov). From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, May 2, 2019 7:43 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Sundry Submission for BRU 214-26 Guy, Hilcorp Submitted a sundry application on the above well on May 24`h to use Coil tubing and perform a cement squeeze to attempt to shut off a water zone. Hilcorp would like to withdraw that sundry and cancel it. We will be submitting a new Sundry in its place to run a 2" velocity string and try to live with the water production for now. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell — 985-867-0665 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Beluga River Field, Undefined Gas/Undefined WDSP Pool, BRU 214-26 Permit to Drill Number: 190-042 Sundry Number: 319-214 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w-oogcc.alaska.gov Enclosed is the approved application for the 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, Daniel T. amount, Jr. Commissioner S t DATED this day of May, 2019. RBDMSL6'-/MAY 0 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 VE D 11 Is. .. APR 2 4 2019 A0GQC 1. Type of Request: Abandon ❑ Plug Perforations ❑✓ ` Fracture Stimulate ❑ Repair Well _ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ �xrv� S ,. Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 190-042 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-232-20083-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Undefined Will planned perforations require a spacing exception? Yes ❑ No ✓ ❑ Beluga River Unit (BRU) 214-26 9. Property Designation (Lease Number): 10. Field/Pool(s): , FEDA029657 BELUGA RIVER -UNDEFINED GAS/UNDEFINEDWDSP ` it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,443' 6,145' 6,020' 5,751' -2,800 psi 5,978' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 30" 221• 221' Surface 2, 977' 13-3/8" 2,977' 2,896' 3,450psi 1,950psi Intermediate Production 6,443' 9-5/8" 6,443' 6,148' 7,510psi 5,600psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 5-1/2" 15,.5# / L-80 1 2,940' Packers and SSSV Type: Camco TRM-4E; Packers and SSSV MD (ft) and TVD (ft): 282'MD/TVD; 2,939'MD/2,860'TVD; Baker SC2 Pkr; 3 Baker SC1-L Iso Packers; 1 Baker F Perm Pkr 3,684' 4,320' 5,055' MO - 3,574' 4,171' 4,852' TVD; 5,921'MD/5,658'TVD 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 10, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS Q • WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kremer Authorized Title: Operations Manager Contact Email: tkramerrdlhl1c2rRJ1M p Contact Phone: 777-8420 Authorized Signature: Date: �-ll rl 1 COMMISSION USE ONLY Conditions of app val: Notify Commission so that a representative may witness Sundry Number: QI j J lk Plug Integrity ❑ BOP Test/� Integrity Test ❑ Location Clearance ❑ QMechanical Other: L,� D O / 5. 3 0 1 Ie,�� 3 Post Initial Injection MIT Req'd7 Yes ❑ No ❑ RBDMS �w MAY 0 2 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / '� ly APPROVED BY Approved byjg� COMMISSIONER THE COMMISSION Date: !1 J ell lm 1(361'q Submit F ' orm and Form 10-403 Revised /2017 Approved applic ti a f t it the date of appro al. pItaWiments n Duplicate H llilwru Alaska, LLQ Well Prognosis Well: BRU 214-26 Date:4/23/2019 Well Name: BRU 214-26 API Number: 50-283-20083-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 05/10/2019 Rig: CTU #13 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: 3. Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 190-042 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 6. 7. Drill out composite bridge plug. RIH and blow well dry, POOH. RDMO CTU. Current Surface Pressure: - 165 psi Maximum Expected BHP: - 1,699 psi @ 3,888' TVD (Calc'd W/.437 psi/ft gradient) Max. Predicted Surface Pressure: •- 2,800 psi (While Pumping Nitrogen) Brief Well Summary Originally drilled in 1990 as a dual string infill development well. After drilling to 4602' MD the BHA stuck during a short trip - no luck fishing and the well was sidetracked from3331' MD. Completed from the Sterling A thru the Beluga H. The well came online making 17-21 MMCFD. In 2005 the well was re -completed to a single string gravel pack completion. The well returned to production making 23 MMscfd and is currently producing 3.3 MMcfd, 550 BWPD at 25 psi flowing tubing pressure. A camera ran in the fall of 2018 identified a water influx zone in the well. Tpurpose of this work is to pump a cement squeeze to shut off a shallow water interval, drill out, blow the well dry, return to production. Note: Nitrogen will be used to blow the well dry. Notes Regarding Wellbore Condition • Min ID is • 3.725" ("BG" Nipple @ 5,978'MD) • Last tag was @ 5,953' WLM, W/ camera 7/21/2018) E -line Work 1. MURU E -line. Pressure test lubricator to 3,500 psi high, 250 low. 2. PU, RIH with composite bridge plug to (+/-) 3,680'. Set same. POOH. 3. PU Composite Cement Retainer, RIH to (+/-) 3,235', set same. POOH. RDE -line. Coiled Tubing Procedure: F�} - r � - 4' -baa 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low© . /�✓ 2. PU stinger, RIH to 3,230', sting into cement retainer. 3. RU Cementers and pressure test lines. 4. Pump Cement job according to cementing proc Jure. POOH, WOC. 5. PU bit and motor on CTU. RIH and drill out Retainer, cement to just above bridge plug. Pressure test to 500 psi. 6. 7. Drill out composite bridge plug. RIH and blow well dry, POOH. RDMO CTU. �- U 11&om Alaska. LL, 8. Bleed off Nitrogen and Return well to Production. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Standard Well Procedure- Nitrogen 5. CT Flow Schematic (Forward) Well Prognosis Well: BRU 214-26 Date: 4/23/2019 30" Beluga River Unit Well: BRU SCHEMATIC d: 11/29/2005 PTD: 190-042feted: corn Alaska, LLC API: 50-283-20083-00 CASINr DFTAII 3to MSL=104.5' RKBto GL=21.15' TT1W Size Type WT Grade Conn ID Btm 30" Conductor 310# X-52 BTC 221' 13-3/8" Surface 681t K-55 BTC 12.415" 2,977' 9-5/8" Prod Casing 43.5# S-95 BTC 8.755" 1 6,443' t. Depth MD (ft.) a 5 1 282 4.562 Camco TRMAE SSSV w/ 4.562" X" selective profile Sterling Sands 2,872 {�. Baker CMU Sliding Sleeve -Closed 3 2,923 4.756 Baker 190-60 PBR #683-19-602M (19.6 ft.) 4 }ti 6 Baker SC -2 Pkr 96C-60 w/ 7-3/4" 46.1 ppf Hyd 523 Box 811. 2,955 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 6 ff• f 5 Model C KOIV w/ Protection Sleeve 6.625" SLHT 7 -'' ' -n r r 4.892 2 Beluga Sands Beluga D 3,684 6 Upper MiddleJso Packer 96A4-60 SC1-L Packer 30 3,693 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 1 3,716 .• • I}•r:: 12 4,320 6 Lower Middle Iso Packer 96A4 -605C1-1. Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 14 4,424 , 5.5" 17 Ib/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17 lb/ft L-80 blank pipe (10 ft.) 14/ 15 jl[E 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 61,71 4,817 4.892 5.5" 17 Ib/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (224 ft.) 19 20 21 M 22 23/24 25 Tubing Min ID = 4.562" 9-5/8" To 6,443' TVD=6,154' PBTD=6,020' ETVD=5,751' Max Angle = 23 deg @ 4,900' TUBING DETAILS 5.5" 1 Production Tubing 1 15.5#L-80 BTC 4.95" 2,940' JEWELRY DETAIL Production Strino ID. Depth MD (ft.) ID (in.) Description 1 282 4.562 Camco TRMAE SSSV w/ 4.562" X" selective profile 2 2,872 4.562 Baker CMU Sliding Sleeve -Closed 3 2,923 4.756 Baker 190-60 PBR #683-19-602M (19.6 ft.) 4 2,939 6 Baker SC -2 Pkr 96C-60 w/ 7-3/4" 46.1 ppf Hyd 523 Box 5 2,955 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 6 3,028 5 Model C KOIV w/ Protection Sleeve 6.625" SLHT 7 3,044 4.892 5.5" 17 lb/ft L-80 blank pipe (205 ft.) 8 3,241 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (440 ft.) Beluga D 3,684 6 Upper MiddleJso Packer 96A4-60 SC1-L Packer 30 3,693 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 11 3,716 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Lower Middle Iso Packer 96A4 -605C1-1. Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 14 4,424 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17 lb/ft L-80 blank pipe (10 ft.) 16 4,630 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 17 4,817 4.892 5.5" 17 Ib/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (224 ft.) 19 5,055 6 Lower lso Packer 96A4-60 SCI -L Packer Grvl Pkd/O en 5,064 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 5,105 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (805 ft.) 5,921 6 Baker 192-60 9-5/8" Model "P' Permanent Packer L 5,%63.958 XO Sub 5.5" LTC Box x 4.5" 12.6ppf IBT-M BXP 5978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 5,987 3.937 Wireline Entry Guide 4.5"15.5 bl/ftX 1/2 Mule Shoe PERFORATION DFTAII. Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Sterling 3,245' 3,369' 3,153' 3,272' 64'* 12 11/17/2005 Grvl Pkd/Open Sterling B 3,386' 3,510' 3,288' 3,407' 28'* 12 11/17/2005 Grvl Pkd/Open Sterling C 3,536' 3,676' 3,432' 3,566' 58'* 12 11/17/2005 Grvl Pkd/Open Beluga D 3,700' 3,942' 3,589' 3,817' 166'* 12 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161' 65'* 12 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577' 76'* 12 11/17/2005 Grvl Pkd/Open Beluga 4,929' 5,332' 4,735' 5,108' S6'* 12 11/17/2005 Grvl Pkd/Open Beluga H 5,392' 5,908' 1 5,164' 1 5,646' 143'* 12 1 11/17/2005 1 Grvl Pkd/O en *Partially Perforated Interval Updated by: DMA 04-23-19 K ailenro Alaska. LLC PROPOSED SCHEMATIC RKB to GL=21.15' 30" — I 1 — 2 3 _ 13-3/8`4 'I TOC @2,985" S Sterling Sands A 7 B 8! C 9 10' Beluga Sands 1 .r.,.�D 12' 13 14/15 16/17 18 19 20 21 H 22 23/24 25 Tubing Min ID=4.562 9 -5/8 - To = 6,443' -5/8"TD=6,443' TVD =6,154' PBTD=6,020' END=5,751' Max Angle = 23 deg @ 4,900' CASING DETAIL Beluga River Unit Well: BRU 214-26 Last Completed: 11/29/2005 PTD: 190-042 API: 50-283-20083-00 Size Type WT Grade Conn ID Btm 30" Conductor 310# X-52 BTC 221' 13-3/8" Surface 68# K-55 BTC 12.415" 2,977' 9-5/8" Prod Casing 43.5# S-95 BTC 8.755" fi,443' TUBING DETAILS 5.5" 1 Production Tubing 1 15.5# 1 L-80 I BTC 4.95" 2,940' JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 282 4.562 Carrico TRM-4E SSSV w/ 4.562" X" selective profile 2 2,872 4.562 Baker CMU Sliding Sleeve -Closed 3 2,923 4.756 Baker 190-60 PBR #683-19-602M (19.6 ft.) 4 2,939 6 Baker SC -2 Pkr 96C-60 w/ 7-3/4" 46.1 ppf Hyd 523 Box 5 2,955 5.3 Gravel Pack Sliding Sleeve 190 -47 -closed 6 3,028 5 Model C KOIV w/ Protection Sleeve 6.625" SLHT 7 3,044 4.892 5.5" 17 lb/ft L-80 blank pipe (205 ft.) 8 3,241 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (440 ft.) 9 3,684 1 6 Upper Middle Iso Packer 96A4-60 SCI -L Packer 10 3,693 5.3 Gravel Pack Sliding Sleeve 190-47 - Closed 11 3,716 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (600 ft.) 12 4,320 6 Lower Middle Iso Packer 96A4-60 SC3-L Packer 13 4,329 5.3 Gravel Pack Sliding Sleeve 190-47 - Closed 14 4,424 4.892 5.5" 17lb/ft L-80 Excluder 2000 Med (197 ft.) 15 4,620 4.892 5.5" 17 lb/ft L-80 blank pipe (10 ft.) 16 4,630 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (187 ft.) 17 4,817 4.892 5.5" 17 Ib/ft L-80 blank pipe (224 ft.) 18 4,827 4.892 5.5" 17 Ib/ft L-80 Excluder 2000 Med (224 ft.) 19 5,055 6 Lower [so Packer 96A4-60 SC3-L Packer 20 5,064 5.3 Gravel Pack Sliding Sleeve 190 -47 -Closed 21 5,105 4.892 5.5" 17 lb/ft L-80 Excluder 2000 Med (805 ft.) 22 5,921 6 Baker 192-60 9-5/8" Model "F" Permanent Packer 23 5,966 3.958 XO Sub 5.5" LTC Box x 4.5" 12,6ppf IBT-M BXP 24 5,978 3.725 BG Nipple w/ 3.725" XN Profile w/Plug 25 5,987 3.937 Wireline Entry Guide 4.5"15.5 bl/ftX 1/2 Mule Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btm (ND) Amt SPF Date Status SterlingA 3,245' 3,369' 3,153' 3,272' 64'* 12 11/17/2005 Squeezed Sterling B 3,386' 3,510' 3,288' 3,407' 28'* 12 11/17/2005 Squeezed Sterling C 3,536' 3,676' 3,432' 3,566' 581* 12 11/17/2005 Squeezed Beluga D 3,700' 3,942' 3,589' 3,817' 166'* 12 11/17/2005 Grvl Pkd/Open Beluga E 3,999' 4,309' 3,871' 4,161' 65'* 12 11/17/2005 Grvl Pkd/Open Beluga F 4,431' 4,757' 4,274' 4,577' 76'* 12 11/17/2005 Grvl Pkd/Open Beluga 4,929' 5,332' 4,735' 5,108' 56'* 12 11/17/2005 Grvl Pkd/Open Beluga H 5,392' 5,908' 5,164' 5,646' 1431* 12 11/17/2005 Grvl Pkd/0 en *Partially Perforated Interval Updated by: DMA04-23-19 N Ililn.rp AL.ln. LLA: Kill Pat WH PSI 2" 1502 x 2-1/11 Flanged Val (Manu ) 2-11161 OK x 10K FlargW (Manual Beluga River Unit BRU 214-26 4/23/2019 Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 Ibs --F--_ 4-1116" 10K Conventional Stripper 5K C062 Lubricator 5K C062 x 4-1116" 10K Flange 4-1/16" 10K Combi BOP Top Set. Blind/Shear Seomd SH Mpe'Shp 4-1/16" 1 O Flow Cross Manual 2x2 Valve 1. 2" 1502x2,1116" 10K Flange Mama) 2x2 Valves 2-1/16" 1OK x2-1/16" 10K Flange Manual 2x2 Valve 3'. 2-1/16" 10K x 2-1/16" 10K Flange Mama) 2x2 Valve4; 2'1502 x 2-1/16" 10K Flange 4.1116" 10K x Wellhead Adapter Flange Wellhead STANDARD WELL PROCEDURE I I ilcorp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALv1 Page 1 of 1 Opm-Top Tank w/ Diffuse s up Annulus) COILED TUBING UNIT N2 JETTNG FLOW SCHEMATC 10,000,000 1,000,000 t Y i c0 L G 300,000 LL v g o Y 10,000 M 0 W O M Y M d LL C 1,000 V 7 V M 100 0 O L H 10 1 a— Jan-1990 HILCORP ALASKA LLC, BELUGA RIV UNIT 214-26 (190-042) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates Cum. Prod Oil (bbls): 0 Cum. Prod Water (bbls): 1,350,802 Cum. Prod Gas (mcf): 132,810,594 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) . GOR -- Produced Water (BOPM) - Produced Oil (BOPM) 10,000,000 W ai 1,000,000 O I 100,000 m 0 0 3 S 10,000 0 Z W d 1 l 1,000 O CM G d M ro 100 ro 0 O 7 s 10 ? I 1 Jan -2020 SPREADSH EET_1900420_BRU_214-26_Prod-I nject_Cu Nes_W el I_Gas_V l20_2Ol9O429.xlsx 4/29/2019 1AlHilcorp wkw, MA; DATE 3/27/2019 19 C04� Debra . udean Hilcorp Alaska, LLC 3 0 508 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 214-26(190-042) CD #1: RECEIVE® FIELD DATA L BRL 214-26_PPROF I4AUG18 11./7!20181:13 PM PDFDocument 4,749 KB BRU 214-26 PPROF_14AUG18_040-dn 11/712 01 8 1:41 PM LAS File 685 KB BRU 214-26 PPROF 14AUG18 j0W-dn 11/7f20181:41 PM LAS File 928 KB BRU 214-26 PPROF 14AUG18_080-up 1117120181:46 PM LAS File 685 KB .]� BRU 214-26_PPROF 14AUG78 120-dn 11172120181:42 PM LAS File 1,209 KB BRU 214-26_PPROF 14AUG18_120-up 11!7,20181:41 PM LAS Fife 1,210 KB Al BRV 214-26 PPROF 14AUG18 img 1117/20181:13 PM TIFF File 7,307 KB :A BRU-214-26PPROF_14.AUG78 stop -3380 111720181.44 PM LAS File 81 KB j BRU 214-26 PPROF 14AUG18 stop -3420 1117/20181:45 PM LAS File 78 KB BRU 214-26 PPROF_14AUG78 stop -3530 11/720181:44 PKI LAS Fife 85 KB BRU 214-26_PPROF 14AUG18 stop -3695 1117120181:43 PM LAS File 75 KB !� BRU 214-26 PPROF_14AUGI6 stop -3995 17720181:43 PM LAS File 80 KB BRU 214-26 PPROF 14AUGIS stop -4354 1117/20181:43 PM LAS File 81 KB ANALYSIS L3 BRU 214-26_PPROF 14AUG18 Processed... 111712012 1:13 PM LAS File L BRU 214-26-PPROF 14AUG18 Report 1117120181:13 PM PDF Document CD #2 WATER CONFORMANCE AND PRODUCTION LOGGING Files Currently on the Disc (7 D) BRU 214-26_ACX_07N W 2930-5940It... fi/r 201812:43 PM DCIS File 198,013 KB BRU 214-26_ACX_07MAY78 2930-5940 t 6161201812:35 PM LAS File Z 521 KB BRU-214-26-ACX 07MAY18_3183-5930ft... 616201 8 1143 PM DLIS File 180,702 KB ia BRU 214-26 ACX78_07MAY3183-5930k 6115, 3`5 !201812PM LAS File 2,301 KB BRU 214-26_ACX_07MAY18_StopAbweSt... 6/6/201B 12:58 PM DLIS File 20,169 KB 21 BRU 214-26_ACX_07MAY78_StopAbweSt... 616/201810211M LAS File 268 KB BRU_214-26_ACX_07MAY18 StopBeluga._ 616201812:58 PM DLIS File 20,203 KB BRU 214-26_ACX_07MAY78 StopBetuga... 616120181:08 PM LAS File 268 KB BRU-214-26_PPROF 07MAYIS 5/31/20181:47 PM LAS File 2,364 KB —�o BRU214-26 WaterConfonnance 07MAY... 616120181:05 PM PDF Document 2,112 KB Please include current contact information if different from above MAR 2 8 2019 AOGCC 1,170 KB 1,666 KB &04**�Q MAR?g?�19 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 e Conoc6Phillips e P. Mazzolini Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 January 9, 2006 RECEIVED JAN 1 0 2006 Alaska Oil & Gas Cons. Commission Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for BRU 214-26 (APD 90-042/305-213) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Beluga River well BRU 214-26. If you have any questions regarding this matter, please contact me at 263-4603 or Mark Chambers at 265-1319. Sincerely, ?~rr¡~ P. Mazzolini Exploration Drilling Team Leader CPAI Drilling and Wells ~k~EJ! ,J/4r~ ,0[ 1. 2DOE PM/skad STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION e e RECEIVED JAN 1 0 2006 REPORT OF SUNDRY WELL OPERA TIONi14~1tA nil R, ~ft_ 1'__ ^ . 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other Ancgag~ Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 90-042/305-213 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20083 7. KB Elevation (ft): 9. Well Name and Number: RKB 104.5' BRU 214-26 8. Property Designation: 10. Field/Pool(s): A-029657 Beluga River Field 11. Present Well Condition Summary: Total Depth measured 6443' feet true vertical 6154' feet Plugs (measured) Effective Depth measured 6020' feet Junk (measured) true vertical 5751' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30" 221' 221' Surface 13-318" 2977' 2896' Production 9-5/8" 6443' 6148' Screen 5.5" 5921' 5658' Perforation depth: Measured depth: 3245'-3676',3846'-4309',4432'-5042',5110'-5908' true vertical depth: 3153'-3566',3727'-4161',4275'-4840',4903'-5646' Tubing (size, grade, and measured depth) 5.5" , L-80, 2950' MD. Packers & SSSV (type & measured depth) Baker SC-2 pkr, 3 Baker SC 1-L pkr, Baker FB-1 @ 2940',3685',4319' & 5055', 5921' WLM Cameo TRM-4E @ 303' 12. Stimulation or cement squeeze summary: RBDMS BFt .IAN 1 0 2006 Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation n/a not available n/a n/a n/a Subsequent to operation n/a not available n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _ X 16. Well Status after proposed work: OilD Gas0 WAGD GINJD WINJD WDSPL 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~~ I~ Contact Mark Chambers @ 265-1319 ~ I-I()-O~ Printed Name Paul Mazzolini Title CI Team Leader Signature?~fVl ~ " ' Phone U3-4¿,o 3 Date 611oc¡ 12-0Dt;, PreDared bv ShafDn AI/sun-Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only Conductpr: 30", 310.00#, X-52 @ 221' MD Surface Casing: 13-3/8", 68.00#, K-55, BTC @ 2977' MD Existing Perfs: 3286' - 3368' 3387' - 3448' 3506' - 3510' 3536' 3598' 3700' - 3850' 3934' - 3941' 3999' - 4006' 4076' - 4085' 4182' - 4188' 4268' - 4277' 4431' 4436' 4553' - 4558' 4978' - 5043' 5392' - 5412' 5586' - 5652' 5796' - 5810' New Perfs: 3245' 3250' 3288' - 3325' 3349' - 3369' 3386' - 3394' 3424' - 3428' 3436' - 3448' 3667' - 3676' 3846' - 3851' 3910' - 3942' 4077' - 4084' 4107' - 4113' 4151' 4156' 4170' 4175' 4183' 4188' 4270' - 4290' 4304' - 4309' 4432' - 4437' 4502' - 4533' 4552' - 4557' 4593' - 4598' 4605' - 4610' 4718' 4723' 4739' - 4757' 4929' 4934' 4998' - 5003' 5013' - 5018' 5032' - 5042' 5110' - 5130' 5322' - 5332' 5744' 5764' 5795' - 5812' 5858' - 5872' 5902' 5908' 14-26 n Schematic System) J PBTO: 6020' MD-RKB (Cleaned out to this depth during workover) Reti:liner: Set @ 6050' w/l0 BBLS Cement Below and 5 BBLS Cement Above Production Casing: 9-5/8", 43.50#, S-95, BTC @ 6443' MD L +/-3,690'MO-OF +/- $.,685' WLM +/- 4,,324' MO - OF +/-4.319'WLM +/- 5,060' MO - OF +/- !i,.055' WLM +/- !i,.926' MO - OF +/- !i,.921 , WLM ¡Iii Tubing Hanger: FMC Hanger w/ 5-1/2", 15.5#, L-80, BTC-Mod Pup Joint installed. Spaceout Tubing Pups (as required): 5-1/2", 15.5#, L -80, BTC-Mod 5-1/2" Carnco 'TRM-4E' w/4562" X-Selective Profile Set @ 303' MD-RKB (Control Line to Surface). (as reqt,lired): 5-1/2'\ 15.50#, L-80, BTC-Mod Sliding Sleeve: Baker 5-1/2" CMU Sliding Sleeve wi 4.562" X-Selective Profile Set@ +/- 2,872' MD-RKB. Handling Pups Installed on Top and Bottom. 5-1/2",15,50#, L-80, BTC-Mod Tt,lbing (Pup Joint): 5-1/2",15.50#, L-80, BTC-Mod PBR Seal Assembly: Baker '190-60' PBR Seal Assembly w/ 15' Stroke (7.05" OD x 4.88" ID). Seals Spaced Out 2.5' Anchor assembly: Baker Model 'S-22' Anchor Tubing Seal Assembly (7.00" OD x 4.88" ID) P¡¡¡eker: Baker SC-2 Packer (96C-60 /43.5# Casing /8.313" OD x 6.00" ID) and GP Assembly (as per BOT Completion Schematic) Mod w/ Protection Sleeve. Blank Pipe (as required): 5-1/2",17.00#, L-80, SLHT Blank Pipe Pup (as required): 5-1/2",17.00#, L-80, SLHT Gravel Pae.k Screen (as required): 5-1/2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Baker SC1-L Packer (8.125" OD )( 6.00" ID) and GP Assembly Schematic) Blank Pipe (as required): 5-1/2",17.00#, L-80, SLHT Blank Pipe - Braden Pup required): 5-1/2",17.00#, L-80, SLHT Gravel Pack. Screen (as required): 5-1/2",17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Baker SCI-L Packer (8,125" OD x 6.00" ID) and GP Assembly BOT Schematic) Blank Pipe (as required): 5-1/2",17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2",17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-1/2",17.00#, L-80, SLHT Baker Excluder 2000 Medium 316L Screen Packer: Baker SCl-L Packer (8.125" OD x 6.00" ID) and GP Assembly per BOT Schematic) Blank Pipe (as required): 5-1/2",17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2",17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-112",17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker FB-1 Permanent Sump Packer (8.280" OD x 6.00" ID) and Lower Tail BOT Completion Schematic) BRU 214-26 Schematic prepared by Mark Champers 01/09/06 ConocoPhillips Alaska Operations Summary Report Scope down derrick and assist Swaco for rig move, blow down boiler and service lines, RD HPU hyd lines unstring tuggers, unstring draworks, clean pits RD poor boy gas buster, Pump out hot well, pump out water tanks, blow down lines, drain pumps, pull and roll up cables, Remove DS back wind wall, dog house, change room, degasser, DS back wind wall, roof cap, ODS dog house, shaker building, remove desander pit, water tank, BOP rails, install rams and scope up and pin floor, lower floor. Lay derrick onto trailer, un-pin rams, RD portable HPU, remove floor plates, choke, koomey, remove subbase wings, load out sub transport, sub and mast, travel to 214-26, load out matting boards and carry to 214-26, RD support buildings and transport to 214-26,spred herculite and mats for sub, set sub base wings, set koomey and accumulator buildings, line up mast trailer and skid mast to floor and pin same, set in white iron floor plates, set protable power pack, set office and sleepers, RU temp power, Raise mast and pin, raise floor Rig down raising rams,set desander pit,shaker house,off drillers side doghouse,wind cap,degasser,water tank,break room,doghouse,wind cap,stairs & landings,bolt up windwalls,set front windwalls,lay herculite for support modules,set matting boards for support complex,set support module buildings. Set power modules,9SS broke down for 3 hrs., set up ,pipe racks & cat walk,work on flow line,set bop trolley,pull electric i lines, rigging up pump room. String tugger lines, rig up drawworks hyd. lines, rig up service lines,install flolines,work on service lines,suction manifold valves,electric lines to pic, string out drlg. line for respool,spoolline on drum & inspect derrick, raise derrick,rig up beaver slide,pick up torque tube,undo bridle lines & hang off,start building berm around rig,spot landings for catwalk, spot bop dolly, hang tongs, rig up service loop to top drive,install bails & sub racks,rig up gas buster,fix leaking & bad steam hoses,pull wires, weld flow line extentions. Rig up flow lines,r/u choke line, hook up equalizers in pits,fill pits w/ fluid to check for leaks,set berm up around rig, roll mud pumps,transfer fluid thru gun lines to check for leaks, hook up pit sensors, pressure test I mud lines to 4500#. 12.00 i WELLSl' OTHR I WRKOVR Rig accepted@1200hrs. 10/2S/2005.=Rig up & winterize swaco,build S.6# kill fluid. Rig up pollard wire line & pull bpv,s, Continue building kill fluid & rigging up swaco. Rig up on 2 7/S" long string. Rig up on annular . I valve to choke manifold. Vetco opening air accuated annular valve 2.50 WELCT~' KILL WRKOVR i Continue building S.6 ppg brine 2.50 WELCT KILL WRKOVR Pump dn 2-7/S' long string take rtns thru choke manifold from 9-5/S" annulus. Pump 470 bbls @ 4 bpm w/ no rtns 1.00 WELCTUKILL IWRKOVR RU on 3-1/2" short string while building brine volume 1.50 WELCT~' KILL WRKOVR build brine volume 1.50 WELCTL KILL WRKOVR Pump dn 3-1/2 short string 175bbls @4 bpm w/ no returns 0.50 WELCTL KILL WRKOVR RU to pump dn 2-7/S" string 3.00 WELCT KILL WRKOVR Pump dn 2-7/S" long string 90 bbls @ 1 bpm w/ no rtns while building I pill, pump 24 bbls 2.5 ppg HEC pill @ 2 bpm until pill outside hole. ~ alternate slow puming and shuting down to let pill soak. 0.50! WELCTL' KILL WRKOVR RU to pump dn 3-1/2" string 1.00 WELCT KILL I WRKOVR Pump dn short string@ 2 bpm w/ 50 psi, increase to 3 bpm @ S5psi ! getting partial rtns. loosing 2 bpm. slow to 2 bpm loosing 1.S bpm 1.00 WELCT~ KILL WRKOVR ! RU on 2-7/S" while finish building 2.5 ppg HEC pill Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BRU 214-26 BRU 214-26 WORKOVER/RECOMP Date Kuukpik 5 , '!! Sub I : From - To : Hours . Code ! Code! Phase --;;;00 - O~;;)T 2400 M';;; I Mo;~i MOVE ! 10/24/2005 1 0/25/2005 00:00 - 00:00 24.00 MOVE MOVE MOVE 10/26/2005 24.00 I MOVE I RIGUP 00:00 - 00:00 MOB 10/27/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 10/2S/2005 00:00 - 12:00 I 12.00! MOVE RURD RIGUP 12:00 - 00:00 10/29/2005 00:00 - 02:30 ! 02:30 - 05:00 05:00 - 06:00 06:00 - 07:30 ,07:30 - 09:00 ! 09:00 - 09:30 i 09:30 - 12:30 12:30 - 13:00 I 13:00 - 14:00 : 14:00 - 15:00 Page 1 of14 Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 Description of Operations ......~._---_._..... . ............-..--....... ........----.--... Printed: 12/1612005 11:23:52AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ,From - To 10/29/2005 115:00 - 16:00 16:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 10/30/2005 00:00 - 00:30 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 04:00 04:00 - 15:00 15:00 - 17:00 17:00 - 00:00 10/31/2005 00:00 - 06:00 06:00 - OS:30 OS:30 - 11 :00 11 :00 - 12:00 12:00 - 15:30 15:30 - 16:00 16:00 - 1S:00 1S:00 - 20:15 20:15 - 22:15 22: 15 - 00:00 11/112005 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:15 02:15 - 03:30 03:30 - 06:00 06:00 - 09:00 ConocoPhillips Alaska Operations Summary Report Page 2 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Start: Rig Release: Rig Number: Kuukpik 5 Hours Code ¡ Sub : Code --j" 1.00 WELCTiKILL 5.00 WELCTi KILL I Phase Description of Operations ...--.. ....~,..._-----....- .... ........_.....__.____w __..... ....---...-..---- WRKOVR pump pill through hole in 2-7/S" tubing, close choke squeeze 5 bbls wI 50 psi at 2 bpm. Open choke wI no change in pump pressure. monitor losses at 2bpm loosing 1.2 bpm. WRKOVR While building pill-rig up on 13 3/S" X 9 5/S" annulus-bleed pressure from 600# to 0# monitor 15 mins.-Rig up on 9 5/S" annulus & 3 1/2" tbg. Spot 22 bbl. HEC pill in tbg. & monitor for 2 hrs. Hole took 19 bbls. in 2 hrs. WRKOVR Circ. surface to surface thru 3 1/2" short string to assure pill is out of tbg. WRKOVR Rig up wireline on 3 1/2" short string-rih & close sliding sleeve @ 3121'. RIH wI plug & set in "XN" nipple @ 320S'. WRKOVR Set prong in 3 1/2" "XN" nipple @ 320S'. WRKOVR Pressure test upper packer to 1000# install bpv,s in 3 1/2" & 2 7/S" tbg. (roll back clocks 1 hr.) Rig down slick line unit-lubricator & sheaves. Pull rotary table-nipple down & layout tree. Stack extention spool,annular & double gate. stack single gate, mud cross & riser spool. Nipple up extention spool, riser spool,mud cross, choke line,killline,single gate,double gate,annular,flow nipple & flow line. Hammer up stack, choke & kill lines. Hook up koomey lines. 2.00 WELLS~ SLlN WRKOVR Rig up pollard wire line-pull bpv's-set test plugs.-rig down wire line. 7.00 WELCT~! BOPE WRKOVR Test bope 250/3000 on choke manifold valves #1 thru #16.250/1000 on 1.9" top rams-no test on blinds-hanger leaks. Annular element leaks on 1.9" test jt. 6.00 WELCT BOPE WRKOVR I Test 2 7/S" floor valve, manuallBOP, Hydraulic IBOP to 250/3000 psi. ¡Attempt to test annular against blinds with 2 7/S" tubing - negative. 2.50 WELCTW BOPE WRKOVR i Continue to test surface BOP equipment - floor valves & dart valve to ~i 250/3000 psi. 2.50 WELCT EQRP I WRKOVR Pull rotary table, ND flowline niple and flowline. Pull annular preventer i cap and change out element. 1.00 WELCT EQRP WRKOVR NU flowline & nipple. Set rotary table. 3.50 WELCTL BOPE WRKOVR Test annular preventer with 2 7/S" tubing to 250/3000 psi. 0.50 WELCTU BOPE WRKOVR Pull two way check valves from both long & short strings 2.00 WELLSR PLGM WRKOVR RU Pollard wireline on 3 1/2" short string. In two runs pull prong & plug ] R ' from XN nipple @ 320S' MD. RD Pollard. 2.25' WELLS OTHR 'WRKOVR RU APRS eline. RIH with jet cutter on 3 1/2" short string and cut at 3102' MD - middle of first full joint above sliding sleeve. While RIH with , cutter hole began taking fluid at 50 bph. 2.00 WE LCT:' OTHR . WRKOVR Mix 25 bbl pill with 4 Ib/bbl HEC and fill hole with same. Observe losses i decrease to 25 bph. 1.75 WELLS OTHR WRKOVR RIH with jet cutter on 2 7/S" long string and cut at 3035' MD - 10' from top of full joint. POOH with cutter assembly. 0.50 WELLS : OTHR WRKOVR Continue POOH with APRS cutter. RD APRS. 0.50 FISH i RURD WRKOVR RU to pull 1.9" heater string. 1.25! WELCT' CIRC I WRKOVR . ~~.served losses increase to 45 bph. Fill hole with 25 bbl 4 Iblbbl HEC 1.25 FISH PULD WRKOVR i PU 2 7/S" landing joint. MU 1.9" blanking plug retrieval tool & crossover. I Tie into 1.9" heater string and pull heater string mandrel free. Lose I returns while filling void below tubing hanger. Pumped 10 bbls before ì observing returns at surface. Observed losses decrease to 24 bph. LD 'I I blanking plug & mandrel 2.50' FISH PULL' WRKOVR . LD 63 joints and mule shoe of 1.9" heater string. 3.00 WELCT BOPE WRKOVR I RU trip tank to annulus. Change top rams from 1.9" to 2 7/S" x 5 1/2" 2.00 WELLS WRKOVR WRKOVR WRKOVR 1.00 WELCT 0.50 WELLS 0.50 WELLS 0.50 WELLS 2.50 WELLS 11.00 WELCT Printed: 12/16/2005 11:23:52AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To ____m__________..._ .. 11/1/2005 06:00 - 09:00 09:00 - 10:00 10:00 - 12:30 12:30 - 14:00 14:00 - 17:00 17:00 - 17:45 17:45-1S:15 1S:15 - 1S:45 1S:45 - 20:15 20:15 - 21:15 21:15-23:00 23:00 - 00:00 11/2/2005 I i 00:00 - 03:00 03:00 - 09:30 09:30 - 10:30 10:30 -11:00 11:00 -13:15 ! 13:15 - 14:00 I 14:00 - 15:15 15:15 -16:15 '16:15 - 19:15 19:15 - 19:30 19:30 - 21 :00 21 :00 - 00:00 e ConocoPhillips Alaska Operations Summary Report Page 3 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP Spud Date: 10/29/2005 End: Group: Start: 10/24/2005 Rig Release: 12/2/2005 Kuukpik 5 Rig Number: Hours! COde! ~~Je: Phase l Description of Operations ·H!r§CT~ ~~~ ~:~g~:I~::;r~~~:!~:~~i:2 ::" m,"drnl ;"~:~:e'- 'I negative, seal sleeve still installed in mandrel. MU spear on drill pipe and attempt to engage tubing - unable to get spear inside 2 7/S" due to OD on tool joint on drill pipe. FISH WRKOVR MU spear to joint of 2 7/S" tubing. Engage 2 7/S" long string. Pull mandrel free from hanger with 35 klbs overpull. Pull mandrel to surface I & LD same. PULL IWRKOVR LD 96 joints, S pup joints + 10' stub of 2 7/S" EUE SRDMod long string. i Total length 3017'. OD on stub 3.75". RURD !WRKOVR RU to pull 3 1/2" short string and hanger. MU spear to 2 7/S" landing I joint. Back out remaining holddown bolts and allow stack to drain. FISH ,WRKOVR RIH and engage spear in hanger. Pull string and hanger free with no I overpull. Pull hanger to surface. Removed spear and 3 1/2" seal sleeve. Observed hole in hanger body - outside of heater string. LD hanger. RU to LD 3 1/2" short string. LD 44 joints of 3 1/2" CS Hydril short string. 31/2" full of HEC pill. MU top drive and pump 15 bbls of S.6 KCI brine to clear string. WRKOVR Continue POOH LD 31/2" CS Hydril short string. LD total 100 joints, 12 pup joints + 15' stub. Total length 30S7'. WRKOVR RU to test BOP stack components unable to be fully tested with leaking hanger in place. Fluid losses to the hole today: 390 bbls. Total to well since start-up: 201S bbls. Test annular, variables, blind and lower pipe rams to 3000 psi. LD BOP test plug PU 2 7/S" overshot assembly #1 with hollow mill carrier. PU drill collars. RIH with 2 7/S" overshot assembly #1 to 1700' MD PU drill pipe. Service top drive. Continue RIH with 2 7/S" overshot assembly #1 to 3034' MD PU drill pipe. FISH !WRKOVR Took weights, Up 76 klbs, Down 66 klbs, Rot 70 klbs. 31 psi @ 40 spm. Tagged top of fish at 3034' MD. Mill over top. Pressure increase to 97 psi. Engage fish with overshot. PU to bleed jars. Released Baker i ! packer AL-5 with 40 klbs straight pull. 'I ' !I PU to release safety joint under packer on long string. Work pipe 4-5 ¡ times with 50 klbs overpull. PU to 60 klbs overpull and with one blow of I jars sheared safety joint. Up weight increased to 7S klbs. 1.25 WELCT~ COND WRKOVR! Fluid U-tubing in well after releasin~ ~acker. Shut in and circulated L i ' bottoms up over the choke. HEC pili In returns. 1.00 WELCT CIRC i WRKOVR Open the BOP and circulated bottoms up. Monitor the well for flow - , negative. 3.00 FISH I TRIP WRKOVR I POOH with 2 7/S" overshot assembly #1 to top of drill collars. 0.25 WELCTU OBSV WRKOVR: Monitor well before pulling drill collars - ok. 1.50 FISH i PULD ,WRKOVR' Stand back drill collars. LD fishing assembly. 3.00 FISH PULL 'WRKOVR Begin LD fish. 2 7/S": tubing stub, 5 joints, 2 pup joints, GLM, Baker AL-5 packer & safety joint - length recovered: 209' : 3 1/2": tubing stub, 3 joints, 4 pup joints, sliding sleeve valve, XN nipple, 'WEG - length recovered: 146' 1.50 i FISH ¡ I 3.00 I FISH 0.75 FISH 0.50 FISH 0.50 FISH 1.50 FISH 1.00 FISH I RURD !PULL CIRC ¡ , 1.75 FISH J PULL 1.00 WELCT BOPE WRKOVR WRKOVR WRKOVR I 3.00 WELCTi BOPE ! WRKOVR 6.50 FISH PULD WRKOVR 1.00 FISH TRIP WRKOVR 0.50 RIGMNTi RSRV WRKOVR 2.25 FISH TRIP WRKOVR 0.75 FISH Fluid losses to the hole today: 126 bbls. Total to well since start-up: Printed: 12/16/2005 11:23:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date m__ _____ ____....__ 11/2/2005 11/3/2005 03:45 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 10:45 10:45 - 13:15 13:15 - 14:30 i 14:30 - 20:00 20:00 - 21:45 21 :45 - 00:00 11/4/2005 00:00 - 03:30 i 03:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 09:00 09:00 - 09:15 09:15 - 11 :00 11:00 -11:30 11 :30 - 13:00 13:00 - 14:30 14:30 - 16:15 16:15 - 16:45 ConocoPhillips Alaska Operations Summary Report I Sub I Code Phase! - PUL~-rW~KOV~-r;~~~-bbIS. ---- PULL ! WRKOVR I Finish LD fish. 12 7/S": tubing stub, 5 joints, 2 pup joints, GLM, Baker AL-5 packer & I safety joint - length recovered 209' 13 1/2": tubing stub, 3 joints, 4 pup joints, sliding sleeve valve, XN nipple, IWEG -length recovered 146' i RD dual handling equipment. Clear rig floor. WRKOVR i PU 2 7/S" overshot assembly #2. RIH on drill collars. WRKOVR [Service top drive. I WRKOVR Troubleshoot UPS. !WRKOVR RIH with 2 7/S" overshot assembly #2 to 3200' MD on drill pipe. i WRKOVR Circulate bottoms up at 6 bpm & 246 psi. WRKOVR Took weights, Up 7S klbs, Down 67 klbs, Rot 71 klbs with 4 kft.lbs. 64 psi @ 3 bpm. Tagged top of fish at 3244' MD. Pressure increase to 150 psi. Engage fish with overshot. Work overpull to 60 klbs. Let jars fire once - pipe comes free. RIH and tag 6' high, see pressure increase and 4 klbs drag. WRKOVR Monitor well for flow - ok. WRKOVR POOH with 2 7/S" overshot assembly #2 to top of drill collars. WRKOVR I Stand back drill collars & LD overshot - no fish. WRKOVR i RU GBR. MU washpipe assembly #1. MU drag shoe. PU 14 joints of 7 : 5/S" washpipe. PU junk baskets. RIH on collars. TRIP iWRKOVR RIH with washpipe assembly #1 to top fish at 3244' MD on drill pipe. :WASH WRKOVR Took weights, Up S3 klbs, Down 69 klbs, Rot 76 klbs with 36 rpm & 3400 ft.lbs. 249 psi @ 6 bpm. Tagged top of fish at 3244' MD. Wash over fish with 36 rpm & 6.5 bpm from 3244 to 3551' MD with no weight ,and torque 3-4 kft.lbs. From 3551' to 3566' MD had increase in torque 'to 7-S kft.lbs with negligible weight. At 3566' MD took 5 klbs and stalled out. Slow progress to 356S' MD at mid night. First sand at shakers at this depth. Fluid losses to the hole today: 110 bbls. Total to well since start-up: i 2254 bbls. WASH WRKOVR Continue washing over fish. Increase pump rate to 9.5 bph @ 570 psi and rpm to 40. Pumped sweep. Broke through bridge at 3572' MD - bottom of blast joints.Start loosing at 120 bph. Reduce pump rate to 6 bph. Loss rate decreased to 60-70 bph. Tag packer at 3622' MD while mixing sweeplHEC pill. Circulate bottoms up - sand & gel in returns. Pump sweeplHEC pill. Losses decrease to 30 bph. 1.00 FISH i TRIP WRKOVR POOH with waspipe assembly #1 above top of fish at 3244'. 0.50 FISH ~ CIRC WRKOVR I Spot 25 bbl HEC pill. 2.50 FISH TRIP WRKOVR' POOH with wash pipe assembly #1 to top of drill collars. 0.25 WELCT OBSV WRKOVR Monitor well for flow - ok. 1.75 FISH PULD IWRKOVR Stand back drill collars, break and clean out junk baskets - 5 gal of I sand & metal cuttings. LD jars. RURD WRKOVR RU GBR to break out washpipe. PULD WRKOVR Stand back 7 stands of washpipe. LD drag shoe - 70% worn. PULD WRKOVR MU 2 7/S" overshot assembly #3 and RIH on drill collars. TRIP ¡WRKOVR RIH with 2 7/S' overshot assembly #3 to 3244' MD on drill pipe. I FISH !WRKOVR Took weights, Up 76 klbs, Down 66 klbs, Rot 70 klbs at 15 rpm. 46 psi ! @ 3 bpm. Tagged top of fish at 3244' MD. Engage fish with overshot. Pressure increase to 95 psi. PU and fish comes free with slight BRU 214-26 BRU 214-26 WORKOVER/RECOMP 2.25 FISH PULD 0.50 RIGMNT RSRV 0.50 RIGMNT RGRP 2.00 FISH I TRIP 0.50 FISH CIRC 1.00 FISH i FISH 0.25 WELCTU OBSV 2.50 FISH TRIP 1.25 FISH PULD 5.50 FISH PULD 1.75 FISH 2.25 FISH 3.50 FISH 1.50 FISH CIRC Kuukpik 5 I ¡ From - To ! Hours I Code - - - -- L - -----1---- 21 :00 - 00:00 3.00 FISH 00:00 - 03:45 3.75 FISH 0.50 FISH 1.50 FISH 1.50 FISH 1.75 FISH 0.50 FISH Page 4 of 14 Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 Description of Operations ............---.-.--.... IWRKOVR Printed: 12/1612005 11 :23:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/4/2005 11/5/2005 11/6/2005 e ConocoPhillips Alaska Operations Summary Report BRU 214-26 BRU 214-26 WORKOVER/RECOMP Kuukpik 5 Page 5 of14 Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 From - To ! Hours i Code ,.~~~~~___Pha~e_j_____~eS:_~i~tion of Op~~~~~~~_~____ 16: 15 - 16:45 0.50 FISH II FISH I WRKOVR overpull. Pressure dropped to 58 psi, Up weight 82 klbs. RIH & tagged , at 3244' MD, observed no pressure increase. 16:45 - 17:15 0.50 FISH : CIRC !WRKOVR Circulate bottoms up at 4.5 bpm & 150 psi. 17:15 - 20:00 2.75 FISH 'TRIP WRKOVR POOH with 2 7/8' overshot assembly #3 to top of drill collars. 20:00 - 20:15 0.25 WELCTJOBSV WRKOVR Monitor well for flow - ok. 20:15 - 21 :00 0.75 FISH I PULD WRKOVR Stand back drill collars and LD overshot - fish at surface. 21 :00 - 00:00 3.00 FISH 'PULL WRKOVR RU GBR. LD Fish - Baker safety joint, 1 joint 2 7/8" and 12 x 20' 3 3/4" I blast joints. Hole in blast joint at 3515' MD. ! i 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 07:45 07:45 - 10:00 10:00 - 10:15 10:15-11:00 11 :00 - 12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 18:00 18:00 - 18:15 18:15 - 19:00 19:00-20:15 20:15 - 22:30 22:30 - 00:00 00:00 - 00:45 00:45 - 01 :30 Fluid losses to the hole today: 343 bbls. Total to well since start-up: 2597 bbls. PULL ¡ WRKOVR Continue LD Fish - 3 x 20' 3 3/4" blast joints and collar from pup joint on GLM (drag shoe had milled up 25% of collar). Total length of fish recovered 330.97'. Top of fish at 3575' MD. RD GBR. Clear floor. MU 2 7/8" overshot assembly #4 with hollow mill. Service top drive. RIH with 2 7/8" overshot assembly #4 on drill collars. RIH with 2 7/8" overshot assembly #4 to top of fish at 3575' MD 0)1 drill pipe. PU 12 joints of pipe from pipe rack. FISH WRKOVR Took weights, Up 82 klbs, Down 70 klbs, Rot 76 klbs. 56 psi @ 3 bpm. Tagged top of fish at 3571' MD. Engage fish with overshot. Pressure increase to 115 psi. PU with 33 klbs overpull. Weight dropped off. RIH & tag up but observe no pressure increase. WRKOVR I Circulate bottoms up. WRKOVR Monitor well for flow - ok. WRKOVR POOH with 2 7/8" overshot assembly #4 to top of drill collars. WRKOVR Monitor well for flow - ok. ! WRKOVR Stand back drill collars. Pull overshot to the floor - no fish. Marks on BHA indicate grapple not over fish. Marks on hollow mill. WRKOVR Redress overshot and RIH with 2 7/8" overshot assembly #5 on drill collars. WRKOVR RIH with 2 7/8" overshot assembly #5 to 3571' MD on drill pipe. WRKOVR Took weights, Up 84 klbs, Down 72 klbs, Rot 78 klbs. 43 psi @ 3 bpm. Tagged top of fish at 3571' MD. Engage fish with overshot. Pressure increase to 900 psi. Bottom out on fish with cut lip guide. PU with 26 klbs overpull. Weight dropped off. RIH & tag up several times, pressure 60-70 psi. Circulate bottoms up. POOH with 2 7/8" overshot assembly #5 to top of drill collars. Monitor well for flow - ok. Stand back drill collars. Pull overshot to the floor. Fish on. LD fish - pup joint, GLM, pup joint, 1 joint, Baker Anchor. Holes 4' & 6' below collar on full joint (3600' & 3602'). Total fish length recovered this time: 52'. Top offish at 3626' MD PULD ¡ WRKOVR PU rope spear assembly #1 & RIH on drill collars. TRIP WRKOVR RIH with rope spear assembly #1 to 2600' MD on drill pipe. 1.00 FISH 1.50 FISH PULD 0.50 RIGMNT RSRV 0.50 FISH PULD 3.00 FISH TRIP 0.50 FISH 0.50 FISH CIRC 0.25 WELCTU OBSV 2.25 FISH i TRIP 0.25. WELCTL'TRIP 0.75! FISH PULD 1.50 FISH PULD 2.00 FISH iTRIP 0.50 FISH . FISH 0.50 FISH ; CIRC 2.50 FISH LTRIP 0.25 WELCT OBSV 0.75 FISH PULD 1.25 FISH I PULL 2.25 FISH 1.50 FISH WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR ! WRKOVR WRKOVR WRKOVR WRKOVR 0.75 FISH 0.75 FISH Fluid losses to the hole today: 121 bbls. Total to well since start-up: I 2718 bbls. TRIP i WRKOVR RIH with rope spear assembly #1 from 2600 to 3626' MD on drill pipe. FISH WRKOVR I Took weights, Up 84 klbs, Down 72 klbs, Rot 78 klbs. 166 psi @ 3 bpm. 'Tagged top of fish at 3626' MD. Set down 4 klbs and rotate 2 turns. PU. Repeat several times. PU off fish - no overpull. Printed: 12/16/2005 11:23:52AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/6/2005 11/7/2005 ! Sub ¡ From - To · Hours. Code I Code! Phase , Description of Operations 01 :30 - 02:00 .. 0.50 ~;.~-~-~~~ . W~~~VR I~i~~ulat~' ~~~~ms u~:--·- . ·.m_____ ... -.-- .----.. 02:00 - 02:45 0.75 WELCTY OBSV WRKOVR i Monitor well for flow while rearrange washpipe in derrick - ok. 02:45 - 05:00 2.25 FISH I TRIP WRKOVR POOH with rope spear assembly #1 to top of drill collars. 05:00 - 05: 15 0.25 WELCTU OBSV WRKOVR Monitor well for flow - ok. 05: 15 - 07:00 1.75 FISH i PULD WRKOVR Stand back drill collars. Pull spear to floor - recovered 20' of slickline : from rope spear. LD jars, bumper sub & spear. 2.00 FISH . PULD WRKOVR, PU new set of jars, bumper sub & "D" packer milling assembly #1. RIH : on drill collars. TRIP WRKOVR i RIH with packer milling assembly #1 to 3626' MD on drill pipe. MILL iWRKOVR [Took weights, Up 86 klbs, Down 72 klbs, Rot 78 klbs. 178 psi @ 3 bpm. i Tagged top of fish with mill at 3626' MD. Pressure increase to 1500 psi. i Hung up trying to PU - 30 klbs overpull. Attempt numerous times to get back down to TOF - negative. Circulate bottoms up. POOH with packer milling assembly #1 to top of drill collars. Stand back drill collars & LD packer milling assembly #1. No significant marks on mill or grapple. i PULD WRKOVR PU packer milling assembly #2 & RIH on drill collars. ¡TRIP WRKOVR RIH with packer milling assembly #2 to 3626' MD on drill pipe. MILL WRKOVR ¡Took weights, Up 84 klbs, Down 72 klbs, Rot 76 klbs with 34 rpm & 13200 ft.lbs. 120 psi @ 3 bpm. Tagged top of fish at 3625' MD. Start milling with 4 klbs WOB, 60 rpm, 4.5 bpm. Signs of fish rotating with shoe. Stalled out several times with 20 klbs overpull when PU. Continue milling with WOB 4-10 klbs, 60 rpm, 3-6 bpm. Progress to midnight- inches. 07:00 - 09:00 09:00 - 11 :00 11 :00 - 13:30 13:30 - 14:00 14:00 - 15:45 15:45 - 17:00 17:00 - 19:30 19:30 - 21 :45 21 :45 - 00:00 00:00 - 02: 15 02:15 - 02:45 02:45 - 03:30 03:30 - 04: 15 04:15 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 10:30 10:30 - 15:30 15:30 - 17:30 e , ConocoPhillips Alaska Operations Summary Report . Page 6 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Kuukpik 5 Start: Rig Release: Rig Number: 2.00 FISH 2.50 FISH 0.50 FISH 1.75 FISH 1.25 FISH CIRC WRKOVR TRIP WRKOVR PULD WRKOVR 2.50 FISH 2.25 FISH 2.25 FISH 2.25 FISH Fluid losses to the hole today: 136 bbls. Total to well since start-up: 2854 bbls. WRKOVR . Continue milling Baker "D" packer. WOB stopped milling off, torque i constant indicating rotating with fish/junk. Vary rpm 35-65, pump rate 0 - 6 bpm & WOB 4 - 12 klbs to get mill shoe to bite. Evidence of junk in the hole - stalling out, torque & overpull when picking up off bottom and not always able to get back on depth. WRKOVR Continue milling - start to mill off. Mill packer to 3627.5' - lose returns. WRKOVR PU & shut down pump. Fill hole and monitor well on the trip tank - losing 40 bph. Bring pump back on at 3.5 bph with returns. RIH and tag fish - lose returns. PU & shut down pump. Fill hole and monitor on the trip tank - losing 30 bph. WRKOVR ¡With 50 rpm RIH & tag fish. Stage up pumps to 3.5 bpm while milling . on fish with returns. Fish appeared to drop & observed an increase in flow. WRKOVR PU & shut down pumps. Monitor well and observe fluid falling in ,annulus. Observe drill pipe pressure increasing to 78 psi. Shut well in ¡ and line up to circulate over the choke. WRKOVR Circulate gas bubble out over the choke. Initial circ press - DPICsg - 78/40 psi. Final circ press - DPICsg - 102/105 psi. Open well. No flow. CBU at 5 bpm. No gas. Monitor well on trip tank. FL - 9 bph. PU DP and wash to top of fish at 3958'. Pump hi vis sweep. Circ hole clean. Monitor well & poh stand back dc,s. Break down & clean out junk baskets Recovered packer parts-metal & wire. MILL 0.50 FISH ¡MILL 0.75 WELClOBSV 0.75 FISH L MILL 0.25 WELCT OBSV I i 2.00 WELCTL CIRC 1.00 WELCTU CIRC WRKOVR 0.50 WELCTLI OBSV . WRKOVR I 2.00 FISH TRIP. WRKOVR 0.50 FISH CIRC 'WRKOVR 5.00 FISH TRIP WRKOVR 2.00 FISH PULD WRKOVR ! I Printed: 12/16/2005 11:23:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/7/2005 11/S/2005 11/9/2005 Kuukpik 5 ; Sub' ; From - To Hours Code I Code I Phase. .. Description of Operations 17:30 - 00:00 6.50 ~I~~--T~~HR i~~~~VR ~e~;-~II~~~e 250~~~~;.~hange~~~-r~~-ber seal on~~~;~IU-~. 00:00 - 01 :30 1.50 WELCTy BOPE I WRKOVR I Finish test BOPE to 250/3000 psi. Replaced dart valve. 01 :30 - 02:00 0.50 WELCTLIOTHR ! WRKOVR Pull test plug. Install wear bushing. 02:00 - 04:00 2.00 FISH TRIP iWRKOVR MU and RIH w/S1/S" OS (7" grapple), jars, bumpersub, DC's and accelerator jars. TRIPWRKOVR RIH to TOF at 395S'. FISH IWRKOVR Break circ at 2 bpm 65 psi. Engage fish. Pressure increased to 300 psi. i POH 20' to 393S'. Fish wt - 25k. Drop ball and rod. CIRC !WRKOVR I Shear circulating sub at 1400 psi. CBU 7 bpm. TRIP . WRKOVR i POH slow w/4 1/2" DP. Intermittently hanging up in csg collars. Max I pull - 30k over string wt. No drag going down. Acts like junk on top of í overshot. (Pull wear bushing-found 2 slip pieces riding on top of packer) RURD WRKOVR II Rig up GBR csg. equipment to lay down fish. PULD WRKOVR: Laying down fish (drill hole in each jt. to relieve pressure). Retrieved i wire line tools lost in tbg. prior to rig work. 04:00 - 07:00 07:00 - OS:OO OS:OO - 09:00 09:00 - 17:30 117:30 - 1S:00 1S:00 - 00:00 00:00 - 10:00 10:00 - 11 :00 11:00-12:001 i 12:00 - 12:30 I 12:30 - 16:00 16:00 - 00:00 11/10/2005 00:00 - 01 :30 01 :30 - 04:30 04:30 - 12:00 12:00 - 00:00 11/11/2005 00:00 - 00:30 ¡ 00:30 - 01 :00 i 01 :00 - 03:00 03:00 - 07:30 07:30 - OS:OO OS:OO - 11 :30 11:30-12:00 12:00 - 17:00 117:00 - 1S:30 i 1S:30 - 21:00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 11/12/2005 00:00 - 03:30 03:30 - 04:30 e GonocoPhillips Alaska Operations Summary Report Page 7 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Sta rt: Rig Release: Rig Number: 3.00 FISH 1.00 FISH 1.00 FISH S.50 FISH 0.50 FISH 6.00 FISH 10.00 FISH Total FL last 24 hrs - 10S bbls PULD WRKOVR Finish POH LD fish. Complete recovery. Total - Pkr, mill out extension, XO, XN nipple, 26 jts 2 7/S" tbg, 2 pup jts, 1 GLM, 31 blast jts and WLEG. Sand bridges and trapped gas in tbg. Drilled a hole all tbg and blast jts that were plugged to relieve pressure. RURD WRKOVR RD GBR and tbg equipment. OTHR IWRKOVR Clean sand and mud from rig floor. i OTHR WRKOVR iRe-install wear bushing. I PULD WRKOVR LD 14 jts 7 5/S" wash pipe from derrick. TRIP WRKOVR Make up BHA-S 1/2" bit-3 junk baskets,dc,s & XO. RIH & picking up 4 1/2" dp. 1.00 FISH 1.00 FISH 0.50 FISH 3.50 FISH S.OO FISH FL last 24 hrs - 100 bbls 1.50 WELLSRI TRIP WRKOVR I RIH picking up 41/2" dp. Tag fill @ 5970'. 3.00 WELLSR CIRC WRKOVR i Clean out from 5970' to 6020'-CBU gas to surface & lots of old drlg. I ml;Jd-pump sweep. Up wt. 124k Dn. wt. 94k Rot wt 108k. 7.50 WELLS1TRIP WRKOVR POH to 392'=Flow check=Stand back DC,S & lay down jars, bumper sub & junk baskets. 12.00 LOG ELOG. WRKOVR Rig up SOS-1 st Run USIT=second run RST wI GR. (Lost S1 bbls. to I hole last 24 hrs.) 0.50 LOG I ELOG WRKOVR i POH wI RST tool. 0.50 LOG ;' RURD WRKOVR RD Schlumberger. 2.00! WELLS PULD WRKOVR RIH w/6 stds 6 1/S" DC'sl POH LD same. 4.50: WELLS TRIP iWRKOVR RIH wI Baker 9 5/S" retrievomatic pkr to 3111'. 0.50 WELLS DEQT: WRKOVR i Set pkr and test annulus to 3000 psi for 10 min. OK. 3.50 WELLS~ TRIP WRKOVR: POH wI pkr. 0.50 WELLSRI PULD WRKOVR Make up BHA-Clean out assy. wI scraper-brush & magnet. 5.00 WELLS~TRIP .WRKOVR Finish making up bha & rih to 2S92'. 1.50 WELLS PULD WRKOVR Make up scraper, brush & magnet. 2.50 I WELLS TRIP iWRKOVR RIH to 6020'. 0.50 WELLS OTHR I WRKOVR ; Flush bope & lines wI safe surf. 0.50 WELLSR OTHR WRKOVR i Clean pits. 1.00 WELLS~ CIRC WRKOVR Displce well to clean 6% KCL. & monitor well f/15 mins. 1.00 WELLS~ TRIP .' WRKOVR POH-Wiper trip to top scraper. (Daily fluid loss to well 33 bbls. Total . loss to well 3249 bbls.) 3.50 WELLS TRIP ¡WRKOVR POH to 2964'. Clean magnet and junk basket. 1.00 RIGMNT RSRV IWRKOVR Service rig and top drive. , Printed: 12/16/2005 11:23:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2005 11/13/2005 e Page 8 of 14 ConocoPhillips Alaska Operations Summary Report BRU 214-26 BRU 214-26 WORKOVER/RECOMP Kuukpik 5 ! Sub From - To Hours. Code I Code ~::~~ ~ ~~:~~ . ~:~;] ~~~~~~ ~~~ 07:00 - 12:00 5.00 WELLS ! CIRC 12:00 - 16:30 16:30 - 17:00 17:00 - 21 :30 21 :30 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 06:00 06:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 14:30 14:30 - 23:00 23:00 - 23:30 23:30 - 00:00 11/14/2005 00:00 - 08:45 08:45 - 09:00 09:00 - 09:30 11/15/2005 09:30 - 15:00 15:00 - 15:30 15:30 - 15:45 15:45-17:15 17:15 - 17:30 17:30 - 18:30 18:30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 04:30 04:30 - 06:00 06:00 - 09:30 09:30 - 11 :30 11 :30 - 18:00 11/16/2005 00:00 - 10:30 18:00 - 00:00 Phase WRKOVR WRKOVR WRKOVR 4.50 WELLS CIRC WRKOVR 0.50 WELLS SFTY WRKOVR 4.50 WELLS AWSH WRKOVR 2.50 WELLSR CIRC 1.00 WELLSR OTHR 1.50 WELLS . CIRC 0.50 WELLS RURD 3.00 WELLS TRIP 1.50 WELLS PULD 2.00 WELLS TRIP 1.00 WELLS PULD 4.00 CMPL TN PULD 8.50 CMPL TN TRIP 0.50 CMPL TN, SFTY 0.50 LOG ! RURD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 8.75 LOG i ELOG WRKOVR 0.25 LOG ,RURD WRKOVR 0.50 CMPL TNI PCKR WRKOVR 5.50 CMPL TN TRIP 0.50 CMPL TN PULD 0.25 LOG RURD 1.50 LOG ELOG 0.25 LOG RURD 1.00 CMPL TN PULD 4.00 CMPL TN TRIP 0.50 CMPL TN OTHR 1.00 CMPL TN OTHR 1.00 CMPL TN! OTHR 0.50 CMPL TN¡' OTHR 3.00 CMPL TN OTHR 1.50 CMPL TN OTHR 3.50 CMPL TN OTHR 2.00 CMPL TN OTHR 6.50 CMPL TN OTHR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 6.00 CMPL TN OTHR WRKOVR 10.50 WAITON EQIP WRKOVR I Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 Description of Operations ,...,.~~....~..._.__..._- ...-----....---.------- RIH to 6020'. PJSM on pumping caustic pill. Pump 75 bbls of caustic SL wash pill. Displaced pill with filtered 8.6 kcl brine at 8 bpm. Rotate and reciprocate pipe. Dumped caustic pill and 125 bbls brine when returns at surface. Continue circ at 8 bpm. Max NTU after pill to surface 1000. Circ until NTU's >20. Circ. & run thru filter press to get NTU,s down (NTU 10 in 14 out) PJSM on acid wash. Pump 10 bbl. Xanvis hi vis pill (2.25 Ibs/bbl.) 6.3 bbls.of 9.3 ppg NaCI brine containing 2 drums of CE-101 & 500 gals. of 15% HCI Acid wI inhibitor & 7 Ibs citric acid. Followed wI clean brine @ 1/2 bpm to mill. Reverse out @ 2 bpm & discard to slop tank. Circ. complete circ. checking to varify NTU,s still under 20. Clean filter press. Circ well with filtered brine. NTU - 10 RD circulating lines. POH to 2964'. LD magnet, scraper and brush assembly. POH to lower assembly. LD magnet, scraper and brush assembly. Pick up & make up sump packer assembly. RIH wI sump packer on 41/2" DP (SLOW) Filling pipe every stand. PJSM Rig up schlumberger for correlation of packer setting depth. (Daily fluid loss to well 154 bbls. Total fluid loss to well 3461 bbls.) Correlate pkr setting depth to OH logs. Rig down Schlumberger. Pressure DP to 1800 psi to set Baker 194-60 "F" pkr at 5926' ( DPM). Pull test pkr. OK. Pull 40k above wt to test pkr. OK. Rotate pipe to release setting tool. POH w/4 1/2" DP. LD Baker setting tool assembly. RU Schlumberger wire line. RIH wI GR correlatiion log to top of pkr at 5921' (WLM). POH. RD Schlumberger wire line. MU Baker model SB plug assembly. RIH w/4 1/2" DP to pkr at 5926' (DPM). Latch plug. Shear plug up w/14k over wt. Spot 7.7 gals 20/40 carbolite in drill pipe. POH w/2 stds DP. Rotate and reciprocate pipe while letting sand fall. FL last 24 hrs - 27 bbls. Total for well - 3488 bbls Finish letting sand fall to bottom RIH and tag top of sand at 5926' POOH from 5926' to 2278' Cut drilling line 98' Found broken strands in drilling line. cut an additional 442' Finish POOH Pull wear bushing,set test plug, make up test jt. test annular, top pipe, blinds, bottom pipe, out side kill, inside kill, manual choke, HCR, floor valve, dart valve, choke manifold valves, to 250 low- 3000 psi high OK. test Koomey-OK Monitor well, clean rig, wait on barge with reconfigured casing guns. Daily fluid loss to well = 81 bbl Cum = 3569 bbl Clean rig, make minor repairs, Wait on reconfigured TCP guns Printed: 12/16/2005 11 :23:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ---_.__.~-_._..._..... 11/16/2005 11/17/2005 11/18/2005 11/19/2005 11/20/2005 00:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 10:30 10:30 - 12:30 12:30 - 14:00 14:00 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 12:30 12:30 - 16:00 16:00 - 21 :00 21 :00 - 00:00 00:00 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 17:00 17:00 - 17:30 17:30 - 19:30 19:30 - 22:30 22:30 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 13:00 13:00 - 15:30 15:30 - 19:30 19:30 - 20:00 e Page 9 of 14 ...... '.. ConocoPhillips Alaska ·»Operations Summary Report BRU 214-26 BRU 214-26 WORKOVER/RECOMP Kuukpik 5 4.50 CMPL TN PERF WRKOVR 0.50 CMPL TN PERF WRKOVR 1.00 CMPL TN PERF WRKOVR 1.50 CMPL TN PERF WRKOVR i , , 1 i 3.00 CMPL TN PERF 2.00 CMPL TN! PERF I 1 1.50 CMPL TN! TRIP 3.50 CMPLTNiTRIP 1.00 CMPL TN OBSV 1.50 CMPL TN PULD 4.00 CMPL TN PULD 6.00 CMPL TN PERF 1.00 CMPL TN PERF 1.00 CMPL TN TRIP 4.50 CMPL TN TRIP 3.50 CMPL TN CIRC 5.00 CMPL TN TRIP 3.00 CMPL TN! TRIP 3.50 CMPL TN TRIP 0.50 I CMPL TN FCO I 1.50 I CMPL TN CIRC 5.00 CMPL TN TRIP 1.50 CMPLTN TRIP 1.00 CMPLTN TRIP 4.00 CMPL TN! TRIP 0.50 CMPL TNI OTHR 2.00 CMPL TN¡ CIRC 3.00 CMPL TN' TRIP 1.50! CMPL TN OTHR 5.00 I CMPL TN TRIP 1.00 CMPL TN OTHR 2.00 CMPL TN CIRC 5.00 CMPL TN TRIP 2.50 CMPL TN OTHR 4.00 CMPL TN TRIP 0.50 CMPL TN! OTHR I I WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: , Sub From - To ! Hours Code Code. Phase m[1 ~:;~~1 ~:~~ 0.50 ~MP~TNI SFT~ WRKOVR 11 :00 - 12:00 1.00 CMPL TNi PERF WRKOVR 12:00 - 22:00 10.00 CMPLTN PERF WRKOVR 22:00 - 00:00 2.00 CMPL TN PERF WRKOVR 10/24/2005 12/2/2005 Description of Operations . ..... .__..._u_....._. ... Hold PJSM for gun handling and running Re-spot gun trailers, load pipe rack, Prep to run TCP guns RIH picking up 7" TCP perf guns and 4-5/8" spacers PU 6-min. firing head, jars, Champ packer and XO/s (fluid loss today 77 bbl Cum loss = 3646 bbls) RIH wI TCP guns on DP from 2725 to 5862 Change bails and elevators, PU safety valve, head pin, circ hose and bubble hose Tag top of sand 56' in on stand # 52 @ 5914 DP measure.PU 10' to place pottom shot @5914' DP MD = 5909' wlm. UP WT = 105k, DN WT = 82k turn pipe 4 truns, set down 40K # and set packer @ 3139'. close bag and pressure annulus to 1700 psi and start firing head timer. 4-1/2 min later bring pressure up to 2800 psi and open "below packer vent". bleed off pressure. At 6.0 min. guns fire. with visible movement and noise. Press annulus to 500 psi and PU on tubing until packer sleeve opens Open bag and release packer, LD single. Pull from 5 914 to 5831' monitor well for losses. losses fluctuating between 61 and 112 bblslhr. Pump 20 bbls HEC pill down DP chase wI 50 bbls brine and place pill in annulus. Shut Dn let pill fall and monitor losses. Decreased to 18 BPH. POH f/5831 to 5670-monitor well on trip tank-losses @ 18 bph. POH fl 5670 to 2845. Monitor well on trip tank @ packer assembly. Trapped gas from guns encountered. Lay down packer assembly. Hold PJSM-Iaying down perf guns.( Very little trapped gas in guns.) POOH slowly wI perf guns letting gas vent. Clear floor of Halliburton equipment PU flat btm mill, 2 j-bskts, magnet, scraper brush RIH WI scraper assembly-tag fill @ 5913' CBU @ 6 bpm-flow increase fl 29% to 50%-shut annular preventer & circ. thru gas buster @ 3 bpm. Open annular & circ. @ 8 bpm to bring down ntu,s to 20. POH & lay down scraper assembly-clean junk baskets. (no recovery) Make up cavins bailer assembly & rih to 2100'. RIH from 2100 to 5915 bail 5915 to 5918 up wt = 82K, dn wt =64k Circ BU POOH from 5918' RD bailer and empty sand MU bailer assembly RIH to 5918' Tag top of fill @5918' bail from 5918 to 5920 CBU @ 6 bpm, monitor well on trip tank, losses approx 8 bph Pooh from 5920 to 720' Break out bailer BHA and redress Finish moving bailer down 3 stds, and RIH to 5920' Bail from 5920 to 5923' Up wt 82, Dn wt 66 Circ BU POOH from 5923 Lay down bailer & redress same. RIH wI redressed cavins bailer to 5923. Work wI bailer attempting to recover packer plug. (had some overpull Printed: 12/1612005 11:23:52AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date From - To 11/20/2005 19:30 - 20:00 20:00 - 23:30 23:30 - 00:00 11/21/2005 00:00 - 04:30 04:30 - 06:00 06:00 - 10:00 10:00 - 11 :00 11 :00 - 12:30 12:30 - 16:30 16:30 - 19:30 19:30 - 23:00 23:00 - 00:00 11/22/2005 00:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 14:00 14:00 - 16:00 16:00 - 19:30 19:30 - 00:00 11/23/2005 00:00 -11:30 11 :30 - 13:00 13:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 11/24/2005 00:00 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 12:30 12:30 - 14:30 14:30 - 17:30 e ConocoPhillips Alaska Operations Summary Report Page 10 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Sta rt: Rig Release: Rig Number: Kuukpik 5 Hours I Code! Sub : Phase i : Code i .. ~:~~ Ig~:~ ~~I ~~~R I ~=~~~~·~~~~~~~~~~~~~~;~~~~~~~d~oW~a~e ~~g.) .. ... . ....... 0.50 CMPLTN TRIP !WRKOVR POH from 5926 to 4650. (Fluid loss to well last 24 hrs.=156 bbls. total loss to well=4949 bbls.) 4.50 CMPL TN TRIP WRKOVR POOH from 4100' 1.50 CMPL TN TRIP i WRKOVR Empty bailer +1- 50' and layout, clear floor 4.00 CMPL TN OTHR I WRKOVR Test annular, top pipe, blinds, bottom pipe, outside kill, inside kill,manual chk, HCR, Chk manifold valves, floor valves, dart valve, manuallBOP, Hyd IBOP, all to 250 psi 10 and 3000 psi high, hold all 5 min. Pull test plug set wear ring, RIDS, LD test jt. Hook up fill line to flow nipple. PU OS, boot bskt, bump sub, circ sub. RIH to 5925'. Tag plug @ 5925. Latch on wI overshot & attempt to pull plug. Pulled 90k over string wt. could not pull plug-Attempt to rotate out plug-rotated off grapple. Circ. @ 8 bpm while fishing. 3.50 CMPL TN TRIP WRKOVR POH wI fishing assembly. 1.00 CMPL TN PULD WRKOVR Break out bha, clean junk basket-recovered full basket of perforation I debri. (Daily fluid loss to well 144 bbls. Total fluid loss to well 5093 bbls.) Make up fishing bha & RIH to 5923'. Latch onto packer plug-pump @ 16 bpm-jarring on fish-fish came loose. Circulate-filter brine. NTU,s 55. POH-Iay down overshot-jars & fish. RIH wI DC,s & DP to 2518. PJSM-Lay down 8 DC,s & 74 jts. 4 1/2" DP. PJSM-Rig up & running screens. (Daily fluid loss to well=179 bbls. Total loss to well=5272 bbls.) PU and RIH wI screens clear floor, change tools, prep to run 4" wash pipe Run 4" inner string. Rig up & test 4" inner string to 4500# OK. Rig up & run 2 7/8" inner string to lift #22. (Daily fluid loss to well=154 bbls. Total fluid loss to well=5428 bbls.) finish running 2-7/8' inner string, land and space out to test test 2/7/8" concentric string to 4500 psi hold for 5 min OK PU packer and attempt to make up 3 pin connection. Collar on top joint of 5-1/2" pulled half way through screen plate pinching pin on packer. Close vari-bore rams, attempt to get slips under false table. No-go, rig up trip tank to annulus, fabricate "C" plate and set on top of flow nipple and install collar clamp. remove screen table and drive in rotary slips, install dog collar .Held safety mtg to decide how to remove damaged 5-1/2" blank could not back out packer. spread screen plate wI porta power and drive off coupling. split coupling off 5-1/2". RU screen table and bowl and get off 4" and 2-7/8" LD packer. Note: Tube is pinched on 5-1/2" and needs to be changed out. won't drift. 2.00 CMPL TN OTHR WRKOVR Pull 2 jts of 2-7/8 + pups and make break Run back in and back off above jt # 68 POOH LD jts and pups. leave 68 jts inside 4" string. 3.00 CMPL TN: OTHR WRKOVR PU 5-1/2" pup upside down and strip over 4" and MU on 5-1/2". Back off tub and leave collar. Screw in pup on top of 4" and set 4 " on 5-1/2". Pull 1 jt of 5-1/2- 4" and set slips, PU 4", back off 5-1/2", set screen Description of Operations , i 1.00 CMPL TNI OTHR I WRKOVR I i 1.50 CMPL TN! PULD 4.00 CMPL TN1 TRIP 3.00 CMPL TN PCKR WRKOVR WRKOVR WRKOVR 6.00 CMPL TN TRIP 1.00 CMPL TN OTHR 1.00 CMPL TN: CIRC 6.00 CMPLTNiTRIP 2.00 CMPLTN!TRIP 3.50 CMPL TN! PULD 4.50 CMPL TNI SCRN WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 11.50 CMPL TN SCRN 1.50 CMPL TN TRIP 7.50 CMPL TN PULD 1.00 CMPL TN DEQT 2.50 CMPL TN PULD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 4.00 CMPL TN TRIP 0.50 CMPL TN OTHR 1.50 CMPL TN. TRIP 6.50 CMPL TN: OTHR WRKOVR WRKOVR WRKOVR WRKOVR Printed. 12/16/2005 1123.52AM e ConocoPhillipsAlaska Operations Summary Report Page 11 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BRU 214-26 BRU 214-26 WORKOVER/RECOMP Start: Rig Release: Rig Number: 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Date Kuukpik 5 . Sub; From - To Hours Code Code' 14:30 - 17:30 3.00 CMPL TNr~THR 17:30 - 19:00 1.50 CMPL TNi OTHR 19:00 - 20:30 1.50 CMPL TN OTHR 20:30 - 21 :00 0.50 CMPL TN OTHR 21 :00 - 23:00 2.00 CMPL TN TRIP 23:00 - 00:00 1.00 CMPL TN OTHR Phase Description of Operations 11/25/2005 00:00 - 04:00 04:00 - 05:00 05:00 - 09:00 09:00 - 10:30 4.00 CMPL TN TRIP 1.00 CMPL TN TRIP 4.00 CMPL TN TRIP 1.50 CMPL TN OTHR WRKOVR I table break of 4" and layout. WRKOVR Strip new jt of 5-1/2" over 4" and PU. MU 4", MU 5-1/2" and RIH 1Jt. WRKOVR I PU 2-7/S and RIH screw into 2-7/S", PU make up and run back in. WRKOVR I MU test plug on2-7/S" and test 4" to 4500 psi 5 min. OK WRKOVR I PU and MU tripple string packer WRKOVR shut annular and pump down back side wI charge pump and flow thru DP. test down DP to 225 psi for 5 min OK Slowly RIH wI screens & packer to 5901' Add bail extensions, change elevators, MU head pin RU BJ equipment on floor Set packer at 2939, pressure up to 1500,2800 and 3100, test annulus to 2S00 psi WRKOVR WRKOVR WRKOVR WRKOVR 11/24/2005 10:30 - 11 :30 1.00 CMPLTNloTHR WRKOVR Release packer, rotate 15 turns, Up wt 104 Dn wt 77 11 :30 - 12:00 0.50 CMPL TNi OTHR WRKOVR set lower iso packer @ 5055, pressure to 3000 psi. OK 12:00 - 13:00 I 1.00 CMPL TNloTHR WRKOVR Close annular pump down backside to verify reverse position. 13:00 - 16:00 3.00 CMPLTN!AWSH WRKOVR PJSM-Pump acid pickle @ .5 bpm 7.7 bbl. vis sweep-12 bbl. acid-S.5 bbl. h20-11 bbl. brine to chase. 16:00 - 19:00 3.00 CMPLTNiAWSH WRKOVR Reverse out acid pickle @ .5 bpm until brine to surface. reverse @ S I . bpm until ntu,s @ 35. 19:00 - 22:30 3.50 CMPL TNi SEQT WRKOVR PJSM-Flush surface hard lines-pressure test lines & 4" tbg. 4500# I close off tbg. & attempt to test hard lines to 7500#-Attempt to find leaks. (Daily loss to hole 426 bbls. Total loss to hole 6013 bbls.) 22:30 - 00:00 1.50 CMPL TN SEQT WRKOVR Hard Line want test - Chasing leak. 11/26/2005 00:00 - 03:00 3.00 CMPL TN SEQT WRKOVR Continue chasing leak. 03:00 - 03:30 0.50 CMPL TN SFTY WRKOVR Hold pre-job safety meeting. 03:30 - 04:00 0.50 CMPL TN GRVL WRKOVR pressure down annulus to 3K to arm hyd locator, set dn 25 on locator. 04:00 - 05:30 1.50 CMPL TN GRVL WRKOVR Gravel pack first zone wI 31,000 # 05:30 - 07:00 1.50 CMPL TN GRVL WRKOVR Reverse out at 4 bpm wI 2300 psi to clean up 07:00 - 09:30 2.50 CMPL TNI GRVL WRKOVR POOH 12 stds. PU 15' and 5' pup 09:30 - 10:30 1.00 CMPL TNi GRVL WRKOVR set locator lower middle iso packer @ 4319' i 10:30 - 11 :00 0.50 CMPL TN! GRVL WRKOVR RU BJ 11:00 -11:30 0.50 CMPL TN GRVL WRKOVR Big valve on floor leaking, change rubber, thaw lines, remove silo from system 11:30-15:00 3.50 CMPL TN SEQT WRKOVR Rigging up BJ=PJSM=Test surface lines to 7500#=set pop offs=Find seal positions 15:00 - 1S:00 3.00 CMPL TN SEQT WRKOVR Hard line want test - Chase leak. 1S:00 - 1S:30 0.50 CMPL TN GRVL WRKOVR Obtain injection rates & gravel pack. 1S:30 - 20:00 1.50 CMPL TNI CIRC WRKOVR Reverse out sand @ 4 bpm 2400#. 20:00 - 21 :30 1.50 CMPL TN; PULD WRKOVR Pull 10 stands dp-Iocate & space out. 21 :30 - 23:00 1.50 CMPL TN PCKR WRKOVR Set ISO packer #3 wI 31 OO#-verify packer is set-locate reverse position. 23:00 - 00:00 1.00 CMPLTNiCIRC WRKOVR Rig up & flush lines. (Daily fluid loss to hole-1251 bbls.-Total fluid loss to hole-7264 bbls.) 11/27/2005 00:00 - 04:00 4.00 CMPL TN DEQT WRKOVR Attempt to test baker mz tool-trouble shoot leaks in BJ equipment. 04:00 - 05:00 1.00 CMPL TN GRVL WRKOVR Perform gravel pack #3. 05:00 - 06:00 1.00 CMPL TN CIRC WRKOVR Reverse out sand @ 4 BPM 23S0#. 06:00 - OS:OO 2.00 CMPL TN TRIP WRKOVR POH 12 stands-Losses @ 200 BPH. OS:OO - 12:00 4.00 CMPL TN GRVL WRKOVR Rig up BJ for #4 gravel pack-lines froze up Temp -10 deg. (Daily fluid loss to well=1SS1bbls. Total loss to well=9145 bbls.) 12:00 - 00:00 12.00 CMPLTN GRVL WRKOVR Thaw lines, repair leaks, test 11/2S/2005 00:00 - 02:00 2.00 CMPL TN GRVL WRKOVR finish RU and thawing out BJ lines. 02:00 - 02:30 0.50 CMPL TN! GRVL WRKOVR Pump gravel pack # 4 top zone. Printed: 12/16/2005 11:23:52AM e ConocoPhillips Alaska Operations Summary Report Page 12 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BRU 214-26 BRU 214-26 WORKOVER/RECOMP Start: Rig Release: Rig Number: 10/24/2005 12/2/2005 Spud Date: 10/29/2005 End: Group: Date Kuukpik 5 : I, ! Sub From - To : Hours I Code i Code Phase :;;:: : :;~ u:~g~~t ~ g~~ I ~~~~~~ 03:30 - 06:00 2.50! CMPL TN TRIP I WRKOVR 06:00 - 07:00 1.00 CMPL TN OBSV i WRKOVR Description of Operations ----.-.-------....--...-------.-- 11/28/2005 Reverse out wI rig at 4 bpm @ 2100 psi Fill hole loss rate = 279 BPH Pooh from 3800 to 3153' Loss rate = 192 BPH Fill hole losses 200 BPH 07:00 - 07:30 0.50 CMPL TN CIRC WRKOVR RU circ long way dn 2-7/8" at 4 bpm at 236 psi. 07:30 - 08:30 1.00 CMPL TN OBSV WRKOVR Fill hole Loss Rate = 200 BPH 08:30 - 09:00 0.50 CMPL TN TRIP WRKOVR POOH from 3153' to 3061' 09:00 - 10:00 1.00 CMPL TN OBSV WRKOVR Fill hole Loss rate 225 BPH 10:00 - 10:30 0.50 CMPL TN OTHR WRKOVR Close annular, install TIW and close. POOH to 3030 to close KOIV 10:30 - 14:30 4.00 CMPL TNi OTHR WRKOVR Monitor losses while RD BJ. Loss rate = 5 BPH Rig up GBR tongs. 14:30 -15:30 1.00 CMPL TN! OTHR WRKOVR Lay down packer. 15:30 - 00:00 8.50 CMPL TN] PULD WRKOVR Rig up & lay down 2 7/8" tbg. & 4" work string. (Daily fluid loss to hole 2178 bbls. Total loss to hole-11323 bbls.) 11/29/2005 00:00 - 02:00 2.00 CMPL TN PULD WRKOVR POH LD 4" innerstring. 02:00 - 03:00 1.00 CMPL TN RURD WRKOVR Clear floor. Remove long bails. RU hydraulic elevators. 03:00 - 05:00 2.00 CMPL TN TRIP WRKOVR RIH w/4 1/2" DP to 1890'. 05:00 - 05:30 0.50 RIGMNT RSRV WRKOVR Service rig. 05:30 - 08:00 2.50 CMPL TN PULD WRKOVR POH LD 41/2" DP. 08:00 - 10:00 2.00 CMPL TN TRIP WRKOVR RIH w/4 1/2" DP to 1928'. 10:00 - 13:30 3.50 CMPL TN PULD WRKOVR POH LD 41/2" DP. 13:30 - 16:00 2.50 CMPL TN RURD WRKOVR Clear floor. Pull wear bushing. RU to run 5 1/2" completion equipment. 16:00 - 23:30 7.50 CMPLTN RUNT WRKOVR Running 5 1/2" 15.50# completion string wI PBR-sliding sleeve & SSSV. 23:30 - 00:00 0.50 CMPL TN PULD WRKOVR POH 9 Jts. 51/2" tbg. 1/4" control line was approx. 150' short. (500' was marked on spool-had approx. 350'.) (0 Fluid loss to well. 11323 bbls. total fluid loss to well) 11/30/2005 00:00 - 01 :00 1.00 CMPL TN PULD WRKOVR LD SSSV. 01 :00 - 01 :30 0.50 CMPL TN RUNT WRKOVR RIH wI 3 jts of 5 1/2" tbg. 01 :30 - 02:00 0.50 CMPL TN PULD WRKOVR MU SSSV. Attach control line and test to 5000 psi. 02:00 - 03: 15 1.25 CMPL TN RUNT WRKOVR RIH w/5 1/2" tbg. Sting into pkr. 03:15 - 03:30 0.25 CMPL TN DEQT WRKOVR Test annulus to 1500 psi. OK. Sheared PBR 30k over string wt. 03:30 - 04:30 1.00 CMPL TN PULD WRKOVR Space out tbg. MU hanger and landing jt. 04:30 - 06:00 1.50 CMPL TN RURD WRKOVR MU control line through hanger. RU reverse lines. 06:00 - 07:00 1.00 CMPL TNI OTHR WRKOVR Break circ with charge pump. Locate top of PBR with seal assembly. , OK. 07:00 - 08:00 1.00 CMPL TN' CIRC WRKOVR Reverse circ 131 bbls pkr fluid/corrosion inhibitor and 5 bbls diesel. 08:00 - 09:00 1.00 CMPL TN OTHR WRKOVR Land tbg. RILDS. 09:00 - 10:00 1.00 CMPL TN DEQT WRKOVR Pressure annulus to 1100 psi. Fluid leaking by hanger. Pressure bled off to 600 psi and held. Bleed off pressure to O. Re-torque LDS. Pressure annulus. Hanger still leaking. Pull hanger to floor. Seals OK. 10:00 - 12:00 2.00 CMPL TN DEQT WRKOVR Reland tbg. Check cheater mark on tbg through annulus valve. OK. Pull 1 LDS to check location of top of hanger. OK. 12:00 - 12:30 0.50 CMPL TN DEQT WRKOVR Pull hanger to rig floor. Order new hanger from FMC. 12:30 - 13:00 0.50 CMPL TN OTHR WRKOVR Lubricate & full service to rig. 13:00 - 00:00 11.00 CMPL TN DEQT WRKOVR New hanger comming out on barge. Assist in rigging down partial swaco-prepare rig for rig move. Loading trailers for barge. Expect barge @ 0600 Fri. (no down hole losses. Total losses to hole 11323 bbls.) 12/1/2005 00:00 - 06:00 6.00 WAlTON EQIP WRKOVR Wait on barge with new hanger. Load trailers for barge. Clean location. 06:00 - 09:00 3.00 CMPL TN OTHR WRKOVR Refmove control line. Back out hanger from pup jt. MU new hanger. Insert control line and test to 5000 psi. 09:00 - 09:30 0.50 CMPL TN OTHR WRKOVR land tbg. RILDS. Pressure annulus to 1200 psi. Hanger seals blew. 09:30 - 10:00 0.50 CMPL TNj OTHR WRKOVR Pull hanger to rig floor to change seals. No LDS marks on new hanger I I Printed: 12/16/2005 11:23:52 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: BRU 214-26 Common Well Name: BRU 214-26 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Kuukpik 5 Date ¡ From - To. Hours I Code i ¿>ouJe. Phase .. . . .......... ......... m_____.____~..._..._......___._._.__...._. 12/1/2005 ['09:30 -10:00 10:00 - 12:00 12:00 - 13:30 13:30 - 17:30 17:30 - 1S:00 1S:00 - 1S:30 1S:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 12/2/2005 00:00 - 05:00 05:00 - 06:00 06:00 - 12:00 12:00 - 00:00 12/3/2005 00:00 - 12:00 12:00 - 00:00 12/4/2005 00:00 - 12:00 junk ring. Land hanger. Remove LDS. measure LDS and well head flange. LDS not engaging hanger. pull hanger to rig floor. Remove 1/S" spacer ring from hanger. Monitor well on trip tank. Order LDS thread tap and new LDS from town. WRKOVR I Wait on lock down screwws-Ioad trailers & prep for rig move. WRKOVR . Land hanger-remove old LDS-chase threads & replace wI new LDS. WRKOVR Test hanger 3000# 30 mins. chart same OK. WRKOVR Pull landing jt. & set back pressure valve. WRKOVR Clear floor-remove elevators-pull mouse hole & rotary table. WRKOVR I Remove flowline-riser-bop chains"choke & kill lines. WRKOVR II Remove koomey lines-pull all rams-flush & grease stack,rams & doors. WRKOVR Break all bolts on stack & begin nippling down bop stack. Fluid loss last 24 hrs - O. i Total fluid loss to well - 11,527 bbls WRKOVR ¡ Remove hoses and valves from cellar. Break apart and remove BOP I components. WRKOVR Set v-door ramp. NU tree adapter and master valve. WRKOVR Torque bolts on master valve. Test tree adapter and hanger to 3000 psi. Test control line to 5000 psi. Pull BPV. Install TWC. Test master valve and tree cap to 5000 psi. Pull TWC. Install BPV. Remove SSV from annulus. Install rotary table. Clean floor and cellar. Secure well. Release rig at 12:00 12-2-05. DMOB DEMOB Drain oil from top drive. Remove saver sub. Disconnect service loop and secure. Roll Koomey lines. Rig down mud tanks. Dress derrick and bridle up. Disconnect and roll up electric cables. Strip #2 pump and winterize. Lay down torque tube. Scope down derrick. Secure top drive and blocks for transport. Prep derrick to layover. Cut 270' drilling line. Strip #1 pump and winterize. Rig down charge pumps and mud ines. DMOB DEMOB Rig down wiring. Prep drawworks for removal. Rig down hydraulic hoses. Secure buildings for removal. Remove upper wind walls. Remove beaver slide and catwalk. Remove front and rear wind walls. Remove ODS and DS buildings. DMOB DEMOB Finish unstacking drill floor modules. Remove shaker possum bellies. Pull handrails and stairs. Roll up hoses and load on trailers. Remove lower wind walls. Set mats and connect hydraulic jacks to derrick. Squat drill floor. Spot derrick trailer. Rig down pump room HPU's and boilers. Held PJSM for layover derrick. Lay down derrick. DMOB DEMOB Un-pin derrick. Remove drawworks and extensions. Remove choke and koomey module. Remove white iron from sub and pull sub off well. Remove sub mats. Set mats over cellar. NU tree and test to 5000 psi against lower master valve. (tree adapter and lower master valve test prior to rig down). Pull BPV. Secure well. DEMOB Rig down power modules and load trailers. Install cellar grates. Set well house with crane. Load trailers. DEMOB Load mats with small items and band down. Blow down camp unit. Clean location. Move derrick to barge landing. DEMOB Load remaining trailers. Clean location. No barge due to mechanical problems. Pollard did not arrive in Beluga due to weather. DEMOB Clean location. Remove snow. Stand by for barge. RU Pollard. Pressure lubricator to 2750 psi. Open SSSV. SITP - O. RIH to KOIV at 3029'. Pressure tbg to 500 psi. Break KOIV. Well on vacuum. POH. Shut well in for night. -______0. _. _..._. 0.50 CMPL TN I OTHR WRKOVR 2.00 CMPL TN OTHR WRKOVR 1.50 CMPL TN! OTHR 4.00' CMPL TN! OTHR 0.50 CMPL TN: DEQT 0.50 CMPL TN! OTHR 1.50 CMPL TN! NUND 1.50 CMPL TN! NUND 1.50 CMPLTN!NUND 1.00 CMPL TNI NUND I 5.00 I CMPL TN NUND 1.00 CMPL TN! NUND 6.00 CMPL TN SEQT 12.00 MOVE 12.00 MOVE 12.00 MOVE I I i 12.00 MOVE 12:00 - 00:00 12.00 MOVE .DMOB I I 12/5/2005 00:00 - 00:00 24.00 MOVE DMOB 12/6/2005 00:00 - 00:00 24.00 MOVE DMOB 12/7/2005 00:00 - 00:00 24.00 MOVE DMOB Page 13 of 14 Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 Description of Operations .. ............----....-..----..------..--.-..--.- .. Printed: 12/1612005 11:23:52 AM e ConocoPhillips Alaska Operations Summary Report Page 14 of 14 BRU 214-26 BRU 214-26 WORKOVER/RECOMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Kuukpik 5 Date From - To : Hours j Code . ..--------l...·..······· .. ...-.~.-...----_.---................. 12/8/2005 00:00 - 00:00 24.00 I MOVE i I 12/9/2005 00:00 - 00:00 24.00 MOVE 12/10/2005 00:00 - 00:00 24.00 MOVE 12/11/2005 00:00 - 00:00 24.00 MOVE 12/12/2005 00:00 - 00:00 24.00 MOVE 12/13/2005 00:00 - 04:00 4.00 MOVE Start: Rig Release: Rig Number: Spud Date: 10/29/2005 End: Group: 10/24/2005 12/2/2005 Sub Code Phase i ..... _......____ ____1.___.___.__._........_....._.................... ...... _. .. ........_..___.. . _._......__.._ DMOB DEMOB I Stand by for barge. Barge should arrive in the afteroon of 12-9-05. Pollard bailed fill from top of PXN plug. (Carbolite and KOIV flapper . pieces). SITP - 840 psi. DMOB DEMOB Load out the Helenka B with 6 trailer loads of rig components and 1 vehicle. Pollard attempted to pull PXN plug from well 214-26 with no success. DMOB DEMOB Load out 2 barge loads of rig components and misc equipment. Est' 2 more loads with the Helenka Band 1 load with the Redoubt to complete demob. DMOB DEMOB Load out 2 barge loads of rig components, crane, tanks, etc. Estimate 1 more load with the Helenka Band 1 load with the Redoubt to complete demob. DMOB DEMOB Load out 2 barge loads of rig components, tanks, swaco equipment, pickup trucks, etc. 1 final load with tthe Helenka B will complete demob operations. DMOB DEMOB Load out final barge with sewage truck (4100 gal) and misc. equipment. Demob complete. Description of Operations· . Printed: 12/16/2005 11:23:52 AM · . eonocÓPhillips TRANSMITTAL Production Data FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Librarian/Data Control AOGCC 333W. ih Avenue Anchorage, Alaska 99501 RE: BRU 214-26 DATE: 12/08/05 Hand delivered Transmitted: ¡qo- 0-4 ~ Beluga River Unit BRU 214-26 Hardcopy Color loa print _ Ultrasonic Imaging Tool, 11/10/2005, run 1 2796-6000' md _ Reservoir Saturation Tool, RST/PBMS 11/10/2005, run 1 2865-6017' md Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska designated AOGCC release date. Proprietary data may be indefinitely confidential. ogist Date: J '/1 ß/05 ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Sl'~Ní\It::r; ¡ i\ ~i '7 1 ~_:.,\:J", 0'>- ~;__- ..~:.c-' \.-),--,j ',~ .1.. d~ GIS-Technical Data Management I ConocoPhillips I Anchorage/ Alaska I Ph: 907.265.6947 I Sandra. D. Lem,ke(âJconocolJhillilJs. com Re: BOP test KUUKPIK 5 ') ) ~~J>âê~t::~~:BqPtrs~~~Il5? .............. ............ .........< .. .......... ....... ..... ............. ~..·...r......:.~I\1:Tl1orn~s~ªµo;dêr<t9A1...:1tlaµnd¢~@a~~n.stªt~;(\~;~~?-.·.:·.····:· ,-:." :.:......:.."." ". .": .," . . :". ". .," .".:. .. .. .... ... ." .....;..: .... ........ .... ..... Ð~~e:Thll~ ·2/10212005 J p:Ö8:C31ëOSQO . Paul, \3> Q-\ '-' S ~ d- \ L\ - d Co \ ~ 0 - é) L-\ ::L. Looks like you got my eddress. As I remember, this proposed procedure is similar to what was necessary on the well you have just finished. Based on what you related in our call, I don't believe you have another option with the hanger leaking. Your proposal is acceptable. Keep us infonned as to your progress/outcome. Tom Maunder, PE AOGCC Beluga River Company Man wrote, On 10/27/2005 11:38 AM: Tom.. Based on our last test of the tubing hanger void it appears the tubing hanger is leaking. We would like to propose the following procedure for the initial BOP test. · Attempt to pressure test under the blind rams to 1000 psi. which is a pressure greater than the shut in tubing pressure ( sitp = 700 psi). If it holds we will continue the BOP test using 1000 psi as the test pressure. · If it won't hold 1000 psi., we will check all connections below the rams to confirm there are no leaks. Then run our 1.9" test joint and close the top rams and test on top of the blind rams. Last time we successfully tested to 1000 psi. Then test the Hydril to 1000 psi. · We will test the choke manifold and other components to 3000 psi. · As soon as the hanger is removed and we can get a test plug in the hole we will test the system to 3000 psi. If this meets your approval contact Paul Mazzolini at 263-4603 Thanks... SCANNED NO\f 0 8 2005 1 of 1 10/31/2005 7:48 AM RE: 7-5/8" Wash Pipe ) ) s?'je¢t:~.:7-~18"Was~~îþe '. .... ........... ...... .' ............. Jfrqrn:·.··I'CbatUbers~.JYEarkA".«Ma.rk.A;Çhamþ~rš@cQnQcôpl#~1ipš~cqm> .......... .....:.............. ....... . .. ......... .. .. ......................... .: ........ ............ ...... .. .....: ............ '.. ........ .. .......... : ".., . .:....." ..". .... ....... ..... ".- "..." ,"' . ... . ~~Je:ìv1on,?~Aµg20Q5Q8:06:.5?-q89q....... ......... .......... ~; :si:·~~~.~~I~~~~~§~~~~~I,i Thank you. if\ ~- d-Co \qO-O~~. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, August 22, 2005 7:47 AM To: Chambers, Mark A Cc: Lutrick, Donald C; Mazzolini, Paul Subject: Re: 7-5/8" Wash Pipe Mark, et al.: Your understanding and contingency plans are as we had discussed during the latter part of the week. Good luck with the workovers. Tom Maunder, PE AOGCC Chambers, Mark A wrote, On 8/20/2005 2.:02 PM: SC;Á~~~\!ED J\UG 2 2 2005 Tom: As we discussed, we plan to utilize 7-5/8" wash pipe on the upcoming Beluga Workovers and may be required to PU as much as 400' at one time. We consider this a BHA and do not plan to add 7-5/8" rams to our stack for this event. Our plan is to MU a crossover on the bottom of a stand of drill pipe and stand it back in the derrick. In a well control event we would PU the stand from the derrick, MU the stand to the wash pipe utilizing the crossover and RIH below the BOP. We would then MU the TIW valve. If you have any questions please feel free to contact me at any of the numbers below. Regards, Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc 907-265-1319 Office 907-240-5868 Cell 907-345-8112 Home 1 of 1 8/22/2005 11 :47 AM Re: BRU 212-24 abandon heater string ) ) " . . ..,.. ...... . ... ...... . ..... .... . .... SUJ)J~çt:. Re:BRD 212~24.abándonQ.¢aterstring Ft~;'µ:;.'1'1i9m~s,.' Ma.und¢r"'<::t9tIi___1}ià11l1f1~t®að.rniri.'state. akus> r'~~µé,·~tJt¡¡~~5..0~:;~j.~p·... Good moves. Braden, John C wrote, On 8/16/2005 8:10 AM: ~ ------ \SO-O~d- 224-13 has a John Braden -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.alS~J\l\~NEr\ lUJG 9 ') 20 r Sent: Friday, August 05, 2005 11:02 AM .. I (,~ /.,' - 0,] To: Braden, John C Subject: Re: BRU 212-24 abandon heater string Not a problem. I saw from the proposed workovers that those well will only have llarger tubing string installed. are there SSVs "on" the production strings?? I presume so if you had them on the heater strings. As I noted, there is no regulatory requirement to have SSV s, but operationally I think we both can agree that having them makes sense. Tom Braden, John C wrote, On 8/5/2005 10:53 AM: Yes, the manual valves will still be in service. We are removing (abandoning) all surface piping from the heater string, no changes to the tree or below. I just wanted to double-check. Thanks, John Braden -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Friday, August 05, 2005 9:55 AM To: Braden, John C Subject: Re: BRU 212-24 abandon heater string John, There have not been any rules issued that require SSVs in BRU. What do you mean by "abandoning"?? Are you just removing it from service?? I presume that manual valves will be in place to allow access if needed. Tom Maunder, PE AOGCC Braden, John C wrote, On 8/5/2005 9:46 AM: 10f2 8/22/2005 1: 13 PM Re: BRU 212-24 abandon heater string ) ) Tom- We are abandoning selected heater strings at Beluga River Unit because many wells are below the hydrate point. 212-24 has a surface safety valve attached to the heater string. We are not planning on using it for annular flow. Do we need to notify AOGCC before removing the SSV? Sincerely, John Braden ConocoPhillips Alaska (907) 263-4536 20f2 8/22/2005 1: 13 PM '~lF' 'tÆ-' ~ Ii ¡i;IW I ,I \ 'I ilil ~'~, " : I' ii· \ : !, i,' L" '""'" '\'\~ i! / I '\ : r il r ;®L:L\,uLb ~ f7"'n \ rp ¡ L, ~, :\ S, dU,!' q I" it ~ j L¡ ~~ /"1\ n ¡r;;\¡1ù P/7 !'~ ..in\ ~:I U~ \.\ ~ :'(l ill~l :¡ Lp q ¡ ,u \ \," 'I ! \ 1lJ. 1 ";-¡ '\ ~ ¡ j",....,. \] '\ '~, , ~\\ ,1_ ',I 1.J Ù L..::::J 1.J U t....:::J U u L.J U i I / ¡ I j i j / / FRANK H. MURKOWSKI, GOVERNOR A"~ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini CI Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 tqÞ- D41- Re: Beluga River 214-26 Sundry Number: 305-213 SCANNED ,~UG r p ?OO~ u () ,\_ J,j Dear Mr. Mazzolini: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date ,of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision Superior Court unless rehearing has been requested. -' DATED this~ay of August, 2005 Encl. en &,Z,.~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. CommissiOn Operation Shutdown D Perforate 0 Waiver AnQIillrage Other D Plug Perforations D Perforate New Pool D 1. Type of Request: D D D Suspend D o o Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104.5' Pull Tubing 8. Property Designation: A-029657 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 6448' 6154' 6013' Casing Length Size Conductor 30" Surface Production 13-3/8" 9-5/8" August15,2005 Date: Stimulate D RECEIVe[)~/' ) AUG 0 2 2005 Time Extension D Re-enter Suspended Well D 4. Current Well Class: Development 0 Stratigraphic D 5. Permit to Drill Number: 90-042 ./ 6. API Number: 50-283-20083 ../ 9. Well Name and Number: BRU 214-26 Exploratory D Service D 10. Field/Pool(s): Beluga River Field PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5745' 6050' K-1 retainer @ 6050' MD TVD Burst Collapse 221' 2977' 6442' 221' Perforation Depth TVD (ft): 3192'-3492',3589'·4392',4781'·5554' Packers and SSSV MD (ft) pkrs set @ 3165', 3622' no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil D Gas 0 WAG D GINJ D Perforation Depth MD (ft): 3286'-3598', 3700'-4558', 4978'-5810' Packers and SSSV Type: Baker A 1-5 prk, Baker Model'D' perm. Pkr no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paul Mazzolini Signature 'U.J 11c.r1:'- ' . 2896' 6148' Tubing Size: 1.9" 1 3.5" 1 2·7/8" Tubing Grade: N-80 Tubing MD (ft): 1992'/3240'/5687' Service D Plugged D WINJ D Abandoned D WDSPL D Contact: Mark Chambers @ 265-1319 Title: CI Team Leade¡r Phone: 263-4603 Date bß 0 il 20(')5- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test ~ Other: <.oö~B\~~, ~{ ~O~c....C d Sundry Number: - ?~,s:..¿}-ß Mechanical Integrity Test D Location Clearance D SCJGO 2c.;\ ~\\i""~~"" "\3()'\>-\-c~~ ~c:.\ro',.I,'o ~ ~{)\> ~-\. (:::¡'I.~~Oê ~ ':- '\ ':> "' s ?- Ù~Ç. ~\ \- \:)~ \ ~ ~ð ~\.\~Ss. --\~<:> '-\<t.S~ '\~ ~~:t~~\"\~" RBDMS BFl AUG Q 4 2005 ~' ReDMS 8Ft AUG hFTIiJr9IYED BY COMMISSIONER fH"E ~~MISSION O R \ C""'''' i r I f~ , "'.' ' . . -. ¡, I\! ßj , ....... . \ ,) t \;, b \ ._.. D::bm~~~ ConocoPhillips BRU 214-26 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH through 3-1/21/ Short String and tag TOF. 2. RU Slick Line Unit. RIH through 2-7/81/ long String. Bail fill to top of fish or as deep as possible below Baker Model 'DB' Permanent Packer. Retrieve fish if possible and attempt to verify tubing is parted and at what depth. Note: Depending on results from step #2, a tubing cut may be required in the 2-7/81/ long string below the Baker Model 'DB' Permanent Packer. Tubing cut should be in the top of the first full joint below the packer. 3. Remove flow line, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Workover Rig. 2. load pits with 6% KCl, Filtered, Kill Weight Brine (8.5 PPG). 3. Kill well with 6% KCl Filtered Brine. Ensure well is dead. 4. RU Slick Line Unit. RIH through 3-1/21/ Short String. Close Sliding Sleeve. Set plug in 'XN' Nipple. Plug required for isolation to ND / NU (Unable to set BPV in 1.901/ Heater String) 5. ND tree. NU 13-3/81/, 5M, BOPE with VB rams. Test BOPE. Pull BPV's. 6. PU landing joint. Screw into 1.901/ Heater String. POOH. 6. PU landing joint. Screw into 3-1/21/ Short String. Rotate string out of packer (set for right hand release). POOH. 7. PU landing joint. Screw into 2-7/81/ long String. Release Baker Model 'Al-5' Dual Packer. Shear safety joint located 2 joints below bottom of packer. POOH with the following. long String from Surface to Safety Joint Short String from Packer to Wire Line Entry Guide Baker Model 'Al-5'Packer Assembly 8. RIH with Overshot. latch onto 2-7/81/ Safety Joint. Jar seals free. POOH with the following: Tubing stub from Safety Joint to Seal Assembly 9. RIH with Packer Mill. Mill up Baker Model 'DB' Permanent Packer. 10. RIH with Spear. latch into Baker Model 'DB' Permanent Packer. POOH with the following: Baker Model 'DB' Permanent Packer Tubing stub from packer to tubing part / tubing cut (location TBD) Mark A. Chambers Page 1 7/27/2005 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. RIH with 7-5/8" Wash Pipe and Rolling Dog. Wash over and latch onto tubing stub. POOH. RIH with 8-1/2" Junk Mill and Spiral String Mill. Cleanout to PBTD or as deep as possible. POOH. RIH with clean out BHA (Casing Scrappers, Brushes, Magnets, Junk Baskets, Etc). Pump Acid / Pickle. POOH. RU E-line Unit. RIH and log well as required. RIH with RTTS Tool and test 9-5/8" casing above proposed top Gravel Pack Packer location (+/- 2900' MD). POOH RIH with Baker Model 'FB-1' Sump Packer and Lower Tubing Tail. Log on depth and set Sump Packer. POOH. RIH with TCP Guns and Packer Plug. Set Packer Plug. Perforate as required. POOH. RIH with clean out BHA (Spiral String Mill, Junk Baskets, Etc). POOH. RIH with Bailer. Clean-up debris on top of packer. Pull Packer Plug. POOH RIH with Multi Zone Gravel Pack Completion Equipment (as per attached schematic). Latch into Sump Packer. Perform Gravel Pack as required. POOH RIH with 5-1/2" Completion Assembly (as per attached schematic). Latch into top Baker Model 'SC-1R' Packer. PU and Shear PBR. Space out with tubing pups and land tubing hanger. Pressure test 5-1/2" x 9-5/8" annulus. ND / NU and test. RDMO ~ Mark A. Chambers Page 2 7/27/2005 ~~Ie. Conoc6Phillips BRU 214-26 56.371 Li Li U - '1Gas Producer Annulus Fluid: Gas la 2a Dual + Heater String Max Hole Angle: 23° @ 4,900' 2977'/ J ~Sect. 26, T13N, RI0W, NE 1/4 RKB to Ground: 16.7' 311 g' _b IT 2b sqz ASP @ Beluga: 2,626,531; 319,131 RKB to SL: 104.5' 3175 le ~ X X CASING & TUSING 3232 Id ~c,d _ Description OD Btm. Weiaht Grade Thread 3288 A Surface 13 3/8" 2,977' 68. # K-55 BTC 3344 Prod Casing 9 5/8" 6,443' 43.5 # 5-95 BTC 3401 le B Heat String 1.90" 1,992' 2.9 # N-80 CS Hydril 3457 B Tbg. String 2 3 1/2" 3,240' 9.3 # N-80 CS Hydril 3514 J Tbg. String 1 27/8" 5,687' 6.5 # N-80 BTC 3570 If,g,F 0 :9 Str. Lbl. Top TUSING JEWELRY & FISH Length 3626 Ih r H Heat string has no jewelry and is accessed through casing valve. 3683 li - J 2 a 47' "X" 3.5" Nipple, Otis 1.09' 3739 Ij DID 2 b 3,121' SS-X Sliding Sleeve, Otis "XA", open 7/11/97 4.45' 3795 ___ ~ -ºI 2 c 3,208' "XN" Nipple, Otis 1.25' 3852 '\~. 2 d 3,239' Re-entry guide, Baker 0.60' 3908 D 1 a 48' "X" 27/8" Nipple, Otis 1.22' 3964 1J 1 b 3,120' GLM IGas Lift Mandrel, 1.5" TGPD T-MERLA 9.54' 4021 E 1.5" DV?, Latch BK-2 ?? 40 77 ____!_~_______~!!_~~~______p_~~____º_~9J_P~~~~~~~~ly!_~~~~!_~!:?__________!~.L__________________________ 4134 E 1 d 3,238' Safety Joint, Baker, 51k# shear 2.49' 4190 1 e 3,272' 15 Blast Joints 299.' 4246 !.. 1 f 3,576' GLM, ,lG,as, "L, ift .M, an,dre,l, 1.,'.' FM, ,.H.O. M.C. MUrry, , 6.07' 4303 1" DV, Latch BK-2 ?? 10/18/91 4359 3,580' After Fish left in Hole, could not, bail below 3580' wlm, full sand 4415 F 1 F 3,597' HOLE IN TBG 4472 1 g 3,621' Nipple, Baker SLS 1.00' 4528 F 1 h 3,622' Pkr Permanent Packer, Baker Model"D" 3.95' 3.25" 8.125" :~:~ ----ri-------3~67õï-----GLM---I~~;,~L~~~~~~~~J~~~~~-PD-;:--M~~~;~~----9~Š4i-------------------------- 4697 1 j 3,685' Blast Joints mixed with tubing 1,969.' 4754 3,750' Fish - Bailer, Spangs and Oil Jars, could not work above 4810 1 J 3,997' TUBING PARTED AND AND DROPPED BELO 4866 1 k 5,654' "XN" 2-7/8" Nipple, Otis 1.10' 4923 1 L 5,686' Shear out sub, Baker 2-7/8" 0.58' 4979 _ Pressure Datum: Sterling 3450' SS: 3,664'MD Beluga 4000' SS 5035 G PERFORA TIONS, FILL & PLUGS 5092 Str. ~ TIm Btm. Status Date 5148 Sqz 3,188' 3,192' Sqzd w/ cmt 2x, test to 2000 psi 09/90 5205 2 A 3,286' 3,368' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5261 2 B 3,387' 3,448' 5" Baker TCP wi 22.7gm Deep penetrator 09/90 5317 2 B 3,506' 3,510' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5374 :HJ 2 C 3,536' 3,598' 5" BakerTCP wi 22.7gm Deep Penetrator 09/90 5430 1 D 3,700' 3,850' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5486 1 D 3,934' 3,941' 5" BakerTCP wi 22.7gm Deep Penetrator 09/90 5543 1 E 3,999' 4,006' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5599 :HJ 1 E 4,076' 4,085' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5655 lk,L W 1 E 4,182' 4,188' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5712 1 E 4,268' 4,277' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5768 :HJ 1 F 4,431' 4,436' 5" BakerTCP wi 22.7gm Deep Penetrator 09/90 5825 1 F 4,553' 4,558' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5881 1 G 4,978' 5,043' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5937 >- 1 H 5,392' 5,412' 5" Baker TCP wi 22.7gm Deep Penetrator 09/90 5994 W~ 0::: 1 H 5,586' 5,652' DST #2B, reperf wI 8 SPF 09/90 6050 rtnr -::-::. 0 1 H 5,796' 5,810' DST #2A - NO GAS, Open 09/90 ~~ ~JI-- PBTD 6,013' Baker K-l retainer @ 6050' +5 bbl cmt 09/90 6353 FC - rn H 6,088' 6,100' sqz. DST #1 09/90 6443 ~J: FC 6,353' Float Collar 09/90 TAGS Str 2 4/21/97 3648' WLM bailer Str 1 9/22/90 PBTD rig 07/97 Str 2: Open 55, displace annulus diesel, produce through both tubing and casing valve 08/02 9x13 annulus slow builds pressure since annular flow started. Wellhead packing good. 10104 Ran PDS caliper log and found hole in TBG @ 3597' wlm. 11/04 Wireline attemped to set patch across TBG hole, tight spots, TBG part opening found @ 3997' wlr with remaining parted tubing fallen rvl00 below. Wireline parted while POOH, leaving spangs and bailer fish in hole API# 50-283-20083-00 Spud Date 7/30/90 Last Completion 9/29/90 Schematic Rev. 1/17/05 by JDB Hole Size Cement 17 1/2" 1327sx+50Osx full returns 12 1/4" 2052sx "G" + additives Bump plug w/ 3000psi 2.813" 2.313" 2.75" 2.992" 2.313" ID OD 3.97" 3.25" 4.55" 4.50" 3.25" 2.25" 3.72" 2.44" 3.70" 4,249'MD Net Incline Ft. Anale SPF 4 12 58' 12 18' 12 4' 12 49' 8 48' 8 7' 8 7' 8 9' 8 6' 8 9' 8 5' 8 5' 8 10' 8 20' 12 41' 4 14' 4 17° 17° 15° 15° 18° 20° 20° 20° 20° 21° 21° 22° 23° 22° 21° 21° 20° 20° 8RU 214-26 Proposel ':ompletion Schematic ConocJP'hillips Conductor: 30",310.00#, X-52 @ 221' MD Surface Casing: 13-3/8",68.00#, K-55, BTC @ 2977' MD ~xisting Perfs: Proposetl Perfs: 3286' - 3368' 3387' - 3448' 3506' - 3510' 3536' - 3598' 3247' - 3251' 3286' - 3325' 3353' - 3368' 3387' - 3392' 3419' - 3428' 3435' - 3446' 3506' - 3510' 3536' - 3566' 3579' - 3598' 3700' - 3850' 3934' - 3941' 3999' - 4006' 4076' - 4085' 4182' - 4188' 4268' - 4277' 3667' - 3677' 3700' - 3725' 3764' - 3778' 3846' - 3850' 3924' - 3927' 3934' - 3941' 3999' - 4005' 4076' - 4085' 4106' - 4114' 4183' - 4188' 4268' - 4277' 4280' - 4286' 4431' - 4436' 4553' - 4558' 4978' - 5043' 4431' - 4436' 4517' - 4520' 4526' - 4532' 4552' - 4554' 4980' - 4984' 5039' - 5043' 5392' - 5412' 5586' - 5652' 5796' - 5810' 5393' - 5412' 5586' - 5610' 5636' - 5652' mD.:. Estimated @ 6013' MD Retainer: Set @ 6050' w/ 10 BBLS Cement Below and 5 BBLS Cement Above Estimated TOC (éù 6013' MD Production Casing: 9-5/8",43.50#, S-95, BTC @ 6443' MD (MZ Frac System) ~ .-J ~ ~ I r I æ z ~ i ~ I i.... I Iii ~ I I ~ il 11 g~g ~ Ii ~ Z 1:/1 II ~ II! i! ~ z B I ~ ~ I II i i II II ~ ~ i ~ ~ ~ ~ ~ ~ I I I ~ I ..- I ~ I~I .~ II I,:::::: ~ ~ ........ I : .... I ~ +/- 3,603' MD I ........ ~ :.:.:.:.:.:.:.: II I :':':':':':':': ~ ::;::;::::;:;:: ~ I ':'~:,:,:,:'~ I & I +/- 4,~85' MD ~ .~ I ~ ~ I nIH I ~ ":""""": I I ,mrn¡ I +(-5055'MD ~ ~ æ ::::::::::::::: ~ ............... æ ~ :';';':':':':': ~ I iI@ I I ~ I +Næ>'MD I ~ 1-1 ~ I I I .-I L Tubing Hanger: FMC Hanger w/ 5-1/2", 15.5#, L-80, BTC-Mod Pup Joint installed. Spaceout Tubing Pups (as required): 5-1/2", 15.5#, L-80, BTC-Mod SSSV: 5-1/2" Cameo 'TRM-4E' w/ 4.562" X-Selective Profile Set @ +/- 400' MD-RKB (Control Line to Surface). Tubing (as required): 5-1/2", 15.50#, L-80, BTC-Mod Sliding Sleeve: Baker 5-1/2" CMU Sliding Sleeve w/ 4.562" X-Selective Profile. 6' HandlinQ Pups Installed on Top and Bottom. Tubing (l-Joint): 5-1/2", 15.50#, L-80, BTC-Mod Tubing (6' Pup Joint): 5-1/2", 15.50#, L-80, BTC-Mod PBR Seal Assembly: Baker '190-60' PBR Seal Assembly w/ 15' Stroke (7.05" aD x 4.88" 10) TUbing (6' Pup Joint): 5-1/2", 15.50#, L-80, BTC-Mod Anchor assembly: Baker Model 'S-22' Anchor Tubing Seal Assembly (7.00" aD x 4.88" 10) Packer: Baker SC-2 Packer (96C-60 / 43.5# Casing / 8.313" aD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Assembly Includes Mod 'C-2' KOIV w/ Protection Sleeve. Top Of Packer (éù +/- 2907' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-1/2", 17.00#, L-80, SLHT - Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" aD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Top of Packer (éù +/- 3603' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-1/2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" aD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Top of Packer (éù +/- 4285' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-1/2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" aD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Top of Packer (éù +/- 5055' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-V2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker FB-1 Permanent Sump Packer (8.280" OD x 6.00" 10) and Lower Tubing Tail (as per BOT Completion Schematic) Top of Packer (éù +/- 5662' MD-RKB BRU 214-26 Schematic v1.0 prepared by Mark Chambers 07/25/05 Kw(- ~ik RieJ ~ Sharrer Type SL 13-5/8" / 5000 PSI/BOP Stack -6 L 13-5/8" Annular Rams Availahh~ For ~eluga Work > < Up.ppr R;em (Options): ~ ~ 1.90" 2-3/8" 4-1/2" ~ Þ 7-5/8" 13-5/8" Double Gate 2-7/8" x 2-7/8" Dual 2-7/8" x 3-1/2" Dual ~ Þ Middle Ram: Blind ~ ~ L J '-- --.J 13-5/8" Mud Cross ~ L- í l ~ ~ ~ ~ lower Ram: 13-5/8" Single Gate VBR (2-7/8" x 5-1/2") ( ~ Mark Chambers 07/19/05 [Fwd: Re: Beluga IMT Drill] ') ') .~ CI" ~,~, ',JI'''~;','~~- ""T,¡'~\.""'tiI> ~;,¡ff)" . Subject: [Fwd: Re: Beluga IMT Drill] From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Tue, 02 Nov 2004 14: 19:25 -0900 To: Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, John Nonnan <john - nonnan@admin.state.ak.us> CC: Jody J Colombie <jody_colombie@admin.state.ak.us> All, I just received a call that CP AI's Beluga IMT drill has been completed. J ody, would you see that a copy of this gets to the file. Tom -------- Original Message -------- Subject:Re: Beluga IMT Drill Date:Tue, 02 Nov 2004 14:17:58 -0900 From:Thomas Maunder <tom maunder@admin.state.ak.us> Organization:State of Alaska To:Thomas Maunder <tom maunder@adn1in.state.ak.us> CC:Tom Brassfield <TOM.J.Brassfield@conocophillips.com>, Jerome Eggemeyer <Jerome.C.Eggemeyer@conocophillips.com>, Jim Regg <jim regg@admin.state.ak.us> References :<4187D3D7 .4020807@admin.state.ak.us> Tom, This acknowledges receipt of your message been completed. Let us know if you need anything from us. Tom Maunder, PE AOGCC that the Beluga IMT drill has Thomas Maunder wrote: > Tom, > This confirms your call that there is an IMT drill in progress > involving an uncontrolled gas flow on the Beluga 214-26 well. A rig > was apparently being moved onto the well and damaged the tree. This > was the initial notification and you will provide further information > as it is available. > Tom Maunder, PE > AOGCC > SCANNED NOV 0 4 20D4 1 of 1 11/2/2004 3 :07 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTO.BER 27, 2000 E E C:LORI~IFILM.DOC PL E W M A T E R IA L U N D ER TH IS M ARK ER ALASKA OIL AND 'GAS CONSERVATION COMtHSSION February 12, 1997 TONY KIVOWLE$, GOVEFtNOFt 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907) 276-7542 T. L. Collins Beluga Asset Manager ARCO Alaska, Inc. P. O. Box 100360 Anchorage, 'Alaska 99510-0360 /, RE. Modifications;f, BRI. I~~& 224-23 Dear Mr. Collins: In your letter of January 20, 1997, you request authorization to modify the production method for Beluga River Unit wells 214-26 & 224-23. We have analyzed your proposal and find that the proposed modifications: 1. May be approved under regulations 20 AAC 25.200(d); 2. Will not significantly decrease well safety; 3. Will probably not jeopardize well integrity; and, 4. Will benefit the public. Based on the above rationale, we approve your proposal to modify BRU wells 214-26 and 224-23 to enable gas from the Sterling Formation to be produced up the inner annulus as le short string during times of peak demand. David CC: Blair Wondzell Joe Dygas l-brugas . = ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficit~l~~~.,...~ Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994, Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. if you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ~ ' jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman~ jo/rpc~z-energy ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering May 20, 1991 Mr. Lonnie Smith, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 lC ,MM Subject: Well BRU 214-26 Dear Mr. Smith: An initial four-point back pressure test was performed on BRU 214-26 on April 7 and 8, 1991, for the dual completed well. A combined open flow potential of 124, 829 MCFD has been calculated for this well. The following data for each producing string is attached: . . Copy of test data Worksheet for calculation of static column wellhead pressures (Pw) Form BPT 3 Gas Well Open Flow Potential Test Report - Form 10-421 Back-Pressure Curves The test was conducted in accordance with the provisions detailed in the "Manual of Back-Pressure Testing of Gas Wells." If you have any questions, please contact Rowland Burno at 263-4145. Sincerely, T. Wellman Cook Inlet Regional Engineer TW:RTB:czm:0066 Attachments CC' C. Kidwell D. Santi Shell Western E&P, Inc. Chevron U.S.A., Inc. RECEIVED MAY 2 1991 Alaska 0il .& Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company -' Attachment #3a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL:~ ANNUAL [] SPECIAL [] lb. TYPE TEST MULTIPOINT ~'1 OTHER 2. Name of Operator ARCO Alaska, [nc. 3. Address . ?.O. Bo× 100360, A~c~orage, AK 99510 4. Location of Well Surface 929fFSL, 308'FWL, Sec. 26, T13N, R10W, SM Top. of Producing Interval 1230'FSL, 1025'FWL, 'Sec. 26, T13N, R10W, SM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. GL=89' KB=lO4 5' I A-¢29657 · · 12. Completion Date 113. Total Depth ]14. Plugback T.D. 9/29/90 I 6443' I 6013' 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. STABILIZED [] 7. Permit NO. 90-42 NON STABILIZED [] CONSTANT TIME [] ISOCHRONAL [] 8. APl Number s0-283-2000:~ 9. Unit or Lease Name Beluga River Unit 10. Well Number BRU 214-26-1 Beluga River Unit~__~~ 11. Field and Pool 9-5/8" 43.5 17. Tbg. Size Weight per foot, lb. 2-7/8" 6.5 18. Packer set at ft. 119. GOR cf/bbl. 3165;3620 { --- 22. Produc!ng thru: Tbg;X~ Csg." ['-] 23. Length of flow channel (L) Vertical Depth 5685 5233 Fl()w Data 15. Type Completion (Describe) Dual Completion Gas Producer Perforations: From To 4431-4436 8.755 6443 3700-3728 3999-4006 4553-4558 24. Prover Choke Line X Orifice Size (in.) Size (in.) 6. 065 'x 2" 6.065 x 2" 6.065 x 2" 6.065 x 2" pMeter ressure psig 9OO 900 900 900 I.D. ininches Setatf,. 13764-3780 4076-4085 4978--4984 2.441 5685 '13846-3050 4182-4188 5039-5043 120. APl Liquid Hydrocarbons ---- ~934-3941 4268-4277 'G)5586-5611. 5636- ~1. (See' Reverse) ! Reservoir Temp. o F. Mean Annual Temp. o F. Barometric Pressure (Pa), psia 108°F @ 5685 33°F 14,§~ j.558 I0.22 10.48 -O- 6" - Flange Diff. hw Temp. 0 F. 85' Tubing Data reter essure psig 1426 1388 341 1270 Temp. °F. 57 57 57 5R Casing Data Pressure psig N/A N/A Temp. °F. N/A N!A · Duration of Flow Hr. r).79 1.(1 120 3.90 5.1} 6.90 7.78 NO. NO. Basic Coefficient (24-Hour) Fb or Fp* 107.05 107.05 107.05 - 107.05 hwPm Pressure Pm Flow Temp. Factor Ft 7.78 7.78 7.78 7.78 Gravity Factor Fg Super Comp. Factor Fpv 1.340 Rate of Flow Q, Mcfd *Included meter constant (M) = 5.477 1.36 1.36 1.36 1.36 Pr Temperature T oR 544 547 mr 1,62 1.63 ZAlas~ 0.9 0.9 MAY R 3 i9'3i Oil & G~s Cons. Anuho~a§G Critical Pressure 547 1 · 63 0.9 Critical Temperature 0.9 1.63 548 for Separator ~iS~'t0~as Gg 673 psia 336°R for Flowing Fluid G Form 10-421 Rev. 7.1-80 CONTINUED ON REVERSE SIDE. Submit in duplicate ;412 .565, Pc !486 pc2 2208.2 Pf .pf2 No. Pt Pt2 ..... Pc2 - Pt2 Pw Pw2 Pc2 - Pw2 Ps Ps2 pf2 . Ps2 1. i426 2033.5 174.7 21/,3.3 64.9 :2. [388 1926.5 281.7 2117.3 90.9 _ 3. 1341 1798.3 409.9 2084.1 124.[ . - 4. 1270 1612.9 595.3 2052.4 I~.5.R. -- 5. 25. AOF (Mcfd), 61~ 940 n 0. 742 Remarks: 21. Specific Gravity Flowing fluid (G): 0.558 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~,~~ , Title. ~a,o/e.- .-~/~ ,~e~,~,~ ~ Date ~'-zo--?/ AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressUre opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-~ hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-~ 1/Z dimensionless F lowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter'differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless F lowing pressure at vertical depth H, psia F lowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd ( 14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless - Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Test/ng Of Gas We#s, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. --' Attachment #3a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL:~ lb. TYPE TEST STABILIZED I-] NON STABILIZED [] ANNUAL [] MULTIPOINT [] CONSTANT TIME [] SPECIAL ['-I OTHER. ISOCHRONAL [] 2. Name of Operator 7. Permit NO. ARCO Alaska, Inc. 90-42 3. Address . 8. APl Number P.O. Box 100360, Ancl~orage, AK 99510 50~283-20083 4. Location of Well 9. Unit or Lease Name Surface BeluKa River Uni~ 929~FSL, 308'FWL, Sec. 26, T13N, RIOW, SM 10. WellNumber Top. of Producing Interval BRU 214-26-1 1230'FSL, 1025'FWL, 'Sec. 26, T13N, R10W, SM 11. FieldandPool Beluga River Unit, Beluga 5. Elevation in feet (indicate Ki~, DF etc.) J 6. Lease Designation and Serial No. GL=89', KB=104.5'I A-¢29657 12. Completion Date 113. Total Depth 114. Plugback T.D. [ 15. Type Completion (Describe) 9/29/90 6443' 6013' Dua...1 Completion Gas Producer 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 4431-4436 9-5/8" 43.5 8. 755 6443 3700-3728 3999-4006 4553-4558 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 3764-3780 4076-4085 4978-4984 2-7/8" 6.5 2.441 5685 3846-3850 4182-4188 5039-5043 5~q2- 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons ------ 3934-3941 4268-4277 'G)5586-5611- 5636- 3165;3620I --- Fl. (See' Reverse) , 22. Produc!ng thru: Reservoir Temp. o F. Mean Annual Temp. o F. Barometric Pressure (Pa), psia Tbg;:"~ Csg.''1-1 108°F @ 5685 33°F 14,~ 23'Length°f fl°w channel(L)I VerticalDepth{H)' G°' i X~ l Tr~'~ 1%H2S I Pr°vet IMeterrun ITaps 5685 . 5233 i '558 0.22 0.48 -0- 6" - ~lanse 24. Flow Data Tubing Data Casing Data , Prover. Choke ~Meter ~Meter Duration of Line X Orifice ~'ressure Diff, Temp, rressure Temp. Pressure Temp, F Iow No. Size (in,) Size (in.) psig hw o F. psig // o F. psig o F. Hr. 1. 6.065'x 2" 900 3.90 84 1426 / 57 N/A N/A 2. 6.065 x 2" 900 5.15 87 1388 57 N/A N/A O..5 3. 6. 065 x 2" 900 6.30 87 1341 57 N/A N/A ]. ~ 4. 6. 065 X 2" 900 7.78 85 ' 1270 58 N/A N/A 1 · S. Basic Coefficient Pressure Flow Temp, Gravity Super Comp, Factor Factor Factor Rate of Flow (24-Hour) hwPm Pm Q, Mcfd No. Fb or Fp* Ft Fg Fpv 1~ 107.05 30.34 7.78 ,9777 1. 340 1. 054 4484; 90 . 2. 107.05 40.07 7.78 .q7~q 1.~40 . 1.054 5906.85 3. 107.05 49.01 7.78 . qT~Cl 1.340 1.054 7'~ ~/, 7q 4. 107.05 60.52 7.78 .qTR8 1.340 . 1,054 8937.92 5. ~ .I *Included meter constant (M) = 5.477 K ~(~'~VED ! for Separator for Flowing Temperature Pr T Tr z MAY 2 ;~t'991 Gas Fluid No. °R ~-,.- ,, n-- n^.. ~,,._,~:~lnn Gg G 2. 1.36 5~ 1 ;. 62 0.9 Ahuhulagu 3. 1.36 547 1.63 0.9 Critical Pressure 673 psia 4. 1.36 547 1.63 0.9 Critica~ Temperature 336°R S. 1.36 548 1.63 0.9 ~412 .565( Form 10-421 CONTINUED ON REVERSE SiDE Submit in duplicate Rev. 7-1-80 Pc 1486 pc2 2208,2 Pf -pf2 No. Pt Pt2 Pc2 - Pt2 Pw Pw2 Pc2 - Pw2 Ps Ps2 pla . Ps2 1. 1426 2033.5 174.7 2143.3 64,9 ..... 2. 1388 1926,5 281,7 2117.3 90,9 -3. 13,41 1798.3 409.9 2084.1 124.1 ,_4. 1270, 1612.9 595.3 2052.4 155.8 5. 25. AOF (Mcfd), . 61,940 ,,, n ,0. 742 Remarks: 21. Specific Gravity Flowing fluid (G): 0.558 I hereby certify that the foregoing is true and correct to the best of my knowledge /-"~'~~ .Title. ~-~/~ -T~/~¢- fC~-~f,~z~ ~ Date ,¢~ zo-- ~?f Signed ' d' AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open F Iow Potential. Rate of F Iow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-x/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity 'factor, dimensionless Super compressibility factor=-x/1/z dimensionless F lowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air--1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter'differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia F lowing wellhead pressure, psia~.::i!:- Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manu~! Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, OklahOma:" Form 10-421 Attachment #la FOUR POINT BACKPRESSURE TEST DATA Beluga River Field: Deliverability Test Data Sheet IWell Name: 214-26-1 [Choke Size' Dual 1/2" IO.P. Size: 2.0" IBeginnin$ Choke Check · Time Choke Wellhead Static Diff MTR Ti Coeff Rate Press O.P. Check Setting Pres Temp. Dwnstrm and comments hh:mm /64tbs PSIA o F o F MCFPD Heater 1312 36/64 1290 58 7.80 7.30 80 150.44 8566 910' 1424 24/64 1426 57 7.78 3.90 84 149.88 4548 900 OP-Clean, Glycol Coated 1448 28/64 1388 57 7.78 5.15 87 149.47 5989 900 1548 32/64 1341 57 7.78 6.30 87 149.47 7326 900 Rate Erratic, Freezing DS Choke 1640 36/64 1270 58 7.78 7.78 85 149.75 9064 900 Opened Heat Strin~ SSV No water produc.ed during test. Start: 4/7/91 Finish: 4/7/91 . Attachment #2a WXl( ~ FOil CU.OI.~TION OF g'ATIC CII.IJ)I IELL~.F. AI) PRESSURES ... , I~ Fr C%Oi'O5-o 0. OlO~0 0.01050 0.01o5-o 0,0105-0 O,O(O~ Q,.O/OgO '0,010~o 0,0(05'o . ,.,,. . Is ~F~ ¢q1, C3..~ ~.1'% 526.~% ~e~,69~ ~F~~Fc~~./)/. 5/0 /oq. ec~ /o?. ~ /95 ~ ~ ~ CAU:33t. ATION QF STATIC ~ WELLHF. AD PRIES (Pw) 10OOO 1000 Attachment #4a 100 10 1000 BRU 214-26, STRING #1 Four Point Back Pressure Test 4/7/91 ... .,,,,,,,,,,..,,,,,,,,,,,,,,,,,,, .,..,,,,,,,o,,,o,,,..,,oo,,o.,,,,. ,,o,,,.,,,-',,,,,o,, ~,,o,,.-'.,,,., ,.,,o...,, ,,..,o....o, ..... o,..,o.,.o.,o,, .,oo.,oo,,..,,.,,,.. o..o,,~ ,oo,,, ,,,,,: · ' i Immmmm mm~m. m m mmm~m mmmm~m mQm m m m m .~mm m m mm m m:m ~m~ ii ................................................................. ~ ......... * .............. * ..... ST'.SS', ............................................................. ~r~'. 'T~ ...... .......... . _~__~ ..... ~ ........ ~,,_~_~ii_~_~ ........................... i ......... ~ ..... .... i ................................ ~ ........... ~ ........................................................... ~ - ~ ...................... =========================== -:~- .......................... i -- '~"-~--:- ~ ...................... -" ............... ~ .......................................... ....... ~ .......... ! .................... / i ................................. : ................... ~; .............. J, ........... * ............. * ..... --~-------- ...... i ................... ~ ............ i ............................. : ........ · ~ ................................................... i ............ i ......... i ....... ~ ...... i .......... ~~' .................. i .................. ~ ............................. ~ ................. ~ .... ................................ ~ ....................................... ~. .............. ~. ......... ~ ..... : ................................................... ~ ............................. q ................ ~... ............................. l ................... [ ............. ~ ..... _[ ............. ~ ....................................................... · ............ '. ....................................... i I I I 10000 100000 Q (MCPD) ARCO ALASKA INC. Cook Inlet/New Ventures Engineering #476 TRANSMISSION T~. Commissioner 'COMPANY: AOGCC ' DATE: 12/20/90 FROM: Victoria Fer~uson COMPANY: ARCO Alaska, In6 WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled M~,lar listing .sCU 33A-8 Z-Densilog,Comp. Neutron 1 1 , ·Temp Log 1 1 ·Venilog 1 1 i , ,PDK- 100 Gamma Ray 1 1 'Seg. Bond 1 1 'ACB VDL/Sign./GR 1, 1 .DIL FOCUSED GR 1 1 DIF Temp Log 1 1 SCU 13-9 Photon Log Gravel Pack Survey 1 1 SRU 31-15 CoilarLog ..... 1, 1 BRU 214-26 Formation Multi-Tester GR i 1 ' ' BHC ACOUSTILOG GR ' 1 1 ~ ,, , Receipt Acknowledgement: _5~_k0.n..._~~~"~ Date: Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED DEC 2 6 1990 Alaska Oil & Gas Cons. Commission Anchorage ~ JKA OIL AND GAS CONSERVATION (. I G I ~ J~ [ ~ WED. cOMpLETION OR RECOMPLETION h£PORT AND LOG '1 Status of Well Classificalfon of Service Well OIL r'~ GAS r~ SUSPENDED r'~ ABANDONED D SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska~ Inc 90-42 3 AddreSS 8 APl Number P.O. Box 100360r Anchorager AK 99510-0360 50-283-20053 4 Location of well at surface 9 Unit o~ Leaae Name 929' FSL, 308' FWL, SEC 26, T13N, R10W SM~..~ .......... ~, ~i:'~:~.~,;;~'.~:'i~'~' BELUGA RIVER UNIT At Top Producing Intewal ~ .,~- ( 10 Well Number At Tota1114'DepthFSL'858' FWL,SEC 26, T1,N, R10W SM~ ~-'/'~/'~'~ { ' --~'~"-~'~- ~"~";;-'i~d~..~'"~.-,~ 11 Field and Pool 1935' FSL~ 1728' FWL~ SEC 26~ T13N~ R10W SM ~ ~Ot,l,~]d~¢:~ i ...... BELUGA RIVER FIELD 5 Elevation in feat (indicate KB, DF, etc.) I 6 Lease'"~'~'fi~'~Serial No. RKB 104.5'I A-029657 12 Date Spudded 13 Date T.D. Reached 114 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 7/31/90. 9/1/90. 9/30/90.I NA feet MSLI 2 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Suwey 120 Depth where SSSV ~et 21 Thickness of permafrost & 5745' TVD YES [~ NO ~I NONE feet MD 0' APPROX 6448' MD &6154' TVD 6014' MD 22 Type Electric o~ Olfler Logs Run DI L/MLL/BHC-AC/CDL/C N/FMT/GR/SP/TEMP/CBL/GYRO/VSP .,~ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I'rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 310# X-52 SURF 221' 30' 13-3/8' 68~ K-55 SURF 2977' 17-1/2' 1180 SX CLASS G~ 500 SX CLASS G TAIL 9-5/8' 43.5~ S-95 SURF 644Z 12-1/4' 2052 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD intewai, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3286'-3598' (gross) MD W/5' TCP @ 12 SPF 3192'-349, TVD ~'~ 3-1/2', 9.3# 3240' DUAL PKR ~ 3166' 3700'-4558' (gross) MD W/5' TCP @ 8 SPF 3589'-439Z TVD 2-7/8'~ 6.5# 5685' 3621' 4978'-5650' (gross) MD W/5' TCP @ 8 SPF 4781'-5404' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5586'-5610' MD W/1-11/16' @ 4 SPF 5345'-5367' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5636'-5650' MD W/1-11/16'@ 4 SPF 5393'-5406' TVD 3188'-3192' 150 SX CLASS G 5796'-5810' MD W/1-11/16' @ 4 SPF 5541'-5554' TVD 6050' Cement Retainer w/10 bbls crnt below & 5 bbls cmt above. TOC (~ 6014' See atta ,chment for complete perf depIhs 27 PFIOOUCTION TEST Date First Production IMelhod of Operation (Rowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (coif) Press. !24-HOUR RATE ~ f CORE DATA , description of lithology, porosity, fractures, apparent dips and p~esence of oil, gas or water. Submit core chips. NOV s 19 0 ' ~'~ ~chora~ _ . ..~ .m__~.,.m. Form 10-407 Rev. 7-1-80 NOV :[ .5 1990 10il .& Gas Cons. ~ch0ra~ Submit in duplicate GEC)L(~IC MARKF..-~5 FORMATION TESTS NAIVE Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. DST #1, Perfed 6088'-6100' w/5" TCP, No Flow A ZONE TOP 3162' 3073' DST #2, Perfed 5586'-5610', 5638'-565Z, 5796'-5810' w/1-11/16' ~) 4spf B ZONE TOP 3368' 3271' Open Well (~ 04:20 on 9/18/90 C ZONE TOP 3525' 3422' Close Well ~ 13:00 on 9/16/90 TBG Pressure = 1150 psi, CSG Pressure = 1500 psi D ZONE BELUGA TOP i3696' 3585' Choke. 6/64' E ZONE TOP 3961' 3835' Tot~U Gas produced 202,824 SCF F ZONE TOP 4300' 4152' No Water produced G ZONE TOP 4798' 4614' H ZONE TOP 5290' 5060' ZONE TOP 5874' 5614' 31. LIST OF ATTACHMENTS GYRO, SUMMARY OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the'best of my knowledge Signed Title AREA DRILLING ENGINEER Date /I /! ~ / v 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 GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING INC. for Gyrodat~ Serviq~s z.c. Beluga River Unit, Kenai, Alaska BRU 214-26 Sidetrack ~,~,i~! ~ ~O N,45.73,E M. NAIRN ., ~.: ~:~i~ ~ ~;ii ~ Gas ~O~S. ~0~~i~:>~'~ , Inc. RECORD OF SURVEY Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Number .... : O IGJNAJ.. lO/Ol/9O RAD LUS ?~'OF ~iC'URVATURE 104.50 f~ * Al{ 0990G 24 ~ ~,~e~x~r~~a 50-283-20083 '~ S MEAS INCLN C DEPTH ANGLE 7 100 0.18 7 200 0.11 7 300 0.12 7 400 0.12 7 500 0.35 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 100.0 -4.5 0.1 N 32.63 E 0.1 N 0.0 E 0.2 N 16.32 E 0.18 200.0 95.5 0.4 N 1.64 E 0.4 N 0.1 E 0.4 N 16.82 E 0.07 300.0 195.5 0.5 N 5.21 E 0.6 N 0.1 E 0.6 N 12.39 E 0.01 400.0 295.5 0.7 N 4.79 E 0.8 N 0.1 E 0.8 N 10.49 E 0. O0 500.0 395.5 1.0 N 40.86 E 1.2 N 0.3 E 1.2 N 14.58 E 0.23 7 600 0.95 600.0 495.5 2.2 N 64.52 E 1.9 N 1.2 E 2.2 N 32.95 E 0.60 7 700 2.26 699.9 595.4 4.8 N 69.43 E 2.9 N 3.8 E 4.8 N 52.04 E 1.31 7 800 5.43 799.7 695.2 10.9 N 71.15 E 5.2 N 10.1 E 11.4 N 62'70 E 3.17 7 900 8.52 899.0 794.5 22.0 N 67.60 E 9.5 N 21.5 E 23.5 N 66.15 E 3.09 7 1000 10.37 997.6 893.1 37.4 N 63.75 E 16.2 N 36.4 E 39.9 N 65.95 E 1.85 7 1100 13.54 1095.4 990.9 57.1 N 63.78 E 25.4 N 55.0 E 60.6 N 65.21 E 3.17 7 1200 16.39 1192.0 1087.5 81.3 N 67.75 E 36.0 N 78.5 E 86.4 N 65.37 E 2.87 7 1300 17.22 1287.7 1183.2 108.1 N 68.22 E 46.8 N 105.3 E 115.3 N 66.03 E 0.83 7 1400 17.42 1383.2 1278.7 135.6 N 68.48 E 57.8 N 133.0 E 145.0 N 66.50 E 0.20 7 1500 17.35 1478.6 1374.1 163.2 N 67.97 E 68.9 N 160.7 E 174.9 N 66.80 E 0.08 7 1600 17.34 1574.1 1469.6 190.8 N 68.01 E 80.1 N 188.4 E 204.7 N 66.97 E 0.01 7 1700 17.06 1669.6 1565.1 218.2 N 67.34 E 91.3 N 215.7 E 234.3 N 67.06 E 0.29 7 1800 16.89 1765.3 1660.8 245.3 N 68.42 E 102.3 N 242.8 E 263.5 N 67.15 E 0.19 7 1900 16.78 1861.0 1756.5 272.0 N 68.53 E 112.9 N 269.7 E 292.4 N 67.28 E 0.11 7 2000 16.62 1956.8 1852.3 298.5 N 67.88 E 123.6 N 296.4 E 321.1 N 67.36 E 0.17 7 2100 16.61 2052.6 1948.1 324.9 N 69.04 E 134.1 N 323.0 E 349.7 N 67.45 E 0.10 'Survey Codes: 7/GYRO (BR21426G) o BRU 214-26 Sidetrack MEAS INCLN VERTICAL-DEPTHS DEPTH ANGLE BKB SUB-SEA 2200 16.26 2148.5 2044.0 2300 16.13 2244.5 2140.0 2400 16.04 2340.6 2236.1 2500 15.66 2436.8 2332.3 2600 15.70 2533.1 2428.6 7 2700 15.57 2629.4 2524.9 7 2800 15.60 2725.7 2621.2 7 2900 15.54 2822.0 2717.5 7 3000 16.54 2918.2 2813.7 7 3100 16.59 3014.0 2909.5 7 3200 16.79 3109.8 3005.3 7 3300 16.91 3205.5 3101.0 7 3400 15.91 3301.4 3196.9 7 3500 15.36 3397.7 3293.2 7 3600 16.97 3493.8 3389.3 7 3700 18.12 3589.1 3484.6 7 3800 19.76 3683.7 3579.2 7 3900 20.11 3777.7 3673.2 7 4000 20.29 3871.6 3767.1 7 4100 20.48 3965.3 3860.8 7 .4200 20.79 4058.9 3954.4 7 4300 21.04 4152.3 4047.8 7 4400 21.38 4245.5 4141.0 7 4500 21.71 4338.5 4234.0 7 4600 21.90 4431.4 4326.9 7 4700 22.40 4524.0 4419.5 'Survey Codes: 7/GYRO RECORD OF SURVEY SECTION DISTNCE 350.8 376.3 401.5 426.1 450.4 474.8 499.1 523.3 548.0 573.2 598.6 624.2 650.0 675.7 703.3 733.4 765.8 799.8 834.3 869.1 904.3 940.0 976.1 1012.8 1049.9 1087.6 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 69.47 E 144.1N 349.5 E N 69.58 E 153.9 N 375.6 E N 71.25 E 163.2 N 401.7 E N 71.85 E 171.8 N 427.6 E N 71.,71 E 180.2 N 453.3 E N 70.16 E 189.1 N 478.7 E N 71.30 E 197.9 N 504.1 E N 71.74 E 206.4 N 529.6 E N 73.23 E 214.7 N 555.9 E N 73.57 E 222.9 N 583.2 E N 73.73 E 231.0 N 610.8 E N 73.65 E 239.1 N 638.6 E N 66.10 E 248.8 N 665.1E N 59.35 E 261.2 N 689.1 E N 43.58 E 278.5 N 710.8 E N 40.80 E 300.8 N 731.0 E N 42.48 E 325.0 N 752.6 E N 42.58 E 350.2 N 775.6 E N 42.74 E 375.6 N 799.0 E N 43.08 E 401.1 N 822.7 E N_ 43.03 E 426.8 N 846.8 E N 43.30 E 452.9 N 871.2 E N 43.78 E 479.1 N 896.1 E N 43.86 E 505.6 N 921.6 E N 43.73 E 532.4 N 947.3 E N 43.88 E 559.6 N 973.4 E Page 2 lO/Ol,/9o CLOSURE DISTNCE BEARING 378.0 'N 67.59 E 405.9 N 67.72 E 433.6 N 67.89 E 460.8 N 68.11 E 487.8 N 68.31 E 514.7 N 68.45 E 541.6 N 68.56 E 568.4 N 68.70 E 595.9 N 68.88 E 624.4 N 69.09 E 653.0 N 69.29 E 681.9 N 69.47 E 710.1 N 69.49 E 736.9 N 69.24 E 763.4 N 68.61 E 790.5 N 67.63 E 819.8 N 66.64 E 851.0 N 65.70 E 882.9 N 64.82 E 915.3 N 64.01 E 948.3 N 63.25 E 981.9 N 62.53 E 1016.2 N 61.87 E 1051.1 N 61.25 E 1086.6 N 60.66 E 1122.8 N 60.10 E /lOO 0.35 0.13 0.16 0.38 0.04 0.17 0.09 0.07 1.01 0.06 0.20 0.12 1.15 0.73 2.10 1.18 1.65 0.35 0.18 0.19 0.31 0.25 0.35 0.33 0.19 0.50 BRU 214-26 Sidetrack RECORD OF SURVEY Page 3 lO/Ol/9O S MEAS INCLN C DEPTH ANGLE 7 4800 22.71 7 4900 22.84 7 5000 22.51 7 5100 22.32 7 5200 22.09 VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 4616.3 4511.8 1126.0 N 44.40 E 587.1 N 1000.1 E 4708.5 4604.0 1164.7 N 44.71 E 614.7 N 1027.2 E 4800.8 4696.3 1203.2 N 44.39 E 642.2 N 1054.3 E 4893.3 4788.8 1241.3 N 44.41 E 669.4 N 1081.0 E 4985.8 4881.3 1279.1 N 44.68 E 696.4 N 1107.5 E 7 5300 21.79 5078.6 4974.1 7 5400 21.57 5171.5 5067.0 7 5500 21.26 5264.6 5160.1 7 5600 21.10 5357.9 5253.4 7 5700 20.88 5451.2 5346.7 7 5800 20.83 5544.7 5440.2 7 5900 20.45 5638.3 5533.8 7 6000 20.38 5732.0 5627.5 7 6100 20.03 5825.8 5721.3 7 6200 19.80 5919.8 5815.3 1316.5 1353.4 1389.9 1426.0 1461.9 1497.5 1532.7 1567.6 1602.1 1636.2 1669.9 1678.2 1719.3 N 44.51 E 723.0 N 1133.7 E N 44.85 E 749.2 N 1159.7 E N 45.18 E 775.1 N 1185.5 E N 44.72 E 800.6 N 1211.0 E N 45.00 E 826.0 N 1236.3 E N 44.93 E 851.2 N 1261.5 E N 45.50 E 876.0 N 1286.5 E N 45.76 E 900.4 N 1311.4 E N 45.63 E 924.6 N 1336.1 E N 45.84 E 948.3 N 1360.5 E N 45.47 E 971.9 N 1384.6 E N 45.66 E 977.7 N 1390.6 E N 45.66 E 1006.4 N 1419.9 E 7 6300 19.55 6014.0 5909.5 7 6325 19.50 6037.6 5933.1 X 6448 19.50 6153.5 6049.0 CLOSURE DISTNCE BEARING 1159.7 N 59.58 E 1197.1 N 59.10 E 1234.5 N 58.65 E 1271.5 N 58.23 E 1308.2 N 57.84 E 1344.6 N 57.47 E 1380.7 N 57.13 E 1416.4 N 56.82 E 1451.8 N 56.53 E 1486.9 N 56.25 E 1521.8 N 55.99 E 1556.4 N 55.75 E 1590.8 N 55.53 E 1624.8 N 55.32 E 1658.4 N 55.12 E 1691.6 N 54.93 E 1699.9 N 54.89 E 1740.4 N 54.67 E DL /lOO 0.32 0.14 0.33 0.19 0.23 0.30 0.22 0.31 0.17 0.22 0.05 0.39 0.08 0.35 0.23 0.25 0.22 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED BRU 214-26 Sidetrack Page 4 10/01/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 105 0.18 105 100 205 0.11 205 200 305 0.12 305 300 405 0.13 405 400 505 0.38 505 0 0 N 31.24 E 0.16 N 0.05 E 0 0 N 1.80 E 0.40 N 0.12 E 0 0 N 5.19 E 0.60 N 0.13 E 0 0 N 6.41 E 0.81 N 0.15 E 0 0 N 41.93 E 1.19 N 0.32 E 500 605 1.01 605 600 705 2.40 705 700 805 5.58 805 800 906 8.62 905 900 1007 10.59 1005 0 0 N 64.74 E 1.88 N 1.27 E 0 0 N 69.51 E 3.01 N 3.95 E 0 0 N 70.98 E 5.36 N 10.52 E 1 1 N 67.38 E 9.80 N 22.22 E 3 1 N 63.75 E 16.81 N 37.55 E 1000 1109 13.81 1105 1100 1213 16.50 1205 1200 1318 17.26 1305 1300 1422 17.40 1405 1400 1527 17.35 1505 5 2 N 64.15 E 26.37 N 56.96 E 9 4 N 67.81 E 37.39 N 81.93 E 13 5 N 68.27 E 48.76 N 110.15 E 18 5 N 68.37 E 60.27 N 139.20 E 23 5 N 67.98 E 71.93 N 168.23 E 1500 1632 17.25 1605 1600 1736 17.00 1705 1700 1841 16.84 1805 1800 1945 16.71 1905 1900 2050 16.62 2005 27 5 N 67.80 E 83.63 N 197.15 E 32 5 N 67.73 E 95.39 N 225.60 E 36 5 N 68.47 E 106.67 N 253.84 E 41 4 N 68.23 E 117.75 N 281.89 E 45 4 N 68.46 E 128.89 N 309.63 E 2000 2154 16.42 2105 2100 2258 16.18 2205 2200 2362 16.07 2305 2300 2466 15.79 2405 2400 2570 15.69 2505 50 4 N 69.27 E 139.57 N 337.38 E 54 4 N 69.53 E 149.82 N 364.72 E 58 4 N 70.62 E 159.76 N 391.86 E 62 4 N 71.65 E 168.95 N 418.96 E 66 4 N 71.75 E 177.73 N 445.64 E 2500 2674 15.60 2605 70 4 N 70.56 E 186.72 N 472.20 E BRU 214-26 Sidetrack Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL lO/Ol/9O SUBSEA MEAS DEPTH -~2600 2700 2800 2900 3000 INCLN TVD DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2778 15.59 2705 73 4 N 71.05 E 196.01 N 498.50 E 2882 15.55 2805 77 4 N 71.66 E 204.89 N 524.92 E 2986 16.40 2905 81 4 N 73.02 E 213.57 N 552.04 E 3090 16.59 3005 86 4 N 73.54 E 222.09 N 580.51 E 3194 16.78 3105 90 4 N 73.72 E 230.52 N 609.26 E 16.91 3205 94 4 N 73.65 E 239.03 N 638.32 E 15.89 3305 99 4 N 65.'88 E 249.18 N 665.91 E 15.47 3405 103 4 N 58.24 E 262.14 N 690.65 E 17.10 3505 107 4 N 43.27 E 280.85 N 713.02 E 18.39 3605 112 5 N 41.07 E 304.62 N 734.33 E 3100 3299 3200 3403 3300 3507 3400 3611 3500 3716 19.84 3705 118 6 N 42.50 E 330.57 N 757.63 E 20.16 3805 124 6 N 42.63 E 357.40 N 782.27 E 20.36 3905 131 7 N 42.86 E 384.52 N 807.31 E 20.61 4005 137 7 N 43.06 E 411.81 N 832.77 E 20.91 4105 144 7 N 43.16 E 439.52 N 858.67 E 3600 3822 3700 3929 3800 4035 3900 4142 4000 4249 21.23 4205 151 7 N 43.57 E 467.52 N 885.09 E 21.59 4305 159 7 N 43.83 E 495.85 N 912.21 E 21.84 4405 167 8 N 43.77 E 524.61 N 939.81 E 22.29 4505 174 8 N 43.85 E 553.83 N 967.82 E 22.67 4605 183 8 N 44.33 E 583.60 N 996.62 E 4100 4356 4200 4463 4300 4571 4400 4679 4500 4787 22.83 4705 191 8 N 44.70 E 613.51N 1026.04 E 22.50 4805 199 8 N 44.39 E 643.28 N 1055.35 E 22.29 4905 208 8 N 44.44 E 672.73 N 1084.19 E 22.03 5005 216 8 N 44.65 E 701.75 N 1112.79 E 21.73 5105 223 8 N 44.60 E 730.34 N 1140.96 E 4600 4896 4700 5004 4800 5112 4900 5220 5000 5328 5205 231 5100 5435 21.46 8 N 44.97 E 758.45 N 1168.86 E BRU 214-26 Sidetrack Page 6 10/01/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5200 5543 21.19 5305 5300 5650 20.99 5405 5400 5757 20.85 5505 5500 5864 20.59 5605 5600 5971 20.40 5705 238 7 N 44.98 E 785.99 N 1196.47 E 245 7 N 44.86 E 813.36 N 1223.67 E 253 7 N 44.96 E 840.38 N 1250.65 E 259 7 N 45.29 E 867.16 N 1277.48 E 266 7 N 45.68 E 893.30 N 1304.10 E 5700 6077 20.11 5805 5800 6184 19.84 5905 5900 6290 19.58 6005 6000 6396 19.50 6105 273 7 N 45.66 E 919.11 N 1330.55 E 279 6 N 45.81 E 944.47 N 1356.55 E 285 6 N 45.51 E 969.49 N 1382.19 E 292 6 N 45.66 E 994.28 N 1407.51 E BRU 214-26 Sidetrack Page 7 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL lO/Ol/9O MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIRT BEARING FROM-WELLHEAD DIRT BEARING 1000 10.37 998 893 37 N 63.75 E 2000 16.62 1957 1852 299 N 67.88 E 3000 16.54 2918 2814 548 N 73.23 E 4000 20.29 3872 3767 834 N 42.74 E 5000 22.51 4801 4696 1203 N 44.39 E DL/ 100 16 N 124 N 215 N 376 N 642 N 36 E 40 N 65.95 E 1.9 296 E 321 N 67.36 E 0.2 556 E 596 N 68.88 E 1.0 799 E 883 N 64.82 E 0.2 1054 E 1234 N 58.65 E 0.3 6000 20.38 5732 5627 1568 N 45.76 E 900 N 1311 E 1591 N 55.53 E 0.1 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. lO/Ol/90 Client .... : ARCO ALASKA, INC. Field ..... : Beluga River Unit, Kenai, Alaska Well ...... : BRU 214-26 Sidetrack Section at: N,45.73,E Surveyor..: M. NAIRN Computation...: RADIUS OF CURVATURE Survey Date...: 9/11/90 RKB Elevation.: 104.50 ft Job Number .... : AK0990G242 API Number .... : 50-283-20083 MARKER IDENTIFICATION KB 13-3/8" CASING POINT TOP OF A ZONE TOP OF B ZONE TOP OF C ZONE TOP OF BELUGA TOP OF D ZONE TOP OF E ZONE TOP OF F ZONE TOP OF G ZONE TOP OF H ZONE TOP OF I ZONE PROJECTED TD INTERPOLATED MARKERS REPORT MEAS INCLN DEPTH ANGLE 0 0.00 2977 16.31 3162 16.71 3368 16.23 3525 15.76 VERT-DEPTHS SECT BKB SUB-S DIST 0 -105 2896 2792 3073 2969 3271 3166 3422 3317 3696 18.07 3585 3481 3696 18.07 3585 3481 3961 20.22 3835 3730 4300 21.04 4152 4048 4798 22.70 4614 4510 DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 5290 21.82 5874 20.55 6448 19.50 0 N 0.00 E 542 N 72.89 E 589 N 73.67 E 642 N 68.52 E 682 N 55.41 E ON 0 E 213 N 550 E 228 N 600 E 245 N 657 E 265 N 695 E 732 N 40.91 E 732 N 40.91 E 821 N 42.68 E 940 N 43.30 E 1125 N 44.39 E 300 N 730 E 300 N 730 E 366 N 790 E 453 N 871 E 587 N 1000 E 5069 4965 5614 5509 6154 6049 1313 N 44.53 E 1524 N 45.35 E 1719 N 45.66 E 720 N 1131 E 870 N 1280 E 1006 N 1420 E Sp~at Land Dlr~£&Janag DrJglJng. Zn£. <K8>O 350 700 to5o t400 t750 2i00 2450 2800 T 3t5o V D 3500 3850 4200 4550 4900 5~50 5600 5950 6300 350 ... VERTICAL SECTION VIEW ARCO ALASKA, INC. BRU 2i4-26 Sidetrack Section at: N 45.73 E TVD Scale.: ! inch = 700 feet Dep Scale.: ! inch = 700 feet Drawn ..... : !0/0!/90 iai'kef' I[len~.if~cal;Jon ~ TYD SECTN INCLN KB 0 0 0 0.00 PROJECTED TI3 6448 6~,54 t7t9 t9.50 350 700 t050 t400 t750 2t00 2450 PSO0 3t50 3500 Section Deparf. ure I, larker Idenl:t f icat Son NO NIS E/N AiM 0 ON O~ B) ~IOJECTED TO 644e 'to06 N t4,?.O E PLAN VIEW ARCO ALASKA, INC. 8RU 214-26 Sidetrack CLOSURE ..... : 1740 ft ,DECLINATION.: 0.00 E SCALE ....... : 'DRAHN ....... : N 54.67 E inch --300 feet lO/Oi/gO t9§0 l----- tBO0 ~-- - 1650 1 .... t500 ~0§0 90O 750 6OO ~ ..... : 450 --- 300 '70 .~r. EAST-> 300 450 600 750 900 i050 t200 t350 iSC BRU 214-26 Perforation Depths 4978'-4984' ~ 8 SPF / 5039'-5043' ~ 8 SPF 5392'-5412' ~ 8 SPF 5586'-5611' ~ 8 SPF 5636'-5650' ~q ~ 8SPF - 672' Achieve uMerbe]e~e for Ran #I, Target pressure = 2000 psi at 5150' TVD. R~ Depths Shot Dens~_ty 3352'-3368' ~ 3387'-3392' < 3SO6'-3SlO' ~ 3'700'-3728' ~ 3764'-3780' 3846'-3850' 3934'-3941' 3999'-,4006' 4076'-4085' 4182'-4188' 4431'-4436' 4553'-4558' 12 SPF 12SPF 12 SPF Achieve ur~lerb~ for R~n #2, Target pzessuze = 12 SPF 12 SPF 12 SPF 12 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 8 SPF 1600 psi ~t 4150' TVD. 9/19/90 ARCO ,~d and Gas Compa, ny O Well History- Initial Report - Dally Inlt~uctlene: Prepare and submit the "Initial Raporl" on the first Wednesday after I well is spudded or workover operltlonl ere Marled. Dally work prior to sPudding should be lummsrlzad on the form giving tnclullve dates ~ly. District I County, parish or borough 18tats ARCO ALASKA INC. I KENAI I Lease or Unit I A029657 Title I DRILLING, EVALUATE, & COMPLETE Field BELUGA RIVER UNIT Auth. or W.O. no. AD6811 lWell no. BRU 214-26 Operator ARCO W.I. ARCO I 33. 3333 Spudded or W.O. begUnsPUD Ioa'e 07/31/90 [Hour 18: 00 I Dele and depth as of 8:00 a.m. 07/30/90 ( TD: 0'( SUPV:RWS 07/31/90 ( TD: 0'( SUPV:RWS 08/01/90 ( TI): 255'( SUPV:RWS 08/02/90 ( TD: 670'( SUPV:JAT 1) 2) ) 3) 25 ;) 4) 41 ,) Complete record for each day reported GRACE 158 INSTALLING DIVERTER MW: 0.0 VIS: 0 FINISH RU RIG. ACCEPT RIG @ 0000 HRS 30-JULY-90. INSTALL DIVERTERAND BUILD MUD. DAILY:SO CUM:SO ETD:SO EFC:$3,410,000 PREPARING TO SPUD MW: 8.5 VIS:100 FIN RU DIVERTERAND MISC RU. FIN MIXING SPUD MUD. WORK ON RIG ENGINES AND PREPARE TO SPUD. DAILY:S292,946 CUM:$292,946 ETD:S292,946 EFC:$3,410,000 DRILLING MW: 8.5 VIS: 80 REROUTE DIVERTER LINE, WORK ON ACCUMULATOR LINE AND GENERATORS. SPUD WELL @ 18:00 HRS 31-JULY-90. DRILLED TO 255'. DAILY:S23,873 CUM:$316,819 ETD:S316,819 EFC:$3,410,000 DRILLING MW: 8.6 VIS: 90 DRILLED AND SURVEYED TO 500' TRIP FOR KO ASS'Y. FAULTY DUMP SWITCH ON PUMP CAUSING ORIENTING PROBLEMS. DRILLED AND 08/03/90 (5) TD: 1282' ( 61: SUPV:JAT 08/04/90 (6) SURVEYED TO 670'. DAILY:S40,146 CUM:$356,965 GIH DRILLED TO 734'. TRIP FOR BHA. TRIP FOR BHA. DAILY:S36,180 CUM:$393,145 POH ETD:S356,965 EFC:$3,410,000 MW: 8.6 VIS:150 DRILLED TO 1282' CIRC. ETD:S393,145 EFC:$3,410,000 MW: 9.0 VIS:120 TD: 2900'( 1611 SUPV:JAT 08/05/90 (7) TD: 2983'( 8 SUPV:JAT 08/06/90 (8) TD: 2983'( SUPV:JAT w,,,,/=4, i 9) TD: 2983' ( SUPV: JAT DRILLED TO 2900'. CIRCULATE PRIOR TO TRIP. HAVING TO PUMP OUT OF THE HOLE. DAILY:S24,147 CUM:$417,292 ETD:S417,292 PU KELLY. EFC:$3,410,000 PREPARE TO POH MW: 9.1 VIS: 75 FPOH. CHANGE BHA. GIH. REAM F/ 2175'-2900'. DRILLED TO 2983'. ST. PREP TO POH. DAILY:S44,784 CUM:$462,076 ETD:S462,076 EFC:$3,410,000 OPENING HOLE TO 17-1/2" MW: 8.9 VIS:140 POH. LOG SURFACE HOLE. MU BHA. OPEN HOLE TO 17.5" F/ 65'-513'. DAILY:S32,439 CUM:$494,515 ETD:S494,515 EFC:$3,410,000 OPEN HOLE TO 17-1/Z" OPEN HOLE TO 1033'. DAILY:S28,383 CUM:$522,898 ETD:S522,898 EFC:$3,410,000 The above is correct For form preparation ~l~diatribution, ~ see Procedures ManualT'~ectlon 10, Drilling, Pages 86 and 87. JNumber all dally wall ~lltory.~)['~.s consecullvely jPage no. they are prepar~i." c I. .. Utt!& (;as C:o s. Commlss or.,, ' ' chora a AR3B-459-1-D ' ~ ARCO 0,, and Gas Compan. y ~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations· If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lltte,lm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers end following setting o! oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish lState KENAI AK IweH Lease or Unit A029657 IBRU 214-26 BELUGA RIVER UNIT Date and deptl~ as of 8:00 a.m. 08/08/90 (10) TD: 2983'( SUPV:JAT 08/09/90 (11) TD: 2983'( SUPV:RWS 08/10/90 (12) TD: 2983'( 0 SUPV:RWS 08/11/90 (13) TD: 2985'( 2 SUPV:RWS 08/12/90 (14) TD: 2985'( 0 SUPV:RWS 08/13/90 (15) TD: 2985'( 0 SUPV:RWS 08/14/90 (16) TD: 2995'( 101 SUPV:RWS Complete record for each day while drilling or workover in progress GRACE 158 OPENING HOLE TO 17-1/2" MW: 8.9 VIS:165 OPENED HOLE TO 17-1/2" F~-1033'-1256'.- *POH." CHANGE BHA AND CO HOLE OPENER. GIH. OPEN-HOLE.-TO 17-~/2" F'/ 1256'-164~'. ' ~.*' DAILY:S28,072 CUM:$550,979~::-: ETD:$550~9~0 EFC:$3~410,000 OPENING HOLE TO 17-1/2" MW: 8.9 VIS:105 OPEN HOLE TO 17-1/2" F/ 1642'-2643'. ' - DAILY:S58,441 CUM:$609,411 ETD:S609,41! EFC:$3,410,000 RU TO RUN CASING MW: 9.2 VIS: 97 OPEN HOLE TO 17-1/2" F/ 2643'-2983'. MADE CONDITIONING TRIP. CBU. POH. RU TO RUN CASING. DAILY:S27,411 CUM:$636,822 ETD:S636,822 EFC:$3,410,000 WOC MW: 9.2 VIS: 75 RU TO RUN CSG. RUN 13-3/8" CSG. CIRC BOTTOMS UP. RU HOWCO, TEST LINES TO 1500 PSI. PUMP 50 BBL FW SPACER, 1327 SX (565 BBL) 12.8 PPG LEAD CMT W/ 8% CACL + 12% GEL, FOLLOWED BY 500 SX CL C (102 BBL) CMT. DISPLACE WITH 437 BBL MUD. FULL RETURNS THROUGHOUT JOB. CMT RETURNS @ 400 BBL INTO DISPLACEMENT. RD HOWCO A/qD CSG TOOLS. WOC, CLEAN PITS, ND DIVERTER LINE. DAILY:S110,327 CUM:$747,149 ETD:S747,149 EFC:$3,410,000 NU BOP 13-3/8"8 2977' MW: 8.6 VIS: 39 WOC, ND DIVERTER LINE. ND HYDRIL, CUT 13-3/8" CSG, WELD ON 13-3/8" X 3000 PSI BRADEN HEAD. TEST TO 1000 PSI. SET ADAPTER FLANGE, MUD CROSS, NU BOP. CLEAN PITS OF BAR AND CMT. DAILY: $34,917 CUM: $782,066 ETD: $782,066 EFC: $3,410,000 · '_.*-_*..'~-:.*'*':;: : ~';*; .-_~ ....... ....... · ......... DRLG OUT.1-3.~3/8'' CSG*** 13-3/8"@*'2977' MW: 8.6 VI*S~ 3'9 FINISH:.NU':BOP'? TEST RAMS, vTEST HCR'~V~LVE~?LEAKE~.~ CO-~{~R. TEST NEW HCR, AND CHOKE MANIFOLD. SET WEAR BUSHING. MAKE UP BRA. CHECK MWD. TIH. TAG CMT @ 2884'. TEST CSG TO 2500'. -- ...... DAILY: $51,618 CUM: $833,684 ETD: $833,684 EFC: $3,410,000 MIXING MUD 13-3/8"@ 2977' MW: 0.0 VIS: 0 TEST CSG TO 2500 PSI - OK. DRLD FLOAT COLLAR, HARD CMT, FLOAT SHOE AND 10' OF NEW HOLE TO 2995'. CIRC AND COND MUD. LOT 16.1 PPG EMW. CLEAN CMT CONTAMINATED MUD OUT OF PITS. FILL PITS WITH FW AND MIX MUD. DAILY:S27,844 CUM:$861,528 ETD:S861,528 EFC:$3,410,000 The above is correct For form preparation distribution see Pro:ePcruerPeasral~lia°nnuae~;ction 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively ]Page no. as they are prepared for each wail. [ ARCO ~.. and Gas Company g~, Dally Well History--Interim i Inltrucflonl: This form is used during drilling or workover operations. If testing, coring, or pertoraling, show formation name In describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim" Iheetl until final completion. Report official or representative test on "Final" form. 1) Submit "leterim" sheets when filled out bul not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string la set. Submit weekly for workovera and following setting of oil string until completion. District Field ARCO ALASKA INC. BELUGA RIVER mit County or Parish IState I KENAI AK Lease or Unit IWeli no. I A029657 I BRU 214-2& Date and deptl~ as of 8:00 a.m. 08/15/90 (17) TD: 3397'( 402 SUPV:RWS 08/16/90 (18) TD: 3953'( 556 SUPV:JAT 08/17/90 (19) TD: 4460'( 507 SUPV:JAT 08/18/90 (20) TD: 4602'( 142 SUPV:JAT 08/19/90 (21) TD: 4602'( SUPV:JAT 08/20/90 (22) TD: 4602'( SUPV:JAT 08/21/90 (23) TD: 3260'( SUPV:JAT Complete record for each day while drilling or workover in progress GRACE 158 WIPER TRIP 13-3/8"@ 2977' MW: 9.2 VIS: 40 MIX MUD. DISP HOLE W/NEWMUD. DRLD-F½2995-30~1~-. HAD MWD FAILUREL-3t--CX/~C CARBIDE LAG, PUMP PILL. _ CHAIN O. UT WET ......... CHARGE OUT TURBINE PULSAR IN..M~ J~IH, TEST MWD, CONTINUE IN HOLE. SURVEY, DRLD F/3077-3233'. HAD 500 UNITS OF GAS, CIRC BOTTOMS UP. WEIGHT UP TO 9.0 PPG. DRLD F/3233-3297'. CIRC. DRLD F/3297-3397'. CIRC AND RAISE MW TO 9.2 PPG. WIPER TRIP TO SHOE. DAILY:S48,809 CUM:$910,337 ETD:S910,337 EFC:$3,410,000 POH 13-3/8"@ 2977' MW:10.2 VIS: 41 FIN ST. DRILLED TO 3953'. ATT TO POH. HOLE NOT FILLING PROPERLY. GIH AND CBU. PREP TO POH. DAILY:S46,057 CUM:$956,394 ETD:S956,394 EFC:$3,410,000 DRILLING 13-3/8"@ 2977' MW:10.2 VIS: 42 TFNB. DRILLED TO 4289'. ST. DRILLED TO 4460'. DAILY:S69,786 CUM:$1,026,180 ETD:S1,026,180 EFC:$3,410,000 MAKING BACKOFF 13-3/8"@ 2977' MW:10.3 VIS: 44 DRILLED TO 4602'. CBU ATT TO MAKE ST. HOLE VERY TIGHT. PIPE STUCK W/ BIT @ 4302' RU AND RUN FP. ATT BO ON TOP OF JARS. NO GOOD. DAILY:S88,723 CUM:$1,114,903 ETD:SI,ii4,903 EFC:$3,410,000 RUNNING FREE POINT 13-3/8"@ 2977' MW:10.2 VIS: 42 MADE BO BETWEEN WHDP AND XO. CBU AND POH. GIH WL JARRING ASS'Y. JAR ON FISH W/O SUCCESS. RU AND RUN FP. DAILY:S26,371 CUM:$1,141,274 ETD:S1,141,274 EFC:$3,410,000 GIH W/ WASH PIPE. 13~3/8,@~2977,'~.~,MW:~0~2 VIS.: 42~ :..~:~ ~.--.= =: ....... PIPE STUCK @ 3780'. FREE @-3~74'-. -MADE XO IN FISHING ASS'Y. CBU .... POH. MA~D~..CO.NDITXQNING.~I~=-.~.:. ..... WITH BIT. PU WASHOVER ASS'~f;---GIH-..CIRC WH!L~MU~ STRIN~ SHOT. PREP TO TAG TOF.- DAILY:S33,368 CUM:$1,174,642 ETD:S1,174,642 EFC:$3,410,000 CIRCULATE 13-3/8"@ 2977' MW:10.2 VIS: 42 GIH AND WO FISH TO 3896'. POH AND PU SCREW-IN ASS'Y. HOLE TO STICKY TO FISH. POH AND LD FISHING TOOLS. GIH OPEN ENDED. SPOT KICK-OFF PLUG F/ 3763'-3260'. POH TO CSG SHOE AND REV CIRC. RD HOWCO. DAILY:S74,503 CUM:$1,249,145 ETD:S1,249,145 EFC:$3,410,000 The above is correct For form preparation and j~ri~ution L~ see Procedures Manual S~lc,,t.~on 10. ~ Drilling, Pages 86 and 87 AR3B-459-2-B INumber all dally well history forms consecutively rPags no. as they are prepared for each well. ARCO O,, and Gas Company (~, Dally Well History--Interim Inltructlons: This form ia used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work perlormed. Number all drill stem tests sequentially. Attach description of ell cores. Work i)erformed by Producing Section will be reported on "lnlsrlm' shaetl until final completion. Report official or representative test on "Final" form. 1) Submit "lnllrlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. BELUGA RIVER TNIT County or Parish IState KENAI I AK Iwe" Itease or Unit A029657 IBRU 214-26 Date and depth as of 8:00 a.m. 08/22/90 (24) TD: 3331'( 71 SUPV:JAT 08/23/90 (25) TD: 3531'( 200 SUPV:RWS 08/24/90 (26) TD: 3780'( 2491 SUPV:RWS 08/25/90 (27) TD: 3780' ( 01 SUPV:RWS 08/26/90 (28) TD: 3975' ( 195 SUPV:RWS 08/27/90 (29) TD: 4200'( 225] SUPV:RWS Complete record for each day while drilling or workover in progress GRACE 158 CHANGING OUT BKA 13-3/8"@ 2977' MW: 9.7 VIS: 40 FPOH W/ CEMENTING STRING. TEST BOPE. WOC. GIH AND WASH FIRM C~T'TO'3290'. WOC. DRILL CMT TO '3331'. 'CBU, POH. "PU KO ASS'Y. DAILY:S326,100 CUM:$1,575,245 ETD:S1,575,245 EFC:$3,410,000 GIH 13-3/8"@ 29~7' MW': 9.6 VIS: 40 PU KO ASS'Y. GIH AND CHECK MWD. POH AND CO PULSER. GIH AND ORIENT BKA. SIDETRACK OFF OF PLUG F/ 3331-3531'. TRIP FOR BHA. DAILY:$44,20~ CUM:$1,619,447 ETD:S1,619,447 EFC:$3,410,000 MU BHA 13-3/8"@ 2977' MW: 9.8 VIS: 39 REAM F/ 3407'-3531'. DYNA DRILLED F/ 3531'-3780'. CBU. POH AND CO BHA. DAILY:S34,542 CUM:$1,653,989 ETD:S1,653,989 EFC:$3,410,000 REAM TO BOTTOM 13-3/8"@ 2977' MW: 9.7 VIS: 39 MAKE UP NEW BHA, CHANGE OUT NB STAB.,PU STEEL DRILL COLLAR AND 3 STAB.,TEST MWD RIH, FILL EVERY 1000',LAY DN 17 SINGLES,RIH TO 3317',KELLY UP,WORK AND REAM TO 3354',UNABLE TO WORK NEW BHA AROUND KICKOFF CORNER, CIRC. AND PUMP PILL, POH W/ BIT #8,RIH WITH NEW ASSY AND BIT #7RR, REAM OUT TO 3780',CIRC BTMS UP,PUMP PILL AND POH,M/U BHA AND TEST MWD, RIH, FILL PIPE EVERY 1000',LAY DN 6 SINGLES,TAG CORNER @ 3361',PU KELLY AND REAM TO BTM DAILY:S33,213 CUM:$1,687,202 ETD:S1,687,202 EFC:$3,410,000 PUMP DRIVE SHAFT OUT-RD 13-3/8"@ 2977' MW:10.0 VIS: 41 WASH AND REAM TO BTM @ 3780',DRLD F/3780-3940',GAS CUT UP,SLIGHT FLOW,CIRC AND WEIGHT UP TO 10.0PPG, MONITOR __ WELL,DRLD F/3940-3975',PULL TO CSG SHOE F/WIPER TRIP,ON TRiP TO SHOE'~'BROKE::TAIL'SHAFT ON':PU~ DRIVE COMPOUND, PULL'PUMP ~' SHAF%~T ;~_,i~0R ~, HOL~ ~"~'! i ?i ~'~~i'.0.'i~; ~ ~:' ~- DOWNTIME"~CHANGE OUT LINERS,BRAKES,RI6 MAINTENANCE, SHAFT SENT TO TRISTATE TO TURN'NEW ONE~EXPECT-TO--B~-RETURNED EARLY AFTERNOON, WELL TAKING FLUID,AM ABLE TO CIRC.,WILL CHARGE PUMP IF NEEDED, DAILY:S29,858 CUM:$1,717,060 ETD:S1,717,060 EFC:$3,410,000 WIPER TRIP TO SHOE 13-3/8"@ 2977' MW:10.0 VIS: 42 RIG DOWN TIME WHILE WAITING ON NEW COMPOUND TAIL SHAFT, CONT. GENERAL RIG MAINT DRESS NEW TAIL SHAFT AND INSTALL SAME,RIH,WASH TO BTM 40',NO TIGHT SPOTS,DRLD F/3975-4133',REAM EACH KELLY TWICE, WELL FLOW, CIRC AND WT UP TO 10.0 PPG, DRLD F/4133-4200',CIRC BTMS UP,NO FLOW, WIPER TRIP TO SHOE,NO TIGHT SPOTR Theaboveiscorrect DAILY:$ZD,~OZ CUM:$i,74Z,'Y4Z ETD:S1,742,742 EFC:$3,410,000 For form pr~ation an~istribution ~ / - / 0 ~ see Proce~res Manual ~tion 10, Drilling, Pages 86 and 87 AR3B-459-2-B lNumber all daily well history forms consecutively [Page no. as they are prepared for each well. ARCO 0,, and Gas Compan, y 0 Dally Well History--Interim Inslmclions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "lnlarlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil string until completion. ...... District Field ARCO ALASKA INC. I County or Parish KENA I Lease or Unit BELUGA RIVER UNIT A029657 Date and depth Complete record for each day while drilling or workover in progress as of e:0o a.m. GRACE 158 Istate AK IWell no. BRU 214-26 08/28/90 (30) TD: 4780' ( 5801 SUPV:RWS 08/29/90 (31) TD: 5071'( 291 SUPV:RWS 08/30/90 (32) TD: 5549'( 478 SUPV:JT 08/31/90 (33) TD: 5860'( 311 SUPV:JT 09/01/90 (34) TD: 6242'( 382 SUPV:JT BB 09/02/90 (35) TD: 6443'( 2011 SUPV:JT BB 09/03/90 (36) TD: 6443'( 0 SUPV:JT BB DRLG 13-3/8"@ 2977' MW:10.0 VIS: 47 RIH F/WIPER TRIP TO SHOE, DRLD F/4200-4417, CBU, POH .~. STD .. SHORT'TRIP,' DRLD F/4417-4635~-'CBU, LOST P~ PRES, CHECK PUMPS & SURF EQUIP, POH LOOKING F/WASHOUT, FOUND F/SURFACE, REPAIR CLUTCH HOSE @ SHOE, RIG DOWNTIME, RIH DRLD F/4638-4780. DAILY:S30,925 CUM:$1,773,667 ETD:S1,773,667 EFC:$3,410,000 DRLG @ 5071 13-3/8"@ 2977' MW:10.0 VIS: 42 DRLD F/4780-4885, REAM EACH KELLY TWICE, CBU, POH F/ BIT & BHA, PULL WEAR BSH & TEST BOPE, PU NEW BIT & BHA, RIH, CUT & SLIP DRLG LINE @ CSG SHOE, ADJUST BRAKES, FRIH, DRLD F/4885-5071, REAM TWICE DAILY:S32,085 CUM:$1,805,752 ETD:S1,805,752 EFC:$3,410,000 BIT TRIP 13-3/8"@ 2977' MW:10.0 VIS: 46 DRLD FROM 5071' TO 5113'. CBU, SHORT TRIP SWABBED SLIGHTLY. DRLD FROM 5113' TO 5329', SHORT TRIP, SWABED SLIGHTLY. DRLD FROM 5329' TO 5549', CBU, TRIP FOR BIT. DAILY:S33,808 CUM:$1,839,560 ETD:S1,839,560 EFC:$3,410,000 DRLG 13-3/8"@ 2977' MW:10.0 VIS: 45 TRIP FOR FAILED MWD, DRLD F/5549-5766, CBU, SHORT TRIP 10 STDS, DRLD F/5766'- 5860' DAILY:S40,185 CUM:$1,879,745 ETD:S1,879,745 EFC:$3,410,000 DRLG 13-3/8"@ 2977' MW: 9.9 VIS: 43 DRLD F/5860-5985, CBU, POH TO SHOE, WORK ON BRAKES, RIH, NO FILL, DRLD 5985- 6235, CBU, SHORT TRIP 10 STDS, DRLD F/6235-6242. DAILY:S85,038 CUM:$1,964,783 ETD:S1,964,78'3 EFC:$3,410,000 · . . POH TO LOG 13-3/8"@ 2977' MW: 9.9 VIS: 41 DRLD F/62.42~-6298, REPLACE B~LOWN:..KE~T~Y~HOSE, DRLD ....... ' ...... - ........... F/6298-f3~43~ - TD=6443' , CBU $~P~IP~..10.-.STDS.~.~CBU~'"~.TR'[P' t0 ................. STDS,-CBU,-DROP SURVEY', PUMP PILL~ POH, SLM, PREPARE TO DAILY:S51,047 CUM:$2,015,830 ETD.' $2, 015, 830 EFC:$3,410,000 POH 13-3/8"@ 2977' MW: 9.9 VIS: 41 RETRIEVE SURVEY, LD MWD & NMDC, SLM (NO CORR), LOGGING 12.25 HOLE W/WESTERN ATLAS, RIH, C&S DRLG LINE, RIH (BREAKING CIRC 3 TIMES), CIRC, POH TO CONTINUE LOGGING DAILY:S27,121 CUM:$2,042,951 ETD:S2,042,951 EFC:$3,410,000 The above is correct I/~/1~ ~'~ For form preparati .... d ~,rbution see Procedures Manual SeCff~n 10, Drilling, Pages 86 and 87 I Number all daily well history torms consecutively IPage no. as they are prepared for each well. AR3B-459-2-B . .. ; ARCO O. and Gas Compan, y Daily Well History--Interim Inat~uctiona: This form ia used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil airing ia set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ARCO ALASKA INC. I KENAI I Field ~Lease or Unit BELUGA RIVER UNIT I A029657 Complete record for each day while drilling or workover in progress GRACE 158 Date and depth as of 8:00 a.m. 09/04/90 (37) TD: 6443'( SUPV:JT BB 09/05/90 (38) TD: 6443'( SUPV:JT BB 09/06/90 (39) TD: 6443'( SUPV:TA 09/07/90 (40) TD: 6443 PB: 0 SUPV:TA 09/08/90 (41) TD: 6443 PB: 0 SUPV:TA 09/09/90 (42) TD: 6443 PB: 6353 SUPV:TA 09/10/90 (43) TD: 6443 PB: 6353 SUPV:TA AK IWell no. BRU 214-26 CIRC 13-3/8"@ 2977' MW: 9.9 VIS: 44 POH, LOG W/ ATLAS, RIH BREAKING CIRC 3 TIMES, CIRC BACKING OFF MW~O.~..7.. DAILY:$22,-1~6 CUM:$2,065,087 ETD:S2,065,087 EFC:$3,410,000 LOGGING 13-3/8"@ 2977' MW: 9.7 VIS: 35 CIRC & REDUCING MUD WT TO 9.7, WO HLS PARTS, POH, TEST BOPE, LOG & CORE W/HLS DAILY:S24,593 CUM:$2,089,680 ETD:S2,089,680 EFC:$3,410,000 DRILLING 9-5/8" CSG 9-5/8"@ 6442' MW: 9.7 VIS: 37 FINISH RUN #2 & #3 SIDEWALL CORES, RD LOGGERS, RIH TO SHOE & CIRC, CUT DRLG LINE, FINISH RIH, BREAK CIRC TWICE, WASH 2' TO BTM, CIRC & COND MUD TO RUN 9-5/8" PIPE, POOH, LD 12-1/4" BHA & 8" DC, PULL WEAR RING, SET TEST PLUG, CHANGE RAMS & TEST TO 3000 PSI, RU CASERS, RUNNING 9-5/8" CSG. DAILY:S169,722 CUM:$2,259,402 ETD:S2,259,402 EFC:$3,410,000 ND BOPE TO SET TBG HEAD 9-5/8"@ 6442' MW: 0.0 FRIH W/9-5/8" CSG, RAN 148 JTS 9-5/8" 43.5# S-95 BTC CSG W/FS, FC, & 48 CENTRALIZERS, WASH 6' TO BTM & CIRC & COND MUD, RU HOWCO & CEMENT W/2052 SXS CLASS G, BUMPED PLUG @ 2140 9/6/90 W/3000PSI, HELD OK, PIPE SET @6442', FC @ 6353', PU STACK, SET SLIPS W/PIPE IN FULL TENSION, CUT OFF, ND TO SET TBG HD DAILY:S140,968 CUM:$2,400,370 ETD:S2,711,060 EFC:$3,099,310 CLEANING PITS 9-5/8"@ 6442' MW: 9.7 WBM INSTALLED TBG SPOOL. NU BOP STACK AND TEST BOPE. GIH AND TAG TOC @ 6349'. CLEANED OUT TO FC @ 6353'. CBU. CLEAN MUD TANKS. DAILY: $122,329 CUM: $2,52"F, 699 ~ ETD :~2;'522~;~699 ~'EFC r$~41'0 ~'000 .......... MIXING BRINE -~.9.-5/8"~. 644~'.... CLEANING MUD TANKS AND DEWATERING:/IRILLING' MLTD'..:'-MI~XING ..... -'-' ...... ~" .~ · BRINE AS VOLUME IS AVAILABLE-.. DAILY:S21,848 CUM:$2,544,547 ETD:S2,544,547 EFC:$3,410,000 MW: 9.7 NaCl DISPLACE HOLE WITH FILTERING BRINE 9-5/8"@ 6442' FINISH CLEANING TANKS AND MIXING BRINE. BRINE. CIRC AND FILTER BRINE. DAILY:S43,360 CUM:$2,587,907 ETD:S2,587,907 EFC:$3,410,000 The above is correct Signature ~ IDate I T~ i -~ ~ i-- Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO O. and Gas Compan, y Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describin,~ work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim' Iheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil string unlll completion. District i ICounty or Parish IState ARCO ALASKA INC. I KENAI Field ILease or Unit BELUGA RIVER JNIT I A029657 Complete record for each day while drilling or workover in progress GRACE 158 Date and depth as of 8:00 a.m. 09/11/90 (44) TD: 6443 PB: 6353 SUPV:TA 09/12/90 (45) TD: 6443 PB: 6353 SUPV:TA 09/13/90 (46) TD: 6443 PB: 6353 SUPV:JT 09/14/90 (47) TD: 6443 PB: 6353 SUPV:JT 09/15/90 (48) TD: 6443 PB: 6353 SUPV:JT AK IWell no, BRU 214-26 RU ATLAS 9-5/8"@ 6442' MW: 9.7 NaCl FINISHED. FILTERING BRINE. --POH AND RU ATLAS FOR CASED.HOLE LOGS. ~'~.' ~.:-' ]~:'~. :..:.'f ~.'.~, "~,.'.,. :'i' l.;~;h~; DAILY:S20,212 CUM:$2,608,119 ETD:S2,608,119 EFC:$3,410,000 PU TEST STRING .9~5~8"@ 6442' LOGGED CASED HOLE WITH CBL, GYRO AND VELOCITY SURVEY. GIH 3-1/2" TEST STRING. DAILY:S32,055 CUM:$2,640,174 ETD:S2,640,174 EFC:$3,410,000 CORR DEPTH WITH AWS 9-5/8"@ 6442' MW: 9.7 NaCl RUN 3-1/2" TBG, RD CSG TOOLS, TEST CSG TO 3000 PSI, CIRC, POH, PU & MU TEST ASSY, RIH W/ 3-1/2" TBG TO 6107', CHANGE OUT BAILS, RU LUBRICATOR, RU AWS TO CORRELATE DEPTHS. DAILY:S94,853 CUM:$2,735,027 ETD:S2,735,027 EFC:$3,410,000 CIRC WELL 9-5/8"@ 6442' MW: 9.7 NaCl CORR LOG, SET PKR, RERUN CORR. LOG, RIG UP TEST EQUIP, SAFETY MTG, PRESS TEST EQUIP, FILL TBG W/NACL, DROP PERF BAR, PI~1902 SAW PRESS DECREASE TO 1835 PSI PF-1896, BLED PRESS TO 1600 IN 15 MIN, HELD FOR ONE HOUR, NO BUILDUP, BLED TO 1300, HELD FOR ONE HOUR, NO BUILDUP, BLED TO 1000, HELD 30 MIN, NO BUILDUP, BLED TBG TO 0, CLOSED LPR-N VALVE, SHUT IN WELL, RU LOGGERS TO RIH & CHECK IF DROP BAR IS ON TOP OF LPR-N, NO INDICATION OF BAR STUCK IN STRING OR ON LPR-N VALVE, POH W/LOGGERS, OPENED LPR-N , PI-29 PSI, PF-49 PSI, PSTAB-49 PSI, OPEN UP OMNI VALVE AND CIRC 9.7 BRINE INSIDE & OUT OF TBG, CLOSED OMNI VALVE, RU SL UNIT W/BAR RETRIEVING TOOL. OPEN LPR-N ~ALVE, .ATT.F~U~ TO.RETRIEVE..BAR TO ENSURE GUNS WOULD NOT FIRE W/POH W/TEST'-STRING, 2 ATTEMPTS COULD NOT LATCH W/OVERSHOT,"RAN IMPRESSIONBLOCK, DEFINITE INDICATION THAT LP~K-N.~ALVE_IS. IN_/CLOSED..POSITION' WHEN PRESS ON ANNULUS SHOUIZ~%[AVE~V~LVE'IN'OPEN POSITION .... PREPARING TO UNSEAT PKR, CHECK FOR PRESENCE OF GAS & POH. DAILY:S17,412 CUM:$2,752,439 ETD:S2,752,439 EFC:$3,410,000 RIH W/BP 9-5/8"@ 6442' MW: 9.7 NaC1 UNSEAT RTTS, REV CIRC, SET RTTS, RU & RUN SLICK LINE, RETRIEVE SHOT BAR, ALL INDICATIONS OF GOOD PERF SHOTS, UNSEAT PKR & CIRC, POH W/3.5" TBG, LD TEST TOOLS (ALL PERFSHOTS VERIFIED), RIH & POH LD HWDP, CO 3 1/2" TO 4 1/2" RAMS & PT BOPE, PU 30 JTS 4 1/2" OFF WALK. PU BP & RIH DAILY:S15,965 CUM:$2,768,404 ETD:S2,768,404 EFC:$3,410,000 The above is correct Signature ~ ~ For form preparation an[F~stribution ~ see Procedures Manual 5'~'ction 10, ~ Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well hislory forms consecutively ~Page no. as they are prepared for each well. 1 ARCO Oil and Gas Comparw () Dally Well History--Interim Inatmctlons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" shasta until final completion. Report official or representative test on "Final" form. 1) Submit "lnterlllt" sheets when filled out but not less frequently than every 30 daya, or (2) on Wednesday Of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. District Field I County or Parish lStale ARCO ALASKA INC. I KENAI I AK ILease or Unit IWell no. BELUGA RIVER UNIT J A029657 IBRU 214-26 Date and depth as of 8:00 a.m. 09/16/90 (49) TD: 6443 PB: 6353 SUPV:JT 09/17/90 (50) TD: 6443 PB: 6353 SUPV:JT 09/18/90 (51) TD: 6443 PB: 5990 SUPV:JT 09/19/90 (52) TD: 6443 PB: 5990 SUPV:JT Complete record for each day while drilling or workover in progress GRACE 158 DST #2 ' 9-5/8"@ 6442' MW: 9.7 NaCl FRIH TO 6050~, SET RETAINER, UNLATCH FROM RETAINER-& R]~V ' - .- · CIRC, SAFETY=MTG, RU HOWC~,--PT LINES TO 4000 PSI, STING INTO RETAINER;'-'PUT 1000 PSI ON BACKSIDE, EST.~' FORMAT{ON BREAKDOWN AT 2000 SPI, GAMMA F-.85, PUMPED 20 BBL H20 PREFLUSH 10 BBL CMT BELOW RETAINER, 5 BBL CMT ABOVE RETAINER, 20 BBL H20 TAIL, REV CIRC FILTER BRINE 1/2 BBL CMT RETURNS, TEST BAKER K-1 RETAINER & CSG TO 3000 PSI, POOH CHAIN OUT LD TOOLS, CO RAMS & PT TO 3000 PSI, PU TEST HEAD, CO LUBRICATOR PU TEST TOOLS #2, RIH W/3-1/2" TBG, SET RTTS @ 5487. RU LOGGERS & SURF TEST EQUIP, HELD SAFETY MEETING, TESTED SURF EQUIP TO 2500 PSI, RIH W/ WIRELINE GR, CCL, 14' OF 4 SPF STRIP GUNS. DAILY:S38,891 CUM:$2,807,295 ETD:$2~807,295 EFC:$3,410,000 POH W/ WL 9-5/8"@ 6442' MW: 9.7 NaCl ATTEMP TO WORK 2 1/8" STRIP PERFGUNS THROUGH DST ASSY, NO GO, RUN 2" DUMMY GUN TO 5450', ONE TIGHT SPOT RIH THREE TIGHT SPOT POH, RUN 1-11/16" GR, CCL TO 5900'. FOUR TRIAL RUNS W/TIGHT SPOTS IN RTTS @ 5480, RUN 2" DUMMY GUN TO 6000, ONE TIGHT SPOT RIH, THREE TIGHT SPOTS POH, WAIT ON 1-11/16" GUNS, MU & RIH W/ 1-11/16" STRIP GUNS, PRESS TBG W/1750 WHILE RIH, OPEN LPR-N W/1500 PSI, TIE IN PERFS. POH W/GUNS, NO FIRE, RU AWS & RIH W/ ALTERNATE FIREING HEAD, CABLE STRANDED WHEN IN HOLE @ 5490', POH W/WL. DAILY:S66,600 CUM:$2,873,895 ETD:S2,873,895 EFC:$3,410,000 FLOWING TEST WELL 9-5/8"@ 6442' MW: 9.7 NaCl REPAIR WIRELINE & DRESS PERF GUNS, PERF 9-5/8" CSG F/5796'-5810', GUNS FIRED @ 1134 HRS, BLEED N2 F/TBG, MONITOR PSI ON TBG, CLOSE LPR-N VALVE, ANN PRESS TO 0, MONITOR WELL, RIH W/PERFGUNS,'OPEN LPR-N VALVE, PRESS ON ANN - To 150~ ~lST RUN F/Se~'~0':~t",~.~P~,"'R~H'W/ 2ND PER~C~UNS, PERF 9-5/8"~-------'--F/~-~--@--O~Og-, LOGGERS, FLOW TEST WELL, GAS @'SURFACE 05/5. RRS. 890 PSI STABILIZED PRESS,-FLARTNG'APPROX FLUID THRU 6/64" CHOKE. DAILY:S20,735 CUM:$2,894,630 ETD:S2,894,630 EFC:$3,410,000 LD DST #2 9-5/8"@ 6442' MW: 9.7 NaCl FLOW TEST WELL THRU SEPERATOR, BLEED OFF ANN PRESS (CLOSE LPR-N), SIW, CYCLE OMNI VALVE, BLEED TBG TO SEPERATOR, CYCLE OMNI VALVE, OPEN CIRC PORTS, CLOSE BALL VALVE, REV CIRC TO SEPERATOR TILL FLUID RETURNS, SWITCH OVER TO DEGASSER AND CIRC ONE TBG VOL, RD TEST MANIFOLD ON FLOOR, PULL PKR LOOSE, CIRC DN TBG STRING TAKING RETURNS THRU DEGASSER UNTIL ALL GAS HAS MIGRATED UP. POH WITH 3-1/2" TBG, LD TEST TOOLS. DAILY:S50,522 CUM:$2,945,152 ETD:S2,945,152 EFC:$3o410,000 The above ,~correct IDate Drilling, Pages 86 and 87' :.~ I Number all daily well history forms consecutively jlPage no, J as they are prepared for each well. ...' . ..... ·., ... /.., AR3B-459-2-B .~' .~."=..,,.~ ,,.'.-~'...~.~..-:.~.~...-.:-,....*. ~,. ,.?...,~.,-,%-~.,.,-,,.'.~?~-~.,,~. ~.-~ ~.,~,..:...~.? ~.~,..,.~.-..:..~. :,~ .,:...~;. ~..-~ ~ . ,.. .,.,.,...~-.~.. ,...... ,~..., ... .-~ .~, , . ~ .- , ~. , ., .. ..... '. ARCO Oil and Gas Company (~, Dally Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name In describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil strin§ unlil completion. District ICounty or Parish Jsta,e ARCO ALASKA INC. KENAI AK Field Lease or Unit no. BELUGA RIVER UNIT A029657 I BRU 214-26 Date and deptr~ as of 8:00 a.m. 09/20/90 (53) TD: 6443 PB: 5990 SUPV:RWS 09/21/90 (54) TD: 6443 PB: 5990 SUPV:RWS 09/22/90 (55) TD: 6443 PB: 5990 SUPV:RWS 09/23/90 (56) TD: 6443 PB: 5990 SUPV:RWS 09/24/90 (57) TD: 6443 PB: 5990 SUPV:RWS 09/25/90 (58) TD: 6443 PB: 5990 SUPV:RWS 09/26/90 (59) TD: 6443 PB= 5990 SUPV:RWS 'The above is correct Signatur~ ~ For form preparation and~tribution see Procedures Manual SLoe, ion 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress GRACE 158 POH 9-5/8"@ 6442' MW: 9.7 NaCl _ _ LD DST-TOO~S...- GIH W/ 9-5/8-~-RETAINER. SET .~ 3207'.. "TEST ..... . ._ RETAINER :TO.'2000 PSI. OK. RU AWS AND.'P~RFORATE F/3188,~'=-~1~2~ @ 4 SPF. GZH"N/ 2-?~8" STINGER. SPOT 100 SK BALANCED PLUG AND POH 4 STDS. SI WELL AND SQUEEZE 16 BBLS CMT INTO PERFS. HELD 1300 PSI WHILE WOC. POH FOR DRILLING ASS'Y. DAILY:S133,371 CUM:$3,078,523 ETD:S3,078,523 EFC:$3,410,000 TESTING SQZ PERFS 9-5/8"@ 6442' MW: 9.7 NaCl CLEAN OUT CMT TO RETAINER AND ATT TO TEST SQZ PERES TO 2000 PSI. NO GOOD. TRIP FOR STINGER AND SPOT 50 SX CLASS 'G' ON RETAINER. POH 4 STDS AND SQZ. WOULD HOLD 3000 PSI. HOLD 3000 PSI WHILE WOC. TRIP FOR BHA AND CLEAN OUT. DRILLED HARD CMT TO RETAINER. TESTED SQZ PERES TO 2000 PSI OK. DAILY:S70,718 CUM:$3,149,241 ETD:S3,149,241 EFC:$3,410,000 GIH W/ 3-1/2" TUBING 9-5/8"@ 6442' MW: 9.7 NaCl DRILLED RETAINER AND PUSH TO BOTTOM. CIRC OUT GAS. POH. RU AWS AND LOG W/ CBL. GIH W/ 3-1/2" TUBING. POH LAYING DOWN AND INSPECTING TUBING. DAILY:S17,412 CUM:$3,166,653 ETD:S3,166,653 EFC:$3,410,000 PREPARE TO PU PERE GUNS 9-5/8"@ 6442' MW: 9.3 NaC1 GIH W/ CSG SCRAPER ON 3-1/2" CS HYDRIL TUBING. CIRC AND FILTER BRINE ADDING 2% KCL. CUT WEIGHT TO 9.3+ PPG. POH AND LD 3-1/2" TUBING. PREP TO PU PERE GUNS. DAILY:S41,361 CUM:$3,208,014 ETD:S3,208,014 EFC:$3,410,000 GIH W/ PERF GUNS 9-5/8"@ 6442' MW: 9.3 NaCl RU TO RUN PERF; GUNS. PU ASS!X--AND PKR---AND-GIH-W/--DP.,--RU .................... AWS AND-~CORRELATE GUNS ON BE~TH~.-SET.~KR-AND .DROP BAR 'TO ~ FIRE GUNny' MONITOR WELL. REV CIRC I DP VOLUME. POH. ALL SHOTS FIRED. LD GUNS. MU/PERF' GUN ASS"~ #ZJ:~:- ~ : ; .' ;~:.' '- .:.:- ~ .~ :; .... DAILY:S22,686 CUM:$3,230,700 ETD:S3,230,700 EFC:$3,410,000 · GIH w~-CS~ SCRAPER 9-5/8"@ 6442' MW: 9.2 NaC1 GIH W/ PERF GUNS ON DP. RU AWS AND CORRELATE GUNS ON DEPTH. SET PKR. DROP BAR AND FIRE GUNS. LOSING FLUID @ 60 BPH. MIX LCM PILL AND P~ SAME. POH W/ PERF GUNS. GIH W/ 8-1/2" BIT AND CSG SCRAPER. LOSING 1-2 BPH. DAILY:S124,601 CUM:$3,355,301 ETD:$3,355,301 EFC:$3,410,000 LD DRILL PIPE 9-5/8"@ 6442' MW: 9.3 NaCl FGIH W/ CSG SCRAPER. POH. RU TO RUN BLAST JOINTS AND TUBING. PU TAIL ASS'Y AND MODEL DB PACKER. GIH ON DP AND SET PKR @ 3621'. POH AND LD DP. · AR3B-459-2-B JNumber all dally well history forms consecutively JPage no. as they are prepared for each well. ARCO O~ and Gas Compaqy Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlel'lm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit 'Interim" sheets when filled out but not less frequently then every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting o! oil string until completion. / . District Date and dept~ as of 8:00 a.m. I County or Parish ARCO ALASKA INC. KENAI Field Lease or Unit BELUGA RIVER ~NIT A029657 Complete record for each day while driJling or workover in progress GRACE 158 09/27/90 (60) TD: 6443 PB: 5990 SUPV:JAT 09/28/90 (61) TD: 6443 PB: 5990 SUPV:JAT 09/29/90 (62) TD: 6443 PB: 6014 SUPV:JT 09/30/90 (63) TD: 6443 PB: 6014 SUPV:JT 10/01/90 (64) TD: 6443 PB: 6014 SUPV:JT 10/02/90 (65) TD: 6443 PB: 6014 SUPV:JT 10/03/90 (66) TD: 6443 PB: 6014 SUPV:JT State AK RUNNING COMPLETION 9-5/8"@ 6442' MW: 9.3 NaCl FPOH ANDLD DP. LD DC'S. RU TO RUN DUAL COMPLETION. RUN LS TO DUAL PACKER. PU DUAL PACKER AND RUN BOTH STRINGS SIMULTANEOUS LY. - ~ DAILY:S75,782 CUM:$3,727,956 ETD:S3,727,956 EFC:$3,410,000 GIH W/ DUAL COMPLETION 9-5/8"@ 6442' MW: 9.3 NaCl FIN RUNNING-DUAL TUBING STRINGS. RU SLICKLINE AND ATT TO SET PLUG IN 3-1/2" XN NIPPLE. WOULD NOT GO THROUGH SS CONNECTOR TO PKR. POH W/ DUAL COMPLETION AND CO CONNECTOR ON SS. GIH W/ DUAL COMPLETION. DAILY:S79,949 CUM:$3,807,905 ETD:S3,807,905 EFC:$3,410,000 PREPARING TO RUN 1.9" STRING 9-5/8"@ 6442' MW: 9.3 NaCl RIH W/DUAL STRING AND TAG 'D' PKR, RU SLICK LINE AND RUN GAUGE RING, RUN 3-1/2" PX PLUG, WRONG SIZE, RUN 2-7/8" GAUGE RING AND 2-7/8" PX PLUG TO 3580',SET PLUG, SPACE OUT HANGER, COULD NOT SET TBG IN TBG HEAD, RE-SPACE OUT AND LAND HANGER IN TUBING HEAD, LOCKDOWN TUBING HANGER IN TUBING HEAD, RD FLOOR OF CSA EQUIPMENT DAILY:S16,995 CUM:$3,824,900 ETD:S3,824,900 EFC:$3,410,000 CLEANING PITS 9-5/8"@ 6442' MW: 9.3 NaC1 RIH W/1.9" HEATER STRING, LAND SAME, SET BPV IN BOTH STRINGS,ND BOPE,NU TREE, SET PX PLUGS IN X NIPPLES,TEST TREE, PULL PLUGS,SET PKR, SHEAR OUT BALL, TEST BACKSIDE, RESET PLUGS IN X PROFILE,RESET BPVS,CLEANING PITS DAILY:S37,169 CUM:$3,862,069 ETD:S3,862,069 EFC:$3,410,000 DEMOB RIG 9-5/8"@ 6442' MW: 9.3 NaCl CLEANING PITS AND RIGGING DOWN, RIG RELEASED 1800 HRS 9-30-90,~OVING RIG TO BRU 232-26 DAILY:S250,743 CUM:$4,112,812 ETD:S4,112,812 EFC:$3,410,000 DEMOB 9-5/8"@ 6442' MW: 9.3 NaCl DEMOB RIG, BARGE EQUIPMENT TO KENAI DAILY: $12,660 DEMOB RIG DAILY: $24,654 Well no. BRU 214-26 CUM:$4,125,472 ETD:S4,125,472 EFC:$3,410,000 9-5/8"@ 6442' MW: 9.3 NaCl CUM:$4,150,126 ETD:S4,150,126 EFC:$3,410,000 The above is correct Signature ~ ~ For form preparation and dis/~['~bution _~ see Procedures Manual Sect~ 10, Drilling, Pages 86 and 87 J Number all daily well history forms conseculively IPage no. as they ere prepared for each well. I .. , . . _ .-.:..... AR3B-459-2-B . . .. , ARCO i and Gas Company Dally Well History-Final Report InllrUctiOlll: Prepare and submit the "Final Report" on tho flint Wedneldly alter allowable hal bean alllgned or wall II Plugged, Abandoned, or 8old. "Final Report" should be submitted Silo when operetlonl are lUll)ended for in Indefinite or appreciable length of time. On WOl'kOv~re when In official tilt II required upon completion, report completion and reprelentitlve tilt data in blockl provided. The "Flail Rigors" form may bi ulld for reporting the entirt operation if spice ia available. Aooountlng OOlt oanter oode District ICounty or Parish Stats ARCO ALASKA INC. I KENAI AK Fie~d Lease or Unit BELUGA RIVER UNIT A029657 rTitle DRILLING, EVALUATE, COMPLETE Auth. or W.O. no. AD6811 Operator /LRCO Well no. BRU 214-26 Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 10/04/90 (67) TD: 6443 PB: 6014 SUPV:RWS A.R.Co. W.I. 33,3333 IOate 07/31/90 Complete record for each day reported GRACE 158 Iotalnumber of wells (active or inactive) on this t est center prior to plugging and bandonment of this well I our I Prior status If a W.O. I 18:00 CONTINUE DEMOB 9-5/8"@ 6442' MW: 9.3 NaCl CONTINUE DEMOB, PULLED 2-7/8" X 3-1/2" BPV & DUMMY VALVE @ 3103', DISPLACE BRINE IN WELL WITH DIESEL, REPLACE DUMMY GLV @ 3103', SECURE WELL DAILY:S10,715 CUM:$4,160,841 ETD:S4,160,841 EFC:$3,410,000 OIdTD I New TD [P8 Depth Rel drig .... JOate JKInd of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method IOfflclal reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on teat Gas per day Pump size, SPM X length Chok'e size T.P. C.P. Water % GOR I Gravlty Allowable Effective date ' ' ! corrected The above is correct For form preparation alll;~liatribution, ~ ~/' / (.J U see Procedures Manuar~,~ection 10, Drilling, Pages 86 and 87. · ~' AR3B-459-3-C · '~ Number all dally well history forms consecutively as they are prepared for each well. iPage no. DlvlMo~ o! AtlantlcRIchfieldCompany. COMPLET~O~ OATE ,~ /~, ~ ~ CO~ CONTACT Zq,'~ ~ ~ check off or list data as it is received.*list received date for 401. if not_,r~'_ ejuircd list as NR. '"401 i*///,,.."/~'.' I driliin! historY' I ~"i' survey! ..... /! well tests l~ core descriptiod' ? cored intervals core analysis !/v~ dr)/ditch inle~als di§ital data .r';.~,.,,./t ~. ¢.~, ...... , , , ¢/¢'~ ~- <' NO. (to thc nearest foot I v · ' ' ( . ~ ................. i41 ' i"O ....... ~ , I I ARCO AI~SKA INC. Cook Inlet~ew Ventures Engineering ~52 TRANSMISSION TO:. Commissioner FROM: Scott Jepsen COMPANY: A~ COMPANY: ARCO Alaska, Inc DATE: 10/19/90 WEl~l~ NAME: listed below I II Transmitted herewith are the following Blue Sepia Sepia Fape & Line Folded Rolled Mylar listing Directional Survey BRU 214-26 Directional Survey SCU 32A-9 Receipt Acknowledgement: Date: Return reciept to ARCO AI.~SKA, Inc. ATYN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' ARCO ALASKA INC. Cook Inlet/New Ventures Engineering g444 TRANSMISSION TO:. Commissioner COMPANY: AOGCC DATE: 10/8/90 FROM: Scott Jepsen COMPANY: ARCO Alaska, Inc WEIJ~ NAME: Listed below Transmitted herewith are the following Biue Sepia Sepia rape & Line Folded!Rolled ,Mylar listin~ BRU 214-26 DUAL INDUCT FOC L 1 1 ' DUAL LATERAL 1 1 ACOUSTIC CEMENT BOND 1 1 , , MINILOG GR 1 1 GAMMA RAY 9/24 1 1 ' ' GAMMA RAY 9/23 ........ 1 "1 ' ' Z-'DENS, COMP NEU' '1 1 "' ..... ACOUSTiJC~ cEMENT BOND 1 1 ' !SCU 32~}-9 SEG BOND GR '" 1 1 ' Z'DElqS CAMP NEU 1 "1 " ........... DUAL IND FOCUSED 1 1 ' SRU 21A-34 NEUTRONGR ' 1 1 " ' INDUCT GR 1 1 , GR 1 1 s C ~ "~ ~ '- ~ 'mg ~ ~ o. , ~ ~ . .-4t- ¢c,, ~. ~ ...... ~ a v .x l ,~.-.'-~d g ~'e_ ~ I co c~ " , ._.~.. , ~ _ " , , , , Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 . Anchorage, AK 99510-0360' RECEIVED Date: OCT 1 0 1990 ~l~l A Gms Corm, Comml,~,lon ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 30, 1990 Subject: BRU 214-26 Permit to Drill Beluga River Gas Field Attention' Russ Douglas Dear Russ: I believe Aden Seidlitz has contacted the AOGCC concerning the BLM's decision on the diverter issue and the change in the diverter schematic from what was in the Application for Permit to Drill. An original copy is included for your records. If all goes according to plan, the well will be spud Monday night or Tuesday. If I can provide any additional information concerning BRU 214-26, please feel free to call me at 265-1544 . A. W. McBride - ATO 1448 L. L. Brown -ATO 1976B File /4/aska Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 26, 1990 Subject: BRU 214-26 Permit to Drill Beluga River Gas Field Attention: Aden Seidlitz Dear Aden: Please find the attached copy of the diverter schematic for the BRU 214-26. Thank you for your help in resolving the discrepency in the Application for Permit to Drill and the Plan of Operation. If all goes according to plan, the well will be spud Monday night or Tuesday. If I can provide any additional information concerning BRU 214-26, please feel free to call me at 265-1544 . WeDiir i i~i.n gC r aEnneg i n e e r~~,O A. W. McBride - ATO 1448 L. L. Brown -ATO 1976B Russ Douglas- AOGCC File GRACE 158 BRU 214-26 DiVERTER SCHEMATIC 5 3 '1 4 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTEN/~NGE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 30" CONDUCTOR 2. SWAGE TO 20" - 2000 PSI FLANGE 3. DIVERTER SPOOL 4. 10" HCR BALL VALVES WITH SINGLE10" DIVERTER LINE TO DIVERTER PIT 5. 20" - 2000 PSI ANNULAR PREVENTER - HYDRIL MSP Dear Mike: Diagram #1 nearby facilities, The full sized schematic should be in your copy of the Plan of Operation, shows the proposed well in relation to the other Diagram #2 shows the area close to the proposed well on a 1"=50' scale. Diagram #3 shows approximate layout of the rig equipment customized for this particular location. Diagram #4 shows the rig layout on the location schematic. Notice the diverter pit on the East side of location. Original plans were to have a single line to this pit. Diagram #$ shows the only reasonable location for a second diverter pit and line, This second pit would require +/- 150' additional diverter line (10") and would be very difficult to get 100' from an ignition source, (the rig's power packages, boilers etc.) Therefore the original proposal indicated that there would be but a single diverter pit and therefore a single diverter line. The Application for Permit to Drill included a diverter schematic showing 2 lines which is not what was intended. I am trying to alleviate confusion that the contradictory information in the Plan of Operation and in the Permit to Drill may cause. We still think it best to use but a single diverter pit and line on this particular location. When you get a chance to look over these diagrams, give me a call at 26~~544 and we can discuss the situation. Thanks. 06161g 0361A3~11 m..t, ON ,% ... ~3~ ... ,O~: ~Inos S]3Ul VS~'338 ? ///////~// / t" s33a · 9N I U'V 3"1~) 0 'f;~1 9NIJ. SIX 3 ~3B~? J. N31AI3/',O~ iai t HiNOS ' "- ' POct P~6¢I 8];C9--~9~-606 :ON 731 ~NI-I-II~t]/AN/I3>?I~>t :CI 8]; :P~ 06 ,-c,~.--II]£' I D: KR~J~C I/NU~DR ILL I NG TEL NO: 907-265~6218 ~9~4 P05 RIG HEADING = N 31 E Div PI! ',,., 8T~c_~::~9~-,',ia6 :ON -13± BNI-I-II~IG/£~N/ID~'I~>t 06, -SC-']ni' ...................................... ' CL, EARINO '- LIMITS J~ '""., ! D: KRU/C I/NU/DR ILL I NG TEL NO: 907-~65-6~1~ iMPROVEMENT Z~RE~ ~ ll ............. m % i, 155 N.)RT,'i BRU 2.14 -26 WELL Sc'urN :4 · ~E~ / EXISTING · .~~ ,{c CLEARIN( ~. ~ ~.,... ,. ',1~ L IMI T.{ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 26, 1990 Mr. M. Minder State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mike: Subject: BRU 214-26 Permit to Drill Beluga River Gas Field I have adjusted the well bore schematic for the subject well to reflect the top of cement in the 13-3/8" surface casing by 9-5/8" production casing annulus to be at 2000' MD. The 1700 sacks of 'G' cement that is in the permit now will provide this volume plus about 50% excess of the open hole volume. This change should cover the concerns we discussed in our meeting of 3-23-90. If I can provide any additional information concerning BRU 214-26, please feel lree to call me at 265-1544. -'Sr. ~r cc P.J. Archey - ATO 1448 L. L. Brown - ATO 1976B File R [?.C£1 V£D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) Alaska, Inc. for an order ) granting an exception to ) the spacing requirements ) of Title 20, AAC 25.055 ) to permit the drilling of ) the Beluga River Unit ) 214-26. ) Conservation Order No. 251 Beluga River Field Beluga River Gas Pool, undefined. May 1, 1990 IT APPEARING THAT: · ARCO Alaska, .Inc. operator of the Beluga River Unit, submitted an application, dated April 2, 1990 request- ing an exception to 20 AAC 25.055 to permit the drill- ing of the Beluga River Unit (BRU) well 214-26. · Notice of the application was published in the Anchorage Daily News on April 6, 1990. 3. No protests to the application were received. FINDINGS: · ARCO Alaska, Inc. proposes to drill the BRU 214-26 from a surface location 295' from the west line, and 930' from the south line of section 26, T13N, R10W, Seward Meridian to a bottom hole location 1573' from the west line and 1400' from the south line of section 26, T13N, R10W, Seward Meridian. · An exception to 20 AAC 25. 055(a)(2) and (4) is neces- sary. 3. Offset operator/owners have been notified. · Drilling the well on a nominal 320 acre spacing in the Beluga River Gas Field will enhance recovery. The drilling of a well closer than 1500 feet to a drilling unit boundary in the Beluga River Unit and at a distance of less than 3000 feet from an existing well will not effect correlative rights. CONCLUSIONS: The requested exception will not create wa'ste-.-an.d~_tt~e- correlative rights of all owners are protected· .......... ~ .... BRU 214-26 Proposed Well Bore Schematic ~ 20" Conductor @ 90' Anticipated TOC=2000' 13-3/8" Surface Csg @ 2900' TVD, 2985' MD cement pBD = +/- 6200~ 9-5/8" Production Csg @ 6148' TVD, 6325' MD May 8, 1990 Telecopy~ (907)276-7542 P. J, Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Beluga River Unit 214-26 ARCO Alaska, Inc. Permit No. 90-42 Sur. Loc. 2.95'F~,~, 930'FSL, Sec. 26, T13N, R10W, SM. Btmhole Loc. 1573'FWL, 1400'FSL, Sec. 26, T13N, R10W, SM. Dear Mr. Arehey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly yours, , / / / Z: ~f ? .,// //f z Chairma~ of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COFR~ISS%ON dlf E'nc losure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL .~ OIL AND GAS CONSERVATION COMMI;. PERMIT TO DRILL 20 AAC 25.005 iN ! la. Type of Work Drill X Redrill w I lb. Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry ~ Deepen ,LI Service Development Gas ~ Single Zone Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 104, Pad 89' GL feet Beluga River Field 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 A029657 Undefined Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 295' FWL, 930' FSL, Sec. 26, T13N, R10W, SM Beluaa River Unit Statewide _ At top of productive interval 8. Well number Number Sterling 910'FWL&1157' FSL Sec. 26, T13N,R10w 214-2t~ #U630610 Beluga 1055' FWL&1210' FSL Sec. 26 T13N,R10W 9. Approximate spud date Amount At total depth 1573' FWL&1400' FSL, Sec 26, T13N, R10W SM 6-15-90 $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 Surface 6325' MD 5027 @ TD feet BRU 241-34 3000feett 8231 6148 'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 5 00 feet Maximum hole angle 17° Maximum surface 2300 psl~ At total depth (TVD) 2850 psl~l 18. Casing program Setting Depth size Specification Top Bottom Quantity et cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stage dataI N/A 20" 94# X-52 0 0 95' 95' Driven 17-1/2' 13-3/8 68# K-55 BTC 2985' 0 0 2985' 2900' 2500 Sx Class 'G' 12-1/4' 9-5/8" 43.5# S-95 BTC 6325' 0 0 6325' 6148' 1700 Sx Class 'G' , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~') Intermediate ~'~;~., Production Liner Perforation deplh: measured true vertical ":~ 20. Attachments Filing fee X~ Property plat _ BOP Sketch ~Y~ Diverter Sketch X Drilling program Drilling fluid program X Time vs depth plot ~ Refraction analysis ~ Seabed report .20 AAC 25.050 requirements 21. I hereby certify that the loregoing is true and correct to the best of my knowledge Signed F~I'~ ._'~ ~ Title Area Drillin[i Engineer Date ~'/~/~'~) Commission Use Only Permit Number I APl number ! Approval date^~/~n/,~,-, I See cover letter for ' ?O""~'/'2-' I 50'~'<~;~''~'~--'OO~'? I U3/UO/~U I other recluirements Conditions of approval Samples required ~Y e s ~ N o Mud log required ~ Ye s ~'N o Hydrogen sulfide measures Yes ~"~l-~ DirectiOnal survey required .~Yes ~ N o Required working press~.w'e-/~r B~"~ _~ ) ~ M' 5 M; 1 0 M; I 5 M Other: ./" J ~,....~/ ./" //' / ~,/ --~ -- by order of ~) . Commissioner lhe commission Dale A_ppro~.e_d. by -- -- ,, ~ , Form 10-401 r~il in triplicate BRU 214-26 General Drilling Procedure ARCO Alaska, Inc., as operator proposes to drill a dual Sterling - Beluga natural gas producing well in the Beluga River Field. The well's name as determined by the bottom hole location will be the BRU 214-26. The well surface location will be approximately 930' FSL and 295' FWL of Sec 26, T 13 N, R 10 W in the Beluga River Unit. OPERATION 1. Move in and rig up drilling rig 2. Drive 20" structural pipe to approximately 80' GL 3. Spud well drilling vertical to 500' , Kick off well directionally and drill to csg point at approximately 2985' MD, 2900' TVD. 5. Open 12-1/4" hole to 17-1/2" o Run and cement 13-3/8" surface csg with approximately 2500 sx Class 'G' cement with additives. A top job will be performed if cement is not circulated to surface. (Notify AOGCC and BLM '24 hrs in advance of surface casing cement job.) 7. Install WH and NU 5M psi WP BOPE, test same to 3,000 psi. (Notify AOGCC and BLM 24 hrs in advance of BOP testing. 8. Test casing, drill out and perform LOT. 9. Drill to first core point (+/- 4500' MD.) :'.,i',,,..~i,:,_.,0i~.,,,'.~,a,s%r~,,O01~.~'~issi0r¢ 10. Core and drill to TD per attached directional plat (3 - 30' cores estimated) 11. Run open hole logs, RFT's, and SWC's 12. Condition hole, run and cmt 9-5/8" production csg with approximately 1700 sx Class'G' cement with additives. (Notify A©GCC and BLM 24 hrs in advance of production casing cement job.) Install tubing spool and test. 13. Make bit and scraper run. Cased hole logging including gyro survey from PBD to surface. 14. Perforate and perform flow tests on up to 3 zones squeezing each zone after the individual tests. 15. Clean out well bore and perform negative test 16. Perforate well w/ TCP. LD drill pipe. 17. Set permanent packer. Run triple completion, (3-1/2" short string, 2-7/8" long string, and 2-3/8" heater string.) Circulate well to diesel. 18. RD and release rig. Clear location for facilities installation. BRU 214-26 Drilling Fluids Program Density, PPG PV, centipoise YP, lb/100 sq ft Spud to Surface Casincj Point 9.0 - 9.5 15 - 20 15 - 10 Funnel Viscosity, seconds / quart 200 - 50 Intial Gel Strength, lb/100 sq ft 8- 2 10 Min Gel Strength, Ib/100sq ft 20 - 8 APl Filtrate, cc / 30 minutes n/c - 20 pH 9 Percent Solids (volume) 5- 10 Surface Casing to TD 9.5 - 10.8 15 - 20 10 - 20 42 - 55 2-3 5 - 25 n/c - <10 10 - 11 10 - 15 Drilling Fluid Processing System Proposed * Tandem shale shaker * Desilter * Desander * Degasser * PVT and FLO SHO * Four Agitators A de-watering system is presently being evaluated for use on this location. Additional solids control equipment is also being considered. Drilling fluids practices will be in accordance with the appropriate regulations stated in 20AAC25.033. Maximum Anticipated Surface Pressure Maximum anticipated surface pressure is estimated by a very conservative approach of assuming bottom hole pressure at the surface. Anticipated BHP = 2,850 psi = maximum anticipated surface pressure. Therefore AAI is proposing BOP tests to 3,000 psi. (Note that with surface casing set, the casing shoe would breakdown at approximately 2,300 psi {15.2 ppg EMW} assuming a gas gradient of 0 psi / ft from surface to 2900' TVD.) . ~ ............. -~ =. ,, ~ ~ ' ~ ~AT'~.' 1~;'' ~ .... ~ ~ : , : , . ~.~: ~:..~::;~: ::::::::::::::::::::::::::::: ::::':::: ::-,. :.~:: .:~ : .._~_:. -. ~nnn: :~:.:-:.. ,.: .:'.:;:'::';; ':-' ' ~: ':' :: ~';::";' ' ================================================= :.:..:,..:,,: ;-:::: ~ .... ~, .. . . ,.. ~ ~.n' ~" :~:::: -:t'~ :..;::'..:::, :: ~ ' ..... : __ L . . ........ . .... ; ' ' ' ' · ............ , . , _ I · ,~ ~ ,,~ . , . . . . . . . , . , . . . / . . , . , ~ . , , ...... . . , . . . ' · , ..... ' ~' · t ' ' ~ .t s t ...... ' ' .... , ....... , ..... , * . - , ~ t · ~ ' , .... ~ ..... , ~ .......... , , , ..... : · , .. ..... . , ~ · · , , · , ,,~ ~.; ..... ~ ''' ~ .......... ........ ~ .... ~ .... i ....... ~ ......... ,i~. . ii, , ~,, .... ~ .... ~ ....... ....... ~... ~., .......... ~, ~ , ~ ; ~ , ,, ...................... ~' ~'1 ~ ~ '~ ' ~ ..... F . ~ . . . . . + . · , , . , +.* , . . . . , , , . I <'3 PZJD I000 HP i iii i · 11 · · · · · I I i i i i i · ,..,,..,,, ..I ,,..,,_ ,,, (~~_, , I t ' I -- ..2.._._1 t t ~ t , ' _ .... -- _ OlVERTER SYS'I EM ARCO ALASKA, INC. FILL-UP II LINE ]~11 · I I I RISER III I 20" ~ 2000 PSI DIVERTER 10" BALL VALVE 10" BALL VALVE FLOWLINE CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I Ill I I r' i r' i i i RIG MODULES NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES 15-510" 5000 PSI BOP STACK D 6RAI'I ~CCUMULATOR CAPACITY TEST I 1 PIPE RAHS BLI liD RAHS DRILLING SPOOL PIPE RAHS TB6 SPOOL 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER II:VEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD, 3. OPEN CASING VALVE(S) ON TUBING HEAD, (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PiPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PiPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 3,500 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 3,500 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 1Z PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BUND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED BRU 214-26 Proposed Well Bore Schematic 20" Conductor @ 90' 13-3/8" Surface Csg @-'2900"-TVD, 2985' MD cement PBD = +/- 6200' 9-5/8" Production Csg @ 6148' TVD, 6325' MD IIII 12 010~ 14 TI2N 29 32 CERTIFICATE Of SURVEYOR .. I hereby ce'rtify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plot represents a location survey mode by me or under my supervision, and that oll dimensions and other details ore correct. Date SURVEYOR I I Proposed Location BRU- 214-Z6 Located in Sec. 26tT. 13N.~ R. IOW.I S. M:.a A!aska Surveyed for ARCO ALASKA INC. RO. BOX 1003,60 ANCHORAGE, AK.99510-056 II I I Surveyed by R.C. DAVIS ~ ASSOC. LAND & MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCHORAGE, .ALASKA 99516 Company CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ~ YES ~ _~.~,~..~ 1. Is the permit fee attached .......................................... ~ Fee (2 thru 8) (2) Loc (3) Admin/~(- ,ZCzJ~,~ 9. (9 thru ~3)~ ~ 10. ~ ' 12. 13. (4) Cas~ ~.~ 3-,?. "'?~ (14 thru 22) 2. Is well to be located in a defined pool ............................. 3. Is we_l] located proper distance from property line .................. 4. Is we~,l located proper distance from other wells .................... 5. Is suz~icient 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 ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lease & Well No. /~1".2~;~'~'~/ ~/ ~_~/q-~ B~'~ NO ~ ' ~REMARKS 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 ......................... ~. 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 ............................ (23 thru 28) 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 ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thrd 317 (6) Add: Geology.: DWJ~ Engineering: Lcs /'" rev: 01/30/89 6.011 For 29. 30. 31. 32. 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 / 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. .o PROGR~ :. LISCAN REVISION: 5.2 Start of execution: Thu 13 SEP 90 2:35p **** REEL HEADER **** LIS 90/09/02 ATLAS 01 'LIS CUSTOMER FORMAT TAPE' PART NUMBER: W5790-MICRO **** TAPE HEADER **** LIS 90/09/02 4573 01 · OPEN HOLE: MAIN & REPEAT OF DLL/ZDL/CN/BHC AC: 6435-0 FT' FILE # 1 MAIN .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : BRU 214-26 FN : BELUGA RIVER COUN : KENAI STAT : ALASKA RECEIVED S E P 1 9 1990 Alaska Oil & Gas Cons. Co_mm'ts,sion Anchorage * COMMENT RECORD * MAIN PASS * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 11 CURVES : NAME CODE SAMPLE# UNIT BYTES '1 GR 2 CAL 3 TTEN 4 RFOC 5 RILD 6 RILM 7 CILD 8 AC 9 CHT 10 SPD 11 SP 68 68 68 68 68 68 68 68 68 68 68 API 4 IN 4 LB 4 OHMM 4 OHMM 4 OH/VIM 4 OHMM 4 US/F 4 LB 4 F/MM 4 MV 4 * DATA RECORD DEPTH RILD SPD 3000.000 -999.2500 -999.2500 2950.000 47.33974 35.99640 2900.000 12.70889 39.99600 2850.000 19.30589 40.34100 2800.000 18.92502 40.65091 2750.000 11.75656 40.99591 2700.000 13.49235 54.86790 2650.000 12.57477 57.99420 2600.000 12.00284 57.88501 2550.000 33.44563 57.33929 (TYPE# GR RILM SP -999.2500 -999.2500 -999.2500 0.0000000E+00 44.58340 60.21667 54.58240 13.29093 77.42053 40.85638 17.09814 52.65404 48.61900 19.25758 54.53052 49.94923 11.38872 77.00040 48.26210 13.72932 79.73160 42.03157 13.36948 57.27112 50.01616 11.62559 87.24236 38.24197 33.44731 68.91069 0) 1014 BYTES * CAL CILD -999.2500 -999.2500 10.00000 21.12390 13.30648 78.68510 12.66540 51.79767 12.66181 52.84012 12.42449 85.05888 12.45479 74.11607 12.46924 79.52431 12.56216 83.31358 12.52554 29.89928 TTEN AC -999.2500 -999.2500 1852.283 128.6435 1784.304 125.6724 1811.410 144.0532 1774.167 133.8467 1756.471 132.7281 1777.068 124.5849 1734.776 127.0711 1719.185 114.6860 1684.443 145.3711 RFOC CHT -999.2500 -999.2500 42.58223 -11498.85 13.54544 -11498.85 24.43166 -11498.85 19.12984 -11498.85 11.00748 -11498.85 12.84029 -11498.85 17.14851 -11498.85 12.53874 -11498.85 27.22937 -11498.85 2500.000 12.74422 57.99420 2450.000 23.54042 57.99420 2400.000 26.39453 58.23001 2350.000 29.51129 57.99420 2300.000 36.08014 57.99420 2250.000 42.75822 57.99420 2200.000 43.77460 58.23001 2150.000 40.07681 57.99420 2100.000 52.93088 57.99420 2050.000 55.31169 57.99420 2000.000 71.07263 57.99420 1950.000 27.64754 57.99420 1900.000 79.00436 57.99420 1850.000 72.83347 59.75819 1800.000 98.20523 59.99400 36.69684 11.93509 96.26775 38.04404 23.12405 59.51454 38.16891 25.94069 76.27277 37.76010 29.09447 58.42064 36.09738 34.92853 84.12671 31.70740 36.17567 56.94962 39.88354 39.01749 80.61319 39.08035 35.35789 33.89368 34.13095 46.26344 77.50143 42.06535 49.11095 102.1434 36.89391 56.52432 88.29738 35.39120 19.80510 113.7400 43.01181 64.46408 103.0020 37.43916 60.38359 101.6064 32.64711 71.86600 105.8291 12.36259 78.46693 12.30984 42.48013 12.31475 37.88664 12.29879 33.88533 12.29654 27.71608 12.30510 23.38731 12.29511 22.84430 12.26324 24.95209 12.22388 18.89256 12.25534 18.07936 12.25528 14.07011 11.65100 36.16959 11.52346 12.65753 11.50505 13.72995 11.60774 10.18276 1674.467 116.5540 1645.533 135.5925 1636.384 140.2174 1608.180 137.1749 1585.615 136.1536 1559.799 139.2310 1544.581 137.1334 1533.134 140.9358 1502.002 145.8316 1468.507 138.2563 1461.621 144.9528 1440.255 125.0683 1422.000 140.7749 1403.017 143.7400 1410.818 144.0735 12.40468 -11498.85 22.54768 -11498.85 24.69456 -11498.85 27.22493 -11498.85 32.12697 -11498.85 34.49817 -11498.85 35.34581 -11498.85 31.63542 -11498.85 42.26352 -11498.85 44.88748 -11498.85 51.31880 -11498.85 29.08803 -11498.85 62.65501 -11498.85 62.52583 -11498.85 79.05981 -11498.85 1750.000 84.00052 59.88480 1700.000 86.71320 60.22980 1650.000 89.05367 59.88480 1600.000 77.87024 59.99400 1550.000 29.12808 59.99400 1500.000 37.24768 59.33911 1450.000 60.92287 59.99400 1400.000 86.73642 59.99400 1350.000 88.48294 60.88470 1300.000 105.2196 51.99481 1250.000 219.3084 48.99510 1200.000 131.0062 48.99510 1150.000 165.6906 49.10431 1100.000 258.4087 48.99510 1050.000 172.6573 46.10460 37.55440 67.13834 97.02049 31.74934 67.26807 97.84383 38.00005 73.76837 88.73349 43.09436 64.50508 87.86444 41.72627 25.99123 94.79842 42.71382 34.79716 76.09216 40.19434 37.08952 80.58586 36.55107 57.64665 97.77222 36.11821 72.10172 99.53671 38.07089 84.11928 74.72150 33.21828 131.5108 77.38147 29.88399 41.48859 77.45682 30.56081 84.32959 66.81625 35.44728 190.5525 49.09441 35.25162 93.89267 67.49706 11.61591 11.90469 11.48824 11.53227 11.39522 11.22918 11.49439 12.84188 11.38061 34.33113 11.42322 26.84731 11.23299 16.41420 11.41947 11.52918 11.93466 11.30161 12.69828 9.503929 15.77961 4.559789 15.12737 7.633224 14.97202 6.035344 14.51105 3.869841 14.73548 5.791821 1374.230 144.3856 1353.407 141.9426 1327.799 144.5340 1320.227 144.9239 1300.713 143.7728 1291.847 138.9600 1239.413 144.8603 1223.250 144. 6963 1219.302 146.1868 1184.237 144.2276 1194.856 126.2163 1153.248 143.7985 1079.992 150.2034 1077.772 124.8373 1012.101 151.1657 68.41071 -11498.85 71.65277 -11498.85 80.15829 -11498.85 57.53688 -11498.85 31.38892 -11498.85 35.85954 -11498.85 55.42761 -11498.85 64.55766 -11498.85 71.12016 -11498.85 121.3351 -11498.85 188.4312 -11498.85 78.72411 -11498.85 131.0176 -11498.85 213.0598 -11498.85 112.2425 -11498.85 1000.000 170.3990 48.10440 950.000 164.5284 48.10440 900.000 148.5423 48.75931 850.000 60.13509 49.10431 800.000 401.9729 49.75922 750.000 204.9931 49. 10431 700.000 282.5208 48.99510 650.000 96.87138 49.99501 600.000 1205.234 49.99501 550.000 49.78661 49.99501 500.000 2088.678 49.99501 450.000 41.12050 49.99501 400.000 46.67551 49.99501 350.000 1401.511 49.99501 300.000 79.39656 50.10420 34.46376 69.03035 72.13806 36.15685 67.84436 74.62120 33.30083 97.59718 46.39053 29.58850 24.58606 47.79343 32.16003 103.9016 47.08182 31.84492 84.91602 42.56950 33.80045 103.4947 42.69131 45.85684 31.07561 52.33876 27.40152 107.2702 48.88051 45.46364 31.37885 12.68814 26.51523 65.87962 41.20767 43.75554 28.05420 20.57008 44.00768 35.00830 12.08889 31.65947 138.2184 3.632947 48.19322 41.84770 -26.65491 15.11101 5.868577 13.36737 6.077977 13.43777 6.732091 15.63899 16.62923 16.65569 2.487730 15.34539 4.878213 15.16909 3.539562 12.92812 10.32297 16.45360 0.8297142 14.56062 20.08572 16.67328 0.4787717 13.34936 24.31877 13.03925 21.42451 15.44866 0.7135155 13.16678 12.59500 1002.950 142.4819 991.9771 151.8553 926.2666 119.2243 894.8286 171.2646 908.1399 145.1411 848.2124 185.2448 844.1462 155.2320 805.3879 164.4113 814.6855 155.6580 776.4922 164.4456 760.2432 141.9099 761.8826 165.4615 734.2998 135.3064 716.0999 170.2222 676.8962 166.6043 96.71832 -11498.85 90.51018 -11498.85 131.2383 -11498.85 54.06886 -11498.85 133.4608 -11498.85 207.7075 -11498.85 427.0278 -11498.85 92.68405 -11498.85 523.2625 -11498.85 53.78964 -11498.85 119.3948 -11498.85 31.70508 -11498.85 60.72939 -11498.85 542.3604 -11498.85 49.41078 -11498.85 250.000 30.89455 152.7162 48.11366 49.99501 -62.85818 200.000 33.69260 188.2690 58.12903 50.23080 -88.66884 150.000 30.43773 146.0981 42.96220 50.88570 -78.13640 100.000 27.23116 2.415810 1.792329 51.88560 -89.11563 50.000 17.75195 1.994696 1.990669 49.88580 -91.13809 0.000 10.2876 0.2000000 0.200000 0.0000000E+00 0.000000 5 0 0E+00 14.94137 689.9807 109.4106 6.548093 159.8506 -11498.85 16.04095 642.0215 96.46239 5.311549 157.9473 -11498.85 15.61603 605.9399 82.97235 6.844716 158.7164 -11498.85 16.11391 583.3906 4.045025 413.9399 119.0748 -11498.85 16.15721 694.5291 2.207538 501.3296 130.0138 -11498.85 16.24222 0.0000000E+00 -250.0000 50.00000 0.2000000 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 286 3000.00 ENDING TAPE DEPTH = 0.00 FILE # 2 MAIN . 002 **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 17 CURVES : NAME CODE SAMPLE# UNIT 1 SP 68 1 MV 2 GR 68 1 API 3 TEMP 68 1 DEGF 4 SPD 68 1 FT/M 5 CHT 68 1 LB 6 TTEN 68 1 LB 7 CAL 68 1 IN 8 RD 68 1 OHMM 9 RS 68 1 OHMM BYTES 4 4 4 4 4 4 4 4 4 10 RMLL 68 1 11 RLML 68 1 12 RNML 68 1 13 ED 68 1 14 ES 68 1 15 ID 68 1 16 IS 68 1 17 TEN 68 1 OHMM 4 OHMM 4 OHMM 4 VOLT 4 VOLT 4 AMP 4 AMP 4 LB 4 * DATA RECORD DEPTH CHT RMLL ID 6450.000 -999.2500 -999.2500 -999.2500 6400.000 104.7148 95.96335 42.43042 6350.000 4595.988 2.148376 273.6665 6300.000 986.2278 2.785243 158.8886 6250.000 1915.252 3.205492 186.3824 6200.000 916.3821 2.679667 156.9160 6150.000 2740.330 2.525665 166.8434 6100.000 1185.658 3.721687 137.8400 (TYPE# 0 ) SP TTEN RLML IS -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 2688.441 32.17909 117.8274 62.46098 2952.444 1.619842 630.7817 69.51038 2735.730 2.254149 414.3179 64.92827 2672.990 4.236452 480.9561 78.26567 2707.733 1.699142 447.2727 67.45926 2772.802 1.571576 418.1433 66.31985 2773.749 1.486233 387.8787 1014 BYTES * GR CAL RNML TEN -999.2500 -999.2500 -999.2500 -999.2500 50.71553 13.80017 4.888798 2727.271 74.84996 13.50254 1.195893 3035.612 67.89113 13.62798 1.600341 2782.556 70.59433 13.63066 2.245644 2715.334 53.20692 13.80889 1.520268 2747.761 69.74086 13.52453 1.238959 2803.133 49.23004 13.61450 1.452438 2781.717 TEMP RD ED -999.2500 -999.2500 -999.2500 0.0000000E+00 37.63644 107.3464 0.0000000E+00 6.333948 116.5317 0.0000000E+00 11.21620 119.8062 0.0000000E+00 9.792191 122.6952 0.0000000E+00 11.94786 126.0366 0.0000000E+00 9.853127 110.5162 0.0000000E+00 14.04849 130.1792 SPD RS ES -999.2500 -999.2500 -999.2500 34.99651 30.54152 92.60425 33.99661 8.338020 135.3546 34.99062 15.60290 166.3632 34.59621 9.406500 116.4293 34.99062 12.52252 144.1410 33.99661 5.005463 53.86487 34.99062 9.777740 97.60294 6050.000 65.79964 67.59653 0.0000000E+00 34.99651 1585.470 4.289329 161.5623 6000.000 27.87109 2.384623 239.5670 5950.000 -974.0073 2.791575 108.8647 5900.000 -1469.319 2.593454 227.2738 5850.000 -1389.507 2.163863 199.9165 5800.000 -1948.683 4.048231 105.9911 5750.000 149.1622 5.609980 84.24438 5700.000 -2216.254 2.045270 223.7025 5650.000 -3960.677 3.684501 90.39995 5600.000 -2652.564 3.846464 85.39346 5550.000 -1416.644 1.886613 192.5651 5500.000 -3004.665 1.784134 217.5146 2736.542 4.319959 411.4414 60.93665 2693.771 1.084418 563.7932 59.99960 2610.387 1.140206 319.2993 55.21584 2633.423 1.574945 563.9065 59.22716 2485.973 1.482097 487.0837 71.92673 2572.731 1.604961 318.8467 76.44186 2532.595 1.528348 258.5525 56.51511 2489.197 0.7848353 603.3437 64.31973 2390.516 1.585110 300.6919 76.60954 2429.452 1.691255 335.4788 53.84387 2500.323 0.5765471 350.8408 56.70158 2418.930 0.8150798 544.7639 13.61245 2.397340 2786.513 78.02837 13.29330 0.9692453 2735.210 69.95370 13.64476 1.017824 2675.437 67.17776 13.28424 1.110761 2674.324 76.10974 13.20950 1.190886 2566.639 47.26350 13.39426 1.372540 2580.310 47.79715 13.50225 1.520638 2580.396 70.48468 13.34651 0.7961745 2521.787 57.05978 13.23466 1.485086 2478.813 59.36374 13.17048 1.500579 2465.118 34.24371 13.31758 0.7250880 2521.469 74.23128 13.23383 0.7711880 2481.396 11.37069 123.5001 0.0000000E+00 6.840297 110.1663 0.0000000E+00 12.22790 89.49074 0.0000000E+00 6.559604 100.2246 0.0000000E+00 8.108049 108.9708 0.0000000E+00 15.83919 112.8591 0.0000000E+00 21.41103 121.2562 0.0000000E+00 6.750202 101.5161 0.0000000E+00 18.05296 109.7103 0.0000000E+00 25.10834 144.1327 0.0000000E+00 8.232042 106.5688 0.0000000E+00 6.908708 101.0258 9.754450 103.2855 34.99651 3.664893 53.17647 35.03221 9.121408 74.95305 35.99640 7.820011 113.4870 35.40271 1.160485 14.54742 35.95480 19.04375 156.2598 34.99651 18.82983 125.2877 35.43251 2.793637 43.37851 35.99640 14.37386 111.2285 35.99640 21.03998 181.6435 35.56041 8.765383 79.14272 35.99640 2.693531 37.76334 5450.000 57.39571 66.69345 0.0000000E+00 35.99640 -4503.973 2.018174 164.9183 5400.000 -3389.297 3.045254 99.90382 5350.000 -4678.254 2.279606 214.0405 5300.000 -4829.762 2.322158 247.7733 5250.000 -5468.730 2.076952 143.2441 5200.000 -7146.965 1.950327 132.7357 5150.000 -7079.121 2.250975 129.1942 5100.000 -6760.344 2.118174 170.9123 5050.000 -9484.148 2.988651 130.7782 5000.000 -7604.906 2.967385 179.2690 4950.000 -7824.281 2.301779 194.4481 4900.000 -9143.531 2.613428 173.7109 2390.950 0.9305040 471.0200 69.04796 2389.386 1.307069 381.7036 54.83101 2348.442 1.009620 438.0967 48.99445 2353.619 0.7528983 567.8933 58.88525 2325.340 0.8234524 406.3291 55.84337 2343.113 0.9493674 380.1545 54.31447 2279.824 1.221050 373.9148 50.73616 2256.475 1.024913 539.5305 48.80214 2243.666 1.359525 381.4412 47.20996 2212.078 1.687658 532.6758 51.69995 2222.750 1.289758 454.0271 57.44209 2202.053 0.4989001 471.9429 12.60722 0.8928875 2441.898 55.73247 12.88458 1.221151 2443.156 68.09145 13.39876 1.068715 2382.073 66.28377 13.66742 0.8306273 2383.463 68.10034 12.85458 0.9856353 2386.500 70.04311 12.13439 0.9363924 2368.083 64.12952 13.06917 0.9992056 2311.071 67.69374 12.98382 0.9063673 2304.566 56.16521 13.09733 1.228979 2272.907 62.52649 13.39427 1.398605 2272.038 64.14162 12.81641 1.094834 2271.562 59.92220 14.25959 0.6425037 2246.978 9.812075 108.7858 0.0000000E+00 20.21692 135.7765 0.0000000E+00 8.014977 115.3304 0.0000000E+00 6.629025 110.4210 0.0000000E+00 12.04655 116.0056 0.0000000E+00 11.81821 105.4579 0.0000000E+00 8.994331 78.11885 0.0000000E+00 9.584078 110.1201 0.0000000E+00 9.839380 86.50589 0.0000000E+00 7.596144 91.54712 0.0000000E+00 6.558442 85.73376 0.0000000E+00 8.534721 99.66922 5.637840 68.34195 35.99640 5.700719 56.00040 35.99640 11.92127 134.4056 36.59601 4.441082 64.90717 36.43831 12.89515 134.8428 36.99631 10.34282 101.1875 36.99631 7.764900 74.72058 36.99631 10.26272 142.4971 37.95461 3.685719 36.18163 36.99631 5.114199 70.10945 36.99631 4.867620 56.87675 37.99622 12.33247 149.7833 4850.000 58.34239 61.91130 0.0000000E+00 36.99631 -7219.937 2.490704 166.9582 4800.000 13014.44 1.663225 203.2027 4750.000 -1225.033 1.749677 203.1969 4700.000 11933.96 5.374564 118.7918 4650.000 16435.29 2.233321 137.0674 4600.000 38218.66 1.396648 199.7600 4550.000 53238.43 1.910789 233.3862 4500.000 78101.50 1.916020 186.6562 4450.000 71105.69 1.578981 212.3238 4400.000 104452.8 1.785590 270.5281 4350.000 104383.4 2.696307 190.2254 4300.000 104194.8 2.380260 213.1362 2202.945 1.194505 534.0435 54.38919 2194.606 0.2847635 529.4360 53.44728 2175.935 0.5229414 517.9031 58.25836 2127.335 3.155188 297.3303 52.02632 2085.292 1.137055 380.9521 50.69281 2069.758 0.5237436 493.0984 51.90126 2027.471 0.5065867 518.2397 52.61053 2025.700 1.152860 447.6921 49.44460 1984.871 0.8406653 643.6611 54.96021 1965.265 0.3506562 819.1289 56.75395 1898.532 1.100464 661.3523 54.30594 1901.257 1.400519 654.1587 14.44736 0.9435707 2225.914 58.78113 14.64273 0.4062467 2206.893 69.64037 14.14128 0.6469922 2217.518 63.18869 15.31245 1.501826 2170.270 75.81873 15.05693 1.057600 2145.077 64.00037 13.92435 0.5451034 2102.265 69.34331 13.64838 0.6132520 2081.158 60.69633 13.70054 0.8920027 2070.465 67.22441 14.26008 0.7766854 2025.222 63.43854 13.79265 0.5231787 2008.144 80.28008 14.01361 0.8407277 1960.828 75.32428 14.19948 1.097863 1963.216 11.73746 131.7413 0.0000000E+00 6.703384 91.57376 0.0000000E+00 5.693564 77.77682 0.0000000E+00 11.49708 91.81517 0.0000000E+00 7.927071 73.04533 0.0000000E+00 5.329694 71.57481 0.0000000E+00 5.383289 84.46411 0.0000000E+00 7.665565 96.19057 0.0000000E+00 6.638208 94.75392 0.0000000E+00 7.299618 132.7574 0. 0000000E+00 10.68415 136.6312 0.0000000E+00 9.279711 132.9644 8.098820 111.3088 37.40250 3.983489 54.27690 37.99622 5.386399 71.79309 37.99622 19.16188 146.6190 37.99622 7.176086 70.35431 38.03191 3.250100 41.24483 37.99622 10.14503 135.3043 37.99622 12.97695 149.5117 38.99020 4.169336 69.06560 38.99609 8.866264 186.9058 39.55411 4.152779 70.68205 39.99010 7.521186 126.6198 4250.000 47.80756 62.14384 0.0000000E+00 39.99600 104266.6 2.948288 234.9365 4200.000 104087.4 2.200480 213.9397 4150.000 104036.7 3.098783 145.6357 4100.000 103947.9 3.263709 212.5237 4050.000 103857.6 2.852292 146.4853 4000.000 102983.4 3.276281 122.5036 3950.000 103730.8 5.220703 98.92570 3900.000 103607.2 2.946591 242.2423 3850.000 103495.6 2.539501 131.6672 3800.000 103355.5 2.341886 210.3512 3750.000 103381.6 69.30128 18.50186 3700.000 103236.7 0.9814537 233.3242 1893.934 0.6138071 622.9395 49.65176 1850.640 1.235244 649.4050 56.77144 1869.036 1.145745 485.3184 53.92578 1821.464 0.5194926 645.6523 57.62709 1805.725 1.028998 475.7031 60.17831 1778.927 1.336440 436.1670 57.62601 1778.722 1.297710 297.7249 47.81442 1684.371 1.870925 622.4907 50.53510 1680.312 1.320197 441.7810 46.02197 1700.014 1.835846 624.8889 43.47279 1673.555 4.064706 88.74965 42.16457 1661.634 1.440654 680.3352 13.57393 0.6247483 1926.486 65.76129 13.78602 0.9618436 1898.190 56.46828 13.72923 0.9720275 1897.483 63.09509 13.64415 0.6355824 1863.956 65.05080 13.65422 0.8674369 1854.115 71.90094 13.57562 1.065617 1820.458 32.66229 14.52201 1.226532 1811.910 71.76508 14.61199 1.120130 1755.085 65.37453 13.71898 1.137197 1732.463 60.28514 14.26009 1.303766 1739.504 18.23801 12.92930 1.683200 1718.670 60.96690 11.85653 1.115872 1695.593 5.996229 94.70595 0.0000000E+00 7.054663 101.4646 0.0000000E+00 10.76170 105.3636 0.0000000E+00 8.463497 120.9211 0.0000000E+00 11.72490 115.4631 0.0000000E+00 15.07036 124.1102 0.0000000E+00 19.77319 131.4964 0.0000000E+00 6.118177 99.63695 0. 0000000E+00 10.89663 96.45200 0.0000000E+00 9.146629 129.3451 0.0000000E+00 99.20549 123.3565 0.0000000E+00 7.531183 118.1324 5.295274 84.89264 39.99010 1.157602 19.34718 39.99600 5.169131 64.56248 39.99600 6.176517 102.6305 38.03781 11.52254 141.0619 38.99609 13.96539 156.7571 39.43800 12.64234 96.86485 38.99609 2.716571 43.52049 39.99600 2.813071 31.98363 39.03770 9.291098 149.4166 39.96031 29.77458 67.99979 39.43211 0.7007296 12.26921 3650.000 37.73221 56.03773 0.0000000E+00 39.58981 103085.1 0.5912231 195.0885 3600..000 102837.9 0.8210819 58.01839 3550.000 102659.6 1.924931 43.15918 3500.000 102586.0 2.469700 167.2454 3450.000 62099.49 2.223953 171.9183 3400.000 102219.9 2.584182 212.2404 3350.000 102273.4 1.196399 189.8874 3300.000 101946.6 1.829320 69.90752 3250.000 101860.4 1.815354 103.6139 3200.000 101729.9 1.956388 190.9856 3150.000 101598.2 1.980096 151.5379 3100.000 101531.7 1.907969 237.3155 1615.300 0.6409303 608.8557 53.39029 1575.681 1.224774 301.6406 66.53589 1569.180 0.6926513 230.9048 42.70792 1526.819 1.444731 499.3823 42.46805 1529.102 1.100141 696.6355 37.14113 1503.199 1.097277 835.1377 48.89929 1503.244 1.971793 999.4429 72.71156 1414.380 1.225913 750.5364 42.75887 1444.397 1.257221 562.7002 47.53702 1416.352 2.149868 768.8582 65.01270 1398.447 1.433846 842.5840 57.73904 1353.659 1.533193 1050.366 16.61989 0.8131273 1663.390 59.56412 16.10138 1.174756 1626.615 59.09856 13.88021 0.8430581 1614.918 60.65614 14.11500 1.177757 1577.803 67.42329 13.29806 1.020673 1556.091 64.60056 13.54410 1.077748 1535.988 62.91092 14.10255 1.059714 1529.896 60.65649 13.00659 1.011511 1485.145 68.99362 12.63748 1.009360 1475.970 54.55299 13.13526 1.371369 1445.165 94.41605 13.28545 1.109909 1426.302 61.14198 12.99108 1.213019 1403.387 8.246367 108.1533 0.0000000E+00 34.17522 133.2858 0.0000000E+00 65.29605 189.4178 0.0000000E+00 9.060925 101.8757 0.0000000E+00 9.500504 109.8025 0.0000000E+00 8.007486 114.2536 0.0000000E+00 11.29932 144.2411 0.0000000E+00 42.74171 200.8491 0.0000000E+00 17.75374 123.6628 0.0000000E+00 11.05970 141.9989 0.0000000E+00 16.60849 169.1937 0.0000000E+00 12.01776 191.7296 5.611051 87.92122 40.39630 14.42485 111.9753 37.99622 39.64577 235.5638 38.43811 3.563362 45.79645 38.59581 4.534202 81.29115 37.99622 3.544050 76.17221 38.40240 3.032251 77.99428 38.99609 11.22127 216.7404 38.99609 11.42787 165.4886 38.99609 5.571524 110.2441 39.99010 7.856915 170.3714 38.99609 4.266657 115.3362 3050.000 99.47050 63.27933 0.0000000E+00 39.00200 10~457.6 1305.634 12.89724 1.506603 1.142960 0.9331625 118.9449 1049.412 1375.376 33.03883 264.1672 3000.000 104.9058 27.44368 0.0000000E+00 101350.1 1356.916 13.33232 128.3012 18.44542 7.224657 3.382785 64.91690 7.529376 81.36337 1390.505 10.16267 274.4617 39.39641 90.12749 188.6605 2950.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 501 6450.00 ENDING TAPE DEPTH = 2950.00 FILE # 3 **** FILE HEADER **** MAIN .003 1024 FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 7 CURVES : NAME CODE SAMPLE# UNIT 1 GR 68 1 API 2 SPD 68 1 F/MM 3 SP 68 1 MV 4 CHT 68 1 LB 5 CAL 68 1 IN 6 TTEN 68 1 LB 7 AC 68 1 US/F BYTES 4 4 4 4 4 4 4 * DATA RECORD DEPTH CAL 6460.000 -999.2500 (TYPE# GR TTEN -999.2500 -999.2500 o) 998 BYTES * SPD AC -999.2500 -999.2500 SP -999.2500 CHT -999.2500 6410.000 67.01375 27.99721 13.24778 6287.734 13%45247 2658.166 99.53484 6360.000 11.99344 6310.000 12.10153 6260.000 12.12407 6210.000 12.72680 6160.000 12.20614 6110.000 11.82482 6060.000 11.65358 6010.000 11.55863 5960.000 11.54328 5910.000 11.52734 5860.000 11.39234 5810.000 11.43671 5760.000 11.32424 5710.000 11.56204 5660.000 12.01258 5610.000 13.09754 5560.000 13.41899 5510.000 12.53416 5460.000 11.71129 63.08545 2595.001 60.96841 2613.842 60.70316 2621.071 54.11945 2573.701 61.06090 2581.930 61.56320 2541.601 63.35986 2527.285 67.43492 2532.109 56.06776 2488.471 66.68196 2496.230 53.62103 2443.513 44.98131 2451.001 51.45009 2427.545 65.56857 2407.565 57.90498 2402.583 59.14117 2373.654 66.76248 2379.921 55.78960 2332.314 62.71362 2305.445 28.99710 95.92560 27.62671 94.94946 35.96069 103.9286 36.59010 103.0294 35.40271 114.9185 36.99040 101.2494 36.40260 100.0231 37.43230 104.8628 37.96051 98.16682 37.87560 105.6800 49.00101 96.95021 47.59491 92.97900 49.59470 103.7350 48.43710 106.4199 49.43111 110.0573 50.95920 99.47942 49.99501 99.61490 51.95320 127.1808 51.55881 121.7124 10.55780 11.96807 12.80894 12.58600 12.56264 17.26892 16.69658 15.85843 15.50687 15.21008 15.21228 13.66636 16.25571 14.62805 16.05226 17.17940 19.71994 16.98656 14.71024 3733.359 6025.250 91849.69 92403.50 92153.87 92135.87 92109.69 91992.31 91986.50 91873.62 92276.87 92211.00 92283.31 92112.56 92187.50 92276.50 92162.69 92124.12 92217.25 5410.000 53.26125 52.98882 15.14211 92083.19 11~. 59595 2276. 793 98. 97809 5360.000 12.94670 5310.000 12.38182 5260.000 12.30918 5210.000 11.98311 5160.000 11.04946 5110.000 11.65037 5060.000 11.84904 5010.000 11.45782 4960.000 12.31937 4910.000 12.23787 4860.000 11.95935 4810.000 12.20674 4760.000 11.69152 4710.000 11.96767 4660.000 12.39130 4610.000 11.98958 4560.000 12.35141 4510.000 12.22786 4460.000 12.74210 58.56444 2240.103 61.56848 2244.036 64.30630 2254.935 65.24538 2240.544 51.96922 2225.906 59.29787 2225.619 61.26266 2163.625 60.90382 2104.793 59.41833 2099.177 48.25674 2111.834 56.86980 2083.478 55.99854 2059.600 63.74593 2037.900 66.89082 2027.285 60.50243 2003.871 61.25964 1987.513 66.18890 1952.133 57.14366 1934.062 56.45479 1903.595 51.59451 115.3686 52.02460 109.7130 52.95901 117.8401 52.98882 109.8176 52.59441 131.3529 52.47830 124.7441 55.03020 116.8502 56.35901 124.0915 54.58830 129.7741 55.62981 131.3675 56.35901 121.6255 56.58810 116.2103 57.55231 129.1956 57.40051 123.8985 57.59390 124.1129 59.95239 126.6964 58.99411 123.6766 59.59370 135.2202 60.55791 100.2837 15.13936 14.60909 13.86113 13.09046 12.05210 12.20988 11.03645 12.00544 12. 65142 11.92904 10.94117 10.79509 10.16437 8.979811 9.657988 9.910200 9.690500 10.04366 10.54798 92068.37 91984.50 91949.31 91977.37 91822.50 91769.25 91854.00 91881.25 91953.50 91907.56 91875.81 91782.94 91861.69 91889.69 91788.00 91858.94 91689.00 91648.31 91600.81 4410.000 33.89357 56.58810 10.16657 91730.75 12~46171 1929.174 136.7481 4360.000 12.77350 4310.000 12.52604 4260.000 13.55853 4210.000 13.30412 4160.000 13.84762 4110.000 13.53107 4060.000 13.85790 4010.000 13.77151 3960.000 13.51866 3910.000 14.02265 3860.000 14.19315 3810.000 14.34263 3760.000 13.75271 3710.000 14.00720 3660.000 13.25211 3610.000 14.41554 3560.000 12.92883 3510.000 14.12778 3460.000 16.62636 60.11131 1866.614 71.81958 1848.364 59.78175 1840.755 61.66283 1838.414 60.08368 1833.381 50.15247 1763.564 56.01271 1751.313 68.91112 1743.528 52.55232 1737.650 52.17523 1705.837 37.90912 1677.848 62.86357 1637.262 65.81253 1635.955 56.93802 1611.556 56.42009 1595.503 60.14215 1556.325 61.47771 1546.581 58.29460 1492.674 58.46216 1494.189 60.15170 125.8334 61.55190 126.7083 60.83621 130.3001 60.43001 127.9647 62.95210 143.9984 64.02930 132.8102 62.99960 130.6041 62.98779 122.3976 64.99352 139.9399 55.55840 128.7836 56.40060 132.6342 57.02409 128.6165 59.95239 127.4673 57.44211 157.7755 58.95840 141.2347 59.58780 147.6446 59.99400 166.7175 47.14961 172.8796 56.99429 144.4629 10.48700 10.32766 11.06355 10.33274 10.68781 10.51017 9.820564 9.199232 9.341005 9.901083 10.49769 10.46608 10.38506 11.14972 8.708975 10.41296 9.528034 10.41622 7.245864 91565.31 91546.31 91502.25 91445.87 91482.56 91557.31 91482.50 91466.37 91514.75 91341.56 91305.00 91258.50 91282.31 91351.94 91440.81 91508.31 91500.00 91145.69 91388.12 3410.000 65.42935 56.55240 8.109928 91477.62 12~56070 1478.552 173.5913 3360.000 52.35175 57.95851 7.269226 11.64192 1489.210 105.1028 91271.19 3310.000 67.55835 57.43620 6.785594 11.51713 1432.492 201.7934 91266.12 3260.000 60.42958 56.56421 7.790789 15.14524 1413.798 149.4308 91209.94 3210.000 64.28618 47.95950 7.714232 13.43595 1380.459 147.0176 90697.00 3160.000 72.62202 47.95950 7.242118 13.80196 1357.309 130.8912 90755.12 3110.000 65.12379 48.63051 7.491192 13.52073 1320.944 127.4482 90726.06 3060.000 57.31210 50.95329 5.901179 13.34347 1318.437 135.2104 90630.00 3010.000 53.97209 50.36551 6.325458 13.80836 1285.176 129.5321 90561.87 2960.000 41.42641 47.50720 5.230594 13.82616 1289.898 68.58771 87102.00 2910.000 36.65103 44.99550 5.866336 13.84960 1267.890 59.98004 90444.56 2860.000 45.40010 45.55351 5.382215 13.76117 1266.176 71.16006 90382.19 2810.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 236 6460.00 ENDING TAPE DEPTH = 2810.00 FILE # 4 **** FILE HEADER **** MAIN .004 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 20 CURVES : NAME 1 GR 2 CAL 3 SSD 4 SHR 5 RB 6 DEV 7 CHT 8 TTEN 9 SPD 10 SFT2 11 HRD1 12 HRD2 13 LSN 14 SSN 15 CN 16 CNC 17 ZDEN 18 ZCOR 19 PE 20 PORZ CODE SAMPLE# UNIT BYTES 68 1 API 4 68 1 IN 4 68 1 CTS 4 68 1 CTS 4 68 1 DEG 4 68 1 DEG 4 68 1 LB 4 68 1 LB 4 68 1 F/FM 4 68 1 CTS 4 68 1 CTS 4 68 1 CTS 4 68 1 CTS 4 68 1 CTS 4 68 1 PCT 4 68 1 PCT 4 68 1 GMCC 4 68 1 GMCC 4 68 1 BARN 4 68 1 PCT 4 * DATA RECORD DEPTH RB SFT2 CN PORZ 6460.000 -999.2500 -999.2500 -999.2500 -999.2500 6410.000 -12.25978 855.7266 38.71562 14.36164 6360.000 -12.25978 822.7522 35.48013 15.08852 6310.000 -12.25978 820.0789 33.70215 13.98983 (TYPE# 0 ) GR DEV HRD1 CNC -999.2500 -999.2500 -999.2500 -999.2500 70.11145 356.1531 1017.161 37.76248 69.35698 356.1531 986.8335 34.84030 71.85039 356.1531 955.3491 32.61253 1014 BYTES * CAL CHT HRD2 ZDEN -999.2500 -999.2500 -999.2500 -999.2500 13.20792 94416.00 1270.084 2.413033 12.85764 94416.00 1252.927 2.401039 13.86073 94416.00 1256.350 2.419168 SSD TTEN LSN ZCOR -999.2500 -999.2500 -999.2500 -999.2500 7596.559 2942.785 39.79591 0.2349974E-01 7508.355 2643.817 41.65199 0.1805323E-01 7651.734 2604.386 44.47081 0.4058110E-01 SHR SPD SSN PE -999.2500 -999.2500 -999.2500 -999.2500 0.5665811 18.14220 158.8170 3.174784 0.5583949 22.87111 157.4010 3.187581 0.6206259 22.76190 162.5701 2.704280 6260.000 -12.25978 835.7942 30.32159 13.77013 6210.000 -12.25978 1027.682 36.17360 18.56111 6160.000 -12.25978 860.0588 59.75586 15.64107 6110.000 -12.25978 862.5098 34.27313 15.07655 6060.000 -12.25978 830.6074 32.79907 14.91166 6010.000 -12.25978 823.8684 34.77135 14.48787 5960.000 -12.25978 1012.469 34.02116 16.41916 5910.000 -12.25978 876.4687 33.70825 13.51969 5860.000 -12.25978 864.8350 29.14404 16.37048 5810.000 -12.25978 1066.379 28.27612 19.31306 72.09755 356.1531 999.0598 29.55240 60.50877 356.1531 1216.556 34.89131 64.79547 356.1531 1042.368 58.49069 66.48854 356.1531 1048.159 33.22487 69.59671 356.1531 1004.056 31.92235 75.67622 356.1531 1016.869 33.57565 65.20015 356.1531 1222.225 32.80325 69.50490 356.1531 1029.285 32.55589 53.93069 356.1531 1019.855 28.75943 48.31134 356.1531 1207.938 27.85422 13.63889 94416.00 1230.154 2.422792 13.98884 94416.00 1572.339 2.343741 14.07769 94416.00 1343.219 2.391922 13.72570 94416.00 1305.215 2.401237 13.55209 94416.00 1266.546 2.403957 13.95373 94416.00 1299.571 2.410950 14.13915 94416.00 1559.604 2.379084 13.97851 94416.00 1320.343 2.426925 13.03125 94416.00 1295.919 2.379887 13.22691 94416.00 1556.143 2.331334 7753.914 2618.163 51.35242 0.5161597E-01 8424.867 2652.148 41.48950 0.6819957E-01 7798.754 2690.363 22.64040 0.3717096E-01 7799.445 2623.926 43.39259 0.4137980E-01 7530.301 2625.412 46.55641 0.1683217E-01 7742.895 2573.191 42.77100 0.3885910E-01 8601.527 2826.973 45.82600 0.8982652E-01 8105.867 2787.822 43.61340 0.8047467E-01 7520.758 2711.826 53.18739 0.9686660E-02 8109.336 2655.923 58.42722 0.3242092E-01 0.5883480 22.23360 175.0596 2.965161 0.6081891 20.76210 158.7281 2.833151 0.6468279 18.68820 113.3942 2.459799 0.6074049 31.77840 160.3689 2.839322 0.6059769 31.46851 167.1963 2.787055 0.5794090 31.45110 159.5516 3.095996 0.5963230 24.46921 168.5538 2.940376 0.5891819 26.23320 159.4545 3.055132 0.6091560 27.88800 176.5690 2.768448 0.6509120 27.99721 190.0667 2.449281 5760.000 -12.25978 840.2561 27.40649 14.64191 5710.000 -12.25978 875.8279 38.65895 13.52339 5660.000 -12.25978 989.5935 38.17300 16.79773 5610.000 -12.25978 996.5505 27.53464 17.83829 5560.000 -12.25978 906.6306 37.54135 14.41239 5510.000 -12.25978 2548.981 57.52573 45.08435 5460.000 -12.25978 1027.345 44.77191 18.69272 5410.000 -12.25978 997.1333 25.73906 18.42136 5360.000 -12.25978 2441.145 44.04776 39.19688 5310.000 -12.25978 1103.529 39.00349 20.22455 49.30754 356.1531 985.8489 27.04793 71.80377 356.1531 1033.027 37.22546 60.17752 356.1531 1228.154 36.78055 60.60580 356.1531 1149.135 27.17729 69.62175 356.1531 1038.314 36.06035 57.50182 356.1531 2992.015 55.95589 70.22455 356.1531 1213.773 42.97488 54.08676 356.1531 1177.668 25.48679 64.00323 356.1531 2776.651 42.53311 65.55975 356.1531 1315.427 37.67436 13.22691 94416.00 1239.506 2.408408 14.16004 94416.00 1285.595 2.426864 14.07619 94416.00 1552.437 2.372837 13.20486 94416.00 1523.793 2.355668 14.48849 94416.00 1333.646 2.412195 14.82242 94416.00 3931.524 1.906108 14.93508 94416.00 1556.501 2.341570 13.27574 94416.00 1483.907 2.346047 13.98611 94416.00 3354.969 2.003251 13.86987 94416.00 1660.052 2.316295 7574.934 2588.686 57.03311 0.2866191E-01 8032.871 2811.689 39.53320 0.7531250E-01 8529.418 2773.859 42.23241 0.8152324E-01 8647.805 2537.298 60.21341 0.1070254 7954.762 2646.341 42.74931 0.5873848E-01 10151.42 2539.531 22.85410 -0.1842592E-01 8199.969 2561.988 29.25551 0.4306730E-01 8054.672 2530.974 65.92320 0.3703997E-01 10742.86 2529.508 33.78621 0.7508570E-01 8439.129 2447.375 37.77220 0.5056360E-01 0.6197330 29.39880 181.6794 2.669689 0.6088181 24.57840 157.6275 2.823551 0.6057690 26.54311 167.0890 2.857590 0.6031930 30.34200 192.4120 2.887445 0.6083349 28.10640 167.3985 2.814516 0.7632840 31.52521 112.5412 1.691270 0.6036481 29.87041 127.0602 2.815938 0.6105380 30.45120 201.3479 2.773309 0.6347119 31.12350 145.4133 2.525077 0.6248150 24.30750 151.4224 2.663067 5260.000 -12.25978 994.0088 32.65099 20.03149 5210.000 -12.25978 953.3750 43.69861 17.79967 5160.000 -12.25978 1944.612 90.84052 34.56360 5110.000 -12.25978 1061.949 35.75085 19.72250 5060.000 -12.25978 1534.009 52.79927 26.66641 5010.000 -12.25978 1220.360 41.56610 21.15921 4960.000 -12.25978 1571.063 40.16321 25.28931 4910.000 -12.25978 2897.703 73.18883 48.10248 4860.000 -12.25978 1234.589 41.17622 21.50374 4810.000 -12.25978 6494.793 76.42815 71.36954 70.70258 356.1531 1263.764 31.25641 71.22917 356.1531 1150.936 41.87335 56.32692 356.1531 2306.020 93.05249 64.75169 356.1531 1252.686 34.50572 68.08167 356.1531 1791.806 51.39146 60.69455 356.1531 1403.122 40.60223 64.98204 356.1531 1845.976 39.23331 49.43378 356.1531 3399.254 73.23886 62.54633 356.1531 1431.277 39.64984 49.84515 356.1531 7264.559 76.39220 15.11395 94416.00 1608.579 2.319480 15.08695 94416.00 1453.424 2.356305 14.23704 94416.00 2858.271 2.079700 13.95637 94416.00 1613.075 2.324578 13.85407 94416.00 2283.343 2.210004 13.08894 94416.00 1752.422 2.300873 13.08894 94416.00 2277.135 2.232726 13.37942 94416.00 4371.422 1.856309 14.21511 94416.00 1873.022 2.295188 14.87483 94416.00 9258.203 1.472403 8396.207 2479.073 44.72290 0.5624077E-01 8137.148 2435.256 39.39030 0.5381081E-01 10139.45 2476.638 19.68761 0.6910950E-01 8319.867 2383.037 39.77100 0.4759307E-01 9840.207 2361.443 27.81010 0.1107116 8784.934 2307.195 35.01410 0.7323909E-01 10483.76 2299.384 35.56671 0.1709478 11440.38 2301.257 18.96490 0.6503671E-01 9529.195 2271.293 30.26221 0.1412732 13566.15 2222.106 18.73351 -0.6818876E-02 0.5481030 22.23360 160.1346 3.430012 0.5803610 32.23260 168.7777 2.998558 0.6639770 31.65179 115.5985 2.274431 0.5787820 32.12340 151.0228 3.047722 0.6057161 32.28931 131.5581 2.786210 0.6369048 32.54251 145.7872 2.702994 0.6119850 29.99701 145.1188 2.750278 0.7364911 30.76111 103.1611 1.770230 0.6047300 32.77831 125.3091 2.815928 0.8864830 31.52521 103.5620 0.9434264 4760.000 -12.25978 1247.421 50.27341 24.23120 4710.000 -12.25978 1097.804 38.06967 21.93330 4660.000 -12.25978 1250.613 36.97676 23.68494 4610.000 -12.25978 1329.472 45.90962 24.54453 4560.000 -12.25978 1458.619 47.86395 26.13283 4510.000 -12.25978 1170.665 41.19019 22.11334 4460.000 -12.25978 1328.763 34.34618 24.45221 4410.000 -12.25978 7672.062 56.68581 76.58856 4360.000 -12.25978 3834.805 69.23122 54.05376 4310.000 -12.25978 1203.878 50.90259 23.51108 56.14323 356.1531 1476.935 48.78497 72.34229 356.1531 1380.961 36.63586 68.09766 356.1531 1511.500 35.64636 63.59950 356.1531 1569.106 44.63957 67.79575 356.1531 1703.432 46.61308 57.06526 356.1531 1361.872 40.11328 62.00653 356.1531 1534.743 33.41922 40.48480 356.1531 8212.820 55.55389 53.71696 356.1531 4197.504 68.90512 80.82785 356.1531 1469.017 49.87910 13.92492 94416.00 1885.865 2.250185 14.24050 94416.00 1721.174 2.288100 14.02462 94416.00 1836.307 2.259198 13.52266 94416.00 1923.496 2.245015 13.48090 94416.00 2143.090 2.218808 13.30549 94416.00 1700.962 2.285130 13.49112 94416.00 1912.389 2.246538 13.55619 94416.00 9922.270 1.386289 13.42717 94416.00 4716.223 1.758113 13.11806 94416.00 1773.215 2.262067 8918.027 2300.738 25.93280 0.6943470E-01 8535.023 2274.354 36.23871 0.4964733E-01 8811.633 2268.895 43.17052 0.5869056E-01 8904.961 2165.612 35.15752 0.5661841E-01 9623.316 2115.170 29.44121 0.1057674 8361.406 2112.440 37.33630 0.3267012E-01 8831.426 2086.827 48.27100 0.5208625E-01 13776.47 2114.453 19.67540 -0.2238572E-01 11157.90 2028.071 20.44051 -0.2984921E-02 8561.437 2010.620 30.58661 0.3953448E-01 0.6129600 31.34190 119.7403 2.667827 0.5835251 31.65179 143.1363 3.092367 0.6337730 32.54251 167.4581 2.603072 0.6146600 35.65140 154.8047 2.749411 0.5694201 34.68660 132.5488 3.131499 0.6051589 35.99640 154.6322 2.798416 0.6459221 36.10561 178.6444 2.474534 0.9069639 35.88719 96.24210 0.8364835 0.7330549 36.86971 108.8289 1.666418 0.5786250 39.54181 142.1124 3.038006 4260.000 -12.25978 1168.855 39.06635 21.44554 4210.000 -12.25978 1383.454 37.30917 26.09039 4160.000 -12.25978 8533.074 87.52171 82.40649 4110.000 -12.25978 1214.498 28.88322 23.57085 4060.000 -12.25978 4044.532 71.36482 55.50952 4010.000 -12.25978 1273.453 38.12381 22.95448 3960.000 -12.25978 5644.762 48.61078 66.11179 3910.000 -12.25978 1403.021 36.62996 28.16837 3860.000 -12.25978 1627.253 49.09715 30.37129 3810.000 -12.25978 1249.618 43.40355 24.25710 66.29329 356.1531 1298.796 37.93872 61.78685 356.1531 1625.935 36.45459 39.66684 356.1531 9362.777 89.36026 55.08643 356.1531 1377.658 28.43323 54.63455 356.1531 4514.672 71.08546 66.60936 356.1531 1482.261 36.89508 57.47485 356.1531 6026.734 47.09525 56.88608 356.1531 1629.366 35.43828 49.60747 356.1531 1848.677 46.88115 70.01718 356.1531 1502.805 42.22185 13.50254 94416.00 1690.281 2.296148 13.11806 94416.00 1980.657 2.219508 13.32110 94416.00 12237.43 1.290293 13.19780 94416.00 1708.743 2.261081 13.73183 94416.00 5699.848 1.734093 13.74427 94416.00 1802.286 2.271251 13.94990 94416.00 7325.691 1.559155 13.78509 94416.00 2050.189 2.185222 16.37181 94416.00 2346.115 2.148873 13.41465 94416.00 1841.023 2.249758 8476.617 1935.376 33.25980 0.5352136E-01 8954.383 1920.358 39.15019 0.5251308E-01 14411.31 1937.737 16.39911 -0.3603233E-01 8186.086 2005.365 52.71361 0.9002332E-02 12005.34 1960.913 22.22630 0.2788557E-01 8746.074 1867.778 33.60490 0.5673470E-01 12344.00 1891.562 25.81480 -0.2772336E-01 8767.000 1857.426 41.49710 0.2519746E-01 9526.320 1862.679 27.20760 0.6925452E-01 8607.227 1726.098 31.05670 0.3559720E-01 0.6371961 28.46880 133.4634 2.457773 0.6252780 28.18050 152.7145 2.669333 0.8832201 27.87061 95.09590 0.9595993 0.6395919 26.57820 173.9437 2.517985 0.7247360 27.23311 119.7427 1.906308 0.6712769 28.45140 132.8495 2.290297 0.7007371 29.34210 117.1640 1.973125 0.6441931 31.01430 160.0180 2.473606 0.6318110 29.77861 124.1214 2.547858 0.5952990 32.87010 132.5627 2.903021 3760.000 -12.25978 1260.384 47.12007 25.22180 3710.000 -12.25978 1546.951 47.38660 33.23105 3660.000 -12.25978 1626.714 49.78494 32.52417 3610.000 -12.25978 2282.474 39.88892 40.59688 3560.000 -12.25978 1587.796 23.85364 34.86496 3510.000 -12.25978 1756.444 28.25047 34.65024 3460.000 -12.25978 3331.805 61.40309 49.16199 3410.000 -12.25978 1662.626 51.04762 32.19414 3360.000 -12.25978 2501.666 39.19058 45.60344 3310.000 -12.25978 1918.717 25.25095 38.82033 66.49156 356.1531 1508.846 45.36632 59.42113 356.1531 2035.397 45.89304 62.28354 356.1531 1924.970 48.27774 68.36292 356.1531 2822.936 38.63118 57.56242 356.1531 1954.950 23.86600 59.39938 356.1531 1995.258 27.91605 62.40732 356.1531 4191.078 59.56631 61.02554 356.1531 1963.575 49.83202 59.75371 356.1531 3009.219 38.12325 65.75514 356.1531 2213.230 25.15282 14.72898 94416.00 1941.166 2.233840 13.90701 94416.00 2571.470 2.101687 13.94930 94416.00 2338.324 2.113351 13.69088 94416.00 3637.843 1.980151 13.04390 94416.00 2454.023 2.074728 13.05299 94416.00 2483.204 2.078271 16.56575 94416.00 5378.613 1.838827 13.46052 94416.00 2463.940 2.118796 13.38670 94416.00 3672.893 1.897543 13.03125 94416.00 2789.908 2.009464 8944.848 1748.656 24.48370 0.6498116E-01 9513.379 1710.268 23.35500 0.4063988E-01 8973.402 1699.576 26.13330 0.4307881E-02 11407.05 1639.273 34.98201 0.1200743 8926.836 1655.661 51.86002 -0.9763028E-02 9215.922 1587.240 42.09320 0.1642835E-01 12921.04 1627.815 21.99580 0.1252359 9499.426 1546.061 28.89540 0.5038469E-01 10207.16 1523.686 33.98801 -0.2196150E-02 9189.207 1556.271 55.40900 -0.1852281E-01 0.5562959 34.12320 109.3219 3.308344 0.4593381 33.88741 104.5942 4.643999 0.6504320 33.76080 120.0711 2.414449 0.5938810 35.86980 142.1495 2.956206 0.5469520 37.12291 150.5878 3.434481 0.5824929 36.34140 136.8479 3.036366 0.5169541 36.65131 111.4746 3.779443 0.5902001 38.76030 134.4453 2.977332 0.5973320 39.99600 136.6484 2.912651 0.6055521 39.12270 167.0857 2.889143 3260.000 -12.25978 1596.534 52.33322 32.83080 3210.000 -12.25978 1677.106 38.24471 32.77820 3160.000 -12.25978 5755.855 51.89363 66.31026 3110.000 -12.25978 1507.484 42.52901 32.14178 3060.000 -12.25978 1532.456 37.79242 32.72087 3010.000 -12.25978 1644.158 56.99872 30.73682 2960.000 -12.25978 273.6426 65.58838 49.51866 2910.000 0.0000000E+00 0.0000000E+00 0.0000000E+00 -15.00000 61.00542 356.1531 2000.063 50.78964 70.96069 356.1531 2002.387 37.21306 87.32758 356.1531 6092.930 50.93335 63.60971 356.1531 1804.591 41.62746 63.10150 356.1531 1828.231 37.01564 47.60162 356.1531 1916.394 56.20888 37.58258 356.1531 556.2661 65.14915 35.34978 0.0000000E+00 0.0000000E+00 0.0000000E+00 14.15616 94416.00 2543.486 2.108292 13.37879 94416.00 2405.381 2.109159 13.03125 94416.00 7334.074 1.555881 12.94445 94416.00 2220.413 2.119660 12.94445 94416.00 2233.149 2.110106 12.95511 94416.00 2327.003 2.142842 13.10487 94416.00 793.0857 1.832942 10.00000 0.0000000E+00 0.0000000E+00 1.650000 9481.262 1583.179 24.31680 0.4086736E-01 9225.355 1450.692 33.06110 0.2226654E-01 12353.62 1437.579 31.93240 -0.2931095E-01 8766.988 1420.633 34.72220 -0.1481825E-02 8820.992 1363.658 37.02170 0.1929026E-02 9376.340 1368.479 23.47050 0.4977448E-01 2814.010 1416.453 18.91881 -0.7478100 0.0000000E+00 1000.000 0.0000000E+00 -0.1000000 0.5686651 37.59450 114.5379 3.241958 0.6045541 40.65091 130.9545 2.773246 0.7495980 40.32361 149.7890 1.670427 0.6175900 43.65060 146.5000 2.684939 0.5960339 44.75970 145.5705 2.829385 0.6619780 44.12221 115.0947 2.325831 0.1960890 42.23160 98.56740 16.98126 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 596 6460.00 ENDING TAPE DEPTH = 2890.00 FILE # 5 REPEAT. 005 **** FILE HEADER **** 1024 * COMMENT RECORD * REPEAT PASS - RUN NO. 1 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 11 CURVES : NAME 1 GR 68 2 CAL 68 3 TTEN 68 4 RFOC 68 5 RILD 68 6 RILM 68 7 CILD 68 8 AC 68 9 CHT 68 10 SPD 68 11 SP 68 CODE SAMPLE# UNIT BYTES 1 API 4 1 IN 4 1 LB 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 US/F 4 1 LB 4 1 F/MM 4 1 MV 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH GR CAL RILD RILM CILD SPD SP 3000.000 -999.2500 -999.2500 2950.000 48.60985 30.95531 2900.000 12.04929 39.99600 2850.000 20.90576 40.39630 2800.000 18.65001 40.99591 -999.2500 -999.2500 -999.2500 0.0000000E+00 44.21790 37.14352 53.05659 12.35995 66.07884 42.73602 19.82288 44.34911 49.29488 19.10539 39.43628 -999.2500 -999.2500 10.00000 20.57196 14.00334 82.99242 12.62727 47.83371 12.61826 53.61929 TTEN AC -999.2500 -999.2500 1836.400 128.1188 1841.390 123.3775 1809.308 144.5410 1781.320 133.8661 RFOC CHT -999.2500 -999.2500 42.96648 -11498.85 13.44076 -11498.85 25.55307 -11498.85 19.29749 -11498.85 2750.000 49.27769 12.55188 -250.0000 0.2000000 0.2000000 0.2000000 0.0000000E+00 0.0000000E+00 2700.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 -999.2500 -999.2500 132.7582 -999.2500 -999.2500 0.0000000E+00 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 29 3000.00 ENDING TAPE DEPTH = 2700.00 FILE # 6 REPT .006 **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 17 CURVES : NAME 1 SP 68 2 GR 68 3 TEMP 68 4 SPD 68 5 CHT 68 6 TTEN 68 7 CAL 68 8 RD 68 9 RS 68 10 RMLL 68 11 RLML 68 12 RNML 68 13 ED 68 14 ES 68 15 ID 68 16 IS 68 17 TEN 68 CODE SAMPLE# UNIT BYTES 1 MV 4 1 API 4 1 DEGF 4 1 FT/M 4 1 LB 4 1 LB 4 1 IN 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 VOLT 4 1 VOLT 4 1 AMP 4 1 AMP 4 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH SP GR TEMP SPD CHT TTEN CAL RD RS RMLL RLML RNML ED ES ID IS TEN 6450.000 -999.2500 -999.2500 -999.2500 6400.000 -7891.570 34.85805 40.84364 6350.000 -6727.309 2.164666 276.5671 6300.000 -4597.410 2.837229 157.1045 6250.000 -4400.555 2.851171 186.1147 6200.000 -3973.774 3.121884 155.7291 6150.000 0.0000000E+00 0.2000000 0.0000000E+00 -999.2500 -999.2500 -999.2500 -999.2500 0.0000000E+00 3143.298 7.563170 120.8096 63.83060 2558.750 1.217971 655.2390 70.73106 2770.855 1.035894 411.7297 67.92715 2720.753 1.267627 442.8154 82.94756 2688.727 1.433582 466.6348 72.19655 3000.000 0.0000000E+00 0.0000000E+00 -999.2500 -999.2500 -999.2500 -999.2500 54.60109 14.40295 2.208674 3210.077 78.59984 13.88561 0.9961002 2618.562 70.21806 14.01836 1.024911 2794.402 74.47372 14.19243 0.9538897 2744.898 57.89000 14.73974 1.210059 2738.425 0.00 10. 0.00 -250 -999.2500 -999.2500 -999.2500 0.0000000E+00 41.56442 114.1148 0.0000000E+00 6.499104 120.8375 0.0000000E+00 11.53451 121.8226 0.0000000E+00 8.989777 112.4796 0.0000000E+00 12.60724 131.9863 -999.2500 -999.2500 -999.2500 37.99622 15.08116 46.88736 37.96051 5.515675 93.01088 36.99631 4.170608 44.19257 36.96060 10.99599 125.3094 36.99631 6.734814 80.87904 00000E+00 0.0000000E+00 0.0000000E+00 00000 0.2000000 0.2000000 00000E+00 0.0000000E+00 0.0000000E+00 .0000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 46 6450.00 ENDING TAPE DEPTH = 6130.00 FILE # 7 REPEAT. 007 **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 64) . CURVES : NAME 1 GR 2 SPD 3 SP 4 CHT 5 CAL 6 TTEN 7 AC CODE SAMPLE# UNIT BYTES 68 1 API 4 68 1 F/MM 4 68 1 MV 4 68 1 LB 4 68 1 IN 4 68 1 LB 4 68 1 US/F 4 * DATA RECORD (TYPE# 0) 998 BYTES * DEPTH GR SPD SP CAL TTEN AC -999.2500 -999.2500 6460.000 -999.2500 -999.2500 -999.2500 -999.2500 6410.000 65.60141 38.65109 4.148441 13.29233 2691.534 97.03310 6360.000 62.79269 40.65091 4.089845 11.59776 2652.610 95.38535 6310.000 64.81841 39.21449 5.769663 11.81555 2685.059 90.85199 6260.000 61.24014 11.27672 2622.054 6210.000 57.34802 11.76771 2590.829 40.12260 5.087549 103.8897 40.76012 5.966169 101.3230 0.0000000E+00 6.460989 50.000O0 6160.000 56.53886 11.37283 1000.000 CHT -999.2500 93172.25 93081.00 93023.87 93049.31 93042.75 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 22 6460.00 ENDING TAPE DEPTH = 6130.00 FILE # 8 REPEAT. 008 **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 20 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 GR 68 1 API 4 2 CAL 68 1 IN 4 3 SSD 68 1 CTS 4 4 SHR 68 1 CTS 4 5 RB 68 1 DEG 4 6 DEV 68 1 DEG 4 7 CHT 68 1 LB 4 8 TTEN 68 1 LB 4 9 SPD 68 1 F/FM 4 10 SFT2 68 1 CTS 4 11 HRD1 68 1 CTS 4 12 HRD2 68 1 CTS 4 13 LSN 68 1 CTS 4 14 SSN 68 1 CTS 4 15 CN 68 1 PCT 4 16 CNC 68 1 PCT 4 17 ZDEN 68 1 GMCC 4 18 ZCOR 68 1 GMCC 4 19 PE 68 1 BARN 4 20 PORZ 68 1 PCT 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH GR CAL SSD SHR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 6460.000 -999.2500 -999.2500 -999.2500 -999.2500 6410.000 -12.25978 890.5200 36.44670 16.06792 6360.000 -12.25978 827.9482 34.99989 15.98145 6310.000 -12.25978 869.9341 31.51639 15.42826 -999.2500 -999.2500 -999.2500 -999.2500 72.25812 356.1531 1069.543 35.62083 73.77440 356.1531 1008.288 34.38098 65.60237 356.1531 1058.406 30.62572 -999.2500 -999.2500 -999.2500 -999.2500 13.12692 94416.00 1360.451 2.384879 12.85764 94416.00 1284.263 2.386306 13.72548 94416.00 1296.747 2.395433 -999.2500 -999.2500 -999.2500 -999.2500 7715.840 2799.778 40.00191 0.2110299E-01 7491.145 2628.932 41.61031 0.8917991E-02 7770.500 2635.407 48.29761 0.3738374E-01 -999.2500 -999.2500 -999.2500 -999.2500 0.5881261 21.45210 153.7658 2.986007 0.5314289 22.99770 155.8772 3.579967 0.6315861 22.99770 168.9389 2.577003 6260.000 -12.25978 870.8843 36.43651 16.28374 69.36526 356.1531 1067.582 35.31712 13.66747 94416.00 1339.476 2.381318 7850.719 2654.398 43.23500 0.4134721E-01 0.5656700 22.99770 166.1644 3.119578 6210.000 66.48418 14.36247 8826.285 0.5978900 -12.25978 356.1531 94416.00 2604.641 22.99770 1044.631 1228.895 1560.177 40.43201 148.6949 34.01443 32.73750 2.357652 0.1149051 2.918104 17.71806 6160.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 51 6460.00 ENDING TAPE DEPTH = 6160.00 **** TAPE TRAILER **** LIS 90/09/02 4573 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 1799 **** REEL TRAILER **** LIS 90/09/02 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : TOTAL RECORDS IN THIS PHYSICAL REEL: End of execution: Thu 13 SEP 90 2:38p Elapsed execution time = 2 minutes, 55.9 SYSTEM RETURN CODE = 0 1800 1800 seconds.