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195-055
By Samantha Carlisle at 8:53 am, Jun 16, 2020 320-264 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.15 17:17:35 -08'00' Taylor Wellman DLB 06/16/20 10-404X gls 6/16/20 DSR-6/16/2020 6/18/2020 dts 6/16/2020 JLC 6/16/2020 RBDMS HEW 6/16/2020 Proposed Perfs ill • II Seth Nolan Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 8 Hilrnrp AT, Istoka. m RECEIVED Fax: 907 777-85100 E-mail: snolan@hilcorp.com AUG 2 9 2017 ADATA LOGGED DATE 08/28/2017 — "O�� M.K.BENDER To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant II 333 W 7th Ave Ste 100 Anchorage, AK 195-055 2855 01-144 28558 99501 205-117 28557 201-231 28559 DATA TRANSMITTAL PEARL STRATIGRAPHIC TESTS Log digital raster data CD: 1 Electric logs re KBU 31-07RD_induction.pdf 9/19/2013 4:27 PM PDF Document 15,5771 KBU 31-07RD_induction.tf 9/18/20139:34 AM TIF File 797 KB i. Lte KBU_31 U7RD_mudlag.pdf 8/14/20178:54 AM PDF Document 1,129 KB • 1,33U_31-07RD_mudlog,of 8/14/20178:47 AM TIF File 3,3620 TO KTU43-6XRD2_ML_MD.pdf 9/1/2005 10:31 AM PDF Document 2,026 KB • KTU43-6XRD2_ML_MD.ti f 8/14/20178:53 AM TIF File 3,701 KB re KU_24-05RD_mudlog,pdf 8/14/20178:54 AM PDF Document 561 KB • KU_24-05RD_mudlog.of 8/14/20178:45 AM TIF File 2,677 KB KIJ_43-06RD_mudlog.pdf 8/14/2017 8:54 AM PDF Document 1,022 KB LC KU 43-06RD_mudlog.tif 8/14/20178:46 AM TIF File 3,362KB Please include current contact information if different from above. SCANNED SEP 1 22017 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: � Date: • M Marathon MARATHON Oil Company November 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 C~ p ~~'~" Field: Kenai Gas Field Well: Kenai Beluga Unit 31-7RD Dear Mr. Maunder: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 31-7RD well. This report covers the capillary string installation performed under Sundry #308-333. The capillary string was installed on 10/30/2008 and set at a depth of 7,220' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ' tom/ ~ei~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ~/~~~~~ ALA~OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Install Performed: Alter Casing ^ Puil Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Capillary String Change Approved Program ^ Operat. Shutdown [] Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory^ 195-055 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20347-01-00~ 7. KB Elevation (ft): 9. Well Name and Number: 95.5' (26' AGL) - Kenai Belu a Unit 31-7RD 8. Property Designation: 10. Field/Pool(s): A - 028142 i Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7575' ~ feet Plugs (measured) 7,550' true vertical 7,167' - feet Junk (measured) NA Effective Depth measured 7,550' feet true vertical 7,142' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 120' 120' 1,530 psi 5,020 psi Surface 2,500' 13-3/8" 2,526' 2,459' 1,540 psi 3,090 psi Intermediate 5,654' 9-5/8" 5,680' 5,389' 6,870 psi 4,750 psi Production 7,549' 7" 7,575' 7,167' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: 6,832' - 7,534' True Vertical depth: 6,110' - 7,090' Capillary Tubing 3/8" 2205 SS 7,220' Tubing: (size, grade, & MD) Production Tubing 3-1/2" N-80 6,444' Packers and SSSV (type and measured depth) Baker 84 - 40x32 SAB Packer 6,306' 12. Stimulation or cement squeeze summary: Intervals treated (measured): A 3/8" Stainless Steel capillary string was installed to a setting depth of 7,220' MD. This string will be utilized as a foamer injection path to Treatment descriptions including volumes used and f+nal pressure: help mitigate wellbore fluid accumulation. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,630 5.2 190 350 Subsequent to operation: 0 1,700 - 235 440 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ - Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ - WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-333 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineeing Technician Signature Phone (907) 283-1371 Date November 17, 2008 Form 10-404 Revised 04/2006~~- ( ~y~-I~ ubmit Original Only l~ ~~~~ ~ operations Summary Report ~ „~,Q„T„D„ S~j~CornP~~f Well Name: KENAI BELUGA UNIT 31-7 Uaily Operations Report Date: 10f31f2008 Job Category: R&M MAIMTEMANCE 2t h r Summary MIRU Dyna coil, run capillary string SZ3rtTlne E~tlTtne Der 0 Code Af.'W Cote opa SfldS TroeDkCOtle Canme~t 08:00 09:00 1 .00 SAFETY MTG AF Held PJSM and discussed safety issues around well head, working in cold conditions, pinch points and overall operations. 09:00 11:00 2.00 RURD COIL AF MI spot equipment. Mu new 318" SS reel. Decide to use the trailer unit and not the heli decked unit to run cap string. MU new threaded connection on ree ca . 11:00 12:00 1 .00 RURD COIL AF PU injector hang the BHA chemical mandrel on 318" capillary string, Set pressure ~ 3700 psig to open, go to well. MU pack off theaded end up to he tree. 12:00 13:00 1 .00 RURD COIL AF PT tree ca to 2500 si no leaks. Open well. RIH with 3P8" capillary string at 60 FPM. 13:00 14:00 1 .00 RK COIL AF Ca illar strip down to 7220' KBD. Set strip PU and rig off of injector. 14:00 11:00 3.00 RURD COIL AF Remove the 3~" SS tubing away from the injector. PU reel and craddled up in tote at well head. Cleaned up around well head and unit. 17:00 18:00 1 .00 RURD COIL AF PU new reel of tubing for next reel. BJ Dyna coil left location. www.peloton.com Report Printed: 11M4f20118 #: 195-055 50-133-20347-01-00 ~ty Des: A - 028142 :vation: 95.5' (26' AGL) I Spud Date: 9/12/1995 te: 9/20/1995 Teased: 9/30/1995 Tree cap: 4-3/4" Otis (on dual tree) 3-1/2", 9.2#, N-80, IBT tubing to 6,444' Camco sidepocket injection mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' @ 6350', ID = 2.813" @ 6412', ID = 2.813" Re-entry Guide @ 6444' KBU 31-7RD ~ Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11W, S.M. MARATHON I ' Conductor 20" 94 ppf i+ .i.; , Top Bottom ~' M D 0' 120' ~~ /~ M TVD 0' 120' LB- 6,509'-6,543' HSC 2-3/8" 4spf 60° (3-14-08) LB- 6,705'-6,715' HSC 2-3/8" 4spf 90° (3-12-08) LB-8 6,832'-6,842' LB-8 6,862'-6,882' LB-9 6,890'-6,900' LB-10 6,940'-6,993' $/04 LB-10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' 7,141'-7,146' 7,180'-7,193' 7,207'-7,212' 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' Cement top at 7,550' MD Q Surface Casing 13-3/8" K-55 61 ppf 8< 68 ppf Top Bottom MD 0' 2,526' TVD 0' 2,459' Cmt w/ 1,400 sks of Class G Intermediate Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 5,680' TVD 0' 5,389' Cmt w/ 2,010 sks of Class G Production Casing 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' TVD 0' 7,167' Cmt w/ 791 sks of Class G Caaillary String 3/8" 2205 Stainless Steel Top Bottom MD 0' 7,220' TVD 0' 6,816' TD PBTD 7,575' MD 7,550' MD 7,167' TVD 7,142' TVD Fill: -~~ , 7460' KB (5/04) Well Name & Number: Kenai Beluga Unit 31-7 ReDrill Lease: A - 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° / 100' @ 1,000' KOP (TVD): 991' Date Completed: 10/10/1995 Ground Level (above MSL): 69.5' RKB (above GL): 26' Revised by: Kevin Skiba Last Revision Date: 11/14/08 M Marathon MARATHON Oil Company November 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Beluga Unit 31-7RD Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 1a~"des Dear Mr. Maunder: The AOGCC approved Marathon's requested to install a velocity string in KBU 31-7RD well on July 5, 2007, under sundry approval #307-218. BJ Dynacoil's presence on the Kenai Peninsula has provided Marathon with another viable option to remove wellbore fluids. Marathon has elected not to install the velocity string at this time. Plans are to utilize a capillary string for foamer injection on KBU 31-7RD. The AOGCC recently granted approval for this capillary string installation. Since the velocity string is not going to be instalied, Sundry #307-218 is being closed out as a non- work activity. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Je~~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS ii 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Non-Work of Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Velocity String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ installation 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory^ 195-055 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20347-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 95' (26' AGL) . Kenai Belu a Unit 31-7 ReDrill 8. Property Designation: 10. Field/Pool(s): A-028142 ~ Kenai Gas Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 7,575' ~ feet Plugs (measured) 7,550' true vertical 7,167' - feet Junk (measured) NA Effective Depth measured 7,550' feet true vertical 7,142' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 20" 120' 120' 1,530 psi 5,020 psi Surface 2,500' 13-3/8" 2,526' 2,459' 1,540 psi 3,090 psi Intermediate 5,654' 9-5/8" 5,680' 5,389' 6,870 psi 4,750 psi Production 7,549' 7" 7,575' 7,167' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: 6,832' - 7,534' True Vertical depth: 6,110' - 7,090' Tubing: (size, grade, and MD) 3-1/2" N-80 6,444' Baker 84 - 40x32 SAB Packers and SSSV (type and measured depth) Packer 6,306' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Marathon has elected not to deploy a velocity string in KBU 31-7RD. This sundry is being closed out as a non-work activity. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 i Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ^~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-218 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~ ~ Signature ~ Phone (907) 283-1371 Date November 14, 2008 Form 10-404 Revised 04/2006 ?"'~ f 5 ~ ~:, I ~' ~ ,r-±,t ~ r~~w' ~ ~s ?QQ~ Submit Original Only ~~~`~~ ~# ~ t ~ k ~ ~: ; "1 ~...' • "" ~ SA RAH PALIN, GOVERNOR CO7~TL+Z1~~j~=O ~ ~~+~ 333 W. 7th AVENUE, SUITE 100 is-7L ~i 1.~~~`~~'~~~...lll~~=•iil ----777 0l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Kevin Skiba FAX (907) 276-7542 Engineering Technician Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 ~~~~~ ~ ~ ~ a~ G~ 20~~ 5s \~~. o Re: Kenai Gas Fleld, Upper Tyonek/Beluga Gas Pooi, 3I -7RD Sundry Number: 308-333 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission shown, a person affected by it may file with the Commiss on an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. hd Chair DATED this day of September, 2008 Encl. ~ E. • M Marathon MARATHON Oil Company September 16, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 31-7RD Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ';~ ~ g ~lask~ 9i1 ~ Gay ~~ ~~. ~ :,, O~~ ~~~ Marathon proposes to run a 3/8" capillary string in KBU 31-7RD to mitigate water loading. Setting depth of the capillary string should be roughly 7,200' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application for Sundry Approvals Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS MDD ' ~ v` ,'1~~~~ STATE OF ALASKA ~~ ~C ~ ~~ ~y`~ ~ ~ ~// o ~ALA~ OIL AND GAS CONSERVATION COMt~ON M ~~( CEP APPLICATION FOR SUNDRY APPROVALS ~~ ~ ~ 2~0 20 AAC 25.280 i r' . '' , 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waive Other ~ A hor,... Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension 'Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String , 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ ~ Exploratory ^ 195-055 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20347-01-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ ^ Kenai Beluga Unit 31-7RD _ Spacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~Q A - 028142 95.5' (29:5' AGL) Kenai Gas Field /Beluga Formation 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,575' l 7,167' ~ 7,550' 7,142' 7,550' NA Casing Length Size MD TVD Burst Collapse Structural Conductor 95' 20" 95' 95' 1,530 psi 5,020 psi Surface 2496.5' 13-3/8" 2,526' 2,459' 1,540 psi 3,090 psi Intermediate 5650.5' 9-5/8" 5,680' 5,389' 6,870 Psi 4,750 psi Production 7,545.5' 7" 7,575' 7,167' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,832' - 7,534' 6,110' - 7,090' 3-1 /2" N-80 6,444' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 84 - 40x32 SAB Packer 6,306' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development Q . Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2008 Oil ^ Gas ^~ ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ ~ P ne (g07) 283-1371 Date September 16, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -3D~'3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ar°'~ ~ ~ ~ ! ni ~ n APPROVED BY '` ' Approved by: COMMISSIONER ~ THE COMMISSION Date: ~~~/ /~ Form 10-403 Revised 06/2006 ~' ~~ ,.~f'~ ~ ,~ ~~~~ Submit in Duplicate 2008 Capillary String Installation • • Page 1 2008 Capillary String Installation Program #2 KGF, SU, NGF KBU 24-7X -Requested KBU 14-6Y -Requested KBU 31-7RD -Requested SU 41-15RD -Requested FC 3 -Requested NS 3 -Requested NS 1 -Requested Objective 1) Install six new CICM's (injection skids) with 545 gallon totes of foamer at wellheads. 2) Install capillary strings (3/8" 2205 0.049" WT) into seven wells for delivering foamer to alleviate liquid loading. Procedure Companies involved: BJDC, BJCS, UOSS, Big G Setting Setting String Estimated Depth Depth Spool Setting Fluid Maximum Tag Above Under PT Max Order Well Len th De th Level Perf De th De th Fill Water Well Notes ID ran 1 KBU 24-7X 9000' 7965' 7850' 8141' 8165' 300' 115' Exca a 1.75 2 KBU 14-6Y 8000' 7050' 7000' 7138' 7132' 82 50' Exca a 1.69 3 KBU 31-7RD 8000' 7220' 7120' 7534' 7392' 172 100' 1.75 4 SU 41-15RD 12000' 10400' 10300' 11506' 11498' 98 100' Exca a 1.75 5 FC 3 10000' 2720' 2615' Gas from SS 7770' N/'~' 105' Lon strip 6 NS 3 11000' 9785' 9550' 10862' 10970' 1185' 235' 4-1/2" 2 7 NS 1 9000' 8733' None 8956' 10220' 1487 0 4-1/2" 2 Installation Procedure: 1) BJCS and ASRC: (PJSM & JSA~ a) Place 6 new CICM skids at listed wells (BJCS, Steve Bolton, 252-9864) - deliver with truck (Oilfield Hotshot Service, Billy Hill, 398-4827) - unload CICM from truck with loader (ASRC Hardline Group, Tony, 294-0548) -unbolt and remove CICM roof with loader and place 545 gal foamer tote with loader - replace CICM roof with boom truck (DOSS, Tom David) and bolt roof b) Install CICM internals (BJCS, Steve Bolton, 252-9864). 2) COGZ work order (contact Senette's groin a) Electrical hookup of CICM. b) Tubing hookup of CICM. 2008 Capillary String Installation ~ • Page 2 3) UOSS -pull well house 4) BJDC, UOSS (PJSM and JSA): 1. Have on site: proper spool, Wayne's Well Head Adapter (long/short both), Sundry. Well Control Standards Sheet. 2. MIRU BJ Dyna-Coil unit. 3. Shut swab valve, pull tree-cap flange, remove snap ring and OTIS blanking plug. Replace plug with WWHA (note o-ring). MU flange. 4. P1U Dyna-Coil injector with UOSS crane, install BJDC packoff assembly into 2-718" female connection. NOTE: a wrench or tongs may be needed to hold the adapter 5. Set Fluid Control Valve release (set based upon TVD, but OVER) 6. MU BHA with centralizers and secure to 318" string. 7. SHUT IN WELL AT WING VALVE to prevent BHA from traveling into flow-tee and down flowline. NOTE: Operator or Company Supervisor may bring well back on after string is below flow-tee 8. RIH to setting depth. 9. Set Rattiguns. Leave 1.5 times SITP (or greater per BJDC) on hydraulic pack off. 10. OPEN WELL TO PRODUCTION 11. Leave remaining spool of tubing outside of well in plastic tote for soap injection skid hookup. 12. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge and HP filter. 13. Lockout Swab, Upper Master and Lower Master as per Capstring Lockout Procedure. 14. Hookup injection line to CICM. NOTE: Start foamer at 1/2 gpd, slowly raising the level to planned rate as the week progresses. CHECK FOR FOAM RETURNS. 15. RDMO. Cleanup site. Sign-out. NOTE: When replacing well house, be careful of the tubing "bend" if it extends through the roof 5) UOSS -replace well house 50-133-20347-01-00 ty Des: A - 028142 vation: 95.5' 29.5' (above GL) Spud Date: 9/12/1995 e: 9/20/1995 leased: 9/30/1995 Tree cap: 4-3/4" Otis (on dual tree) 3-1/2", 9.2#, N-80, IBT tubing to 6,444' sidepocket injection mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' fipple @ 6350', ID = 2.813" fipple @ 6412', ID = 2.813" reline Re-entry Guide @ 6444' KBU 31-7RD Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11 W, S.M. • Nu-~-nioN Drive Pipe 20" 94 ppf ' Top Bottom MD Surf 95' ND Surf 95' Surface Casing 13-3/8" K-55 61 ppf & 68 ppf Top Bottom MD 0' 2,526' ND 0' 2,459' Cmt w/ 1,400 sks of Class G Intermed iate Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 5,680' ND 0' 5,389' Cmt w/ 2,010 sks of Class G LB- 6,509'-6,543' HSC 2-3/8" 4spf 60° (3-14-O8j LB- 6,705'-6,715' NSC 2-3/8" 4spf 90° (3-12-08) LB-8 6,832'-6,842' LB-8 6,862'-6,882' LB-9 6,890'-6,900' LB-10 6,940'-6,993' 8/04 LB-10 7,012'-7,031' 7, 080'-7,114' 7,125'-7,137' 7,141'-7,146' 7,180'-7,193' 7,207'-7,212' 7,225'-7,231' FraC'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7, 512'-7, 516' 7,529'-7,534' Production Casing 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' ND 0' 7,167' Cmt w/ 791 sks of Class G ~ 6 ~ Q a ~ 9 ~ ~ ~ a ~ TD PBTD 7,575' MD 7,550' MD 7,167' ND 7,142' ND Fill: ~~ 7460' KB (5/04) Cement top at 7,550' MD Well Name & Number: Kenai Beluga Unit 31-7 ReDrill Lease: A - 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° / 100' ~ 1,000' KOP (TVD): 991' Date Completed: 10/10/1995 Ground Level (above MSL): 66' RKB (above GL): 29.5' ~, vises by:~ tiev;r Skiba ~~ 50-133-20347-01-00 tv Des: A - 028142 vation: 95.5' 29.5' (above GL) Spud Date: 9/12/1995 ~: 9/20/1995 eased: 9/30/1995 Tree cap: 4-3/4" Otis (on dual tree) 3-1/2", 9.2#, N-80, IBT tubing to 6,444' Camco sidepocket injection mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' @ 6350', I D = 2.813" @ 6412', I D = 2.813" Re-entry Guide @ 6444' KBU 31-7RD Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11 W, S.M. Active Perfs (Beluga Formation) LB- 6,509'-6,543' HSC 2-3/8" 4spf 60° (3-14-08) LB- 6,705'-6,715' HSC 2-3/8" 4spf 90° (3-12-08) LB-8 6,832'-6,842' LB-8 6,862'-6,882' LB-9 6,890'-6,900' LB-10 6,940'-6,993' 8/04 LB-10 7,012'-7,031' 7, 080'-7,114' 7,125'-7,137' 7,141'-7,146' 7,180'-7,193' 7,207'-7,212' 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' TD PBTD 7,575' MD 7,550' MD 7,167' TVD 7,142' TVD MAiGTMOM Surface Casing 13-3/8" K-55 61 ppf & 68 ppf Top Bottom MD 0' 2,526' TVD 0' 2,459' Cmt w/ 1,400 sks of Class G Intermediate Casing 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 5,680' TVD 0' 5,389' Cmt w/ 2,010 sks of Class G Production Casing 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' TVD 0' 7,167' Cmt w/ 791 sks of Class G Drive Pipe 20" 94 ppf Top Bottom MD Surf 95' TVD Surf 95' Fill: ~~ 7460' KB (5/04) Cement top at 7,550' MD Well Name & Number: Kenai Beluga Unit 31-7 ReDrill Lease: A- 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° / 100' ~ 1,000' KOP (TVD): 991' Date Completed: 10/10/1995 Ground Level (above MSL): 66' RKB (above GL): 29.5' Revised by: Kevin Skiba Last Revision Date: 09/16/08 M Marathon MARATHON Oil Company April 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave -~~ ~ 5 Anchorage, Alaska 99501 ~~5 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 31-7RL? Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~/ V Alma APR ~ ' 2048 .~ ~~~ c ~11l Attached for your records is the 10-404 Sundry Report for KBU 31-7RD well. This sundry covers the perforation work completed under Sundry #308-063. Forty four feet of perforations were added to the Beluga Zone at 6,509'-6,543' and 6,705'-6,715'. Initial gas production increases by 1,650mcf at 449psi. / Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, `! ~.J .~~U-r~ 5~~~ MAY 1 ~ 200 Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Operations Summary Current Well Schematic cc: Houston Well File Kenai Well File KJS WEC STATE OF ALASKA ' ~~~~~ ALA~-.,~ OIL AND GAS CONSERVATION COMNIr~ION ~~` AP REPORT OF SUNDRY WELL OPERATIONS ecu~, R 0 ~ 2048 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~A_ ° Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ~ Waiver^ Time Extension U "~'~V "~/n ~ Change Approved Program ^ Operat. Shutdown ^ Pertorate ^~ Re-enter Suspended Well ^ ~~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development Q Exploratory^ 195-055 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20347-01-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 95.5' Kenai Belu a Unit 31-7 eDrill 8. Property Designation: 10. Field/Pool(s): up~,,y-(~Ja~x~„~(c ~,~~ ~~ A - 028142 • Kenai Gas Field / I 11. Present Well Condition Summary: ~ •a Total Depth measured 7,575' feet Plugs (measured) 7,550' true vertical 7,167' feet Junk (measured) NA Effective Depth measured 7,550' feet true vertical 7,142' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 65.5' 20" 95' 95' 1530 5,020 psi Surface 2496.5' 13-318" 2,526' 2,459' 1540 3,090 psi Intermediate 5650.5' 9-5/8" 5,680' 5,389' 6870 4,750 psi Production 7,545.5' 7" 7,575' 7,167' 8160 7,020 psi Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 6,832' - 7,534' True Vertical depth: 6,110' - 7,090' Tubing: (size, grade, and measured depth) 3-112" N-80 6,444' Packers and SSSV (type and measured depth) Baker 84 - 40x32 SAB Packer 6,306' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,050 4.3 176 247 Subsequent to operation: 0 2,700 ,/ 2.7 229 449 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-063 Contact Kevin Skiba (907) 283-1371 Printed Name Wayne E. Ciss I _~ Title Work Over Supervisor Signature I Phone (907) 283-1308 Date April 3, 2008 Form 10-404 Revised 04/20 ~ `~ ~F' ~n D 1 I ` I ~ ! / \ I ~5~ ` ` ~/,~,bmit Origi al Only o ~- y ~. ~ Marathon Oil Company Page 1 of 2 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 31-7 Common Well Name: KENAI BELUGA UNIT 31-7 Spud Date: 12/15/1981 Event Name: MAINTENANCE/REPAIR Start: 3/13/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hotirs Code Code Phase Description of Operations 3/13/2008 08:00 - 08:20 0.33 RURD_ ELEC CMPPRF Start and spot equipment. 08:20 - 09:00 0.67 SAFETY MTG_ CMPPRF Obtain Permit. Hold PJSM and discuss Expro JSA. Discuss slips and trips, location has a couple of icy spots. 09:00 - 10:13 1.22 RURD_ ELEC CMPPRF RU lubricator. PU 2-3/8" Shot dummy guns and spangs, jars. 10:13 - 10:30 0.28 TEST_ EOIP CMPPRF PTest lubricator to 1500 psi. 10:30 - 10:57 0.45 RUNPU ELEC CMPPRF Open well. 230 psi on well. Well flowing. RIH to 6750'. No problems. Have operations shut well in to obtain desired underbalance. 10:57 - 11:35 0.63 RUNPU ELEC CMPPRF POOH. 11:35 - 11:57 0.37 SAFETY MTG_ CMPPRF Hold Explosives Safety Meeting . Shut down all cell phone. Post signage. Station guard at gate. 11:57 - 12:13 0.27 RURD_ ELEC CMPPRF Arm guns. Carry to well head. Test OTS. Test good. 12:13 - 13:10 0.95 RUNPU ELEC CMPPRF Open well (669 psi.) RIH w/ 10' of 2-3/8" HSC 4 spf, 90 degree phased guns w/ PX-1 initiator. 13:10 - 13:50 0.67 RUNPU ELEC CMPPRF Pull up into position and wait for well to build pressure. 13:50 - 14:22 0.53 PERF_ CSG_ CMPPRF WHP 900 psi. Shoot guns @ 6705-6715' (OHlCH). 4 spf 90 degree phased. POOH. Time Pressure 10:50 900 psi 10:52 910 psi 10:58 920 psi NO big pressure response but, well seems to be building pressure at a slightly faster rate. Well shut in monitored on Skaida. Shut-in approximately 1-1l2 hours prior to shooting. Well shot at 10:50 and allowed to continue building up until guns were OOH. Then it was turned back over to production operations. 14:22 - 15:30 1.13 RURD_ ELEC CMPPRF OOH. Confirm guns fired. Guns were wet and full of mud. RD. 15:30 - 16:00 0.50 SECUR WELL CMPPRF Secure well and location. Turn in Permit. Leave loc. 3/15/2008 07:45 - 08:10 0.42 RURD_ ELEC CMPPRF Start and spot equipment. 08:10 - 08:30 0.33 SAFETY MTG_ CMPPRF Obtain Permit. Hold PJSM and discuss Expro JSA. Discuss slips and trips, location has a couple of icy spots. 08:30 - 09:20 0.83 RURD_ ELEC CMPPRF RU lubricator. 09:20 - 09:42 0.37 SAFETY MTG_ CMPPRF Hold Explosives Safety Meeting . Shut down all cell phone. Post signage. Station guard at gate. 09:42 - 10:00 0.30 TEST_ EOIP CMPPRF Arm guns. Carry to well head. PTest lubricator to 1500 psi. 10:00 - 10:20 0.33 RURD_ ELEC CMPPRF Bleed off lubricator. Replace o-ring on bottom of OTS. PTest to 1500 psi. Test good. 10:20 - 11:20 1.00 RUNPU ELEC CMPPRF Open wel. Well flowing 240 psi @ 1.2 MMscf.) RIH w/ 14' of 2-3/8" HSC 4 spf, 60 degree phased guns w/ PX-1 initiator. 11:20 - 11:30 0.17 RUNPU ELEC CMPPRF Run correlation log. 11:30 - 11:40 0.17 RUNPU ELEC CMPPRF Pull up into position and wait for well to build pressure. 11:40 - 12:20 0.67 PERF_ CSG_ CMPPRF WHP 500 psi. Shoot 14' of guns @ 6529'-6543' (OH/CH). 4 spf 90 degree phased. POOH. Time Pressure 11:40 500 psi 11:42 520 psi 11:43 540 psi 11:44 565 psi 11:45 580 psi 11:49 670 psi 11:51 700 psi 11:55 790 psi 12:00 860 psi YflfllBtl: 4/S/LUUC 'J:S.S:UJ HM ~ ` l F~* I~ `+*§.~ Marathon Oil Company Page 2 of 2 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 31-7 Common Well Name: KENAI BELUGA UNIT 31-7 Spud Date: 12/15/1981 Event Name: MAINTENANCE/REPAIR Start: 3/13/2008 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hotars Code Code Phase Description of Operations 3!15!2008 11:40 - 12:20 0.67 PERF CSG_ CMPPRF 12:10 980 psi 12:15 1020 psi NO big pressure response but, change of slope noticed on Skaida Well shut in monitored on Skaida. Shut-in approximately 1-1/2 hours prior to shooting. Well shot at 10:50 and allowed to continue building up until guns were OOH. Then it was turned back over to production operations. 12:20 - 12:30 0.17 RURD_ ELEC CMPPRF OOH. Confirm guns fired. Guns were wet and full of mud. 12:30 - 14:45 2.25 WAITON EOIP CMPPRF Turn well over to production. Choke washs out almost immediately. Shut well in to change chokes. 14:45 - 17:00 2.25 FLOW TEST CMPPRF Production gets well flowing. 17:00 - 17:40 0.67 RUNPU ELEC CMPPRF RIH (2) w/ 20' of 2-3/8" HSC 4 spf, 60 degree phased guns w/ PX-1initiator. WHP 680 psi. 17:40 - 18:40 1.00 PERF_ CSG_ CMPPRF Pull up into position. Shoot 6509- 6529' (OHlCH). POOH. Run correlation log. 17:58 680 psi. 18:03 820 psi 18:20 1040 psi. 18:40 - 19:30 0.83 Time ELEC CMPPRF OOH. RD. 19:30 - 20:00 0.50 11:40 WELL CMPPRF Secure well and location. Turn in Permit. Leave loc. Printed: 4!3/2008 9:53:03 AM #: 195-055 50-133-20347-01-00 ty Des: A - 028142 vation: 95.5' 29.5' (above GL) Saud Date: 9/12/1995 e: 9/20/1995 eased: 9/30/1995 Tree cap: 4-3/4" Otis (on dual tree) 3-1/2", 9.2#, N-80, IBT tubing to 6,444' Camco sidepocket injection mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' @ 6350', ID = 2.813" @ 6412', ID = 2.813" Re-entry Guide @6444' KBU 31-7RD Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11W, S.M. 6,509'-6,543' HSC 2-3/8" 4spf 60° (3-14-08) 6,705'-6,715' HSC 2-3/8" 4spf 90° (3-12-08) 8 6,832'-6,842' 8 6,862'-6,882' 9 6,890'-6,900' 10 6,940'-6,993' 8/04 10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' 7,141'-7,146' 7,180'-7,193' 7,207'-7,212' 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' ~ C ~ C ~ C ~ C ~ G r L ~ ~ o ~ *„ y ~~ ~ -mo t:, TD PBTD 7,575' MD 7,550' MD 7,167' TVD 7,142' TVD MARATHON Surface Casino 13-318" K-55 61 ppf & 68 ppf Top Bottom MD 0' 2,526' TVD 0' 2,459' Cmt w/ 1,400 sks of Class G Intermediate Casinst 9-518" N-80 47 ppf BTC Top Bottom MD 0' 5,680' TVD 0' 5,389' Cmt w/ 2,010 sks of Class G Production Casins~ 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' TVD 0' 7,167' Cmt wl 791 sks of Class G Drive Pipe 20" 94 ppf Top Bottom MD 0' 95' TVD 0' 95' Fill: ~~~-E~~ ~~~ 7460' KB (5/04) Well Name & Number: Kenai Beluga Unit 31-7RD Lease: A - 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° / 100' @ 1,000' KOP (TVD): 991' Date Completed: 10/10/1995 Ground Level (above MSL): 66' RKB (above GL): 29.5' Prepared By: Mike Sulley Last Revision Date: 03/20/08 • • ~~'~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ SARAH PAUN, GOVERNOR AijAS~A Ojj, A1QD CjcA5 333 W. 7th AVENUE, SUITE 100 C01~5ER'QA'1'IO1~T COr'II~II551O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis M. Donovan Production Engineer Marathon Oil Company 5~ PO BOX 1949 ~ ~ '' d Kenai, Alaska 99611-1949 1 Re: Kenai Gas Field, Beluga Gas Pool, Kenai Beluga Unit 31-7 ReDrill Sundry Number: 308-063 ~~;~~~ FEB ~ ~ 200 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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 to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED thisZ? day of February, 2008 Encl. • M Marathon MARATHON Oil Company February 20, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field Well: Kenai Beluga Unit 31-7 ReDrill Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~,~,~~® 'f~~B 2 ~ _?flQ~ p-laska Oil ~ ~$ ' ' ~, Commss~g~ Anchar~ge Marathon requests permission to enhance gas production from KBU 31-7RD well by adding perforations to the Lower Beluga sands. Plans are to add perforations above the existing perforations at 6,509' - 6,543' and from 6,705'-6,715' measured depths. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ` ~~ ~.A ;j1C~ Kevin J. Ski a Production Technician Enclosures: 10-403 Sundry Notice Work Scope Procedure Current Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS DMD ORIGINAL n ~ ~/t ~~ STATE OF ALASKA °'?V~~~~~~~ ALA OIL AND GAS CONSERVATION COM~SION ~~;~~~ FHB 2 ,0 ~V APPLICATION FOR SUNDRY APPROVALS ~~ 20 AAC 25.280 Ale~l.® na 4. r_.,., r,.~.. 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate^ Waiver ~OrB~ they Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 195-055 3. Address: Stratigraphic ^ Service ^ 6. API Number. PO Box 1949, Kenai Alaska, 99611-1949 50-133-20347 01-00 7. If perforating., closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ S i E i R ~ ^ Kenai Beluga Unit 31-7 ReDrill pac ng xcept on equired? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A - 028142 95.5' f Kenai Gas Field /Beluga Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,575' 7,167' 7,550' 7,142' 7,550' NA Casing Length Size MD TVD Burst Collapse Structural Conductor 65.5' 20" 95' 95' 1,530 psi 5,020 psi Surface 2496.5' 13-3/8" 2,526' 2,459' 1,540 Psi 3,090 psi Intermediate 5650.5' 9-5/8" 5,680' 5,389' 6,870 psi 4,750 psi Production 7,545.5' 7" 7,575' 7,167' 8,160 Psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,832' - 7,534' 6,110' - 7,090' 3-1/2" N-80 6,444' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 84 - 40x32 SAB Packer 6,306' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 20, 2008 Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature ~ Phone Date (907) 283-1333 February 20, 2008 • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ,~~ ~ (~ ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~Q ` ~~, n~~ ~~~ ~~ ~~ ~ ~ ~ ~ ~. ~> ~, Subsequent Form Required: ~O L ~°> ~"~~~ .~ ,~~~~i APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: i Form 10-4 Revised 06/2006 Submit in Duplicate M MARATHON MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 31-7rd Add perfs WBS # W0.07.15663.CAP.001 History: Well KBU 31-7rd. Objective: Perforate Lower Beluga sand. OUTLINE PROCEDURE: ~. Run dummy perf gun to 6750' MD. 2. Perforate Lower beluga from 6,509' - 6,543' & 6705' - 6715' 3. Turn over to production and request a well test. PROCEDURE: ~. RU Expro and run a dummy pert gun to 6750' MD. 2. PERFORATE LOWER BELUGA: PU 10' pert gun and RIH to pert depth. Tie into open hole logs. 3. Shut in well and allow wellhead pressure to increase to 900 psi. SHWHP = 950 psi. Well needs 1 hour to reach 900 psi surface pressure. 4. Perforate from 6,509' - 6,543' & from 6,705' - 6,715'. Note any pressure response after each perforating run. 5. POOH. s. Open well to production. ~. RD Expro. 8. Turn well over to production and request a well test. PROPOSED LOWER BELUGA PERFORATIONS Measured Depth TVD 6509`- 6543' (34ft) 6110' - 6144' 6705`- 6715' (loft) 6303' - 6313' CONTACTS Mickey Mullin: 907-283-1337 (w) 907-398-9954 (c) SBHP 1000 psi Ken Walsh: Surface Wellhead Pressure 900 psi 907-283-1311 (w) 907-394-3060 (c) it #: 195-055 50-133-20347-01-00 ~rtv Des: A - 028142 levation: 95.5' 29.5' (above GL) ill Spud Date: 9/12/1995 ate: 9/20/1995 .eleased: 9/30/1995 Tree cap: 4-3/4" Otis (on dual tree) 3-1/2", 9.2#, N-80, IBT tubing to 6,444' co sidepocket injection mandrel @ 1012' 80-40 K-Anchor @ 6304' 84-40x32 SAB Packer @ 6306' @ 6350', ID = 2.813" @ 6412', ID = 2.813" Re-entry Guide @ 6444' Active Perfs {Beluga Formation} LB-8 6,832'-6,842' LB-8 6,862'-6,882' LB-s s,sso'-s,soo' 8/04 LB-10 6,940'-6,993' LB-10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' 1 F 'd 7,141'-7,146' rac ( 7,180'-7,193' J 7,207'-7,212' 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7, 480' 7,490'-7,508' 7,512'-7,516` 7,529'-7,534' KBU 31-7RD Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11W, S.M. • MarurNON Drive Pipe 20" 94 ppf Top Bottom MD 0' 95' TVD 0' 95' ~c c ~ c ~ C ~ c L ~ ~ ~ ~ TD PBTD 7,575' MD 7,550' MD 7,167' TVD 7,142' TVD Surface Casing 13-318" K-55 61 ppf 8 68 ppf Top Bottom MD 0' 2,526' TVD 0' 2,459' Cmt wl 1,400 sks of Class G Intermed iate Casing 9-518" N-80 47 ppf BTC Top Bottom MD 0' 5,680' TVD 0' 5,389' Cmt w/ 2,010 sks of Class G Production Casing 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' TVD 0' 7,167' Cmt wl 791 sks of Class G Fill: _~ ~~ 7460' KB (5104) Well Name & Number: Kenai Beluga Unit 31-7RD Lease: A - 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° 1100' a~ 1,000' KOP (TVD): 991' Date Completed 10/10/1995 Ground Level (above MSL): 66' RKB (above GL)' 29.5' ~' , ~ Kevin SkiE~a ~ L~~ Revision Date: 02I12I08 KBU 31-7RD ermit #: 195-055 PI #: 50-133-20347-01-00 ropertv Des: A - 028142 B Elevation: 95.5' B: 29.5' (above GL) eDrill Spud Date: 9/12/1995 ~ Date: 9/20/1995 ict Released: 9/30/1995 et: Ong: Tree cap: 4-3/4" Otis (on dual tree) Pad 14-6 406' FSL, 1,306' FWL Sec. 7, T4N, R11 W, S.M. PROPOSED 3-1/2", 9.2#, N-80, IBT tubing to 6,444' sidepocket injection mandrel @ 1012' 80-40 K-Anchor @ 6304' 84-40x32 SAB Packer @ 6306' @ 6350', ID = 2.813" @ 6412', I D = 2.813" Re-entry Guide @ 6444' 8 6,832'- 6,842' 8 6,862'- 6,882' 9 6,890'- 6,900' r 10 6,940'- 6,993' L 10 7,012'- 7,031' 7,080'- 7,114' 7,125'- 7,137' 7,141'- 7,146' C 7,180'- 7,193' L 7,207'- 7,212' 7,225'- 7,231' 7,250'- 7,326' r 7,388'- 7,420' L 7,452'- 7,480' 7,490'- 7,508' 7,512'- 7,516' 7,529'- 7,534' ~ C ~ C ~ rc L ~ ~ ~.' '. TD PBTD 7,575' MD 7,550' MD 7,167' TVG 7,142' TVD MARATHON Surface Casing 13-318" K-55 81 ppf & 68 ppf Top Bottom MD 0' 2,526' TVD 0' 2,459' Cmt w/ 1,400 sks of Class G Intermediate Casino 9-5/8" N-80 47 ppf BTC Top Bottom MD 0' 5,680' TVD 0' 5,389' Cmt w/ 2,010 sks of Class G Production Casino 7" N-80 29 ppf BTC Top Bottom MD 0' 7,575' TVD 0' 7,167' Cmt w/ 791 sks of Class G Drive Piae 20" 94 ppf Top Bottom M D 0' 95' TVD 0' 95' Fill: _~ ~~~ ~~ 7460' KB (5/04) Well Name & Number: Kenai Beluga Unit 31-7RD Lease: A - 028142 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth (MD): 1.35° / 100' @ 1,000' KOP (TVD): 991' Date Completed: 1 011 0/1 99 5 Ground Level (above MSL): 66' RKB (above GL): 29.5' Prepared By: Kevin Skiba Last Revision Date: 02/12/08 swAid/8TH®t3 AlasTca Asset Team United States Production Operations December 4, 2007 P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 FedEx Alaska Oil & Gas Conservation Commission ~ ,, Attn: Howard Okland ~~~ ~~~ ~i ~ ~~~ 333 W. 7~ Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon KDU #5 -API 50-133-20319-00 Marathon KBU #41-7 -API 50-133-20327-00 Marathon KBU #31-7RD -API 50-133-20347-01 t~ Marathon BC #9 -API 50-133-20445-00 CONFIDENTIAL Dear Mr. Okland: Enclosed is one CD containing confidential core data for the above referenced wells. The Summary of Core Analyses Results document included alt the wells in one document. I've included the original document, and have also saved each well out to a separate document for your files. Summary of Core Analyses Results: KDUS_KBU41-7 KBU31-7RD_BC9_Summary_of Core Analsyis.pdf Separate Documents for each Well of Summary of Core Analyses Results: KDUS_50133203190000_Core_Analsyis_Surnm.pdf KBU41-7_50133203270000_Core Analsyis_Summ.pdf KBU31-7RD_50133203470100_Core_Analsyis_Summ.pdf BC9_50133204450000 Core Analsyis_Summ.pdf Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-499-8504. Thank you, Kaynell Zeman Engineering Tech Enclosure Received by: Date: 7 ~ e,~~•~w- _ a~ (~ ~~ ~~s-~s~ . ~V~VŒ lID~ ~~~~[K(~ . AI~ASIiA OILA5D GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 lQ5-055 Re: Kenai Gas Field, Beluga Tyonek Gas Pool, Kenai Beluga Units 31-7 Sundry Number: 307 -218 Dear Mr. Donovan: SCANNED JUl 0 6 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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 to Superior Court unless rehearing has been requested. Sincerely, DATED this 6' day of July, 2007 Enc!. . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 Marathon Oil Company June 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 RECEI\!E JUN 2 5·· ")n1'\7 . (UU! Alaska Oil & Gas Anch~f~e Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 14-6 Well: Kenai Beluga Unit 31-7 redrill Dear Mr. Maunder: We propose to run a 1.75" velocity string in KBU #31-7rd. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, well bore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. Sinc~ ' Dennis Donova~ Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File DMD KJS 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 ~UËN~ge Other [] Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 V-String Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil ComDanv Development [] Exploratory 0 195-055 ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20347-01-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0...,./ No [] Kenai Beluga Unit 31-7 redrill / 9. Property Designation:,. _. "-"- , ¿-Ç¡?ð? 10. KB Elevation (ft): 11. Field/Pool(s): ~~\\,)<::ft i''lo''-.t:\i.. «<'c:. Ç>oo \ 406'FSL, 1306'FVVL,Sec. 7, T4N, R11VV, S.M. 29.5 Kenai Gas Field, Pad 14-6 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7550' 7142' 7305' 6899' 7550' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 95' 20" 95' 95' 1530 psi 5020 psi Surface 2526' 13-3/8" 2526' 2459' 1540 psi 3090 psi Intermediate 5680' 9-5/8" 5680' 5389' 6870 psi 4750 psi Production 7575' 7" 7575' 7163' 8160 psi 7020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6832'-7534' 6428'-7090' 3-1/2" N-80 6444' Packers and SSSV Type: Baker 84-40x32 SAB Packer Packers and SSSV MD (ft): 6306' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program [] BOP Sketch 0 Exploratory 0 Development [] Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 16-Aug-07 Oil 0 Gas [] Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis Donovan Title Production Engineer Signature ~, ~1\.. Phone (907) 283-1333 Date 13-Jun-07 ~ - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L ~~Î .. r::l/ R Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~ç~~-:.ì. <..\ \SCJ'?~+- Û~ ~\o..\{'\ "'~0 So",",,,"',, F,~ Reqo;,e,t '-\C)~ RBDMS 8FL JUL 0 6 2DD7 J ";j APPROVED BY ?,.~,.or- Approved by: J "f/U -/ COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 crF<1 ~ -N ~ ~~DuPlicate £: RECEIVED . /5/ STATE OF ALASKA ¿ ,ð7 C¡{f 7 A~ OIL AND GAS CONSERVATION COM ION ~ I#N 2 5 2007 APPLICATION FOR SUNDRY APPROVALS O" & G C f' . 'S5'On 20 MC 25.280 - Naška I as on5. l10mml I . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field, Pad 14-6 Kenai Beluga Unit 31-7 redrill 2007 CT Velocity String Hangoff Procedure Notes: . This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. . Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. Bj CoilTech supervisor will drift all VVH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real-time Flowina Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PjSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro VVireline. 2. Install Coil Tubina Head. 3. Make flowline modifications for coil tubina velocity strina. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back eQuipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubina unit with Bj work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assembly (WHA). Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install Bj coil tubing connector and pull test to 15,000 Ibs. Nipple up injector to VVHA. 7. Pressure test suñace lines and CT eQuipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, VVHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in wellbore. (ONLY IF FILL IN VVELL IS COVERING PERFORATIONS) MU Bj CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off VVHA. MU velocity string BHA to end of CT. . . Page 2 of2 10. Nipple UP injector to WHA. Pressure test VVHA using CT kill line (200/1500 psi). Bleed VVHP to flow back tank. Prior to next Step, ensure that flowback line from VVHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubina velocitv strina and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubina. PUH to span WHA for final landing depth. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release VVHP above tubing rams to the flowback tank. Nipple injector off of VVHA. VValk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from VVH. Vetco to connect VGCT Coil Tubing Hanger. VVhile Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 Ibs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanaer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. VVatch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purae N2 from CT remainina in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. KBU 31-7rd Pad 14-6, Kenai Gas Field J API: 50-133-20347 AOGCC: 85-153 RT-MSL (Original Drlg): 29.5' KB-THF 406' FSL, 1306'FVVL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on duai tree) Tubinq Strinq - 3-1/2", 9.2#, N-80, IBT tubing to 6,444' Cameo sidepocket inj mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' X-nipple @ 6350' ID = 2.813" X-nipple @ 6412' ID = 2.813" Wireline Re-entry Guide @ 6444' Fill: 7551' (4/97) 7513' MD (5/98) 7513' KB (5/99) 7460' KB (5/04) L 120",94#, drivepipe @ 95" 13-3/8",61&68 #, K-55, BTC Surface Casing @ 2526' Cmt w/1400 sks of class "G" ..... 9-5/8",47#, N-80, BTC @ 5,680' Cmt w/ 2010 sks of class "G" Active Perfs (Beluqa Formation) LB-8 6,832'-6,842' } LB-8 6,862'-6,882' LB-9 6,890'-6,900' 8/04 LB-106,940'-6,993' LB-10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' } 7,141'-7,146' Frac'd 7,180'-7,193' 7,207'-7,212' } 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' 7",29#, N-80, BTC, 7,575' Cmt w/ 791 sks of class "G" POSED KBU 31- Pad 14-6, Kenai Gas Field J API: 50-133-20347 AOGCC: 85-153 RT-MSL (Original Drlg): 29.5' KB-THF 406'FSL,1306'FVVL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on dual tree) Tubinq Strinq - 3-1/2", 9.2#, N-80, IBT tubing to 6,444' Cameo sidepocket inj mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' X-nipple @ 6350' ID = 2.813" X-nipple @ 6412' ID = 2.813" Wireline Re-entry Guide @ 6444' Fill: 7551' (1/97) 7513' MD (5/98) 7513' KB (5/99) 7460' KB (5/04) 13-3/8",61&68 #, K-55, BTC Surface Casing @ 2526' Cmt w/1400 sks of class "G" iIII.. 9-5/8",47#, N-80, BTC @ 5,680' Cmt w/ 2010 sks of class "G" Active Perfs (Beluqa Formation) LB-8 6,832'-6,842' } LB-8 6,862'-6,882' LB-9 6,890'-6,900' 8/04 LB-10 6,940'-6,993' LB-10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' } 7,141'-7,146' Frac'd 7,180'-7,193' 7,207'-7,212' } 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' 7",29#, N-80, BTC, 7,575' Cmt w/ 791 sks of class "G" STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION ~ECE 1\ Ir: REPORT OF SUNDRY WELL OPERATIONs" nrT 1 4 2004 1. Operations Abandon U RepairWell U Plug Perforations U Stimulate U Other U Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverO Alaska~ðfì~"" """,.",¡S:¡iUII Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended A'fflJ1{illJage 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 Exploratory 0 195"()55 3. Address: P. O. Box 196168, Anchorage, AI< 99519- Stratigraphic 0 Service 0 6. API Number: 6168 50-133-20347"()1 7. KB Elevation (ft): 9. Well Name and Number: 95' KB KBU 31-7rd 8. Property Designation: 10. Field/Pool(s): Kenai Beluga Unit Kenai Gas Field/ Beluga 11. Present Well Condition Summary: Total Depth measured 7550 feet Plugs (measured) N/A true vertical 7142 feet Junk (measured) fill-7460' Effective Depth measured 7305 feet true vertical 6899 feet Casing Length Size MD ìVD Burst Collapse Structural Conductor 95' 20" 95' 95' 1530 520 Surface 2526' 13-3/8" 2526' 2459' 3090 1540 Intermediate 5671' 9-5/8" 5671' 5389' 6870 4750 Production 7575' 7" 7575' 7163' 8160 7020 Liner Perforation depth: Measured depth: 7080-7529 (238' net) True Vertical depth: 6674'-7090' Tubing: (size, grade, and measured depth) 3-1/2" N-80 6444' Packers and SSSV (type and measured depth) Pkr: Baker 84-40x32 SAE Pkr: 6306' 12. Stimulation or cement squeeze summary: 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-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1600 255 Subsequent to operation: 1590 450 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations 2 daily reports 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 304-315 Contact Denise Titus Printed Name Denise M. Titus Title Production Engineer Signature Phone 907.283.1333 Date ;0 / I~ / Ii Lf' Form 10-404 Revised 04/2004 0 R , G 1 ~, A , ~fd)r¡) ~inal Only MARATHON OIL COMPANY Page 1 of 2 Daily Recompletion Report Increase Production WELL NAME KB IGL 124 HR PROG TMD TVD IDFSO I DOLO IRPT#1 DATE KENAI BELUGA UNIT 31-7 29.5 66.00 13-Auo-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Denise Titus WO041 0833EXP FIELD NAME RIG PHONE MOCWI NRI 1 DAILY WELL COST I CUM WELL COST KENAI 13,950 () 13,950 0 STATE/PROV COUNTY/OTHER LAST CASING 1 NEXT CASING I LEAKOFF Alaska Kenai t!ù 0 (in) t!ù 0 (ft) CURRENT STATUS@6AM 124 HR FORECAST Riooed back for niaht Flow overnioht and resume oerforatina in AM OPERATION COMMENTS Perforate 6940'-6933' and 7012'-7031' (LB-10). Rig back. Will attempt to flow over night. SA~~ I y' CH II ........u MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT ~EGULATORY INSP? LAST RIG INSPECTION 91.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBl DESCRIPTION 07:30 08:30 1.00 AF CMPPRF SAFETY MTG Sign in, obtain work permit, hold safety and procedure meeting. 08:30 10:30 2.00 AF CMPPRF MOB RIG- Spot equipment on well location. Provide air compressor for Expro test pump. Well house does not have walkway. Call for man lift. Shut well in for perforating (to avoid excess drawdown). 10:30 11:30 1.00 TA CMPPRF vV AITOf\ EQIP LOWE Continue to RU and wait on manlift. 11:30 12:30 1.00 AF CMPPRF RURD- ELEC Manlift delivered to location. Continue to RU equipment and work on test pump. 12:30 14:30 2.00 TA CMPPRF vVAITOf\ EQIP LOWE Attempt to RU. Swab valve + master valves will not hold pressure. Call out Vetco to grease valves. 14:30 15:00 0.50 AF CMPPRF RURD ELEC RU BOPs to wellhead. Pwh=1100psi. 15:00 16:00 1.00 AF CMPPRF PULD- PGUN Make up tool string and lubricator. Pick up 19' gun #1 with PX-1 safe firing head. Pressure test lubrictor using Expro test pump to 2000psi 16:00 18:15 2.25 AF CMPPRF RUNPUL ELEC RIH wI gun #1. Initially had problems getting gun to fall. Suspect hydraulic lock. Work line until gun will fall freely. RIH to perforating interval. 18:15 18:45 0.50 AF CMPPRF LOG - CSG - Correlate on depth. Pull into position and perforate the LB-10 zone from 7012'-7031'. 18:45 19:25 0.67 AF CMPPRF RUNPUL ELEC POOH wI carrier. 19:25 19:45 0.33 AF CMPPRF PULD PGUN At surface with gun #1. All shots fired. Pwh=1100psi. MU gun #2. 19:45 20:30 0.75 AF CMPPRF RUNPUL ANCH RIH wI 27' gun #2 to approximate depth. 20:30 20:45 0.25 AF CMPPRF LOG - CSG - Correlate on depth. Position gun and perforate 6966'-6993'. Good indication of firing in the truck. 20:45 21:25 0.67 AF CMPPRF RUNPUL ELEC POOH wI gun #2. 21:25 21:45 0.33 AF CMPPRF PULD PGUN At surface, all shots fired. Pwh=1100psi. PU 26' gun #3. 21:45 22:35 0.83 AF CMPPRF RUNPUL ELEC RIH wI gun #3. 22:35 22:45 0.17 AF CMPPRF LOG - CSG - Correlate and position gun. Perforate 6940'-6966'. Questionable indication of detonation. 22:45 23:25 0.67 AF CMPPRF RUNPUL ELEC At surface. All shots fired. 23:25 00:00 0.58 AF CMPPRF RURD- ELEC Lay down lubricator. Night cap BOPs. Secure remaining perforating guns and location for night. Printed: 9/24/2004 11:37:13AM MARATHON OIL COMPANY Page 1 of 1 Daily Recompletion Report Increase Production WELL NAME KB IGL 124 HR PROG TMD TVD IDFSO ¡DOLO IRPT#2 DATE KENAI BELUGA UNIT 31-7 29.5 66.00 14-AuQ-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Denise Titus WO0410833EXP FIELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST KENAI 13,450 0 27,400 0 STATE/PROV COUNTY/OTHER LAST CASING I NEXT CASING 1 LEAKOFF Alaska Kenai @ 0 (in) t!ù 0 (ft) CURRENT STATUS@ 6AM 124 HR FORECAST Flow overniaht and resume Derforatina in AM OPERATION COMMENTS Well flowed to system at 1700MCFD at 800psi. Perforate with well flowing LB-8 6832'-6842' & 6862'-6882' and LB-96890'-6900'. Well flowing to test separator at 1900MCFD at 700psi. ~Ar-'" y ~I ........u MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 25.50 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 09:30 09:45 0.25 CMPPRF SAFETY MTG Sign in, obtain permit, hold safety meeting 09:45 10:30 0.75 CMPPRF PULD PGUN PU lubricator and arm gun #4. 10:30 11:25 0.92 CMPPRF ,UNPUL ELEC RIH wI 10' gun to correlating depth 11:25 11:30 0.08 CMPPRF LOG - CSG - Correlate and perforate LB-9 zone 6890'-6900' with good indication in truck. 11:30 12:15 0.75 CMPPRF ,UNPUL ELEC POOH wI fired gun. 12:15 12:30 0.25 CMPPRF PULD PGUN PU 20' gun #5. 12:30 13:30 1.00 CMPPRF ,UNPUL ELEC RIH wI gun to correlating depth. 13:30 13:35 0.08 CMPPRF LOG- CSG- Log on depth. Pull into position and perforate LB-8 6862'-6882'. Pwh=800psi. 13:35 14:20 0.75 CMPPRF ,UNPUL ELEC POOH wI gun. 14:20 14:35 0.25 CMPPRF PULD- PGUN At surface, all shots fired. Pwh=800psi (well still flowing to system about 1700 MCFD). PU gun #6. 14:35 15:20 0.75 CMPPRF ,UNPUL ELEC RIH wI 20' gun #6 15:20 15:25 0.08 CMPPRF LOG CSG Correlate and perforate LB-8, 6832'-6842'. 15:25 16:00 0.58 CMPPRF ,UNPUL ELEC POOH to surface. 16:00 18:00 2.00 CMPPRF RURD ELEC Perforating complete. Rig down Expro. PERSONNEL DATA POB @ 06:00: COMPANY I SERVICE I NO. I HOURS II COMPANY I SERVICE I NO. I HOURS Expro I Perforating I 31 25.50 II I I I LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE ID I SHOE TEST MAX SICP I MD I ìVD I WT I GRADE I BURST Printed: 9/24/2004 11 :36:21 AM ~ KBU 31-7rd Pad 14-6, Kenai Gas Field J API: 50-133-20347 AOGCC: 85-153 RT-MSL (Original Drlg): 29.5' KB-THF 406'FSL,1306'FVVL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on dual tree) Tubina Strine - 3-1/2",9.2#, N-80, IBT tubing to 6,444' Camco sidepocket inj mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' X-nipple @ 6350' ID = 2.813" X-nipple @ 6412' ID = 2.813" Wireline Re-entry Guide @ 6444' Fill: 7551' (1/97) 7513' MD (5/98) 7513' KB (5.'99) 7460' KB (5/04) :::8 :::8 ::I :::8 =- ] :::8 :=II l 120",94#, drivepipe @ 95" 13-3/8",61&68 #, K-55, BTC Surface Casing @ 2526' Cmt wI 1400 sks of class "G" .. 9-5/8",47#, N-80, BTC @ 5,680' Cmt wI 2010 sks of class "G" Active Perfs lBeluaa Formation) -= -= r::: Ie: Ie: [ LB-8 6,832'-6,842' LB-8 6,862'-6,882' LB-9 6,890'-6,900' LB-10 6,940'-6,993' LB-10 7,012'-7,031' 7,080'-7,114' 7,125'-7,137' } 7,141'-7,146' Frac'd 7,180'-7,193' 7,207'-7,212' } 7,225'-7,231' Frac'd 7,250'-7,326' 7,388-7,420' 7,452'-7,480' 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' } 8/04 Ie: Ie: 7",29#, N-80, BTC, 7,575' Cmt wI 791 sks of class "G" Alaska Business Unit Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 October 12,2004 RECEIVED OCT 1 4 2004 AI;¡sk@ em 8. r...~ ,..~.¡.. ....~ -, . . - ""'" ""UI ~. ....ùfnrl1'SS!M At;eh~fØdtl Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KBU 31-7rd Dear Mr. Aubert: Enclosed is the 10-404 Report of Sundry Well Operations. The proposed work to add perforations in Kenai Gas Field well KBU 31-7rd was completed 8/14/04. I have also included a Daily Recompletion Report and an updated wellbore diagram for your review. If you require any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, r /7/ ~..\. (., \ll~/.II., //11 "\Jv.- /1, " Lv ,¡ /'- Denise M. Titus Production Engineer /' Enclosures ,,--... ~ ¿ M J Marathon MARATHON Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 10,2004 ~~ Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W th Ave Anchorage, Alaska 99501 Reference: KBU 31-7rd Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approval. The proposed work is to add perforations in Kenai Gas Field well KBU 31-7rd. This work is expected to begin 8/16/2004. I have also included a procedure and well bore diagram for your review. If you require any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus@marathonoil.com. Sincerely, !!~1~ Denise M. Titus Production Engineer Enclosures - - OR\G\NAL /"""",, ~ ~'-1/í fJr;-J 6" ¿./ ¿'UV"!- 0/ /2( tJ- 1. Type of Request: STATE OF ALASKA ALA~r<A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: / Development 0 Stratigraphic D Suspend Repairwell D Pull Tubing D Exploratory D Service D I Waiver Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: t q 5 ~ 05S jUlJ,f- it-' GK"' 50-133-20347 - 0 ( Annular Dispos. Other D Abandon Alter casing D Change approved program D 2. Operator Name: Marathon Oil Company 3. Address: PO Box 1949, Kenai, AK 99611 7. KB Elevation (ft): 95' KB 6. API Number: 8. Property Designation: Kenai Beluga Unit 9. Well Name and Number: KBU 31-7rd / 10. Field/Pools(s): Kenai Gas Field/ Beluga 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 7550 7142 7305 6899 N/A Length Size MD TVD Junk (measured): fill-7460' Casing Structural Conductor Burst Collapse Surface Intermediate 13-3/8" 9-5/8" 95' 2526' 5671' 7575' 95' 2459' 5389' 7163' 1530 3090 6870 8160 520 1540 4750 7020 Production Liner 95' 2526' 5671' 7575' 20" 7" Perforation Depth MD (ft): 7080-7529 (238' net) Packers and SSSV Type: Perforation Depth TVD (ft): Tubing Size: 6674'-7090' 3-1/2" Packer: Baker 84-40x32 SAB SSSV: N/A Tubing Grade: N-80 Packers and SSSV MD (ft): Tubing MD (ft): 6444' Packer: 6306' Date: 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed wyrk: 8/16/2004 Oil D Gas 0 / Plugged WAG D GINJ D WINJ Service D 12. Attachments: Description Summary of Proposal .J Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: D D Abandoned WDSPL D D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name enise. Titu Title Production Engineer 907-283-1333 Signature Phone 907-394-2733 Date COMMISSION USE ONLY 8/9/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3D - IS- Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Approved by: 4 RBDMS 8fL AUG 1 1 ')nm COMMISSIONER INSTRUCTIONS ON REVERSE ~ ~, (1:4) MARATHON OIL COMPANY ALASKA BUSINESS UNIT Kenai Gas Field ~U,sl:-:JJZD Add Peñorations was # WO.O4.1 0475.EXP History: KBU 31- 7rd is a KGF Beluga well completed with a single 3-112" tubing string in 7" casing. The tubing was installed shallow to permit the addition of up hole perfs. Many ofthe existing perforations are ftac stimulated. There are two X-nipples in the tubing (ID=2.813" at 6350' and at 6412'). Current SITP=146Opsi with a SffiHP= 180Opsi. Objective: Add perforations in the LB8, LB9, and LBI0 zones. /' Procedure: 1. Hold safety and environmental awareness meeting. 2. MI Expro wire line service with full lubricator (pump in sub and flow tubes), and BOPE. 3. Perform safety meeting outlining job procedures and concerns. Pressure test / lubricator and equipment to 3000 psi with methanol. 4. RIH with gun Gamma Ray, CCL, and 2-3/8" guns. Correlate to existing log. Perforate the following zones: LB-8 LB-8 LB-9 LB-10 LB-10 6,832'-6,842' 6,862'-6,882' 6,890'-6,900' 6,940'-6,993' 7,012'-7,031' (10') (20') (10') (53') (19') 5. Turn well to sales following completion oftesting. Release rental equipment and return to vendors. 6. Bullhead with high pressure gas if needed to kick off well. Be watchful of potential sand production. CLU #7 Non-Rig Completion Procedure Page 1 ~ ~ .~ KBU 31-7rd Pad 14-6, Kenai Gas Field J API: 50-133-20347 AOGCC: 85-153 RT-MSL (Original Drlg): 29.5' KB-THF 406' FSL, 1306'FVVL Sec. 7, T4N, R11W, S.M. Lift threads: ??? Tree cap: 4-3/4" Otis (on dual tree) Tubino Strino - 3-1/2",9.2#, N-80, IBT tubing to 6,444' Camco side pocket inj mandrel @ 1012' Baker 80-40 K-Anchor @ 6304' Baker 84-40x32 SAB Packer @ 6306' X-nipple @ 6350' ID = 2.813" X-nipple @ 6412' ID = 2.813" Wireline Re-entry Guide @ 6444' Fill: 7551' (1/97) 7513' MD (5/98) 7513' KB (5/99) 7460' KB (5/04) =- =- ::J =- =- ] =- =- L 120",94#, drivepipe @ 95" 13-3/8",61&68 #, K-55, BTC Surface Casing @ 2526' Cmt w/1400 sks of class "G" ~ 9-5/8",47#, N-80, BTC @ 5,680' Cmt w/ 2010 sks of class "G" &444 Active Perfs (Beluoa Formation) 7,080'-7,114' } Frac'd 7,125'-7,137' -= 7,141'-7,146' -= I:: 7'180'-7'193' } -= 7,207'-7,212' -= 7,225'-7,231' Frac'd [ 7,250'-7,326' 7,388-7,420' -= 7,452'-7,480' -= 7,490'-7,508' 7,512'-7,516' 7,529'-7,534' 7",29#, N-80, BTC, 7,575' Cmt w/ 791 sks of class "G" ( 1 MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X -06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177 -029 KEU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-179 KBU 44-06 ~.~(Cfìl~NElD JAN 2 @ 2004 Alaska. gion Domestic Production Marathon Oil Company .. P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 29. 1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage. AK 99501-3192 The following logs are enclosed: Kenai Gas Field Kenai Gas Field 43-6X-RD Core Analysis Report Kenai Gas Field 43-6X-RD Core Description Kenai Gas Field 31-7RD Core Analysis Report Ouantitv This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures A subsidiary of USX Corporation Received By: Date: Alask~ jion Domes.._ Production _ Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 25.1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed: Kenai Gas Field LOGS 1 ) KBU 31-7RD Production r,..oo: Auaust.. =~..'~° 1996 2) KBU 31-7RD Therma[ Decay Time Tool August 21. 1996 Beaver Creek Print 1 Film 1 LOGS 3) BC-9 Completi.on Record 2.5 HSD August 13. 1996 4) BC-9 Completion Record 2.5 HSD August 9. 1996 This data is considered confidential until the normal released date. MAR,X, THON OIL COMPANY T4:"~ten K. Gamel ~IICIOSuFC: A subsidiary of USX Corporation Received By: t--~ r-,~_ ~-- ~ Date: JUL 2 8 1997 ~.~ma oi & oas r.3ons. Commission Anchorage Environmentally aware for the long run. ?3- 7F PERMIT DATA AOGCC Individual Well Geological Materials Inventory DATA_PLUS Page' 1 Date' 07/28/97 RUN DATE_RECVD 95-055 AIT/GR ~676-7494 1 12/01/95 95-055 LDT/N ~/~76-7570 1 12/01/95 95-055 PERF 95-055 PERF MLTI ISOTOPE 95-055 95-055 NGR SPEC 95-055 PLUG SET 95-055 DISI/GR 95-055 CMRI 95-055 CET 95-055 CBL 95-055 FMI ~6880-7379 ~//6896-7386 SP ~/~800-7413 ~W~76-7540 /400-7555 ~5676-7445 ~/~700-7430 ~00-7550 ~/~900-7528 ~700-7420 10/26/95 1 01/02/96 11/06/95 1 01/02/96 1 01/02/96 1 12/01/95 1 12/01/95 1 12/01/95 1 12/01/95 1 12/01/95 12/01/95 ~ ~,,~.0 1 12/01/95 10-407 DAILY WELL OPS ¥/ o '// / Are dry ditch samples requ~ir_ed? yes ~ And received? yes Was the well cored? ~____~po ~alysis__a de~scription received? Are well tests required? lyes Well is in compliance Initial COMMENTS Received? yes ~ "' .... STATE OF ALASKA /' .$KA OIL AND GAS CONSERVATION C ..... MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS~ SUSPENDED~ ABANDONED~ SERVICE~ 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 95-55 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20347-01 4. Location of Well at Surface ~,~.i.~,,i~:~.~ 9. Unit or Lease Name 406' FSL, 1306' FWL, Sec. 6, T4N, R11W, S.M. i:" ".:;.~;{~. ~i .: ,'.; -,.: ; .... .......... h__-.,l~;,,~. Kenai Beluga Unit : ..... ;,~, At top of Producing Interval u ' "--/~-:'/'~;'/~. ;~,',)~ j~'' ' 10. Well Number 1056' FNL, 2524' FVVL, Sec. 7, T4N, R11W, S.M. (~ 6673' TV ! , :'~ ' ~-~.~-~ KBU 31-7rd At Total Depth."~'~,,~.~.~."~'?:~: ~"~'i' i 1 . Field and Pool 1073' FNL, 2607' FWL, Sec. 7, T4N, R11W, S.M. {~ 7163' TVD - ~ "' .~ Kenai Gas Field/Beluga ,.~ __- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. 95' KBI A-028142 12. Date Spudded9/9/95 : 13. Date T.D. Reached 9/21/95 - 7575' TVD 14. Date Comp., Susp. or Aband. 17' T°tal Depth (MD+TVD)7575, MD/7163' TVD 18' Plug Back Depth (MD+TVD):19' Directi°nal SurveY7556, MD/7144' TVD Yes, ,Noir] [---1~ 120' Depth where sssV set N/A feet MD 121' Thickness °f Permafr°st IN/A / 22. Type Electric or Other Logs Run LDT/CNT/GNT, CMR/GR, FMI/GR, CET/CBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 0' 95' DRIVEN 13-3/8" 61/68~ K-55 0' 2526' 17-1/2" 1400 SX 9-5/8" 47# N-80 0' 5671' 12-1/4" 2010 SX 7" 29~ P-110 0' 7575' 8-1/2 740 SX 24 Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-112" 6445' 6306' See attached Perforation Summary 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Cement Squeeze See attached Operation Summary Rpt Fracture Treatment See attached Operation Summary Rpt 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 10/13/95 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/22_/96 24 TEST PERIOD -~ 3016 0.4 I FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1490 psig 0 psig 24-HOUR RATE ---~ 3016 0.4 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Description. Core 1; 6078-6082.5' Core 2: 7130-7190' Form 10-407 Submit in Triplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Middle Beluga 5685' 5298' Lower Beluga 6420' 6015' See attached Operations Summary 31. LIST OF ATTACHMENTS Operations Summary Report, Perforation Summary, Wellbore Diagram, Directional Survey, Core Descriptions 32. I hereby certify that the foregoing is true and correct to the best of my knowledge \, Title ~_~ ~ ~ , ~ ~ P-~- Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-sltu 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 2'1: 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores take,, indicate "none". Form 10-407 H:\EXCEL~IRSFORMS~AOGCOMPL.XLW APR 04 l~;¢G PETROLEUM SERVICES ! ! MARATHON OIL CO. CORE ANALYSIS REPORT 31-7 J~ KENAI GAS FIELD KENAI, ALASKA CL FILE NO. BP-3-1587 Performed by' Core Laboratori es 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented December 6, 1995 JUL 50 199'! Oil & Gas ~ns. Commission And~omge These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (aLl errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oil, gas or other mineral well or formation in connection with which such report is used or relied upon. Core Laboratories, Inc. 8005 Schoon Street, Anchorage, Alaska 99518-3045. (907) 349-3541, Fax (907) 344-2823 INTRODUCTION Core Laboratories was requested to sample and perform a core analysis study on behalf of Marathon Oil Co. on core samples recovered from the 31-7 well in September 1995, Kenai, Alaska. Here are the results of this study. Service description and methodology are presented in section 1. The core analysis results with descriptions are presented in section 2. Graphical depiction and statistical summary are presented in section 3. Data diskette is presented in section 4. We sincerely appreciate this opportunity to be of service and hope this data prove beneficial in the development of this reservoir. mm mmmmm m m mmm MARATHON OIL COMPANY 31 -7 KENAI GAS FIELD KENAI, ALASKA CORE LABORATORIES FILE: BP-3-1587 DATE: 13-OCT-95 ANALYSTS: PB, DS, DA I OVERBURDEN COR SMPL DEPTH PRESSURE # # FT PSI G PERMEABIUTYKAiRMD I POROSITY (HELIUM) (%) 6087.8 atto 18.9 2300 6.23 18.0 6097.4 atm 19.2 2300 2.76 18.0 6100.8 atto 18.0 2300 53.0 17.1 6102.3 atto 17.9 2300 50.0 1 6.7 6106.2 atto 18.8 2300 16.1 1 7.7 6128.5 atto 14.8 2300 0.1 4 1 3.7 6132.5 atto 23.2 2300 9.93 20.4 7130.7 atto 16.9 2850 1.72 1 5.9 7144.5 arm 1 5.0 2850 0.81 1 4.2 7146.6 arm 16.5 2850 0.49 1 5.6 7150.2 atto 1 7.3 2850 0.49 1 7.0 DEAN STARK ANALYSIS HORIZONTAL PLUG SAMPLES % Pv I % Pv i GM/CC DESCRIPTION 0.0 89.7 2.72 SS-vltgy, m-cgr,pred mgr, pcmt, modsrtd,sbang,lith,cly 0.0 91.2 2.71 SS-vltgy,fgr, pcmt, modsrtd,sbang,lith,cly,c 0.0 80.6 2.71 SS-Itgy, m-vcgr,pred mgr,pcmtd,modsrtd,sbang,lith,cly,calc 0.0 82.2 2.71 SS-Itgy,m-cgr,pred mgr, pcmt, sbang,lith,cly,calc 0.0 86.4 2.71 SS-Itgy,m-cgr,pred mgr, pcmt, sbang,modsrtd,lith,cly 0.0 98.4 2.62 SS-ltgy,vf-fgr, predvfgr, modcmt, wsrtd,sbang,c,lith,cly 0.0 71.5 2.72 SS-Itgy,f-mgr,predfgr,pcmt, sbang,wsrtd,lith,cly,calc 0.0 83.1 2.72 SS-mltgy,vf-fgr, prevfgr, pcmt, sbang,wsrtd,lith,cly,calc 0.0 92.6 2.73 SS-Itgy,f-mgr,predfgr,pcmt, sbang,wsrtd,lith,cly, calc, broken 0.0 91.1 2.73 SS-Itgy,vfgr,wcmt, sbang,wsrtd,lith,cly,calc 0.0 89.4 2.73 SS-Itgy,f-mgr,predfgr,wcmt, sbang,wsrtd,lith,cly,slcalc MARATHON OIL COMPANY 31 -7 KENAI GAS FIELD KENAI, ALASKA COR SMPL # # DEPTH FT OVERBURDEN PRESSURE P~G PERM EABI UTY KAIR MD 2 2 2 2 2 2 2 4 7156.2 5 7158.8 6 716O.6 7 71 63.7 8 7180.1 9 7187.9 10 7190.0 atm 285O atm 2850 atm 285O atm 285O atm 2850 atm 285O arm 2850 1.97 1.64 4.33 0.74 O.29 0.82 0.04 POROSITY (HEUUM) (%) 16.0 15.3 16.4 15.6 18.1 16.8 16.0 15.4 16.9 16.0 16.3 16.0 15.3 15.4 CORE LABORATORIES FILE' BP-3-1587 DATE: 13-OCT-95 ANALYSTS: P B, D S, DA DEAN STARK ANALYSIS HORIZONTAL PLUG SAMPLES SATURATIONS[GRAIN OIL I WATERI DENSITY %Pr I %Pv I GM/CC DESC RI PTI ON 0.0 86.8 2.73 SS-vltgy,fgr, wcmt, wsrtd,sbang,lith,cly,calc 0.0 92.2 2.73 SS-Itgy,f-mgr,pred mgr, wcmt, sbang,wsdd,lith,slcalc 0.0 91.2 2.72 SS-Itgy,f-mgr,pred mgr, pcmt, sbang,wsrtd,lith,cly,calc 0.0 86.8 2.73 SS-Itgy,f-mgr,predfgr,wcmt, sbang,msrtd,lith,cly,calc 0.0 73.0 2.74 SS-Itgy,vfgr, pcmt, sbang,wsrtd,lith,sltylams,cly 0.0 86.6 2.72 SS-Itgy,vf-fgr, pre vfgr, pcmt, sbang,msrtd,lith,cly 0.0 99.4 2.74 MDST-Itgy,slty,calc,mcmt Company Well : MARATHON OIL CO. : 31-7 CORE LABORATORIES Fi el d : KENAI GAS FI ELD Formation : File No.: MA1587 Date : 02-NOV-95 TABLE I SU#NARY OF CORE DATA ZONE AND CUTOFF DATA CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: Identification ......... NOT SPECIFIED Top Depth ................ 6087.0 ft Bottom Depth ............. 7191.0 ft Number of Samples ........ 18 ATA TYPE: Porosity (HELIUM) Permeability ....... (HORIZONTAL) Kair CUTOFFS: Porosity (Minimum) ....... 0.0 % Porosity (Maximum) 100.0 % Permeability (Minimum) --- 0.0000 md Permeability (Maximum) --- 100000. md Water Saturation (Maximum) 100.0 % Oil Saturation (Minimum) - 0.0 % Grain Density (Minimum) -- 2.00 gm/cc Grain Density (Maximum) -- 3.20 gm/cc Lithology Excluded NONE ZONE: Number of Samples Thickness Represented - POROSITY: Storage Capacity Arithmetic Average Minimum Maximum - Median ................ Standard Deviation GRAIN DENSITY: Arithmetic Average .... Minimum Maximum ............... Median ................ Standard Deviation .... 18 18.0 ft 294.8 ~-ft 16.4 % 13.7 % 20.4 % 16.0 % ±1.6 % 2.72 gm/cc 2.62 gm/cc 2.74 gm/cc 2.72 gm/cc -,-0.03 gm/cc PERMEABILITY: Flow Capacity ......... Arithmetic Average Geometric Average Harmonic Average Minimum ............... Maximum Median Standard Dev. (Geom) -- 151.5 md-ft 8 42 I 78 0 39 0 04 53 0 I 68 K.io±O 833 md md md md md md md HETEROGENEITY (Permeability): Dykstra-Parsons Var. -- Lorenz Coefficient .... 0.817 0.748 AVERAGE SATURATIONS (Pore Volume): Oil ................... Water ................. 0.0% 87.0 % Stat 1 - 1 Company : MARATHON OIL CO. Wel 1 : 31-7 CORE ANAL YT ! CAL PROCEDUR LABORATORIES Field : KENAI GAS FIELD Formation : ES AND QUALITY File No.: MA1587 Date : 02-NOV-95 ASSURANCE HANDLING & CLEANING Core Transportation Solvent Extraction Equipment Extraction Time Drying Equipment Drying Time Drying Temperature ANALYSIS : TRUCK : TOLUENE : DEAN STARK : 24 HOURS : CONVECTION OVEN : 48 HOURS : 240 DEG. F. Overburden pressure for core I was 2300 psig. Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Permeabilities measured on I in. diameter drilled plugs Core Ganlna Composite Dean Stark grain densities clean, dry solid mineral phase are measured The "OB" samples were confined in HYDROSTATIC HOLDER REMARKS Overburden pressure for core 2 was 2850 psig. CORE DESCRIPTION: KBU 31-7RD CORE 1; 6078-6138 (shift up 3 feet to log depth) DEPTH 6078 6080 6085 LEGEND Sandstone Siltstone Shale Coal ROP (mir~/ft) ~ Sandstone ~ Siltstone F:":-~I Sha,e I~ Crossbedded ~ Conglomerate ~ Laminated r~ Bentonite GRAIN GRAPHIC DESCRIPTION S~ZE L~THOLOGY P C M f S C $0 6078: Shale, black, carb, lam - wavy ~.ed, laminated coal parting on top. 6078.25 :Shale, dk-med blue gray, lam-mod, tai~ bent glob, 0.1 ft salt @ 6081.5, grad top & base. 6082.5: SS,mod gray, mod sort,subeng,qtz & lith meta sad (phy)~ caJc cd,fair phi & K, top sharp -bsse rapid grad. 6083: Shale, mad gray, faint lam,si{ silt @ base. 6084.5: SS, mad-It gray, vf-silt, well sor[, subrnd, rip and plan tam, bent, firm up - interbed siI~ and share, fair ph~ & ~ sli calc, ~z & lithic meta ~d (phy) 50/50%, CORE DESCRiPTiON: KBU 31-7RD CORE 1 {Page 2) DEPTH ROP GRAIN GRAPHIC (m~) S~ZE LITHOLOGY P C ~I F S C 5O 6085 6090 DESCRiPTiON 6086: Shale, mad blu grey, lam, bant, sharp top, grad base, 6087.05: SS, medgray, f-cg, mod sod:,subang,grains-qtz & Iithic mats sed(phyl), ~r~e up, pad: clay cement, sharp base, grad top, massive, good phi & K, lithic 60%. 6088.05: SS, mod gray, f-vfg, well sor[,submd, grains-z~z & lithic mete sad (phyl), interbad and fine [~p, fair clay cement, sharp top & base, dpple to cross lam, fair phi & K, lithic 70%. 6088.7: Shale, dark gray, mod, increase carb & rooted 609t.5: Coal, lig-sub bit, grad top & base. 6092.25: Siltstone, light gray, sbaley, mod, sandy @ base, grad top & base. 6095 CORE DESCR PTION: KBU 31-7RD CORE1 (Page 3) DEPTH ROP GRAIN GRAPHIC DESCRIPTION (mir~) SIZE L~THOLOGY P C M F S C 50 0 (~095 ~ 6095: Shale, dk gray, s~i carb, mod-spintered, sharp top, grad base. 6100 61 O5 6095.6: SS, mad gray, vfg, mod sort, subang, qtz & ~ith meta sad (phyl), clay matrx, rip lam, interbed - interlam silty sha~e. 6097.3: SS, medgray, m-fg, mod-poor sort, subang, gtz & lithic meta sed(phy. I), fine up, good phi & K, 60% lithic, clay 6098: SS, mad gray, med-peb, stacked cycles, poor sort, subang, ~x & lith meta sad (ph¥1), coal gms, massive to faint planar' m, fine up, excell ph~ & K, grad top, sharp base. CORE DESCR~PTION: KBU 31-7RD CORE 1 (Page ,3) DEPTH ROP GRAIN GRAPHIC DESCRIPT~ON 6105 -- 6110 - 6115 5O SIZE LITHOLOGY M F S C 6106.4: Shale, dark gray, csrb-coal, bent, faint-we~l lam or mod, sharp top, gradbase. 6112: Shale, It-reed gray, carb-coaly(0.1-0.5 ft thick}, mod-lam, bant, grad top, sharp base. CORE DESCRIPT~ON: KBU 31-7RD CORE 1 (Page 5) DEPTH ROP GRA)N GRAPH)C (mirror) S)ZE L)THOLOGY P C ~l F S C 50 6115 ~ 6120 -- 6125 ~ DESCRiPTiON CORE DESCRiPTiON: KDU 31-7RD CORE 1 {Page DEPTH ROP GRAIN GRAPHIC SiZE L~THOLOGY P C M F S C 50 6125 ~ 6130 -- 6135 DESCRIPTION 6128.2: SS,, med-dk gray, vfg, curb, clay and curb matrix, mod sort, subal~g, poor phi & K, faint lam, sharp top & 6128.8: Siltstone, reed gray, clayey, faint lam, Crarb, sharp base & top. 6129.8: Shale, mod gray, faint ~am, curb, sharp top, grad base. 6130.6: Coal, shaley, lam, grad top & base. 6130.9: SS, med-dk gray, m-vfg, poor sort, subang, ~z & lith mete sod (phyl), c~ay lam, planar lam, frac, fair phi & K, fine up, scour base, grad & curb top. 6434: Shale, d~( gray, mod, curb, sharp top, grad CORE DESCRiPTiON: KBU 31-7RD CORE 1 (Page 7) DEPTH ROP GRAIN GRAPHIC SIZE L~THOLOGY P C M F S C 50 6135 .~ 6140 - DESCRIPTION 6135.25: Ss, reed gray, vfg. mod sort, subang, gtz & lithic mete seal (pbyl), interbed ar~ linter lam shale (dk gray), p~or phi & K, grad top, sharp base. 6t36.8: Sha~e, reed gray, carb, bent, faint lam-mod, bottom 1.25 feet in core catcher and broken, sharp top. CORE DESCRiPTiON: KBU 31-7RD 11/95 DEPTH ROP GRAIN GRAPHIC (mir#ft) SIZE L~TNOLOGY P C M F S C 50 7130 -- 7135 -- 7140 -- CORE 2 7130-7190 (shift core up I foot to log depth) DESCRIPTION 7130: SS, mad grey, Yfg, well sor~, subang, qtz & lithic mete sad (phyt), lith 50%, clay matrix, sli fine up, massive-plan lam, 0.1 fo~ silty shale beds @ 7130.5 & 7t31.3, fair phi & K, grad base. 7133: SS,dk gray, vfg, well sor~, subang, cltz and lith mete sad (~.hyl),carb, carb lam, faint plan lam, sharp base, poor phi & 7134.3: SS, dk gray, vfg, well so~t, subang, carb, qtz & lith mete sad (phyl), lam, poor phi & K. I~erbed shale, 0.1 foot thick, dk gray, carb, lam sandy. Sharp base. 7136.1: SS, dk gray, vfg-silt, well sort, subang, carb, rooted qtz & lithic mete sad (pbyl), clay matrix, lam, fine poor phi & K, sharpbase. 7136.9: SS, med-dk gray, vfg-silt, we~l sort, subang, carb, root, qtz & lithic mete sad (phyl), lam, fine up, poor phi & K, sharp base. 7138.6: Shale, dk-med gray, carb, wavy ism, thin inter lam coal 0.1 ft thick, silty, Sandy 7139.9-7140.1. Sharp base. CORE DESCR~PTION: KBU 31-7RD CORE 2 (Page 2) DEPTH ROP GRAIN GRAPHIC (r. ir~t)SIZE L~THOLOGY P C M F $ C 5O 7140 7145 DESCRIPTION 7144~25: SS, mad gray, c-fg, poor sort~ s[~bal~g, qfz & ~iH~ r~e~ sad (phy~), 60% l~[hic, coursen up (0.3-0.5 fi), faint lam- mass,w. Interbed shsle (0.1 fi), carb, fa~r phi & K, sharp base. 7148.5: Shale, dk gray, lam-mod~ carb, sharp base. 7148.7: Siltstonm mad grey, ~am, send, carb gms, clay matrix, sharp b~se. 7150 CORE DESCRiPTiON: KBU 31-7RD CORE 2 (Page 3) DEPTH ROP GRAIN GRAPHIC LITHOLOGY P C M F S C 50 7150 -- 7155 -- 7'~ 60 ~ DESCRIPTION 7151: Shale, d k gray, carb sandy, amalga~ faint lam. 7151.45: SS,, med-dk gray, vfg-silt, carb ~am, areal, clayey, qtz & lith meta sed(phyl), course up, poor phi & K sharp base. 7153: Shale, dk gray, faint lam, carb, sharp base. 7~53.8: SS, mad gray, fg-shale, poor sort, sub ang, fairer lam, coursen up, qtz & lith meta sad (phyl}, 50% lithic, sharp base, fair-poor phi & K. 7154.2: SS, med gray, mg-shale, bent, poor sort, sub ang, faint coursen up, qtz & lith meta sad (phyl), 50% lithic, sharp base, fair-poor phi & K. 7155.2: SS mad gray c-vfg, be~, carb, poor sort, sub ang, faint lam, coursert up, qtz & lith mats sad (phyl), 50% I~thic, clayey @ base, sharp base, good phi & K, coal@ 7t 57.2~ CORE DESCR~PTION: KBU 3'I-7RD CORE 2 (Page 4) DEPTH ROP GRAIN GRAPHIC (mi~/ft) SiZE L~THOLOGY 7160 50 7165 DESCRIPTION 7166: Shale, dk gray, lam - mod, coaly (7167.1-7167.5, 7169-7~ 7170.7-7171.1, 7~J72.2-7~J73.2,7173.8-7174.'~), grad base. 7~70 ~ CORE DESCRiPTiON: DEPTH ROP 5O 7170 ~ 7175 KBU 31-7RD CORE 2 (Page 5) GRAIN S~ZE GRAPHIC L~THOLOGY DESCRiPTiON 7t75: Shale, reed green gray, bent, sli carb, coal @ 7177.5-7178.2, 7180 CORE DESCRIPTION: KBU 31-7RD CORE 2 (Page DEPTH ROP GRAIN GRAPHIC S~ZE LITHOLOGY P C M F S C 50 7180 ~ 7185 -- 7190 DESCRiPTiON 7t81.8: Si)tstone, dk grey, inter lam w/coal-mod, grad b3se. 7184: Shale, dk gray, mod-ism, w/carb [sm, rooted, grad base. 7187.3: SS mad gray, vf-fg, mod sort, subang, qtz & lith mete sad (phyJ), 50% Jithic, carb, fin up, Ism, poor-fair ph & K, grad base. 7188.2: Shsle, dk gray, carb, sandy @ 7188.5, ~am-mod. CORE DESCR~PTION: KBU 31-7RD CORE 2 (Page 7) DEPTH ROP GRAIN GRAPHIC (min/ft) $~ZE L~THOLOGY P C M F S C 7190 7191 DESCRIPTION LEGEND Sandstone Siltstone Shale Coa~ Sandstone Shale Conglomerate Bentonite Siltstone Cross laminated Laminated 12/13/95 12./13/95 12/13/95 11/6/95 10/26/95 10/26/95 10/26/95 10/12/95 10/17/95 10/17/95 10/17/95 KBU 31-7rd PERFORATION SUMMARY PERFORATIONS MD 7080-7114' 7125-7137' 7141-7146' 7290-7326 7180-7193' 7225-7231' 7250-7290' 7452-7480 7490-7508' 7512-7516' 7529-7534' TVD 6673-6707' 6718-6730' 6734-6783' 6881-6916' 6772-6785' 6817-6822' 6841-6881' 7041-7069' 7079-7096' 7100-7104' 7117-7122' SAND L10/11 Lll Lll L13 L12 L12 L13 L17/18 L18 L18 L18 SPF 6 6 6 6 6 6 6 4 4 4 4 GUN TYPE 2-1/2" Hollow Career 2-1/2" Hollow Career 2-1/2" Hollow Carder 2-1/2" Hollow Carder 2-1/2" Hollow Carder 2-1/2" Hollow Carder 2-1/2" Hollow Carder 1-11/16" Pivot Gun 1-11/16" Pivot Gun 1-11/16" Pivot Gun 1-11/16" Pivot Gun rev. 3/25/1996 KBU 31-7rd ................ COOPER TUBING HANGER: 30.5 (OD:10.900 ID:2.950) PRODUCTION LINER: 7575.0 (OD: 7. 000) SURFACE CASING: 95.0 (OD:20.000) SL INTERMEDIATE CASING: 2526.0 (OD:13.375)~ TUBING: 30.5-1012.7 (OD:3.500 ID:2.992) PRODUCITON CASING: 5680.0 (OD:9.625) CAMCO INJECTION MANDREL: 1012.7-1019.6 (OD:5.187 -/ ID:2.900) TUBING: 1019.6-6304.7 (OD:3.500 ID:2.992) [.Core 6 0 7 8 ...0....-....6..1..3..~.,, .0, ..................................................... ] BAKER 80-40 K-ANCHOR: 6304.7-6305.8 (OD:4.750 ID:3.250) BAKER 84-40X32 SAB PACKER: 6305.8-6310.7 (OD:5.687 ID:3.250) TUBING: 6310.7-6350.3 (OD:3.500 ID:2.992) CAMCO X NIPPLE: 6350.3-6351.3 (OD:3.867 ID:2.812) TUBING: 6351.3-6412.2 (OD:3.500 ID:2.992) CAMCO X NIPPLE: 6412.2-6413.2 (OD:3.867 ID:2.812) TUBING: 6413.2-6444.0 (OD:3.500 ID:2.992) FRACTURE TREATMENT 7080.0 - 7146. Perf 7080.0 - 7114. Perf 7125.0 - 7137. Perf 7141.0 - 7145. Core 7130.0 - 7190.0 Perf 7180.0 - 7193. FRACTURE TREATMENT 7180.0 - 7326.0 Perf 7225.0 - 7231.0 Perf 7250.0 - 7290.0 Perf 7290.0 - 7326.0 Perf 7452.0 - 7480.0 Perf 7490.0 - 7508.0 Perf 7512.0 - 7516.0 Perf 7529.0 - 7534.0 Cement Plug: 7556.0-7575.0 (OD:6.016) WellView 5.0 50-133-20347 3125/96 OPERATION SUMMARY REPORT WELL: KENAI BELUC~ UNIT ; : - ~': ' i ---: - ' ~ ::::: ::i:::::::: ::: . :.: i :~ :: ::::! : i -.:...- . ~ ....... -- .: -. :, : :- · ...... . ............... . ........ .-i...:.-..-.-.-~ 08/28/95 1 6680 8.600 ACCEPTED RIG FROM MOBILIZATION AT 1400 HRS, 8'27'95. MIXED MUD. PULLED BPV~$. R/U LINES AND TESTED SAME. BULLHEAD 110 BBLS DOWN LONG STRING. CIRULATE KWM DC)tdN LONG STRING AND UP SHORT STRING. NO RETURN S AFTER 100 BLS OVER CALCULATED VOLUME. SHUT DCYdN PUMPS AND MONITER WELL. LS 1500 PSI. SS 0 PSI. ANNULUS 1400 PSI. BLED LS TO 0 PSI. 08/29/95 2 6680 8.600 MONITERED WELL, BUILT SURFACE VOLUME. R/U SLICK LINE ON SHORT - STRING AND CONFIRMED SLIDING SLEEVE OPEN. BLED PRESSURE OFF ANNULUS. CIRCULATED DC)WN ANNULUS AND UP SHORT STRING. ATTEMPTED TO CIRCULATE DOWN LONG STRING, NO RETURNS UP SHORT STRING. CIRC DOWN ANNULUS AND UP SHORT STRING. MONITERED WELL. ATTEMPTED TO PUMP DOWN SHORT STRING AND UP LONG STRING, NO RETURNS. R/U SLICK LINE, SET PLUG IN LONG STRING AT 500m. 08/30/95 3 6680 8.600 SET PLUG IN SHORT STRING. SET BACK PRESSURE VALVES IN BOTH STRINGS. N/D TREE. N/U BOpmS. CHANGED RAMS. TESTED BOP'S. 08/31/95 4 6680 8.600 R/U SLICKLINE AND PULLED PLUGS ON SHORT AND LONG STRINGS. ATTEMPTED TO PULL TUBING. R/U AND RAN FREE POINT. MADE JET CUTS AT 5766' AND 5446'. CIRCULATED TRROUGH CUT AT 5446~. 09/01/95 5 6680 8.600 CBU. RAN FREE POINT. MADE CHEMICAL CUT AT 5085". CBU. STARTED PULLING AND LAYING DOWN TUBING. PACKER STUCK. WORKED FREE. SHORT STRING STARTEO FLOtJING. CIRCULATEO BOTTOMS UP ON BOTH STRINGS. PULLEO ANO LAYEO DOWN TUBING. 09/02/95 6 6680 8.600 FINISHED PULLING AND LAYING DOWN DUAL 3 1/2" TUBING. R/D TUBING HANOLING TOOLS. CHANGE DUAL RAMS TO VARIABLES. P/U AND M/U KELLY. STARTED TESTING 8OPE. 09/03/95 7 6680 8.600 FINISHED TESTING BOPE. M/U FISHING ASSEMBLY. RIH P/U DRILL PIPE. REPAIRED SCR SYSTEM. RIH P/U DRILL PIPE. 09/04/95 8 6680 8.600 RIH P/U DRILL PIPE. CBU. LATCHED FISH AT 5085m . JARRED FREE. CBU. POOH AND LAYED DOWN FISH. P/U WASH PIPE. RIH TO 5446~. WASHED OVER FISH TO 5782'. CBU. POOH. L/D WASH PIPE AND M/U NEW FISHING ASSEMBLY 09/05/95 9 6680 8.700 RIH WITH FISHING ASSEMBLY. MILLED OVER AND LATCHED FISH. CBU. POOH. L/D FISH. RIH WITH MILL AND CASING SCRAPER TO 5778m. CBU. POOH. REAMED TIGHT SPOT AT 5662m. POOH. L/D MILL AND SCRAPER. RIH WITH CEMENT RETAINER. 09/06/95 10 5772 8.600 RUN IN HOLE AND SET RETAINER AT 5T72m. ESTABLISHED INJECTION RATES. SQUEEZED 66 BBLS OF CEMENT BELOW RETAINER. PULLED ONE STAND AND CBU. THICK MUD TO SURFACE. POOH TO 2909m. CIRCULATED OUT CONTAMINATED MUD. CIRCULATED , CONDITIONED AND BUILT MUD VOLUME. POOH. RIH TO 2909m. CBU. STAGED IN HOLE TO 5657'. CBU. OPERATION SUMMARY REPORT WELL: KENAI BELUGA UNIT . :..:::.:: ,,, 09/07/95 11 5772 8.700 CBU. ESTABLISHED INJECTION RATE. POOH. RIH WITH 3 1/2" CMT STINGER. SET 356 SX BALANCED CEMENT PLUG. POOH TO 4318". SQUEEZED 15 1/2 BBLS CEMENT AWAY. WOC. POOH. 09/08/95 12 5772 8.800 FINISH L/D 3 /12" DP. RIH WITH BIT TO 4500". CIRCULATED AND WAITED ON CEMENT. RIH, TAGGED CEMENT AT 4931". TESTED CASING TO 2000 PSI. DRILLED CEMENT FROM 4931" TO 5770". CBU. 09/09/95 13 5772 8.900 TESTED PERF'S TO 11.6 PPG EMW. CIRCULATED AND CONDITIONED MUD. POOH. M/U SECTION MILL AND RIH. MILLED SECTION FROM 5671' TO 5708~. 09/10/95 14 5772 9.100 CIRCULATED, MADE CONNECTION. MILL QUIT MILLING. CBU. POOH. WEAR PATTERNS ON MILL INDICATED NO CUT. M/U NEW MILL AND RIH. MILL CASING FROM 5678' TO 5721'. 09/11/95 15 5772 9.300 MILLED FROM 5721' TO 57'58", MILL QUIT TAKING WT. CBU. POOH. MILL CUTTER ARMS 100% WORN. CHANGED CUTTER ARMS AND R]H. MILLED FROM 5738 TO 5752", MILL QUIT TAKING WT. CBU. POOH. NO WEAR ON CUTTERS. P/U 3 1/2" CEMENT STINGER AND RIH TO 5770". CIRCULATED AND CONDITIONED MUD. 09/12/95 16 5465 9.300 CIRCULATED AND CONDITIONED MUD. R/U LINES. TESTED SHOE TO 11.1 PPg EMW. SPOT 140SX BALANCED CEMENT PLUG. POOH 10 STDS. CIRCULATED.POOH. SET RETRIEVABLE BRIDGE PLUG AT 930'. N/D BOP"S. N/D TUBING SPOOL. N/U CASING SPOOL AND TESTED SAME. PULLED RETRIEVABLE BRIDGE PLUG. SET TEST PLUG AND START TESTING BOP"S. 09/13/95 17 5730 9.350 TESTED BOP~S. M/U BHA AND RIH. TAGGED CEMENT AT 5447~.DRILLED CEMENT FROM 5447! TO 5680". ORIENT MUO MOTOR TO SIDETRACK, TIME ORILLED FROM 5680" TO 5730~. 09/14/95 18 5903 9.200 DRILLED FROM 5730" TO 5885'. CBU. POOH TO SHOE. CLEANED MUD PITS. TRANSFERRED POLYMER MUD TO MUD PiTS ANO WEIGHTEO UP TO 9.2 PPG. OISPLACED HOLE WITH POLYMER MUD. CIRCULATED AND CONDITIONEO MUO. DRILLEO FROM 5885" TO 5903'. 09/15/95 19 6113 9.350 DRILLED FROM 5903' TO 6070'. CBU FOR SAMPLES. DRILLED TO 6078'. CBU FOR SAMPLES. POOH. M/U CORING ASSEMBLY. R[H. CBU. COREO FROM 6078' TO 6113' 09/16/95 20 6325 9.300 CORED FROM 6113' TO 6138'. CBU. POOH. L/D CORE. FULL RECOVERY. M/U DIRECTIONAL BHA. RIH TO 6030'. REAMED TO 6138'. DRILLED TO 6195'. CIRCULATED AND CONDITIONED MUD. DRILLED TO 6325' 09/17/95 21 7130 9.350 DRILLED FROM 6325~ TO 6690'. CBU. MADE WIPER TRIP TO SHOE. DRILLED FROM 6690' TO 6998'. CBU. DRILLED FROM 6998' TO 7130'. CBU. STARTED WIPER TRIP. 09/18/95 22 717'5 9.250 MADE WIPER TRIP TO SHOE. CIRCULATED AND CONDITIONED MUD. REPAIRED RIG. POOH. M/U CORING ASSEMBLY AND RIH TO 7130'. CORED FROM 7130' OPERATION SUMMARY REPORT WELL: KENAI BELUGA UNIT TO 7173'. 09/19/95 23 7'340 9.450 CORED FROM 7__17'5]--~-~190,!~ CBU. POOH. L/D CORES. 100% RECOVERY. TESTED BOPE. BHA. RIH TO 7130'. REAMED TO 7190'. DRILLED FROM 7190' TO 7"'540~. CBU. 09/20/95 24 7515 9.500 CIRC1JLATED OIJT C~AS. DRILLED FROM 7340' TO 7495'. CBU. DRILLED TO 7515'. CBU. MADE WIPER TRIP TO SHOE. CBU. POOH. BHA. R/U TO LOG. RIH WITH AIT DSI GR. LOGGED FROM 7'515' TO 5671'. POOH. RIH WITH FMI GR. 09/21/95 25 7575 9.800 RIH WITH FMI GR TO 7515. TOOL STUCK AT 7476' WHILE LOGGING. WORKED SAME FREE, POOH R/D E LINE. RIH WiTH BiT TO 7515'. CBU. DRILLED FROM 7515 TO 7565. CBU AND EVALUATED CUTTINGS. DRILLED FROM 7565 TO 7575. CBU. POOH. R/U E LiNE AND RIH WITH LDT CNL NGT CMR AMS TO 6570. TOOL STUCK WHILE CALIBRATING. WAiT ON FISHING TOOLS. R/U TO STRIP OVER WIRELINE. 09/22/95 26 7575 9.800 M/U FISHING TOOLS. STRIPPED OVER WIRELINE AND LATCHED TOP OF FISH AT 6497'. WORKED SAME FREE. PULLED OUT OF ROPE SOCKET AND POOH WiTH WIRELINE. POOH WITH FISH. 100% RECOVERY. P/U BHA AND RIH TO 75758. CIRCULATED AND CONDITIONED MUD. POOH. 09/23/95 27 7575 9.900 R/U E LINE. LOGGED WITH LDT/CNT/GNT FROM 7575' TO 5671'. LOGGED WITH CMR/GR FROM 7420' TO 5700'. M/U BHA AND RIH TO 7575'. CIRCULATED AND CONDITIONED MUD. POOH. R/U E LINE. RIH WiTH FMI/GR TO 7420' AND STARTED LOGGING UP. 09/24/95 28 7575 9.900 FINSIHED RUNNING FMI/GR LOG FROM 7420' TO 5700'. POOH, R/D E LINE. RIH WITH BIT TO 7575'. CIRCULATED AND CONDITIONED MUD. POOH. L/D Dcms. CHANGED TOP SET OF RAMS TO 7". R/U TO RUN CASING. STARTED RUNNING 7" PROOUCTION CASING. 09/25/95 29 7575 9.900 FINISHED RUNNING 7" PROOUCTION CASING TO 7575'. CIRCULATED AND CONDITIONED MUD. CEMENTED FIRST STAGE WITH 350SX CEMENT. OPEN STAGE COLLAR AND CIRCULATED. CEMENTED SECOND STAGE WITH 390 SX CEMENT. P/U STACK, SET CASING SLIPS. MADE ROUGH CUT. 09/26/95 30 7575 9.700 INSTALLED TUBING SPOOL AND TESTED SAME. N/U BOP'S. CHANGED PIPE RAMS TO 3 1/2". TESTED BOP'S. L/D 5" DP FROM DERRICK. 09/27/95 31 7575 9.800 CHANGED OUT KELLY. RIH P/U 3 1/2" DP. DRILLED STAGE COLLAR AT 5533'. RIH P/U DP. TESTED CASING TO 3500 PSI. DRILLED FLOAT COLLAR AT 7530' AND CEMENT TO 7560'. CUB. POOH. R/U E LINE AND LUBRICATOR. RIH WITH CEMENT BOND LOG TOOLS. 09/28/95 32 7556 9.750 RAN CRT/CBT LOG. POOH. RAN AND SET BRIDGE PLUG AT 7555' WLM. RIH WITH BIT AND SCRAPERS. TAGGED BRIDGE PLUG AT 7556' DPM. CIRCULATED AND EMPTIED MUD PITS. CLEANED MUD PITS AND FILLED WITH WATER. OPERATION SUMMARY REPORT WELL: KEHAI BELUGA UNIT "::,'::::::: . :: .... : ::' ~ · :: {i~:::!:i::: :: :,: ..: ::.:.. '-:::.::::--::~ ::?:--'--::::::-..-;! :!:::::::< .:.::-:-.-::::.-:.:: ::...::: . ::..::.:..:.:: ::: --: ::, -.: ,; .-:- - -::: - ;:-:-: : .---.- -,-..--...,:...-...-.-.......?.............................:.....:;:;:.- 09/29/95 33 7556 8.700 FILLED PITS WITH UATER. DISPLACED WELL 14ITH WATER. ROUND TRIPPED CASING SCRAPERS. CIRCULATED AND SI,/EPT HOLE. DISPLACED HOLE WITH COHPLETION FLUID. POOH L/D DRILL PIPE. 09/30/95 3/+ 7556 8.750 L/D BHA. L/D KELLY, SWIVEL AND SPINNER. RAN COflPLETION ASSEMBLY OH ~.5" TUBING. CZR~LATED AND INHIBITED C~LETION FLUID. LANDED HANGER AND TESTED ~500 PSI. PACKER AT 6~05' AND TUBING AT ~5~. DROPPED PACKER SETTING BALL. 10/01/95 35 ~56 0.000 SET PACKER AT 6305~. TESTED TO 3500 PSI. SET T~O ~AY CHECK IN HANGER. R/D TUBING RUNNING EQUIPMENT. N/D BOPE. N/U TREE AND TESTED TO 5000 PSI. RELEASED RiG AT 1600 HRS 9/~0/95. ... OPERATION SUMMARY REPORT: POST RIG WELL: KBU 31-7RD 10/9/95 RU WIRELINE, SWAB WELL DOWN TO 4987' 10/10/95-! RU PUMP AND PRESSURE UP TUBING TO 1700 PSIG N2. BLEED OFF 10/10/95 PRESSURE, CHANGE OUT SURFACE VALVE, PRESSURE UP TUBING TO 1800 PSIG N2. 10/12/95- RU E-LINE AND PERFORATE 7452-7480' (L17/18) USING 1-11/16" 10/13/95 PIVOT GUNS, 4 SPF, 180 DEGREE PHASING, 22 GM CHARGES. HAD TWO MISRUNS. ATTEMPT TO FLOW WELL. WHP BLED OFF TO 0 PSIG IN 1 HOUR. SI WELL. 10/17/95 RU E-LINE ~qD PERFORATE 7529-7534' (L18), 7512-7516' (L18) 7490-7508' (L18) W/ 1-11/16" PIVOT GUNS, 4 SPF, 180 DEGREE PHASING, 22 GM CHARGES. WHP BLED OFF TO 0 PSIG IN 33 MINUTES. SI WELL. 10/19/95 FLOW WELL. Q = 144 MSCFPD @ 245 PSIG WHP, 0 BWPD. 10/20/95- MU TANDEM ELECTRONIC GAUGES, OBTAIN FBHP AND 72 HOUR PBU. 10/24/95 Q= 144 MSCFPD, 257 PSIG, 51% DD. 10/25/95 RU CT AND SAND BACK L17/18 PERFS. PU TO 6444' AND BLOW TUBING DRY W/ N2. LEFT 2000 PSIG ON WELLHEAD. 10/26/95 RU E-LINE AND PERFORATE 7180-7193' (L12), 7250-7290 (L13), 7225-7231' (L12) W/ 2-1/2" HOLLOW CARRIERS, 6 SPF, 60 DEGREE PHASING, 10.5 GM CHARGES. Q = 461 MSCFPD, 360 PSIG WHP, 0 BWPD. 10/31/95- MU TANDEM ELECTRONIC GAUGES, OBTAIN FBHP AND 72 HOUR PBU. 11/4/95 Q= 450 MSCFPD, 635 PSIG, 64% DD. 11/6/95 RU E-LINE AND PERFORATE 7290-7326' (L13) W/ 2-1/2' HOLLOW CARRIERS 6 SPF, 60 DEGREE PHASING, 10.5 GM CHARGES. Q = 1000 MSCFPD, 670 PSIG WHP, 0 BWPD. 11/22/95 RU FRAC EQUIPMENT AND FRAC L12/13 W/ 73777# 20/40 CARBOLITE TAGGED W/ SC46, SB124, IR192. TOTAL LOAD WATER OF 560 BBLS. FLOWED WELL FOR 30 MINUTES, SI, REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE AT 996' 11/22/95- RU CT AND CLEANOUT WELLBORE. PU TO 4000' AND CIRCULATE 11/23/95 N2 TO BLOWDOWN TUBING. Q = 2600 MSCFPD, 7 BWPD, 360 PSIG WHP. 11/26/95 RU E-LINE AND RUN MIST TOOL ACROSS FRAC'D INTERVAL. 12/1/95- MU TA~4DEM ELECTRONIC GAUGES, OBTAIN FBHP, ~,ID 96 HOUR PBU. 12/5/95 Q= 2718 MSCFPD, 0 BWPD, 395 PSIG WHP, 84% DRAWDOWN. 12/8/95 RU E-LINE AND RUN PL TOOLS ACROSS L12/13. OPERATION SUMMARY REPORT: POST RIG WELL: KBU 31-7RD 12/11/95 RU CT AND SAND BACK L12/13 PERFS. PU TO 5250' AND BLOW TUBING DRY W/ N2. LEFT 2000 PSIG ON WELLHEAD. WHP = 2000 PSIG. 12/13/95 RU E-LINE AND PERFORATE 7080-7114' (L10/ll), 7141-7146' (Lll), 7125-7137' (Lll) W/ 2-1/2" HOLLOW CARRIERS, 6 SPF, 60 DEGREE PPLASING, 10.5 GM CHARGES. 12/17/95 MU TANDEM ELECTRONIC GAUGES, OBTAIN SBHP. REPLACE CHEMICAL INJECTION VALVE W/ DUMMY VALVE AT 991' 12/21/95- RU FRAC EQUIPMENT AND FRAC Li0/ll W/ 97337# OF 20/40 12/22/95 CARBOLITE, 560 BBLS FLUID. FLOWED 58 BBLS BACK. SI. RU WIRELINE AND REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE. RU CT AND CLEANOUT SAND TO TD (7555'). PU TO 6000' AND CIRCULATE N2. Q= 3000 MSCFPD AT 1300 PSIG WHP. 1/18/96 PERFORM SURFACE 4 POINT. MAX RATE= 6.9 MMSCFPD @ 750 PSIG WHP. 01(6 3 I g wo MARATHON DAILY DRILLING REPORT AN DATE 09/06/95 RPT 10 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET is PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: CIRCULATING LAST CASING O.D. LAST CASING SHOE DEPTH ft. SHOE TEST PPG DAYS ON LOCATION 10 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: cif RUN IN HOLE AND SET RETAINER AT 5772'. ESTABLISHED INJECTION RATES. SQUEEZED 66 BBLS OF CEMENT BELOW c: RETAINER. PULLED ONE STAND AND CBU. THICK MUD TO SURFACE. POOH TO 2909'. CIRCULATED OUT CONTAMINATED .s.+ MUD. CIRCULATED . CONDITIONED AND BUILT MUD VOLUME. POOH. RIH TO 2909'. CBU. STAGED IN HOLE TO 5657'. /') CBU. 2: MUD WT 8.6 VIS 42 PV 10 YP 17 GELS 4/ 10 pH 10.2 WL 20 HPHT WL _ Pm 0 Pf /Mf 0.1/ 0.3 Cl 300 Ca 20 % Oil % SOLIDS 4 BENT /SALT 21.0 / 0.0 DRILLED 33.2 BARITE -29.0 (lb /bbl) SPM #1 71 SPM #2 TOT SPM 71 PRESSURE 588 TOT GPM 307 ANN VEL DP 159.1 DC 250.6 CRIT 256.3 RUN# B1T# SIZE.:.::: ;:TYRE: ";; " >:;': SERIAL NO. « <: ":lET(32Is )_:..:.1:EET:.: " : HOURS s ?: <[::FT/HR >: >:::;OFF »; kO <.bL Er:: »B1C S:: =R <:;" 5 RR1 8.500 J2 C97CR 5657 4 MILLI 8.500 3 HM1 7.625 JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. _ BHA WT. IN MUD: RPM: - 25 SLACK OFF WT. _ WOB - --- PICK UP WT. TORQUE: 250 START: : :END;:. HOURS, . S OPERATIONS ::.IN'.: SEQUENCE ..:::::::::" .:.:::: :::::.:::::..::::..::::::::: :..::::::::::::: : "OPs > <CODES >` 06:00 07:00 1.00 RIH WITH RETAINER. A TR 07:00 08:00 1.00 R/U AND BREAK CIRCULATION. SET RETAINER AT 5772'. • A CN 08:00 09:00 1.00 TESTED LINES TO 5000 PSI. ESTABLISHED INJECTION RATE INTO PERFS ABOVE A CN RETAINER. 1 BPM AT 650 PSI AND 2 BPM AT 980 PSI. STUNG INTO RETAINER AND ESTABLISHED INJECTION RATE INTO PERFS BELOW THE RETAINER. 1 BPM AT 1450 PSI AND 2 BPM AT 1750 PSI. STUNG OUT. 09:00 10:30 1.50 PUMPED 5 BBLS OF WATER. MIXED AND PUMPED 310 SACKS(66 BBLS) OF 15.8 A CN PPG CEMENT WITH .2% CFR -3. .4% HALAD 344. .2% HR-5. DISPLACED WITH 5 BBLS OF WATER AND 20 BBLS OF MUD. STUNG IN. SQUEEZED WITH 77 BBLS OF MUD. FINAL INJECTION PRESSURE WAS 1950 PSI AT 2 BPM. STUNG OUT. R/D PUMP IN SUB. PULLED ONE STAND. R/U PUMP IN SUB. 10:30 12:30 2.00 CBU. CIRCULATED CEMENT CONTAMINATED MUD. CIRCULATED SECOND BOTTOMS A CF UP. MUD GOT THICKER. LOOSING MUD TO PERFS. APPEARS THAT THE EZSV ALLOWED CEMENT TO FLOW BACK THROUGH IT. 12:30 13:00 0.50 PULLED 10 STANDS. A TR 13:00 13:30 0.50 P/U KELLY AND ATTEMPTED TO BREAK CIRCULATION. COULD NOT BREAK A CF CIRCULATION. 13:30 15:00 1.50 POOH TO 2909'. BROKE CIRCULATION. A TR 15:00 20:00 5.00 CIRCULATED AND CONDITIONED MUD AND BUILT VOLUME. PUMPED SLUG. A CF 20:00 21:30 1.50 POOH. L/D RUNNING TOOL. A TR 21:30 22:30 1.00 L/D 7 6 1/4" DRILL COLLARS. A BH 22:30 23:30 1.00 M/U BIT AND BHA. _ A BH 23:30 00:30 1.00 RIH TO 2909'. A TR 00:30 01:00 0.50 CBU. CHECK UP AND DOWN WEIGHTS AND TORQUE. A CF 01:00 06:00 5.00 STAGE IN HOLE 5 STANDS AT A TIME CBU AFTER EACH 5 STDS. TAGGED FIRM A TR CEMENT AT 5657'. CONTAMINATED MUD ON EACH CIRCULATION. STARTED CBU AT 0600 HRS. DAILY WELL COSTS 35480 CUM$ 300011 DAILY MUD$ 3253 CUMS 14391 Supervisor: PKB • .. . . . MARATHON DAILY DRILLING REPORT ;. ANCHORAGE:; DATE 09/07/95 RPT 11 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: POOH, L/D DP LAST CASING O.D. LAST CASING SHOE DEPTH ft. SHOE TEST PPG DAYS ON LOCATION 11 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CBU. ESTABLISHED INJECTION RATE. POOH. RIH WITH 3 1/2" CMT STINGER. SET 356 SX BALANCED CEMENT PLUG. POOH TO 4318'. SQUEEZED 15 1/2 BBLS CEMENT AWAY. WOC. POOH. MUD WT 8.7 VIS 41 PV 9 YP 13 GELS 5/ 17 pH 10.8 WL 21 HPHT WL _ Pm 0 Pf /Mf 0.3/ 0.5 Cl 200 Ca 20 % Oil % SOLIDS 4 BENT /SALT 20.0 / 0.0 DRILLED 27.4 BARITE - 18.0 (lb /bbl) SPM #1 SPM #2 _ TOT SPM _ PRESSURE TOT GP _ ANN VEL DP DC CRIT _,- kUN# ::BIT # >::: S I 2 >; >::YR ; ;; : >: >_ •>: E ;_ : .. ; >s: : > :< >:� cs<: >: >: ; ;>: s ;; E : >T E ... : >: ... S RIAL` <NOr: >JET(3 s) .fEE -: . HO URSF.T /HR:: ; <::(3F 1.. ai.Da.::. :. $::GS.: ;: R. JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. _ BHA WT. IN MUD: RPM: _ - _ SLACK OFF WT. WOB: _ - _ PICK UP WT. _ TORQUE: START. SEND:: HO R :: ::[:> >[: » » » »:>: >: OPERA710NS::I N::SEQUENCg:: :: ::::.;;:: «;;:;:;:;;::: >: :::::;;:: :s::;;::, OR:::CODES::<; 06:00 07:00 1.00, CBU _ A CF 07:00 08:00 1.00 R/U HALLIBURTON. TEST LINES TO 3000 PSI. TEST PERF'S, EST INJ RATE OF A PT .3 BPM AT 600 PSI. 08:00 11:30 3.50 PUMPED DRY JOB AND POOH - A TR 11:30 13:30 2.00 R/U 3 1/2" HANDLING TOOLS. P/U 1200' OF 3 1/2" DP FOR CMENT STINGER. A TR 13:30 16:00 2.50 RIH W/ 5" DP. TAGGED CEMENT AT 5696'. A TR 16:00 16:30 0.50 CIRCULATED A CF 16:30 17:30 1.00 R/U HALLIBURTON. TESTED LINES TO 3000 PSI. MIX AND PUMP 356 SX 'G' A CN CEMENT W/ .2% CFR-3, .4% HALAD 344. .2% HR-5 WITH FRESH WATER AT 15.8PPG SET BALANCED PLUG FROM 5696' TO 4672'. 17:30 19:00 1.50 POOH 15 STANDS TO 5318'. CIRCULATED HOLE CLEAN. A OT 19 :00 20:00 1.00 SQUEEZED 15 1/2 BBLS OF CEMENT AWAY. FINAL 1NJ RAT 1/2 BPM AT 1750 A CN PSI. CIP 1945 HRS 9-6 -95. EST TOC 4876'. 20:00 02:00 6.00 WOC HOLDING PRESSURE. PRESSURE BLED FROM 1400 PSI TO 900 PSI. A WC 02:00 02:30 0.50 BLED PRESSURE, PUMPED DRY JOB. A TR 02:30 06:00 3.50 POOH. L/D 61 JTS 5" DP, L/D 39 JTS 3 1/2" A TR DAILY WELL COST$ 42765 CUM$ 342776 DAILY MUDS 1258 CUM$ 15649 Supervisor: LHL • MARATH ; REPORT AN CHORAGE. DATE 09/08/95 RPT 12 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET iJ PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: CIRCULATING BOTTOMS UP LAST CASING O.D. LAST CASING SHOE DEPTH ft. SHOE TEST PPG DAYS ON LOCATION 12 LINER 1 0.0. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.0. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: FINISH L/D 3 /12" DP. RIH WITH BIT TO 4500'. CIRCULATED AND WAITED ON CEMENT. RIH, TAGGED CEMENT AT 4931'. TESTED CASING TO 2000 PSI. DRILLED CEMENT FROM 4931' TO 5770'. CBU. MUD WT 8.8 VIS 36 PV 8 YP 16 GELS 7/ 15 pH 11.9 WL 28 HPHT WL _ Pm 10 Pf /Mf 1.5/ 1.8 Cl 180 Ca 160 % Oil _ % SOLIDS 4 BENT /SALT. 18.0 / 0.0 DRILLED 22.6 BARITE -6.9 (lb /bbl) SPM #1 71 SPM #2 TOT SPM 71 PRESSURE 400 TOT GPM 307 ANN VEL DP 159.1 DC 250.6 CRIT 246.7 ' G5 >:::<::< » > >s SERIAL T 32s ..... FEET'.' <': HOURS:::;;. FTIHR< '::::OFF > D1` >?: >:$ RUN# BIT# SIZE >T :NO .. JE ( ) 6 2 8.500 J2 C99CR 839 13.50 62.14 5 RR1 8.500 J2 C97CR - - -- 5657 4 MILLI 8.500 - - - - -__ JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. 150 BHA WT. IN MUD: _ RPM: 60 - 80 SLACK OFF WT. 125 WOB: 20 - 25 PICK UP WT. 185 TORQUE: 450 ::::.::.:: .:.OPa >sCODE START: s.END >: HOURS :.;::<;;:;:;:::.: :;;;:< .::.:::: :::::::::....::::::::OPERATIONS IN;; SEQUENCE .:::..::::::::::::::.:.::.::.::::.:.....::: :�:::::: ::::::::::::::::::.:::. 06:00 07:30 1.50 FINISH L/D 3 1/2" DP. A TR 07:30 08:30 1.00 CHANGE HANDLING TOOLS. CLEAR RIG FLOOR. SERVICE RIG. ' A SR 08:30 10:00 1.50 RIH WITH BIT TO 4500' A TR 10:00 12:00 2.00 CIRCULATE AND WAIT ON CEMENT A WC 12:00 13:00 1.00 RIH, TAGGED CEMENT AT 4931'. A TR 13:00 13:30 0.50 TESTED CASING TO 2000 PSI FOR 30 MIN OK A PT 13:30 05:30 16.00 DRILLED CEMENT FROM 4931' TO 5770'. ADT 13.5 HRS. A DO 05:30 06:00 0.50 CIRCULATED HOLE CLEAN A CF DAILY WELL COSTS 88000 CUM $ 430776 DAILY MUDS 2342 CUM$ 17991 Supervisor: LHL 4 4 . . MARATHON DAILY DRILLING REPORT DATE 09/09/95 RPT 13 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET is PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: MILLING SECTION AT 5708' LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST PPG DAYS ON LOCATION 13 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 O.D. INTERVAL - ft. SHOE TEST PPG EXECUT SUMMARY: TESTED PERF'S TO 11.6 PPG EMW. CIRCULATED AND CONDITIONED MUD. POOH. M/U SECTION MILL AND RIH. MILLED SECTION FROM 5671' TO 5708'. MUD WT 8.9 VIS 99 PV 10 YP 68 GELS 20/ 33 pH 12.2 WL 28 HPHT WL _ Pm 12 Pf /Mf 1.0/ 1.2 Ct 500 Ca 120 % Oit _ % SOLIDS 11 BENT /SALT 23.0 / 0.0 DRILLED 138.0 BARITE -98.8 (lb /bbl) SPM #1 _ SPM #2 100 TOT SPM 100 PRESSURE 1500 TOT GPM 432 ANN VEL DP 223.9 DC 352.6 CRIT 485.1 • R #"" :B 1:1 ::: S1TE::. T. YRE;:; ;:"»><:: SERI AL: tdO.::..- ::;:JET:(32'a); >::;ifEET.:.::- "::HOURS:: >'.::FT /HRs: >::; OFF>:: ::.t<i< >:L3 >::- D;: >: >::L< >: >::; 7 MILL2 8.500 KSB 264 37. 8.50 4.35. 6 2 8.500 J2 C99CR 839 13.50 62.14 5 RR1 8.500 .12 C97CR 5657 JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. 150 BHA WT. IN MUD: RPM: 60 - 90 SLACK OFF WT. 125 WOB: 5 - 15 PICK UP WT. 200 TORQUE: 400 ,; END :::; HOUR S''>;:::>::':>»?:: ;sss >::::::;C:<.:_::;::<i<_::zz "" DAERATIONS:z:IN >: SEQUENCE : >:;::;:: >_ >::::;;<::::> :>::; : :":;>:::: ?;::::<:.::? isi «iiii<r> >;?>OR:;,,;:CODES >::::: 06:00 06:30 0.50 TESTED PERF'S TO 700 PSI W/ 8.9 PPG MUD. 11.6 PPG EMW. A PT 06:30 11:00 4.50 CIRCULATED AND CONDITIONED MUD, RAISING VIS AND GELS. _ A CF 11:00 13:30 2.50 POOH _ A TR 13:30 16:00 2.50 M/U SECTION MILL. P/U JARS AND 6 DC'S. RIH WITH HVY WT TO 1141'. _ A BH 16:00 17:00, 1.00 SLIP 45' AND CUT 127' OF DRILLING LINE. A SR _ 17:00 19:00 2.00 BREAK DOWN KILL LINE MANIFOLD. CLEANED OUT CEMENT PLUG FROM MANIFOLD. A OT 19:00 21:30 2.50 RIH. TAGGED RETAINER AT 5770'. STAND BACK ONE STAND. P/U 10' PUP FOR A TR SPACEOUT. 21:30 06:00 8.50 MILL SECTION IN 9 5/8" CASING FROM 5671' TO 5708'. _ A MC DAILY WELL COST$ 29736 CUM$ 460512 DAILY MUD$ 1987 CUM$ 19978 Supervisor: LHL - - I MARATHON DAILY DRILLING REPORT ANCHORAGE DATE 09/10/95 RPT 14 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: MILLING SECTION AT 5721' LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST PPG DAYS ON LOCATION 14 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CIRCULATED, MADE CONNECTION. MILL QUIT MILLING. CBU. POOH. WEAR PATTERNS ON MILL INDICATED NO CUT. M/U NEW MILL AND RIH. MILL CASING FROM 5678' TO 5721'. MUD WT 9.1 VIS 99 PV 11 YP 68 GELS 18/ 39 pH 12.2 WL 37 HPHT WL _ Pm 14 Pf /Mf 2.1/ 2.5 Cl 700 Ca 120 % Oil % SOLIDS 15 BENT /SALT 23.0 / 0.1 DRILLED 197.1 BARITE -135. ((b /bbl) SPM #1 SPM #2 100 TOT SPM 100 PRESSURE 1500 TOT GPM 432 ANN VEL DP 223.9 DC 352.6 CRIT 483.3 RUN# :.:BIT#.::::: I. SIZE :;:`:;:T.YPE::<`:!:: `:SERIAL : >:NO' <'::JET(32 ...::::fEE.;: . T HOURS <<> <FT/HR ::::: >aFF::< LpDL:<::' 81;SR ":;: 8 MILL3 8.500 KSB 1133 43 12.50 3.44 7 MILL2 8.500 KSB 264 37 8.50 4.35 5708 6 2 8.500 J2 C99CR 839 13.50 62.14 JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. 165 BHA WT. IN MUD: RPM: 60 - 90 SLACK OFF WT. 130 WOB: 5 - 15 PICK UP WT. 225 TORQUE: 400 . R : ;:.END HOURS ::;:.:::;::;:..: ...;:.:::;:;; >:.;;::;:;::;;:OPERAT3ONS;JN< SEQUENCE OP r CODES ::;': 06 :00 07:00' 1.00 CBU, MADE CONNECTION A CF 07 :00 08:00 1.00 ATTEMPTED TO MILL FROM 5708' TO 5720'. MILL WOULD NOT TAKE ANY A MC WEIGHT. 08:00 09:00 1.00 CBU. PUMPED DRY JOB. _ A CF 09:00,12:00 3.00 POOH.( HAD TO PUMP SECOND DRY JOB) _ A TR 12 :00 14:00 2.00 L/D MILL #2. CUTTERS WORN ON OUTSIDE. NO WEAR ON BOTTOM, NEVER MILLED A BH ALL THE WAY THROUGH THE CASING. P/U MILL #3. CUTTERS WOULD NOT _ COLLAPSE ALL THE WAY IN. MODIFIED SAME. 14 :00 16:30 2.50 RIH TO 5678' _ A TR 16:30 01:00 8.50 MILLED CASING FROM 5678' TO 5707' _ A MC 01:00 02:00 1.00 CBU, MADE CONNECTION A CF 02:00 06:00 4.00 MILLED CASING FROM 5707' TO 5721' A MC DAILY WELL COSTS 25582 CUMS 486094 DAILY MUDS 1915 CUMS 21893 Supervisor: LHL • • MARATHON DAILY DRILLING REPORT ANCHO..RAGE <.... DATE 09/11/95 RPT 15 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5772 (TVD) 5386 FOOTAGE HOURS PRESENT OP: CIRCULATING AND CONDITIONING MUD LAST CASING O.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST PPG DAYS ON LOCATION 15 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 O.D. INTERVAL ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: MILLED FROM 5721' TO 5738', MILL QUIT TAKING WT. CBU. POOH. MILL CUTTER ARMS 100% WORN. CHANGED CUTTER ARMS AND RIH. MILLED FROM 5738 TO 5752', MILL QUIT TAKING WT. CBU. POOH. NO WEAR ON CUTTERS. P/U 3 1/2" CEMENT STINGER AND RIH TO 5770'. CIRCULATED AND CONDITIONED MUD. MUD WT 9.3 VIS 99 PV 11 YP 68 GELS 19/ 39 pH 12.2 WL 44 HPHT WL _ Pm 14 Pf /Mf 2.0/ 2.6 Cl 700 Ca 120 % Oil % SOLIDS 16 BENT /SALT 23.5 / 0.0 DRILLED 201.2 BARITE -128. (lb /bbl) SPM #1 SPM #2 100 TOT SPM 100 PRESSURE 1500 TOT GPM 432 ANN VEL DP 146.4 DC 146.4 CRIT :r ::<; RUN# . >BT7 # <::::5IZE<' i:Es':7 L: TYPE SERIAL NO. ,;= zJET(32s)::. .:f EE T: >? `<:HOURS >' '; <FT/HR :; >OfE`:: I( _.. BGSR . . 9 RRMIL3 8.500 KSB 1133 14 2.00 7.00 5752 8 MILL3 8.500 KSB 1133 60 15.50 3.87 5738 7 MILL2 8.500 KSB 264 37 8.50 4.35 5708 JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. 165 BHA WT. IN MUD: _ RPM: 60 - 90 SLACK OFF WT. 130 WOB: 5 - 15 PICK UP WT. 225 TORQUE: 400 START :::.:END ::> HOURS : >:. >;:: >::,::!: »:<:<:`::: >;::::;:: ;.;:;. >:. > >:; >;::: ><:OPERATIONS IN SEQUENCE :.OP.::;:: CODES 06:00 09:00 3.00 MILL FROM 5721' TO 5738'. MILL QUIT TAKING WT. A MC 09:00 10:30 1.50 CBU. MIXED AND PUMPED DRY JOB. A CF 10:30 13:30 3.00 POOH A TR 13:30 14:30 1.00 CUTTERS ON MILL 100% WORN. CHANGED OUT CUTTERS. A BH 14:30 17:00 2.50 RIH TO 5738' A TR 17:00 19:00 2.00 MILLED FROM 5738' TO 5752'. MILL QUIT TAKING WT, GOING DOWN INSIDE OF A MC STUB. 19:00 21:00 2.00 CBU. MIXED AND PUMPED DRY JOB. A CF 21:00 24:00 3.00 POOH A TR 24:00 01:00 1.00 BHA L/D 6 DC, BUMPER SUB, JARS, SECTION MILL. ARMS ON MILL WOULD NOT A BH FULLY OPEN ON SURFACE. NO INDICATION OF MILLING STUB. 01:00 02:00 1.00 CHANGE OUT HANDLING TOOLS, STRAP 3 1/2" DP. A OT 02:00 05:00 3.00 RIH WITH 500' OF 3 1/2" DP, AND 5" TO 5770' A TR 05:00 06:00 1.00 CIRCULATE AND CONDITION MUD. START THINNING BACK. A CF DAILY WELL COST$ 38395 CUM$ 524489 DAILY MUDS 1629 CUMS 23522 Supervisor: LHL MARATHON __:DAILY DRILLING REPORT .. ANCHORAGE ........ .... ... DATE 09/12/95 RPT 16 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET iJ PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5465 (TVD) 5283 FOOTAGE HOURS PRESENT OP: TESTING BOP'S LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST PPG DAYS ON LOCATION 16 LINER 1 0.0. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CIRCULATED AND CONDITIONED MUD. R/U LINES. TESTED SHOE TO 11.1 PPG EMW. SPOT 140SX BALANCED CEMENT PLUG. POOH 10 STDS. CIRCULATED.POOH. SET RETRIEVABLE BRIDGE PLUG AT 930'. N/D BOP'S. N/D TUBING SPOOL. N/U CASING SPOOL AND TESTED SAME. PULLED RETRIEVABLE BRIDGE PLUG. SET TEST PLUG AND START TESTING BOP'S. MUD WT 9.3 VIS 41 PV 8 YP 36 GELS 10/ 18 pH 12.2 WL 50 HPHT WL _ Pm 13 Pf /Mf 2.1/ 2.4 Cl 800 Ca 120 % Oil _ % SOLIDS 16 BENT /SALT 20.0 / 0.1 DRILLED 204.6 BARITE -128. (lb /bbl) SPM #1 _ SPM #2 _ TOT SPM _ PRESSURE TOT GPM _ ANN VEL DP DC CRIT . ` :" .;> _": HR `c <:AFF::;: IO DL:: >.::'8 GS >: R ::<;: RUN # >B1 T #:<:> zS12E ". ;:;:::z:TYPE _ ::;:: SERIAL NO. - >:aJET(32t5) - FEET.. .+TOURS ..FT/ JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. _ BHA WT. IN MUD: _ RPM: SLACK OFF WT. _ WOB: — - — PICK UP WT. TORQUE: OR; > > CODES START >:END <.: HOURS <::>:>:<:>::«:::;:>::>;; >.::c:i::: »;:;: >: >:: >::: »: >:;: i:::DPERA7i0N5'iN SEQUENCE OD 06:00 08:30 2.50 CIRCULATED AND CONDITIONED MUD, LOWERING V1S AND YIELD POINT. A CF 08:30 10:00 1.50 R/U HALLIBURTON. TEST LINES TO 3000 PSI. TESTED SHOE T'O 500 PSI W/ A CM 9.3PPG MUD. 11.1 PPG EMW. MIX AND PUMP 140 SX, CLASS 'G' CEMENT WITH .6% CFR-3, .05% HR-5, MIXED WITH FRESH WATER AT 17.0 PPG. SPOTTED BALANCED PLUG. CIP AT 1000 HRS 9-11 -95. EST TOC 5465'. 10:00 11:30 1.50 POOH 10 STDS. CIRCULATED TWO BOTTOMS UP. PUMPED DRY JOB. A CF 11:30 15:00 3.50 POOH. L/D 23 JTS 5" DP. L/D 3 1/2" DP. A TR 15:00 18:00 3.00 P/U RETRIEVABLE BRIDGE PLUG AND RIH TO 1024'. ATTEMPTED TO SET SAME. A TR POOH. CLEANED METAL SHAVINGS OUT OF RBP. RIH, SET RBP AT 930'. POOH 18:00 04:00 10.00 N/D BOP'S. N/D 13 5/8 5M X 11" 5M TUBING SPOOL. N/U 13 5/8 5M X 13 A BO 5/8 5M CASING SPOOL. TESTED SAME TO 3300 PSI FOR 30 MIN. N/U BOP'S. 04:00 05:00 1.00 RIH, PULLED RBP. L/D SAME. A TR 05:00 06:00 1.00 M/U TEST PLUG AND START TESTING BOP'S A PK DAILY WELL COSTS 36243 CUM$ 560732 DAILY MUDS 1242 CUM$ 24764 Supervisor: LHL 4 1! MARATHON. DAILY: DRILLING REPORT ANCHORAGE DATE 09/13/95 RPT 17 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5730 (TVD) 5254 FOOTAGE 50 HOURS 10.00 PRESENT OP: DRILLING AT 5730' LAST CASING O.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 17 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 1 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: TESTED BOP'S. M/U BHA AND RIH. TAGGED CEMENT AT 5447'.DRILLED CEMENT FROM 5447' TO 5680'. ORIENT MUD MOTOR TO SIDETRACK. TIME DRILLED FROM 5680' TO 5730'. MUD WT 9.3 VIS 42 PV 10 YP 12 GELS 16/ 38 pH 11.9 WL 48 HPHT WL _ Pm 22 Pf /Mf 4.3/ 5.2 Cl 3500 Ca 60 % Oil _ % SOLIDS 16 BENT /SALT 20.0 / 0.6 DRILLED 200.2 BARITE - 123. (lb /bbl) SPM #1 100 SPM #2 _ TOT SPM 100 PRESSURE 2000 TOT GPM 432 ANN VEL DP 223.9 DC 146.4 CRIT RUN# ::.BIT #;>,`:S <:: !:T >: <;:;:;:> d.SERIAI >aJOs:: :;;; JET(32 5) .. . FEET :: >> HOURS " : >:ET :`:::OFF 1 O D ... . .. - 10 RR #3 8.500 C1VLRG BH108 14 14 14 253 13.50 18.74 6078 2 2 WT A E 2 NO CP 9 RRMIL3 8.500 KSB 1133 14 2.00 7.00 5752 8 MILL3 8.500 KSB 1133 60 15.50 3.87 5738 JV: 306.5 BIT PRESSURE DROP: 784.3 psi BIT HP: 197.69 BIT HP /in2: 3.484 ROTATING STRING WT. 150 BHA WT. IN MUD: _ RPM: 200 - 250 SLACK OFF WT. 125 WOB: 5 - 25 PICK UP WT. 180 TORQUE: 250 START; ::END:: HOURS.:.;:::::::: »::.:...:::: -::::. -. OPERATIONS IN SEQUENCE .. ............................... . OP CODES 06:00 08:00 2.00 ATTEMPT TO GET TEST PLUG TO HOLD PRESSURE. TIGHT THROUGH STACK. A OT STRIPED RUBBER OFF TWICE. 08:00 11:00 3.00 TEST BOP'S.ALL LINES. RAMS, VALVES AND MANIFOLD 250/5000 PSI. PULLED A PT TEST PLUG, SET WEARBUSHING 11:00 12:00 1.00 P/U AND M/U BHA, MUD MOTOR. MWD. D BH 12:00 15:30 3.50 RIH, SHALLOW TESTED MWD AT 1019'. TAGGED CEMENT AT 5447'. D TR 15:30 20:00 4.50 DRILLED CEMENT FROM 5447' TO 5680'. D DO 20:00 06:00 10.00 SURVEYED AND ORIENTED MUDMOTOR. TIME DRILLED FROM 5680' TO 5730'. D DD CUTTINGS COMING BACK AT 5720' 100% FORMATION. DAILY WELL COSTS 54701 CUM$ 615433 DAILY MUD$ 17888 CUM$ 42652 Supervisor: LHL • MARATHON DAILY DRILLING REPORT ANCHORAGE ..: DATE 09/14/95 RPT 18 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 5903 (TVD) 5514 FOOTAGE 173 HOURS 6.50 PRESENT OP: DRILLING AT 5903'. LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 18 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 2 LINER 2 0.D. INTERVAL ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: DRILLED FROM 5730' TO 5885'. CBU. POOH TO SHOE. CLEANED MUD PITS. TRANSFERRED POLYMER MUD TO MUD PITS AND WEIGHTED UP TO 9.2 PPG. DISPLACED HOLE WITH POLYMER MUD. CIRCULATED AND CONDITIONED MUD. DRILLED FROM 5885' TO 5903'. MUD WT 9.2 VIS 58 PV 14 YP 11 GELS 2/ 2 pH 10.1 WL 6 HPHT WL _ Pm 0 Pf /Mf 0.1/ 0.3 Cl 40000 Ca 100 % Oil % SOLIDS 9 BENT /SALT 5.0 / 13.7 DRILLED 83.7 BARITE -41.8 (lb /bbl) SPM #1 100 SPM #2 _ TOT SPM 100 PRESSURE 2000 TOT GPM 432 ANN VEL DP 223.9 DC 146.4 CRIT RUN# i61T #::::::::::SIZE` %: >:;zTYPE <:>: %z`> sSERTAL :NO. > >' ;; >::JET(32 ' s). ..FEET :<: :HOURS ':::::FT/HR <:::OFF I0 .._ 10 RR #3 8.500 C1VLRG BH108 14 14 14 426 18.75 22.72 6078 2 2 WT A E 2 NO CP 9 RRMIL3 8.500 KS8 1133 14 2.00 7.00 5752 8 MILL3 8.500 KSB 1133 60 15.50 3.87 5738 JV: 306.5 BIT PRESSURE DROP: 771.7 psi BIT HP: 194.52 BIT HP /in2: 3.428 ROTATING STRING WT. 150 BHA WT. IN MUD: _ RPM: 200 - 250 SLACK OFF WT. 125 WOB: 5 - 15 PICK UP WT. 190 TORQUE: 250 ;: SEQUENCE CODES START ':END ' <= HOURS '<>:>': �>:'>`>':>:::»» s:<:<::<:. :`;::. >;:. »:< >::: >:eOPERATIONS .IN E E 06:00 13:00 7.00 DRILLED FROM 5730' TO 5885'. ADT 5.5 HRS. D DD 13:00 14:00 1.00 CBU. D CF 14:00 14:30 0.50 SET KELLY BACK. PULLED UP TO SHOE. P/U KELLY. D TR 14:30 24:00 9.50 PUMPED MUD OUT OF PITS. CLEANED PITS. TRANSFER POLYMER MUD TO PITS D OT FROM STORAGE TANKS. WEIGHTED UP MUD TO 9.2 PPG. 24:00 01:30 1.50 DISPLACED HOLE WITH 9.2 PPG POLYMER MUD. D CF 01:30 03:00 1.50 CLEANED POSSUM BELLY, TRIP TANK AND SHAKER PANS. D OT 03:00 03:30 0.50 SET KELLY BACK. RIH WITH 2 STANDS. P/U KELLY. D TR 03:30 05:30 2.00 CIRCULATED AND CONDITIONED MUD. CHANGED SHAKER SCREENS. D OT 05:30 06:00 0.50 DRILLED FROM 5885' TO 5903'. ADT .25 HRS. D DD DAILY WELL COST$ 49944 CUM$ 665377 DAILY MUDS 9622 CUM$ 52274 Supervisor: PKB r J MARATHON DAILY DRILI;ING REPORT ANCH RAGE:. DATE 09/15/95 RPT 19 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET is PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 6113 (TVD) 5720 FOOTAGE 210 HOURS PRESENT OP: CORING AT 6113'. LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 19 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 3 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: DRILLED FROM 5903' TO 6070'. CBU FOR SAMPLES. DRILLED TO 6078'. CBU FOR SAMPLES. POOH. M/U CORING ASSEMBLY. RIH. CBU. CORED FROM 6078' TO 6113'. MUD WT 9.3 VIS 49 PV 16 YP 18 GELS 4/ 8 pH 9.2 WL 5 HPHT WL _ Pm 0 Pf /Mf 0.2/ 1.5 Cl 41000 Ca 180 % Oil _ % SOLIDS 8 BENT /SALT 5.0 / 14.2 DRILLED 54.7 BARITE -10.8 (lb /bbl) SPM #1 _ SPM #2 68 TOT SPM 68 PRESSURE 725 TOT GPM 294 ANN VEL DP 152.3 DC 240.0 CRIT 277.5 S Y t .;:z . JET 32 ..::.f -: HOURS...::>.: F: T lHR::<::'> Uf. EIODL::;::z::8G 5 ?:`::R RUN# BIT# :::SI2E::: >.;::::: TYPE >:: >:«:: <:::SERTAL >#10. :;. { ) 11 RRCB1 8.500 SC712 0117740 35 7.75 4.51 6138 10 RR #3 8.500 CIVLRG BH108 14 14 14 601 23.55 25.52 6078 2 2 WT A E 2 NO CP 9 ,RRMIL3 8.500 KSB 1133 14 2.00 7.00 5752 JV: 104.5 BIT PRESSURE DROP: 91.2 psi BIT HP: 15.64 BIT HP /in2: 0.276 ROTATING STRING WT. _ BHA WT. IN MUD: 39 RPM: 50 - 70 SLACK OFF WT. _ WOB: 4 - 18 PICK UP WT. TORQUE: ;; N SEQUENCE > :_:::_::::;:;::::: >:: >::c; »`:;< :: >: >:<> >:« _ , : >::<i:2: >: >: _: ` START END > HOURS : >- <::, >:::::;::`: >:> < >: > <: <<:' >::�> >OPERl1 IONS ENCE 0 CODES I U 06:00 11:30 5.50 DRILLED FROM 5903' TO 6070'. ADT 4.5, HRS. D DD 11:30 12:00 0.50 CBU FOR SAMPLES. E CG 12:00 12:30 0.50 DRILLED FROM 6070' TO 6078'. ADT .3 HRS. D DD 12:30 13:00 0.50 CBU FOR SAMPLES. PUMPED SLUG. E CG 13:00 16:00 3.00 POOH FOR CORING ASSEMBLY. E TR 16:00 17:00 1.00 POOH WITH BHA. E BH 17:00 18:30 1.50 M/U CORING ASSEMBLY. E BH 18:30 21:00 2.50 RIH. E TR 21:00 22:00 1.00 CBU. DROPPED BALL. E CF 22:00,06:00 8.00 CORED FROM 6078' TO 6113'. E CC DAILY WELL COSTS 51725 CUM$ 717102 DAILY MUDS 10760 CUM$ 63034 Supervisor: PKB 1 MARATHON DAILY DRILLING:_ REPORT ANCIiORAGE .. DATE 09/16/95 RPT 20 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 6325 (TVD) 5929 FOOTAGE 212 HOURS 12.50 PRESENT OP: DRILLING AT 6325'. LAST CASING O.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 20 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 4 LINER 2 0.0. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CORED FROM 6113' TO 6138'. CBU. POOH. L/D CORE. FULL RECOVERY. M/U DIRECTIONAL BHA. RIH TO 6030'. REAMED TO 6138'. DRILLED TO 6195'. CIRCULATED AND CONDITIONED MUD. DRILLED TO 6325'. MUD WT 9.3 VIS 54 PV 17 YP 24 GELS 5/ 13 pH 8.8 WL 4 HPHT WL _ Pm 0 Pf /Mf 0.1/ 1.1 Cl 41000 Ca 420 % Oil % SOLIDS 10 BENT /SALT 7.5 / 13.9 DRILLED 92.4 BARITE -45.6 (lb/bbl) SPM #1 104 SPM #2 68 TOT SPM 172 PRESSURE 1850 TOT GPM 450 ANN VEL DP 233.2 DC 152.5 CRIT , .. s:. RUN #. ``BIT #.'::: ;:SIZE '' >:::::TYPE : <; <;: >: >;. >::: SERIAL : >:NO. <:: <_.:::; :JET (32* :.:.5) ...FEET : >:: HOURS :::> «:FT/HR :<:: ;:OEE:< i' 0 ..... ...._ ......... .. 12 4 8.500 CO5VLRG BJ507 14 14 14 187 3.75 49.86 7130 2 2 CT A E 1 LT CP 11 RRCB1 8.500 SC712 0117740 60 14.50 4.13 6138 10 RR #3 8.500. CIVLRG BH108 14 14 14 601. 23.55 25.52 6078 2 2 WT A E 2 NO CP JV: 319.2 BIT PRESSURE DROP: 846.5 psi BIT HP: 222.25 BIT HP /in2: 3.917 ROTATING STRING WT. 160 BHA WT. IN MUD: _ RPM: 200 - 260 SLACK OFF WT. 135 WOB: 15 - 25 PICK UP WT. 195 TORQUE: 400 p OP> %_:CODES IN SEQUENCE > s»>::;>s> s:<:>::<>;; :_;:;: >:«:::;.:; :::;:<s:;..:<;s : -:::.; ;:;. z;:::: START END HOURS »s »s»::' » >>> >; »: » »s » ?:: :?i:' -'% OPERATIONS 06:00 12:30 6.50 CORED FROM 6113' TO 6138'. TORQUE INCREASED AT 6131'. P /U, BREAK E CC CORE, AND WORKED PIPE. CONTINUED CORING. 12:30 13:00 0.50 CIRCULATED AND PUMPED SLUG. E CF 13:00 16:00 3.00 POOH. E TR 16:00 17:00 1.00 BHA. L/D CORE. FULL RECOVERY. E BH 17:00 18:30 1.50 M/U DIRECTIONAL BHA. CHANGED OUT JARS. D BH 18:30 20:00 1.50 RIH TO 6030'. D TR 20:00 20:30 0.50 REAMED FROM 6030' TO 6138'. D WA 20:30 22:30 2.00 DRILLED TO 6195'. HOLE TIGHT ON CONNECTION AND ROTARY TORQUE HIGH. D DD PULLED 75K OVER. ADT 1.25 HRS. 22:30 02:30 4.00 CIRCULATED AND CONDITIONED MUD. LARGE AMOUNT OF SOLIDS OFF OF D CF SHAKERS. RAN CENTRIFUGE. CUT MUD WEIGHT FROM 9.6 TO 9.3 PPG. 02:30 06:00 3.50 DRILLED FROM 6195' TO 6325'. ADT 2.5 HRS. D DD DAILY WELL COSTS 71296 CUM$ 788398 DAILY MUDS 4369 CUM$ 67403 Supervisor: PKB • p 4 MARATHON DAILY DRILLING REPORT AN DATE 09/17/95 RPT 21 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7130 (TVD) 6723 FOOTAGE 805 HOURS 18.50 PRESENT OP: WIPER TRIP LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 21 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 5 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: DRILLED FROM 6325' TO 6690'. CBU. MADE WIPER TRIP TO SHOE. DRILLED FROM 6690' TO 6998'. CBU. DRILLED FROM 6998' TO 7130'. CBU. STARTED WIPER TRIP. MUD WT 9.3 VIS 47 PV 16 YP 16 GELS 4/ 8 pH 8.3 WL 4 HPHT WL _ Pm 0 Pf /Mf 0.0/ 1.7 Cl 41000 Ca 600 % Oil _ % SOLIDS 10 BENT /SALT 7.5 / 13.9 DRILLED 89.0 BARITE -40.0 (lb /bbl) SPM #1 104 SPM #2 TOT SPM 104 PRESSURE 1850 TOT GPM 450 ANN VEL DP 233.2 DC 152.5 CRIT . RUN# >:BIT #.::>: <; SIZE:: >:: >::: >> TYPE <`<:: >=: ::SERIAL '`NO. :::: >''JE7:(32 FEET HOURS _ >FT/ R... OFF .. 12 4 8.500 CO5VLRG BJ507 14 14 14 992 18.25 54.35 7130 11 RRCB1 8.500 SC712 0117740 60 14.50 4.13 6138 10 RR #3 8.500 CIVLRG BH108 14 14 14 601. 23.55 25.52 6078 2 2 WT A E 2 NO CP JV: 319.2 BIT PRESSURE DROP: 851.1 psi BIT HP: 223.45 BIT HP /in2: 3.938 ROTATING STRING WT. 170 BHA WT. IN MUD: _ RPM: 150 - 210 SLACK OFF WT. 140 WOB: 20 - 25 PICK UP WT. 225 TORQUE: 425 SEQUENCE ' >:<:::::::<::::;>:>::::;::<:<:::::::<:::: : >:: >::<::: >:: >:<: >:: »::: >:::<: _ >;: >;< >:.':;':::::> :::` OP ><COD START END HOURS »::::»>:.:::> �.;:.:.;;:>::: s:<::<:::<. ::: >::::;::<:<. >::`::OPERA7IONS IN S S E E 06:00 14:30 8.50 DRILLED FROM 6325' TO 6690'. ADT 6.5 HRS. D DD 14:30 16:00 1.50 CIRCULATED HOLE CLEAN. • D CF 16:00 17:30 1.50 MADE 11 STD WIPER TRIP TO SHOE. MAX PULL 40 K ON SECOND STD. D TR 17:30 00:30 7.00 DRILLED FROM 6690' TO 6998'. ADT 5.75 HRS. HOLE VERY TIGHT AT 6978'. D DD 00:30 01:30 1.00 CIRCULATED AND CONDITIONED MUD. D CF 01:30 04:30 3.00 DRILLED FROM 6998' TO 7130'. ADT 2.25 HRS. D DD 04:30 06:00 1.50 CIRCULATED UP FOR SAMPLES. CONDITIONED MUD. SET KELLY BACK FOR WIPER E CG TRIP. DAILY WELL COST$ 42353 CUM$ 830751 DAILY MUDS 10368 CUM$ 77771 Supervisor: PKB MARATHON DAILY DRILLING REPORT ANCHORAGE DATE 09/18/95 RPT 22 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET B PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7173 (TVD) 6765 FOOTAGE 43 HOURS 8.50 PRESENT OP: CORING AT 7173'. LAST CASING O.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 22 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 6 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: MADE WIPER TRIP TO SHOE. CIRCULATED AND CONDITIONED MUD. REPAIRED RIG. POOH. M/U CORING ASSEMBLY AND RIH TO 7130'. CORED FROM 7130' TO 7173'. MUD WT 9.2 VIS 45 PV 13 YP 16 GELS 4/ 9 pH 8.1 WL 5 HPHT WL _ Pm Pf /Mf / 1.6 Cl 40000 Ca 1200 % Oil _ % SOLIDS 10 BENT /SALT 7.5 / 13.5 DRILLED 96.2 BARITE -50.9 (lb /bbl) SPM #1 68 SPM #2 _ TOT SPM 68 PRESSURE 650 TOT GPM 294 ANN VEL DP 152.3 DC 240.0 CRIT 254.8 r . : >::> .: >: >: t < >.: >:: «?.:> ;::.. ;:ET :HR` ' OFFI0DL: <: > >BGS R :::::: >: RUN # >:BIT #..::SIZE:_ :.; ::TYPE.:.; :_.: SERIAL NO. ..JETE32 s). .I:EET HOURS. ... FT/ HR RR2CB1 8.500 SC712 0117740 43 8.00 5.37 12 4 8.500 CO5VLRG BJ507 14 14 14 992 18.25 54.35 7130 2 2 CT A E 1 LT CP 11 RRCB1 8.500 SC712 0117740 60 14.50 4.13 6138 JV: 104.5 BIT PRESSURE DROP: 90.2 psi BIT HP: 15.48 BIT HP /in2: 0.273 ROTATING STRING WT. _ BHA WT. IN MUD: _ RPM: 75 - 80 SLACK OFF WT. 150 WOB: 10 - 15 PICK UP WT. 230 TORQUE: 400 T N ' >_::::»:;:;.:;:>::::«:::>:>::::<::>:.:<:>:>::>:_:.<:;::.;;::::«:: :::::z>:::::«:::: >::::;:: >: OP: >:` CODES START < <:END::HOURS <::<: >: > >:;': >.<::: >:::: >::; <: >: >:':: »::::::;:::;::::;OPERA OPERATIONS 1N SEQUENCE S 06:00 08:00 2.00 MADE 19 STAND WIPER TRIP TO SHOE. D TR 08:00 11:00 3.00 CIRCULATED AND CONDITIONED MUD FOR CORING. ' D CF 11:00 13:00 2.00 CDT. REPAIRED ISOLATION VALVE IN MUD SYSTEM AND IRON ROUGHNECK. D RC 13:00 16:00 3.00 PUMPED SLUG AND POOH. D TR 16:00 17:00 1.00 BHA. L/D MWD AND MOTOR. D BH 17:00 18:00 1.00 M/U CORING ASSEMBLY. E BH 18:00 20:30 2.50 RIH TO 7130'. NO FILL. E TR 20:30 21:30 1.00 CBU AND DROPPED BALL. E CF 21:30 06:00 8.50 CORED FROM 7130' TO 7173'. ACT 8 HRS. E CC DAILY WELL COST$ 44190 CUM$ 874941 DAILY MUD$ 4937 CUM$ 82708 Supervisor: PKB 1 MARATHON DAILY DRILLING REPORT .:ANCHORAGE DATE 09/19/95 RPT 23 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7340 (TVD) 6930 FOOTAGE 167 HOURS 8.50 PRESENT OP: CBU. LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 23 LINER 1 0.1). INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 7 LINER 2 O.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CORED FROM 7173' TO 7190'. CBU. POOH. L/D CORES. 100% RECOVERY. TESTED BOPE. BHA. RIH TO 7130'. REAMED TO 7190'. DRILLED FROM 7190' TO 7340'. CBU. MUD WT 9.4 VIS 48 PV 14 YP 12 GELS 4/ 10 pH 8.3 WL 5 HPHT WL Pm Pf /Mf 1.8 Cl 40000 Ca 1200 % Oil % SOLIDS 10 BENT /SALT 7.5 / 13.5 DRILLED 82.5 BARITE -28.9 (lb /bbl) SPM #1 _ SPM #2 104 TOT SPM 104 PRESSURE 1750 TOT GPM 450 ANN VEL DP 233.2 DC 367.3 CRIT 236.5 ..., . RUN# " B PT #: >^ : SIZE TYPE _ '::: SERIAL ::: NO. :>:;:>:> ET( 32}5) ... FEET : ' >:: HOURS '' FT/HR :::<:OFF I ::: A L .. $ ... Ci .... S ... R .. 14 5 8.500 C1VLRG BJ499 14 14 14 150 3.00 50.00 13 RR2CB1 8.500 SC712 , 0117740 60 8.00 7.50 7190 12 4 8.500 CO5VLRG BJ507 14 14 14 992 18.25 54.35 7130 2 2 CT A E 1 LT CP JV: 319.2 BIT PRESSURE DROP: 860.2 psi BIT HP: 225.84 BIT HP /in2: 3.980 ROTATING STRING WT. 180 BHA WT. IN MUD: 470 RPM: 210 - 210 SLACK OFF WT. 160 WOB: 20 - 25 PICK UP WT. 240 TORQUE: 425 START END HOURS >::::::.;:>:::;>::>:::::>::>::>::>::»:: s> : >:;::: »:: >:.s:: >::::OPERAT]ONS IN SEQUENCE ::;:;:>::>:>::;:>::>::::>:;::::>::>::::::::>::>::>;::::: s:;:::>::::;:>::>::>;::>:: s::;::::>::>::.::_ . > > >::CODES:;::<:. 06:00 11:00 5.00 CORED FROM 7173' TO 7190'. TOTAL OF 60'. E CC 11:00 12:00 1.00 CBU. ' E CF 12:00 15:00 3.00 POOH. E TR 15:00 16:30 1.50 BHA. L/D CORES AND CORING EQUIPMENT. 100 % RECOVERY. E BH 16:30 21:00 4.50 TESTED BOPS. ALL RAMS, LINES, VALVES 250/5000 PSI. ANNULAR 250/2500 D PT PSI. 21:00 23:00 2.00 M/U BHA. D BH 23:00 02:00 3.00 RIH. D TR 02:00 02:30 0.50 REAMED 7130' TO 7190'. D WA 02:30 06:00, 3.50 DRILLED FROM 7190' TO 7340'. ADT 3 HRS. AT REPORT TIME GAS INCREASED D DD TO 1220 UNITS. STARTED CBU. DAILY WELL COSTS 39866 CUMS 914807 DAILY MUDS 3029 CUMS 85737 Supervisor: PKB tip MARATHON: DAILY DRILLING REPORT AN ,. CHORALE ;: DATE 09/20/95 RPT 24 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7515 (TVD) 7104 FOOTAGE 175 HOURS 3.00 PRESENT OP: LOGGING LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 24 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 8 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 O.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: CIRCULATED OUT GAS. DRILLED FROM 7340' TO 7495'. CBU. DRILLED TO 7515'. CBU. MADE WIPER TRIP TO SHOE. CBU. POOH. BHA. R/U TO LOG. RIH WITH AIT DSI GR. LOGGED FROM 7515' TO 5671'. POOH. RIH WITH FMI GR. MUD WT 9.5 VIS 47 PV 15 YP 12 GELS 5/ 14 pH 8.3 WL 5 HPHT WL 15 Pm Pf /Mf / 1.6 Cl 40500 Ca 1000 % Oil _ % SOLIDS 11 BENT /SALT 10.0 / 13.6 DRILLED 94.8 BARITE -38.1 (lb /bbl) SPM #1 _ SPM #2 104 TOT SPM 104 PRESSURE 1750 TOT GPM 450 ANN VEL DP 233.2 DC 367.3 CRIT 244.8 RUN #:::'BT >T #::: > SIZE ':> >`.::: >T:YPEi:: ><: >:::> SERIAL NO. ::>::>JETd32 s3:: ::FEET » ;:HOURS :::;>:FT/HR ">::::OF . >: >> .... 14 5 8.500 C1VLRG BJ499 14 14 14 325 6.00 54.16 7515 1 1 WT A E 3 NO TD 13 RR2CB1 8.500 SC712 0117740 60 8.00 7.50 7190 12 4 8.500 CO5VLRG BJ507 14 14 14 992 18.25 54.35 7130 2 2 CT A E 1 LT CP JV: 319.2 BIT PRESSURE DROP: 864.7 psi BIT HP: 227.03 BIT HP /in2: 4.001 ROTATING STRING WT. 180 BHA WT. IN MUD: 470 RPM: 210 - 210 SLACK OFF WT. 150 WOB: 20 - 25 PICK UP WT. 240 TORQUE: 450 START END HOURS `:::;;;::;::;:.::;.i:: -;.:`:::;: > %:«:: »` »: > <: ; <:: >OPERATIONS'' >I N SEQUENCE OP ?':= :CODES 06:00 06:30 0.50 CIRCULATED OUT GAS. MAX GAS 1220 UNITS. , D CF 06:30 10:00 3.50 DRILLED FROM 7340' TO 7495'. ADT 2.75 HRS. D DD 10:00 11:30 1.50 CIRCULATED HOLE CLEAN. D CF 11:30 12:00 0.50 DRILLED FROM 7495' TO 7515'. ADT .25 HRS. D DD 12:00 13:00 1.00 CBU. D CF 13:00 15:00 2.00 WIPER TRIP TO SHOE. D TR 15:00 16:30 1.50 CIRCULATED HOLE CLEAN. D CF 16:30 17:00 0.50 DROPPED SURVEY. D SU 17:00 19:30 2.50 POOH. D TR 19:30 21:00 1.50 BHA. RETRIEVED SURVEY. L/D MOTOR. D BH 21:00 06:00 9.00 R/U SCHLUMBERGER. RIH TO 7515'( 7513.5'WLM). LOG RUN #1 AIT DSI GR. E LG LOGGED FROM 7515' TO THE SHOE AT 5671'(5676' WLM). TOOLS ON BOTTOM AT 2400 HRS. TEMP 111 F. POOH. M/U LOG RUN #2. FMI GR. RIH. DAILY WELL COST$ 54591 CUM$ 969398 DAILY MUDS 9163 CUM$ 94900 Supervisor: PKB t. MARATHON DAILY DRILLING: REPORT H .ANC ORAGE DATE 09/21/95 RPT 25 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7575 (TVD) 7163 FOOTAGE 60 HOURS 3.00 PRESENT OP: FISHING R/U TO STRIPOVER E LINE LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 25 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 9 LINER 2 0.D. INTERVAL ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: RIH WITH FMI GR TO 7515. TOOL STUCK AT 7476' WHILE LOGGING. WORKED SAME FREE, POOH R/D E LINE. RIH WITH BIT TO 7515'. CBU. DRILLED FROM 7515 TO 7565. CBU AND EVALUATED CUTTINGS. DRILLED FROM 7565 TO 7575. CBU. POOH. R/U E LINE AND RIH WITH LDT CNL NGT CMR AMS TO 6570. TOOL STUCK WHILE CALIBRATING. WAIT ON FISHING TOOLS. R/U TO STRIP OVER WIRELINE. MUD WT 9.8 VIS 54 PV 16 YP 24 GELS 8/ 18 pH 8.3 WL 4 HPHT WL 12 Pm _ Pf /Mf 1.6 Cl 46000 Ca 1000 % Oil _ % SOLIDS 15 BENT /SALT 10.0 / 15.1 DRILLED 145.9 BARITE -64.4 (lb /bbl) SPM #1 _ SPM #2 _ TOT SPM PRESSURE TOT GPM _ ANN VEL DP DC CRIT 306.6 ' <: >::::;: G5:: »: R ?;< RU N# :: B1 > ::: >'. 7 . YPE ::::.::::.::.SERIAL aJO.,:.:.;::JET(32s):.:: FEET HOURS FT/HR :(3FF IO :> DL[:: >< >9 ...... .. 15 6 8.500 C1VLRG BJ533 12 12 12 60 2.70 22.22 7575 1 1 WT A E I NO TD 14 5 8.500 C1VLRG BJ499 14 14 14 325 6.00 54.16 7515 1 1 WT A E 3 NO TD 13 RR2CB1 8.500 SC712 0117740 60 8.00 7.50 7190 JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. BHA WT. IN MUD: 47 RPM: _ - _ SLACK OFF WT. _ WOB: - - PICK UP WT. TORQUE: N : :. ;: »: >:> >:. :;.:;::. COD START; :.:ENO; .HOURS OPERATIONS :.;:,;.;;;:<;,.::.:::.:,.:;<.:;-:;; ::,::.;;;. >::;:.;::. > :IN :.SEQUENCE ............. ............ OP:'z 06:00 09:00 3.00 RIH WITH FMI GR TO 7515'. OPENED CALIPER ARMS STARTED LOGGING UP, TOOL E LG STUCK AT 7476'. WORKED SAME FREE. POOH, R/D SCHLUMBEItGER. 09:00 13:00 4.00 M/U BIT AND RIM. E TR 13:00 13:30 0.50 CBU MAX GAS 900 UNITS. E CF 13:30 16:00 2.50 DRILLED FROM 7515' TO 7565'. HAD 660 UNITS CG AT 7535'. E DD 16:00 17:30 1.50 CBU AND EVALUATED CUTTINGS E CG 17:30 18:00 0.50 DRILLED FROM 7565' TO 7575'. E DD 18:00 19:00 1.00 CBU, PUMP DRY JOB E CF 19:00 22:30 3.50 POOH, SLM. NO CORRECTION. L/D JARS. E TR 22:30 02:00 3.50 R/U SCHLUMBERGER. P/U LDT CNL NGT CMR AMS AND RIH TO 6570'. E LG CALIBRATED TOOL, TOOL STUCK. UNABLE TO PULL FREE. 02:00 03:30 1.50 WAIT ON FISHING TOOLS AND HAND. E WS 2 03:30 06:00 2.50 GET TOOLS TO RIG FLOOR. HELD SAFETY MEETING. CUT LINE. ATTACH E OT 2 ROPESOCKET AND SPEARHEAD. HANG SHEAVES. DAILY WELL COST$ 59596 CUM$ 1028994 DAILY MUDS 5873 CUM$ 100773 Supervisor: LHL • • • Id 1111, MARATHON -DAILY DRILLING'REPORT GE: -: -- s: ! >: ::::_:: >'::::' ' :: > >5 .. :. :..:::.. . : DATE 09/22/95 RPT 26 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7575 (TVD) 7163 FOOTAGE HOURS PRESENT OP: POOH, STAND BACK BHA LAST CASING O.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 26 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 10 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: M/U FISHING TOOLS. STRIPPED OVER WIRELINE AND LATCHED TOP OF FISH AT 6497'. WORKED SAME FREE. PULLED OUT OF ROPE SOCKET AND POOH WITH WIRELINE. POOH WITH FISH. 100% RECOVERY. P/U BHA AND RIM TO 7575'. CIRCULATED AND CONDITIONED MUD. POOH. MUD WT 9.8 VIS 54 PV 16 YP 22 GELS 9/ 18 pH 8.1 WL 4 HPHT WL 10 Pm Pf /Mf____/ 1.8 CI 46000 Ca 1100 % Oil % SOLIDS 16 BENT /SALT 7.5 / 14.9 DRILLED 166.8 BARITE -79.0 (lb /bbl) SPM #1 _ SPM #2 104 TOT SPM 104 PRESSURE 2100 TOT GPM 450 ANN VEL DP 233.2 DC 367.3 CRIT 299.5 :RUN# ''B 1:T #?:.532E ? .. . TYPE ;; >::' SERIAL <:NO: >:;.;«: fEE1.:..:. HOURS: :FT /HROFF:<:.I:..;;0 D - L;: ::: ::$:S: >,:::R:<: 16 6RR 8.500 C1VLRG BJ533 12 12 12 7575 15 6 8.500 C1VLRG BJ533 12 12 12 60 2.70 22.22 7575 1 1 WT A E I NO TD 14 5 8.500 C1VLRG BJ499 14 14 14 _ 325 6.00 54.16. 7515 1 WT A E 3 NO ID JV: 434.5 BIT PRESSURE DROP: 1652.6 psi BIT HP: 433.89 BIT HP /in2: 7.646 ROTATING STRING WT. 180 BHA WT. IN MUD: 47 RPM: - SLACK OFF WT. 150 WOB: - - PICK UP WT. 240 TORQUE: . OPs;;>:CODES>:z:: ;: ND:` HOURS >: : >: <:::>::>::>:>:<::<:::>::>:;:::;:::> s::;:>:;;:;::;:;: >:: >OPERAT >IONS:: >:iN >::SEOUENC .; :.... ........... .................. 06:00 07:30 1.50 FINISH HANGING SHEAVES. M/U 7 5/8" GUIDE SHOE AND OVERSHOT WITH 3 3/8" E BH 2 BASKET GRAPPLE. 07:30 13:00 5.50 RIH STRIPPING OVER WIRELINE TO 5650'. E TR 2 13:00 13:30 0.50 M/U CIRCULATING SUB AND GET PUMP RATES E OT 2 13:30 15:00 1.50 STRIPPED OVER WIRELINE TO 6443'. CIRCULATED. LATCHED TOP OF FISH AT E Fl 2 6497'. WORKED SAME FREE. POOH 66'. PULLED OUT OF ROPESOCKET. 15:00 16:00 1.00 POOH WITH WIRELINE(GOT ROPESOCKET BACK) E OT 2 16:00 16:30 0.50 POOH TO SHOE E TR 2 16:30 17:00 0.50 SHEARED OUT PUMP OUT SUB AND PUMPED DRY JOB. E CF 2 17:00 19:30 2.50 POOH SLOWLY. HAD 100 % REOCVERY OF FISH. NO VISIBLE DAMAGE TO FISH. E TR 2 19:30 20:30 1.00 L/D LOGGING TOOLS AND FISHING TOOLS. E BH 2 20:30 21:30 1.00 RIH WITH BHA FOR CONDITIONING TRIP E BH 21:30 22:30 1.00 CUT 138' DRILLING LINE E SR 22:30 01:30 3.00 R1H TO 7575'. HAD 6' OF FILL. HOLE LOOKED GOOD E TR 01:30 03:00 1.50 CIRC AND COND MUD. MAX GAS 1325 UNITS E CF 03:00 06:00 3.00 POOH. NO PROBLEMS. E TR DAILY WELL COSTS 46079 CUM$ 1075073 DAILY MUDS 1329 CUM$ 102102 Supervisor: LHL . ��� =~ t ^ -e MARATHON DAILY DRILLING REPORT ANCHORAGE DATE 09/23/95 RPT 27 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122o AFE $ 2563000 DEEPEST TARGET m prxn xns'wo' 920119e HOURS PRESENT OP: LOGGING WITH FMI/GR DEPTH (MD) 7575 (TVD) 7163 FOOTAGE LAST CASING ' 9.625 U ' 0 9.625 LAST CASING SHOE DEPTH _ 5G7 ft. SHOE TEST 11'10 PPG DAYS ON LOCATION ----- INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 11 1 oo LINER ' ' ^"'�",°^ ---- '^' OE; --- '� ---- PPG LINER 2 U.D. INTERVAL - ft. SHOE pxuuwoocu DAYS 29 TEST __- LINER 3 o'o' INTERVAL - ft' SHOE TEST PPG EXECUTIVE SUMMARY: FROM 7575' TO 5671' ' LOGGED WITH CMR/GR FROM 7420' TO 5700' ' m/u BHA AND R/U cz��ws'rsi»«Gc»CIRCULATED NlTV LD7/�NT/«NT wnzTIowco woo' pouo R/U E LIws' RIH WITH rx1/ox TO 7420' AND STARTED LOGGING UP. MUD WT 9.9 VIS 51 PV 12 YP 24 GELS 8.0 WL 5 HPHT WL 10 Pm p, Cl 46000 Ca 1000 %oil % SOLI DRILLED 159.9 BARITE -68.0 (lb/bbl) SPM #1 SPM #2 104 TOT SPM 104 PRESSURE 2100 TOT GPM 450 ANN VEL DP 233.2 DC 367.3 CRIT 287.4 kuw# o1T#^«slZE . TYPE SERIAL NO. VET(32 F SG-SR- 16 6RR 8'500 C1VLRG uJ533 12 12 12 7575 15 6 8.500 xlvmo BJ533 12 12 12 60 2.70 22.22 7575 1 1 WT A E I NO TD 14 5 8.500 o1vms uJ499 14 14 14 325 6'00 5*'16 7515 1 1 WT A E 3 NO TD JV: 434'5 BIT PRESSURE DROP: 1669'5 psi BIT HP: 438'32 BIT op/inz; 7'724 ROTATING STRING WT. 180 BHA WT. IN MUD: 47 RPM: —__ ' ___ SLACK OFF wr' 150 WOB: __. ' ___ PICK up WT. 240 TORQUE: ----- START END HOURS OPERATIONS IN SEQUENCE ����DOP CODES 06:00 13:30 7.50 R/U SCHLUMBERGER. P/U LDT/CNT/GNT AND RIH TO 7575'. 1,0nnso 7575' TO E m 5671'' POOH L/D TOOLS. 13,30 20:30 7.00 M/U CMR/GR AND RIH. LOGGED 7420' TO 5700'' POOH uo Toom' x/n E m ncxLuwocxosx' 20:30 21:00 0'50 BHA . E BH 21:00 23,30 2'50 RIH 7o 7550'' NO FILL' E TR 23:30 01:00 1'50 CIRCULATED AND CONDITIONED wuo' MAX GAS 750 U. PUMPED DRY Juu' E CF 01:00 03:30 2'50 POOH E TR 03:30 06;00 2.50 R/U SCHLUMBERGER. P/U FMI/GR AND RIH TO 7420'. STARTED LOGGING UP. E m DAILY WELL COSTS 40650 CUM$ 1115723 DAILY moon 1995 numm 10*097 Supervisor: mL • . Sloe L . ... ............... .. . MARATHON DAILY DRILLING REPORT ANCHORAGE .: DATE 09/24/95 RPT 28 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET is PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7575 (TVD) 7163 FOOTAGE HOURS PRESENT OP: RUNNING 7" PRODUCTION CASING LAST CASING 0.D. 9.625 LAST CASING SHOE DEPTH 5671 ft. SHOE TEST 11.10 PPG DAYS ON LOCATION 28 LINER 1 O.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 12 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: FINSIHED RUNNING FMI /GR LOG FROM 7420' TO 5700'. POOH, R/D E LINE. RIH WITH BIT TO 7575'. CIRCULATED AND CONDITIONED MUD. POOH. L/D DC'S. CHANGED TOP SET OF RAMS TO 7 ". R/U TO RUN CASING. STARTED RUNNING 7" PRODUCTION CASING. MUD WT 9.9 VIS 51 PV 14 YP 19 GELS 7/ 18 pH 8.2 WL 4 HPHT WL 10 Pm Pf /Mf_/ 1.6 CL 44000 Ca 1100 % Oil _ % SOLIDS 16 BENT /SALT 7.5 / 14.2 DRILLED 160.6 BARITE -67.7 (Lb /bbl) SPM #1 _ SPM #2 _ TOT SPM _ PRESSURE TOT GPM _ ANN VEL DP DC CRIT : �.�: >:� �C:: >>:> ?;$d S 12. ,. ;:.::�:<::;::: FEET >- :f7 /HR`:> ; >OFE:;: L0pL RUN #:::BI::T #; >s: $12E TYPE :.SER > >1J0..:: ;_: :.JET(32 s). . . JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. _ BHA WT. IN MUD: _ RPM: _ - SLACK OFF WT. WOB: _ - _ PICK UP WT. _ TORQUE: ._ ...,... :;:3i; iii �� s�: > �; >ii:;>i>:ic>:>:: : :�: .:> ... ...._ ...;;;; START `'END:` ' HOURS z:::<<::»>:>;:< :_i >:: > ? ? >::? :<_ >:<:: >:: <::`::: <::; >:;APERATiONS:<_IN -.SEO SEQUENCE • _ ....:... . OP; : >:CODES 06:00 10:00 4.00 LOGGED WITH FMI /GR FROM 7420' TO 5700'. (MADE 2 PASSES OVER SAME E LG INTERVAL). POOH. R/D SCHLUMBERGER. 10:00 13:30 3.50 RIH TO 7575'. NO FILL C TR 13:30 16:00 2.50 CIRCULATED AND CONDITIONED FLUID. MAX GAS 100U. C CF 16:00 18:30 2.50 POOH TO HVY WT C TR 18:30 19:30 1.00 BREAKDOWN KELLY C OT 19:30 21:00 1.50 POOH W/ HVY WT. L/D DC'S AND STABS C BH 21:00 22:30 1.50 PULLED WB. SET TEST PLUG. CHANGED TOP SET OF RAMS TO 7 ". TESTED C OT DOORS TO 1200 PSI. 22:30 01:00 2.50 R/U TO RUN CASING. HELD SAFETY MEETING. C OT 01:00 06:00 5.00 RUN 7" 29# P -110 BTC CASING. ONE CENTRALIZER PER JOINT ON FIRST 40 JTS C CA OF CASING. HAD 50 OUT OF 181 JTS RUN AT 0600 HRS. DAILY WELL COST$ 66117 CUM$ 1181840 DAILY MUDS 2791 CUM$ 106888 Supervisor: LHL • • tow 46, HARATHON:DAILY DRILLING: REPORT:; AIJCHORAGE :::.:::`:;s :;:', DATE 09/25/95 RPT 29 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31 -7RD RIG 1220 AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7575 (TVD) 7163 FOOTAGE HOURS PRESENT OP: MAKING ROUGH CUT LAST CASING 0.D. 7.000 LAST CASING SHOE DEPTH 7575 ft. SHOE TEST PPG DAYS ON LOCATION 29 LINER 1 0.0. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 13 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 O.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: FINISHED RUNNING 7" PRODUCTION CASING TO 7575'. CIRCULATED AND CONDITIONED MUD. CEMENTED FIRST STAGE WITH 350SX CEMENT. OPEN STAGE COLLAR AND CIRCULATED. CEMENTED SECOND STAGE WITH 390 SX CEMENT. P/U STACK, SET CASING SLIPS. MADE ROUGH CUT. MUD WT 9.9 VIS 51 PV 14 YP 21 GELS 6/ 20 pH 11.0 WL 6 HPHT WL 10 Pm 3 Pf /Mf 0.4/ 3.8 Cl 41000 Ca 680 % Oi( _ % SOLIDS 16 BENT /SALT 5.0 / 13.0 DRILLED 164.2 BARITE -67.2 (lb /bbl) SPM #1 _ SPM #2 TOT SPM _ PRESSURE TOT GPM ANN VEL DP DC CRIT };. R N# C JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. BHA WT. IN MUD: _ RPM: - SLACK OFF WT. _ WOB PICK UP WT. TORQUE: START ::::::EN » 0 HOU .. .. 06 :00 13:00 7.00 FINISHED RUNNING 7" 29# P -110 PRODUCTION CASING SHOE AT 7575', F/C AT C CA 7530'. STAGE COLLARE AT 5533'. 13 :00 16:00 3.00 CIRCULATED AND CONDITIONED MUD AND RECIPROCATED PIPE. UP WT 250K, DOWN C CF WT 160K. 16:00 17:30 1.50 PUMPED 10 BBLS WATER, TESTED LINES TO 3500 PSI. PUMPED 20 BBLS C CM SUPERFLUSH, 10 BBLS WATER. MIXED AND PUMPED 350 SX 'G' WITH .2% CFR -3, .35% HALAD 344, .12% HR-5 WITH FRESH WATER AT 15.8 PPG. DROPPED PLUG AND DISPLACED WITH 291 BBLS MUD. BUMPED PLUG WITH 1500 PSI. FLOATS HELD OK. PRESSURED UP TO 2200 PSI AND OPEN STAGE COLLAR RECIPROCATED PIPE THRU WHOLE JOB. HAD FULL RETURNS. CIP 1730 HRS 9-24 -95 17:30 01:30 8.00 CIRCULATED OUT 30 BBLS OF SPACER. NO CEMENT. CIRCULATED WHILE WOC. C CF 01:30,03:00 1.50 PUMPED 10 BBLS WATER, 20 BBLS SUPERFLUSH, 1OBBL WATER. MIXED AND C CM PUMPED 390 SX TLW W/ .2% CFR-3 .4% HALAD 344, .25% LAP-1, .05% HR -5 MIXED WITH FRESH WATER AT 13.2PPG. DISPLACED WITH 214 BBLS MUD. BUMPED PLUG WITH 3000 PSI. STAGE COLLAR CLOSED OK. CIP 0300 HRS 9-25 -95. HAD FULL RETURNS THROUGHOUT JOB. 03:00 06:00 3.00 P/U STACK. SET SLIPS WITH 160K. MAKE ROUGH CUT. C OT DAILY WELL COSTS 213595 CUM$ 1395435 DAILY MUDS 1067 CUM$ 107955 Supervisor: LHL . • >:<:::<:: <:: >;::. > :; : ::: MARATHON:: DAILY.. DRILLING. REPORT _ _ AN CHORA - - -- DATE 09/26/95 RPT 30 FIELD KENAI GAS FIELD WELL NAME KENAI BELUGA UNIT No 31-7RD RIG 122D AFE $ 2563000 DEEPEST TARGET a PTVD 7380 AFE.NO. 9201195 DEPTH (MD) 7575 (TVD) 7163 FOOTAGE HOURS PRESENT OP: LAYING DOWN 5" DP LAST CASING 0.D. 7.000 LAST CASING SHOE DEPTH 7575 ft. SHOE TEST PPG DAYS ON LOCATION 30 LINER 1 0.D. INTERVAL - ft. SHOE TEST PPG DAYS SINCE SPUD 14 LINER 2 0.D. INTERVAL - ft. SHOE TEST PPG PROGNOSED DAYS 29 LINER 3 0.D. INTERVAL - ft. SHOE TEST PPG EXECUTIVE SUMMARY: INSTALLED TUBING SPOOL AND TESTED SAME. N/U BOP'S. CHANGED PIPE RAMS TO 3 1/2 ". TESTED BOP'S. L/D 5" DP FROM DERRICK. MUD WT 9.7 VIS 40 PV 8 YP 9 GELS 4/ 10 pH 10.8 WL 9 HPHT WL 12 Pm 3 Pf /Mf 0.4/ 1.9 Cl 36000 Ca 400 % Oil _ % SOLIDS 16 BENT/SALT 5.0 / 11.1 DRILLED 179.6 BARITE -88.5 (lb /bbl) SPM #1 _ SPM #2 _ TOT SPM _ PRESSURE TOT GPM _ ANN VEL DP DC CRIT JV: BIT PRESSURE DROP: psi BIT HP: BIT HP /in2: ROTATING STRING WT. _ BHA WT. IN MUD: _ RPM: SLACK OFF WT. _ WOB: — - — PICK UP WT. TORQUE: >:START >:fND?:: HOURS ::<::<::::<:: :>::::: »:;:::;::<:aPERATIONS:;IN SE UE E OP E'<';cCODES s »i 06:00 11:00 5.00 MADE ROUGH CUT. L/D LANDING JOINT. MADE FINAL CUT. INSTALLED 13 5/8 C OT 5M X 11 5M TUBING SPOOL. TESTED SAME TO 5000 PSI OK. 11:00 15:30 4.50 N/U BOP'S. CHANGED PIPE RAMS TO 3 1/2 ". CLEANED PITS. MIXED 430 BBLS C BO KCL WATER. 15:30 17:00 1.50 CLEARED RIG FLOOR. P/U TEST PLUG AND TEST JOINT C OT 17:00 20:00 3.00 TESTED BOP'S. ALL LINES, RAMS, VALVES AND MANIFOLD 250/ 5000 PSI. C PT ANNULAR 250/2500 PSI. PULLED TEST PLUG. SET WEAR BUSHING. 20:00 06:00 10.00 L/D 5" DRILLPIPE AND HVY WT FROM DERRICK. C DS DAILY WELL COSTS 25511 CUM$ 1420946 DAILY MUDS 3688 CUM$ 111643 Supervisor: LHL • • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 11/22/95 FIELD: Kenai Gas Field WELL #: KBU 31 -7RD FILL DEPTH /DATE: 7409' 11/6/95 TUBING: 3 -1/2" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 11/17/95 TREE CONDITION: Good WORK DONE: Replace injection valve w/ dummy valve BENCHES OPEN: L12/L13 (L17/18 covered) PRESENT OPERATION: Frac L12/13 - bring well on line PROBLEMS: SUMMARY OF OPERATIONS 11/21/95 - Spot Dowell frac and CT equipment. Fill up frac tanks w/ water, heat to 10OF and mix 3% KCI. Gel 250 bbls of YF 135 and 500 bbls of WF120. RU lines and install tree saver on top of well. PTS RU lines. PT to 1500 psig to choke, 400 psig downstream choke, fill line heater and startup, check equipment. 11/22/95 - hold safety meeting w/ Dowell and PTS personnel. Check gel properties. Stroke tree saver (WHP = 2348 psig). Test lines 0845 to 9000 psig - good test. PRessure up back side to 3400 psig. Fill hole and perform breakdown and injection test pumping 60 bbls of WF120 and 70 bbls of pad (hole volume = 90 bbls). ISIP = 2751 psig (F.G. = 0.85 psi /ft). 4500 psig STP @ 20 BPM w/ WF120 slick water. Calculate pert friction @ 449 psig (negligible). Continue pumping 49 bbl pad, followed by 26 bbls 2 ppa, 42 bbls 4 ppa, 58 bbls 5 ppa, 91 bbls 6 ppa, 94 bbls 7 ppa, 65 bbls 8 ppa and 80 bbls WF120. Flushed final proppant stage to within 3 bbls of top perforation. ISIP = 2850 psig. 100% of planned design was placed. Total proppant pumped wat 75,027 #; of which 73,777# went into th eformation, and 1250 # was left in the wellbore. Approximately 560 bbls of Toad water to recover. Proppant used was 20/40 Carbolite. The pad was tagged with 7 mCi of SC46 (Scandium); stages 2 -6 ppa were tagged with 15mCi of SB124(Antimony); stages 7 -8 ppa were tagged with 15 mCi IR 192 (Iridium). RD treesaver and brought well on line. WHP dropped from 1900 psig to 0 psig in approximately 5 minutes. Produced a total of 24.2 bbls in 30 minutes. Well dribbling water into tank. RU HES and SI well. RIH w/ 2 -1/2" OK -1 and 1 -1/4" JDC pulling tool. Latch dummy valve in injection mandrel at 996' wlm and POOH. RIH w/ 10/64" injection valve w/ dual check. Set valve and POOH. WHP 1310 increased to 700 psig in 1 hour. Flow small gas head off well followed by .5 bbls of water. Well dribbling water into tank. Estimated costs: Transportation - $3000 Fuel - 1000 HES - 1500 Dowell frac - 165000 Steam on Wheels - 2000 ProTechnics - 10000 Total - $182,500 WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: 0.42 0 660 0 11/5/95 AFTER: COMMENTS: DAILY COST: $ 182,500 CUM: $ 2,210,693 REPORTED BY: Olson /Sinclair • • ) • MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 11/24/95 FIELD: Kenai Gas Field WELL #: K8U 31 - 7RD FILL DEPTH /DATE: 7409' 11/6/95 TUBING: 3 -1/2" 9.3# L -80 CASING: 7 "- 7575' DATE LAST WL WORK: 11/17/95 TREE CONDITION: Good WORK DONE: Replace injection valve w/ dummy valve BENCHES OPEN: L12/L13 (L17/18 covered) PRESENT OPERATION: Frac L12/13 - bring well on line PROBLEMS: SUMMARY OF OPERATIONS 1500 11/22/95 RU Dowell CTU. Test to 4000 psig. Let well flow while RU. Total fluid recovered was 42 bbls. 1700 RIH w/ CT to 7250' circulating .25 bpm. Did not tag sand. Circulate 10 bbl gel sweep while POOH to 6500'. Recovered some 20/40 proppant. RIH to 7405'. Tagged previous sand back plug. Washed to 7415'. Circulate 10 bbl gel sweep. POOH to 6500', Recovered some proppant. RIH to 7405'. Circulate 10 bbl gel sweep. Did not recover any proppant. POOH to 4000'. 11/23/95 Start pumping N2 at 4000'. Recovered 53 bbls. Stop N2. Put well thru PTS separator. Well making 400 mcfpd (mainly 0030 N2). Water rate fell to 0. Start N2. Recovered additional 9 bbls. Water rate dropped to 0. RIH to 5250' w/ CT. Continue pumping N2. Recovered 17 bbls of water. Water rate fell to 0. RIH to 6400'. Continue pumping N2. Recovered additional 20 bbls of water. 0230 Stop pumping N2. Recovered 6 bbls of water. Gas rate = 285 mcfpd. 0400 Pump N2 for 1 hour. Recovered 14 bbls of water. Stop N2 for 1 hour. Recovered 1 bbl of water. Gas rate 793 mcfpd. Pump N2 for 0600 1 hour. Recovered 7 bbls of water. Stop N2 for 1 hour. Recovered 2 bbls of water. Gas rate 946 mcfpd. Pump N2 for 30 minutes. 0700 POOH while pumping N2. Recovered additional 13 bbls while POOH. Total load recovered to date is 187 bbls. RD CT. Flow well to PTS. Rate is 560 mcfpd at 275 psig w/ 2 bwph. 11/24/95 Rate 2.163 mmcfpd at 375 psig with 0.5 bph. Recovered additional 50 bbls of Toad. Total Toad recovered is 237 bbls. Turn well to production facilities. 1300 1130 Cost estimate: PTS - $36300 APC - 2280 Udelhoven - 4650 Dowell - 30000 Total - $73230 • WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: 0.42 0 660 0 11/5/95 AFTER: 2.163 12 375 11/24/95 COMMENTS: DAILY COST: $ 73,230 CUM: $ 2,283,923 REPORTED BY: Sinclair •4) •) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 11/26/95 FIELD: Kenai Gas Field WELL #: KBU 31 -7RD FILL DEPTH /DATE: 7415' 11/22/95 TUBING: 3 -1/2" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 11/22/95 TREE CONDITION: Good WORK DONE: CT cieanout/N2 blowdown BENCHES OPEN: L12/L13 (L17/18 covered) PRESENT OPERATION: RUN MULTIPLE ISOTOPE SPECTROSCOPY PROBLEMS: FREEZING IN TREE SUMMARY OF OPERATIONS 0830 SWS on location. RU equipment. MU TOOL, PT LUB TO WHP WHP -.= 2150 PSI NOTE: WELL SHUT IN AT 1200 MIDNIGHT ON SATURDAY. WELL AT 2.7 MMCFPD @ 360 PSI MADE THREE LOGGING PASSES ACROSS PERFED INTERVALS. ISOTOPES USED DURING FRAC JOB = SC46 (SCANDIUM - PAD), SB124 (ANTIMONY - 2 -6 PPA STAGES), IR -192 (IRIDIUM - 6 -8 PPA STAGES) INSPECTED LOGS FOR REPEATABLITY FIELD INTERPETATION FROM LOG INDICATES MOST OF THE SAND WENT INTO THE PERF INTERVAL @ 7180 -7193 AND ABOVE THE TOP PERFS FROM 7158 - 7164'. SMALLER AMOUNTS OF SAND WENT INTO THE PERFS @ 7207 -7219 AND 7225- 7230'. THE PERFS BETWEEN 7250 -7326' APPEAR TO BE LARGELY UNTREATED WITH ONLY A SMALL VOLUME OF PAD AND TRACES OF THE 2- 6 PPA STAGES ENTERING THE PERFORATIONS. 2030 RD SWS, CHECK FOR RADIATION AT SURFACE. • WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: 2.7 0 360 0 11/24/95 AFTER: 2.7 0 360 11/25/95 COMMENTS: DAILY COST: $ 11,861 CUM: $ 2,295,784 REPORTED BY: WEC • •3 •) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/11/95 FIELD: Kenai Gas Field WELL #: KBU 31 - 7RD FILL DEPTH /DATE: 7409' 11/6/95 TUBING: 3 -112" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 12/8/95 TREE CONDITION: Good WORK DONE: Production Log BENCHES OPEN: L12/L13/L17/18 covered) PRESENT OPERATION: Placed sand plug over the L12 and L13 sands. PROBLEMS: Final sand plug tag is partially covering the L11 sand. SUMMARY OF OPERATIONS 0600 Steam on Wheel heating up 330 bbls of water in tiger tank. 0730 Dowell continue to RU from previous day. 1400 Water tank temp = 100 F. SD steam. PT to 4000 psig using methanol /water mix. 1430 Good test. Circulate methanol /water out of coil and back to 2000 gallon tank. 1520 Open swab and RIH. Well flowing @ 950 psig. SI well @ 1800' (1605 hrs). Circulate fluid through coil every 15 -20 mins. Flow gas through flow line every 30 mins to prevent freeze up. 1717 Tag fill twice @ 7412' kb (7400' ctm). Last E -line tag was 7415' kb. 1740 Mix sand per design - no changes. Add 6600# sand, to 22.5 bbls of water w/ 10 gallons J877 gel, 4# breaker 466 and 2# breaker aide 218. Mix for 1 hour. 1913 Pump 30 bbls of sand slurry followed by 35 bbls 3% KCl water. POOH from 7403' on a 1:1 displacement ratio after 1 bbl on sand has passed through nozzle. WHP initial was 1681 psig. Final WHP = 711 psig. Returns were taken to open top tank. PU to 6300' and wait 2 hours. Circlulate water through coil every 15 minutes, pressuring up WHP to 1000 psig. 2200 WHP = 436 psig. RIH and tag sand plug @ 7122' kb (33' high). PU to 6957' and wait 30 minutes. RIH and tag sand plug @ 7122' kb. Mix up 15 bbls water w/ 5 gallons J 877 gel. RIH and cleanout sand plug to 7158' kb. Pumped 10 bbls water, 15 bbls gel and circulate bottoms up. Worked up and down to flush sand out of casing. Pump rate was 1.75 - 2.1 bpm. PU to tubing tail and circulate bottoms up. Wait 30 minutes. 0030 0030 RIH and tag sand plug @ 7151' kb twice. Pump 2 bbls methanol to pressure up on plug from 92 psig to 539 psig. Pressure decreased to 362 psig in 1 minute. RIH and tag plug at 7151' kb. POOH to 5000'. PT N2 to 3000 psig. Unable to take returns to production due to frozen drain on test separator. RIH to 5250'. Begin pumping N2 at 1000 scf /m taking returns to open top tank. Kept super sucker on location to keep tank dry to prevent spill when N2 hits. Pumped a total of 600 gallons N2. Maintained backside pressure at 1000 psig. When N2 hit, pressure increased to 2105 psig. Dry returns. SD N2. 0305 RIH and tag sand plug @ 7144' kb two times. POOH. OOH. WHP = 1605 psig. Pressure up well to 2000 psig w/ N2. Close master and blow down coil through flow line to remove any water in flow Tine. Close wing, swab, and open master valves. 0545 RD. Note. Sand plug was tagged at 7144'. The L11 interval from 7141 -7149' is partially covered. Plans are to perf just the top part of this sand. Also, the CTM was never corrected for the last E -line tag. If this correction is made, the sand plug would be at 7147. Perforating will begin after SWS get done w/ Rig work (there were no other crews available). WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: 2.41 0 1105 12/11/95 AFTER: COMMENTS: DAILY COST: $ CUM: $ 2,322,812 REPORTED BY: Olson 4 •) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/13/95 FIELD: Kenai Gas Field WELL #: KBU 31 -7RD FILL DEPTH /DATE: 7145' 12/13/95 TUBING: 3 -1/2" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 12/11/95 TREE CONDITION: Good WORK DONE: Sand back L12/13 sands BENCHES OPEN: L12,13,17,18 covered) PRESENT OPERATION: Perf the L11 and L10 zones PROBLEMS: Freezing in tree SUMMARY OF OPERATIONS 1100 SWS RU Unit, WHP =1800 Held a safety and environmental meeting and discussed procedure. 1415 Set up communication Blackout prior to loading gun. Posted sings up on both sides of location. MU 2 1/2" HC gun, 6 spf, 60 deg. phasing on each run in well. Set up communication blackout prior to loading gun and pulling gun up to surface. bled the well to 1750 psi on the first gun run. Perforate the following: Run # Interval Footage Comments: 1 7094 - 7114 20' tag fill after perforating fill at 7147', perf L11 WHP = 1750 psi before /after perforating 1900 2 7080 - 7094 14' tag fill after perforating fill at 7145', perf L10/1 1 WHP= 1800 psi before /after perforating 2220 3 7141 - 7146' 5' Possibly shot the interval 1' high based on the pickup weight. Perf. L11 WHP= 1800 psi & 12/14 after reperforating. 0120 4 7125 - 7137' 12' Possibly shot the interval 1' high based on the pickup weight. Perf. L1 1 WHP= 1800 psi, before & after reperforating. 0230 OOH with Run #4, all shots fired on each run in well. RD SWS • note:WHP= 1800 psi, put well to Test separator for 35 min. bled the well down to 1510 psi /6 -7 MMCFPD rate prior to shutting the well in at the Line heater. Shut well in at 0330 am. Decide not to flow well to risk flowing sand plug back. Gas was bled off well to clean up perfs. Will get a SBHP on Saturday, 12/16/95. WHP =1900 PSI AT 1000 AM. WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ 15, 681 CUM: $ REPORTED BY: Cissell 1) 10) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/17/95 FIELD: Kenai Gas Field WELL #: KBU 31 -7RD FILL DEPTH /DATE: 7145' 12/13/95 TUBING: 3 -1/2" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 12/13/95 TREE CONDITION: Good WORK DONE: Perf L10/L11 sands BENCHES OPEN: L1o/11 (L12,13,17,18 covered) PRESENT OPERATION: Well SI pending frac PROBLEMS: SUMMARY OF OPERATIONS 1300 Arrive on location. RU. Start HMR gauge 10015 at 14:03.56 and 10078 at 14:04.56. MU gauges and MI string. 1414 Open well. Test against WHP. No leaks. 1418 RIH w/ gauges. Tag fill at 7167' WLM RKB. 1510 PU to 7112' and record SBHP for 2 hours. POOH. 1750 OOH. 1815 MU 3.5" OK -1 kickover tool w/ 1 -1/4" JDC pulling tool. Latch injection valve @ 991' WLM. OOH w/ 1905 valve. 1905 RIH w/ 3.5" OK -1 and 210 RT 1000 running tool. Set dummy valve in mandrel. Test control line to 3000 psig for 15 minutes. Bleed to 0 psig. Good test. Note small amount of sand on KO tool. RD. Download gauge data, paperwork. 2030 Leave lease. Left well SI. WHP = 1993.6 PSIA, SBHP = 2856.4 PSIA, SBHT = 120.5 F (Gauge 10015) WHP = 1986.6 PSIA, SBHP = 2858.5 PSIA, SBHT = 120.4 F (Gauge 10078) WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ 2262 CUM: $ REPORTED BY: R. Ashford 1) i) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/21/95 FIELD: Kenai Gas Field WELL #: KBU 31 - 7RD FILL DEPTH /DATE: TUBING: 3 -1/2" 9.3# L -80 CASING: 7" - 7575' DATE LAST WL WORK: 12/17/95 TREE CONDITION: Good WORK DONE: SBHP, installed dummy valve in inj. mandrel BENCHES OPEN: L10,11,12,13,17,18 PRESENT OPERATION: RIH w/ CT to cleanout sand PROBLEMS: Crimped CT in goose neck roller several times SUMMARY OF OPERATIONS 0600 12/21/95 Dowell and PTS continue RU frac and testing equipment from previous day. 1100 Hold safety meeting w/ Dowell and PTS personnel. PT PTS equipment to 2000 psig. RU tree saver . Pressure up control line to 3000 psig, backside to 3100 psig. PT Dowell equipment to 9900 psig. Good test. Open swab and set tree saver - test back side - OK. WHP = 2233 psig. Begin pumping 4500 gal WF135 pad, followed by 500 gal YF135 pad, 1000 gal YF135 w/ 2.0 ppa, 1000 gal YF135 w/ 4.0 ppa, 2500 gal YF135 w/ 5.0 ppa, 3500 gal YF135 w/ 6.0 ppa, 3500 gal YF 135 w/ 7.0 ppa, 4000 gal YF135 w/ 8.0 ppa. 114 bbls into 8 ppa stage increase proppant to 12 ppa. Cut cross linker. Displace proppant w/ 74 bbls of WF135. 52 bbis into flush dec rate to 15 bpm. 62 bbls into flush dec rate to 10 bpm. 67 bbls into flush dec rate to 5 bpm. Proppant displaced to within 5 bbls of top perf. Total proppant pumped was 98961#; of which 97337# went into the formation, and 1624# left in wellbore. Proppant was 20/40 Carbolite. Inj pressure ranged from 3650 to 4476 psig while pumping frac @ 20 bpm. Approximately 560 bbls of load water to recover. SI well - ISIP = 3419 psig. Immediately flowed well back to force closure. Flowed back 20 bbls of fluid in 8 minutes, initially at 0.5 bpm and increasing rate to 4 bpm. RD tree saver and open well through PTS equipment. Produced 38.25 bbls in 1.5 hours. 1440 Initial WHP = 2075 psig. Final WHP = 0 psig. SI well. HES RU. RIH w/ 3 -1/2" OK kick over tool and 1- 1 /4" JD pulling tool to 991' wlm. Pull dummy valve. POOH. RIH w/ 1" double check orifice and set @ 1600 991' wim. POOH. RD. Open well up to production. WHP bled from 700 psig to 0 psig in a couple of 1645 minutes. RU CTU. PT coil to 4000 psig. Good test. Well dead - flowed back 60.75 bbls through PTS equipment. 2035 RIH pumping 0.5 bpm holding 200 -300 psig back pressure. At 250', stripping rubber began to leak. PU and leak stopped. POOH and retest to 4000 psig. Good test. Found flat spot in CT at 250' - coil jumped off of roller and got caught in the top roller. Decide to cut off 300' of coil. 2350 RIH pumping .6 bpm hold 200 -300 psig back pressure. At 1057' CT shifted off of goose neck. PU and check coil. Found flat spot in coil again. POOH. Cut off 1090 of coil. Install guide on goose neck. Believe problems are due to coil being RU too close to well (24'1. 0700 12/22/95 PT coil to 4000 psig and RIH. ** *Total bbls recovered = 80.75 out of 560 bbls injected. Estimated Cost: Dowell Frac 165,000 Dowell CT 1,500 Otis 1,100 Fuel 1,000 Transportation 3,200 APC Vac truck 1,300 PTS 5,000 Steam of Wheels 2,000 Udelhoven 2,200 Total $182,300 WELL TESTS: MMSCFPD BWPD TP CP DATE BEFORE: AFTER: COMMENTS: DAILY COST: $ 182,300 CUM: $ REPORTED BY: Olson /Sinclair v •� • ) KBU 31 -7rd Cooper Tubing Hanger (29.5 -30.5, OD:10.906, I D:2.953) Tubing (30.5 - 6444.0, OD:3.500, ID:2.984) Intermediate Casing (0.0- 5680.0, OD:9.625) Structural Casing (0.0 -95.0, OD:20.000) Camco Injection Mandrel (1012.7- 1019.6, OD:5.188, I D:2.906) Surface Casing (0.0- 2526.0, OD:13.375) Production Casing (0.0- 7575.0, OD:7.000) Core (6078.0 - 6138.0) Baker 80 -40 K- Anchor (6304.7 - 6305.8, OD:4.750, ID:3.250) - r 7 Baker 84 -40x32 SAB Packer (6305.8- 6310.7, OD:5.687, 10:3.250) Camco X Nipple (6350.3 - 6351.3, OD:3.859, ID:2.813) Camco X Nipple (6412.2 - 6413.2, OD:3.859, ID:2.813) Wreline Reentry Guide (64440 - 6444.6, OD:3.859, BEM 10:3.000) L10 Pert (7080.0- 7114.0) Fracture Treatment (7080.0- 7146.0) _ _ L11 Pert (7125.0- 7137.0) Perf (7141.0- 7146.0) L12 Core (7130.0- 7190.0) - - �f_ Perf (7180.0- 7193.0) L13 Pert (7207.0- 7212.0) - l Pert (7225.0- 7231.0) >_ Fracture Treatment (7180.0- 7326.0) - - -_ - Pert (7250.0- 7290.0) Pert (7290.0- 7326.0) Pert (7452.0- 7480.0) - -- -- L17 Pert (7490.0- 7508.0) -___ = L18 Perf (7512.0- 7516.0) Pert (7529.0- 7534.0) - Fill (7551.0- 7556.0, OD:6.188) Cement Plug (7556.0- 7575.0, OD:6.016) -� API 50- 133 -20347 4/11/97 i,~ Oil Company - Kenai Gas Fie[~ ,: KBU 31-7RD dP! 50-133-20347-01 # DEPTH DEVIATION AZIMUTH TVD XOFFSET YOFFSET 0.000 0.000 0.000 0.000 0.000 0.000 100.000 0.166 297.000 100.000 -0.129 0.066 200.000 0.366 330.000 199.999 -0.450 0.393 300.000 1.133 267.000 299.989 -1.600 0.882 400.000 0.550 317.000 399.978 -2.945 1.348 500.000 0.566 287.000 499.973 -3.763 1.857 600.000 0.600 292.000 599.968 -4.721 2.197 700.000 0.533 265.000 699.963 -5.690 2.346 800.000 0.316 262.000 799.961 -6.426 2.263 900.000 0.083 351.000 899.960 -6.707 2.411 1000.000 1.033 144.000 999.954 -5.934 2.397 1100.000 3.366 135.000 1099.87'5 -3.402 -0.485 1200.000 5.853 112.000 1199.544 3.321 -4.761 1300.000 7.58~ 90.000 1298.855 14.737 -6.879 1400.000 7.800 260.000 1397.956 15.433 -15.840 1500.000 9.18~ 118.000 1496.857 14.101 -27.037 1600.000 9.750 137.000 1595.495 27.072 -37.027 I700.000 12.133 131.000 1693.670 40.745 -50.180 1800.000 14.416 132.000 1790.991 57.938 -65.399 1900.000 17.433 49.000 1887.143 83.042 -65.021 2000.000 20.633 132.000 1981.664 112.867 -65.907 2100.000 23.866 130.000 2074.206 141.451 -90.733 2200.000 25.016 130.000 2165.243 17'5.147 -117.329 2300.000 25.183 131.000 2255.800 205.402 -144.878 2400.000 25.433 131.000 2346.202 237.664 -172.924 2500.000 25.366 131.000 2436.536 270.036 -201.064 2600.000 25.850 130.000 2526.713 302.902 o229.133 2700.000 26.116 132.000 2616.605 335.964 -257.873 2750.000 25.950 139.000 2661.532 351.335 -273.517 2800.000 26.316 145.000 2706.421 364.885 -290.866 2850.000 26.8~3 148.000 2751.138 377.227 -309.518 2900.000 26.866 149.000 2795.748 389.026 °328.772 3000.000 27.450 150.000 2884.723 412.191 -368.101 3100.000 28.000 149.000 297'5.242 435.804 -408.186 3200.000 28.8~3 150.000 3061.192 459.954 -449.189 3300.000 29.000 149.000 3148.725 484.496 -490.851 3400.000 28.816 150.000 3236.264 509.030 -532.502 3500.000 28.966 150.000 332~.818 533.188 -574.344 3600.000 28.816 150.000 3411.372 557.345 -616.185 3700.000 28.800 150.000 3498.996 581.439 -657.917 3800.000 28.933 150.000 3586.571 605.5~ -699.726 3900.000 28.533 150.000 3674.258 629.613 -741.358 4000.000 28.733 149.000 3762.028 653.935 -782.646 4100.000 28.550 149.000 3849.792 678.622 -823.733 4200.000 28.600 149.000 3937.611 703.257 -864.732 4300.000 28.28~ 151.000 4025.541 727.069 -905.975 4400.000 28.483 149.000 4113.520 750.8~8 -947.139 4500.000 28.466 150.000 4201.423 775.035 -988.219 4600.000 28.333 150.000 4289.388 798.816 -1029.408 4700.000 27.783 149.000 4377.635 822.687 -1069.936 4800.000 25.650 148.000 4466.954 846.171 -1108.267 4900.000 23.466 148.000 4557.903 868.193 -1143.509 5000.000 21.466 146.000 4650.309 888.995 -1175.558 5100.000 19.68~ 145.000 4743.927 908.895 -1204.519 5200.000 18.166 143.000 4838.519 927.951 -1230.758 5300.000 17.050 144.000 4933.832 945.945 -1255.072 5400.000 16.716 145.000 5029.522 962.810 -1278.715 5500.000 16.683 144.000 5125.304 979.496 -1302.108 5600.000 16.716 143.000 5221.087 996.589 -1325.207 5700.000 16.733 143.400 5316.857 1013.827 -1348.249 ,07.000 5999.000 6124.000 6217.000 6309.000 6402.000 6495.000 6588.000 6681.000 6773.000 6867.000 6988.000 7437.000 7450.000 ?500.000 7'575.000 12.200 11.200 11.200 10.700 10.700 10.300 10.100 9.800 9.700 9.600 9.600 9.300 9.000 8.500 8.500 8.500 8.500 146.100 135.900 128.800 121.100 115.950 109.200 105.500 106.300 106.800 107.400 107.400 105.500 104.310 102.600 102.600 102.600 102.600 5427.~ 5518.280 5608.528 5731.251 5822.635 5913.094 6004.624 6096.225 6187.882 6279.566 6370.277 6463.002 6582.462 7O26.235 7039.092 7088.543 7162.719 1030.282 1042.117 1055.316 1074.757 1089.923 1105.393 1121.109 1136.563 1151.660 1166.561 1181.201 1196.002 1214.595 1281.017 1282.892 1290.105 1300.923 -1371.475 -1386.125 -1398.154 -1411.754 -1419.997 -1426.434 -1431.345 -1435.747 -1440.233 -1444.817 -1449.405 -1453.776 -1458.726 - 1474.627 -1475.046 -1476.658 -1479.076 acashon Oi I Comp any ; 1-,3-96 ;10'25A~I ; Anchorage~ Alaska Region Domestic Production ~07 276 7542;# 2/ 8 -~ Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 6, 1995 Steve McManus Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 civPJD RE: Kenai Gas Field Completion Reports JAN 0 ~ 11[~G Dear Steve: Alaska 0il & Gas Cons. Commission Anchorage As we discussed last week, Marathon has plans to extensively test the redrills ~9 .-. and workovers in the Kenai Gas Field ,fter the rig has been released. This letter ,,~~ is to inform you of those plans. " ~., w,.. ~'~'~ - ~ KTU 43 6XRD Redrill Rig work completed on 8/16/95 ~'~:"~5 KBU 31~7RD Redrill Rig work completed on 9/30/95 KDU 4RD Workover Rig work completed on 10/24/95 x~ KDU 2 Workover Rig work in progress KBU 41-7 Workover TO be performed ~..~ KTU 43-6XRD The Tyonek D-1 interval has been perforated and tested. An extreme ~verbalance surge treatment was attempted but was unsuccessful. A hydraulic fracture treatment was performed on 10/30/95. The well is currently cleaning up following this treatment. . ~ After sand zone time, the well cleans up, plans are to temporarily abandon the D-1 by setting a plug across the zone, The plans are to perforate and test the Tyonek 86-2 and then sand it off. Then perforate and test the Tyonek 84-6 zone. At this the Tyonek 84-6 is expected to be the "permanent" completion interval, KBU 31-7.RD The Beluga L-17 and L-18 zones have been perforated and tested. A pressure build up test was run prior to sanding off these intervals. The Beluga L-12 and L-13 were then perforated and tested. A pressure build up test has been run on these zones. A subsidiary of USX Corporation Environmentally aware for the long run. ~ca~non 9ii ~ompany A~c~orage~ · Alask~ Oil & Oas Consen~ti~n Commission November Page; Plans are to perforate additional L-13 interval ancl then evaluate for a fracture _treatment. Two scenarios are curremly being evaluated. The first is to fracture treat the L-12 and L-13, then perforate and fracture treat the L-10 and L-11 intervals. Altematively a single stage fracture treatment of the L-10 thru L-13 may be performed. Irregardless of the fracture treatment m~thod, the "permanent' completion interval is expected to be the Beluga L-10 thru L-13. No perforating or testing has been performed to date. Plans are to perforate and test the Beluga L-13 interval and perform a pressure build up test. The L-13 interval will then be sanded off. The Beluga L-9 and L-10 intervals will then be perforated, tested, and sanded off. Following that, the Beluga M-14 thru L-3 will be perforated and evaluated for a fracture treatment. The "permanent" completion interval is expected to be the Beluga M-14 thru L-3. KDU 2 Following dg operations, plans are to perforate the Tyonek 75-8 and evaluate for fracture treatment. Depending on the results of that interval, the Tyonek 73-1 and 72-8 may also be tested. K_BU_41~-7 Current plans are to fracture treat two lower Beluga packages while the rig is on the well. Exact intervals will be determined based on the results in other wells. Due to the extensive testing programs for the wells, my plans are to delay filing Completion Reports until the "permanent" intervals are tested and treated. If further information is required, please advise. Sincerely, M. F. Sinclair Drilling Superintendent MFS/I~;MF81106b,ltr JAN 0 3 l°JgG Alaska Oil & Gas Cons. Commission Anchorage Letter of Transmittal MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 1961 68 Anchorage, Alaska 99519-61 68 Telephone: (907) 561-5311 Fax: (907 564-6435 January 2, 1996 TO: Howard Okland Alaska Oil & Gas Conservation Commission ,.,uu, Porcupine Dr~ve Anchorage, AK 99501 FROM' Chick Underwood Exploitation Department Description t "~KKDU-4RD PERFORATING RECORD bfi/~, PERFORATING RECORD ~3,,1-7RD PERFORATING RECORD PERFORATING RECORD , -"/ )" MULTIPLE ISOTOPE SPECTROSCOPY KBU 41-7 SQUEEZE GUN /,~fi / ~./~ " CEMENT RETAINER Print Film 11/11/95 1 1 11/25/95 1 1 10/26/95 1 1 11/O6/95 1 1 11/26/95 1 1 12/12/95 1 1 12/12/95 I I TOTAL 7 7 The data is considered confidential until the normal release date. (Marathon Oil) (R~eyed By) v' (Date) (Date) Please Return 1 Copy by Either FAX or Mail to Marathon JAN 0 Alaska 0tl & Gas Cons. Commission An~h0rage MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 1961 68 Anchorage, Alaska 99519-6168 Telephone: (907) 561-5311 Fax: (907 564-6435 Letter of Transmittal December 1, 1995 TO: Howard Okland Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~)~._~/.- WELL' KBU 31-7RD C,/~ APl 50-133-20347-01 FROM' Chick Underwood Exploitation Department WELL LOGS Description Print Film LithoDensity Neutron (LDT/N) Array Induction/GR (AIT/GR) Dipole Sonic Imager (DSl) Combinable Magnetic Resonance Formation Micro-Image (FMI) Natural Gamma Spectroscopy (NGS) Cement Bond Log (CBL) Cement Evaluation Log (CEL) Plug Setting Record (CMRI) Mud Log TOTAL 10 DIGITAL DATA DSI/AIT Field Tape Copy 1 LDT/CNL/NGT Field Tape Copy 1 FMI Field Tape Copy 1 CET Field Tape Copy 1_ TOTAL 4 1 1 1 1 1 1 1 1 1 ~-1 10 RECEIVED DEC 0 1 1995 Alaska 0il & Gas Cons, CommissiOn' Anchorage Note' Because the well is classified as Not Completed the history is not being submitted at this time, The data is considered confidential until the normal release date. (Marathon Oil) (Date) (Received By) (Date) Please Return 1 Copy by Either FAX or Mail to Marathon RECEIVED 0£C - ] ]995 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst..pr~, DATE: Chairm~. September 2, 1995 THRU' Blair Wondzell, ,~~ FILE NO: P. I. Supervisor ~/~/9~'- FROM: Lou Grimaldi, F~o~_ SUBJECT: Petroleum InsCector A99JH3CD.DOC BOP test Pool #122 Marathon well # 31-7rd Kenai Gas Field PTD #95-55 Wednesday, August 30,1,995: I witnessed the Initial BOP-test on Pool rig #122 in the Kenai Gas field. _ The test was began shortly after midnight and went very well. The well was currently completed as a dual string with both tubing strings tied into the packer. This necessitated pulling both strings together. The wellhead hand reported that the thread connections in the top of the hanger were not in good shape and advised against side torque being applied on them. The lower pipe rams (single 4 1/2") and Annular preventer were not tested because of this situation. I requested that Lance Lamens (Marathon drilling foreman) formulate a plan to test these on future wells when in the same situation. Saturday, September 2, 1995: ! returned this morning to witness the testing of the BOPE stack after the tubing had been pulled. The stack had been reconfigured for drilling the sidetrack. The test went very well with all components functioning properly and holding the pressure applied to them. The choke manifold had been tested on the previous test and pressure was applied on the outside valves through the choke line SUMMARY: I witnessed two BOP tests on Pool rig #122. Test time 3 hours. No failures. Attachments: A99JH3CD.XLS cc: Marc Sinclair (Marathon drilling superintendent) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlng Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X POOL Rig No. 122 PTD # Marathon Rep.: 31- 7 RD Rig Rep.: Set @ Location: Sec. Weekly Other X 95-55 DATE: Rig Ph.# Pete Verga 9/2/95 Darrel Greene 6 T. 4N R. 11W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: Housekeeping: Reserve Pit N~A Hazard Section OK BOP STACK: Annular Preventer Upper Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve OK Well Sign OK OK (Gen) Drl. Rig OK Standing Orders OK Test Quan. Pressure P/F 1 P 30O/50OO 1 300/5000 P 1 30O/5OOO P 1 300/5000 1 300/5000 P 2 300/5000 P 1 3OO/5OOO P 300/5000 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P H2S Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure 1 300/5000 1 300/5OOO P 1 30O/5OO0 1 300/5000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 13 Test Pressure P/F 300/5000 P 30 300/5000 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 1900 3,000 I F 1,600 P minutes 25 sec. minutes 5 sec. X Remote: X Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Components tested are those that were missed due to dual configuration on previous test (A99JH3CD.XLS) Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R Orimaldi FI-021L (Rev. 7/19) A99JIBCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlng Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial 8/30/95 Other Workover: X DATE: POOL Rig No. 122 PTD # 95-55 Rig Ph.# Marathon Rep.: Lance Lamens 31- 7 RD Rig Rep.: Darrel Greene 7" Set @ Location: Sec. 6 T. 4N R. 11W Meridian Seward X Weekly TEST DATA MISC. INSPECTIONS: Location Gen.: Housekeeping: Reserve Pit Hazard Section OK BOP STACK: Annular Preventer Dual Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve OK Well Sign OK OK (Gen) Drl. Rig OK Standing Orders OK Test Quan. Pressure P/F 1 300/5000 1 * 1 300/5000 P 1 300/5000 1' 1 3OO/5000 P 1 300/5000 P 2 300/5000 P 1 300/5OOO P 300/5000 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P H2S Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 300/5000 1' 300/5000 1 300/5000 I 300/5000 . CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 13 Test Pressure P/F 300/5000 P 30 300/5OOO P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 1900 3,000 F 1,800 P minutes 24 sec. minutes 12 sec. X Remote: X Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: removed and stack is reconfigured for drilling. Good test procedure. Rig is in Good shape. 1') These components were not tested due to dual string configuration, they will be tested when tubing is Distribution: orig-Well File c- Oper./Rig c- Database c- Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24- HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R OrJmaldi FI-021L (Rev. 7/19) A99JH3CD.XLS DUlll~l~., - Production Mav,,,thon OilC-mpan¥ RO. Bo~ 190168 Anchorage, AK 99519-0168 Telepi~one 907/§61-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING DOCUMENTS TO: Company Dcpartmen[/Location Facsimile Number , --.. Nl]Llmher of pages (including this cover page) .., ,11 - · I i-- FROM: RECEIVED A subsidiary ol USX Comorat~n APR 17 1995 Alaska Oil & Gas Cons. Comm'tsst°' Anchorage APR 17 1-995 g, la$.~...Ojl .& Gas Cons. ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 27, 1995 Mark Sinclair Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Re: Kenai Beluga Unit 31-7RD Marathon Oil Company Permit No. 95-55 Sur. Loc. 4878'FNL, 1306'FWL, Sec. 6, T4N, RllW, SM Btmnhole Loc. l125'FNL, 2681'FWL, Sec. 7, T4N, RllW, @ 7380' TVD, SM Dear Mr. Sinclair: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at -1433. Y Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Alaska R,. ~,on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 12, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: Re: Kenai Gas Field Well 31-7RD Enclosed is an application for a permit to redrill Well 31-7 in the Kenai Gas Field. The sundry for abandonment prior to sidetracking the well was previously submitted and has been approved. If further information is required, please contact me at 564-6450. Sincerely, Mark F. Sinclair Drilling Superintendent MFS:kgh Enclosures H:\WP\Oper95\0412.5 RECEIVED APR 7 5 199~ ~J~ska OJl & Gag Con& Comr~/$s[on 4nChora ~ A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COiv~MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill _J RedrillX~l lb. Type of well. Exploratory ~!, Stratigraphic Test [] Development Oil © Re-Entry ~ Deepen'~1 Service [] Developement Gas ~ Single Zone [] Multiple Zone tX] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Marathon Oil Company 100 feet Kenai Gas Field/Belug 3. Address 6. Property Designation P.O. Box 196168, Anchorage, AK 99519-6168 A-028142 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.O25) 4878'FNL,1306'FWL,Sec.6,T4N,R11W,S.M. Kenai Beluga Unit At top of productive interval 8. Well nu ,mber Number 5194234 1080'FNL,2557'FWL,Sec.7,T4N,R11W @ 6630'TV3 31-7RD At total depth 9. Approximate spud date Amount $200,000 1125'FNL,2681'FWL,Sec.7,T4N,R11W @ 7380'TV} 7-1-95 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 2557 feet 500 feet 6000 7800'MD,7380'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5700 feet Maximum hole angle'16.°7 Maxim,m su,face 3068 ps~g At total depth (TVD) 3454 psig 18. Casing program; Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29~ N-gO BTC 7800' 0 0 7800' 7380' 1050 SKS 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7.550 feet Plugs (measured) Baffle Col 1 ar at 7400' true vertical 7094 feet Effective depth: measured 7305~feet Junk (measured) Retainer Junk at 7305' true vertical 6858 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 95' 20" Driven 95' 95' Conductor Surface 2526' 13-3/8" 1400 SKS 2526' 2459' Intermediate RECEIVEO Production 7538' 9-5/8" 2010 SKS 7538' Liner APR 1 ;~ 1995 Perforation depth: measured 5016' - 6618' true vertical 4665' - 6197' ~Ka Uil & 6as Cons. Commission 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~. Drilling prog~:~"r~"~ Drilling fluid program E~ Timevs depth plot ~ Refraction analysis I~ Seabed report ~ 20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~..~ Title /"~.__//) ,,~ff~ Date~/_?.-.-/~.r" Commission Use Only Permit Number APl number J A p p r~.~;I..,d a~..~ ~J See cover letter ?~--- ,.~,~ 50--/~.~ - ..;?._4:~ ~//:~'.-- o / '" for other requirements Conditions of approval Samples required [] Yes ~' No Mud Icg required g Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ,~ Yes ~ No Required working pressure for BOPE ~2M; [] 3M; j~5M; [] 10M; ,~. 15M Other: Original Signed By by order of .~/ /_ ..___ Approved by David W, Johnston Commissioner the commission Date 7/2 717 Form 10-401 Rev. 12-1-85 Submit in t¢ plicate D[ 'NG AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KBU 31-7RD PAD: 1 4-6 SLOT: NA REVISION NO.: 2 SURFACE LOCATION: TARGETS: Beluga L10-15 L16-18 BOTTOMHOLE LOCATION: KB ELEVATION: GL ELEVATION: FIELD: Kenai Gas Field AFE No.: 9201195 TYPE: Beluga Producer DATE: 4/6/95' 4878' FNL,1306' FWL,Sec.6,T4N,R11W, S.M. 1080' FNL, 2557' FWL Sec 7, T4N, R11W @ 6630' TVD 1100' FNL, 2613' FWL Sec 7, T4N, R11W @ 6970' TVD 1125' FNL, 2681' FWL Sec 7, T4N, R11W @ 7380' TVD 100 ft. mean S.L. (est.) 66 ft. mean S.L. (est.) I. IMPORTANT GEOLOGIC HORIZONS (below Sidetrack Point): FORMATION DEPTH(MD) Middle Beluga 5682 Lower Beluga 6423 DEPTH(TVD) 5300 6025 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) DEPTH(TVD) Middle Beluga 5682 5300 Lower Beluga 6423 6025 POTENTIAL CONTENT Gas Gas RECEIVED ~A~aska 0il & Gas Cons. Corilrrljssiorl Anchora, ~ page 1 JL EQUIPMENT ? BLOWOUT PREVENTERS . Dlowout preventer stack will consist of a 13 5/8" x 5000 psi annular preventer, an 13 5/8" x 5000 psi double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 13 5/8" x 5000 psi drilling spool (mud cross) equipped with a 3-1/16" x 5000 psi outlets, and an 13 5/8" x 5000 psi single gate ram type preventer outfitted with pipe rams. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Aisc included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING HEAD: CIW 20" 2M xSOW starting.head. (In place) CASING HANGER: 20"x 13 -3/8" boll weevil flow-thru hanger. (In place) CASING HEAD: CIW 20" 2M x 13-5/8" 5M. (In place) CIW 13 5/8" 5M x 13 5/8" 5M. (New) TUBING HEAD: CIW 13-5/8" 5M x 10" 5M DCB: In place and will be refurbished. CHRISTMAS TREE: 3-1/16" - 5000 psi dual christmas tree including two master valves, one flow tee, one manually adjustable choke, and one swab valve per tubing string. Existing ClW Type F Xmas tree will be replaced with a single tree. CASING DESCRIPTION IV. CASING PROGRAM: TYPE SIZE WT. SET GRADE THREAD FROM SET TO HOLE SIZE PRODUCTION: 7 29 N-80 BTC Surf 7800' MD 738O' TVD 8-1/2" CASING DESIGN SIZE WEIGHT GRADE 7" 29.0# N-80 SE'FFING FRAC GRD FORM PRSS DEPTH,TVD @ SHOE @ SHOE MASP DESIGN FACTORS TENS COLL BURST 7380 3263 2460 3.74 1.35 1.33 page 2 RECEIVED APR 1 ~ 199~ ul~ & Gas Cons. COmmiSSIOn Anchora ¢: PROGRAM .,JDUCTION: LEAD SLURRY: 7" @ 7800'MD Halliburton Light Premium w/.2% CFR-3, .25% HALAD-344, .3% HR-7 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 187O ft. 13.6 ppg. 1.53 cu. ft./sk 7.59 gal/sk 5:04 hrs:min 35 % 450 sx TAIL SLURRY: Halliburton Premium w/.2% CFR-3, .3% HALAD-344, .1% HR-7 TOP OF CEMENT: 5300 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5.0 gai/sk PUMPING TIME: 5:01 hrs:min EXCESS (%): 50 % ESTIMATED VOLUME 600 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1 Remove thread protectors and visually inspect connections. 2 Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3 M/U float collar. (Baker-lok all connections to top of float collar) 4 Fill pipe until circulating. 5 Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6 Circulate and reciprocate until no gains in circulating efficiency is made. 7 With as little shut down as possible, drop bottom plug and begin pumping spacer. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8 Pump 5 bbls ddll water. 9 Mix and pump 121 bbls. lead slurry(450 sx). 10 Mix and pump 122 bbls. of tail slurry(600 sx). Drop top plug. 11 Displace cement. Reciprocate as long as possible. 12 Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13 P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 14 WOC 12 hours. 15 Test BOPE. RECE[VED APR 1 199,5 A.~ska. 0il & Gas Cons. C0mmissic Anch0ra. q ECEIVED lO 1995 Gas Cons. C0mmissi0' Anch0ra ~ page 3 -~GRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO ppg sec/qt LOSS TYPE 5700' 7800' 8.6-10 40-80 4-6 cc PHPA/KCL Ventrol 401 or Liquid Casing will be used to prevent differential sticking. The solids control equipment will consist of two Derdck flowline cleaners, a 2-cone desander, a mudcleaner, and a Swaco 518 centrifuge. VII. LOGGING, TESTING, AND CORING PROGRAMS PRODUCTION: COMPLETION: LOGGING PROGRAM Phasor Induction/SP/Cal/from 7800'MD-5700'MD. LDT/CNL/Cal/SGR from 7800'MD-5700'MD. Dipole Sonic from 7800'MD-5700'MD. FMI or CBIL for 2000' over cored intervals. RFT pressure data and sidewall cores will be gathered from intervals to be selected after evaluating the other openhole logs. A TDT will be run from PBTD to +/- 6000' MD. A Cement Bond Log (CET/GR) and a directional gyro- survey will be run prior to perforating. CORING PROGRAM A 60' whole core will be taken in both the Middle and Lower Beluga. Core points are approximately 6062'md/5670'tvd to 6122' md and 7068'md/6660' tvd to 71 28' md. None planned. TESTING PROGRAM RECEIVED APR 1,3 199,5 Alaska 0il & Gas Cons, Commission Anch0ra, q page 4 ,fHOLE PRESSURES AND POT~,'~ITIAL HAZARDS =ten sulfide gas has not been encountered in any well in the Kenai Gas Field. The Beluga ,~e is expected to be normally pressured with the exception of the following intervals: TVD, ft. Est. pressure, psi Gradient, ppg. Middle Beluga M-3 5365 1058 Lower Beluga L-3 6090 1166 Lower Beluga L-4 6170 1186 Lower Beluga L-9 6435 1339 Lower Beluga L-10 6520 1386 Lower Beluga L-12 6755 1667 3.72 3.62 3.64 3.94 4.03 4.68 IX. OTHER INFORMATION DIRECTIONAL PLAN DESC MD TVD INCL AZIM RKB KICKOFF, (Tie-in) 5700 5317 16.73 143 END OF CURVE 6033 5641 10.00 110 TOTAL DEPTH 7800 7380 10.00 110 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) NORTH COORD -1374 -1422 -1527 DEPTH (MD) WEST VERT COORD SECTION 1031 1439 1087 1508 1375 1815 REEEIVED APR ] 5 199§ ~t~ska 0il & Gas Cons. Commission Anch0ra ~ page 5 DRILLING PROGRAM ABANDONMENT AND SECTION MILLING Move in and rig up rotary drilling rig. R/U slickline and open sliding sleeves in long string at 6458', 6126', 6013', and 5751' and sliding sleeve in short string at 4921'. Circulate mud to kill the well. Set two way check valves and nipple down Xmas tree. Nipple up BOPE and test. Clean out well to 5769'. Set retainer at 5760'. Squeeze with 100 bbls of cement. Spot cement from 5760' to 4000'. POOH to 3500' and squeeze perforations with 55 bbls. Drill out cement and test perfs to 1000 psi. Cut section from 5675' to 5725'. Spot K/O plug from 5755' to 5500'. Set RBP at 1000' and nipple down tubing spool and nipple i up casing head. Nipple up BOPE and test. Retdeve RBP. WOC for 24 hours. DRILLING RIH with directional assembly and dress off cement plug to 5675' (directional driller to witness). Kick off well and drill to core point #1(+/-6062'md). Cut 60' core. Drill to core point#2(+/-7068'md). Cut 60' core. Drill to TD at 7800' md. Log as per the logging program. Run and cement 7" casing, Complete as per the completion program. COMPLETION: Clean out casing to PBTD. Run gyro and CBL. Run TDT log from PBTD to 6000'. a later date, Completion procedure to follow at RECEIVED APR 1 5 1995 0il & Gas Cons. Commission Anchora ,~, page 6 MARATHON 0il Company Structure · KBU $1-7 Well · .31-7 Field' Kenai Gas Field Location · Kenai, Alaska [---- Point T;e on End of Drop End of Hold ICreated by : cheramie WELL PROFILE DATA IPIot Reference is KBU 31-7Rd~1 Version MD Inc Olr TVD North East Deg/lOOICoordinotes ore in feet reference slot ~31-7. 5700 16.73 143,40 5317 -1374 1031 O,o01True Vertical Depths ore reference RKB. 6033 10.00 110.00 5641 -1422 1087 3,001 Baker Hughes INTEQ --- 7799 10.00 110.00 7380 - 1527 1375 0.001 o 5200 _ _ 5400_ ..~ - ("") 5600_ - 5800_ .-- 6000_ _ 6200_ =5 6400_ I-~ - -- 6800_ _ 7000_ 7200_ 7400. _ 7600 Scale 1 - 20.00 E a st - - > 920 960 1000 1040 1080 1120 1160 1200 1240 1280 1320 1360 1400 1440 1320 ~ _ .. '~p t136° ~ - S~detrack Pt co~ C' 1440 ~ KOP - Si~tr~k Pt - 1 ~.~ 1520 V 12.46~I DOGLEG = 3.0 DEG/IOO'MD I ~ To AVERAGE ANGLE 10.0 DEGREES LIO-18 lTD I I I i I I i ! I I i 1000 1200 1400 1600 1800 2000 REEEIVED APR I 3 1995 .Oil & Gas Cons. Commission Anch0ra ~, INTLIq HYDRIL 1,3 5/8'-5000PSi GK ANNULAR BOP LATCHED HEAD 15 5/8"- I O,O00PSI HUB t30TTOM CONNECTION /-Pr'DRIL 1,3 5/8'- 10,O00P$1 MPL RAM 80P HUB CONNECTIONS 4. 7,/76"- ? O, O00PSI SIDE OUTI_ETS MPL RAM BOP HUB CONNECTIONS II ~ , IL ~ m ~---L'm~! INTERNAllONAL ' -- HCR 5 1/16.-10,000PS1 HCR MANUAJ. MANUAL CHECK VALVE CHOKE WING KILL WING McEVOY 4 1//16'- 70, O00PSI TYPE E GATE VALVE McEVO¥ 5 1/1 6'- 10,O00PSI TYPE E GATE VALVE ~ H~D~ ~ 51¢-~o, oooPs~ , MPL RAM 130P HUB CONNECTIONS I I ~ 7/76'-10,000PSI SIDE OU~ I 15 5/~- 10, O00PSI HUB X !5 5/8 5,000 ~GE AO~TOR BLOW-OUT PREVEN~R STACK PM RIG 429-L RECEIVED APR 1 3 1995 Oil & Gas Cons. Commission '_/~chora, ~ TO SHAKER BOX TO FLARE PIT TO GAS BUSTER -~- FLARE \ I \ / INLET A WcEVOY TYPE 'E'-3 1/8" - 5W GATE VALVE B. CAWERON TYPE FCC 3' 1/8' - 5M GATE VALVE C. WoEVOY TYPE 'E'-2 1/16- 5W GATE VALVE O. 4-W,4¥ FLOW BLOCK S 1/8' X $ I/8" X $ 1/'8' X $ 1/'8' 5M F. ,C-WAY FLOW BLOCK 2 1//1¢ .¥ 2 1/16' X $ 1/8' X $ 1/8' 5W F. 3-WAY FLOW BLOCK $ 1/8' X 2 1/16' X $ 1//¢ 5W G. TRI-FLO $ 1//16'-10M HYDRAULIC CHOKE H. NATiOIVAI. TYPE 'F' 2 ?/'16'-5M MANUAL CHOKE do s l/a' x s I/a' 5M SPOOL K. 3 1/6- X ~ 1/8' 5M SPOOL L. S l/~' X 2 ~/76'-5M SPOOL ~. ~ I/6- X 2 1/~6'-5~ SPOOL N. 5 ~/~6--10~ X 2 ~/~6'-5M OOUBLE STUDaED AOAPTOR P. 5 1/_16--10M X 2 1/'16'-5M DOUBLE STUDDED ADAPTOR o. ~ ~/6' x ~ 1/¢'-5~ SPOOL R. ~ 1/¢_-5~ rARaET FLANGE S. ~ 1/6- X ~ ~/8'-5~ SPOOL T. SENSATOR BLOCK u. 2--5~ THREAO~ FLUTE (2' NPT) RECEIVED APR 1 3 1995 CHOKE MANIFOLD SCHEMA TIC PM. RIO 429-L ¢~i~ska Oil & Gas Cons. Commission Anchora, ~ SUMP TO K. BEACH ROAD _%_O__c_J VALVE BLDG BLDC J I WATER BI DO WEST REBOILER BLDG REBOILER [3LDO HEATER BLDG WEST CONTACTOR BLDG METER BL WEST COMPRESSOR BLDG KDU-1 KU 14-6 KU21-7 KU 1¢X-6 KU 13-6 KBU 23-6 KBU 31-7 TO 41-7 KU ¢3-12 EAST COMPRESSOR BLDG EAST REBOILER BLDG EAST CONTACTOR BLDO PAD LIMITS .... > MARATHON Oil COMPANY KEANI GAS FIELD PAD 14-6 FIGURE 3 -..~ .... '.. ,/ _./' .. ; ,, /, , , ._ :_,..- :'~ ~'-_!- - ' .:' :-. ............. ';i::.',.... ', :,', -~'"'-'-~-. ~ .' · ' ..: -.-::. :~i.~ ..." .,..:.'.. ;!:::: '::'~;.: ! ' ;,',.,~ ' - :'--.:, ~. . ..d_ ' , :-::,.,:.:::.'::':.~-,~ /..~'~~ :~ .'Y,~..~--'- ,.~,,~'-., -,,,-.~h ..~,...,~ .... . , ..-.'".;,.:: .~-::.:: ---,.:..' ..-.. :'-- , _m- ,o7 r'-.:.~-.-'-'/g .: .-,-- ~,.. k' ...... , ..' .. ,---- / i-...'.-.-._'.: -'"' '":'- .... - .... ' · ~" " ' ; ' ' '"'~'"',t I ~ - .. o .. ' ..-. 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I-- "'"' ' ' ""~. : .... - ; ¢ : ' · ' ""7 '" · ,x~ · ~1 i '%", '<" I : '.: I -'~ ~ '--~ ; ' ",~'., I " '~ ,/--' ~ · ,'?'"~! , . , '-'~'e- · :.',.. ,~, ; ~ ..... .-.,./.~¢ ~ . .-. . .~,,. ~ . · .:---. , , ', , ,,,,,.,,,-.o. o,. oo,,...,,1 ' ~:. . :~""~- ~ ...... ~- ....... ~. ....... T--'T'~.~--~---,~'~'--. -. ~,.~..:"T----'~,-' J--j : .'. ":; ~ t, , ~ · ., ~ ~ ".-'A' .~'/'h i KENAI GAS FIELD .... ~''~ ~ i ;'s i · / : '~ .' '! / :\ { , I -, :.. - '-i.. \ " ' ' '~. -~ '~ ' . '-'.-:':_.~:'/':~' '-\ \ ; I I " ~' .:-.~ ,,.~. .: ~ .. · · .'.. '- k · "-'%4..,, ; . · -- '~' . , '~--.~;..' - ~/z~,,~ ..... . ~,,~ FIGURE I I · 36 ~, 31 ~ 32 · "'. - 3'3~.,4~/-" .'; (;'~:~ . / J : '~ : /' ' " : , '~ / - / ~' L~ - ' · :,~ ~,. -: .--~.. . ;r~-~,.,..,'..;y~.-~ ¢_~ ~ ~ - ...... 22 27 ; ~,~ ...... *- '".': -' ....... ~ ' \ ~.~'-'~-KU · 44-30 '.;: / / u -u ..... , x~ ...... '" · · -~: T~O 5700 ' ~ KU I~-e i~-~ . ~ ~ ..... .~b'; -- -'% ~?.,~,~'~, ': ~ 16 ~ '. " ,..? --~ , ~ .;~.::~ ..... :. :~==- :- :.:--~:~:~ .~ f ARCO '\ 40MMCF ~EHY. ~, :' ' · U-Id KDU 4 RD 13-7 THD I0,810 KU 45-1~ TMD 65Z0 I ,'.;-'.ASTER METE.~ S','", E" ,. ......... c,, COOK INLET ' 15 1 i i t I KENAI GAS FIELD . FIGURE.. '~ MARATHON OIL COMPANY STATE OF ALASKA .~.,..ASKA OIL AND GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abando~ __ Suspend ~ Operation shutql, own Re-enter suspended well ~ Alter casing __ Repair well w Plugging A "--~me extensIon w SIimulale __ Change approved program __ Pull tubing __ Variance __ Perforate I Other 2. Name of Operator 1 /15. Type of Well: Development ~b MARATHON OI L COMPANY Exploratory__ 3. Address Stratigraphic ~ -P.O. Box 196168 Anchorage AK 99519-61 Service__ of SW Corner, Sec. 6, T4N, R11W, S.M. of NW Corner, Sec. 7, T4N, RllW, S.M. 4. Location of well at surface 406' N & 1306~ E At top of productive interval 800' S & 2216' E At effective depth At total depth 1389' S & 2626' E of NM Corner, Sec. 7. T4N. R11W. S.M. 12. Present well condition summary Total depth: measured - - true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 95' 2526' 7538' measured true vertical Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic 6. Datum elevation (DF or KB) KB 95 Z Unit or Property name Kenai Beluga Unit 8. Well number KBU #31-7 9. Permit number 81-15,,3 10. APl number 5o-133-20347 11. Field/Pool Ken~i Gas Field feet 7550 feet Plugs(measured) Baffle Collar at 7400' 7094 feet 7305 feet Junk(measured) Retainer Junk at 6858 feet ~-~ Size Cemented Measured dept True vertic~ldepth 13-3/8" See Schematic FEB 2 4. 1995 /~ 0il & Gas Cor~s. commission Artchors~,, 13. Attachments Description summary of proposal __ Detailed operations program .~ BOP sketch 14. Estimated date for commencing operation April 1, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil__ Gas X Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~., ~ Title Drilling Superintendent FOR COMMISSION USE ONLY I Approval N~,~_ 43,.,~, Conditions of approval: Not~,Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~O"[. Approved Copy Approved by order of the Commission Original Signed 8y David W. Johnston Commissioner Form 10-403 Rev 06/15/88 ~-£ELD & PCOL CHECKLIST UNIT# PROGRAM: exp [] dev [] redrll~ serv [] ~//~O 0~/0FF s~o~ ~ ) ADMINISTRATION 3. 4. 5. 6. · 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................ Surface casing protects all known USDWs ......... CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . CMT will cover all kno~ productive horizons ...... Casing designs adequate for C, T, B & permafrost .... Adequate tankage or rescue pit ............ If a re-drill, has a 10-403 for abndrnnnt been approved.~ N Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid progr~ schematic & equip list adequate BOPEs adequate ..................... BOPE press rating adequate; test to ~-~z~ psig.~ N Choke manifold complies w/~I ~-53 (Ma--~--~...'. Work will occur without operation shutdown ....... Is presence of ~2s gas probable ............. GEOLOGY APPR / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones. .... Y /N 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N ' 34. Contact name/phone for weekly progress reports . . . [exploratory onl~] ~/ . GEOLOGY: ENGINEERING: COMMISSION: Cc~ments/Instructions: '"~RMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER · ....... SCHLUMBERGER ....... * COMPANY NAME : MARATHON OIL COMPANY WELL NAME : KBU 31-7RD FIELD NAME : KENAI GAS FIELD BOROUGH : KENAI STATE : ALASKA AP1 NUMBER : 50-133-20347 REFERENCE NO : 95352 RECEIVED · LIS Tape Verification Listing Schlumberger Alaska Computing Center ?-NOV-1995 05:19 *=** REEL HEADER SERVICE NAME : FBSTA DATE : 95/~9/23 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER SERVICE NAME : FFBSTA DATE : 95/09/23 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PAGE: **** FILE HEADER **** FILE NAME : FBSTA .096 SERVICE : DEPTH- VERSION : 7C0-427 DATE : 95/09/23 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 30259 4 66 5 66 6 73 7 65 IN 8 73 69 9 65 .liN 11 66 12 68 -999. 13 66 1 14 65 .lIN 15 66 73 16 66 1 0 66 LIS Tape Verii~ica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er SET TYPE - CHAN ** 7-NOV-~995 08:~9 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS FBSTA IN 00 282 01 0 75 1 1 4 68 0000000000 CS FBSTA F/HR 00 636 21 0 75 1 1 4 68 0000000000 CVEL FBSTA F/MN 00 636 00 0 75 ! 1 4 68 0000000000 TENS FBSTA LBF 00 635 21 0 75 1 1 4 68 0000000000 ETIM FBSTA S 09 636 21 9 75 1 1 4 68 9999999999 MARK FBSTA f 99 159 91 9 75 ! 1 4 68 9999999999 LC91 FBSTA 99 999 99 9 75 1 1 4 68 9999919999 AREA FBSTA FT2 99 289 94 9 75 ! 1 4 68 9999999999 AFCD FBSTA FT2 99 282 91 9 75 I 1 4 68 9999999999 ABS FBSTA FT2 99 282 91 9 75 I 1 4 68 9999999999 FCD FBSTA IN 99 282 91 9 75 I [ 4 SS 9999999999 ICV FBSTA F$ 99 282 91 9 75 1 [ 4 68 9999999999 STIA FBSTA F 99 999 99 9 75 1 [ 4 68 9999999999 STIT FBSTA F 99 999 99 9 75 1 [ 4 68 9999999999 SPCF FBSTA 99 61[ 9[ 9 75 1 1 4 68 9999999999 DPTR FBSTA DEG 99 6[[ 91 9 75 [ [ 4 68 9999999999 DPAZ FBSTA DEG 99 611 91 9 75 1 1 4 68 9999999999 DATA ** DEPTH = 7429.999 FEET ** BS.FBST 8.599 CS.FBST 883.219 CVEL.FBST -14.729 TENS.FBST ETIM.FBST 9.999 MARK.FBST 92.999 LCgl.FBST [3.999 AREA.FBST AFCD.FBST 9.267 ABS.FBST 9.394 FCD.FBST 7.999 IHV.FBST ICV.FBST -9.999 STIA.FBST 9.999 STIT.FBST 9.999 SPCF.FBST DPTR.FBST -999.259 DPAZ.FBST -999.259 END OF DATA ** -1.999 9.987 9.943 9.999 · *** FILE TRAILER FILE NAME : FBSTA .696 SERVICE : DEPTH- VERSION : 7C9-427 DATE : 95/99/23 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : LIS Tape Verification Listing' ~ Schlumberger Alaska Computing Center 7-NOV-1995 05:19 PAGE: **** TAPE TRAILER SERVICE NAME : FFBSTA DATE : 95/09/23 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL TRAILER SERVICE NAME : FBSTA DATE : 95/09/23 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION ~ : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY ALASKA COMPUTING CENTER · ........ SCHLUMBERGER COMPANY NAME : MARATHON OIL COMPANY WELL NAME : KBU 31-7RD FIELD NAME : KENAI GAS FIELD BOROUGH : KENAI STATE : ALASKA AP1 NUMBER : 50-133-20347 REFERENCE NO : 95352 A,~aska.Oil & [ ~ssio~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-NOV-lg95 13:56 **** REEL HEADER SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER **** SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : ! PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PAGE: **** FILE HEADER FILE NAME : LDTD .088 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/~9/23 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 460 4 66 5 66 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 17 12 68 -999. 15 66 14 65 .lin 15 66 73 16 66 1 0 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center SET TYPE - CHAN *, 8-NOV-lg95 13:56 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CS LDTD F/HR 45 636 21 0 67 1 1 4 68 0000000000 TENS LDTD LBF 45 635 21 0 67 1 1 4 68 0000000000 CGR LDTD GAPI 45 310 01 0 67 1 1 4 68 0000000000 POTA LDTD 45 719 5~ 0 67 1 1 4 68 0000000000 SGR LDTD GAPI 45 310 01 0 67 1 1 4 68 0000000000 THOR LDTD PPM 45 790 50 0 67 1 1 4 68 egeeeeeeee URAN LDTD PPM 45 792 59 9 67 1 1 4 68 9999990999 WING LDTD CPS 45 319 92 9 67 1 1 4 68 9999929999 W2NG LDTD CPS 45 319 92 9 67 1 1 4 68 9999929999 W3NG LDTD CPS 45 319 92 9 67 1 1 4 68 9999929999 W4NG LDTD CPS 45 319 92 9 67 1 1 4 68 9999929999 WSNG LDTD CPS 45 319 92 9 67 1 1 4 68 9999929999 HTEN LDTD LBF 45 999 99 9 67 1 1 4 68 9999999999 MRES LDTD OHMM 45 999 99 9 67 I 1 4 68 9999999999 DRHO LDTD G/C3 45 356 91 9 67 1 ~ 4 68 9999999999 LSRH LDTD G/C3 45 359 92 9 67 1 1 4 68 9999999999 LURH LDTD G/C3 45 359 92 9 67 ~ 1 4 6e 9999999999 PEF LDTD 45 358 91 9 67 1 1 4 68 9999999999 ~LS LDTD G/C3 45 354 91 9 67 1 I 4 68 9999999999 USS LDTD G/C3 45 354 91 9 67 1 1 4 68 9999999999 RHOB LDTD G/C3 45 359 92 9 67 1 ! 4 68 9999999999 S1RH LDTD G/C3 45 359 92 9 67 1 1 4 68 9999999999 LSHV LDTD V 45 354 99 9 67 I 1 4 68 9999929999 SSHV LDTD V 45 354 99 9 67 I I 4 68 9999999999 RCAL LDTD IN 45 289 91 9 67 1 1 4 68 9999999999 LL LDTD CPS 45 354 91 9 67 1 1 4 68 9999999999 LU LDTD CPS 45 354 91 9 67 1 1 4 68 9999999999 LS LDTD CPS 45 354 91 9 67 1 1 4 68 9999999999 LITH LDTD CPS 45 354 91 9 67 1 1 4 68 9999999999 SS1 LDTD CPS 45 354 92 9 67 1 1 4 68 9999999999 SS2 LDTD CPS 45 354 92 9 67 1 1 4 68 9999999999 CALI LDTD IN 45 289 91 9 67 1 1 4 68 9999999999 · DRTA LDTD 45 999 99 9 67 1 I 4 68 9999999999 RTNR LDTD 45 999 99 9 67 1 1 4 68 9949999999 RCNT LDTD CPS 45 999 99 9 67 1 1 4 68 9999999999 RCFT LDTD CPS 45 999 99 9 67 1 1 4 68 9999999999 CNTC LDTD CPS 45 999 99 9 67 1 1 4 68 9990999999 TNRA LDTD 45 ~99 99 0 67 1 1 4 68 0442000990 CFTC LDTD CPS 45 999 99 9 67 1 1 4 68 ~099999999 MTEM LDTD DEGF 45 999 99 9 67 1 1 4 68 9999999999 DTEM LDTD DFHF 45 999 99 9 67 1 1 4 68 9999999999 DPHI LDTD PU 45 899 91 9 67 1 1 4 68 9999999999 TNPH LDTD PU 45 999 99 9 67 1 1 4 68 9242999499 NPHI LDTD PU 45 999 99 9 67 1 1 4 68 9242999999 NPL LDTD PU 45 999 99 9 67 1 1 4 68 9999999999 NPOR LDTD PU 45 999 99 9 67 1 1 4 68 9999909999 HDRH LDTD G/C3 45 356 91 0 67 6 1 24 68 9999999999 HDAL LDTD 45 356 91 9 67 6 1 24 68 9999999999 RHLL LDTD CPS 45 354 92 9 67 6 1 24 68 9999929999 RHLU LDTD CPS 45 354 92 9 67 6 I 24 68 9999929999 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-NOV-199~ 13:S6 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RHLS LDTD CPS 45 354 02 0 67 6 1 24 68 000002~000 RHLI LDTD CPS 45 354 02 0 67 6 1 24 68 0000020000 RHS1 LDTD CPS 45 354 01 0 67 6 I 24 68 0000~20000 RHS2 LDTD CPS 45 354 01 0 67 6 I 24 68 0000020000 HDPH LDTD PU 45 890 01 0 67 6 1 24 68 0000000000 HDRT LDTD 45 000 00 0 67 3 1 !2 68 0000000000 HTAL LDTD 45 000 00 0 67 3 1 12 68 000~000000 RHNT LDTD CPS 45 000 00 0 67 3 1 12 68 0000000000 RHFT LDTD CPS 45 000 00 0 67 3 1 12 68 eeoooe0000 HTNP LDTD PU 45 000 00 0 67 3 1 12 68 0242000400 ** DATA DEPTH = 7588.500 FEET ** CS.LDTD 867.888 TENS.LDTD 207~.e00 CGR.LDTD i25.697 POTA.LDTD SGR.LDTD 114.825 THOR.LDTD 6.498 URAN.LDTD -1.450 W1NG.LDTD W2NG.LDTD 255.639 W3NG.LDTD 75.188 W4NG.LDTD 15.038 WSNG.LDTD HTEN.LDTD -73.215 MRES.LDTD 0.064 DRHO.LDTD -0.028 LSRH.LDTD LURH.LDTD 2.568 PEF.LDTD 5.4el QLS.LDTD -e.e3e QSS.LDTD RHOB.LDTD 2.497 S1RH.LDTD 2.669 LSHV.LDTD 1335.137 SSHV.LDTD RCAL.LDTD 2.637 LL.LDTD 135.353 LU.LDTD 264.863 LS.LDTD LITH.LDTD 44.793 SSI.LDTD 210.114 SS2.LDTD 299.973 CALI.LDTD DRTA.LDTD 0.000 RTNR.LDTD 3.500 RCNT.LDTD 1708.964 RCFT.LDTD CNTC.LDTD 1712.260 TNRA.LDTD 3.295 CFTC.LDTD 528.015 MTEM.LDTD DTEM.LDTD 0.000 DPHI.LDTD 9.263 TNPH.LDTD 38.651 NPHI.LDTD NPL.LDTD 39.758 NPOR.LDTD 38.651 HDRH.LDTD -999.250 HDAL.LDTD RHLL.LDTD -999.250 RHLU.LDTD -999.250 RHLS.LDTD -999.250 RHLI.LDTD RHS1.LDTD -999.250 RHS2.LDTD -999.250 HDPH.LDTD -999.250 HDRT.LDTD HTAL.LDTD -999.250 RHNT.LDTD -999.250 RHFT.LDTD -999.250 HTNP.LDTD ** DEPTH = 5539.5~0 FEET ** CS.LDTD 884.278 TENS.LDTD 2875.9~0 CGR.LDTD 55.144 POTA.LDTD SGR.LDTD 59.883 THOR.LDTD 3.274 URAN.LDTD 0.632 W1NG.LDTD W2NG.LDTD 94.124 W3NG.LDTD 34.861 W4NG.LDTD 4.482 WSNG.LDTD HTEN.LDTD 654.275 MRES.LDTD 0.066 DRHO.LDTD -0.811 LSRH.LDTD LURH.LDTD 2.786 PEF.LDTD 31.601 QLS.LDTD 9.000 QSS.LDTD RHOB.LDTD 1.927 S1RH.LDTD 4.4~7 LSHV.LDTD 1341.131 SSHV.LDTD RCAL.LDTD 8.397 LL.LDTD 99.915 LU.LDTD 196.373 LS.LDTD LITH.LDTD 20.477 SS1.LDTD 74.i87 SS2.LDTD 116.571 CALI.LDTD DRTA.LDTD 0,003 RTNR.LDTD 3.9T9 RCNT,LDTD 1042.51T RCFT,LDTD CNTC.LDTD 1068,487 TNRA.LDTD 3,740 CFTC.LDTD 284.518 MTEM.LDTD DTEM.LDTD 0.900 DPHI.LDTD 43.834 TNPH.LDTD 46.879 NPHI.LDTD NPL.LDTD 40,997 NPOR.LDTD 48.961 HDRH,LDTD -999.259 HDAL.LDTD RHLL.LDTD -999.250 RHLU.LDTD -999.250 RHLS.LDTD -999.259 RHLI.LDTD RHS1.LDTD -999.250 RHS2.LDTD -999.250 HDPH.LDTD -999.25~ HDRT.LDTD HTAL.LDTD 9.607 RHNT.LDTD 1986.287 RHFT.LDTD 311.376 HTNP.LDTD 0.063 255.639 0.000 2.557 -9.025 1449.497 267 784 2 752 483 436 116 156 46 072 -999 250 -999 259 -999.250 -999.250 0.927 162.849 0.996 2.737 -0.086 1452.087 197.201 8.536 255.478 96.418 47.554 -999.250 -999.250 0.029 46.840 LIS Tape Verifica¢ion Lis¢ing Schlumberger Alaska Compu¢ing CenCer $-NOV-1995 13:56 PAGE: END OF DATA ***~ FILE TRAILER FILE NAME : LDTD .088 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 9~/09/23 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ***~ TAPE TRAILER SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY ***~ REEL TRAILER SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL HEADER SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY LIS Tape Verification Listing Schlumberger Alaska Computing Center *=** FILE HEADER ***= FILE NAME : SPEA .038 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/20 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : 8-NOV-1995 13:56 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 180 4 66 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 45 12 68 -999. 13 66 14 65 .lin 15 66 73 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SP SPEA MV 99 010 01 ~ 26 I I 4 68 000000~000 PR SPEA 99 0¢0 00 0 26 1 1 4 68 00000¢¢¢00 CHR2 SPEA 99 000 00 ~ 26 1 I 4 68 0~0000~00 DT2R SPEA US/F 99 520 80 , 0 26 1 1 4 68 00000~0~00 TTR2 SPEA US 99 000 0~ 0 26 1 1 4 68 00000000~0 DTRP SPEA US/F 99 520 80 0 26 1 1 4 68 00000000~0 TTRP SPEA US 99 000 00 0 26 1 1 4 68 00000000~0 CHRP SPEA 99 000 00 0 26 1 1 4 68 00000~00~0 DTRS SPEA US/F 99 520 80 0 26 1 1 4 68 00~0000~00 TTRS SPEA US 99 000 00 0 26 ~ 1 4 68 0000000e00 CHRS SPEA 99 000 00 0 26 1 1 4 68 00000~00~0 DT2 SPEA US/F 99 520 80 0 26 1 1 4 68 00000~0000 DT4P SPEA US/F 99 520 80 0 26 1 1 4 68 00000~0000 DT4S SPEA US/F 99 520 80 0 26 1 1 4 68 0e00000~00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-NOV-1995 13:56 PAGE: NAME SERV UNIT SERVICE API aPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) HTEN SPEA LBF 99 000 00 0 26 1 I 4 68 0000000000 MRES SPEA OHMM 99 000 ~0 0 26 ~ 1 4 68 0000000000 MTEM SPEA DEGF 99 000 00 0 26 I I 4 68 0000000000 SPHI SPEA PU 99 890 01 0 26 1 1 4 68 00000000~0 GR SPEA GAPI 99 000 00 0 26 I 1 4 68 0000000000 A020 SPEA OHMM 99 0~0 00 0 26 2 ~ 8 68 0000900000 A030 SPEA OHMM 99 900 09 9 26 2 I 8 68 009~909999 A060 SPEA OHMM 99 900 90 9 26 2 1 8 68 0099009900 A090 SPEA OHMM 99 000 00 9 26 2 I 8 68 0009909909 AT10 SPEA OHMM 99 900 00 0 26 2 1 8 68 0099900000 AT20 SPEA OHMM 99 000 90 0 26 2 ~ 8 68 9909909000 AT30 SPEA OHMM 99 900 90 9 26 2 I 8 68 009099090~ AT69 SPEA OHMM 99 ~00 00 0 26 2 I 8 68 9090090099 AT99 SPEA OHMM 99 9~0 ~ 0 26 2 I 8 68 0090900999 AORT SPEA OHMM 99 000 09 9 26 2 I 8 68 90990099~9 AORX SPEA OHMM 99 900 09 0 26 2 1 8 68 0990009099 ATRT SPEA OHMM 99 000 00 9 26 2 1 8 68 0990999999 ATRX SPEA OHMM 99 000 90 0 26 2 I 8 68 9090000999 DATA DEPTH = 7524.000 FEET ** SP.SPEA 0.000 PR.SPEA -999.250 CHR2.SPEA 0.962 DT2R.SPEA TTR2,SPEA 2600.000 DTRP.SPEA 96.563 TTRP.SPEA 1990.900 CHRP,SPEA DTRS.SPEA -999.259 TTRS.SPEA -999.259 CHRS.SPEA 0.000 DT2.SPEA DT4P.SPEA 96.563 DT4S,SPEA -999,259 HTEN.SPEA -29.982 MRES,SPEA MTEM.SPEA 109.913 SPHI,SPEA 26.254 GR.SPEA 67,510 AO20,SPEA AO30.SPEA -999.25~ AO60,SPEA -999.259 AO90,SPEA -999,250 AT19.SPEA AT29.SPEA -999,25~ AT39,SPEA -999.250 AT69,SPEA -999.250 AT90.SPEA AORT,SPEA -999.250 AORX.SPEA -999,259 ATRT.SPEA -999.250 ATRX,SPEA ** DEPTH = 5562.500 FEET SP.SPEA 60.313 PR.SPEA 0.303 CHR2.SPEA TTR2.SPEA 2899.000 DTRP.SPEA 57.996 TTRP.SPEA DTRS.SPEA 1~1.126 TTRS.SPEA 130~.000 CHRS.SPEA DT4P,SPEA 56.085 DT4S,SPEA 195.469 HTEN,SPEA MTEM.SPEA 100.722 SPHI.SPEA 9.095 GR.SPEA AO39.SPEA 1950.009 AO60.SPEA 1959.000 AO99.SPEA AT29.SPEA 5.197 AT30.SPEA 17.649 AT69.SPEA AORT.SPEA 262.[03 AORX.SPEA ~3~5.764 ATRT.SPEA 0.983 1100 000 0 869 1825 116 51 794 9 205 1950 900 3 232 DT2R.SPEA CHRP.SPEA DT2.SPEA MRES.SPEA AO29.SPEA AT19,SPEA AT90.SPEA ATRX.SPEA 179.295 9.788 138.355 9.061 -999.250 -999.250 -999.250 -999.250 198.022 ~.497 189.379 9.069 1950.0~0 2.990 3.206 3,284 END OF DATA LIS Tape Verit:ication List, ing Schlumberger Alaska Computing Cenf~er S-NOV-1995 13:56 PAGE: *-*- FILE TRAILER ,~, FILE NAME : SPEA .038 SERVICE : PLAYBA VERSION : TC~-427 DATE : 95/09/2~ MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** TAPE TRAILER ,*,* SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL TRAILER *~*~ SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL HEADER **** SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : ~ PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY · ,~, TAPE HEADER SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY LIS Tape VerilY|cation L|sting Schlumberger Alaska Comput|ng Center **** FILE HEADER **** FILE NAME : CMRT .083 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/22 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : 8-NOV-1995 13:56 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 24 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 12 68 -999. 13 66 1 14 65 ,liN 15 66 73 16 66 1 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS CMRT LBF 29 635 21 0 65 1 1 4 68 0000e00000 KCMR CMRT MD 29 0~0 00 0 65 1 1 4 68 000~000000 T2LM CMRT MS 29 000 00 0 65 1 1 4 68 00000000~0 CMRP CMRT PU 29 00~ 00 0 65 1 1 4 68 00~0000~00 CMFF CMRT PU 29 000 00 0 65 1 1 4 68 00~0000~00 GR CMRT GAPI 29 000 00 0 65 1 1 4 68 00e0000000 ** DATA ** ** DEPTH = 7425.500 FEET LIS Tape Verification Listing Schlumberger Alaska Computing Center TENS.CMRT 2390.000 KCMR.CMRT CMFF.CMRT 0.560 GR.CMRT DEPTH = 5584.000 FEET TENS.CMRT 3115.000 KCMR.CMRT CMFF.CMRT 2.379 GR.CMRT END OF DATA ** 8-NOV-1995 13:56 9.999 T2LM.CMRT 88.282 9.135 T2LM.CMRT 89.556 16.238 CMRP.CMRT 14.329 CMRP.CMRT PAGE: 1.981 11.333 **** FILE TRAILER FILE NAME : CMRT .983 SERVICE : PLAYBA VERSION : 7C9-427 DATE : 9~/99/22 MAX REC SIZE : 8~92 FILE TYPE : DL LAST FILE : **** TAPE TRAILER SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL TRAILER SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY * ALASKA COMPUTING CENTER * · ....... SCHLUMBERGER COMPANY NAME : MARATHON OIL COMPANY WELL NAME : KBU 31-TRD FIELD NAME : KENAI GAS FIELD BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-133-20347 REFERENCE NO : 95352 LIS Tape Verification List|ng Schlumberger Alaska Computing Center 7-NOV-1995 15:33 **** REEL HEADER *~* SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER *~*~ SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PAGE: **** FILE HEADER FILE NAME : CRT SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 3748 4 66 5 66 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 2 12 68 -999. 13 66 1 14 65 .liN 15 66 73 16 66 ~ 66 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er SET TYPE - CHAN ,, 7-NOV-1995 15:33 PAGE: NAME SERV UNIT SERVICE API API API aPI FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS CET IN 80 282 01 0 102 1 1 4 68 0000009000 CS CET F/HR 89 636 21 9 192 1 1 4 68 9999999999 CVEL CET F/MN 89 636 99 9 192 ~ 1 4 68 9999999999 TENS CET LBF 89 635 2~ 9 102 ~ 1 4 68 0999099999 ETIM CET S 89 636 2~ 9 192 1 1 4 68 9999999999 MARK CET F 89 159 91 9 192 1 ! 4 68 9999999999 BIND CET 89 999 99 9 192 1 1 4 68 9999999999 CWWM CET 89 999 99 9 192 1 1 4 68 9999999999 W2R~ CET 89 999 99 9 192 1 1 4 68 9999999999 W2R2 CET 89 999 99 9 192 1 1 4 68 9999999999 ~2R3 CET 89 999 99 9 192 ~ 1 4 68 9999999999 W2R4 CET 89 999 99 9 192 1 ~ 4 68 9999999999 W2R5 CET 89 999 99 9 ~92 1 1 4 68 9999999999 W2R6 CET 89 999 99 9 192 ~ ~ 4 68 9999999999 W2R7 CET 89 999 99 9 192 1 ~ 4 68 9999999999 W2R8 CET 89 999 99 9 192 1 1 4 68 9999999999 W3R~ CET 89 999 99 9 192 1 1 4 68 9999999999 W3R2 CET 89 999 99 9 192 1 1 4 68 9999999999 W3R3 CET 89 999 99 9 192 1 1 4 68 9999999999 W3R4 CET 89 999 99 9 192 1 1 4 68 9999999999 ~3RS CET 89 990 90 9 192 ~ 1 4 68 9999999999 WSR6 CET 89 999 99 9 192 1 1 4 68 9999999999 W3R? CET 89 990 99 9 ~92 ~ 1 4 68 9999999999 W3R8 CET 89 999 99 9 192 1 1 4 68 0990999999 CW2L CET 89 999 99 9 192 1 ! 4 68 9999999999 CW2H CET 89 989 99 9 192 1 1 4 68 0999999999 CW3L CET 89 090 99 9 192 ! 1 4 68 9999999909 CW3H CET 89 999 90 9 192 1 1 4 68 9999999999 CW2X CET 89 999 90 9 192 1 1 4 68 9999999999 CW3X CET 89 900 99 9 192 1 ~ 4 68 0999999999 MNCS CET PSI 89 999 09 8 192 1 1 4 68 9999999999 MXCS CET PSI 89 980 99 9 192 1 1 4 68 9999999999 W2RA CET 80 909 89 9 ~92 1 1 4 68 9999999999 WSRA CET 80 989 99 9 192 1 1 4 68 9099999999 FRGI CET 80 999 80 9 192 1 1 4 68 9999999990 GOCI CET 89 999 90 9 192 1 ~ 4 68 9~99999999 QQCI CET 89 990 99 9 192 1 ~ 4 68 0999999999 AW21CET 80 000 80 0 102 ~ 1 4 68 9909990999 AW22 CET 80 909 99 9 192 1 ~ 4 68 9909999999 AW23 CET 89 909 90 9 192 1 ~ 4 68 0999999999 AW24 CET 80 999 00 9 ~92 1 1 4 68 0999999999 AW25 CET 89 999 99 9 192 1 1 4 68 9999999999 AW26 CET 89 990 99 9 192 ! ~ 4 68 9999999999 AW2T CET 89 999 99 0 192 1 1 4 68 9999999999 AW28 CET 80 999 99 9 192 1 1 4 68 9999999999 AW29 CET 89 909 09 9 192 1 1 4 68 0999999999 AW3~ CET 89 990 09 9 ~92 1 1 4 68 9999999999 AW$2 CET 89 990 99 9 192 1 1 4 68 9999999999 AW$$ CET 89 099 99 9 ~92 1 1 4 68 0999999999 AW$4 CET 80 999 99 9 192 1 1 4 68 9099999999 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen%er ?-NOV-1995 15:S3 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AW35 CET 80 000 ~0 AW36 CET 80 000 00 AW37 CET 80 000 ~0 AW3$ CET 80 00~ ~0 AW39 CET 80 00~ ~0 AAG1CET 80 00~ 00 AAG2 CET 80 000 00 AAG3 CET 80 000 00 AAG4 CET 80 000 ~0 AAG5 CET 80 000 ~ AAG6 CET 80 000 ~0 AAG7 CET 80 000 ~0 AAG8 CET 80 0~ 00 AAG9 CET 80 0~0 ~0 AWl1CET 8~ 000 ~ AWl2 CET 80 0~0 ~0 AWl3 CET 80 0~ 0~ AWl4 CET 80 000 ~ AW1B CET 80 000 ~0 AWl6 CET 80 0~0 00 AW17 CET 80 000 ~0 AWl8 CET 80 0~ 00 AWl9 CET 80 00~ 00 BLPR CET 80 000 00 CSMN CET PSI 80 000 ~0 CSMX CET PSI 80 00~ ~0 RB CET DEG 8~ 651 11 DEVI CET DEG 80 620 ~1 LATT CET DB/F 80 000 ~ UATT CET DB/F 80 000 ~0 BATT CET DB/F 80 000 ~0 R32R CET DB/F 8~ 00~ ~0 DT CET US/F 80 0~0 00 DTMD CET US/F 80 000 00 FLSA CET 80 000 ~0 FLTT CET 80 0~0 00 ULTR CET DB/F 80 000 ~0 SATN CET DB/F 80 00~ 00 SBI CET 80 0~0 ~0 SCBL CET MV 80 000 ~0 NATN CET DB/F 80 0~ 00 NBI CET 80 000 ~0 NCBL CET MV 80 000 00 DATN CET DB/F 80 000 00 DBI CET 80 0~0 00 DCBL CET MV 80 000 00 NFPI CET MV 80 0~0 ~0 SFPI CET MV 80 000 ~0 BATM CET DB/F 80 000 00 UATM CET DB/F 80 ~00 00 LATM CET DB/F 80 000 00 102 1 1 4 68 000~000000 102 1 1 4 68 0000000000 102 1 1 4 68 ~00~00000 102 1 1 4 68 0~000000~0 102 1 1 4 68 000~000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 00~0000000 102 1 1 4 68 00000000~0 102 1 1 4 68 00~00~0000 102 1 1 4 68 ~000000000 102 1 1 4 68 ~000000000 102 1 1 4 68 ~0000000~0 102 1 1 4 68 000~000000 102 1 1 4 68 ~000000000 102 1 1 4 68 00~0~00000 102 1 1 4 68 00~00~0000 102 1 1 4 68 00~0~00~00 I02 1 1 4 68 0000000000 102 1 1 4 68 00~000000~ 102 1 1 4 68 00~0000000 102 1 1 4 68 ~0000~0000 102 1 1 4 68 0000000000 102 1 1 4 68 00~0000000 102 1 1 4 68 ~0000~0000 102 1 1 4 68 0000000~0 102 1 1 4 68 0000000000 102 1 1 4 68 ~000000000 102 1 1 4 68 00~0000~00 102 1 1 4 68 0~000~0000 102 1 1 4 68 ~000000000 102 1 1 4 68 00000~000~ 1~2 1 1 4 68 0000~00000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 ~00000000 1~2 1 1 4 68 0000~0000 102 1 1 4 68 0000000000 102 1 1 4 68 ~000000000 102 1 1 4 68 0000000000 102 1 1 4 68 00~0000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 000000000~ 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 i5:33 PAGE: NAME SERV UNIT SERVICE AP1 AP1 aPI AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BILI CET 80 000 00 GOBO CET MV 80 000 ~0 UTVO CET V 80 000 00 LTV0 CET V 80 ~00 00 MNLV CET MV 80 000 ~0 DNLV CET MV 80 000 00 RUAM CET DB/F 80 000 00 RLAM CET DB/F 80 0~0 00 RUAT CET DB/F 80 000 ~0 RLAT CET DB/F 80 000 00 DTUM CET US/F 80 ~0 00 DTLM CET US/F 8~ 000 00 DTUT CET US/F 80 0~0 0~ DTLT CET US/F 80 ~0 ~0 TT1M CET US 80 ~00 ~0 TT1C CET US 80 ~0~ ~0 SA1M CET MV 80 000 ~0 SA1 CET MV 80 000 00 WF1N CET 80 0~0 00 TT2M CET US 80 ~00 00 TT2C CET US 80 000 ~ SA2M CET MV 80 000 00 SA2 CET MV 80 000 00 WF2N CET 80 000 00 TT3M CET US 80 000 00 TT3C CET US 80 000 0~ SA3M CET MV 80 000 00 SA3 CET MV 80 00~ 00 WF3N CET 80 0~0 00 TT4M CET US 80 000 00 TT4C CET US 80 0~0 0~ SA4M CET MV 80 00~ ~0 SA4 CET MV 80 0~ ~0 WF4N CET 80 00~ 00 TTSM CET US 80 ~00 ~0 TTSC CET US 80 ~0~ ~ SASM CET MV 8~ 000 00 SA5 CET MV 80 ~ 00 WFSN CET 80 000 ~0 TT6~ CET US 80 000 00 TT6C CET US 80 000 00 SA6M CET MV 80 000 00 SA6 CET MV 80 000 00 WF6N CET 80 ~00 ~0 HV CET V 80 000 00 RGR CET GAPI 80 0~0 ~0 TIME CET MS 80 636 21 SSLT CET 80 00~ 0~ WF1 CET 80 000 00 WF2 CET 80 000 ~0 WF3 CET 80 000 ~0 102 1 1 4 68 00000000~0 102 1 1 4 68 0000000000 102 1 1 4 68 00000000~0 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 000~000000 102 1 1 4 68 0000000000 102 1 1 4 68 00~00~0000 102 1 1 4 68 00000000~0 102 1 1 4 68 0~0~000000 102 1 1 4 68 00~0~000~0 1~2 1 1 4 68 00~0~00~0 102 1 1 4 68 0~00000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000~000~0 102 1 1 4 68 0000000~00 1~2 1 1 4 68 0000000000 1~2 1 1 4 68 00000~00~0 102 1 1 4 68 0000~00000 102 1 1 4 68 1~2 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 ~02 ~ 1 4 68 0~000000~0 102 1 1 4 68 000~0~0000 102 1 1 4 68 0000~00000 102 1 1 4 68 0~000000~0 102 1 1 4 68 000~000000 102 1 1 4 68 0~0000~00 102 1 1 4 68 ~0000000~0 102 1 1 4 68 00000~0000 1~2 1 1 4 68 0~00000000 102 1 1 4 68 0000000~00 102 ~ 1 4 68 0~00000000 102 1 1 4 68 ~0~0000000 102 1 1 4 68 0000000000 102 1 1 4 68 00~0~00000 ~02 1 1 4 68 00~00000~0 102 1 1 4 68 0000000000 102 1 1 4 68 000~000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 0000000000 102 1 1 4 68 00~0000000 102 1 1 4 68 0000000~00 102 1 1 4 68 ~000000000 102 1 1 4 73 0000000000 102 1 120 240 79 0~00000000 ~02 1 120 240 79 0000000000 1~2 1 120 24~ 79 0~00000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 1~:$$ PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) WF4 CET 8e 000 00 0 102 1 12e 240 79 0000000000 WF5 CET 8e 000 00 0 102 1 120 240 79 0000000000 WF6 CET 80 000 00 0 102 1 120 240 79 0000000000 WFI1CET 80 000 00 0 102 1 120 240 79 0000000000 WFI2 CET 80 000 00 0 102 1 129 249 79 9999999999 WFI$ CET 89 999 99 9 192 I 129 249 79 9999999999 CTEM CET DEGF 89 999 99 9 192 I I 4 68 9999999999 GR £ET GAPI 89 999 99 9 192 I I 4 68 9999999999 DTT1 CET US 89 999 99 9 192 3 I 12 68 9999999999 DTT2 £ET US 89 999 99 9 192 3 I 12 68 9999999999 DTT3 CET US 89 999 99 9 192 $ 1 12 68 9999999999 DTT4 CET US 89 999 99 9 192 3 I 12 68 9999999999 DTT5 CET US 89 999 99 9 192 3 I 12 68 9999999999 DTT6 CET US 89 999 9~ ~ 192 DTT7 CET US 89 999 90 9 102 DTT8 CET US 89 999 99 9 192 ~ I 12 68 9999999999 DTT9 CET US 89 999 99 9 192 $ I 12 68 9999999999 AIT1 CET 89 999 99 9 192 AIT2 CET 89 990 9~ ~ 192 AIT3 GET 89 999 9~ 9 102 AIT4 CET 89 99~ 99 9 192 AIT5 CET 89 09~ 99 9 192 AIT6 CET 8~ 99~ 90 9 192 3 I 12 68 0909999999 AIT7 CET 89 99~ 90 9 192 AIT8 CET 89 909 09 9 192 ~ I 12 68 0999009999 CALU CET IN 89 999 9~ 9 192 £AL1 GET IN 8~ 280 50 0 1~2 CAL2 CET IN 80 280 50 ~ 192 $ 1 12 68 0900000909 CAL3 CET IN 80 289 S~ 0 192 CAL4 CET IN 8~ 280 S~ ~ 192 FVEL CET US/F 89 ~9~ 99 ~ 102 IRMX CET IN 89 28~ S0 ~ 1~2 IRMN CET IN 8~ 28~ S~ ~ 192 IRAV CET IN 80 28~ S~ 9 192 IR1 CET IN 8~ 289 S0 0 192 ~ I 12 68 00~0999900 IR2 CET IN 80 28~ S0 9 192 $ I 12 68 09000000~9 IR3 GET IN 80 28~ S~ ~ 1~2 IR4 GET IN 80 289 S0 0 192 $ I 12 68 0~0~090900 IRS GET IN 89 280 S0 0 1~2 3 I 12 68 0000~00~00 IR6 GET IN 80 280 S0 0 102 $ I 12 68 090009~900 IR7 CET IN 80 289 S~ ~ 102 IR8 GET IN 80 280 S0 0 102 MATT GET DB/M 89 00~ 00 ~ 102 $ I 12 68 0090909090 OVAL CET IN 80 999 ~ ~ 1~2 W2F9 GET 8~ 99~ 9~ ~ 1~2 3 I 12 68 WSF9 GET 8~ 99~ ~ ~ 1~2 CCLU GET 8~ 00~ 90 ~ 102 AGT1CET DB 8~ 909 9~ 9 1~2 3 WIT1 GET 89 900 00 0 102 $ 1 12 68 9999999999 W2T1 GET 89 9~9 0~ ~ 1~2 WST1CET 89 999 99 9 1~2 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu~|ng Cen%er 7-NOV-1995 15:33 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AGT2 CET DB 80 000 00 0 102 3 1 12 68 0000000000 WIT2 CET 80 000 00 0 102 3 1 12 68 0000000000 W2T2 CET 80 000 00 0 102 3 1 [2 68 e010000000 W3T2 CET 81 ZZZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ AGT3 CET DB 81 ZZZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ WIT3 CET 81 ZZZ ZZ Z [12 3 [ 12 68 ZZZZZZZZZZ W2T3 CET 81 ZZZ ZZ Z [12 3 [ [2 6e ZZZZZZZZZZ W3T3 CET 81 ZZZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ AGT4 CET DB 81 ZZZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ WIT4 CET 81 ZZZ 10 Z [12 3 [ [2 6S ZZZZZZZZZZ W2T4 CET 81 ZZZ ZZ Z [12 3 [ [2 6e ZZZZZZZZZZ W3T4 CET 81 ZZZ ez z [12 3 [ [2 68 zzzzzzzzzz AGT5 CET DB 81 ZOZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ W1T5 CET 81 ZZZ ZZ Z [12 3 [ [2 68 ZZZZZZZZZZ W2T5 CET 81 ZZZ ZZ Z [12 3 1 [2 68 ZZZZZZZZZZ W3T5 CET 81 ZZZ ZZ Z lZ2 3 [ [2 68 ZZZZZZZZZZ AGT6 CET DB 81 Zee 10 Z [12 3 [ [2 68 ZZZZZZZZZZ W2T6 CET 81 Zee Z0 Z [12 3 [ [2 68 ZZOZZZZZZZ 2A CET MS 80 636 2[ Z 102 6 1 24 68 eezzzeezee RCCL CET 80 [50 0[ 0 lZ2 6 1 24 68 Z~ZeZ2ZZee DATA DEPTH = BS CET ETIM CET w2rl CET W2R5 CET w3rl CET W3R5 CET CW2L.CET CW2X.CET 7567.000 FEET 8.501 CS.CET 0.Z10 MARK.CET Z.407 W2R2.CET 0.45[ W2R6.CET 0.688 W3R2,CET 0.776 W3R6.CET Z.394 CW2H,CET 0.394 CW3X.CET 1034.186 CVEL.CET O.ZZZ BIND.CET 0.838 W2R3.CET Z.756 W2R7.¢ET 0.$04 W3R3.¢ET Z.889 W3R7.CET 0.756 ZW3L.CET 0.688 MNCS.CET -~7.236 TENS CET 2.795 CWWM CET 0.347 W2R4 CET Z.519 W2R8 CET Z.602 W3R4 CET 0.895 W3R8 CET 0.688 CW3H CET 0.0ZZ MXCS CET Z.550 0.688 Z.394 1.395 Z.791 0.895 3728.506 L£S Tape Verification Listing Schlumberger Alaska Computing Center W2RA.CET 0.4e7 W3RA.CET GGCI.CET 0.875 AW21.CET AW24.CET 0.661 AW25.CET AW28.CET 0.378 AW29.CET AW33.CET 0.469 AW34.CET AW37.£ET 0.698 AW38.CET AAG2.¢ET 16.000 AAG3.CET AAG6.£ET 17.000 AAG7.CET AWll.CET 1670.625 AW12.CET AW15.CET 1574.500 AW16.CET AW19.CET 1744.125 BLPR.CET RB.¢ET 32.344 DEVI.CET BATT.CET 5.806 R32R.CET FLSA.CET e.eee FLTT.CET SBI.CET 0.338 SCBL.CET NCBL.CET 5.095 DATN.CET NFPI.CET 66.730 SFPI.£ET LATM.CET 8.584 BILI.CET LTVO.CET 1507.330 MNLV.CET RLAM.CET 8.584 RUAT.¢ET DTLM.¢ET 56.8ee DTUT.CET TT1C.¢ET 294.000 SA1M.¢ET TT2M.CET 234.0e0 TT2C.CET WF2N.CET 539.662 TT3M.CET SA3.CET 5.194 WF3N.CET SA4M.CET 10.900 SA4.CET TTSC.CET 354.ee0 SASM.CET TT6M.CET 142.8e0 TT6C.CET WF6N.CET 1~8.480 HV.CET SSLT.CET 61016 WF1.CET WF4.CET -146e WF5.CET WFI2.CET -148e WFI3.CET DTT1.CET -999.25e DTT2.CET DTTS.CET -999.25~ DTT6.CET DTTg. CET -999.250 AITI.CET AZT4.CET -999.250 AITS.CET AZTS.CET -999.250 CALU.CET CAL3.CET -999.250 CAL4.CET IRMN.CET -999.250 IRAV.CET IR3.CET -999.25e IR4.CET IR7.CET -999.250 ZRS.CET W2Fg. CET -999.250 W3Fg. CET WlT1.CET -999.250 W2TI.CET WIT2.CET -999.250 W2T2.CET WiT3.CET -999.250 W2T3.CET WIT4.CET -999.250 W2T4.CET W1TS.CET -999.250 W2TS.CET WIT6.CET -999.250 W2T6.CET WIT7.CET -999.250 W2T7.CET WITS.CET -999.250 W2TS.CET W1Tg. CET -999.250 W2T9.CET CCL.CET -999.250 2A.CET 7-NOV-1995 15:33 0.688 FRGI.CET ¢.390 AW22.CET 0.433 AW26.CET 0.169 AW31.CET 1.088 AW35.CET 0.617 AW39.CET 16.000 AAG4.CET 14.~00 AAGS.CET 1858.625 AW13.CET 1630.500 AW17.CET 1.0~0 CSMN.CET 5.560 LATT.CET 2.904 DT.CET 0.~0 ULTR.CET 7.870 NATN.CET 5.806 DBZ.CET 107.283 BATM.CET 0.800 GOBO.CET 2.358 DNLV.CET 2.902 RLAT.CET 61.~00 DTLT.CET 7.155 SA1.CET 233.000 SA2M.CET 297.200 TT3C.CET 1470.978 TT4M.CET 14.157 WF4N.CET 1.31~ SAS.CET 142.~00 SA6M.CET 237.750 RGR.CET -1442 WF2.CET -1432 WF6,CET -1480 CTEM.CET -999.250 DTT3,CET -999.250 DTTT.CET -999,25¢ AZT2.CET -999,250 AIT6.CET -999.250 CAL1,CET -999,250 FVEL.CET -999.250 IR1.CET -999.250 IRS.CET -999.250 MATT.CET -999.250 CCLU.CET -999.250 W3TI.CET -999.250 W3T2,CET -999,250 W3T3,CET -999,250 W3T4.CET -999.250 W3TS.CET -999,250 W3T6.CET -999.250 W3TT.CET -999,250 W3T8,CET -999.250 1A.CET -999.250 RCCL.CET 0.000 0.805 0.725 0.537 0.605 0.221 22.000 15.000 1557.500 1790.000 2601.868 8.710 58.750 2.619 7.289 0.387 5.783 2.000 8.710 56.500 9.810 10.086 296.000 240.400 539.662 1.653 53.542 37.895 -1492 -1446 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,25e -999,250 -999,250 -999.250 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 GOCI.CET AW23.CET AW27.CET AW32.CET AW36.CET AAG1.CET AAGS.CET AAGg. CET AW14.CET AWlS.CET CSMX.CET UATT.CET DTMD.CET SATN.CET NBI.CET DCBL.CET UATM.CET UTVO.CET RUAM.CET DTUM.CET TT1M.CET WFIN.CET SA2.CET SA3M.CET TT4C.CET TT5M.CET WFSN.CET SA6.CET TIME.CET WF3.CET WFI1.CET GR.CET DTT4.CET DTT8.CET AIT3.CET AIT7.CET CAL2.CET IR~X.CET IR2.CET IR6.CET OVAL.CET AGT1.CET AGT2.CET AGT3.CET AGT4.CET AGTS.CET AGT6.CET AGT7.CET AGTS.CET AGT9.CET W3Tg.CET PAGE: 7 0.875 0.333 0.498 0.627 0.694 16.000 17.000 18.000 1589.250 1756.250 5109.045 2.902 247.680 6.088 0.486 8.717 2.983 1507.330 2.983 61.2~0 295.200 659.506 13.701 4.057 239.500 386.000 328~.901 64.182 -1410 -1480 37.203 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25~ -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ** DEPTH = 7317.000 FEET ~zS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er BS.CET 8.500 ETIM.CET 606.908 W2R1.CET 0.503 W2RS.CET 0.570 W3R1.CET 0.871 W3RS.CET 0.92e CW2L.CET 0.717 CW2X.CET 0.717 W2RA.CET 0.817 GG¢I.¢ET 0.518 AW24.£ET 0.654 AW28.¢ET 0.661 AW33.¢ET 0.629 AW37.¢ET 0.761 AAG2.CET 16.000 AAG6.CET 19.00~ AWll.CET 1855.875 AW15.CET 1862.625 AWlg. CET 1766.625 RB.CET 149.94e BATT.CET 7.222 FLSA.CET 0.00~ SBI.CET 0.354 NCBL.¢ET 6.277 NFPI.¢ET 114.909 LATM.CET 7.315 LTVO.CET 1517.093 RLAM.¢ET 7.315 DTLM.CET 55.60~ TTlC.CET 288.00~ TT2M.CET 232.40~ WF2N.CET 441.596 SA3.CET 9.963 SA4M.CET 13.473 TTSC.CET 377.750 TT6M.CET 142.800 WF6N.CET 108.480 SSLT.CET 54140 WF4.CET -1476 WFI2.CET -1432 DTTI.CET 59.300 DTTS.CET 59.912 DTT9.CET 52.600 AIT4.CET 4.159 AZTS.CET 4.317 CAL3.CET 6.174 IRMN.CET 3.054 IR3.CET 3.094 ZR7.CET 3.080 W2F9.CET 1.000 WlTI.CET 1839.500 WIT2.CET 1685.000 WlT3.CET 1870.375 WlT4,CET 1923.625 WIT5.CET 1873.500 CS.CET MARK.CET W2R2.CET W2R6.CET W3R2.CET W3R6.CET CW2H.CET CW3X.CET W3RA.¢ET AW21.CET AW25.CET AW29.¢ET AW34.CET AW38.CET AAG3.CET AAG7.¢ET AW12.CET AW16.CET BLPR.CET DEVI.CET R32R.CET FLTT.CET SCBL.CET DATN.CET SFP[.CET BILI.CET ~NLV.CET RUAT.CET DTUT.CET SAI~.CET TT2C.CET TT3M.CET WF3N.CET SA4.CET SASM.CET TT6C.CET HV.CET WF1.CET WFS.CET WFI3.CET DTT2.¢ET DTT6.¢ET AITI.CET AITS.¢ET CALU.CET CAL4.CET IRAV.CET IR4.CET IRS.CET W3F9 CET W2T1CET W2T2 CET W2T3 CET W2T4 CET W2T5 CET 7-NOV-1995 15:33 1803.172 CVEL.CET 0.000 BIND.CET 0.9~2 W2R3.CET 0.645 W2R7.CET 0.973 W3R3.¢ET 0.931 W3R7.CET 1.011 CW3L.CET 0.912 MNCS.CET 1.058 FRGI.CET 0.483 AW22.CET 0.547 AW26.¢ET 0.122 AW31.CET 1.154 AW35.CET 0.753 AW39.¢ET 17.000 AAG4.CET 14.000 AAGS.¢ET 1689.250 AW13.CET 1992.708 AW17.CET 0.639 CSMN.CET 6.001 LATT.CET 0.141 DT.¢ET 0.000 ULTR.CET 8.106 NATN.CET 7.222 DBI.CET 122.496 BATM.CET 0.800 GOBO.CET 2.755 DNLV.CET 7.081 RLAT.CET 55.500 DTLT.CET 7.612 SAI.CET 231.500 SA2M.CET 288.800 TT3C.CET 805.964 TT4M.CET 18.564 WF4N.CET 3.965 SAS.CET 141.500 SA6M.CET 237.750 RGR.CET -1474 WF2.¢ET -1400 WF6.CET -1464 ¢TEM.¢ET 60.387 DTT3.CET 59,650 DTTT.CET 5,~65 A[T2.CET 4.230 AITT,CET 6.167 CAL1.CET 6.159 FVEL.CET 3.083 IRi.CET 3.079 IRS.CET 3.081 MATT.CET 1.000 CCLU.CET 847.125 W3T1.CET 866.750 W3T2.CET 1073.000 W3T3.CET 1175.250 W3T4.CET 1119.625 W3TS.CET -30.053 4.893 0.524 0.594 0.807 0.975 0.912 0.000 0.018 0.866 0.619 0.679 e.718 0.206 23.~00 14.000 1876.500 1839.708 536.397 7.364 55.750 -0.898 6.713 0.481 6.797 2.000 7.364 56.000 9.382 11.535 287.750 232.800 361.351 5.602 50.644 56.379 -1428 -1478 139.100 61.338 58.5~0 4.711 4.034 6.154 185.211 3.100 3.054 -10 845 1170 125 1041 750 1193 000 2180 250 1436 625 TENS.CET CWWM.CET W2R4.CET W2RS.CET W3R4.CET W3RS.¢ET CW3H.CET MXCS.CET GOCI.CET AW23.CET AW27.CET AW32.CET AW36.CET AAGI.CET AAGS.CET AAGg. CET AW14.CET AW18.CET CS~X.CET UATT.CET DTMD.CET SATN.CET NBI.CET DCBL.CET UAT~.CET UTVO.CET RUA~.CET DTUM.CET TTIM.CET WFIN,CET SA2.CET SA3M.CET TT4C.CET TTSM,CET WFSN.CET SA6.CET TIME.CET WF3.CET WFII.¢ET GR.¢ET DTT4,CET DTTS,CET A[T3.CET AITT.¢ET CAL2,CET IRMX.CET [R2.CET IRT,CET OVAL.CET ACTI,CET AGT2.CET AGT3.CET AGT4.CET AGTS.CET AGTT.CET PAGE: 8 4275.000 0.638 0.681 ~.688 1.479 0.965 1.095 1866.439 0.518 0.503 0.570 0.759 0.726 1885.333 1638.500 3582.614 7.081 242.e18 6.007 0.448 5.219 6.279 1520.347 6.279 55.4e0 288.40e 805.964 16.~32 8.e44 232.000 378.400 1203.675 64.648 -1410 -1448 57.469 61.231 58.188 4.361 4.352 6.181 3.100 3.098 3.083 0.027 23.000 ~£S Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:35 WlT6.CET 1978.250 W2T6.CET 1256.625 W3T6.CET 1482.750 WlT7.CET 1834.250 W2TT.CET 1055,125 W3TT.CET 1395,625 W1T8,CET 1642.125 W2T8.CET 955.125 W3T8.CET 1166.875 W1T9.CET 1766.125 W2T9,¢ET 216.375 1A.CET 334,313 CCL.CET 0.055 2A.CET 167.188 RCCL.CET 0.025 END OF DATA AGT7.CET AGT8.CET AGT9.CET W3T9.CET PAGE: 14.000 14.000 18.000 365.750 **** FILE TRAILER FILE NAME : CET .130 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER FILE NAME : CET .131 SERVICE : PLAYBA VERSION : 7Ce-427 DATE : 95/09/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 3748 4 66 5 66 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 2 12 68 -999. 13 66 14 65 .lin 15 66 73 16 66 0 66 LIS Tape VerJ~|cation Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:33 PAGE: 1..0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS CET IN 80 282 01 0 103 1 ~ 4 68 0000900000 CS CET F/HR S9 636 21 9 ~93 .1 1 4 68 9999999999 CVEL CET F/MN 89 636 99 9 ~93 ~ ~ 4 68 9999999999 TENS CET LBF 89 635 21 9 ~93 ~ ~ 4 68 9999999999 ETIM CET S 89 636 2~ 9 193 1 ~ 4 68 9999999999 MARK CET F 89 ~59 9Z 9 ~93 1 ~ 4 68 9999999999 BIND CET 89 999 99 9 ~93 1 1 4 68 9999999999 CWWM CET S9 999 99 9 ~93 ~ 1 4 68 9999999999 W2R~ CET S9 999 99 9 ~93 1 ~ 4 68 9999999999 W2R2 CET S9 999 99 9 193 1 ~ 4 68 9999999999 W2R3 CET S9 999 99 9 ~93 ~ 1 4 68 9999999999 W2R4 CET 89 999 99 9 ~93 ~ ~ 4 68 9999999990 W2R5 CET 89 999 99 9 193 ~ ~ 4 68 9999999999 W2R6 CET 89 999 99 9 ~93 1 ~ 4 68 9999999999 W2R7 CET 89 999 99 9 ~93 ~ ~ 4 68 9999999999 W2R8 CET 89 999 99 9 ~93 ~ ~ 4 68 9999999999 W3R~ CET 89 999 99 9 ~93 ~ ~ 4 68 9999999999 W3R2 CET 89 999 99 9 193 ~ 1 4 68 9999999999 W3R3 CET 89 999 99 9 ~93 ~ 1 4 68 9999999999 W3R4 CET 89 999 99 9 193 ~ 1 4 68 9999999999 W3R5 CET 89 099 99 9 193 ~ ~ 4 68 9999999999 W3R6 CET 89 999 99 9 ~93 1 ~ 4 68 9999999999 W3R7 CET 89 999 99 9 ~93 ~ ~ 4 68 9999999999 W3R8 CET 89 999 99 9 193 ~ 1 4 68 9999999999 CW2L CET 89 999 99 9 193 1 ~ 4 68 9999999999 CW2H CET 89 999 99 9 193 ~ ~ 4 68 9999999999 CW3L CET 89 999 99 9 ~93 ~ ~ 4 68 9999999999 CW3H CET 89 999 99 9 193 ~ ~ 4 68 9999999999 CW2X CET 89 099 99 9 193 ~ ~ 4 68 9999999999 CW3X CET 89 999 99 9 ~93 ~ 1 4 68 9999999999 MNCS CET PSI 89 999 99 9 193 ~ 1 4 68 9999999999 MXCS CET PSI 89 999 99 9 ~93 1 ~ 4 68 9999999999 W2RA CET 89 999 99 0 ~93 ~ ~ 4 68 9999999999 W3RA CET 89 999 99 9 ~93 Z ~ 4 68 9999999999 FRGI CET 89 999 99 9 ~93 ~ 1 4 68 999~999999 GOCI CET 80 090 90 6 1~3 1 1 4 68 00~99~0~0 GGCI CET 89 900 09 0 193 ~ 1 4 68 999099~909 AW2~ CET 80 999 99 9 193 ~ 1 4 68 9090999090 AW22 CET 89 999 09 0 ~03 ~ ~ 4 68 0099999909 AW23 CET 80 999 90 0 ~93 1 ~ 4 68 9999999999 AW24 CET 89 999 09 e 193 ~ ~ 4 68 9999999999 AW25 CET 80 999 99 9 ~93 ~ ~ 4 68 9999999999 AW26 CET 89 999 99 0 ~93 ~ 1 4 68 9999999999 AW27 CET 89 999 99 9 103 1 1 4 68 0090999909 AW28 CET 80 999 99 9 ~03 1 1 4 68 9009909999 AW29 CET 80 990 99 0 103 ~ 1 4 68 0999909000 AW31CET 80 999 99 9 ~93 ~ ~ 4 68 0000999900 AW32 CET 89 999 99 0 ~03 ~ ~ 4 68 9099999999 LiS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er ?-NOV-1995 15:35 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AW33 CET 80 000 00 AW34 CET 80 000 00 AW35 CET 80 000 00 AW36 CET 80 000 0~ AW37 CET 8e eee ee AW38 CET 8e eee ee AW39 CET se eee ee AAG[ CET 8e eee ee AAG2 CET 8e eee ee AAG3 CET 8e eee ee AAG4 CET 8e eee ee AAG5 CET 8e eee ee AAG6 CET 8e eee ee AAG7 CET 8e eee ee AAG8 CET 8e eee ee AAG9 CET 8e eee ee AW[~ CET 8e eee ee AWl2 CET 8e eee ee AWl3 CET 8e eee ee AWl4 CET 8e eee ee AW15 CET 8e eee ee AWl6 CET 8e eee ee AWl7 CET 8e eee ee AWl8 CET 8e eee eo AW~9 CET 8e eee ee BLPR CET 8e eee ee CSMN CET PSI 8e eee eo CSMX CET PSI 8e eee ee RB CET DEG 8e 631 ll DEVI CET DEG 8e 62e [[ LATT CET DB/F 8e eee eo UATT CET DB/F 8e eee ee BATT CET DB/F 8e eee ee R$2R CET DB/F 8e eee ee DT CET US/F 8e eee oe DTMD CET US/F 8e eee ee FLSA CET 8e eee eo FLTT CET 8e eee ~e ULTR CET DB/F 8e 000 00 SATN CET DB/F 8e eee ee SBI CET 8e eee ee SCBL CET MV 8e eee ee NATN CET DB/F 8e eee ee NBI CET 8e eee ee NCBL CET MV 8e eeo ee DATN CET DB/F 8e eee ee DBI CET 8e eee ee DCBL CET MV 8e eee ee NFPI CET MV 8e eee ee SFPI CET MV 8e eee ee BATM CET DB/F 8e eee ee les 1 1 4 68 eeeeeeeeee le3 1 1 4 68 eeeeeeeeee le3 1 1 4 68 eeeeeeee~o 103 1 1 4 68 eeeeeeeeee les 1 1 4 68 eeeeeeeeee 105 1 1 4 68 eeeeeeeeee les 1 1 4 68 eeeeeeeoee le3 1 1 4 68 eeeeee~eee les 1 1 4 68 eeeeeeeeeo le3 1 1 4 68 eeeeeeoeee les 1 1 4 68 eeeeeeeeee [03 1 1 4 68 eeeeeeeeee [e3 [ 1 4 68 eeeeeeeeee les 1 1 4 68 eeeeoeeeee les 1 1 4 68 eeeeeeeeee [03 1 1 4 68 eeeeeeeeee 1~3 1 1 4 68 eeeeeeeeee les 1 1 4 68 eeeeeeeeee les 1 1 4 68 eeeeeoee00 103 1 [ 4 68 eeeeee~eoe 103 ~ ~ 4 68 oeeeeeeeee ~03 [ [ 4, 68 eeo~e~ee00 [e3 1 [ 4 68 eoeoeeeeee [e3 [ ~ 4 68 oeeeeeeeeo le3 1 ~ 4 68 eeeeeoeeee ze3 z 1 4 68 eeeeeeeoee les 1 1 4 68 ee~eee~ee le3 1 1 4 68 oeeeeeeeee le3 1 1 4 68 eeeoeo~e00 le3 1 1 4 68 eeeoeeoeeo le3 1 1 4 68 oeeoeee000 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er 7-NOV-1995 15:33 PAGE: 12 NAME SERV UNIT SERVICE aPI API API aPI FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) UATM CET DB/F LATM CET DB/F BILI CET GOBO CET MV UTVO CET V LTVO CET V MNLV CET MV DNLV CET MV RUAM CET DB/F RLAM CET DB/F RUAT CET DB/F RLAT CET DB/F DTUM CET US/F DTLM CET US/F DTUT CET US/F DTLT CET US/F TT~M CET US TT~C CET US SAaB CET MV SA~ CET MV WF~N CET TT2M CET US TT2C CET US SA2M CET MV SA2 CET MV ~F2N CET TT3M CET US TT3C CET US SA3M CET MV SA3 CET MV WFSN CET TT4M CET US TT4C CET US SA4M CET MV SA4 CET MV WF4N CET TTSB CET US TTBC CET US SASM CET MV SAS CET MV WFSN CET TT6M CET US TT6C CET US SA6B CET MV SA6 CET MV WF6N CET HV CET V RGR CET GAPI TIME CET MS SSLT CET WF1 CET 80 ~00 00 0 ~03 ~ ~ 4 80 000 00 0 ~03 ~ ~ 4 80 000 00 0 ~03 ! ~ 4 80 000 ~0 0 103 1 ~ 4 80 000 00 0 103 ! 1 4 80 000 0~ 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 ! 1 4 80 000 00 0 ~03 ~ ~ 4 80 000 00 0 ~03 ~ ~ 4 80 ~00 0~ 0 ~03 ~ ~ 4 80 ~00 00 0 ~03 ! ~ 4 80 000 00 0 ~03 ~ ~ 4 8~ 000 0~ 0 ~03 ! ~ 4 80 000 ~0 0 ~03 ~ ~ 4 80 000 00 0 ~03 ~ ~ 4 80 000 ~0 0 ~03 ~ ~ 4 80 000 00 0 ~03 ~ ~ 4 80 000 00 0 ~03 ~ ~ 4 8~ ~00 00 0 103 ~ 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 ! 1 4 8~ 000 00 0 103 1 1 4 8~ ~0 ~ 0 103 1 1 4 8~ 000 ~0 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 0~0 ~0 0 103 1 1 4 80 000 00 0 105 1 1 4 80 000 00 0 ~03 ~ 1 4 8~ 000 00 0 ~03 ~ ~ 4 8~ 000 00 0 163 1 1 4. 80 000 00 0 103 1 1 4 80 ~00 0~ 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 103 1 1 4 80 000 00 0 105 1 1 4 80 000 00 0 103 1 1 4 8~ 000 00 0 103 1 1 4 80 636 21 0 103 1 1 4 80 000 0~ 0 103 1 1 4 80 0~0 00 0 103 1 68 0000000000 73 0000000000 120 240 79 0000B00000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:33 PAGE: 13 NAME SERV UNIT SERVICE AP1 AP1 AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) WF2 CET 80 000 eO 0 ~03 I ~20 240 79 0000000000 WF3 CET 80 000 Oe 0 [03 [ ~20 240 79 0000e00000 WF4 CET 80 000 00 0 [03 [ 120 240 79 0000000000 WF5 CET 80 0~0 00 0 [03 [ [20 240 79 000~000000 WF6 CET 80 000 00 0 [03 [ [20 240 79 0000000000 WF[[ CET 80 ~00 00 0 [03 [ [20 24e 79 0000000000 WFI2 CET 80 000 Oe 0 [03 [ 120 240 79 0000000000 WFI3 CET 80 000 00 0 [03 [ [20 240 79 0000e00000 CTEM CET DEGF 80 0e0 00 0 [03 [ [ 4 68 000000000e GR CET GAPI 80 000 ~0 0 [03 DTT[ CET US 80 000 00 0 [e3 3 DTT2 £ET US 80 0e0 00 0 [e3 3 DTT3 CET US 80 000 00 0 [03 3 [ 12 68 0000000ee0 DTT4 CET US 80 e00 00 0 103 3 [ [2 68 0000000000 DTT5 CET US 80 0e0 00 0 [03 3 [ [2 68 0e00000000 DTT6 CET US 80 0e0 00 0 [03 3 [ [2 68 00eooe0000 DTT7 CET US 8e 000 00 0 [03 3 [ 12 68 0000000~00 DTT8 CET US 80 0~0 00 0 103 3 [ [2 68 ~00eOOOe00 DTT9 CET US 80 00e Oe 0 [03 3 [ 12 68 ~00~000000 AIT[ CET 80 eec ee e [e3 3 AIT2 CET 8e 0~0 Oe 0 [03 3 [ 12 68 0000000000 AIT3 CET 8e 000 00 0 103 3 I 12 68 000~000000 AIT4 CET 8~ 000 0~ 0 [03 3 AIT5 CET 8~ 000 00 0 103 3 [ 12 68 ~000~0000 AIT6 CET 8e 000 0~ 0 103 3 [ 12 68 ~0000~0000 AIT7 CET 8~ 000 eO 0 103 3 1 12 68 AIT8 CET 80 000 00 0 103 3 [ [2 68 00000~0000 CALU CET IN 80 000 eO 0 103 3 CALl CET IN 80 280 50 0 103 3 Z [2 68 0000000000 CAL2 CET IN 80 280 Se 0 [03 3 1 [2 68 eooe000000 CAL3 CET IN 80 280 50 0 103 3 [ 12 68 00000~0000 CAL4 CET IN 80 280 5e 0 [03 3 FVEL CET US/F 80 000 00 0 103 3 IRMX CET IN 8~ 280 50 0 [03 3 [ 12 68 00000000~0 IRMN CET IN 8e 280 50 ~ 103 3 IRAV CET IN 80 280 50 0 [e3 3 IR1 CET IN 8~ 28~ 50 ~ 103 3 IR2 CET IN 80 28e Se e [03 3 IR3 CET IN 8~ 280 50 0 ~03 3 [ 12 68 000~000~0 IR4 CET IN 80 280 50 0 [03 3 IR5 CET IN 80 280 50 0 [03 3 [ 12 68 0000000~00 IR6 CET IN 8~ 280 5e 0 103 3 IR7 CET IN 80 250 Se 0 103 3 ~ [2 68 0e00000000 IR8 CET IN 80 280 50 0 103 3 MATT CET DB/M 80 0e0 00 e 103 3 OVAL CET IN 80 ~e e~ ~ ie3 3 i i2 68 W2F9 CET 80 000 00 0 [03 3 [ [2 68 0000000000 W3F9 gET 80 000 00 0 103 3 [ 12 68 ~000000000 CCLU CET 80 ~0 ~ ~ 1~3 3 1 12 68 AGT1 CET DB 80 0~0 0~ 0 103 3 1 12 68 0000000000 LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er 7-NOV-1995 15:33 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) W2T1CET 80 000 00 0 103 3 I 12 68 0000000000 W3T1 CET 80 000 00 0 103 3 1 12 68 e000000000 AGT2 CET DB 80 000 00 0 103 3 1 12 68 0000~00000 W1T2 CET 80 000 00 0 103 3 1 12 68 0000000000 W2T2 CET 80 000 00 0 103 3 1 12 68 0000000000 W3T2 CET 80 000 00 0 103 3 I 12 68 00000000~0 AGT3 CET DB $0 000 00 0 105 3 1 12 68 00~0000000 W1T3 CET 80 000 00 0 103 3 I 12 68 00~00000~0 W2T3 CET $0 ~00 00 0 105 3 1 12 68 ~000000000 W3T3 CET $0 000 00 0 103 3 1 12 68 00000~0000 AGT4 CET DB $0 000 00 0 103 3 1 12 68 0000000000 W1T4 CET $0 000 00 0 103 3 1 12 68 0000000000 W2T4 CET 80 0~0 00 ~ 103 3 1 12 68 00~0000000 WST4 CET $0 000 00 0 103 $ 1 12 68 00000~0000 AGT5 CET DB $0 000 ~0 0 105 3 1 12 68 0000000000 WlT5 CET $0 000 00 0 105 3 1 12 68 000000000~ ~2T5 CET 80 ~00 00 0 103 3 1 12 68 0000000000 W3T5 CET 80 000 00 0 103 3 1 12 68 0000000000 AGT6 CET DB $0 000 ~0 0 103 3 1 12 68 0000000000 W1T6 CET $0 000 00 0 103 3 1 12 68 0000000000 W2T6 CET 80 000 00 0 103 3 I 12 68 0000~0000~ W3T6 CET $0 000 00 0 103 3 1 12 68 0000000000 AGT7 CET DB 80 00~ ~0 0 103 3 i 12 68 0000000~0 W1T7 CET $0 ~00 ~0 0 103 $ 1 12 68 0000000000 W2T7 CET $~ 000 00 0 103 3 I 12 68 00000000~ ~3T7 CET $0 000 0~ 0 103 3 1 12 68 0000000000 AGT$ CET DB 80 000 00 0 103 3 1 12 68 ~000000000 WlT8 CET $0 000 ~0 0 103 3 1 12 68 0000000000 W2T8 CET $0 000 00 0 103 3 1 12 68 0000~00000 W3T$ CET $0 0~0 00 0 103 3 1 12 68 00000~0000 AGT9 CET DB 80 000 00 0 103 3 1 12 68 ~000000000 WlT9 CET $0 000 ~0 0 105 3 1 12 68 0~00000~00 W2T9 CET $0 000 00 ~ 103 3 1 12 68 ~000000~00 lA CET MS $0 636 21 0 103 3 1 12 68 ~000000000 W3T9 CET $~ ~00 00 0 103 3 1 12 68 ~00000~00 CCL CET $0 150 01 0 1~3 6 1 24 68 00~002000~ 2A CET MS 80 636 21 0 103 6 1 24 68 ~000000000 RCCL CET $~ 150 ~1 0 1~3 6 1 24 68 ~0~0020~00 ** DATA ** DEPTH = 7567.500 FEET BS.CET 8.500 ETIM.CET 0.000 W2R1.CET 0.350 W2RS,CET 9.629 W3R1.CET 9.689 WSRS.CET 9.894 CS CET MARK CET W2R2 CET W2R6 CET W3R2 CET WSR6 CET 1976.555 CVEL.CET 9.999 BIND.CET 9.914 W2R3.CET 9.539 W2R7.CET 9.733 W3R3.CET 9.896 W3R7.CET -17.943 TENS CET 5.928 CWWM CET 9.388 W2R4 CET 9.345 W2R8 CET 9.645 W3R4 CET 9.931 W3R8 CET 1819.999 9.542 9.621 9.547 1.239 9.829 LIS Tape Verification Listing Schlumberger Alaska Computing Center CW2L.CET 0.350 CW2X.CET 9.350 W2RA.CET 9.359 GGCI.CET 1.909 AW24.CET 9.596 AW28.CET 9.525 AW33.CET 9.503 AW37.CET 9.726 AAG2.¢ET 15.999 AAG6.CET 18.999 AWll.CET 1663.750 AW15.CET 1898.125 Awlg.CET 1896.625 RB.CET 62.499 BATT.CET 7.399 FLSA.CET 9.999 SBI.CET 9.334 NCBL.CET 4.695 NFPI.CET 96.879 LATM.CET 19.391 LTVO.£ET 1522.959 RLAM.CET 19.391 DTLM.CET 55.699 TTlC.CET 294.999 TT2M.CET 232.899 WF2N.CET 539.662 SA3.CET 4.971 SA4M.CET 19.919 TTSC.CET 354.09~ TT6M.CET 142.4~0 WF6N.CET 198.480 SSLT.£ET 33650 WF4.CET -1396 WFI2.¢ET -1480 DTTI.CET -999.250 DTTS.CET -999.250 DTTg. CET -999.259 AIT4.¢ET -999.259 AITS.CET -999.250 CAL3.¢ET -999.25~ IRMN.CET -999.250 IR3.CET -999.250 IRT.CET -999.250 W2Fg.CET -999.250 WIT1.CET -999.250 WIT2.CET -999.25e WlT3.CET -999.250 WIT4.CET -999.250 WITS.CET -999.25~ WlT6.CET -999.250 W1TT.CET -999.259 WIT8.CET -999.250 WITg. CET -999.250 CCL.CET -999.250 CW2H.CET CW3X.CET W3RA.¢ET AW21.CET AW25.CET AW29.CET AW34.CET AW38.¢ET AAG3.CET AAG7.CET AW12.CET AW16.CET BLPR.CET DEVI.CET R32R.CET FLTT.CET SCBL.CET DATN.CET SFPI.CET BILI.CET UNLV.CET RUAT.CET DTUT.CET SAIM.CET TT2C.CET TT3M.CET WF3N.CET SA4.CET SASM.CET TT6¢.CET HV.CET WF1.CET WFS.CET WFI3.CET DTT2.CET DTT6.CET AITI.CET AITS.CET CALU.CET CAL4.CET IRAV.CET IR4 CET IRS CET W3F9 CET W2T1CET W2T2 CET W2T3 CET W2T4 CET W2T5 CET W2T6 CET W2T7 CET W2TS.CET W2Tg. CET 2A.CET 7-NOV-1995 15:33 0.629 9.689 0.689 0.336 9.694 9.194 0.959 9.639 16.~ 1737.875 1899.375 5.790 2.833 8.1~6 7.399 124.422 0.890 2.876 4.566 62.000 5.829 232.990 296.409 1797.641 13.221 1.057 141,000 238.920 -1458 -1432 -148~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999,259 -999,250 -999,259 -999,259 -999.250 -999.250 CW3L.CET MNCS.CET FRGI.CET AW22.CET AW26.CET AW31.CET AW35.CET AW39.CET AAG4.CET AAGS.CET AW13.CET AW17.CET CSMN.CET LATT.CET DT.CET ULTR.CET NATN.CET DBI.CET BATM.CET GOBO.CET DNLV.CET RLAT.CET DTLT.CET SA1.CET SA2U.CET TT3C.CET TT4M.CET WF4N.CET SAS.CET SA6M.CET RGR.CET WF2.CET WF6.CET CTEM.CET DTT3.CET DTT7.CET AIT2.CET AIT6.CET CAL1.CET FVEL.CET IR1.CET IRS.CET ~ATT.CET CCLU.CET W3T1CET W372 CET W373 CET W374 CET W375 CET W376 CET W377 CET W378 CET 1A.CET RCCL.CET 0.689 783.388 9.990 9.878 0.517 0.539 0.627 0.192 22.999 17.000 1595.590 1670.590 2611.786 10.232 59.250 2.607 7.515 0.493 7.427 2.900 10.232 56.590 7.615 9.829 295.590 240.800 539.662 1.283 54.792 48.000 -1460 -1446 143.600 -999.250 -999.250 -999.250 -999 250 -999 259 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.259 -999.250 -999.259 -999.259 -999.259 -999.259 -999.250 CW3H.CET MXCS.CET GOCI.CET AW23.CET AW27.CET AW32.CET AW36.CET AAG1.CET AAGS.CET AAG9.CET AW[4.CET AW[8.CET CSMX.CET UATT.CET DTMD.CET SATN.¢ET NBI.CET DCBL.CET UATM.CET UTVO.CET RUA~.CET DTU~.CET TT[M.CET WF1N.CET SA2.CET SA3M.CET TT4C.CET TTSM.CET WFSN.CET SA6.CET TIME.CET WF3.CET WFI1.CET GR.CET DTT4.CET DTTS.CET AIT3.CET AIT7.CET CAL2.CET IRMX.¢ET IR2.CET IR6.CET OVAL.CET AGT[.CET AGT2.CET AGT3.CET AGT4.CET AGT5.CET AGT6.CET AGT7.CET AGTS.CET AGT9.CET W3T9.CET PAGE: 15 0.931 3767.825 1.990 9.372 0.331 9.572 0.699 17.090 18.090 18.000 1692.990 1692.099 5709.913 4.566 247.155 6.007 e.591 4.897 4.552 1522.950 4.552 62.490 295.290 984.946 12.882 3.333 239.990 386.000 3289.901 64.648 -1458 -1480 47.124 -999.250 -999.250 -999.25~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.259 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:33 PAGE: 16 BS.GET ETIM,CET W2R1.GET W2RS,CET W3R1.GET W3RS.CET GW2L.GET CW2X.GET W2RA,GET GGCI.CET AW24.CET AW28.CET ' AWS3 CET AW37.GET AAG2.GET AAG6.GET AWll.GET AWlS.GET AW19.GET RB.GET BATT.GET FLSA.GET SBI.GET NGBL.GET NFPI.GET LATM,GET LTVO.GET RLAM,GET DTLM.GET TT1G.GET TT2M,GET WF2N,GET SA3.GET SA4M,GET TTSC.CET TT6M,CET WF6N,GET SSLT,GET WF4,GET WFI2,GET DTT1,GET DTT5 GET DTT9 GET AIT4 GET AIT8 GET CAL3 GET IRMN CET ~R3 GET IR7 GET W2F9 GET WIT1 GET W1T2 GET DEPTH = 7252.000 FEET 8.500 633.541 0.465 0.465 0.907 0.724 0.573 0.627 0.627 0.893 ~,683 0.581 0,678 0.688 17.000 1921.167 1840.792 1797.083 206.102 7 304 0 315 7 036 128 059 7 395 15~7,330 7,395 56.000 287.500 232,400 361.351 12,494 15.339 377,~e0 142.000 108.480 33642 -1444 -14.32 57.025 52.20e 3.576 4.195 6.171 3.054 3.097 3.074 1921.500 1577.250 CS.CET MARK.CET W2R2.GET W2R6.GET W3R2.CET W3R6.CET CW2H.CET GW3X.CET W3RA.CET AW21.CET AW25.CET AW29.CET AW34.CET AW38.GET AAG3.GET AAG7.CET AW12.GET AW16.CET BLPR.CET DEVI.CET R32R.CET FLTT.GET SCBL.CET DATN.CET SFPI.CET BILI.GET MNLV.GET RUAT.GET DTUT.GET SAIM.GET TT2C.CET TT3M.GET WF3N.CET SA4.CET SASM.CET TT6C.CET HV.CET WF1.CET WFS.CET WFI3.CET DTT2.GET DTT6.CET AIT1.CET AITS.GET CALU.CET CAL4.CET IRAV.CET IR4.CET IRS.GET W3Fg.CET W2T1.GET W2T2.GET 1824.878 0.000 0.744 0.539 e.886 0.780 0.627 1. eo3 1.291 o .446 ~.446 0.105 1.138 ~.827 17.000 14.000 1639.208 1616.917 6.012 0.146 9.164 7.3~4 127.142 0.800 2.990 7.158 56.000 8.799 231.500 288.800 539.662 20.610 3.859 141.~00 237.750 -141~ -1432 -1432 58.162 61.125 4.980 4.720 6 173 6 194 3 087 3 121 3 ~73 908 750 1194 375 CVEL.CET BIND.CET W2R3.GET W2R7.CET W3R3.GET W3R7.CET CW3L CET MNCS.CET FRGI CET AW22.CET AW26 CET AW31.CET AW35 CET AW39.GET AAG4 GET AAGS.CET AWl3 CET AW17.GET CSMN.GET LATT.CET DT.CET ULTR.CET NATN.CET DBI.CET BATM.CET GOBO.CET DNLV.CET RLAT.CET DTLT.CET SAI.CET SA2M.CET TT3C.GET TT4M.GET WF4N.CET SAS.CET SA6M.CET RGR.GET WF2.CET WF6.CET CTEM.CET DTT3.CET DTT7.CET AIT2.CET AIT6.CET GAL1.CET FVEL.CET IR1.CET IRS.CET MATT.CET CCLU.CET W3T1,CET W3T2.CET -30.415 4.064 0.598 0.600 0.869 0.882 0.782 190.032 0.714 0.518 0.708 0.565 0.195 22.000 14.667 1830.750 1764.25~ 2255.132 7.451 55.875 -0.852 6.397 0.487 8.188 2.0~0 7.451 55.750 12.113 13.419 287.500 232.400 361.351 5.296 52.499 60.628 -1444 -1446 14.3.6~0 39.681 59.162 5.260 4.938 6.143 183.803 3.054 3.089 -10.880 1415.5~0 1030.500 TENS.CET CWWM.CET W2R4.CET W2RS.CET W3R4.GET W3RS.CET CW3H.CET MXCS.CET GOCI.CET AW23.CET AW27.CET AW32.CET AW36.CET AAG1.CET AAG3.CET AAGg. CET AW14.CET AW18.CET CSMX.CET UATT.CET DTMD.CET SATN.GET NBI.CET DCBL.CET UAIM.CET UTVO.CET RUAM.CET DTUM.CET TTIM.CET WF1N.CET SA2.CET SASM.CET TT4C.CET TTS~.CET WFSN.CET SA6.CET TIME.CET WF3.CET WFI1.GEI GR.CET DTT4.CET DTT8.CET AIT3.CET AITT.CET CAL2.GET IEMX.CET IE2.CET IR6.CET OVAL.CET AGT1.CET AGT2.CET AGT3.CET 3970.~00 0.591 0.711 0.603 1.458 1.061 1.003 2443.649 0.893 0 574 0 576 0 691 0 608 15 000 18 000 18 000 1638 667 1685 938 4213 734 7 158 241 699 5 668 0 426 3 067 8.981 13~8.892 8.981 56.000 288.400 639.506 17.472 7.635 231.500 378.000 12~3.673 66.615 986.000 -1474 -1400 33 770 61 487 58 037 4 110 4 558 6 185 3.121 3.080 3.105 ~.~49 15.000 15.000 17.~ LIS Tape Verification Listing Schlumberger Alaska Computing Center W1TS.CET 1856.375 W2T3.CET WlT4.CET 1608.250 W2T4.CET W1TS.CET 1842,875 W2TS.CET W1T6.CET 1580.000 W2T6.CET W1T7.CET 1772.250 W2T7.CET W1TS.CET 1936.000 W2TS.CET WITg. CET 1797.000 W2Tg. CET CCL.CET -0.e02 2A.CET 7-NOV-1995 15:33 115[.500 W3T3.£ET 1178.500 W3T4.CET 945.125 W3TS.¢ET 757.000 W3T6.CET 956.125 W3T7.CET 1169.625 W3T8.CET 185.500 1A.CET 164.313 RCCL.CET 1273.000 1856.875 1093.500 978.750 1246.250 1657.125 328.688 -0.002 AGT4.CET AGTS.CET AGT6.CET AGT7.CET AGT8.CET AGTg. CET W3Tg.CET PAGE: 22.000 18.000 17.000 14.000 16.000 18.000 349.250 ** END OF DATA ** **** FILE TRAILER FILE NAME : CET .131 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER FILE NAME : CET .132 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 3748 4 66 1 5 66 6 73 0 7 65 IN 8 73 60 9 65 .lIN 11 66 2 12 68 -99g. 13 66 1 14 65 .lin LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:33 PAGE: 18 TYPE REPR CODE VALUE 15 66 73 16 66 0 66 SET TYPE - CHAN ~* NAME SERV UNIT SERVICE APl APl APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS CET IN 80 282 01 0 194 1 I 4 68 9999999999 CS CET F/HR 89 636 21 9 194 1 1 4 68 9999999999 CVEL CET F/MN 89 636 99 9 194 1 1 4 68 9999999999 TENS CET LBF 89 635 21 9 194 1 1 4 68 9999999999 ETIM CET S 89 636 21 9 194 1 1 4 68 9999999999 MARK CET F 89 159 91 9 194 1 1 4 68 9999999999 BIND CET 89 999 99 9 194 1 1 4 68 9999999999 CWWM CET 89 999 99 9 194 1 1 4 68 9999999999 W2R1 CET 89 999 99 9 194 1 1 4 68 9999999999 W2R2 CET 89 999 99 9 194 1 1 4 68 9999999999 W2R3 CET 89 999 99 9 194 1 1 4 68 9999999999 W2R4 CET 89 999 99 9 194 1 I 4 68 9999999999 W2R5 CET 89 999 99 9 194 I 1 4 68 9999999999 W2R6 CET 89 990 99 9 194 1 I 4 68 9999999999 W2R7 CET 89 999 99 9 194 1 1 4 68 9999999999 W2R8 CET 89 999 09 9 194 1 1 4 68 9999999999 W3R1CET 89 999 99 9 194 1 1 4 68 9999999999 W3R2 CET 89 999 99 9 194 1 1 4 68 9999099999 W3R3 CET 89 999 99 9 194 1 1 4 68 9999999999 W3R4 CET 89 999 99 9 194 1 1 4 68 9999999999 W3R5 CET 89 999 99 9 194 1 1 4 68 9999999999 W3R6 CET 89 990 99 9 194 1 1 4 68 0999999999 W3R7 CET 89 999 99 9 194 1 1 4 68 9999999999 W3R8 CET 89 990 99 9 194 1 1 4 68 9999999999 CW2L CET 89 999 99 9 194 1 1 4 68 9999999999 CW2H CET 89 999 99 9 194 1 1 4 68 99~9999999 CW3L CET 89 999 99 9 194 1 1 4 68 9099999909 CW3H CET 89 990 0~ 9 194 1 1 4 68 9999990999 CW2X CET 8~ 990 99 9 194 1 1 4 68 9999999999 CW3X CET 80 ~90 00 0 ~94- 1 1 4 68 900~000000 MNCS CET PSI 80 990 09 9 194 1 1 4 68 9909990099 MXCS CET PSI 80 90~ 90 9 1~4 1 1 4 68 9009909999 W2RA CET 89 990 90 0 194 ~ 1 4 68 9909099009 W3RA CET 80 900 99 9 194 1 1 4 68 9999999999 FRGI CET 80 900 00 9 194 1 1 4 68 9999999999 GOCI CET 89 909 99 9 194 1 1 4 68 9999999999 GGCI CET 89 900 90 9 194 1 1 4 68 9999999999 AW21 CET 89 999 99 9 104 1 1 4 68 9999999999 AW22 CET 80 999 99 9 194 1 1 4 68 9999999999 AW23 CET 80 900 90 9 194 1 1 4 68 9999999999 AW24 CET 89 990 99 9 194 1 1 4 68 9999990999 AW25 CET 89 990 99 9 194 1 1 4 68 9999999999 LIS Tape Ver|f|ca%ion L|s%ing Schlumberger Alaska Compu~|ng Cen~er 7-NOV-1995 15:33 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AW26 CET 80 000 00 AW27 CET 8e 000 00 AW28 CET 8e 000 00 AW29 CET 8~ ~00 00 AW3~ CET 8~ 000 00 AW32 CET 8~ 000 00 AW33 CET 80 000 00 AW34 CET 8e 000 00 AW35 CET 8e 000 00 AW36 CET 80 000 00 AW37 CET 80 000 00 AW38 CET 8e 000 00 AW39 CET 80 000 eO AAG[ CET 8e 000 Oe AAG2 CET 8e 000 00 AAG3 CET 80 e00 00 AAG4 CET 80 000 eO AAG5 CET 80 e00 00 AAG6 CET 8e 000 00 AAQ7 CET 8e 000 eO AAG$ CET 8~ 000 00 AAG9 CET 8e 000 00 AW[[ CET 8~ Oe~ 00 AWl2 CET 8e e00 Oe AWl3 CET 80 000 00 AWl4 CET 80 000 00 AWl5 CET 8e 0e0 Oe AWl6 CET 80 ~0~ 00 AWl7 CET 80 000 Oe AW~8 CET 80 0~0 00 AWl9 £ET 80 0~0 00 BLPR CET 8e e00 00 CSMN CET PSI 8~ 000 00 CSMX CET PSI 8~ 00~ 00 RB CET DEG 8~ 631 11 DEVI CET DEG 80 620 11 LATT CET DB/F 8~ ~Oe 0~ UATT CET DB/F 80 0e0 00 BATT CET DB/F 80 600 66 R$2R CET DB/F 80 00~ 00 DT CET US/F 8~ 060 00 DTMD CET US/F 80 000 06 FLSA CET 8e 000 00 FLTT CET 8~ 00~ 00 ULTR CET DB/F 80 060 06 SATN CET DB/F 8~ 060 00 SBI CET 8~ 0~ 00 SCBL CET MV 8~ 000 00 NATN CET DB/F 80 000 00 NBI CET 80 000 00 NCBL CET MV 80 000 06 104 1 1 4 68 0~00000000 164 1 1 4 68 606~000000 164 1 1 4 68 0000000000 104 1 1 4 68 0000000000 104 1 1 4 68 0000000000 104 1 1 4 68 0000000000 164 1 1 4 68 oeooe60000 104 1 1 4 68 0000000000 164 1 1 4 68 000000e000 104 1 1 4 68 0000000000 104 1 1 4 68 0000000000 104 1 1 4 68 0000000000 164 1 1 4 68 0000000e00 104 1 1 4 68 0000000~00 104 1 1 4 68 6000000000 104 1 1 4 68 0~00000000 164 1 1 4 68 0000060000 104 1 1 4 68 00eoO600eO 104 1 1 4 68 0000000000 104 1 1 4 68 0000000000 104 1 I 4 68 0000060000 104 [ 1 4 68 0000~60000 104 1 1 4 68 0600000000 104 1 1 4 68 0600060600 164 1 1 4 68 6006060S00 164 1 1 4 68 0000000000 164 1 1 4 68 0000000000 164 1 1 4 68 6660e60066 164 1 1 4 68 0000060000 104 1 1 4 68 600eoe0000 164 1 1 4 68 6600000060 104 1 1 4 68 000e000000 104 1 1 4 68 00e~000000 164 Z 1 4 68 606e000~06 104 1 1 4 68 000~6000~ 164 1 1 4, 68 6066066666 164 1 1 4 68 0600060006 164 1 1 4 68 ~600060000 104 1 1 4 68 06600600~0 164 1 1 4 68 0000000000 164 1 1 4 68 6~0060066 104 1 1 4 68 0606060000 104 1 1 4 68 0060060000 104 1 1 4 68 0000000~00 164 1 1 4 68 6660~00066 164 1 1 4 68 0000000000 104 1 1 4 68 0000~00000 104 1 1 4 68 000~0~0000 LIS Tape Yeti{ica%ion Li$%ing Schlumberger Alaska Computing CenSer 7-NOV-1995 15:$$ PAGE: 20 NAME SERV UNZT SERVICE APZ API API API FZLE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DATN CET DB/F DBI CET DCBL CET MV NFPI CET MV SFPI CET MV BATM CET DB/F UATM CET DB/F LATM CET DB/F BILI CET GOBO CET MV UTVO CET V LTVO CET V MNLV CET MV DNLV CET MV RUAM CET DB/F RLAM CET DB/F RUAT CET DB/F RLAT CET DB/F DTUM CET US/F DTLM CET US/F DTUT CET US/F DTLT CET US/F TT1M CET US TT1C CET US SA1M CET MV SA1 CET MV WF1N CET TT2M CET US TT2C CET US SA2M CET MV SA2 CET MV WF2N CET [ TT3M CET US , TT3C CET US SA3M CET MV SA3 CET MV WF3N CET TT4M CET US TT4C CET US SA4M CET MV SA4 CET MV WF4N CET TTSM CET US TTSC CET US SASM CET MV SA5 CET MV WFSN CET TT6M CET US TT6C CET US SA6M CET MV SA6 CET MV 80 000 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~ 00 0 ~04 1 I 4 80 0~0 00 0 104 1 1 4 80 000 00 0 ~04 1 1 4 80 0~0 00 0 1~4 1 1 4 80 000 00 0 104 1 1 4 $0 0~0 00 ~ 104 1 1 4 80 ~ 00 0 104 1 1 4 80 0~ 0~ ~ 104 1 1 4 8~ 000 00 0 104 1 1 4 80 0~ 00 0 104 1 1 4 8~ ~0 00 0 104 1 1 4 80 ~0 00 0 1~4 1 1 4 80 0~0 ~ 0 104 1 1 4 80 0~ 0~ 0 1~4 1 1 4 8~ ~0 00 0 104 1 1 4 80 0~ 00 ~ 1~4 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 8~ ~ ~ ~ 1~4 1 1 4 8~ ~ ~ 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 0~ 0~ 0 104 1 1 4 80 00~ 00 0 104 1 1 4 8~ 0~0 00 0 104 1 1 4 80 0~0 0~ ~ 1~4 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 8~ ~0 00 0 104 1 1 4 80 0~0 00 ~ 104 1 1 4 80 00~ 00 ~ 104 ! 1 4 80 0~0 00 ~ 104 1 1 4 80 0~0 0~ 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 00~ 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 000 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~0 00 0 104 1 1 4 80 0~ 00 0 104 1 1 4 8~ ~0 ~0 ~ 1~4 1 1 4 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 7-NOV-3.995 3.5:33 PAGE: 23. NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) WF6N CET 80 000 00 HV CET V 80 000 00 RGR CET GAPI 80 000 00 TIME CET MS 80 636 21 SSLT CET 80 000 00 WF! CET 80 000 00 WF2 CET 80 000 00 WF3 CET 80 000 00 WF4 CET 80 900 99 WF5 CET 89 999 99 WF6 CET 89 999 99 WFI1CET 89 999 99 WFI2 CET 89 999 99 WFI3 CET 89 999 99 CTEM CET DEGF 80 909 99 GR CET GAPI 89 999 99 DTT1CET US 89 999 99 DTT2 CET US 89 999 99 DTT3 CET US 80 999 99 DTT4 CET US 89 999 99 DTT5 CET US 89 999 99 DTT6 CET US 89 999 99 DTT7 CET US 89 999 99 DTT8 CET US 89 999 99 DTT9 CET US 89 999 09 AIT1 CET 80 999 90 AIT2 CET 89 999 99 AIT3 CET 89 999 00 AIT4 CET 80 999 99 AIT5 CET 80 999 99 AIT6 CET 89 999 99 AIT7 CET 89 999 00 AIT8 CET 89 909 09 CALU CET IN 89 999 09 CALl CET IN 89 289 59 CAL2 CET IN 89 289 59 CAL3 CET IN 89 289 59 CAL4 CET IN 89 289 59 FVEL CET US/F 80 00~ 00 IRMX CET IN 89 280 59 IRMN CET IN 89 280 50 IRAV CET IN 80 280 50 IR1 CET IN 80 280 50 IR2 CET IN 80 280 50 IR3 CET IN 80 280 50 IR4 CET IN 80 280 50 IR5 CET IN 80 280 59 IR6 CET IN 80 280 59 IR7 CET IN 89 280 50 IR8 CET IN 80 280 59 MATT CET DB/M 80 009 00 194 1 1 4 68 9909090990 104 1 1 4 68 9090900990 104 1 1 4 68 0009909999 104 1 1 4 68 9999999090 194 3. 1 4 73 9099099990 104 1 129 240 79 9099099990 104 1 129 249 79 0099999990 194 1 129 249 79 9909999990 104 1 120 240 79 9009090990 104 1 120 249 79 9909999090 104 1 129 249 79 0909999990 104 1 129 249 79 0909909090 194 1 120 249 79 0909099990 194 ~ 12~ 240 79 9999909990 104 1 1 4 68 0999099990 104 1 1 4 68 0000990990 104 3 1 12 68 0009909990 104 3 1 12 68 0009990990 104 3 1 12 68 0009909990 104 3 I 12 68 0999999990 104 3 1 12 68 9099909999 104 3 1 12 68 0009999990 104 3 1 12 68 9090900090 104 3 I 12 68 0000000990 194 3 ! 12 68 0000999090 194 3 1 12 68 9900900990 104 3 1 12 68 0000000900 104 3 1 12 68 0000090990 104 3 1 12 68 0009099090 104 3 1 12 68 0090900990 104 3 1 12 68 0009000990 194 3 1 12 68 0~900~9900 194 3 1 12 68 0090090090 104 3 1 12 68 0000999090 104 3 1 12 68 0999900900 104 3 1 12 68 9099909090 104 3 ~ 12 68 00~9090900 104 3 ~ 12 68 09009~0900 104 3 ~ 12 68 00000000~0 104 3 1 12 68 000~geOOOe 104 3 ~ 12 68 00000000~0 104 3 1 12 68 0000000000 104 3 ~ 12 68 0000000~00 104 3 1 12 68 0000000~00 ~04 3 1 12 68 0000000090 104 3 1 12 68 0000000000 104 3 1 12 68 0000000000 104 3 1 12 68 0000000090 ~04 3 1 3.2 68 0000900000 104 3 3. 12 68 0000000~ 104 3 1 12 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-1995 15:33 PAGE: 22 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) OVAL £ET IN W2F9 CET W3F9 CET CCLU CET AGT1CET DB WlT1CET W2T1CET W3T1CET AGT2 CET DB WlT2 CET W2T2 CET W3T2 CET AGT3 CET DB WlT3 CET W2T3 CET W3T3 CET AGT4 CET DB W1T4 CET W2T4 CET W3T4 CET AGT5 CET DB W1T5 CET W2T5 CET W3T5 CET AGT6 CET DB W1T6 CET W2T6 CET W3T6 CET AGT7 CET DB W1T7 CET W2T7 CET W3T7 CET AGT8 CET DB W1T8 CET W2T8 CET W3T8 CET AGT9 CET DB WlT9 CET W2T9 CET lA CET MS W3T9 CET CCL CET 2A CET MS RCCL CET 80 0~0 00 0 104 3 80 000 00 0 104 3 80 000 00 ~ 104 3 80 000 00 0 [04 3 80 000 00 0 104 3 80 000 00 0 104 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 89 999 99 9 194 89 999 99 9 194 3 89 999 99 9 104 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 0 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 89 999 99 9 194 3 80 090 ~ ~ 104 3 89 636 21 9 194 3 89 999 99 9 194 3 89 159 91 9 104 6 89 636 21 9 194 6 89 159 91 9 194 6 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9099999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 [2 68 9099999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 [2 68 9999999999 12 68 9990999999 12 68 9999999999 12 68 9999999999 12 68 9999999999 12 68 99999~9999 12 68 9999999999 12 68 9~00909909 12 68 9999999999 12 68 9990999999 24 68 9999929999 24 68 9999999999 24 68 9999929999 DATA ** DEPTH = 7577.909 FEET LIS Tape Verification Listing Schlumberger Alaska Computing Center BS.CET ETIM.CET W2R1.CET W2RS.CET W3R1.CET W3R3.CET CW2L.CET CW2X,CET W2RA,CET GGCI.CET AW24.CET A~28.CET AW33.CET A~3T,CET AAQ2.CET AA~6.CET AWll.CET AW13.CET AW19.CET RB.CET BATT.¢ET FLSA.GET SBI.CET NCBL.CET NFPI.£ET LATM.CET LTVO.CET RLAM.CET DTLM.CET TTIC.CET TT2M.CET WF2N.CET SA3.CET SA4M.CET TTSC.CET TT6M.CET WF6N.CET SSLT.CET WF4.CET WFI2.CET DTT1.CET DTTS.CET DTTg. CET AIT4 CET AIT8 CET CAL3 CET IRMN CET IR3 CET IRT CET W2F9 CET WlT1CET WlT2 CET WlT3 CET WlT4 CET WlT3.CET 8.500 0.090 9.540 0.769 9.841 0.819 0.481 0.481 9.540 0.471 9.462 9.539 9.751 13.999 17.990 1921.625 1662.259 1794.759 49.394 8.992 0 339 4 672 113 798 19 430 1313 140 10 430 33 699 294 999 232 899 539 662 3.887 19.458 334.090 141.699 198.480 36969 -1396 -1448 -999.259 -999.230 -999.250 -999.230 -999.239 -999.259 -999.259 -999.259 -999.259 -999.259 -999.250 -999.250 -999.259 -999.230 -999.259 CS.CET MARK.CET W2R2.CET W2R6.¢ET W3R2.¢ET W3R6.CET CW2H.CET CW3X.CET W3RA.CET AW21.CET AW23.CET AW29.CET AW34.CET AW38.CET AAG3.CET AAG7.CET AWi2.CET AW16.CET BLPR.CET DEVI.CET R32R.CET FLTT.CET SCBL.CET DATN.CET SFPI.CET BILI.CET MNLV.CET RUAT.CET DTUT.¢ET SAIM.CET TT2C.CET TT3M.¢ET WF3N.¢ET SA4.CET SA3M.CET TTbC,CET HV.¢ET WF1.CET WFS.CET WFI3.CET DTT2,CET DTTb,CET AITI,¢ET AIT3.¢ET CALU,CET CAL4,¢ET IRAV.CET IR4.CET IR8.CET W3F9.CET W2T1.CET W2T2.CET W2T3.CET W2T4.CET W2T3.CET 7-NOV-1995 15:33 928.553 0.000 0.844 0.629 9.789 0.865 0.769 0.789 0.841 9.518 9.738 9.995 0.932 0,638 16.099 13.099 1718.259 1680.750 1.090 3.743 2.139 7.822 8.902 139.199 9.899 2.739 5.864 62.999 5.071 232.999 296 499 1797 641 12 494 I 924 149 599 237 750 -1490 -1489 -1448 -999.250 -999.239 -999.25~ -999.259 -999.250 -999.250 -999.259 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CVEL CET BIND CET W2R3 CET W2R7 CET W3R3 GET W3R7 GET CW3L CET MNCS.CET FRGI.CET AW22.CET AW26 CET AW31CET AW33 CET AW39 CET AAG4 CET AAG8 CET AW13 GET AWl7 CET CSMN.CET LATT.CET DT.CET ULTR.CET NATN.CET DBI.CET BATM.CET GOBO.CET DNLV CET RLAT CET DTLT CET SA1CET SA2M GET TT3C CET TT4M GET WF4N CET SA5 CET SA6M.CET RGR.CET WF2.CET WF6.CET CTEM.CET DTT3.CET DTT7.CET AIT2.CET AIT6.CET CAL1.CET FVEL CET IR1CET IR5 CET MATT CET CCLU CET W3T1CET W3T2 CET W3T3 CET W3T4 CET W3T5 CET -15.476 19.395 9.292 9.481 9.680 9. 963 9.789 9.990 9.810 9. 694 9.636 9.639 9.189 22.999 15.990 1626.375 1653.399 3231.731 19.141 59.990 2.373 7.528 9.533 7.990 2.999 19.141 56.999 6.335 9.607 295.999 249.809 539.662 [.252 53.436 37.333 -1444 -1462 148.199 -999.250 -999.259 -999.250 -999.250 -999.259 -999.259 -999.259 -999.259 -999.259 -999.259 -999.250 -999.230 -999.250 -999.250 -999.259 TENS.CET CWWM.CET W2R4.CET W2RS.CET W3R4.CET W3RS.CET CW3H.CET MXCS.CET GOCI.CET AW23.CET AW27.¢ET AW32.CET AW36.CET AAG1.CET AAG3.CET AAGg. CET AW14.CET AW18.CET CSMX.CET UATT.CET DTMD.CET SATN.CET NBI.CET DCBL.CET UATM.CET UTVO,CET RUAM.CET DTUM.CET TTIM,CET WFIN.CET SA2.CET SA3M.CET TT4C,CET TTSM.CET WF3N.CET SA6.CET TIME,CET WF3.CET WF[1.CET GR.CET DTT4.CET DTTS.¢ET A[T3.CET AIT7.CET CAL2.CET [RMX.CET [R2.CET [R6.CET OVAL.CET AGTI.CET AGT2.CET AGT3.CET AGT4.CET AGTS.CET AGT6.CET PAGE: 23 1715.090 0.566 e.499 0.481 1.196 0.818 0.963 4595.496 1.999 9.259 0.462 0.613 0.673 17.999 18.090 18 999 1798 125 1610 759 5665 957 3 864 247 042 9.392 3.933 5.550 15i3.14e 5.550 62.49~ 295.290 984.946 12.835 3.i47 239.~9o 385.690 328o.991 64.986 -1458 -1448 36.652 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-NOV-199~ 1~:33 WlT6,¢ET -999,250 W2T6,CET -999,250 W3T6,¢ET -999,250 WlTT.¢ET -999.250 W2TT,CET -999,250 W3TT.CET -999.250 WlTS,¢ET -999,250 W2TS.CET -999,250 W3T8,CET -999,250 WlTg,CET -999,25e W2T9,CET -999,250 1A,CET -999,250 CCL.CET -999,250 2A.CET -999,250 RCCL.CET -999,250 DEPTH = 4877,500 FEET ¢S.CET MARK.CET W2R2.CET W2R6.CET W3R2.CET W3R6.CET CW2H.CET CW3X.CET W3RA.CET AW21.CET AW25.CET AW29.CET AW34.CET AW38.CET AAG3.CET AAGT.CET AW12.CET AW16.CET BLPR.CET DEV~.CET R32R.CET FLTT.CET SCBL.CET DATN.CET SFP~.CET BILI.CET MNLV.CET RUAT,CET DTUT,CET SAIM.CET TT2C.CET TT3M,CET WF3N.CET SA4.CET SASM.CET TT6C.CET HV,CET WF1.CET WFS,CET WFI3 CET DTT2 CET DTT6 CET AIT1CET AIT5 CET CALU CET CAL4 CET IRAV CET BS.CET 8,50S ETIM,CET 5356,689 W2R1,CET 0,984 W2RS,CET 0,929 W3R1,CET 1,042 W3RS,CET 1,053 CW2L,CET 0,764 CW2X,CET 0,921 W2RA,CET 0,921 GGCI,CET 0,339 AW24,CET 0,729 AW28,CET 0,461 AW33,CET 0.835 AW37,CET 0.871 AAG2.CET 16.~0 AAG6.CET 19.~00 AW11.CET 1727.625 AW15.CET 1643.708 AW19.CET 1599.458 RB.CET 333.015 BATT.CET 4.719 FLSA.CET 0.000 SBI.CET 0.241 NCBL.CET 8.7~9 NFPI.CET 74,253 LATM,CET 5,286 LTVO.CET 1530.769 RLAM.CET 5.286 DTLM,CET 56.909 TTIC.CET 289.999 TT2M.CET 233.699 WF2N.CET 295.687 SA3.CET 12.198 SA4~.CET 17.091 TTSC.CET 377.590 TT6~.CET 142.890 WF6N.CET 108.489 SSLT.CET 42695 WF4.CET -1412 WFI2.CET -1464 DTTI.CET 61.959 DTT5.CET 58.699 DTTg. CET 52.700 AIT4.CET 3.621 AITS.CET 4.783 CAL3.CET 6.201 IRMN.CET 3.042 1794.901 0.000 0.661 1.911 1.167 1.117 0.921 1.193 1.445 0,944 0,892 1,238 0,651 1797,167 1890.900 0,639 21.822 9,641 14,849 4,719 113,793 9.8~0 2.819 4.978 56,250 8 594 232 750 289 29e 539 662 23 186 3 794. 141 509 249,999 -1442 -1489 -1432 61.237 58.725 2.877 2,361 6.191 6.296 3,095 CVEL.CET BIND.CET W2R3.¢ET W2R7.CET W3R3.CET W3R7.CET CW3L.CET MNCS.CET FRGI.CET AW22.CET AW26.CET AW31.CET AW35.CET AW39.CET AAG4.CET AAGS.CET AW13.CET AW17.CET CSMN.CET LATT.CET DT.CET ULTR.CET NATN.CET DBI.CET BAT~.CET GOBO.CET DNLV.CET RLAT.CET DTLT.CET SAI.CET SA2~.CET TT3C.CET TT4M.CET WF4N.CET SAS.CET SA6M.CET RGR.CET WF2.CET WF6.CET CTEM.CET DTT3.CET DTTT.CET AIT2.CET AIT6.CET CAL1.CET FVEL.CET IR1.CET -29.915 2.143 1.915 0.945 1.~70 1.116 0.936 0.~00 0.634 0.971 0.813 0.821 9.150 15.~90 1676.667 1675.417 566.423 5.369 56,375 -0,656 5.811 0,315 4,766 2,990 5,369 56.599 11.861 17.114 288.500 233.299 295.687 5,238 75,498 39,150 -1428 -1430 61,550 59,369 3,546 2,439 6.188 185.563 3.~77 AGT7.CET AGT8.CET AGT9.CET W3T9.CET TENS.CET CWWM.CET W2R4.CET W2R8.CET W3R4.CET W3R8.CET CW3H.CET MXCS.CET GO¢I.CET AW23.CET AW27.CET AW32.CET AW36.CET AAGI.¢ET AAGS.CET AAG9.CET AW14.CET AW18.CET CSMX.CET UATT.CET DTMD.CET SATN.CET NBI.CET DCBL CET UATM CET UTVO CET RUAM CET DTUM CET TT1M CET WF1N.¢ET SA2.CET SA3~.CET TT4C.CET TTS~.¢ET WFSN.¢ET SA6.CET TIME.CET WF3.CET WFI1.CET GR.CET DTT4.CET DTTS.CET AIT3.CET AITT.CET CAL2.CET IRMX.CET IR2.CET PAGE: 24 -999,250 -999,250 -999,250 -999.250 2745.000 ~.848 0.759 0.480 1.588 0.835 1.103 1799.872 0.339 0.974 0.907 ~.91~ 0.871 15.900 18.000 18.~00 1866.333 1714.583 3347.511 4.978 242.736 4,336 0,387 12.918 4.245 153~.760 4.245 56.299 539.662 20.591 9.~99 232.9~9 378.499 1470.978 74.944 1002.990 -1442 -1416 34.064 69.325 60.737 2.231 2.844 6.169 3.127 3.~42 LIS Tape Verifica~,ion List, ing Schlumberger Alaska Comput~ing Cent, er IR3.CET 3.088 IR4.CET IR7.CET 3.112 IR8.CET W2F9.CET 1.~00 W3F9.CET W1TI.CET 1724.$00 W2T1,CET W1T2.CET 1711.250 W2T2.CET W1T3.CET 1649.000 W2T3.CET W1T4.CET 1922.000 W2T4.CET WITS.CET 1629.250 W2TS.CET WlT6.CET 1902.250 W2T6.CET WlT7.CET 1674.875 W2T7.CET W1TS.CET 1699.000 W2TS.CET WlT9.CET 1~99.875 W2T9.CET CCL.CET -9.~21 2A.CET END OF DATA 7-NOV-1995 15:33 3.112 IRS.CET 3.094 MATT.CET 1.000 CCLU.CET 1571.500 W3TI.CET 1265.750 W3T2.CET 1837.75~ W3T3.CET 1388.875 W3T4.CET 1743.625 W3TS.CET 1987.250 W3T6.CET 1542.000 W3T7.CET 854.375 W3TS.CET 154.500 1A.CET 167.000 RCCL.CET 3.110 -10.647 -0.001 1414.25~ 1617.750 1458.875 2383.875 1481.875 1706.000 1453.625 1132.875 334.000 -0.019 IR6.CET OVAL.CET AGT1.CET AGT2.CET AGT3.CET AGT4.CET AGTS.CET AGT6.CET AGT7.CET AGTS.CET AGTg.CET W3Tg.CET PAGE: 25 3.127 0.036 15.000 16.990 17.0e0 23.090 18.990 19.000 15.~00 **** FILE TRAILER FILE NAME :CET .132 SERVICE : PLAYBA VERSION : 7C9-427 DATE : 95/M9/27 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** TAPE TRAILER SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** REEL TRAILER SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY ALASKA COMPUTING CENTER · · ....... SCHLUMBERGER COMPANY NAME : MARATHON OIL COMPANY WELL NAME : KBU 31-7RD FIELD NAME : KENAI GAS FIELD BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-133-20347 REFERENCE NO : 95352 RECEIVED Ataska Oi~ & ,3as go'~s, Oommissir,~, LIS Tape Verification Listing Schlumberger Alaska Computing Eenter 8-NOV-1995 13:49 **** REEL HEADER *~ SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION ~ : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY *~ TAPE HEADER *~ SERVICE NAME : CSNAM DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY PAGE: **** FILE HEADER **** FILE NAME : SPEA .036 SERVICE : PLAYBA VERSION : 7C~-427 DATE : 95/09/20 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 79 1960 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 4 12 68 -999. 13 66 14 65 .lin 15 66 73 16 66 1 ~ 66 LIS Tape Verification L|st|ng Schlumberger Alaska Computing £en~er SET TYPE - CHAN ** 8-NOV-1995 13:49 PAGE: NAME SERV UNIT SERVICE AP1 aPI AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CS SPEA F/HR TENS SPEA LBF IHV SPEA F3 SP SPEA MV RSP SPEA MV RT SPEA OHMM RXO SPEA OHMM I'IT SPEA S SNR2 SPEA DB PR SPEA CHR2 SPEA ENR2 SPEA DB TER2 SPEA US CER2 SPEA LFR2 SPEA EER2 SPEA DB DT2R SPEA US/F TTR2 SPEA US DTRP SPEA US/F TTRP SPEA US CHRP SPEA ENRP SPEA DB TERP SPEA US CERP SPEA EERP SPEA DB LFRP SPEA DTRS SPEA US/F TTRS SPEA US CHRS SPEA ENRS SPEA DB TERS SPEA US CERS SPEA EERS SPEA DB LFRS SPEA DT2 SPEA US/F DT4P SPEA US/F DT4S SPEA US/F HTEN SPEA LBF MRES SPEA OHMM ASFI SPEA MV TIME SPEA MS GTEM SPEA DEGF MTEM SPEA DEGF SPHI SPEA PU C[R2 SPEA SIR2 SPEA US/F TlR2 SPEA US EIR2 SPEA DB C2R2 SPEA T2R2 SPEA US 99 636 21 0 24 1 1 4 68 0000e00000 99 635 21 0 24 1 1 4 68 0000000000 99 282 01 0 24 1 ~ 4 68 000000000~ 99 010 01 0 24 1 1 4 68 000~00000 99 010 el 0 24 I 1 4 68 00~0020000 99 935 01 0 24 I I 4 68 ~000000000 99 935 04 0 24 1 I 4 68 ~0~0~000~0 99 529 82 0 24 I I 4 68 00~0000000 99 ~00 00 0 24 1 I 4 68 ~000~00000 99 000 00 0 24 I I 4 68 ~00000000~ 99 000 00 0 24 I I 4 68 ~000~00000 99 000 00 0 24 1 I 4 68 0000000000 99 000 00 0 24 I I 4 68 ~00~00~000 99 000 00 0 24 1 I 4 68 00~0000000 99 000 00 0 24 1 I 4 68 0000000000 99 000 00 0 24 I I 4 68 0000000000 99 520 80 0 24 I 1 4 68 0000000000 99 000 00 0 24 1 I 4 68 ~000000000 99 520 80 0 24 I I 4 68 0000000000 99 000 ~0 0 24 I I 4 68 ~000~000~0 99 000 00 0 24 I I 4 68 ~000000~00 99 000 00 0 24 1 I 4 68 00000000~0 99 000 00 0 24 I I 4 68 0000~00000 99 000 00 0 24 I 1 4 68 ~000000000 99 000 ~0 ~ 24 I 1 4 68 ~0~0~00000 99 000 00 0 24 1 I 4 68 ~0~00000~0 99 520 8~ 0 24 I I 4 68 ~000000000 99 000 00 0 24 1 1 4 68 ~0000000~0 99 000 00 0 24 1 1 4 68 ~000~00000 99 000 00 0 24 ~ 1 4 68 ~000000000 99 000 ~0 0 24 ~ ~ 4 68 ¢000000¢0~ 99 000 00 ~ 24 1 Z 4 68 ¢000000~0¢ 99 000 ~0 0 24 1 ~ 4 68 00000000~0 99 000 00 0 24 ~ ~ 4 68 0000000000 99 520 80 0 24 ~ 1 4 68 000000¢0¢0 99 520 80 0 24 1 1 4 68 00~0000000 99 520 80 0 24 ~ ~ 4 68 0000000¢00 99 000 ~0 0 24 ~ 1 4 68 ¢0¢0¢00¢00 99 000 ~0 0 24 ! ~ 4 68 ~000000000 99 0¢0 ~0 0 24 ~ ~ 4 68 0000000000 99 636 21 0 24 ~ ~ 4 68 ~000000000 99 660 00 0 24 1 1 4 68 0000000000 99 000 00 0 24 ~ 1 4 68 ¢0¢00¢0000 99 890 01 0 24 ~ 1 4 68 0000000~00 99 000 00 ¢ 24 Z ~6 64 68 0000000000 99 000 00 0 24 1 16 64 68 0000¢00000 99 ¢00 00 0 24 1 16 64 68 0~000~00 99 000 ~0 0 24 1 %6 64 68 0000¢00000 99 0¢0 00 ~ 24 Z ~6 64 68 ~0~0000000 99 000 00 0 24 1 16 64 68 ~0¢000~00 LIS Tape Ver|fication Listing Schlumberger Alaska Comp-uting £enter 8-NOV-1995 13:49 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) E2R2 SPEA DB 99 000 00 0 24 1 16 64 68 0090009000 SPR2 SPEA 99 999 99 9 24 1 191 494 68 9999999999 NPR4 SPEA 99 999 99 9 24 1 1 4 73 9999999999 C1R4 SPEA 99 999 99 9 24 1 16 64 68 9999999999 S1R4 SPEA US/F 99 999 99 9 24 1 16 64 68 9999999999 TlR4 SPEA US 99 999 99 9 24 1 16 64 68 9999999999 E1R4 SPEA DB 99 999 99 9 24 1 16 64 68 9999999990 C2R4 SPEA 99 999 99 9 24 1 16 64 68 9999999999 T2R4 SPEA US 99 999 99 9 24 1 16 64 68 9999999999 E2R4 SPEA DB 99 999 99 9 24 1 16 64 68 9999999999 SPR4 SPEA 99 999 99 9 24 1 ?1 284 68 9999999999 GR SPEA GAPI 99 999 99 9 24 1 1 4 68 9999999999 la SPEA MS 99 636 21 9 24 3 1 12 68 9999999999 HGR SPEA GAPI 99 999 99 9 24 3 1 12 68 9999999999 A029 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 A039 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 A069 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 A099 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AT19 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AT29 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AT39 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AT69 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AT99 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999990 AFl9 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999~99999 AF2~ SPEA OHMM 99 999 99 ~ 24 2 1 8 68 9999999999 AF39 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999990990 AF69 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999909999 AF90 SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AFRT SPEA OHMM 99 999 99 9 24 2 I 8 68 9999099999 AFRX SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AORT SPEA OHMM 99 999 99 9 24 2 1 8 68 9999999999 AORX SPEA OHMM 99 999 99 9 24 2 1 8 68 9909099999 ATRT SPEA OHMM 99 999 99 9 24 2 1 8 68 999999~999 2A SPEA MS 99 636 21 9 24 2 1 8 68 9999999990 ATRX SPEA OHMM 99 99~ 99 0 24 2 1 8 68 9999990999 DATA CS.SPEA RSP.SPEA SNR2.SPEA TER2 SPEA DT2R SPEA CHRP SPEA EERP SPEA CHRS SPEA EERS SPEA DEPTH = 7517.599 FEET 813.375 TENS.SPEA 4120.999 IHV.SPEA 9.999 SP.SPEA -154.438 RT.SPEA 35.129 RXO.SPEA -999.259 ITT,SPEA 59.686 PR.SPEA -999,259 CHR2.SPEA 9.947 ENR2.SPEA 3299.999 CER2,SPEA 9.894 LFR2,SPEA 9.999 EER2.SPEA 189.941 TTR2.SPEA 2699,999 DTRP.SPEA 97.351 TTRP.SPEA 0.799 ENRP,SPEA 2,932 TERP,SPEA 1299.999 CERP.SPEA 17.323 LFRP,SPEA 9.999 DTRS.SPEA -999.259 TTRS.SPEA 9.999 ENRS.SPEA -999.259 TERS.SPEA -999.259 CERS.SPEA -999.259 LFRS,SPEA 10.999 DT2.SPEA 138.723 DT4P.SPEA 9.999 9.999 22.986 33.996 ~.667 -999.259 97.351 LIS Tape Ver|~ication List|ng Schlumberger Alaska Computing ~en~er DT4S.SPEA -999.250 TIME.SPEA 0.000 C1R2.SPEA 0.947 C2R2.SPEA 0.804 NPR4.SPEA E1R4.SPEA 2.032 SPR4.SPEA 33.324 AO20.SPEA -999.250 AT10.SPEA -999.250 AT90,SPEA -999,250 AF60,SPEA -999.250 AORT,SPEA -999.250 ATRX.SPEA -999.250 HTEN.SPEA GTEM.SPEA S1R2 SPEA T2R2 SPEA C1R4 SPEA C2R4 SPEA GR SPEA A030 SPEA AT20.SPEA AF10.SPEA AF90.SPEA AORX.SPEA DEPTH = 6990.50~ FEET 8-NOV-1995 13:49 1011.959 MRES.SPEA 0.061 108.914 MTEM.SPEA 108.914 180.041 T1R2.SPEA 2600.0~0 3200.000 E2R2.SPEA 33.006 0,790 S1R4.SPEA 97.351 0.667 T2R4.SPEA 1200.000 67.510 1A.SPEA -999.250 -999.250 AO60.SPEA -999,250 -999,250 AT30.SPEA -999,250 -999.250 AF20.SPEA -999,250 -999.250 AFRT.SPEA -999.250 -999.250 ATRT.SPEA -999,250 CS.SPEA 863.575 TENS.SPEA 4790.000 IHV.SPEA RSP.SPEA -143.563 RT.SPEA 14.639 RXO.SPEA SNR2.SPEA 44.470 PR.SPEA 0.193 CHR2.SPEA TER2.SPEA 3400.000 CER2.SPEA 0.884 LFR2.SPEA DT2R.SPEA 160.914 TTR2.SPEA 2800.000 DTRP.SPEA CHRP.SPEA 0.926 ENRP.SPEA 23.836 TERP.SPEA EERP.SPEA 32.480 LFRP.SPEA 0.000 DTRS.SPEA CHRS.SPEA 0.000 ENRS.SPEA -999.250 TERS.SPEA EERS.SPEA -999.250 LFRS.SPEA -5.000 DT2.SPEA DT4S,SPEA 157.484 HTEN,SPEA 1769.771 MRES,SPEA TIME.SPEA 2079.500 GTEM.SPEA 108.683 MTEM.SPEA C1R2,SPEA 0,962 S1R2,SPEA 175.432 T1R2.SPEA C2R2,SPEA 0,769 T2R2.SPEA 3800.000 E2R2.SPEA NPR4.SPEA 2 C1R4,SPEA 0.982 S1R4.SPEA E1R4,SPEA 20,952 C2R4.SPEA 0,925 T2R4.SPEA SPR4.SPEA 23.135 GR.SPEA 72.320 1A.SPEA AO20,SPEA 12.861 AO3e,SPEA 7.992 AO60.SPEA AT10,SPEA 13,454 AT20,SPEA 12,652 AT30.SPEA AT90,SPEA 8,033 AF10,SPEA 12.281 AF20.SPEA AF60,SPEA 12.585 AF90.SPEA 11,984 AFRT.SPEA AORT,SPEA 3,836 AORX.SPEA 11.164 ATRT,SPEA ATRX.SPEA 10.875 END OF DATA 162.045 -999.250 0.954 0.000 98.541 1350.0~0 164.344 -999.250 163.628 0.062 108.556 3200.~00 24.182 87 136 130~ 000 693 250 3 667 7 297 11 737 12 400 8.967 ASFI.SPEA SPHI.SPEA E1R2.SPEA SPR2.SPEA T1R4.SPEA E2R4.SPEA HGR.SPEA AO90,SPEA AT60.SPEA AF30,SPEA AFRX.SPEA 2A.SPEA SP.SPEA ITT.SPEA ENR2.SPEA EER2.SPEA TTRP.SPEA CERP.SPEA TTRS,SPEA CERS.SPEA DT4P.SPEA ASFI,SPEA SPHI,SPEA E1R2,SPEA SPR2.SPEA T1R4.SPEA E2R4.SPEA HGR,SPEA AO90.SPEA AT60,SPEA AF30.SPEA AFRX,SPEA 2A,SPEA PAGE: -0.439 26.548 22.086 30.069 1000.000 17.323 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10.875 0.~48 25.594 35.395 1150.000 0.882 -999.250 97.158 14.401 26.476 23.~77 39.959 110~.000 31.958 76.013 3.619 8.620 7.802 11.713 1039.75~ **** FILE TRAILER FILE NAME : SPEA .036 SERVICE : PLAYBA VERSION : 7C~-427 DATE : 95/09/20 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Eenter ***, FILE HEADER **** FILE NAME : SPEA .038 SERVICE : PLAYBA VERSION : ?C0-427 DATE : 95/09/20 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : 8-NOV-1995 13:49 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~* TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 1960 4 66 1 5 66 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 4 12 68 -999. 13 66 14 65 .lIN 15 66 73 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CS SPEA F/HR TENS SPEA LBF IHV SPEA F$ SP SPEA MV RSP SPEA MV RT SPEA OHMM RXO SPEA OHMM ITT SPEA S SNR2 SPEA DB PR SPEA CHR2 SPEA ENR2 SPEA DB TER2 SPEA US CER2 SPEA 99 636 21 0 26 1 1 4 68 99 635 21 0 26 1 1 4 68 99 282 01 0 26 1 1 4 68 99 010 01 0 26 1 1 4 68 99 010 gl 0 26 1 1 4 68 99 935 01 0 26 1 I 4 68 99 935 04 ~ 26 I 1 4 68 99 529 82 0 26 1 1 4 68 99 000 00 0 26 I 1 4 68 99 ~00 00 0 26 ! 1 4 68 99 000 00 0 26 1 1 4 68 99 000 00 0 26 1 1 4 68 99 000 00 0 26 1 1 4 68 99 000 00 0 26 1 1 4 68 LIS Tape Veri¢ication Listing Schlumberger Alaska Computing Center S-NOV-1995 13:49 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) LFR2 SPEA 99 000 00 0 26 1 1 4 68 0000000000 EER2 SPEA DB 99 000 00 ~ 26 1 1 4 68 0000~00000 DT2R SPEA US/F 99 520 80 0 26 1 I 4 68 0000~00000 TTR2 SPEA US 99 000 00 ~ 26 ~ 1 4 68 0~00~00000 DTRP SPEA US/F 99 520 80 0 26 1 1 4 68 0~0000000 TTRP SPEA US 99 000 00 0 26 ~ 1 4 68 oeooe00~00 CHRP SPEA 99 000 00 0 26 1 ~ 4 68 0000e00000 ENRP SPEA DB 99 000 00 0 26 ~ ! 4 68 0000000000 TERP SPEA US 99 000 00 0 26 [ ~ 4 68 00000~000~ CERP SPEA 99 000 00 0 26 1 I 4 68 o~00eoo~eo EERP SPEA DB 99 000 00 0 26 ~ ~ 4 68 e000000000 LFRP SPEA 99 000 00 0 26 1 ~ 4 68 00eoooooeo DTRS SPEA US/F 99 520 80 0 26 ~ ~ 4 68 0000000000 TTRS SPEA US 99 e00 00 0 26 ~ ~ 4 68 000~00000 CHRS SPEA 99 000 Oe 0 26 1 ~ 4 68 0000000000 ENRS SPEA DB 99 000 00 0 26 ~ ~ 4 68 0000000000 TERS SPEA US 99 000 00 0 26 ! ~ 4 68 0000000~0 CERS SPEA 99 000 eO 0 26 [ ~ 4 68 0000000000 EERS SPEA DB 99 000 00 0 26 ~ [ 4 68 0000000000 LFRS SPEA 99 000 00 0 26 ~ ~ 4 68 0000000000 DT2 SPEA US/F 99 520 80 0 26 1 ~ 4 68 00000~0000 DT4P SPEA US/F 99 520 80 0 26 1 1 4 68 0000~0e000 DT4S SPEA US/F 99 520 80 0 26 1 ~ 4 68 000000e00~ HTEN SPEA LBF 99 0e0 00 0 26 1 ~ 4 68 00000eooee MRES SPEA OH~M 99 000 00 0 26 ~ 1 4 68 00000000e0 ASFI SPEA MV 99 000 00 0 26 ~ ~ 4 68 00000000e0 TIME SPEA MS 99 636 2~ 0 26 ~ 1 4 68 0000000000 GTEM SPEA DEGF 99 660 00 0 26 1 ~ 4 68 0000000000 MTEM SPEA DEGF 99 00~ 00 0 26 1 [ 4 68 00000000e0 SPHI SPEA PU 99 890 0~ 0 26 ~ 1 4 68 0000000000 CIR2 SPEA 99 000 00 0 26 ~ 16 64 68 00000000~0 SIR2 SPEA US/F 99 000 00 0 26 ~ ~6 64 68 0000000000 TIR2 SPEA US 99 000 00 0 26 1 ~6 64 68 0000000000 EIR2 SPEA DB 99 000 00 0 26 ~ 16 64 68 0000000000 C2R2 SPEA 99 000 00 0 26 1 [6 64 68 0000000000 T2R2 SPEA US 99 ~0~ 00 0 26 1 16 64 68 0000000000 E2R2 SPEA DB 99 000 00 0 26 ~ ~6 64 68 00000000e0 SPR2 SPEA 99 000 00 0 26 1 10~ 404 68 00000000e0 NPR4 SPEA 99 0~0 00 0 26 [ ~ 4 73 00000000~ CIR4 SPEA 99 000 00 0 26 1 ~6 64 68 00000~00~0 SIR4 SPEA US/F 99 000 00 0 26 ~ ~6 64 68 00000000~0 TIR4 SPEA US 99 000 00 0 26 1 ~6 64 68 0000000000 E[R4 SPEA DB 99 ~00 00 ~ 26 [ 16 64 68 0000000000 C2R4 SPEA 99 000 00 0 26 1 [6 64 68 0000000000 T2R4 SPEA US 99 000 00 ~ 26 ~ ~6 64 68 00000000~0 E2R4 SPEA DB 99 000 00 0 26 [ 16 64 68 0000000000 SPR4 SPEA 99 000 00 0 26 ~ 71 284 68 0000000000 GR SPEA GAPI 99 0e0 00 0 26 [ 1 4 68 0000e00000 lA SPEA MS 99 636 21 0 26 3 ~ ~2 68 0000000000 HGR SPEA GAPI 99 0e0 00 ~ 26 3 ~ ~2 68 0000000000 A020 SPEA OHMM 99 000 00 0 26 2 1 8 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-NOV-1995 13:49 PAGE: NAME SERV UNIT SERVICE AP1 APl AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) A030 SPEA OHMM 99 000 90 9 26 2 1 8 68 9999999999 A069 SPEA OHMM 99 909 99 9 26 2 1 8 68 9090909909 A099 SPEA OHMM 99 999 99 0 26 2 1 8 68 9999999999 AT10 SPEA OHMM 99 909 99 0 26 2 1 8 68 9999909999 AT29 SPEA OHMM 99 999 99 9 26 2 1 8 68 9999999999 AT39 SPEA OHMM 99 999 99 9 26 2 1 8 68 9999999999 AT69 SPEA OHMM 99 999 90 9 26 2 1 8 68 9990909999 AT99 SPEA OHMM 99 999 99 9 26 2 1 8 68 9999999900 AFl9 SPEA OHMM 99 999 99 0 26 2 1 8 68 9999999999 AF29 SPEA OHMM 99 999 99 9 26 2 1 8 68 9099990999 AF39 SPEA OHMM 99 999 99 9 26 2 1 8 68 9099909999 AF69 SPEA OHMM 99 999 99 0 26 2 1 8 68 9099909999 AF99 SPEA OHMM 99 999 99 9 26 2 1 8 68 9999999999 AFRT SPEA OHMM 99 999 99 9 26 2 1 8 68 9999999999 AFRX SPEA OHMM 99 909 90 9 26 2 I 8 68 9990999999 AORT SPEA OHMM 99 999 90 9 26 2 1 8 68 9999999990 AORX SPEA OHMM 99 909 99 0 26 2 1 8 68 909099999~ ATRT SPEA OHMM 99 999 90 9 26 2 1 8 68 9090999099 2A SPEA MS 99 636 21 0 26 2 1 8 68 9000909000 ATRX SPEA OHMM 99 99~ ~0 9 26 2 1 8 68 9009909099 DATA DEPTH = 7524.999 FEET CS.SPEA 778.942 TENS.SPEA RSP.SPEA -165.938 RT.SPEA SNR2.SPEA 49.197 PR.SPEA TER2.SPEA 3200.900 CER2.SPEA DT2R.SPEA 179.295 TTR2.SPEA CHRP.SPEA 0.788 ENRP.SPEA EERP.SPEA 19.458 LFRP.SPEA CHRS.SPEA 0.099 ENRS.SPEA EERS.SPEA -999.250 LFRS.SPEA DT4S.SPEA -999.25~ HTEN.SPEA TIME.SPEA 0.000 GTEM.SPEA CiR2.SPEA 0.962 S1R2.SPEA C2R2.SPEA 0.843 T2R2.SPEA NPR4.SPEA 2 CIR4.SPEA E1R4.SPEA -0.736 C2R4.SPEA SPR4.SPEA 32.144 GR.SPEA AO20.SPEA -999.250 AO30.SPEA AT10.SPEA -999.250 AT29.SPEA AT90.SPEA -999.250 AF10.SPEA AF60.SPEA -999.259 AFgO.SPEA AORT.SPEA -999.259 AORX.SPEA ATRX.SPEA -999.250 2910.990 11.371 -999.250 9.843 2600.99¢ -0.736 -999.250 10.009 -29.982 109.913 179,295 3290.000 0.788 0.691 67 510 -999 250 -999 250 -999 250 -999 250 -999 250 IHV.SPEA 0.0~9 SP.SPEA RXg.SPEA -999.250 ITT.SPEA CHR2.SPEA 0.962 ENR2.SPEA LFR2.SPEA ~.009 EER2.SPEA DTRP.SPEA 96.563 TTRP.SPEA TERP.SPEA 12~.~0~ CERP.SPEA DTRS.SPEA -999.250 TTRS.SPEA TERS.SPEA -999.259 CERS.SPEA DT2.SPEA 138.355 DT4P.SPEA MRES.SPEA 9.e61 ASFI.SPEA MTEM.SPEA 199.913 SPHI.SPEA T1R2.SPEA 2600.000 E1R2.SPEA E2R2.SPEA 33.652 SPR2.SPEA S1R4.SPEA 96.563 T1R4.SPEA T2R4.SPEA 1200.000 E2R4.SPEA 1A.SPEA -999.250 HGR.SPEA AO60.SPEA -999.250 AO90.SPEA AT30.SPEA -999.250 AT69.SPEA AF29.SPEA -999.250 AF39.SPEA AFRT.SPEA -999.250 AFRX.SPEA ATRT.SPEA -999.250 2A.SPEA 0.9~9 9.900 23.597 33.652 1009.090 0.691 -999.250 96.563 -1~.215 26.254 23.597 35.781 19.458 -999.250 -999.250 -999.259 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Senter 8-NOV-1995 13:49 PAGE: DEPTH = 5562.500 FEET CS.SPEA 881.785 TENS.SPEA 4175.000 IHV.SPEA RSP.SPEA -105.625 RT.SPEA 3.533 RXO.SPEA SNR2.SPEA 46.001 PR.SPEA 0.303 CHR2.SPEA TER2.SPEA 340e.00e CER2.SPEA 0.941 LFR2.SPEA DT2R.SPEA 198.022 TTR2.SPEA 2800.000 DTRP.SPEA CHRP.SPEA 0.407 ENRP.SPEA -19.565 TERP.SPEA EERP.SPEA -3.983 LFRP.SPEA o.eeo DTRS.SPEA CHRS.SPEA 0.869 ENRS.SPEA 14.177 TERS.SPEA EERS.SPEA 18.776 LFRS.SPEA 0.000 DT2.SPEA DT4S.SPEA 105.469 HTEN.SPEA 1825.116 MRES.SPEA TIME.SPEA 2045.000 GTEM.SPEA 100.757 MTEM.SPEA C1R2.SPEA 0.968 S1R2.SPEA 205.798 T1R2.SPEA C2R2.SPEA e.887 T2R2.SPEA 3400.e00 E2R2.SPEA NPR4.SPEA 3 C1R4.SPEA 0.724 S1R4.SPEA E1R4.SPEA 26.608 C2R4.SPEA 0.675 T2R4.SPEA SPR4.SPEA 23.392 GR.SPEA 51.704 1A.SPEA AO20.SPEA 1950.~00 'AO30.SPEA 1950.000 AO60.SPEA AT10.SPEA 2.99~ AT20,SPEA 5.197 AT30.SPEA AT90.SPEA 3,206 AF10.SPEA 3.044 AF20.SPEA AF60.SPEA 1950.000 AF90.SPEA 3,966 AFRT,SPEA AORT.SPEA 262,103 AORX.SPEA 1315.764 ATRT,SPEA ATRX.SPEA 3.284 685.440 -999.250 0.983 0.000 57.996 1300.0~ 101.126 1500.000 189.379 0.069 100.722 2800.000 35.546 106.606 1600.000 681.500 1950.~0 17.640 5.591 4.~42 3.232 SP.SPEA ITT.SPEA ENR2.SPEA EER2.SPEA TTRP.SPEA CERP.SPEA TTRS.SPEA CERS.SPEA DT4P.SPEA ASFI.SPEA SPHI.SPEA EIR2.SPEA SPR2.SPEA T1R4.SPEA E2R4.SPEA HGR.SPEA AO90.SPEA AT60.SPEA AF30.SPEA AFRX.SPEA 2A.SPEA 60.313 0.180 27.317 36.181 1100.000 0.~63 1300.~00 0.771 56.085 43.733 0.095 28.414 1~.288 14~.~0 27.823 51.962 9.205 1950.~0~ 4.990 3.242 1~22.500 ** END OF DATA **** FILE TRAILER FILE NAME : SPEA .038 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 95/09/20 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** TAPE TRAILER **** SERVICE NAME : CSNA~ DATE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY LIS Tape Verification Listing Schlumberger Alaska Computing (enter 8-NOV-~995 ~3:49 PAGE: · ~-~ REEL TRAILER ~ SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION ~ : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY
