The URL can be used to link to this page

Home My WebLink About182-085 Ima.~roject Well History File Cove~ ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) [] Color items: []//~J~rayscale items: Poor Quality Originals: [] Other: NOTES: [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCE~E' MARIA WINDY Project Proofing [] Maps: [] Other items scannable by large scanner OVERSIZED (Non,Scannable) [] Logs of various kinds [] Other DATE:~> ~SI BY: Scanning Preparation BEVERLY ROBIN VINCENT SHERYL MARIA WINDY. DATE; /S/ BY: BEVERLY ROBINf~'~SHERYL MARIA WINDY Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: -I ~ q PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~' YES BEVER V,NOENT S.ERYL MA.,., W,NDY DATE: 1-13'g.5 BY: Stage 2 BY: (SCA~INING I$ COMPLETE AT THIS POINT UNLESE SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO IF NO IN STAGE '1 ~ PAGE(S) DISCREPANCIES WERE FOUND: YES . NO ReScanned (individual page [special at~el~fion]~cat~ning completed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: lEI Quality Checked 12110102Rev3NOTScanned.wpd . . MEMO WELLS PRODUCING IN KENAI, STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201- 231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44- 3 OL DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X 7'. I 0 ?yJ1 ,.o~ L þl-- "'1;,Co SCANNED JUL 2 7 2007 · AlaSka. Team Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 October 25, 2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 '~~MNE[) <;\ ¡;-,., t;;~1 \/ RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production from this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: ,V ell No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 31- 7X API No. 5011331009001 501133100910 1 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibele@marathonoi1.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Files Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage i Operations performed: g:~cm n\drlg\kgf'twells~ku 11-8s~AOGCC01A,xls "{" '" STATE OF ALASKAi~, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate Pull Tubing ~ Alter Casing ..... Repair Well Other X Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 429'N & 1288'E of SW Cor, Section 6, T4N, R1 lW, SM At top of Productive Interval 2189'N & 393'E of SW Cor, Section 6, T4N, R11W, SM At Effective Depth At Total Depth 2655'N & 136'E of SW Cor, Section 6, T4N, R11W, SM 5. Type of Well: Development X Exploratory Stratigraphic Service Convert to Annular Flow 6. Datum Elevation (DF or KB) 28 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 13-61 9. Permit Number 82-85 10. APl Number 50- 133-20356 11. Field/Pool KENAI GAS FIELD/POOL 6 12. Present Well Condition Summary Total Depth: measured true vertical 5500 feet 4783 feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size 96' 20" 2008' 13 3/8" 5499' 9 5/8" measured C-1 Sand: 5178' - 5268' Cemented Measured Depth True Vertical Depth Driven 96' 96 1435 sacks 2008' 1884 2000 sacks 5499' 4804 true vertical C-1 Sand: 4532' - 4608' Tubing (size, grade, and measured depth) Long string: 31/2% 9.2#, N-80 to 5124' Short string: 31/2", 9.2~, N-80 to '!,'!,~.d' Packers and SSSV (type and measured depth) A-5 dual packer at 4430', Model FH packer at 4728', Model D packer at 5070'. ir,' ";'-',': , 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 6088 0 0 110 Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations hereby certify t the foregoing i Signed Form 10-404 Rev. 06/15/ unknown, not yet tested 116. Status of Well Classification as: --~ I Oil__ Gas X and correct to the best of my knowledge. J. Gary Eller Title Production Engineer Suspended Service Date -9/8/99 Submit in Duplicate) Kenai Gas Field Well KU 13-6, Pad 14-6 Marathon Oil Co., Alaska Region RT-THF: 26.00' RT-GL: 29.00' 429' N & 1288' E of SW Corner Sec. 6, T4N, Rl lW Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. Squeeze Perfs 4080' - 4082' DIL (4 spf) Otis "XA" Sliding Sleeve @ 4419' ID = 2.750" 20% 94#, H-40 Drive pipe @ 96' 13-3/8", 61#, K-55, BTC Casing @ 2008' Cmt w/1435 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve @ 4395' 1D = 2.750" Opened for Annular Flow (8/12/99) Otis "XN" Nipple ID = 2.635" Shortstring Perfs B-3 4521' - 4597' (4", 4 Spf, 120o phase, 7/1/82) Baker A-5 Dual Packer @ 4430' Blast Joints 4503' - 4621' Otis "XA" Sliding Sleeve @ 4714' ID = 2.750" Baker Model FH Packer @ 4728' Squeeze Perfs 4823' - 4833' (Sqzd w/300 sks 6/29/82) Lon~Istrinq Perfs C-1 5178' - 5268' (2-1/8", 4 spf) Junk: 30' of 3-1/2" tbg w/PX plug in X-nipple TD (~ 5500''~ Otis' "XA" Sliding Sleeve @ 5036' ID = 2.75O" Baker Model D Packer @ 5065' DIL Tubing Cut @ 5090' (7/9/82) Tag fill Ca). 5384' (5/21/96) 9-5/8", 47#, N-80, BTC Casing @ 5499' Cmt w/2000 sks of Class G Last Rev: JGE, 8/17/99 99081 ?.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/17/99 FIELD: FILL DEPTH/DATE: 5384' WLM TUBING: DATE LAST WL WORK: 5/21196 WORK DONE: PRESENT OPERATION: Pull plug OTHER: Day #6, AFE 0480398 - Annular Flow Conversion Kenai Gas Field WELL #: KU 13-61 3-1/2", 9.2#, L-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: tree cxn getting sloppy BENCHES OPEN: Steding C-1 SUMMARY OF OPERATIONS IMIRU slickline. Test lubricator and BOPE to SITP. RIH with 2" JDC to 4694' WLM. Latch and POOH with PXX prong. RIH with 3.5" GS pulling tool. Latch and POOH with PXX plug body. RDMO slickline. 8/18 - 8/19/99 APC roustabouts installed annular flowlines and hydro-tested. ---FINAL REPORT--- Vendor Equipment Daily Cost Cumulative Cost Air Liquide nitrogen $0 $3,898 APC flowlines, etc $2,500 $34,500 Dowell nitrogen $0 $8,072 Halliburton slickline $1,735 $4,572 Misc. car rental, airline $500 $3,000 R&K vac truck $0 $300 Vetco 2" gate valves $0 $1,300 Weaver Bros. trucking $0 $493 DALLY COST: $4,735 CUM: $58,315 REPORTED BY: J.G. Eller 990816.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/16199 FIELD: FILL DEPTH/DATE: 5384' WLM TUBING: DATE LAST WL WORK: 5/21196 WORK DONE: PRESENT OPERATION: Purge casing with nitrogen OTHER: Day #5, AFE 0480398 - Annular Flow Conversion Kenai Gas Field WELL #: KU 13-61 3-1/2", 9.2#, L-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: tree cxn getting sloppy BENCHES OPEN: Sterling C-1 SUMMARY OF OPERATIONS MIRU Dowell nitrogen unit on casing of KU 13-6 and test lines to 2500 psig. RU return lines on tubing of KU 13-01. Held safety meeting. Pump nitrogen down casing taking returns on Iongstring tubing. Pumped 146,200 SCF of nitrogen with a top pressure of 1 500 psig before getting nitrogen returns on tubing. Recovered approximately 230 bbl of liquid. Allowed casing pressure to bleed to 500 psig before shutting well in. RDMO nitrogen unit. " Vendor Equipment I~"aily Cost ' C~'mOlati~e Cosi -" Air Liquid.e nitrogen $3,898 $3,898 APC flowlines, etc $0 $32,000 ,, Dowell nitrogen $5,247... $8,072 Halliburton slickline $0 $2,837 ........ Misc. car rental, airline $500 $2,500 R&K vac truck $300 $300 .... Vetco 2" gate valves $0 $1,300 Weaver Bros. trucking $108 .. $493 DALLY COST: $10,053 CUM: $53,580 REPORTED BY: J.G. Eller 990812.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 8/12/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: 5384' WLM TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/21/96 TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Open sliding sleeves to communicate with annulus OTHER: Day #4, AFE 0480398 - Annular Flow Conversion WELL #: KU 13-61 9-5/8", 47#, N-80 tree cxn getting sloppy Sterling C-1 SUMMARY OF OPERATIONS MIRU Halliburton slickline on KU 13-61. SITP = 1720 psi, SICP = 0 psig. Test lubricator and BOPs to SITP. RIH with 3.5" BO shifting tool and locate sliding sleeve at 4396' WLM. Shift open sliding sleeve. Tubing pressure fell to 1 660 psi, casing pressure increased to 500 psi. Continued jarring to verify sleeve was fully open. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost , APC flowlines, etc $0 $32,000 Dowell nitrogen $0 $2,825 Halliburton slic kiln e $1,367 $2,837 Misc. car rental, airline $500 $2,000 Veco roustabouts $0 $180 Vetco 2" gate valves $0 $1,300 Weaver Bros. trucking $0 $385 DAILY COST: $1,867 CUM: $43,527 REPORTED BY: J.G. Eller 990811 .xls MARATHON OIL COMPANY DATE: 8111199 FILL DEPTH/DATE: 5384' WLM DATE LAST WL WORK: 5/21196 WORK DONE: PRESENT OPERATION: Install new casing valves OTHER: Day #3, AFE 0480398 - Annular Flow Conversion DAILY WELL OPERATIONS REPORT PAGE I OF 1 FIELD: Kenai Gas Field WELL #: KU 13-61 TUBING: 3-1/2", 9.2#, L-80 CASING: 9-5/8", 47#, N-80 TREE CONDITION: tree cxn getting sloppy BENCHES OPEN: Sterling C-1 SUMMARY OF OPERATIONS Brief Veco roustabouts on job assignment and held safety meeting. Removed blind flange and old 2" casing valve. Installed two reconditioned 2", 5M gate valves on 9-5/8" casing outlet. Verified that no VR plugs were left behind in the tubing head. RDMO. Vendor Equipment Daily Cost Cumulative Cost iAPC towlines, etc $0 $32,000 Dowell nitrogen $0 $2,825 Halliburton slicklin e $ 0 $1,470 Misc. car rental, airline $500 $1,500 Veco roustabouts $180 $180 Vetco 2" gate valves $1,300 $1,300 Weaver Bros. trucking $0 $385 DAILY COST: $1,980 CUM: $41,660 REPORTED BY: J.G. Eller 990810.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 8110/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: 5384' WLM TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/21196 TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Test casing, apply nitrogen pressure on tubing OTHER: Day #2, AFE 0480398 - Annular Flow Conversion WELL #: KU 13-61 9-5/8", 47#, N-80 tree cxn getting sloppy Sterling C-1 SUMMARY OF OPERATIONS MIRU nitrogen unit on tubing of KU 13-61. Test lines to 2500 psig. Pressure up tubing to 1860 psig using nitrogen. RDMO nitrogen unit. Note: The 9-5/8" casing already had 320 psig on it, so no need for an additional pressure test. Vendor Equipment Daily Cost Cumulative Cost Misc. car rental, airline $500 $1,000 Dowell 'nitrogen $2,825 $2,825 Halliburton slickline $0 $1,470 Weaver Bros. Itrucking $160 $385 APC !towlines, etc $0 $32,000 DAILY COST: $3,485 CUM: $37,680 REPORTED BY: J.G. Eller WirelJne Company: Work Being Done: Present Operations: Marathon Supervisor: Wireline Unit #: Zero Wireline at: Minimum Tut)in,(] I.D. MARATHON WELL SERVICE REPORT 8-9-99 Halliburton Energy Services Set Plug Well Shut in Wayne Cissell 2825 TBG Hanger Well Number: Location: AFE#/POft: Wireline Crew: Total Wireline Miles' Fill Tagged at (KB): Well KB: Max Tool Strinq O.D. 13-6 Lono Pad 14-6 KGF N/A Fore/Hewston 30 N/A N/A Time 12:30 t3:45 13:46 14:27 15:33 16:00 17:00 Work String Detail: I Operation Details Spot equipment and begin to rig up Rigged up Run in the hole with plug and set in XA sleeve Plug set start out of the hole Run in the hole with prong Out of the hole and begin rig down Rigged down and off location Description of any tools or debris left in the hole: Brief Summary of t · Total Work I Completed: Ticket #: Dailv Cost; Well Downtime Hrs. Dav #: Cumulative Cost: H25 [~om: Alaska R({r ~ Domestic Froduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 9, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Application for Sundry Approvals Well KU 13-61 Dear Mr. Wondzell: Enclosed is the Application for Sundry Approvals for Well KU 13-61. If you have any questions, please call me at 564-6315. Sincerely, J. ~,.'~ller ProSa'ction Engineer M:~lRSDocs~Drilling~jgeclaog.doc Enclosure CC: CEF Well File G. A. Laughlin M. H. Chauffee, Lafayette A subsidiary of USX Corporation Environmentally aware for the long run. G:\CMN\DRLG\KGF~WELLS\KU13-6L~AOGCC01 .xl$ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION'FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown ,,, Alter Casing Repair WellI Plugging m Change Approved Program Pull Tubing Vadance ........ Re-enter Suspended Well Time Extension Stimulate Perforate Other X Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 429'N & 1288'E of SW Cor, Section 6, T4N, R11W, SM At top of Productive Interval 2189'N & 393'E of SW Cor, Section 6, T4N, R11W, SM At Effective Depth At Total Depth 2655'N & 136'E of SW CoB Section 6, T4N, R11W, SM 5. Type of Well: Development X Exploratory _ Stratigraphic Service Convert to Annular Flow 6. Datum Elevation (DF or KB) 28 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 13-61 9. Permit Number 82-85 10. APl Number 50- 133-20356 11. Field/Pool KENAI GAS FIELD/POOL 6 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length 96' 2008' 5500 feet Plugs(measured) 4783 feet feet Junk (measured) feet Size Cemented 20" Driven Measured Depth m~l~;';~epth 96' 96 5499' 13 3/8" 1435 sacks 2O08' 1884 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 9 5/8" 2000 sacks 5499' 4804 C-1 Sand: 5178' - 5268' C-1 Sand: 4532' - 4608' Long string: 31/2", 9.2#, N-80 to 5124' ORIGINAL Short string: 31/2'', 9.2~, N-80 to 4444' A-5 dual packer at 4430', Model FH packer at 4728', Model D packer at 5070'. 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 8/9/99 If Proposal was Verbally A.p.,proved Oil / Gas ~ Name o[Approver~ ./// Date App ed Service I hereby c~fy that the foregoil[g is true and correct to the best of my knowledge. Signed ~%~~~ Gary Eller Title Production Engineer 16. 17. Suspended__ '-,,,,, - ~ ',., 'v FOR COMMISSION USE ONLY Conditions of Approval: Notify.~mmission so representative may witness Plug Integrity__ BOP Test Location Clearance Mechanical Integrity Test~ Subsequent Form Required 10- t,L(;Cf~ ORIGINAL SIGNED BY Approved by Order of the Commission Robert N. Christenson Form 10-403 Rev. 06115/88 Date 8/9/99 Commissioner Date ¢ '"'/?"' ~ ¢ Submit in Triplicate ' . Re: ~ll KU 13-,6, Kenai Gas Field PTD 8~q5 Subject: Re: Well KU 13-6, Kenai Gas Field PTD 82-085 Date: Wed, 11 Aug 1999 11:17:24 -0800 From: Blair Wondzell <blair wondzell~_~dmin.state.ak.us> Organization: State of Alaska, Dept ~f Admin, Oil & Gas To: John GEller <JGEller~MarathonOil.com> Gary, Thanks for the information. Your request for annular-flow of 13-61 is esentially the same as the approved request for annular flow of 13-68; therefore I hereby give verbal approval for annular-flow of KU 13-61. The Sundry Notice approval number will be 399-151. Blair Wondzell 8/11/99 John GEller wrote: > Blair - I am writing this note to explain why I wish to cancel the sundry #399-120 for converting well KU 13-68 to annular flow. At the same time, I would like to get your verbal approval to instead convert KU 13-61 to annular flow. > > On Friday 8/6/99, just prior to beginning the annular conversion of well KU 13-68, I got a phone call from our Production Operator at the Kenai Gas Field. He told me that he didn' t think an annular flow conversion was a good idea because they have recently had trouble getting KU 13-68 to flow. This was the first time I had heard that they were having trouble with this well, and the other Anchorage engineering staff were also unaware. Over the weekend they got KU 13-68 to unload 60 bbl of water, but even then the well could not sustain gas production. Obviously current conditions are not conducive to an annular conversion. > > I have written a replacement sundry notice asking that we instead convert KU 13-61 to annular flow. We will still attempt to produce KU 13-68 to the best of our ability up the tubing string. Annular conversion of KU 13-61 will provide an increase in gas deliverability at minimal risk and cost, as I have addressed in my sundry notice. Please call if you have questions. 1 of 1 8/11/99 11:18 A WELL KU 13-6L KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective: Allow flow up the tubing-casing annulus in well KU 13-61 to increase gas deliverability. Procedure; 1. Shut in both sides of well KU 13-6. MIRU slickline on KU 13-61. Test BOPs and lubricator to SITP. Set PX plug in XA sleeve (ID = 2.750") at 4714' MD. RDMO slickline. 2. MI nitrogen unit on KU 13-6. Using nitrogen, pressure test 9%" casing to 400 psig. Monitor 13%" casing for potential communication. When test is complete, bleed all pressure off 9%" casing. RU nitrogen on tubing of KU 13-61. Pressure up tubing with nitrogen and test PX plug to 1900 psig. When complete, do not bleed pressure off of tubing. RD nitrogen. 3. When casing is completely bled down, remove blind flange on tubing spool across from the existing 95/8'' casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull off the old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 4. MIRU slickline on KU 13-61. Test lubricator and BOPs to SITP. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve (ID = 2.750") at 4395' MD. Shift open sliding sleeve at 4395' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. 5. RU nitrogen unit on 9%" casing of KU 13-6. Pump nitrogen down casing, taking fluid returns on longstring tubing to catch tank. Continue until nitrogen is blowing around the tubing. RD nitrogen. 6. MIRU slickline on KU 13-61. Test BOPs and lubricator to SITP. RIH and pull PX plug at 4714' MD. POOH, RDMO slickline. 7. As soon as possible, produce well at maximum flow rate up tubing to clear any residual liquid from the wellbore. Put well in test separator, and record flow rate and tubing pressure. 8. Shut in KU 13-61. Install flowline to produce out both sides of the tubing head on KU 13-61. When complete, flow casing side and tubing side simultaneously to test separator and KU 13-61 Annular Flow Conversion Page 2 compare with previous test. When testing is complete, produce as per instructions of Production Foreman. JGE August 9, 1999 N:kDRLGX~KGF~WELL SLKU 13-6LL~,NNFLOW.WPD WELL KU 13-61, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling C-1 Sand (Pool 6) in well KU 13-61 to be produced up the 3 ½" tubing and 9%" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Solution Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing The highest potential for erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 10 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Pressures imposed on the 9%" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 36% of the rated casing burst or collapse. The squeeze perfs above the dual packer (4080' MD) will be pressure tested in excess of maximum anticipated shut-in pressure. Kenai Gas Field Well KU 13-6, Pad 14-6 Marathon Oil Co., Alaska Region RT-THF: 26.00' RT-GL: 29.00' 429'N & 1288' E of SW Comer Sec. 6, T4N, RI lW Shortstring Tubing: 3-1/2", 9.2/t, N-80, Butt. · Squeeze Perfs 4080' - 4082' DIL (4 spt) Otis "XA" Sliding Sleeve @ 4419' ID = 2.750" Otis "XN" Nipple (~} 4445' ID = 2.635" Shortstring Perfs B-3 4521'- 4597' (4", 4 spt; 120° phase, 7/1/82) Squeeze Perfs 4823' - 4833' (Sqzd w/300 sks 6/29/82) Longstring Perfs C-1 5178'- 5268' (2-1/8", 4 spt) Jumk: 30' of 3-1/2" tbg w/PX plug in X-nipple m (_a) 5500' 20", 94t/, H-40 Drive pipe @ 96' 13-3/8", 61 #, K-55, BTC Casing @ 2008' Cmt w/1435 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. It. Otis "XA" Sliding Sleeve @ 4395' ID = 2.750" Baker A-5 Dual Packer (,q~ 4430' Blast Joints 4503'- 4621' OtisID"XA"= 2.750"Sliding Sleeve @ 4714' Baker Model FH Packer ((3 4728' Otis "XA" Sliding Sleeve (¢ 5036' ID = 2.750" Baker Model D Packer @ 5065' DIL Tubing Cut @ 5090' (7/9/82) Tag till (~ 5384' (5/21/96) 9-5/8", 47#, N-80, BTC Casing ~ 5499' C~nt w/2000 sks of Class G Last Rev: JGE, 8/9/99 Re: Well KU 13-6, Kenai Gas Field PTD 82-_Q~5 ( Subject: Re: Well KU 13-6, Kenai Gas Field PTD 82-085 Date: Wed, 11 Aug 1999 11'17:24-0800 From: Blair Wondzell <blair wondzell@admin, state.ak.us> Organization: State of Alaska, Dept ~f Admin, Oil & Gas To: John GEller <JGEller~MarathonOil.com> Ga~-, Thanks for the information. Your request for annular-flow of 13-61 is esentially the same as the approved request for annular flow of 13-6s; therefore I hereby give verbal approval for annular-flow of KU 13-61. The Sundry Notice approval number will be 399-151. Blair Wondzell 8/11/99 John GEller wrote: > Blair - I am writing this note to explain why I wish to cancel the sundry #399-120 for converting well KU 13-6s to annular flow. At the same time, I would like to get your verbal approval to instead convert Kg 13-61 to m_~m_ular~.flow. > On Friday 8/6/99, just prior to beginning the annular conversion of well KU 13-6s, I got a phone call from our Production Operator at the Kenai Gas Field. He told me that he didn't think an annular flow conversion was a good idea because they have recently had trouble getting KU 13-6s to flow. This was the first time I had heard that they were having trouble with this well, and the other Anchorage engineering staff were also unaware. Over the weekend they got KU 13-6s to unload 60 bbl of water, but even then the well could not sustain gas production. Obviously current conditions are not conducive to an annular conversion. > I have written a replacement sundry notice asking that we instead convert KU 13-61 to annular flow. We will still attempt to produce KU 13-6s to the best of our ability up the tubing strinq. Annular conversion of KU 13-61 will provide an increase in gas deliverabil'ity at minimal risk and cost, as I have addressed in my sundry notice. Please call if you have questions. 1 of 1 8/11/99 11:18 AM G:\CMN\DRLG\KG~WELLS\KU13-6L~AOGCC01 .xls ¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspendm Operation Shutdown__ Re-enter Suspended Well .... Alter Casing ~ Repair Well~ Plugging ~ Time Extension ~ Stimulate. Change Approved Program~ Pull Tubing ~ Variance ~ Perforate Other X Name of Operator MARATHON OIL COMPANY 12. 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 429'N & 1288'E of SW Cor, Section 6, T4N, R11W, SM At top of Productive Interval 2189'N & 393'E of SW Cor, Section 6, T4N, R11W, SM At Effective Depth 5. Type of Well: Development X Exploratory Stratigraphic Service Convert to Annular Flow Datum Elevation (DF or KB) 28 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 13-6s 9. Permit Number 82-85 10. APl Number 50- 133-20356 At Total Depth 11. 2655'N & 136'E of SW Cor, Section 6, T4N, R11W, SM Present Well Condition Summary Total Depth: measured 5500 feet Plugs (measured) true vertical 4783 feet Effective Depth: measured feet Junk (measured) true vertical feet Length Size Cemented Measured Depth 96' 20" Driven 96' 2008' 13 3/8" 1435 sacks Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: 5499' 9 5/8" 2000 sacks Field/Pool KENAI GAS FIELD/POOL 5.1 measured B-3 Sand: 4521' - 4597' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) True Vertical Depth 96 B-3 Sand: 3971' - 4037' Long string: 31/2'', 9.Z#, N-80 to 5124' 2008' 1884 41askaOi,~~JL' ld t9 9 Sho~ string: 3W', 9.~, N-80 to A-5 dual packer at 4430', Model FH packer at 4728', Model D packer at 5070'. 13. Attachments Description Summary of Proposal .~X Detailed Operations Program .~X BOP Sketch 14. Estimated Date for Commencing Operation 115. Status of Well Classification as: 7/19/99 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby ~that the fo~_~ng is true and correct to the best of my knowledge. Signed ~ '~~ ~ Gary Eller Title Production Engineer " ' '""""J '~ "' F°R COMMISSION USE ONLY conditions of Approval: ~Commission~ so repre~eniative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test / "---Subsequent Form Required 10- /,4, O~ . Suspended Date 7/7199 Approved by Order of the Commission ORIGINAL SIGNED-BY Robert N. Chdstenson Form 10-~,03 Rev. 06/15/88 Commissioner Date ~-" Submit in Triplicate WELL KU 13-6s- AFE 0480398 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective: Allow flow up the tubing-casing annulus in well KU 13-6s to increase gas deliverability. Procedure: 1. MIRU nitrogen unit on KU 13-6. Using nitrogen, pressure test 9%" casing to 400 psig. Monitor 133/8'' casing for potential communication. When test is complete, bleed all pressure off 9%" casing. 2. When casing is completely bled down, remove blind flange on tubing spool across from the existing 9%" casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull off the old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 3. Shut in both sides of well KU 13-6. MIRU slickline on KU 13-6s. Test BOPs and lubricator to SITP. Set PXN plug in XN nipple (ID = 2.750") at 4445' MD. RDMO slickline. 4. RU nitrogen on KU 13-6s. Pressure up tubing with nitrogen and test PXN plug to 1900 psig. When complete, do not bleed pressure off of tubing. RD nitrogen. 5. MIRU slickline on KU 13-6s. Test lubricator and BOPs to SITP. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve (ID = 2.750") at 4419' MD. Shift open sliding sleeve at 4419' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. 6. RU nitrogen unit on 9%" casing of KU 13-6. Pump nitrogen down casing, taking fluid returns on shortstring tubing to catch tank. Continue until nitrogen is blowing around the tubing. RD nitrogen. 7. MIRU slickline on KU 13-6s. Test BOPs and lubricator to SITP. RIH and pull PXN plug at 4445' MD. POOH, _RDMO slickline. 8. As soon as possible, produce well at maximum flow rate up tubing to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. 9. Shut in KU 13-6s. Install flowline to produce out both sides of the tubing head on KU 13-6s. When complete, flow casing side and tubing side simultaneously to test separator and Well KU 13-6s Convert to Annular Flow Page 2 compare with previous test. When testing is complete, produce as per instructions of Production Foreman. JGE July 7, 1999 N:kDRLGLKGF~WELLSLKU 13-6S~ANNFLOW.WPD WELL KU 13-6s, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling B-3 Sand (Pool 5.1) in well KU 13-6s to be produced up the 3 ½" tubing and 9%" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Solution Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing The highest potential for erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 10 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Pressures imposed on the 9%" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 36% of the rated casing burst or collapse. The squeeze perfs above the dual packer (4080' MD) will be pressure tested in excess of maximum anticipated shut-in pressure. Kenai Gas Field Well KU 13-6, Pad 14-6 Marathon Oil Co., Alaska Region RT-THF: 26.00' RT-GL: 29.00' 429' N & 1288' E of SW Comer Sec. 6, T4N, R1 l W Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. · Squeeze Perfs 4080' - 4082' D1L (4 spf) ~' ~.. Otis "XA" Sliding Sleeve (~3, 4419' ID = 2.750" Otis "XN" Nipple @) 4445' ID = 2.635" Shortstring Perfs B-3 4521'- 4597' (4", 4 spt; 120° phase, 7/1/82) Squeeze Perfs 4823' - 4833' (Sqzd w/300 sks 6/29/82) Longstring Perfs C-1 5178'-5268' (2-1/8",45pt) , Junk:, 0 of 3-1/2" tbg w/PX plug in X-nipple Wr) ((~ 5500' 20", 94//, H-40 Drive pipe ~ 96' 13-3/8", 61//, K-55, BTC Casing ~ 2008' Cmt w/1435 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve ~ 4395' ID = 2.750" Baker A-5 Dual Packer ~ 4430' Blast Joints 4503'- 4621' Otis "XA" Sliding Sleeve @ 4714' ID = 2.750" Baker Model FH Packer (~ 4728' Otis "XA" Sliding Sleeve @ 5036' ID = 2.750" Baker Model D Packer @ 5065' DIL Tubing Cut. (¢ 5090' (7/9/82) 9-5/8", 47#, N-80, BTC Casing ~ 5499' Cmt w/2000 sks of Class G Last Rev: JGE, 1/8/98 Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 7, 1999 Mr. Blair Wondzell Alaska Oil & (:;as Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gas Coa~. Comm'~ss'tor'. Reference: Annular Flow Conversion of KU 13-6s and KU 14-61, Kenai Gas Field Dear Mr. Wondzell: Attached are sundry notices for the conversion of wells KU 13-6s and KU 14-61 to annular flow. Each includes a procedure, wellbore schematic, and a discussion of potential risks associated with the annular conversion. You will notice that there are squeeze perforatiOns present above the dual packer in well KU 13-6. I am providing you with further information about the squeeze perfs to address concerns about their integrity and their potential to impact production. I trust that the following information will alleviate any concerns you may have. You will recall that we initially had similar concerns with regard to well KU 43-6al, and the 1998 annular conversion of that well did not compromise the squeeze perfs. The 9~/s'' casing in well KU 13-6 was perforated at 4080' MD on June 22, 1982 in order to perform a block squeeze. The hole was full of 9.7 ppg mud at the time. The first squeeze attempt on June 22 was unsuccessful. A second squeeze was performed on June 25 used 217 sacks of cement and was successfully tested to 1100 psig surface pressure (15.6 ppg EMW). There has been no indication of these squeeze perfs having broke down any time since. The annular conversion procedure for KU 13-6s is written to minimize stress on the squeeze perfs and to minimize risk. The 9¥8" casing will be tested to 400 psig using nitrogen, which will test the squeeze perfs to a pressure of 440 psig to 1980 psig (depending On the fluid level in the annulus). The static bottom hole pressure of the Sterling B-3 Sand in KU 13-6s is only 295 psig. Therefore the initial pressure test exceeds the pressure that the squeeze perfs will be exposed to following the annular conversion. A subsidiary of USX Corporation Environmentally aware for the long run. Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission July 9, 1999 Page 2 Please contact me if further information is needed. I hope to commence this work on Monday, July 19, so your prompt attention is appreciated. Sincerely, J.G. Eller Production Engineer G:~CMN~RLG\KGF~WELLS~KU13-6L~SUNDRY.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown~ Re-enter Suspended Well~ Alter Casing .. Repair Wellm Plugging Time Extension m Stimulate ~ Change Approved Program Pull Tubing Variance Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 429'N & 1288'E ofSW Cor, Section 6, T4N, R11W, SM At top of Productive Interval 2189'N & 393'E of SW Cor, Section 6, T4N, R11W, SM At Effective Depth At Total Depth 2655'N & 136'E of SW Cor, Section 6, T4N, R11W, SM 5. Type of Well: Development X Exploratory ,,,, Stratigraphic ,,,,, Service Datum Elevation (DF or KB) 28 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 13-6L 9. Permit Number 82-85 10. APl Number 50- 133-20356 11. Field/Pool KENAI GAS FIELD/POOL 6 12. Present Well Condition Summary Total Depth: measured true vertical 5500 feet Plugs (measured) 4783 feet RECEIVED Effective Depth: measured true vertical feet Junk (measured) DEC "5 "J~g]P feet Casing Length Size Cemented Structural 96' 20" Driven Conductor Surface 2008' 13 3/8" 1435 sacks Intermediate Production 5499' 9 5/8" 2000 sacks Liner Perforation Depth: measured C-1 sand: 5178' - 5268' true vertical C-1 sand: 4513' - 4589' Measured I~ka 0il & Gas C0tlS. C0ailt~i0tl 96' Arl~l~)~,ca, uep~n 2008' 1884 5499' 4804 ORI61NAL Tubing (size, grade, and measured depth) Long string: 31/2'', 9.2¢f, N-80 to 5124' Short string: 31/2'', 9.2~, N-80 to Packers and SSSV (type and measured depth) A-5 dual packer at 4430', Model FH packer at 4728', Model D packer at 5070'. 13. Attachments Description Summary of Proposal X Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 1/1/98 15. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X Service Suspended~ 17. I hereby ce~ify that tl~e, [oregoing is true and,correct to.the best of my knowledge. Signed~~% ~~ Title Production Engineer L '", . co ,ss,o. COnditions of ApprOX. Notify Commissmn so representative may witness Plug Integrity__ BOP Test Location Clearance Mechanical Integrity Test -'"~ubsequent Form Required 10-'-~Oq Date 12/2./97 JApprova, Approved by Order of the Commission 0riginai SJgnecl By David W. Johnston Form 10-403 Rev. 06/15/88 ^~C,~¢_.~,,~?~ . , . C,ommissioner Date /Su~b~?i~Tfd?cat J Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 3, 1997 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Well 13--6L Dear Mr. Wondzell: Please find attached a procedure for permitting annular flow in well KU 13-6L in Kenai Gas Field. The increased flow area of producing up the 95/8'' casing and the 3%" tubing simultaneously is expected to double the well's gas deliverability. Flow up the 95/8'' casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. Surface safety devices will be similar to those present on existing completions in the Kenai Gas Field. This work is expected to commence in January 1998. Please contact me if further information is needed. .~ ~-- 6 '3 t ~ Sincerely, ~n E gineer G:\CMNkDRLGkKGFkWELLSkKU 13-6L\SUNDi~YCL. ORIGINAL RECEIVED Attachments DEC - 5 199 ' 'Nas~ 0il & Gas Cons. Commissle~ Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. WELL KU 13-6L KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective; Allow flow up the tubing-casing annulus in well KU 13-6L to increase gas deliverability. Procedure: 1. Shut in both sides of well KU 13-6. MIRU Haskel pump on tubing-casing annulus. Pressure test 9%" casing to 2,000 psig using water while monitoring pressure on long string, short string, and the 13%" casing. Record the volume of water used, and record test pressures using a 2-pen recorder. When test is complete, bleed pressure o_~_ff 9%" casing. 2. MIRU slickline on KU 13-6L. Set PX plug in profile of XA sleeve at 4,714' MD. (Alternate setting depth is the nipples at 5,036' MD, but try the one at 4,Ti4' first.) 3. Hook up a jumper hose from well KU 31-7rd to the tubing of well KU 13-6L. Pressure test ~ PX plug to 2,000 psig. Maintain 2,000 psig pressure on tubing. '~ 4. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve at 4,395' MD. Shif~ open sliding sleeve at 4395' MD while monitoring tubing pressure. POOH. RDMO slickline. 5. Move the jumper hose from the tubing to the 9%" casing of KU 13-6. Pressure up on 9%" casing using gas from KU 31-7rd while taking returns via longstring. Do not exceed 2,000 psig on 9%" casing. Leave the short string shut in during this entire operation. Continue to circulate gas until water is fully displaced from casing and tubing. When complete, shut in the tubing-side and allow tubing pressure to build to 500 psig. Remove jumper hose. 6. Modify flowline configuration to allow annular flow as per attached diagram. 7. MIRU slickline on KU 13-6L. Tag fluid level in tubing. Proceed with step #8 only if fluid is tagged at expected level. 8. Pull PX plug at 4,714' MD. RDMO slickline. Well KU 13-6L Convert to Annular Flow Page 2 9. Return well KU 13-6L to production via the tubing-side. When production has stabilized and when instructed by Production Foreman, open casing-side of well KU 13-6L and perform a flow test. JGE November 11, 1997 G:\ClVIN~R.LGkKGFkWELLSkKU 13 -6L~uNNFLOW. WPD RECEIVED DEC - 5 1997 Naska Oil a Gas Cons. Commission Anchorage WELL KU 13-6L CONVERSION TO ANNULAR FLOW POTENTIAL PROBLEMS ADDRESSED Potential Problem Solution Erosional velocity inside the 9%" casing string~at current conditions~exceeds 50 MMCFD. Maximum anticipated annular flowrate is less than 15 MMCFD. Erosion of the casing or the sliding sleeve is not anticipated. Erosional Velocity Corrosion Stress on Packer Surface Safety Controls Burst/Collapse of Casing Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is unlikely. Tubing movement calculations indicate that the net stress imposed on the dual packer will be less than 5,000 lbs. This procedure should not put undo stress on the tubing or dual packer. The casing-side will be produced via the same flowline as the tubing-side, so there will be no change in surface safety controls. Pressures imposed on the 9%" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 55% of the rated casing burst or collapse. WELL KU 13-6 CASING & ABANDONMENT DETAIL I. Rotary Table @ 0.0" II. ClW Dual 3-1/2' Tubing Hanger @ 26.00' III. 20', 94#, H-40 Drive Pipe @ 96' - IV. 1_.3_T_3/8', 61#, K-55 Casing @ 2,008' V. Top of Cement @ 5,438' VI. 9-5/8', 47#, N-80 Casing @ 5,499' qv~ 5 TUBING DETAIL LONG STRING: 3-1/2", 9.2-¢t,, N-80 TUBING 1. /4 ~o. ~3' 4. 5. 6. 7. 8. 9. 10. SHORT A. B. C. DA TE 6/22182 6~28/82 7/1/82 7/2~82 7/9182 Otis 'XA' Sleeve @ 4,394.85' Baker Model A-5 Dual Packer @ 4,429.50' Baker Blast Joints From 4,503.47' to 4,621.48' Otis 'XA' Sleeve @ 4,714.30' Baker Single Hyd. Packer @ 4,728.17' Otis 'XA' Sleeve @ 5,035.98' Baker Locator @ 5,069.00' Baker Model 'D' packer W/Seal Assembly @ 5,069.9' Otis 'X' Nipple @ 5,092.49' Bottom of Mule Shoe @ 5,124.17' STRING: 3-1/2",' 9.2¢I'~ N-80 TUBING Otis 'XA' Sleeve @ 4,419.05' Baker Model A-5 Dual Packer @ 4,433.04' Otis 'XN' Nipple @ 4,443.65' PERFORATION RECORD INTERVAL 4,080'-4,082' 4,823'-4,833° 4,521'-4,597' 5,178'-5,183' 5,183'-5,268' CONDITION Top A-8 Sd. Sqz'd Zn. Isolation B-5 Sd Sqz'd for Zn. Isolation B-3 Sd. Open for Production C-1 Sd. Open for Production C-1 Sd. Open for Production V VI 4 RECEIVED DEC - 5 Naska Oil & Gas Cons. Commissioil Anchorage A -05716 WELL KU 13-6 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ~:~,~ B.A.W. ~ :~. NONE ~"[ 2119186 Union Oil and Gas Division-Western Region Union Oil Companys~[`''' .;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen August 13, 1984 Ns. Fran Oones State of Alaska Oil and Gas Conservation Commission 3001 Rorcupine Anchorage, Alaska 9~501 Dear Ns. Sones: Enclosed is a copy of KU 13-6 survey plat which the Commission requested on August 13, 1~84. Should you have any questions, please contact me. Sincerely, Kirk D. Kiloh Development Geologist KDK/pg Enclosure RECEIVED AUG ! ~.~i & Gas Cons. C0rnll~|ssiolt Anchorage N SCALE l" : 300' 1288' BASE LINE W.C. ~ East-856 12 ! . SW COR. SEC. 6 K. U. 13-6 ..... I -~--- (Set wood stake! Fi~__ Lat. 60°27'38.3 ,,%/ J Lonq. 151°15'43 ~9,N, W , q,.%/// j X: ' 272,203.73 o oq'-/~-'x Y= 2,-362,476.34 LEGEND AND NOTES' ~ Found GLO brass cap monument. o Found 1/2" x 24" rebar. All bearings refer to the west line of Section 6 as being North. Top of gravel pad elevation is 76.8 feet above MLLW of Cook Inlet or 65.7 feet above Mean Sea Level. · Basis of coordinates is USC&GS Tri Station AUDRY in ASP Zone 4 /~ AUDRY · Lat. 60730'50.559" N Long..151016,37.445,, W X: 269,866.75 Y: 2,382,045.45 KU PREPARED FOR ., UNION OIL. COMPANY OF C~IL.IF. OPERATOR SURFACE LOCATION. 429 Ft. North and 1288 Ft. East from the SW corner of Section 6,. T4N, RllW, S.M., Alaska. Surveyed by: McLane and Associates, Inc. Date of Survey- June 3, 1982 F.Bk. 82-23 ~ ~ 1 STAGEY S Mc~NE Y~ ~ 'RECEIVED ~ Comm~Ssion nchorage ' TUBING DETAIL Z.~//,¢ I 31/2" OTIS "XA" SLEEVE AT 4594.85' 2. A-5 DUAL PACKER AT 4429.5' 5. BLAST JOINTS FROM 450;5.47' TO 4621.4-8' 4. ;51,/2" OTIS "XA" SLEEVE AT 4714.;50' 5. BAKER HYDRAULIC PACKER AT 4728.17' 6. :31/2" OTIS "XA" SLEEVE AT 5055.98' 7. LOCATOR AT 5069.00' 8. BAKER SEALS AT 5069.90' 9. :31/2" OTiS "X" NIPPLE AT 5092.49' I0.MULE SHOE AT 5125.39' SH~7- A. 51/2" OTIS "XA" SLEEVE AT 4419.05' B. A-5 DUAL PACKER AT 44:33.04' C 31/2" OTIS "XN" NIPPLE AT 4443.65' PERFORATION RECORD D, tTE IIVTEAYIIL 6/~2/8£ 4080' - 4082' 6/28/82. 482:3' - 4855' 7/I/82 452~' - 4597' 712/82 5~78' - 5185' 7/9/82 5t85' - 5268' OOIVDI£10N SQZ'D, A- 8 SAND , B-5 SAND OPEN, B-3 SAND ii II ii II 11 KU 1:3-6 O! 26.0' I! 20, 94~, H-40 DRIVE PIPE AT 96' II 13 3/8,61~,K-55 CASING AT 2,008' 9 5/8", 474 N- 80 CASING AT 5~499' union KU 13-6 WELL SCHEMATICS COMPLE TED: ? / I 1 / 82 Well KU ~5-6 [Field KENAI GAS ,County KENAI ~Date 11/2_9/82 Drawn By B,W, IChecked By Approved By Scale 11C¢NE I Page i Of I Union Oil and Gas D/,~sion: Western Region Alaska Expl~ ~tion District Union Oil Company o, c;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 October 5, 1982 HAND DELIVERY union DOCUMENT TRANSMITTAL TO: State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Anchorage, Alaska Attention: Mr. William Van Alen FROM: R. C. Warthen REFERENCE: KU 13-6 One (1) mag tape and verification list h.~KNOWI,EDGE RECEIPT BY SIGNING /XND RETURNING ONE COPY Ok" THIS DOCUMENT TRANSbflTTh.I',. RECEIVED BY: DATED: i(] STATE OF ALASKA , ALASKA AN D GAS CONSERVATION CC~'. ,.vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG t/- 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number - UNION OIL CONPANY OF CALIFORNIA 82-85 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o_133-20356 4. Location of well at surface 9. Unit or Lease Name 429'N & 1288'E of SW Cot, Section 6, TbN, RllW, SM. KENAI UNIT At Top Producing Interval 10. Well Number 2189'N & 393'E of SW Cor, Section 6, T4N, RllW, SM. KU #13-6 At Total Depth 11. Field and Pool 2655'N & 136'E of SW Cor, Section 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KENAI GAS FIELD KB +90' MSLI A-028142 Sterling Pool 12. Dat~-~pudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/9/82 6/17/82 7/11/82 --- feet MSLI 2 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost - 5500' & 4783' _-- YES~ NO [] .... feet MD 22. Type Electric or Other Logs Run DIL-BHC-Sonic, 0H-VDL, FDC-CNL-GR, CBL-¥DL-GR-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 'I CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED . 20" 94 H-4O 0 96 Driven. Driven --- 13 3/8 61 K-55 0 2008 i/ i/2 i435 sxs --- ·9 5/8 47 N-80 0 54~ 12 1/4 .zuuu sxs --- 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. 'TUBING RECORD interval, size ~nd number) SIZE DEPTH SET (MD) PACKER SET.(MD) MD TVD HPF Pool '~ 1/2" 5090' 5065' 4521-4597' ..- 3961-4026' 8 5.1 3 1/2" --- 4430' 5178-5268/ 4513-4589' 8 6 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '- DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED /,n~n_^n~9 ,' 500' SXS cmt $.q7 /,¢~O-4_/,R-4-4, 300 SXS c.m.f qn7 ! ~ , , . . , . 27. "pROD'uO]~I0N TEST Date~l~ir. st Production .: ... Method of Operation (Flowing, gas lift, etc.) "7/19/82' ' '" " FloWing '"' "-' · '_ ,, . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 7/19/82: ' .24 .TEST PERIOD I~ - 4,.27/8.59 - I FioTM ~ubing Casir)g Pressure CALCULATED OIL'-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 'Press':" 1000/,.~00 -- , 24-HOUR'RATE ~ -. 4,27'/8.: 59 - 28. ' " ' CORE DATA AUG - .NONE · . , , ~aska Oil & Gas Cons. . , , r Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. GEOLOGIC MARKERS FORMATION TESTS . ,- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/Sterling 4080' 3593' 5.1 Pool B-3 4521"-4597' MD - 6.98 ~FPD Gas Sands w/ 9.6 BWRD ~ 780 psi ~,i Final rate 13.6 MMCFPD w/ T/Beluga Fm. 5423' 4740' 4.6 BWPD 5.2 Pool B-5 4823-4833' MD - 1500 psig, 50 MCF for 1 hr test & +1000 BWPD 6 Pool C-1 5178-5183' MD - 5.5 MMCFPD w~ 9.6 BWPD ® 720 psi · 6 Pool C-1 5178-5268' MD - 10.4 MMc-FPD! W/ 9'.6 BWPD ~ 800 psi " Final rate 9.6 MMCFPD w/ 4.8 · BWPD $ 750 psi 31. LIST OF ATTACHMENTS , 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shoWn) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. 1 LEASE A-028142 WELL NO. KU #13-6 FIELD Kenai Gas Field - Sterling Pool LOCATION: 429'N & 1288'E of SW corner~ Section 6~ T4N~ RllW~ SM. (Surface) SPUD DATE 6/9/82 COMP. DATE CONTRACTOR Brinkerhoff RIG NO. TYRE UNIT 7/11/82 59 DRILL PIPE DESCRIPTION 5" 19.5# "E" PERMIT NO. 82-85 SERIAL NO. A-028142 TD 5500 ' TVD 4783 ' DEVIATION ('BHL) COMPANY ENGINEER Watson~ Abernath¥ ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL 29.0' .PT TO DRILL DE~ RT TO PROD~CTION~ECK('// .,~,/]~,___ CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# H-40 96' Driven 13 3/8" 61# Butt. K-55 2008' 1435 sxs "G" cmt w/ 2 1/2" PH gel & 2% CaCL2 9 5/8" 47# Butt. N-80 '5499' 2000 sxs cl "G" cmt w/ 3% kcI~..1.2% D-19~ 0.1% A-2~ 0.1% R-5, 0.2% D-6~ 0.2% gel "3 1/2" L~ ' '~'.2# Butt. N-80 5124' '"3 1/2'" SS 9.2# Butt. N-80 4445' A-5 dual pkr ~ 4430' PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 6/22/82 4080-4082' 4053' Top of A-8 sds 4" csq ~uns 4 HPF~ ,~qz'd w/ 500 SXs for zone isolation 6/28/82 4823-4833' 5438' (cmt) B-5 sds 7/1/82 4521-4597' 4850' (ret) B-3 sds 7/2/82 5,,178,-51,83' 5438' (cmt) C-1 sds 7'/9/82 5183-5268' 5395' (tbg jk) C-1 sds 2 1/8" guns 4 HPF sq,z'd w/ 300 sxs for zone isolation 2 1/8" guns 4 HPF, reperfed 7/3/82 w/ 4" 9uns 4 HPF - Open 2 1/8" guns 4 HRF - Open 2 1/8" guns 4 HPF - Open (Total of 8 HPF open to production in C-1 & 8-3 sands) INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR RENARKS 7/10/82 B-3 800 psi 13600 4.6 BWPD 7/11/82 C-1 (LS) 750 psi 9600 4.8 BWPD WELL HEAD ASSEMBLY TYPE: CASING HEAD: 12" 3000 psi x 13 3/8" SOW CIW Csg Head CASING HANGER: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: CIW type "AW" CIW "DCB" 13 3/8" 3000 psi x 10" 5000 psi 3 !/,2'' Oua.l.CIW rog Hanger 3 1/2" 8rd EUE APR 1 9 1983 ' ~'"~ "GaS MASTER VALVES: 3 1/16" 5000 psi CHRISTMAS TREE TOP CONN: 3 1/2" 8rd LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #13-6 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 3/8" CASING DETAIL OTS DESCRIPTION LENGTH BTM TOP Float Shoe Ot 13 3/8" 61# Csg Float Collar 1.81' 2006.19' 2008' ' 38.6!' 1967.58' 2006.19' 2.18' 1965.40' 1967.58' 47 Ots 13 3/8" 61# Csg 1923.48' 41.92' 1965.40' Cut-off in String 10.92 31.0' Cut-off below RT 31.0' 0 41.92 ' 31 O' * Cmt'd w/ 1235 sxs cl "G" cmt w/ 2% CaCL2 and 2 1/2% prehydrated gel and tail slurry of 200 sxs cl "G" cmt w/ 2% CaCL2. Good returns to-surface. CIR ~ 14:25 hrs 6/12/82. JTS 9 5/8" CASING DETAIL DESCRIPTION LENGTH BTM TOP 132 B&W 9 5/8" Float Shoe Jts, 9 5/8" 47# N-80 Butt Csg B&W 9 5/8" Float Collar Jts 9 5/8" N-80 47# Butt Csg KB to top CIW SOW Csg Head 1.70' 5497,30' 5499.0' 80.64' 5416.66' 5497.30' 1.45' 5415.21' 5416.66' 5385.31' 29.90' 5415.21' 29.90' 0 29.90' *Cmt'd w/ 2000 sxs cl "G" cmt w/ 3% kcl, 1.2% D-19, 0.1% A-2, 0.1% R-5, 0.2% D-6, 0.2% gel. Lost returns w/ 210 bbls displaced, regained partial returns ~ 250 bbls, lost returns again ~ 300 bbls. Pressure increased 1000 psi ~ 390 bbls, bumped p!ug $ 413 bbls. CIP © 06:00 hrs 6/20/82. LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. KU #13-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS LONG STRING TUBING DETAIL OTS DESCRIPTION LENGTH TOP BTM 142 Mule Shoe Ot 3 1/2" N'-80 9.2# Otis X-Nipple Pup 3 1/2" N-80 Butt Baker Seals Locator Ot 3 1/2" N-80 9.2# Otis XA Ots 3 1/2" N-80 9.2# Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Baker Single Hyd Set Pkr Pup 3 1/2" N-80 Butt Otis XA Ots 3 1/2" N-80 9.2# Blast Ots 3 1/2" Baker Ots 3 1/2" N-80 9.2# Baker Pkr Dual A-5 3 1/2" Ot 3 1/2" N-80 9.2# Otis XA ors 3 1/2" N-80 9.2# 0.78' 29.50' 1.40' 9.94' 12.65' 0.90' 29.20' 3.85' 279.53' 10.10' 9.95' 8.20' 10.05' 3.82' 92.82' 118. O1 ' 61.19' 12.78' 30.79' 3.86' 4343.0' 5123.39' 5093.89' 5092.49' 5082.55' 5069.90' 5069.00' 5039.80' 5035.98' 4756.42' 4746.32' 4736.37' 4728.17' 4718.12' 4714.30' 4621.48' 4503.47' 4442.28' 4429.50' 4398.71' 4394.85' 51.85' 5124.17' 5123.39' 5093.89' 5092.49' 5082.55' 5069.90' 5069.00' 5039.80' 5035.98' 4756.42' 4746.32' 4736.37' 4728.17' 4718.12' 4714.30' 4621.48' 4503.47' 4442.28' 4429.50' 4398.71' 4394.85' SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Kenai Unit WELL NO. KU #13-6 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS OTS DESCRIPTION LONG STRING TUBING DETAIL (cont) LENGTH TOP' BTM Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Cameron Hanger Dual 3 1/2" Below RT 6.00' 10.0' 4.35' 4.50' 1.00'' 26.00' 45.85' 35.85' 31.50' 27.00' 26.00' 0 51.85' 45.85' 35.85' 31.50' 27.00' 26.00' LEASE Kenai Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KU #13-6 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAIL'S OF OPERATIONS, DESCRIPTIONS & RESULTS JTS DESCRIPTION SHORT STRING TUBING DETAIL LENGTH TOP BTM 142 Otis XN Baker Dual 3 1/2" A-5 Pkr Pup 3 1/2" N-80 Butt Otis XA Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Ots 3 1/2" N-80 9.2# Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Pup 3 1/2" N-80 Butt Cameron Dual 3 1/2" Hanger Below RT 1.43' 10.61' 10.10' 3.89' 10.02' 10.08' 5.08' 4344.60' 10.29' 8.88' 3.10' 1.00' 26.00' 4443.65' 4433.04' 4422.94' 4419.05' 4409.03' 4398.95' 4393.87' 49.27' 38.98' 30.10' 27.00' 26.00' 0 4445.08' 4443.65' 4433.04' 4422.94' 4419.05' 4409.03' 4398.95' 4393.87' 49.27' 38.98' 30.10' 27.00' 26.00' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS A 616/82 DALLY COST: $ 38,905 ACC COST: $ 38,905 AFE AMT: $2,250,000 B 6/7/82 DAILY COST: $ 130,048 ACC COST: $ 158,953 AFE AMT: $2,250,000 C 6/8/82 20" D. 82' DAILY COST: $ 32,471 ACC COST: $ 191,424 AFE AMT: $2,250,000 1 6/9/82 436'/436' 20" D. 96' 67 PCF 105 SEC DAILY COST: $ 46,131 ACC COST: $ 237,555 AFE AMT: $2,250,000 2 6/10/82 1258'/822' 20" O. 96' 68 PCF 82 SEC DAILY COST: $ 47,001 ACC COST: $ 284,555 AFE AMT: $2,250,000 3 6/11/82 2020'/762' 20" D. 96' 70 PCF 60 SEC DAILY COST: $ 55,229 ACC COST: $ 303,784 AFE AMT: $2,250,000 4 6/12/82 2020'/0' 20' D. 96' 13 3/8" C. 2008' 70 PCF 60 SEC DAILY COST: $ 170,407 ACC COST: $ 474,191 AFE AMT: $2,250,000 Commenced operations on KU #13-6 8 00:01 hrs 6/6/82. Began to rig up Brinkerhoff Rig #59. Rigging up. RU Brinkerhoff Rig #59. Commenced operations 14:45 hrs. Drove 20" conductor to 96' RKB. Drove rat hole. Cut off 20" cond & installed 20" 2000 psi SOW flange & diverter system. Spud ~ 16:00 hrs. Drld 17 1/2" vertical hole to 300'. Trip for dyna-drill. Oriented dyna- drill w/ SDC steering tool. Dyna- drld 17 1/2" hole f/ 300' to 436'. Dyna drld 17 1/2" hole w/ BHA #2 & bit #1PR f/ 436' to 760'. POOH . RIH w/ BHA #3 & bit #2. Dir drld 17 1/2" hole f/ 760' to 1258'. Dir drld 17 1/2" hole f/ 1258' to 1593'. POOH. RIH w/ bit #3 on BHA #4. Dir drld 17 1/2" hole f/ 1593' to 2020'. Circ btms up. Trip to shoe. No fill. Repair solids equip. C&C mud & hole for csg.- C&C mud & hole for csg. POOH. Ran 48 jts of 13 3/8" 61# K-55 butt csg. Cmt'd 13 3/8" csg thru DP w/ FS ~ 2008' & stab-in FC ~ 1966' w/ 1235 sxs "G" w/ 2 1/2% pre-hydrated gel & 2% CaCL2 & tail slurry of 200 sxs "G" w/ 2% CaCL2. Good cmt returns to surf. CIP ~ 14:25 hrs. POOH w/ DP. WOO 8 hrs. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO, LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 6/13/82 2020'/0' 20" D. 96' 13 3/8" C. 2008' 70 PCF 65 SEC DALLY COST: $ 23,037 ACC COST: $ 497,228 AFE AMT: $2,250,000 6 6/14/82 2912'/892' 20" D. 96' 13 3/8" C. 2008' 69 PCF 62 SEC DAILY COST: $ 39,559 ACC COST: $ 536,787 AFE AMT: $2,250,000 7 6/15/82 4016'/1104' 20" D. 96' 13 3/8" C. 2008' 71PCF 64 SEC DAILY COST: $ 33,701 ACC COST: $ 596,597 AFE AMT: $2,250,000 8 6/16/82 5100'/1084' 20" D. 96' 13 3/8" C. 2008' 72 PCF 63 SEC DAILY COST: $ 26,448 ACC COST: $ 623,045 AFE AMT: $2,250,000 9 6/17/82 5500'/400' 20" D. 96' 13 3/8" C. 2008' 72 PCF 53 SEC DALLY COST: $ 33,223 ACC COST: $ 636,268 AFE AMT: $2,250,000 10 6/18/82 5500'/0' 20" D. 96' 13 3/8" C. 2008' 72 PCF 47 SEC DAILY COST: $ 20,967 ACC COST: $ 677,235 Removed 20" diverter assy. Cut off 13 3/8" csg. Installed 12" 3000 psi X 13 3/8" SOW csg head. Head would not test. Removed & reinstalled csg head. Tested head - ok. Installed & tested BOPE. RIH w/ bit #4 on BHA #5 to FCe 1966' Tested 13 3/8'"csg to 2200 psi. 6rld FC ~ 1966' & reteSted 13 3/8" csg to 2500 psi. Drld out shoe & new hole to 2022'. Tested 13 3/8" shoe to 90 PCF equiv w/ no leak off. POOH. RIH w/ bit #4 on BHA #6. Dir drld 12 1/4" hole f/ 2022' to 2912'. Directionally drill 12 1/4" hole f/ 2912' to 3587' w/ BHA #6 & bit #4 POOH. CIH w/ bit #5 OH BHA #7. Directionally drill 12 1/4" hole f/ 3587' to 3972'. POOH. RIH w/ bit #6 OH BHA #8. Directionally drill 12 1/4" hole f/ 3972' to 4016'. Dir drl 12 1/4" hole f/ 4016-4230'. POOH. RIH w/ BHA #9 & bit #6PR1. Stuck pipe ~ 3976' on trip in - work free. Ream f/ 3932-4230'. Dir drl 12 1/4" hole f/ 4230-5100'. Oir drld 12 1/4" hole f/ 5100-5131'. POOH. RIH w/ bit #7 on BHA #10. Dir drld 12 1/4" hole f/ 5131-5500'. C&C mud & hole for logs. Short tripped to shoe. C&C mud. POOH. RU DA. Ran DIL-BHC-Sonic, OH-VDL & FDC-CNL-GR logs, (had 1 misrun on DIL & lost l0 hrs due to surf equip malfunctions while running FDC-CNL- GR). AFE AMT: $2,250,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO, LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 6/19/82 5500'/0' 20" D. 96' 13 3/8" C. 2008' 72 PCF 50 SEC DAILY COST: $ 362,908 ACC COST: $1,040,143 AFE AMT: $2,250,000 12 6/20/82 DAILY COST: ACC COST: AFE AMT: 13 6/21/82 5500' TD 5400' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 72 PCF 42 SEC $ 105,611 $1,145,754 $2,250,000 5500' TD 5440' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 72 PCF 42 SEC DAILY COST: $ 36,226 ACC COST: $1,181,980 AFE AMT: $2,250,000 14 6/22/82 DAILY COST: ACC COST: AFE AMT: 15 6/23/82 DALLY COST: ACC COST: 5500' TD 4053' ETD 13 3/8" C. 2008' 9 5/8" C. 5449' 69 PCF 40 SEC $ 50,995 $1,232,975 $2,250,000 5500' TD 4376' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 69 PCF 40 SEC $ 20,901 $1,253,876 Compl running FDC-CNL-GR. RD DA. RIH. Had l' fill. C&C mud & hole for 9 5/8".csg. POOH. Ran 9 5/8" 47# N-80 butt csg. Broke chain on compound while circ& reciprocating prior to cmtg. Repaired chain on compound. Cmt'd 9 5/8" csg w/ 2000 sxs cl "G" w/ 3% KCL, 1.2% 0-19, .1% A-2, .1% R-5, .2% D-6 & .2% gel. Stuck 9 5/8" after dropping top plug& could not reciprocate during cmtg. CIP ~ 06:00 hrs. Lost returns w/ 210 bbls displaced, regained partialjreturns ~ 250 bbls, lost again ~ 300 bbls, press incr 1000 psi ® 390 bbls, bumped plug ~ 413 bbls. Installed & tes%ed "DCB" spool. NU & tested BORE. RIH w/ 8 1/2" bit & 9 5/8" scrpr. Circ clean. POOH. RU & RIH w/.gyro survey. Tool stopped ~ 3300'. RD WL. RIH w/ 8 1/2" bit (did not see , .anything ~ 3300'). C0 cmt f/ 5400¢¢ to 5440'. Circ clean. POOH. RU WL. ~an SDC gyro surv f/ 5420' to surf.' Ran CBL-VDL-GR-CCL f/ 5440' to 800' (reran VDL f/ 5440' to 3800'). Tested 9 5/8" csg to 3000 psi. LD HWDR. Rerfed & sqz'd top of Ster- ling "A-8" sand f/ 4080' to 4082' DIL w/ 4" csg guns loaded 4 HRF us- ing 250.sxs "G" w/ 10% silica flour, .75% 0-31, .7% D-19, .2% D-6, .2% A-2 & 5% KCL thru cmt ret ~ 4053' DRM. Initial rate 2 1/2 BRM ~1500 psi. Form held 850 psi w/ pumps off. Final rate 3 BRM ~ 1800 psi. Form held llO0 psi w/ pumps off. CIP W 22:35 hrs. POOH. RIH w/ bit. WOC 14 hrs. Drld out ret ~ 4050'. CO cmt to 4080' - still soft. WOC 3 more hrs, CO cmt f/ 4080' to 4110' & stringers to 4353'. Drld hrd cmt f/ 4353- 4376' (23' in I 1/2 hrs). AFE ANT: $2,250,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 16 6/24/82 DAILY COST: ACC COST: AFE AMT: 17 6/25/82 DAILY COST: ACC COST: AFE AMT: 18 6/26/82 5500 ' TD 5440' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 69 PCF 40 SEC $ 27,997 $1,281,873 $2,250,000 5500' TD 4042' ETD (RET) 13 3/8" C. 2008' 9 5/8" C. 5499' Water $ 49,930 $1,331,803 $2,250,000 5500' TD 5438' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' Water DAILY COST: $ 30,150 ACC COST: $1,361,953 AFE AMT: $2,250,000 19 6/27/82 DAILY COST: ACC COST: 5500' TD 5438' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 31,089 $1,393,042 Trip for new bit & lay down csg scrpr. Drld'cmt & ret parts f/ 4385-4395' (3 1/2 hrs). Trip for mill. Milled cmt & ret parts f/ 4395' to 4425' (4 hrs). RIH f/ 4425' to 5440'. Circ clean. POOH. RIH & set RTTS'~ 4193'. Tested 9 5/8" under sqz perfs to 3200 psi- 'ok. Set RTTS ~ 4008' & displ DR w/ N2. Dry tested sqz perfs f/ 4080' to 4082' - not dry, started making gas. Dry tested perfs ~ 4080' to 4082'. Had gas ~ 800 psi in 15 min. Killed well. Pumped into perfs f/ 4080' .to 4082' w/ 1500 psi.~ 3 1/2 BRM. RIH to 4193' & rev out gas cut mud. POOH. Set Baker cmt ret on WL 8 4108' DIL. Set cmt ret on DR ~ 4042' DIL. Broke down perfs f/ 4080' to 4082' DIL w/ 2000 psi 8 4 BRM. Form held llO0 psi w/ pumps off. Sqz'd perfs f/ 4080' to 4082' w/ 250 sxs "G" w/ 10% silica flour, .75% D-31, .7% D-19, .2% D-6, .2% A-2 & 5% KCL. Final rate 3 BPM ~ 1800 psi, form held 1100 psi w/ pumps off. Rev clean & POOH. CIP ~ 12:45 hrs. WOC 14 hrs. Drld out ret ~ 4042' & hard cmt to ret @ 4108'. POOH. RIH & set RTTS ~ 4008'. Displ w/ N2 & dry tested perfs f/ 4080' to 4082' - no entry. POOH. RIH w/ 8 1/2" bit. Drld out ret ~ 4108' & CO to 5438'. POOH. RIH w/ 8 1/2" bit & 9 5/8" csg scrpr to 5438'. X-over to clean 3% KCL compl fluid. POOH. RIH w/ RTTS & test tools. Set RTTS ¢ 4685'. Displ DP w/ N2 - had N2 to surf in ann in 10 min - leak in DP. POOH LD 3 1/2" DP. PU new bypass valve & checked RTTS. AFE AMT: $2,250,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 6/28/82 DAILY COST: ACC COST: AFE AMT: 21 6/29/82 DAILY COST: ACC COST: AFE AMT: 22 6/30/82 5500' TD 5438' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 32,206 $1,425,248 $2,250,000 5500' TD 4775' ETD (RET) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 58,376 $1,483,624 $2,250,000 5500' TD 4850' ETD (RET) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE DAILY COST: $ 31,451 ACC COST: $1,515,075 AFE AMT: $2,250,000 23 7/1/82 DALLY COST: ACC COST: AFE AMT: 5500' TD 4850' ETD (RET) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 42,470 $1,557,545 $2,250,000 RIH w/ test tools PU 3 1/2" tbg. Set RTTS ~ 4710' w/ tbg tail to 4756'. Opened bypass valve & displ tbg w/ N2 to' bypass. Closed bypass & bled off N2 to have 700 psi ~ RTTS. Perfed Sterling "B-5" f/ 4823' to.4833' DIL w/ 2 1/8" guns loaded 4 HPF under +700 psi draw- down. Opened well to test. Bled to 0 psi in 9 min. RIH w/ surf readout press recorder. Had fluid level ~ +850' & BHP ~ parrs +1500 psi w/ well producing small amt of gas ~ surf. POOH w/ recorder. Killed well. Circ clean. Well taking fluid ~ 44 BPH. Spot safe-seal pill across perfs. ROOH. Ran GR to 5000'. Set cmt rat's ¢ 4850' DIL & 4775' DIL. RIH w/ DR. Rumped into "B-5" perfs ~ 5 BRM w/ 2000 psi, form held 0 psi w/ pumps off. Sqz'd "B-5" perfs f/ 4823' to 4833' for abandonment w/ 300 sxs "G" w/ 10% silica flour, · 75% D-31, .7% D-19, .2% D-6, .2% A-2 & 5% KCL. Final rate 5 BPM ~ 2500 psi. Form held 1600 psi w/ pumps off. CIR ¢ 17:50 hrs. Rev clean & ROOH. WOC. Drld out cmt ret ~ 4775' & CO hrd cmt to ret 8 4850'. Circ clean & POOH. RIH w/ test tools on tbg. Set RTTS ~ 4436'. Tested surf equip to 3000 psi & displ tbg w/ N2. RIH w/ HP press recorder to 4775'. Bled off N2 to 0 psi 8 surf. Ini- tial BHP ¢ 4775' = 209 psi, BHP ~ 4775' after i hr = 210 psi - perfs dry. Rulled press recorder up to 4550'. Rress up w/ N2 to have 700 psi BHR ® 4550'. ROOH w/ press rec. Rerfed Sterling B-3 w/ 2 1/8" guns loaded 4 HRF f/ 4521' to 4597'. Flowed well to clean up. Stabilized rate 6.98 MMCFPD w/ 9.6 BWPD ~ 780 psi. Killed well. RIH to 4671'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 7/2/82 5500' TD 5438' ETD (CMT) 13 3/8" C. 2008' 9 5/8" C. 5499' 67 PCF BRINE DAILY COST: $ 34,615 ACC COST: $1,592,160 AFE AMT: $2,250,000 25 7/3/82 DAILY COST: ACC COST: AFE AMT: 26 7/4/82 DAILY COST: ACC COST: AFE AMT: 27 7/5/82 5500' TD 5828' ETD (FILL) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 40,786 $1,632,946 $2,250,000 5500' TD 5428' ETD (FILL) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 20,693 $1,653,639 $2,250,000 5500' TD 5428' ETD (FILL) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE DAILY COST: $ 148,560 ACC COST: $1,802,199 AFE AMT: $2,250,000 28 7/6/82 DAILY COST: ACC COST: 5580 ' TD 5428' ETD (Fill 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE $ 72,378 $1,874,577 Circ clean & POOH. RIH w/ 8 1/2" bit. DO ret 8 4850' & CO to 5438' RBTD. Circ clean w/ high vis pill. POOH. RIH w/ test tools on 3 1/2" tbg. Set RTTS ~ 5045'. Displ tbg w/ N2. Rerfed "C-l" sd w/ 2 1/8" guns loaded w/ 4 HRF f/ 5178' to 5183'. Test for water. Tested Sterling "C-i" perfs f/ 5178' to 5183'. Rate stabilized ~ 5.5 MMCFPD w/ 9.6 BWPD ~ 720 psi. Killed well. RIH to 5264'. Spot safe-seal, pill across "C-i" & "B-3" perfs. POOH. Perfed "B-3" sd w/ 4" csg guns loaded 4 HPF on 120° phasing f/ 4521' to 4597'. RIH w/ 8 1/2" bit & 9 5/8" scraper to 5828' (fill). POOH.. Set Baker "D" pkr on WL ® 5065'. RIH w/ 2' seal on DP to test pkr. RIH. Tagged "D" pkr ~ 5068' DPM. Tested pkr to 200 psi. POOH LD 5" DP. RU to run 3 1/2" comp assy. Ran dual 3 1/2" comp assy. Tested down LS to confirm in "D" pkr - no test. RU Otis on LS & confirmed that "XA" sleeves were closed. Re- tested LS - no test. Worked tbg 6' down hole - LS tested. Worked tbg 6' into "D" pkr & retest LS to confirm in "D" pkr ~ 5065' DIL -ok. Set & tested "FH" pkr. Set "A-5" pkr & LS would not land after setting "A-5" pkr. Pulled & stood back 3 1/2" comp assy. RIH w/ 307' tail on seal assy. Tested "D" pkr ~ 5065' - ok. Circ clean 8 +5373'. AFE AMT: $2,250,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 7/7/82 5500 ' TD 5428' ETD (Fill) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE DAILY COST: $ 38,086 ACC COST: $1,912,663 AFE AMT: $2,250,000 30 7/8/82 5500 ' TD 5428' ETD (Fill) 13 3/8" C. 2008' 9 5/8" C. 5499' 64 PCF BRINE DAILY COST: $ 32,753 ACC COST: $1,945,416 AFE AMT: $2,250,000 31 7/9/82 DAILY COST: ACC COST: AFE AMT: 32 7/10/82 5500' TD 5395' ETD (TBG FISH) 13 3/8" C. 2008' 9 5/8" C. 5499' PKR FLUID $ 54,974 $2,000,390 $2,250,000 5500' TD 5395' ETD (TBG FISH) 13 3/8" C. 2008' 9 5/8" C. 5499' PKR FLUID DAILY COST: $ 111,463 ACC COST: $2,111,853 AFE AMT: $2,250,000 33 7/11/82 DAILY COST: ACC COST: AFE AMT: 5500 ' TD 5395' ETD (TBG JUNK) 13 3/8" C. 2008' 9 5/8" C. 5499' $ 41,355 $2,153,208 $2,250,000 Circ clean. POOH. Ran 3 1/2" dual comp assy. Stabbed into pkr ~ 5065' & tested pkr. PU & spaced out tbg. Ran & set Otis plug in "XA" ~ 5036'. Plug would not hold. Pulled & re- dress plug. Set plug in "XA" ~ 5036' - plug still leaking. Set plug in Otis "XA" @ 5036'. Plug would not hold. POOH w/ plug. Set "PX" plug in "X" nipple ~ 5094'. Set & test "FH" pkr. "PX" plug stuck in "XA" sleeve. RIH w/ WL & sinker bars. Jarred "PX" plug down LS f/ 5036' to 5092' w/ sinker bars. Set plug in "XN" in SS ~ 4443' & set "A-5" pkr 9 4430'. Pulled plug f/ "XN". Test- ed dual pkr - ok. Jet cut LS 3 1/2" tbg ~ 5090' & dropped 30' tbg w/ "X" nipple & "PX" plug to btm (EST TOF ~_ 5395'). Removed BOPE. Installed & tested dual tree. Opened "XA" in LS ® 4395' & displ ann above "A-5" pkr w/ pkr fluid. Closed "XA" ~ 4395 ' · Opened "XA" in LS ~ 4714' & displ LS w/ N2 taking returns thru SS until SS started producing. Flowed SS un- til clean. Final rate SS "B-3" 13.6 MMCFRD w/ 4.6 BWRD. SI SS. Closed "XA" ® 4714'. Bled off LS to 0 psi & LS "C-l" perfs unloaded & started producing. Inflow perfed "C-i" w/ 2 1/8" guns loaded 4 HPF f/ 5183' to 5268'. (Total perfs 5178' to 5268'). Test- ed well. Stable rate 10.4 MMCFPD & 9.6 BWPD ~ 800 psi. Inflow perfed an additional 4 HPF f/ 5178' to 5268'. Tested well. Stable rate 9.6 MMCFPD & 4.8 BWPD ~ 750 psi. Shut in well. Installed BPV'S. Released rig to moving rate ~ 12:00 hrs. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KU #13-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 34 7/12/82 DAILY COST: ACC COST: 5500' TD 5395' ETD (Tbg Fish) 13 3/8" C. 2008' 9 5/8" C. 5499' $ 16,660 $2,169,868 Rigged down to move. Released rig to KU #24-5 ~ 24:00 hrs 7/12/82. AFE AMT: $2,250,000 CONTRACTOR Brinkerhoff Signal Inc. OIL COMPANY Union Oil Company RIG NO. 59 LEASE/WELL NO. BIT RECORD KU #13-6 COUNTY Kenai STATE Alaska FIELD/TOWN TOOL PU_SHER. Bake.r/McKeever. DR RIG MAKE & MODEL DR RECORD NO. DR SEC/TSHIP/ ,RANGE ,, , ,S,e,c,., 6, T4N, RllW, SM. ._ SHEET TOOL NO. OOINTS MAKE SIZE TYPE 4 1/2 iF OD 6 1/4 NO. 1 PUMP MAKE & MODEL Emsco F-lO00 Liner 6 1/2 SPUD DATE 6/9/82 UNDER SURF DRILL COLLARS NO OD 8" ID 2 7/8" LENGTH NO. 2 PUMP MAKE & MODEL Oilwell lO00P Liner 6 INTER TD DRILL COLLARS NO OD ID LENGTH RUN no... SIZE, MAKE ETC. ) OETS 32ND' BIT DEPTH FOOT- TYPE 1,, 2 ,3 ...... ,SER, ,.No-, .... OUT AGE,, .HOURS WT ACCUM 1000 VERT PUMP No 1 No. 2 MUD DULL COND REMARKS HOURS . ,LB ,~ R?M, DEV,.' PRESS, ,SPM LIN, ,SPM .LIN, ,WI, VIS, T B G (FAILURE, Sec 17 1/2 S350 20 20 20 " " 13 16 16 130487 760 725 130488 1593 833 3 " " 13 13 13 130100 4 Htc 12 1/4 X-3A B 13 13 MM681 5 " " ---do--- LA 910 6 " " ---do--- " 7 " " B 13 13 ST677 8PR Reed 8 1/2 Open 930266 9 " S13GJ 16 16 16 910467 l0 " S44G ---do--- 262884 i1 " " ---do=-- 262886 12 " 03 ---do--- SR448 2020,~ 427 358 ¢ 1567 3972 385 5131 1159 5500 359 10 10 10/40 120 750 62 52 6 1/2 6 1/2 15/40 DD 1050 55 45 3 1/2 3 1/2 40/50 80/150 2200 55 14 3/4 14 3/4 25/45 110 2100 90 4 4 30/35 110 -do- -do- 14 1/4 19 1/2 40/50 llO 2400 -do- 5 5 40/45 110 -do- -do- Wiper & Ret ret & cmt 7 1/2 38 3 45 67 110 1 3 I Surface 68 82 2 2 I Lost jet/sd-cly 70 60 1 1 I " 71 64 4 2 I "+ coal 71 64 1 2 I " 72 53 4 6 1/8 Sd & Sh 72 53 1 1 I H20 3 5 1/16 C.O. -do- 2 6 I -do- i i I -do- 4 3 I -do- 4 i I Ret & fill JOB NUMBE;R: WEI..L NAME: L 0 C A l' I 0 N: SURVEY DATE ,:) U I~ V E Y I:. N (.~ I N E E R: AMI::' / SCIENTIFIC DR;I ...... lNG ANCHORAGE OFFICE GYRO,SCOPIC DIRECTIONAL SURVEY FOR · x- .x..x..x. * ,x..x..x- .x. * .x..x..x- .x. -x. -x..x- .x..x..x- .x- .x..x- .x..x. · x. UNION OIL OF CALIFORNIA.x. · x., .x..x..x..x..x..x..x, .x..x..x..x..x..x..x..x..x..x..x..x., .x., .x. DRII..L SITE 1~ WEL. L 6 KENAI GAS FIELD 06/21/82 CHAP P EL.L./WALTER METHOD OF CAI...CUI...ATION: l'Hl'.{ ANGI...E-AVERAGED MEI'HOD VE]<TICAI... St:.CF.I. ON: (.,AI...CUI_AIED USING PROPOSAL OF N ,:.7-.4~ W COMMENTS: THANI< YOJJ **************************************************************** · x- T FI I ~ ..... ,.~ SURUEY .I.S CORRECT TO THE: BEST OF MY .x. · x'KNOWI~I~DGE AND IS rS,,UI:)PORTED BY ACTUAL F'IEI. D DATA,.x. · x. -~.X. .x..x..x..x. -x..x. .~. · x. ~, C(]M~NY REPRESENTATIVE .x. · x..x..x..x.,.x. ,.x., .x., .x..x..x..~.x.,,, .x..x., .x..x., .x..x.,,, *** .x. ** .x.,,, .x..x..x..x., AHF / SCIENTIFIC DRILLoING ANCHORAGE OFFICE P AGE JCIB NUMBER: H E: A ~,S, V E R T. V E R '1", l) IE P 't['H D E P 'i" I"1 o,:~l: C ..... I' . ,14 1.40 5,15 13,35 11 O0 , O0 1084 , 52 138,80 1200 , O0 1178,19 173,80 1300, O0 1270,33 212,67 1400, O0 1:~61 , 14 254,52 1500 , O0 1449 , 74 300 , 85 INRUN SURVEY BY THE ANGLE'-.AVERAGED METHOD C 0 tJR ¢'' · :,El:[NC BEAR IN(; DEV. D H D M ,22 0-15 N 21'-10 IE ,65 0-30 N 30'- 8 E .31 1- 0 N 12- 7 E .93 3-30 N 33-31 W ,28 6- 0 N 37-46 W 11 , 68 ~' '~= z""~,~ N 42'44 W 15,36 10'"'15 N 40'57 W 19.51 18-15 N 38-88 W 22,92 14-15 N 36- 1 W 26,93 17- 0 N 35- 6 W 30,90 19- 0 N 30.-30 W 35,02 22-' 0 N 29- 4 W 38,87 23-45 N 27-12 W 41,87 25-45 N 25-1'1 W 46,37 29-30 N 25-T57 W DATE: 06121/82 COORDINATES LATITUDE DEPARTURE D'"'L..EG PIER 100 ,20 N ,08 E ,25 ,79 N .,."56 E ,26 2,01 N ,83 E: ,55 5,87 N ,11 E 2,89 12,60 N 4,72 W 2,52 21,52 N 12,27 W 1,53 32,96 N 22,51 W 2,85 47,97 N 34,98 W 2,06 66,21 N 48,85 W 2,08 88,12 N 64,51 W 2,76 81,25 W 2,45 98,64 W 3,04 116,97 W 1,89 135,45 W 2,17 155,34 W 3,76 114,10 N 144.49 N 178,77 N 216,34 N 258,23 N A. AMi"- / SCIENTIFIC DRILLING ANCHORAGE OFFICE PAGE JOB NUMBER: M i::. A,:~, V E R 1' V E R T, I) E P T FI I) E P '1' FI S I'.'-. C T, INRUN SURVEY BY "['FIE ANGL. E-AVEI:~AGED METHOD [;OUR SE I Nil; BEAR I NG DEV, D M D M DATE: 08121/82 COORDINATES I_ATITUDE DEPARTURE 1800,00 1535,68 351.(74 51,13 32- 0 N 25'-19 W 304.39 N 177,33 W '1700,00 1620,49 404,89 52,99 32- 0 N 25-28 W 352,26 N 200,05 W o , 223 1800,00 1705,41 457,87 52,81 31-45 N ~.6-17 W 399 77 N .... 10 W 1900,00 17~{],56 510,08 52,44 31-S0 N 24....53 W 447.07 N 245,74 W 2000 00 1875 7'1 562 48 ' ') 44 31-45 N o,~._=:,~ W 4~4 44 N 288 23 541,81 N 291,58 W 589.29 N 315,09 W 637.15 N 337,85 W 685,28 N 360.01W 734,26 N 382.1(I W 2100.00 1980,83 615,25 2200 , O0 2045,43 668,22 2`300 , OO 21`30 , 24 721 , 17 2400 , 00 2215,04 :774,09 25{]0 , 00 2299,38 82'7,72 2800, O0 2383,25 882.08 2700 , 00 2488,40 934.44 2800, O0 2553,09 98'7,5'7 2900,00 26`35,99 1043.45 3000.00 2718,77 1099.52 54.46 33'- 0 N 24-20 W 784.00 N 404,29 W 52,44 30-15 N 25- 0 W 831,65 N 428,18 W 53,18 34- 0 N 25-35 W 879,73 N 448,90 W 55.92 34- 0 N 25-43 W 930,14 N 473,10 W 56.10 34-15 N 25'-53 W 980,65 N 497,52 W I) .... LEG PER 100 2,50 ,08 ,50 ,78 ,80 ,40 ,18 .83 .07 1 ,14 ,31 2,77 3,7(.') ,07 ,27 AMF / SCIENTIFIC DRILLING ANCHORAGE OFFIC. E PAGE S JOB NUMBER: 1333 M E A S. V E R T. V E R T, D E P T H D E P T H S E C T, Si 00, O0 3200, O0 S300, O0 3400.00 3500, O0 3600 , 00 S 700,00 3800,00 3900, O0 4000,00 41 00,00 4200,00 4300,00 4400,00 4500, O0 2801.06 1156 2882.98 1213.64 2964.39 1271.69 3045.16 1330.62 3125,42 1390,28 3205,28 1450,45 3284,88 1510,96 3364,22 1571,82 3443,29 1633,03 3522,62 1693,90 3603.91 1752.14 3688.13 1806.06 377~'.~. 62 1857.93 3858.77 3943,69 1963.16 DATE: 06/21/82 INRUN SURVEY BY THE ANGLE-AVERAGED METHOD COURSE INC BEAR lNG DEV, D M D M COOR D I NATES D'.-LEG LATITIJDE DEPARTURE PER 100 56.82 35- 0 N 25'-42 W 1031.80 N 57.36 35- 0 N 26-10 W 1083.39 N 58.07 S6- 0 N 26-12 W 1135.50 N 58.95 36-15 N 26'-38 W 1188.30 N 59.66 37- 0 N 27-- 6 W 1241.~°..~ N 60.18 37- 0 N 26-40'W 1295.19 N 60.53 37-30 N ,26- ? W 1349.41 N 60.88 37-30 N 26-19 W 1404.I)3 N 61 .22 38- 0 N 26-35 W 1458.84 N 60.88 37- 0 N 27'-28 W 1513.07 N 522.24 W .76 547.32 W .27 572.95 W 1.00 599.18 W .36 626.14 W .80 653.35 W ,26 680.26 W .60 707.15 W .12 734,42 W ,53 762.08 W 1.14 58,25 34-.15 N 53,91 31- 0 N 51,88 31-30 N 52,44 31-45 N 52.81 32-' 0 N 27-45 W 1564.69 N ?89.07 W 2.75 28-41 W 1612.19 N 814.56 W 3.29 28-36 W 1657,72 N 839,43 W ,50 28-38 W 1703.75 N 864.54 W ,25 28-I3 W 1750.19 N 889.68 W AMF" / SCIENTIFIC DRILLING ANCHORAGE OFFICE PAGE 4 J 0 B Pi IE A S, DEP TH 4800 4700 480 O 4900 5000 51 00 520 (! 5S 00 5400 NLJHBIER: VIER 'F. D E P 'Ir' I..I VIER T, ,:~EC 1'. 0 4028.49 2016.15 0 411S.S0 2069.1S 0 4197.87 2122.48 0 4;281 .50 2177.S0 0 4S64.89 22~8,48 DATE: ()6t~1/82 INRUN SURVEY BY THE ANGLE-AVi-_-RAGED HE'rHOI) 0 4448.58 0 45~1.91 0 4615.54 0 469~.52 C (3 U R S E I N C, B E A R I N G DEV. D Pi ][) Pi C (] O R D I N A TIE S D -' - I... E G LATITUDE DEPARTURE: PER 100 52.99 32'- 0 N 28-51 W 1796.75 N 914.99 W .34 52.99 32- 0 N 29.- 4 W 1843.11 N 940.65 W .11 53.~6 32-~0 N 28-41 W 1889.84 N 966.42 W .54 54.83 34'- 0 N 28-50 W 19~7.91 N 992.80 W 1.50 55.19 3~-' 0 N 28-56 W 1986.24 N 1019.46 W 1.00 8287.S0 54.8~ 2S42.48 55.19 2S97,29 54.8S 2451.55 54.28 SO N 28"=58 W 20S4.21N 1046.00 W ,50 SO N 28-58 W 2082.50 N 1072.75 W 0 N 29- 8 W 21~0.4~ N 1099.55 W .51 45 N 29-85 W 2177.78 N 1125.89 W .29 THI!!: HORIZONTAL DISPI_ACEMENT AT THEE DEEPTH OF 5400 O0 F'IEIET EQUAI...S ~ ~' , , . ,_4..~1 61 FEIET AT N 27-20 W Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~nd Number 'd~e-r~t~r, Reports and Materials to be received by: Required Date Received Remarks Ccmpletion Report Yes Wel 1 History Samples ~.. ~ ;~ .. ;' Core Description ~/~ ~/~_~, Registered Survey Plat '"'":}~ Inclination Su~ey ~~ ..... /' , ,. Drill Stm Test Re. ms , ~ /~... , Pr~u~i°n Test Re~s y~ ~ ~s R~. Yes /'"Digitiz~ ~ta ............ :/~'5,, , ........... ~.~, .%% .~,- ,, , .~ F~rm 9-330 (l~ev. 5-63) 15. UNi{ iD STATES SUBMIT IN;DUPLICd'" (See other In- DEPARTMENT OF THE INTERIOR reverse side) GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: o!I, C~ CAS ~ DRY [~] Other w ELL W ~:I,I, b. TYPE OF COMPLETION: 1VEI,L OVER EN BACK EESVR. Other 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3..II)DRESS OF OPERATOR PO BOX 6247 ANCHORAGE AK 99502 4. I,OCATION OF WELL (Report location clearltl and in accordance udth any ~tate requirements) At surface 429'N & 1288'E of SW corner, * At top prod. interval reported below ~ . .~lto8t.gl'gp~ 393'E of SW corner, ,, 14. PERMIT NO. 265}'N & 1}6'E of SW corner, * ':. 4"., DATE SPUDD'" I 'e' DATE T'D' REAC"ED I ~;' DATE COM~L' (n'aa" to proa')6/9/82 6/17/82 7/11/82 Form approved. Budget Bureau No. 42-R355.5. 5. I,EASE DESIGNATION AND 81~RIALNO. A-028142 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME KENAI UNIT $. FARM OR LEASE NAME 9. WELL NO. KU #13-6 10. FIELD A~D POOL, OR WILDCAT Kenai Gas Field qt-,:,v,l ~ nn Pnnl ~T.'s't~.?~.,' ~., ~'., ~gFLOC~ ,ND SURVEY OR AREA Sec. 6, *T4N, RllW; SM. DATE ISSUED 12.COUNTY OR ] 13. STATE PARISH 6/9/82 Kenai ~K . KB'+90' MSL --- 20, TOTAL DEPTH, MD & TVD5500{' & 4783' 21' PLUG' BAC'K T'D*' MD & TVD I 22' IF MULTIPLE COMPL*'------ HOW M 24. PRdDUCINO INTERVAL(S), OF THIS COMPLETION~TO~ BDTTOM,-,NAME (~[4ND TVD)s i521-4597' MD 3961-4026' lVD''~ ~ B-3~ Sa~ 5178-5268' MD 4513-4589' TVD':~ C~ S~nd . r'~ ,/". 23. INTERVALS DRILLED BY ROTARY TOOLS CABLE TOOLS I 'Total { -',- 25. WAS DIRECTIONAL SURVEY' MADE 26. TYPE ELECTRIC AND OTHER LOGS OIL-mC-Sonic OH-VDL ! ... 28. :,' ; CASINO SIZE ., ~".~ 5/8" 29. - ' SlZE I 27. WAS WELL CORED , I '"; ' ;2- ' ' ' .., .' ; CEMENTING RECORD' ~.j ~,". '.~. AMOUNT P~LED - : ' 5~t" .} ~;1~ ' r2000 sxs _,.,- ..o :q ~ .-, ,-'. :: '- '.' I f~l ~; - ' ' ' ' ~o. ~um~o a~U%~ ......... ,.-. 'r. c .... u z .. , :~: '~ ,.~¢ ~1,-., 3 t/2" 5090_" . ..... '~' ~' ~' ~" :¢': ~::~ ~'~ 3 t/2" ,'I iS,I q. I --~ ¢ ' ' .... - WEIGHT. LB./FT. 47# TOP (MD) .. 31. PERFORATION RECORD (Interval, st~e and number) .~. C) · ~_ > {-,,mm : A~.~D -~HnT FRACTURE, OEMENT SQUEEZE, :~C~. ; - ' t~-; _~ d- fu ~i~, (~, k~,'/ "~ ..... ,. '- - .. ,. . ., ' . %80-4082'-MD '4'HPP- ~z'd w/'500 'sxs .l o l- - 'l' 500 ~.Xs'"cmt' sqz -.:~ J~ :: :. ~ 4521-4597 ', .D 8 hPf , / ':' I >oo ~:~:~ cmt:. sqz :482~-48~ HD 4 HPF- ~ d ~ 300 ~ ~ :~ '::;:;~ ~ I Al 7R-S?~R MD a HPF v: ~ r,-i I ,,'i:, : ' :: ~..' : I '. ............. ~ 7: eaULdfl}' ..~ ".' ~..' '~: ::.' '.~ocucing:' :~.:' DATE FIRST PRODUCTION [ PRODUCTION METHOD .( Flowing, gas lilt, pumptng~st~e and~Si¥pe o/ pump) ,})'i--~->a'~ ...... ................. F'ioWing :: ~/19/R2 24 ~'. o~- ,~, ~ ;: ~ [~ 4.27/8. ,.., - . ,~...~ : ' ~nnn/onn I I ' > "': ~' 4~. ~.5~ -~ , .... . .... .,. - ', .if ? '2' :, ' ,..' h:~ . - 'L ' Enid .-::..., - ' . . .. 35. LI8~ OF A~ACHMENTS :,;~ . ~., ': ~6. I hereby cert~y that the foresoing and at~ched inform~on l~o~l~te~nd correct as..deiermined from all available ~e~s.. (See Inst ces for A~ditional Data 0n' Revere Side) INSTRUCTIONS : . G~ncral: This form is designed for submitting a complete and correct well. completion report and log on all types of lands and leases to either a Federal agency or a SLate agency, or both, pursuant to applicable Federal and/or State laws and regulations.! Any'necessary special instmlctions concerning the use of this form and the number of copies to be 'sUbmitted, particularly with regard to local, area, or regisnal. Procedures and praci~ice~, either are shown below or will be issued by, or may be obLained from, the local Feden~l and~'~r State office. See instructions on items 22 and 24, and 3~:be'low regarding separate reports for separate completions. If n~t~ filed prior to the time' this sugary record is submitted,,d~.P~Les Of alll currently available ]~ogs (drillers, geologilsts, sample and core analysis, all types electric, etc.), forma- tion'-dnd pressure tests, and directiqaal Surveys, should be attacl~l~:hbreto, to ~the' exten~ reqfi_f.red by applicable F/~deral and/or. State laws and regulations. All attachments srio~iId be listed on this form, see item 35. i$.~m 4: If there are no applicable ~ate requirem~t~ilocations on Federal or Indian land should be described in accordance ~i.th Federal requirements. Consult local Stain or Federal office for sPecific instructiO-jas .... I~¢m ]8: Indicate which elevation is-).lsed as refere~c;~ (where not otherwise shown) for depth measurements given in other spaces on this form and in any I~¢mE 22 a~d 24: If this well is completed for separ~]:eq~r0duction from more than one interval zone (multiple completion), so state in item 22, and in item 24 shuw ~he producing inter~al, .or intervals,~.top(s), bottom(s), and name{B):j(if afiy) for only~the interval reported in item '-33. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing th,~additional data pertinent to such interval.. · I$~m 27: "Sacks Cetne'nt": Attached supplemental recordS'for tl~is)Well should show the details of any multip.!..e, stage cementing and the location of the cementing I$~m 33: Submit a separate completion report on this form for .~acjlinterval to be separately produced. (See instructio~n for items 22 and 24 above.) SHO~' Al,I. IMPORTA~ ZONES OF POROSITY AND CON~TB THERBOF; CORED INTeR'AL87 ~'D ALL DRILL-HTEM TESTS, INcLU~.INO DEPTH INTERVAL Ig~TED, CUSHION USED, ~IME TO0~ ~ENi FLOWING AND SHOT-IN PRESSURES, A~D ~ECOVERIE8 x- 5.~ PoO'l ~ B-3 Sand >5.2 ¢ool · B-5 Sand :: ~6 Pool ~: ~'~i' Sand , ~,,~;, . ..: ; ,.. / '4521' "::~' '4597' ' 6.98 MMCFPD w7:9.~ BWPD~._~ 780 psi Final ravel i~:6"MMCFPD W/ 4.~.,6 BWPD 4823' 4833' 50 MCF for 1 i:h~.]]test $. ~50~,i.:~i ' . & +1000 BWPD ~ :.... 5778,'-' : 5183' 5.~ MMCFPD~ w/ 9.6 BWPD ~ 720' ,psi 5178' ~-5268' 10.4 MMCFPD w,7 ~_~.6 BWPD,~.~ 800~ psi - F~nal fete 9,6 ~MMCFPD w,/ 4.~8 BWPD , ~"--; . ~ 75o ~si. . ~ .~ . C ' /- ' '~ ' ' '" -38. C EOLO(.; IC MARKERS NAME T/Sterling Gas Sands T/Beluga Fm. TO I' MEA8. DEPTH 4080' 5423' TRUE VERT. DEI>~H 3593' 4740' U.S. GOVERNmeNT P~INTING C~'FICE: 871.233 , .,. STATE OF ALASKA ~._. ALASKA ~'" . AND GAS CONSERVATION CO( AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation [] Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 82-85 3. Address 8. APl Nu~_20356 PO BOX 6247 ANCHORAGE AK 99502 50- 9. Unit or Lease Name KENAI UNIT Location of Well at surface 429'N & 1288'E of SW Corner, Sec. 6, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB +90' MSL A-028142 10. Well No. KU ~13-6 11. Field and Pool KENAI GAS FIELD STERLING POOL For the Month of 3uly ,19 82 Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 3 1/2" tubing fish - TOF $ 5395' ETD TMD 5500' Released Rig ~ 12:00 hrs 7-11-82 13. Casing or liner run and quantities of cement, results of pressur9 tests Set Baker "D" pkr ~ 5065 w/ 3 1/2" tbg string Set Baker "FH" · 4728' Set Baker "A-S" dual pkr ~ 4430 w/ 3 1/2" tbg string. 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed for production 4521-4597 8 HPF 5178-5268 8 HPF AUG - 5 iS82 0il & Gas Cons. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N eport this form is required for eac ss of the status of operat'~ons, and must be filed in duplicate with the Alaska O.~nd Gas Cor~servation Commission by the ~ 5t~l~'~b~c ec ed-~g month, unless otherwise directed. Form ~ 0-404 ~ Submit in duplicate Rev. 7-1-80 ~ ~A STATE OF ALASKA ' ' - ALASKA O~AND GAS CONSERVATION COII~ISSION MONTHLY REPORT OF DRILLING AND'WORKOVER OPERATION 1. Drilling well ~ Workover operation [] 2. Name of operator 7. permit No. UNION OIL COMPANY OF CALIFORNIA 82-85 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20356 4, Location of Well 9. Unit or Lease Name at surface : KENAI UNIT 10. Well No. 429'N & 1288'E of SW Corner, KU~ #13-6 . Sec. 6, T4N, RllW, SM. 11. Field and Pool KENAI GAS FIELD 5. Elevation in feet (indicate KB DF, etc.) I 6. Lease Desig~at~o~)erial No. KB +...~0' MSL ' STERLING POOL For the Month of Oune ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling' pro;blems, spud date, remarks Commenced operations $ 00:01 hfs on 6/6/82 Spud $ 16:00 hfs 6/9/82 ' 13. Casing or liner run and quantities of cement, results of pressure tests ' ' Drove 20" condUctor to 96' RKB - ~ Ran 2008' of 13 3/8" 61# K-55 csg - cmt w/ 1435 sxs -,.tested to 2500 psi ok Ran 5499' of 9 5/8" 47# N-80 csg - cmt w/ 2000 sxs - tested to 3000 psi - ok 14. Coring resume and brief description None 15. Logs run and depth where run -- ~* DIL-SP-BHC-Sontc-0HVDL-GR & FDC-CNL-GR f/ 5500' to 2008' JUL ~ 9 982 CBL-VDL-GR-CCL f/ 5410' to 800' Commission {nCnorage 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed for ~solation sqz f/ 4080' to 4082t w/ 500 sxs - dry tested ok. Perfed Pool 5.2 f/ 4823' to 4833~ & production tested wet Sqz'd & abandoned w/ 300 sxs - dry tested ok. 17. I hereby cer~ that the foregoing is true and correct to the best of my knowledge. SIGNED ~ BIST BRL6 SUPT DATE 7/14/82 NOTE--Repor~ o/~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Cc~ervation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Attention: Mr. William Va TRANSMITTING THE FOLLOWING: unl __n Permit No. APl Number o- 133-20356 aska 0il & Gas Conservat C. Warth~'~ 'Un,for LeaseName KENAI UNIT Commission 0. Box 6247 &We, No. Anchorage, Alaska 99504 I KU #13-6 urvey angentia 3rection. · STATE OF ALASKA ......... '-',, ^ ~-,,~k, r,r~f i!SSlON I~ Document fransmitta~'-~r~ Union Oil Company of Califo~, ..... ' 1. Field and Pool KENAI GAS FIELD STERLING POOL 11 ted to 2500 psi - ok ed to 3000 psi - ok Oil &/~as Cons, Commission nc.bOrage FORM 1-2M02 fREV, !1-72) PRINTED IN U.S.A. ~"~" ......... dry tested ok. Perfed Pool 5.2 f/ 4823' to 4833' & proauc[zo,, L:o~:. wet Sqz'd & abandoned w/ ~00 sxs - dry tested ok. 17. I hereby cerCt~that the foregoing is true and correct to the best of my knowledge. SIG D - Oil and Gas C ~ DIST DRLG SUPT DATE 7/14/82 this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Form 10-404 Rev. 7-1-80 9rvation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in dUpliCate June 4, 1982 P~r. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Re: Kenai Tyonek Unit KU 13-6 Union Oil Company of California Permit No. 82-85 Sur. Loc. +_425~N, +_1495'E of $~V er See 6, T4N, I~llW, Btmhole Loc. :~2490'N, _+210'E of SW er Sec 6, T4N, 1t.119/, SM. Dear Mr. Anderson: Enclosed is the approved application for perruit to drill the above referenced well. Well samples and a mud Icg are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log tnfo~ation shall be submitted on all logs for copytn// except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spa. wnin~ or migration of anadromous fish. Operations in these areas are subjeat to AS 16.0§.870 and the regulations pr~l~ated thereunder (Title 5, Alaska Ad~ini.strative Code). Prior to convincing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Pollution of any waters of the ~tate is prohibited by AS 46, Chapte~ 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended, Frior to eocm~ncin~ operations you umy be contacted by a representative of the Department of ~nvironmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is Robert T.. Ana.~ son Kenai Tyonek Unit KU 13-6 -2- June 4, 1982 spudded. We would also like to be notified so that a representative of the Commission may be present, to witness testint~ of blowout preventer equi~ent before surface easing shoe is drilled. In the event of suspension or abandonment' please give this office adequate advance notification so that we may have a wi tness present. Very truly yout'a, C, V. Chatterton CIca i r~n o f aBYna a~[~ O~ T,~_ Alaska Oil ~as ~nservatlon u~lssion Ene 1 osure cc: Department of Fish & Game, Habitat Section w!o enel. Department of Environmental Conservation w/o enc. l. CVC~be Union Oil and Gas ~l'ison: Western Region Union Oil Company' of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600' union Robert T. Anderson District Land Manager June 1, 1982 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001Rorcupine Drive Anchorage, Alaska 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KU #13-6, A-028142 (8-86-71-5390-600972) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill KU #13-6 in the Kenai Gas Field. Also enclosed is our Check .No. 19200 in the amount of $100.00 to cover filing fees. sk Enclosures (4) Very truly yours, cc: O. R. Callender A. Lannin-LA Office JUN - 1.982 ~aska Oit & Gas Cons. Commission Anchorage PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL'[] DEVELOPMENT OIL [] /j~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS]]~ MULTIPLE ZONE 2. Name of operator UN[ON 0IL COHPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface 9. Unit or lease name +425'N & +1495'E of SW Corner, Section 6, T4N, RllW, SH. KENAI TYONEK UNIT At top of proposed producing interval 10. Well number +lgO0'N & +400'E of SW corner, S.6 T4N RllW SM. KU #13-6 At total depth 11. Field and pool +2490'N & +210'E of SW corner, S.6 T4N RllW SM. 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. KB +90' MSL A-028142 KENAI GAS FIELD 12. Bon'-d information (see ~0 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount $200,000'.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling Or completed ' SoItt_h 6 miles 210 feet well ~ .feet Propos-d depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date { ¢;-55[3 '-'7~IJD 5700 ' ~"v'_.O feet 2560 6/1/82 F POINT 300 feet. MAXIMUM HOLE ANGLE 34 oI (see 20 AAC 25.035 (c) (2) . ~J~)_Q~psig@,_ 5000ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) - 20" 94# H-40 Plain 100' 0 I 0 +100~ +100 Driven ~7 ~/? 1-~ ~/a ¢;1~ K-55 Butt. +2000 0 0 +.~0Og-~-- +~_1100_ __ sxs to surf'. 17 1/lz 9 5/R 47~ N-80 Butt. ..~e~' 0 , 0 '_~r,~ee~~ ..+l~uu sxs to sur[. 22. Describe proposed program: 1. Move in and rig up Brinkerhoff Rig #59. 2. Drive 20" to refusal at +100' and install diverter. 3. Drill 17 1/2" directional' hole to +2000'. 4. Run and cmt 13 3/8" csg to 2000'. - '~7~, -- R E C E I VE 5. Install and test BORE to 3000 psi/.~- ~ ;~ 6. Drill 12 1/4" directional hole tc~_-~' TMD, TD 7. Run logs. ' ' JUN - 1 1982 8. Run and cmt 9 5/8" csg to 9. Test and complete well as d-ual Sterling producer Alaska0il& Gas C0ns. C0mmissi0n · Anchorage 23. I hereby certify tha~t~[.~o'm~j~true an~orrect ~o)the best of my knowledge SIG ~n/d~/ ~ ~TITLE District Land Hgr DATE 6/1/82 The space below for Commission use / CONDITIONS OF APPROVAL Samples required I Mud log-required Directional Survey required I APl number OYES ~NO []YES ~'NO ]~[-YESONe150--/ 3- Permit ri'umber Approval date ~ff~/ .~.~/"'"'~C~/~041,112,...,... ..,.. /7 J SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY (.~/( ~ ,COMMISSIONER DATE ,]1]1~ / / by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 ) ) ADDENDUM TO KU #13-6 USGS DRILLING PERMIT SURFACE USE PLAN The surface location of well KU #13-6 is located on Federal land and will not require any additional access road construction. Enclosed is a copy of our Kenai Unit Field facility map which reflects the subject location, existing wells and all existing field access roads end production equipment. Also attached is a plat of the pad layout. Fresh water for drilling operations will be taken from an existing water well on the pad. No construction, other than leveling the existing permanent 14-6 drilling pad, will be necessary. Any gravel materials for the leveling of the pad will be obtained from a nearby private source. The existing field sewage disposal system will be used. Drilling fluids will be contained in an existing gel-lined reserve pit for temporary storage and will eventually be disposed of at an accepted waste disposal site. When the reserve pit level of the 14-6 site exceeds 75% of its capacity the excess pumpable liquids will be taken to the Sterling dump site. The drillsite pad is a permanent location. It is anticipated that the well will be productive and operations will not be detrimental to the environment. Union's field representative is Sim R. Callender, Union Oil Company of California, RO Box 6247, Anchorage AK 99502, 276-7600. I hereby certify that I, or persons under my direct supervision, have inspected the proposed drillsite and access route; that I am familiar with the conditions which presently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and, that the work associated with the operations proposed herein will be performed by ED SALTZ and its contractors and subcontractors in confirmity with this plan and the terms and conditions under which it is approved. DATE /~."3im R. Caliender ~ Dist. Drlg Superintendent RECEIVED JUN - i982 Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM TO KU #13-6 USGS DRILLING PERMIT Surface Formation: Superficial glacial deposits of sand and gravel Estimated Geological Marker Tops: Base Glacial/Top Sterling Formation = +LO0' MD & VD Top Sterling Fm. Gas Sands = +3950' MD-(+_3565' VD) Top Beluga Fm. = +--4850' MD (+-4850' VD) Estimated Tops - Gas Zones: Top Sterling Fm. Gas Sands = +_3950' MD (+--3565' VD) Fresh Water Sands: +400' MD & VD Water Sands: 1600-2300 ppm CL from +_400' MD & VD to +-3950' MD (3565' VD) The BORE will be tested weekly per regulations. Equipment and valves will be tested to 3000 psi and witnessed by USGS personnel. Circulating medium will be 72#/CF average mud weight utilizing a gel-water system. This drilling fluid is one of the generic types which have been tested and approved for discharging into Federal offshore waters under the authority of the Federal Water Pollution Control Act. Weight material will be used only as required to slug drill pipe. A nominal amount will be stocked at the location. Completion fluid will be 3% KCL water. 3 1/2" N-80 butt tbg - dual string CIW 13 3/8" SOW X 12" 3M csg head 12" 3M X 10" 5M DCP spool Dual 3 1/2" tree w/ 10" 5M flange Surface facilities for the well will cDnsist of approximately 220' of buried 4" flowline and approximately 70' of buried 4" blowdown line. The routing of theselines is indicated on the As-Built Survey Map attached. RECEIVED JUN - i982 Alaska Oil & Gas Cons. Commission Anchorage CASING SIZE HOLE SIZE ~.'MUD WT. 'r STA~ 41 l~.sk,.._ DATE 5-/27/~F.~ DESIGN BY 75 ,~/~: ~o GR. z.S[I psi./f.t__ MUD ~. IZ ~/g. HYD. GR. II , psi/ft. ~.S.?. :" INTERVAL Bottom Top ~09o, , ,' , o i~oo TVlD ~4o ,o... c '-I~ TVb Wt. DESCRIPTION Grade Thread '&EIGHT TENSION 52N!-ML~4 TDF COLLAPSE COLLAPSE W/BF ... -top of STRENG~d PRESS. ~ ~ZSIST. W/O B? section TENSION bottom tension lbs lbs 1000 lbs . ,, psi , psi CDF BUPST IET£RF~L PRESSURE YIELD psi psi BDF PP_vCE PER PT. , COS2 6870 Formulae: Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = ~s? + ~ ( Hyd. Gr. Iz --.5) BF (Bouyancy F~c'tor) = z.oo - (o.oz~3 x ~ud Wt. Z) Calculations: 'Total Cost 3.000 RECEIVED JUN - 1. ~982 Oil & Gas Cons. Commission hnch0rage ~oo0 .o .o CHECK, V,~ · · G,~TE VALV£ e. · JUN - 1 i98~' Alaska Oil & Gas Cons, Commission .~nchorage . · .. · o '"2 HY~,?A YLI£ ' OP£Pv4 TED VALVe. · .. ' . ' . . . PIPE dA/.loe · - · )~OTC ' ALt. CHANGES hlUST HAVE WRIT.TEN APPROVAL BY THE DISTRICT ' · o- o .. . . · · · .. · o RECEIVED . .. JU~ - t ~82 Alaska Oil & Gas' Cons. C0mrnissio~ ' '~ Anchorage ---- ,4/YGLEO ,FILL UP . .o. . . .." ...- o,..~ . .'... *. · · . .-,. :, , . . Z.-..I -.: . .....: ~?~-/~,,,,~ '(s'.) "- '.":i..~.: . .~ r~r~ :. · :.-L~,~' ~z~'%'~~'..'''..t. · -. .. .., ...' :; :. · .. '"'- .. · . . (I ' 20" ~oo~ e~',. ,~ ~51~" T~ooo el*. 2. c~': Zooo e~,'~ '5. o.~,.~. UOTE ' ~o" ' ALt.. CHANGES hlOST HAVE %YRIT.TEN APPRC',/2, L BY THE CISTRICT ~ O.qlLt_l;{G SUPSRI:ITE,NDE NT RECEIVED . DAT~ l:'ORrtd ~'&7 (l'qll~w JUN - 1 i982 Atas~ Oil & Gas Cons. Commission t~chorage "UNION 611. CO~LPAN¥ OF CALIFORNIA i i[ iii D/AWN ~ CLOD. ~ AJ)P'D. SGAL~ , ,, DATE S H F..~I'S J 14-4 +~ AND AIIOT[$ 4- ~r ~ ( P.P.) s~ imvfNdmndaA UNION OIL COMPANY OF CALIFORNIA AS- BUILT SURVEY LOCATION K.U. 14-6 Anc~orog~, A/~, 99~0;~ DATE - · AIL 14 16 PAD LIMITS -. ": £,-462,200 0 Basis in A..c. -1o05 AUDR Lot. 6( 'Long. I Y: Metal va, SITE · BTU/hr. hgrt - SR u 4- ! I ! ! -F I 12 w ?4 TMO :eu.$E-? '~ u-M KU- ~n z u-. / I + I I ' 1 ! I ! ...,~ITE I4-4 -' ~U-14-4 I.S m~ 8TU/'hr, Mc Rr:c~lv~ r .... J Alaska Oil & Gas Cons, C~ion Anchorage union KENAI GAS FIELD PRODUCTION FACILITIES CHECK LIST EOR NE~W WELL PERMITS Company Lease & Well No. IT~-M APPROVE DATE · 3. 41 5. 6. .7. 8. (3) Ad min~7~J~- ~/-~' 9. .__'~/) thru 11> 10. 11. (4) Casg ~. ~.~. ~-ff' fff--12. (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. YES NO Is the pemnit fee attached .......................................... Is well to be located in a defined pool ............................ ~ ~-~__ Is well located proper distance from property line ................. Is well located proper distance from other wells .................... Is sufficient .undedicated acreage available in this pool ............ Is well to be deviated, and is well bore plat included ............... Is operator the only affected party .. ., ............. Can permit be approved before ten-day ;~i~' ..~..[i ........ Does operator have a bond in force .................................. ~._ Is a conservation order needed ....................................... / Is administrative approval needed ................................... Is duct stri g pr vid d ' con or n o e .................... ............ . ....... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ............... , ..... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension~and burst. I~ this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... R~MARKS (s) (21 thru '24) 21. 22. 23. 24. Is a diverter system required ....................................... z~ Are necessary diagrams of diverter and BOP equipment attached ....... ~f Does BOPE have sufficient 'pressure rating - Test to ~..~??.. p.s.~g... ~ , Does the choke manifold comply w/AP1 RP-53 (Feb.78). · ....... (6) Add: ~_~,~. Ge ology: Engine~ring: HWK__ LCS ~_~_~_ BEW _~ WVA JKT.-~'RAD ~ jAL ~.MTM ~ rev: 01/13/82 25. Additional requirements INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company UNION OIL COMPANY OF CALIFORNIA Well KU 13-6 Field KENAI GAS FIELD County, State KENAI, ALASKA Date 6-18-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RILD , Indu,,ct,ion ,Log -,D,.e, eP ....... Dill .2-2000 RILM " " - 'Medium " " RFOC " " - Focused " " GR · Gamma Ray " 0-100, 100-200 SP Self Potential " 0-100, 100-200 CAL Caliper CDL ' 6-16 DEN Bulk Density CDL 2-3 CN Compensated Neutron CN 60-0 AC Accoustic BHC AC 150-50 GR1 Gamma Ray CDL 0-100, 100-200 DENP Density Porosity CDL 60-0 CORR Correction Curves CDL -.5 to .5 RECEIVED nnT 1982 · .~ .~,,, mt ,.o,. GaS C!:~'~.; ',.' .... ';~ ................... lu::,,,, .... Anchorage " , ,,,, ,,, , , ,, , , ,, , ECC NUMBER UNION OIL COMPANY OF __C__A_.L___!.E~__R_N__I_~_ KU 1;5-6 CFOC CIL~ CILD SP FROM 1955,00 TO 5 5 ~-~-'~"~-~ .............................................................................................................................................. _7~_~_~:_E ................ C~i~,_-/_-_._ ~i S~?~-~ ~_~ ' ::_~Z~Z~'~ 62, SAiqPLES PER RECORD PAGE i UNION OIL 200~. 27 2006 29 3 79 8 1~4 ~ 68 35 ~ 68 2012. 55 5 66 2 1~5 2014. 57.6 65.6 1~ 2016. 35.2 2018. 59.0 2020. 38.3 2022. 56.2 202~. ~1.~ 2028. 58.5 5~.~ 1~0.5 11 7 37 20~. 38.1 6~ 5 139 20~&. 56.6 6~ 1 159 20~8. 57.1 62.7 1~8.5 9 !5 PAGE 2 WITH OIFL O PTH GR1 SP ,AC API MV R F QC .B_ILM _ _R_~ G R .......CN ......... QEM__DENP ...... CaJ. .....C.OR 2050, 35.7 ~3ol 137 11 2052 36 8 ~3 3 140 8 11 2054. ~1.5 ~2.7 13B.O 2056, 39.5 4,2.4 137.6 2066. 30.8 143 6 11 9 13 2068. 37,2 2070. 37.8 2072° 2074 41 8 2076. q..0 ~.1.1 139 7 ~i~ ~T~~~! ~ ~::: ~:~::i~?::~{~: ~:~:~::~:: :::~ ~::~ 2088. 37.0 PAGE UNION OIL COMPANY OF CALIFORNIA 2100. 37.8 38.5 APT ~ G/£ ~ 2102. ~0 0 38 3 139 210 36 8 2110. 38,2 ~,~ 139~ A~ L ~A ~ ~ :..:~: .:..;~. ~.~:~,.~ ~:~.r.?.~..:~:~...~.~< .~...~.:.~:~ ~<?..v~ .=. <.~.~ · · :.?: ...: .: ~?... :.:~.~: ~. ~...~......~..,:. :......:~. ~ ~..~ .~..~.....:~:.. .... ::.. 211~. 39.~ 38.2 139 8 2116, 39.6 1~0 6 10 2118. 35.6 2120. q5.6, 2122. 37 1 212~. 38.3 2136. 36.6~.~6.8 132.8 8.5 2i38. 37.5 ~9 i36.o 21~8, ~0.2 ~0 7 132 PAGE UNION OIL COMPANY OF CALIFORNIA DEPTH GR1 SP AC RFO_C _RILMR__~. 15~ 2156, 2158 2160 216~, 2166, 2168, 46,9 2170, 2172, 217~, ~0 3~,0 39,6 135 :56 9 39 37 2 5;) 2 129 5 6q. 66 2176, ~2,8 59,2 ....... = ......... ~ :~:: ::~:~ ~::~:::..;~::~: ?]: ~::... ~::: o19 =6 2196, ~ ~..~ ~2,0 15~.6 ~,~ 21~8, ~O,O ~7,6 1~0.0 8 1 8 PAGE 5 UNION OIL CONPANY OF CALIFORnia6. :'?' KU i3'6 IlS-RUN __ _GR _ CN ____DEN OENP ,-£AL ~R- APl_ ....... M_~ ......................................................................... ~_P_.I_ .............. ~ ....... -G/C__ .....~ 2202. 40 i 45.3 )_20 q. 35 7 :206 39 !208 38 0 39 6 134 221q,. 33.9 40.3 140 q. 9 1 .9 2216 8 9 1 9 2218. 38.3 2220. 33.3 2222 222~ 2228. 37~ 67.9 151,~ 6 .,~, ,,...: .:..,. 223~. ~9.2 6~,~9 ~31~2 ~ .... ' Q ~ C 2238. 51.6 65.9 135~5 22~2.~51.2 60.~ 13~7 5~9 ~ 7 B ~5~ ' 1 3-~9 Lt,8 0.1 2248 38 2 PAGE 6 UNION OIL COMPANY OF CALIFORNA~A_ KU 13-6 GR1 IS RUN WITHD_!EI,.. ............................................. DEPTH__. GR1 ....... S_P_ ............. _A,.C_ .......... R_E.O£ ..... J3_~___B_I_LEL ......... GR £.N_ ........ D_E_BL ..... EIENR ..... C-4L---£ORR-. 2252 ~1 3 ~2 0 138 225~ ~2 2 ~4 2256. bi.8 ~7 0 152 2258 41 4 ~2 6 226~. ~6.~ ~5 8 152 7 7 2266. ~0.9 1~7.2 8 ~ 8 2268. 39.6 2272 227~ 38 2276. q.O.7 p~.5 ~6,.7 8~8 8.7 9~4 2278. ~.0 ~0.9 137,8 8~6 8__.7 ~ 2280. 56.2 ~0.2 ~,8 ~ 8 8 8 228~. ~7.0 ~Z.8 l~~ ~.8 8.~ 9.~ ~?.~~.~ 2286. ~~ ~!.7 15~9 ~8 ~..,~, 8 2288. 38.9 59.8 135.~.~,1 8.9 ~292, 37.1 39~2 139,2 9.0 8.V 9.~ 39.2 PAGE ? UNION OIL COMPANY OF _C_..A_L..IFORN]:A_ KU 15-.6 RUN WIIH____..D IFL ............. AP i ...... __GR £N nFN ri ir I~1 D P Al Pni~D ~300 6 q.O 9 '¸3 , 2 16 35 3 3 8 2318. 33.6 2320. 2322. 232~. 36 .. 2330, 39,4 ~.0~3 ~ 5 ~. 9 ~.0 ~ 2332. 3~.1 ~,7 i33~0 .__._. 2336. 36.6 39.B 13~ ~ 2338. 38.1 ~.9 1~0.7 ~8~.7 8.n 23~2. 39.0 39.~ 139,1 ~ 23~6. ~,.. ~3,~q 13a, 19,~ 8.i 9. 38 = ' '~; ....... ~-~"; 8- .................. ~'z - ' ' PAGE 8 UNION OIL COMPANY OF CALIFORNIA .......................................................... KU !_3_,_6_ $_RI I,S R._U_~_C_W._I_?H._D_!.Ek D E P T H G R :L S P AC.. ........ ~EO_C... ....... B~I.L_PI_ ...... R__IJ_D ............... .GB .............. EB/_ .......... BEN DEAIP_ ...... ET ....... A_P_.!_ .............. ~..V_ ............................................................................................. _AP.I ........................ ,~ ............. G/E ........................ 235q. 38 6 ~1 6 133 2356, 38 1 38 2 138 2358 38 0 ~0 q 137 2360 qO 5 ~7 q 133 2362 ~3 3 6~ 9 2364,, ~9.3 69,2 127 2366. 53 9 2368 2370. 33.5 2372, 2374 36 6 5 5 5 2~92 .:8 0 394. ~8 9 ~5 396 36 ~ ~6 2598. 57.7 ~6 5 152 PAGE 9 UNION OIL COMPAN~ OF CALIFORNIA RUN WITH D_IEk ~00 36 q5 2q02 36 2 ~3 404 bO 2406 33 9 ~6 2~I6, 37.~ 139 I 11 2~18. 39.1 2420, 39.8 2422. 37.3 36.5 2~50. 39.1 ~2.7 1~6,3 11.7 !3,1 6 37 1 52 6 128. 8 11 0 12 ~:~.~:0:~:,~.:.. '. ~ 5.~ ~: ?.: ? .~: ::: ~:~ ~:::7 .: :~ ~: ~:~ :~:~::.~ ~:~:~, ~:.:: ~:.~J ~& .~::~. ~:2~ : :~ ::, ~2::::~:~0~.~,~:: ~::::~ ~; ~.5.~ :~.~:,~::~ ;~:~:~ :.:7.::: :,~..: ~:~.0. ~-~ .0 58.2 q8 q 113 ~ 12 7 39 PA6E 10 UNION OIL COMPANY OF CALIFORNIA KU 13-6 GR1 IS RUN WITH DIFL DEPTH GR1 SP FT API M~ ~ ..... RFOC RILM RILD ..... ~ £N __D F N___~ ........ C,-~L,-. CORR- AR! ~ __G/C_ _._~ '2~50. 5~-~ .... %5.6 li6.3 8.7 _9.5 lP._i ~_2_._5 _~,7 _ 2,! 56,1 --19,5---- 0..~ 2452. 47.1 66.4 15 2454. 52.4 65 9 13~ 2456. 44.3 59 7 130 2458. 45.7 56 5 42.9 50.8 2466. 42.9 1~5.1 2468. 42.1 2470. 43.3 2472. 44.7 247~. 42.3 UNION OIL COMPAN[OE C_~_LIF_ORNIA_ ..... PAGE 11 5O0, 45 5 2502, 37 0 65 504. 36 5 64 25 38 6 54 25O 41 5 43 510. 429 40 2514. 38.4 41.0 142 2516, 38.4 144 7 1; 2518, 38,2 2520, 48.7 2522. 45 5 252~. ~:~:~:~:~: :~:~::~:~=~:~':~s~::~:~'~?:.~::~:::::~:~??~:~::~:~: ~. :~:~:~::~ ::~:: : :~ ~:~:~ ~ ~;~ 253~. ~9,5 62.8 124,~ ~ 9~! i 4 1 ~A~ E ~ ' 3 25~2. 48 0 62 544 ~9.9 65 546 47.6 6g 6 150 2548. 43.9 65.4 120 7 9 UNION OIL COMPANY OF CALIFORNIA KU 13 _ DEPTH GR1 SP AP! M~ A C_ .B£__O_C R I L M R I L O ....... CN DEN DENP OiL CORR 2552, 45.4 56.8 131 2554. 41 0 62 6 2556. 40.2 68 0 13~ 2566, 46.0 2568. 43.8 2570. 2572. 35.5 2574. 40 5 =~ '~>~:." ~' ~::~:~:~ :'~"..~x~ ~:~ ::~:~: :~:~: :~ 2578. 37.9 ~6 5 I~,Z ~ 16 ~ _~___ ~,2 1.9 a~.n ~ n ,n I e582. ~0~ 5D~5 l~l~ ~2~5 15.~ iT.e ~6~ ~1,o ~-~ -~ ~ ~;' -- ~ , ............ 258~. 58~ ~..107,~~ ~ ......... 21 .... 5 ...... 5.5.0 ~0.9 p.~ l~_p 11_1 ~pg~. ~a 0 ~~i~i,~ i ~ · ~ ~ .... ~ · "". PAGE 15 UNION OIL COMPANY OF CALIFORNIA WITH OIEL O. 32 9 gg, 9 1+6 50.2 135, 2616. 37.0 2618, 36.1 2620. 37,1 2622. ~3 5 262~. 42.5 PAGE UNION OIL COMPANY_0F_._.~AL.!EO_B, NIA .......... KU 1~-6 ~' GR1 IS RUN WITH .~IEL .................................................................................................................................................. D E P TH GFI 1 SP A_C_ ....... _R_E_O_C; EILL~L_.~ ......... GE .... C N __~EN ......... ~ ........ C~ ~R FT API MV .......................................................... ~ ........ ~ .......... G/C __ ~ ..................... 67 2656 ~7 9 68 i 151 2658 ~8 ~ 66 266~, ~7 1 65 7 126 2666 2670. ~7.1 2672. 42.7 2674 ~2 2676, 38.5 56.9 1~~ 11.1 IO.P 12.9 2680. ~0.~ 68.3 ~9.5 ~.0 7.~ 9.0 2682. ~ ~,8 115,2 7.6 7.9 2690. ~9.7 60.5 123~ 2696, ~ 8 52,0 1~!~ 1~,~ PAGE 15 UNION OIL COMPANY OF CAk!F_QR..NI. 6 KU RUN WiTH DIFL GR 1 SP_ .................. _A.£ ........... ~_EOC ...... ~J~LM _B. ILD_ ......... GR ..... CN ...... 372 ~8 1~.8 16 2718 2720, ~0.0 2722, ~'1.7 272q. ~2~ 7 273q. ~5.5 69.1 12~.1 l~ ~-~ 9.9 50.& ~7.P ~9 ~-a ~i-A ~D~.( ~V~: ~:~~ :~:~ ::: ?:, ~:?~37 ::~? .:::: 27~0 ~7 2 68 9 120 27~2. ~9.7 62 3 119 27~. q5 9 55 5 125 27~6. ~5 1 51 6 135 27.8. gl 2 52 2 PAGE UNION OIL COMPANY OF CALIFORNIA KU 13-6 GR1 IS RUN WITH.DIEL O E P T H G R 1 S P ~_C .... R F_~J~__R~._GR .FT API MV AP! 2750. q.,'3.8 5,'.'5oq._i~_8_~_~9 _10.~. 13.n 1~._3 ~8,8 8~-~-L~0,7 !!,5--0.~ 275~. ~5.3 56 8 128 2756 ~8 9 63 5 123 2766, ~9.7 3 ~ 2768. ~2.9 2770. ~8.8 2772. 277~ ~5 2776. ~1.5 58.4 l~51mO 10~ 1.3.;:) lq...'~ q, 4..~ ~.~ ~_n xn.~ .~S q ~ 2788. ~ ~.Z~8 127 8 ' ~" ~ ' PAGE 17 UNION OIL COMPANY OF CALIFORNIA UN: W I TH O,I FL__ PTH APl O. ~.6 69 2802. '+1.0 62 804 45 2816. ~6.5 I28 2 5 2818, ~7.7 2820. 2822 PAGE UNION OIL COMPANY OF CALIFORNIA' KU 13-_ 6 :d~, GR! IS RUN WITH DIFL _. DEPTH _. FT API 2852. ~.9 53.1 135 2854, ~5.9 50 2856, ~6,5 ~9,7 13~ 5 ~864. ~5,2 51,7 132 2 1 .... 2868. ~5,8 2870, 2872. PAGE UNION OIL COMPAN. __O_E_ A_LI_F_QR_NI A ='KU i'3'6 RUN WITH DIEI._ ...... SP .... _AC._ __~OC__ R!LM RTLB_ . GE___ CN __ DEN DENP AP~ .............. A ...... GZC_ ~.900 ~ ~916. 2918 2920. 35.6 2922. $8.~ 292~. ,3.0 ,?~: :~;;~ ~;;% ~?~%S' ~77 ~;% F~ ~ ;:::: 'FS?~;~:~;~ ~:~ ;:: :?: : ::~S7*;:;:%%~?~ ~L': ~ 7:~ ~ ,,,: ~::~,:>:: :;:,~,:..,, ~ ::~:~: ~ :~: ~:~:: ~: ::~; :~ ~:~ :~:; ;:::~ :'::: ::: ~ :~: :; ,;~ :;:: :. ~r ~; ~::. ~:; :: ~: ,:;::::. :?;:: ; ;: ~;: :: ::;:?;::;;::,~ :~:; ~ ;: ;:;:: .:;:; :; :::;: ;~:; :;< ;::;: :::. :; :;::: :;:: :; :::::: ;:: ;: :;; :: ::; PAGE 20 UNION OIL COMPANY OF CALIFORNIA 'KUi3'6 ~ GR1 IS RUN WITH DIFL DEPTH GR1 Sp FT APT MV AC RFOC RILM RILD _ GR £N DFN D F'_ Np C_AL CORR AP_L_ __,~_ ........ G/C__ ..~ 2952. ~9.3 68.0 129 295~. 65.1 12E 66.2 128 67.2 128 66 296~. 2966. 2968. 2970, 2980. 25 5 70~ 128~.T 29..8~ · ~8.~ 70.8 ~A5.6 9.~ 2986. 50,7 ~.:~ ~131.3 998. 49.9 ~5~0 130~_8 7,~ ~1 PAGE 21 UNION OIL COMPANY OF CALIF0_R__NIA KU 13-6, - i/'2'$R:! IS RUN_~_I_?.H___D.!_EL ................................................................................................................................................................... GR 1 SP AC B_E_OC ....... RI_L~__ R_ILEL ........... G.E{ ....... F.N ............... D. EN ........ D_ENP_ ....... r.~ ....... CORR .......... ?_._! ................ M.V ~_I .......... ~ ..... G/.C .......... ~ .............................................. 500q. qq.O 61 0 129 ~006, q7 6 57 7 128 3008. 47 5 65 2 126 30lq. 31.9 6,8.5 132.4 38 2 3~, 5 35 5016. 19.q 131 8 20 6 15 5018. ~0.1 ~020. qg.1 B022. q5.2 302~. q-q.9 49.6 71.2 128 2 7 50~6. q5 0 71 8 120 30qS. q8.8 66.7 119 5 7 PAGE 22 UNION OIL COMPANY OF CALIFORNIA KU 13-6 GRI IS RUN WITH D.!.EL DEPTi! GR1 SP Ag ........... B. EO_C__~_ILB ...... B_.I_LD ..... GB .... ~[~L_. ..... QEZ~ .... ~-~~OR-R- ~: FT '- API RV ................................................................................ AP_I_ ................. 52 50 6 67 ~ 127 3054 ~6 5 68 9 116 3056. 48.6 66 3066 5068 3070, ~6.6 3072, ~8.3 3076. ~1.0 q7~3~ 1 13.7 18.1 3078. ~8 0 ~8 ~ 36,3 ~ 308~, ~5,6 ~7~ ~6~,7 8 ~'~:'~;~'~' ~;~::~;~:~% ~:;:-. :~:~]:?~.:~%~;~:~ f :~:~77:~,~:~ 3086. ~.~ ~8~5 138~1 ~_g ~8, 3088. ~5.5 ~9,7 13~1 ~090. ~6~ 56.5 i~.~ 3096. ~6.6 68~.~ 12!.1 ~1 9-v 309m~' 5~.5 61 1 119 0 PAGE 25 UNION OIL COMPANY OF CALIFORNIA D?':KO 'i3~6 WITH OIFL O Sp 3100. 58.9 63.1 1 7 3102. 5%.5 70.1 128 Oq. ~5.8 69 8 128 _ 5106. ~8,9 68,.~. [2~.7_~_ a.~ 9.~s 11.n 51_~ ~.~ .>_n .'zZ a ~" ~ n~ ~108. 51.9 .... ~5~6 129~5 ~ ~_~ ~n_~ ~2 "q O ~ ~ ~ --;' ~ n ~ ~:':~::~:::~:~::~::~:~::: :::::::::::::::::::::::::::::::::::::::::::: ~:.:: ~:~::~:~::~:~:~u~: ~'~ :::::::::::::::::::::::::: ::: :~i::::~i~::;~:,::~::~::i ~ :~:~:~: :::::~::~:~:::~::~::~::i~:._~.i:~::::::~,:~::::: 3112, ~9.5 70~~0 0 ~,~ ~ :~ ~ · · ~ :::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::: :::::::::::::::::::::::::::: ;: : :~ ~11~ 51 2 70 2 129 3116, 125.5 1 8 3118, q8.7 3120. B122. ~.. :~:~' ~::~:::~::::::.~:::::::::: :::::::::::::::::::::::::::f.::~:~:~::~: ~:::,:~:~::.::::::::~:~:~ , :~:~:~:::: ~"~ ~?::~:~..~.~:~:.:~: 3128. %7~ ~,5 126.5 8.5 ~ ]n_fl 3,~,~ q9.7 69,3 126.0 . ~.,.9_. Z~ ~ 3~2, ~6,3 6~j8 126~3 7.0 8.~ 9.3 53~P ~6~1 · :...: -....~.........,'.,..?:.. <., ....: .: - ..: ...:,.:..:. :,.' · ;.: :: ,::.". s.s: .. :~: :~.: ;::..~ ~.-. ~ ...... -~. ::::::::::::::::::::::::::::::::::::::: ::::~.: : ~::~ ::::::::::::::::::::::::::: :: :::.::~:::~:~ ~:: : :~::: =============================================== :::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::: ::~ Sl~8. 50.0 ~0.3 ~1~ :~,~ 8,n 9.7 ~9.~8.~ ~.n :~ ~ J J_7 n_n 31~0, ,8.6 71 7~ 1819 ~ ~ .......==================================================================================: ::::::::::: ::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::~.:~: :~: :: :: ::: :~:~::: :~:~::: :::: ~. :: :::.~: :.~,: :~:~:::: ::~.,~: ~:~: ~ :: :: :.::.:: :: :: ::: :::::::::::::::::::::: :: :: ~,: ::~: :::::::::::::::::::::: :ID~ ::::~:: ::::: :~:~i: :::::::,:~:~::~:~ PAGE 2~ a152. ~s.5 71.1 125 315~, 51 5 69 0 129, 3156, g9 1 69 0 123 3158. ~3 ~ 66 2 121 3168. ~2.0 5170. ~1.9 3172. ~1.7 317~. ~5 3176, q, 2.8 52~ 32.2 15.5 20.5 21.2 q. 6.2 q. 2.2 2.0 :~.~5 3196. 53 ~ 65 ~ 122 3198. 50.7 68 0 125 5 9 PAGE 25 UNION OIL COMPANY OF CALIFORNIA D G R ~. .__~?_ ..... 202 5qoO 60.5 320q. 51.5 ~206, q6,7 60.q 5216. ~5.2 5218. 52,q 5220, 5~.2 ~222. ~9.~ 522~. ~6,2 52q~. qq.5 56.7 126 52q6. qq.? 55 8 12q 32q8, q2,q 57 7 122:1 12 PAGE 26 UNIOF~ OIL COMPANY OF CALIFORNIA KU 15-6 GRI~IS RUN WITH DIFL DEPTH GR1 SP API MV AC RF OC_____B_IL_M_ R I LD ...... ..G__E ...... EN_ __D_EN___DE~.__ £~.-- --C ORR. 325~. ~5.~ 57 1 124 5256. ~5.6 56 8 128 3258. 40.1 54 5 125 ~260. 49.2 5'+.4 126 5262. 59 7 55 1 127 0 13 ~264. 48.1 55.8 124 6 1~ 124 7 18 5268. ,5270, 48.1 3272 ~5274. 47.;5 ~280. ~8.5 51~.9 121~2 .... 8 ~ .... ~2 6. ~ .8 51 4 121 1 8 2 5 6 5292. ~ .2 53.1 122. 3298. ~7.8 49.2 121 7 PAGE 27 UNION OIL COMPANY __0_~__CAL__I_F~ WITH DIFL .$_~__ .. AC RFOC RILM RII_D . GR ! _ M_._V ~P z ....... DEN DE.NP ----C~~R R 30~ ~5 3306 3308 53 0 q7 3310 50 g g6 0 113~ 3312 ~3 8 ~7 I 113 331~. g6.7 ~5.8 126. 3316. ~1., 123.~ 13 3318. 3320, 46.8 3322. 37.1 3324. ~.0 3326. ~0.3 ~3.9 127.2 1~.0 18.P 19.3 65.2 ~$.2 ~,9 9qa J~l- ~ n ~ ~:~ :?~:::~: ::::: :: :::::~:t~:~: ~:: :~?:~: ~:~ :~::,~ :::: s3~,. ~.a ~.6 ~e3~ ~e.7 ~.~6.5..~ 3 ~ ~ ...... ~.~ 5338. ~ .6 ~9.9 ~15.8 10~6 ~3. 1 ~ ~ ~, J 33~8 ~3 6 ~7 5 117 PAGE 28 UNION OIL COMPANY OF £AL!_F_iO_R_NI.A_ KU_. :]. ~-_~ . O E. T H G R ~ 8 P 6C ....... B~_GC ............ .[~.I~M .... R_ILD ........... G.B_ ................ C N ............... O~ ....... ~ ....... C~ ...... CORR- F T A P I M 3~5~. ~7.0 47 2 122 ~556. ~6 9 ~3 ~ 125 ~558. ~6 5 g5 8 129 3~60. q5 2 ~5 336q. 4-0.5 q'2.5 1~1 3366. ~O.q 128. 6 1 3~68. 3570. ~1 3 337q-. ~.5 3398 42 7 q2 7 128 PAGE 29 UNION OIL C_OMPANY__O..E_~_CA_L.!_EORNIA RUN W!TH D_!FL ..... .... ~_ ............. ~ ........ ~EOC _~_RII__FI _GR .... CN_____D£N____~!p .C-~L, -~OR.~-. AELI ....... ~ .... G/C~ ........ "'~.-- ............................................................................................................................................................................... :-_':_-:::_L:L:_.-:::. 3400. 4G.! q. 1 ,,.2 129 3g02, ~9,0 43 3q18, 3420. 3~2~. PAGE 50 UNION OIL COMPANY OF CALIFORNL_A KU GR1 IS RUN WITH DIFL __ D E P T ii G R 1 S P A C R F O_C_ R I LMM_ .... _R_ILL.D ~58, ~9 7 ~1 6 107 5~66o ~2.3 6 13 3~70. 59.1 3q-72, ~5 9 27.2 PAGE UNION OIL COMPANY OF CALIFOR~I~ KU 1~-6 DEPTH FT G R 1 $ ~ ...................... Ag ........ R_E.O_C_ _JL[LI~L__R_ILO__ ....... _GP, .... ~-~iP-----~ aL ----C-ORR- A P I, ............ ._M.~/ ............................................................................................ ARI_ ....................... ~ .............. G/C ........................ ~ ..................................................... ~500 ~8 51 ~ 56 55 5~ 7 552q. 38.8 3526. q5.7 qS.l 136~.7 13,517.¢, 18 7 q5.7 :5528. 39.8 42.8 128,9 2552. q6.8 5q 6 118 0 9 355q 50 8 58 ~ 121 7 8 3536. 52 2 56 2 125 7 7 & 9 3538 q9 2 50 ~ 130 0 9 1 35q0. q9.3 qS.q 132 5 9 35~2. 48.2 q8 3 35~ ~8.3 51 6 12~ 35q8. q6,2 55 7 3 8 PAGE UNION OIL COMPANY OF CALIFORNIA <':' KU 13-6 ~ SRI IS RUN WITH D IFL GR! SP A P I ..~_V_ AC RFOC RILM RILl] GR CN OFN DENP CAL CORR __JPI _ _ _3~__ G/C_ ...... ?~ 3550. ~5.7 55 3 127 3552, ~7.5 56 i 129 ~568, 3570, 3572. 52, 357~, ~ 5 3588. ....~.~ ~..."~,.~.~?~:~:~:~ .... 3592. ~5.9 58.5 ~.2~ &~ ~d ~6~ ' ~ ....559.~ ~6. ~,~. :~:~;: <;::~ ~. :~:~:: ::~: :: :~:;~::~:: ~?~::~ :~:~:~ ~ ~ ::~;~::::~:~': :::::::::::::::::::::: ::::: .. ~598. 52.2 51.8 12~ ~,,. .]'.~:~:~:~ ~. PAGE 33 Uf~ION OIL COMPANY OF CALIFORNIA_ KD, Z i600 ~6 0 b6 3 58 3610 50 6 58 36 ~7 5 57 9 121 5 ~ 7 6 361~. 47.7 58.5 12~:6 6 8 7 ~616. ~7.2 125.~ 7 1 7 3618. ~8.2 ~620, 50,6 3622. ~2.7 562~. 50.7 363~. ~8.5 55_~3 119.0 8.1 7.p 8.7 ~8,~ ~7.~ ~.1 xa ~ ~v O ~ 50 6 61 3 126 PAG~ .54. UNION QIL COiqPANY OF CALIFORNIA DEPTH GRI SP Ap1 Ply_ A C R F 0_C_ .... ~ _ 3652. 47.7 58 4 128 3656 45 0 58 5 126 5 7 58 52 2 60 1 123, 3666 9 5 3666. 6~.q. 5670. 56.5 3672 367g 54 3676. 51.5 58.5 12~m2 ~ 8.2 49.8 ~9.0 2.1 31.2.. 1.l..c~ ............. O.~ ::::::::::::::::::::: ============================== 5698. ~.3 ~9 9 118 5 PAGE 35 UNION 0I~ COMPANY OF CALIFORNIA AP, Z .~ GR CN_ DEN OENP GAL CORR AP! % _--GZC.-- .... % 2 5~ ~718. 16.$ 60 5 33 3720. ~6.2 3722. 41.0 3724. ~.7 3726. 43.5 3728 45 3730. q. 9.7 6q..9 125,8 6.8 5.a 7.~ 51.r1 ~7.7 p.n -,~¢:. ~,~. ~n ~. 3 37~8. .....~8 5 ~2,3 127~ ~ ~ 5 A ' ~ g ~ 5750, 5 .8 ~6 ! ]22 9 9 5 37 53 5 ~ 6 125. PAGE UNION OIL COMPANY OF CALIFORNIA KU 13-6 -i GRI I8 RUN WITH DIFL DEPTH GR1 SP · =. _ FT AP1 MV AC RFD~ RILM RILD GR ____APl__ EN DEN DENP £AL ---CORR · _ ~ ...... 5758. ~ 52 21 5760 ~ 8 56 7 108 9 9 ~762, ~6 0 53 0 122 3766, 9-8,0 60.0 119~8 7~7 8~ ~ ~ G " ~ 3768. ~4.5 60 9 122 8 7 ~770, 46 1.25 0 7 2 7 5772, ~6,8 577~, 52,1 ~776 3778, ~6.3 3780, 51.~+ ~o2 ~ lq..9 q. 7.7 3782. ~ ~ ~_5~6,,~9 150~ 5 8~, ~1 6 57 1 152,6 24.~ 7 3788, ~ 5 60 6 33~ 5 - ' 5791, 29,5 59,~ 15~.0 ~795. 52.5 ~~ 129/2 17~ 11.~ :~ 3799, 65 9~57,= 120~3 3803. ~5 ~ 58 1 12~ 2 9 PAGE ;57' UNION OIL COMPANY OF CAL__I_EQBN__IA__ A P I ................ M.V ' ARL ................... ~ .......... G/- C ............... ~ ~0 ~7.6 60 09. ~9 ~819. 46.0 58 ~821. 37.2 ~825, 3825. 5827 3829. ~9.2 384.9, 50,3 55 8 128 3851. 55.6 58.9 1.22 3855, 54.8 59.9 117 5 G PAGE UNIO__N oI. L _COMP&N_T.__O_F_.._.CALIFOBN_!A_ KO, 15-6 GR1 IS RUN WITH DIFL _ DEPTiI G_R1 SP AC R_F_Q_C__._RiLM RILO_ ..... 6B ...... ~ _gf_N_--QEALP--CAL_ £ORR- __ F f _ _~_P I ........... ~_V ..................................................................... __AP_L ............ ~ ........ _G/C ............ ~ 5857, 50.8 61 1 115 5 5 3859, ~9.9 61.0 127 3861 ~9 2 59 5 150 386.3. 36,5 61 2 12~ 3871. 51.1 3873. 5~.8 3875. 56 2 5877, 51.2 3879. q9 . 889, 3897. ~6 9 3899 ~6 7 ~1 '5905. 50,6 ~2 8 135 PAGE UNION OIL COMPANY OF CALIFORNIA KU "iS:" RUN, WI T,H___O__!FJ.. R T L n _GE_ ~__ __DE~.~_--~ ~L--COEE- API .... ~.____G/~S __~ s9 o 5. ~77A- ...... -~-6---'i ....................................................... 7 0 ~2 2 I 2 ~909 ~5 9 ~3 5911 ~!::~,i~i:~:~;· .:L ~& ~'. ~:~ :~." ~]~ ) ~i ::~ ;:: :::: 3917. g6.7 g3~ 135,.6 1~.9 19~2~~0~ ~2.9 ~.l] ~n,1 ~-5 n 3921. 50.7 3925. 45.6 3925, ~8.0 39217, 47.6 5929. 36.8 3955. PA~E 40 UNION OIL COMPANY OF CALIFORNIA DEPTH GR1 ~ .......... ~ ......R__FOC__]IIJ_I~t RILl] ~ CN _BEN _~p _,CAI,. COR.i:L , ~:"': A_P_L ................ ~_V AP_]: .............. ~ ..... GZC ......... ~ _ 3955. 40 1 43 4 126 3957 ~8 ~ ~2 3959. 40 8 45 3961 ~ 8 48 1 124 3969. 54.6 61.1 109 5971. 52 ~ 0 7 3973 3975. 3q'.3 L~ 97"7. 37.6 3979 8981. ~*.~ 60.0 125.5 ~3 7.~ 8.151.1 3989. ~8.0 61 5 1295 ~ ~ 3991. ~8.0 56.9 1,2~5 .~8 10.~ ~2.6 ..... .7.._4.. ~7~-~ 3997. ~7.2 ~.,6 126~7~ 11.9 14.'% 14.7 ~g ~oos. ~.8 ~ o ~ PAGL 41 UNION OIL COMPANY OF CAL_I__F_ORN_IA D~ PTH GR1 AP SP A~ _RFOC .~I.B__~ GR CN J3F_N_~__C_~ ..... -CO.RR-. 42 4007 45 7 41 8 125. 4011, 47,0 4013 45 0 4015 51 9 47 4017 45 0 49 6 123 3 4,019. 49.0 47.8 122,2 ~021, 47,7 129 ~02~. 49.5 ~025, ~027. ~029. 28.0 k~051. ~8.5 61.1 120.1 9~5 7 1 28 ~0~1. 27,6 63.6 134 ~0~5. ~0.1 60.7 I~0.7 25~2 4047. ql.2 62.3 116 4049. 50.8 62.6 117 ~051. 51 8 59 4 ~5 6 61 8 119, 8 5 PAGE UNION OIL COMPANY OF CALIFORNIA KU 15...6 __ ~GR,:I IS RUN WIT _ DEPTH GR1 ..... FT API SP ..... A_C_C ........ ~RFg_ R I L MV ................................................. ~ 4059, 44,3 56,2 125 S 9 8 ~061, 39,5 q9 3 I q063 40 6 42 5 146. 4065 ~071, 43.5 52 7 109 q073, ~9.7 4 7 2 6 4075° 5~,1 4077. 25,2 ~,081 48 0 4085..~.,.~ ~099, 50.6 ~101, 51.5 UNION OIL COMPANY__.QF__._C_A_L_I__F__O_R_N_IA AP I___ _M.._V_ ................................................................................................. AP..L ...................... ~ ............ G/.& ................ ~ ................................................................ 4125. 49.1 ~125 4127. 53.3 ~129. 49.0 4131 51 9 4155 ~8 4 59 0 122 5 5 PAGE UN I ON 0 I~L _C_OMP._AN_Y__O_F_._CA_L_~.E_O_.R!'J..~_A_ ................................................................................................................................................................................. : KU 3_ 3'G SRI IS RUN WITH DIFL DEPTH GR1 SP AC RFO_C. ..... J~iL.~_ ...... _R_.T. LQ ............. .G.B_ ............. ~ .............. QEF. J ......... D~_ ......... C-z~-- CORR... 415 7 · 4 8 , 9 5 7 , 6 12~.,.~ .......... .8 · 0__.__6.~_5_ ..... Z_~ 5 q=7__~&___~LT.~ 5 .......... 2_--1 ....3--~,-L--l_1-,-SL_ 0 ,J 4159. ~6.2 51.2 126 7 2 7 4161 49 0 54 8 128 416~ 57 0 58 8 32 5 ~169. 50.7 58.~ 150.6 6.6 5.~ 5.9 50.7 ~5.8 P.l~ 3~,_ .:% ~o_n n_~ 4171. 55 4 56 0 I~0 8 ~ 4173. ~.6 8 5 4175. ~9.1 4177. 55.0 4179 4181 4183. 49.9 54~9 11~1 ~ 6.4 52.8 ~42.3 ~-~ ~r.. ~.~. ,~,g nn , ~185. 50,6 6 9 1~9~ " ~ q187. 50.5 57.2 1~04~0 &.3 5.6 63 50.0 ~6.7 glgl. 50.9 56.6 119.~ 7.0 5.K G.G 50.3 a3.a P.P PV_~ 1~_7 ~n_~ ~195. 52.2 5~6 i1~.~ ~,0 ~.q ~.0 55.7 ~:~ ~!97.,_. ~5..5 ........ 58~9 115,7 a~.9 ~ S 7~ 59.5 ~205 ~6 3 58 2 121 9 PAGE UNION OIL COMPANY OF CALIFQB_Ni.A 15-6 RUN W I T__H_ D I EL ..................... ____ AC RFFIC R I LM R ! Il_') _GR _._ CN ___-DL~L--D~Np AP_L_ ............ ~ ........... G/-C ...... ~ ................................ ,207 48 48 q. 21 ~21:3. 47 0 45 4225. 51.7 110 1 6 4 ~225 q. 227. 51.5 ~229. 49.2 ~251. 5 2 59.0 4239. 33.3 58.6 132.8 ~2~5. ~ .9 59.3 i22.~ _ ~2~9. 49.5 60.4 121~ ~253. ~7.7 60 1 128. I 4255. ~5.8 55 3 1,26 3 7 7 7 PAGE UNION OIL COMPANY OF CALIFORNIA -- KU 13-6 GRI IS RUN WITH ~_!_FL D PTH GE1 SP AC R~_ _R_~L~L .... RILQ ......... ~ ........ API C N ..... ~ DEN.P__ ...... Ca~ CORR ~259 ~261 4265 45 2 4~ 6 126 ~6 8 36 7 155 ~275. ~9 6 ~275o 46.4 ~277. 49.7 4279, ~8.8 ~281 ' 7 ~ ~:~:~¢t ~C~;;~,~'~ ~';~"~;a.. ~2~7. 47.8 ~3~. ~4~5 43,5 162,5 4305. ~3.8 ~ ~ 200 9 PAGE UNION 0IL C0MPA__h_-I_.Y_.__QF. .... _C.._A.._.LI_F0_RNIA ..................................................................................................................................... KU 1;5-6 ................................................................................................................................................................................................. ? GR1 IS RUN WITH D!_EL GR1 API S P _A_C .... RE.(I~ .... iiIL_M R ! L D G R ....... OM_ ..... _DE~__J2EN. p .......CAI.---CORR M ~ ................................................................................ ARI_ .............. _~ ........... GZC_ ........ ~ .................................. 4509. ~5.7 46.5 166.8 3 ....... ~511. ~2 5 52 9 4J15. 38 7 60 q 125 ~321. 52.2 61.7 115 8 6 ~ ~ ~525, ].07,6 ~325, 52 0 ~527. 55.5 4529. ~331. 34.2 . ~555, 2 .8 59.4. 151~.6 ~33 59,0 i32,? ~ ~337. 63.3 60~5 122., 5 . ~3~1. 53.6 ~ ~3~, ......... ~..~ 61,6 112.6 ~ ~,~5~:.~.. ~,8 ....... 5~.., 0 i2O. 9 ::: ~55. 55.8 5~ 0 PAG~ ~8 UNION OIL COMPANY OF CALIFORNIA ' KU 13-6 ?i'~:~ GR1 I$ RUN WITU_D_IFL D PTH GR1 SP AC RF~C RILM RILO GR _ CN __J~_~L,__~p ~357. 60,3 ~8 2 q. 359, 51o0 4~°6 126,2 q361. 41.9 39 7 136 q. 363. 43.6 37 6 144 ......... :~ ih :~: ~: :~: 4371. 49.7 39.2 152 ~375, 42.7 153.2 2~ 4375. t~7.6 4377, 4q.1 ~379. 43.q. ~381. 46.5 q387. 5 .1 ~5 6 35~,5 35 5 5q ~7 ................ ....... ~ :~. ...... ..;~:::~:~:~~: ~ '~:~ ~389. ~ .0 ~.2 156 6 37 5 1 6 ~6 & 5 -Q ~595, ~9.2 ~5.2 153,2 36,0 ~~ 50.A ~227.7 ~ ~399. ~.8 ~,8 15~6 3~.5 52.A 53.~ ~2.5 AO.6 1.9 PAGE q9 UNION OIL COMPANY OF CALIFORNIA K 15 6 D 07. q9.1 .gO9. ~8 3 q~25, ~9.7 ,q27. 55.1 gq29. 53.7 4~g3. 51.8 qN-~5. 51.5 ~.3 131a9 1~7 1~.~ 16.6 q6.0 ~0.7 2.1 ~S_ _ ~ ~55. 51.~ 50.5 125,2 9 2 ~59. ~8 e ~2 ~6 3 ' 7 PAGE 50 UNION OIL COMPANY OF CALIFORNIA KU 13.6 GR! IS RUN WITH DEPTH GR1 SP AC R E_O_C ILZL~ .... R_I_LQ __GR ..... C_N ...... ~N -~----~~O R ~ 142 50,3 ~0 6 14! ~485. ~2 0 6 19 ~87. 44.9 ~89. ~6.8 PAGE 51 UNION OIL COMPANY OF CAL_!.__EQ..R_NIA GRi,,' RUN GR1 API ~ ........... J_C .... .~F o C __R I L M R I L D ......... G R CN ..... _DEN~ -C.-~J~ --CORR- 4521. ~0.9 37 8 128 ~525 ~6 6 38 ~ .......... 4527, q,O ~ 38m3:1.27,8 ~533. ~,6 ~0 i 135 ~535, ~8 9 ~+537. ~.7 ~539, 45~3. ~1,8 ~ ~. 43.~~.G 133.0 13~ ~551, ~2 ~3.2 132,7 13,~ 455~.~ ........ ~8.8 ~1.9 134,1 1~.~ ~~ ~56i, .... ~.~.6 ~0.7 132~8 1_6,7 ~567. ~l 1 ~0 6 1~7 9 19 PAGE 52 UNION OIL COMPANY OF CALIFORNIA KU 13-6 GR1 IS RUN WITH DEPTH GR1 ..... ~ ............... AC ........... REOG ........ _E~ R_IL/1 __GR. -~---~R ....... CAL CORR FT AP1 4571. 43.1 41 9 173 4575 41 0 42 5 159 4577. 59 9 41 7 148, 4581, 42.0 45.7 i~6~0 17.2 2~.1 ~583. ~9.0 4~.1 1~2 3 4585 ~587. 39.3 4589. 44.5 4591. 42.5 ~595 ~597. ~5 6 ~605. ~5.3 64.3 ~607, 59.1 ~:~'~{{~'...~f ~""~'~;~ .~ '.:~{~ ........... 4613, 60 9 63 6 PAGE 53 UNION 0IL COMPANY OF CALIFORNIA__. ..... GR1 SP .... _AC ..... BEDC RILM ._g/LO__ _GR A P ! ..... .~J/ AP_I _ DEN DENP · 621, 55,0 58 · 62~ 3'::) ~62 21 4~637. ~8.3 46!%1. 59.0 96~3 38 q~6q, 5. :59..5 ~ 0 12'~ 4- ~..~.~ 4. 8. ~ 9.4. 4.4,. O 4, q.. 9 ~ 1 ~n. ~ n. v (~- 2 ~6~7. 39.3 51.0 117,~ 7 ~ 6 ~ ~ &Z ~& ~ D~ ~ ~ :~: ~:~ ::~: ~': ,~,~ ~::~ :~? :~:~:~: ......... ...... ~:~. q653. ~1~ ~6.2~22~ ~6~ ~ ~ ~ ~ ~659. 50&~.. 60 2 112~1 ~5~ 5 ' ~ ' Z ~ ~667 ~1 3 39 8 132 PAGE 5~ UNION OIL COMPANY OF CALIFORNIA KU 13-6 .................................................................................................................................................................... RUN WITH _ D[PTH GR1 FT API SP AC RFOC ~LILN__R~~__¢_~ _£N .... ~ ~~ CORR 4669. 42.6 4671. 42 1 38 6 134 4673 45 6 39 3 133 4675. 45 5 39 1 4681, 50,1 ~2.1 15~1 lOm7 13.P 13.5 42.0 X5.1 o n .~q_~ ln_~_n_n ~685, 39.8 40.6 158. 5 4585, 40.8 140 7 1 7 13 ~687, ~5.4 4689. 40.2 4691. 42,1 ~693. ~0,2 ~695. 42.6~ 43.0 7~5 10.4 13,3 13.9 1.9 ~; ¢, · ~. ............. , ~f~'~{~ ~,:~::~:. :. :~: :::::~:::~:~7~:: ~:~ '-'~?~?:::: ~:,~, .,~,~:~ ~:: : 4711. 39,~ ~2.1 i~5 IA~9 i2 ~ ~ ~~,~2~,0 ~,:.: ~:'~:~ ::~:,:::::: ::::::::::: :: :: : ::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::: ::::~ PAGE 55 UNION OIL COMPANY OF CALIFORNIA -- iS RUN W!TH OIFL sP ..... AC_._ AP! RV ~719, 41.4+ ~721. ~5.5 4+1 9 ~72, 52 I 4+4+ ~72~ ~3.3 4+2 RE0_C___RILB_~__. GR __ CN OEN OENP - CAL--.CORR ~733, 4+2.3 4+1,5 136~ q735, 4+9,6 '139 3 11.2 4+757, 4+6,6 q. 739, 4+5.7 ~7~1. ~5,~ ~7~3, ~,0 ~7~5. ,5.z ,5.9 ~25.~ 8 ~ ~7~7. ,8.8 5z 5 ~22 ~757. ~8.~7? 58.~ 115.8 ~759. ~2.1 50~9 122&2 7.3 ~f~:~:~' "~T'i~?f:': ': :;?:~ ~-; 4765. ~6,7 ~2.5 i1~,~ 6.6 ~767. ~9 8 55 Z Z~7 PAGE UNION OIL COMPANY OF CALIFORNIA :KU 15'6 ~-GR~.:IS:RUN WiTH DIFL DEPTH GR1 SP AC ~7~. "'-~-~;'~- ..... ~-7~'-'~'~-~- 477I, 4775. ~777 RFOC RILM RILD _GR _AB3 .... £N DSN _D_ENP___~ CORR 41.6 ~7 5 118 51 1 57 51 I 50 q. 78.; 44 4 q. 6 2 127 ~785. 46 9 49 9 9 ~787. 49.4 4789. 47.0 4791. 45.6 4793. 4795. 48.0 ~0.9 155.6 9.6 ~805, ~ 2 ~2 5 I~Q 1 ~807. sg.s ~ i....,;%,,~.0~9~ ~813. 66.2 65 7 118 6 PAG~ 57 UNION OIL COMPANY O_F_.~.A._L__IFOR_NIA API _ R!LM RILD ...... GR 4819' __ ~_:': '::' :~:a'~o' D~,_ __D!...l_~__._i__~.....i. 39 9837, ~839. PAGE 58 UNION OIL COMPANY OF CALIFORNIA KU 13-6 GR1 I$ RUN WITH D_~_EL ...................................................................................................................................... _ DEPTH GR1 SP ....... AC ......... ~EQ_C ...... ~LI_L~_~ SR .......... ~ ....... DKN___QE~R ........ ~--CORR FT API R~ ..................................................................... A~ ................. ~ .......... ~Z~ ........~ ~875. ~9 6 ~2 ~ ~885. 128 8 8 2 9 ~887, ~ 9 ~89I. q~.6 ~895. ~6 9 PAGE 59 UNION OIL COMPANY OF CALIFORNIA 9, 58 _.AC __~FOC RILM R!ID _GR £N DEN OENP .-C_.n L CORR- AP I -- _~L__-~.~ ~ ~937. 52 PAGE 60 UNION OIL COMPANY OF CALIFOB.~I_A_ KU :1,3-6 6R1 IS RUN WITH D_~FL DEPTH GR! SP FT A P I .M__V_ AC _ R__~ BILH RILD 4975, ~987. ~7 8 ~989. ~991. 499~. PAGE 6! UNION OIL COMPANY OF_C_AL][FQB~IA KU 13-6 ~' 6R:l IS RUN "][TH O][FL AP ! 21 5037, 5059, q9 0 5045. 52~9~5,5 9827 10,,0 0 i 6 56 7 - , ~ 50 1. 57 7 q8~ 99~2 8~ 9 ~ ~ ~5055. 5q.6 qG 5 99 3 5059. 52.5 ~7.6 99,j~ a~6 : ' ' ' · ~..::::::::::::::::::::::::::::::::::: : ::~::~::~t ~:::z: : ::Y~:?:~:~ y; ~:~:::~:::: :::: : ~. ~,:~:~: ::: ~: :: ~: : ::~::~::~: ~:: :~:~:~:: ::: ~ ::~.::~:.::?:~:: ::~:~: :::~: 5067. q8.9 q8 5 97.q ' PAGE 62 UNION OIL COMPANY OF CALIFORNIA R!I IS-RUN WITH ~IF_~ D TH GR! SP AC RFOC PI MV RILM RILD _ GR __ API CN :" -: .~ -_AL COR~ ._~ .... ~ ........... 9 55 4 507 2 96 75 ~7 8 50 i, ~+9 4 42 5085, 55 8 7 9 5087 5089, 56,9 5091. 59.8 5095. 55,8 5095, ~4,0 . 5~ 58~0 108~ 5101. 58,2 5~. 5~ 98,.2 ~9~, 5105, ........ 5_9., 1 5~.5 98.6 1~.~ 1~.~~ 5Z05, 5e 6 52 5107, 57,8 5~ 101.6 lO.1 5109. 60 0 I N OIL COMPANy _O_E PAGE 65 N WITH_DIFL .................. . SR ......... AC _B_F_QC____RILM RT/n GR ____CN .... _~ ..... DENP C_~L AP! _ _ ~ ......... G/C_ ..... ~ ............................ 5i2: 52 8 ~ 5ie5, 55 7 52 5i27, 55.7 ~7 5 92 5135, 62,B 100 0 I 5137. 58.1 5139. 60.1 51~3. 59,2 5155, 5q,O 37,7 ~~59. 37.1 51.~117.8 5167, 57.0 63 6 PAGE UNION OIL COMPANY OF CALIFORNIA DEPTH GR1 ,, SP ............. A_..C ....... BF_O_C_~ GR _£L_OEN DE.NP~CA:L. CORR-. AP1 MV ~ ~. ~/C_ ___._~_ 5169, 55 5 55 q 108 7 7 5171. 55 0 ~q 7 92 5175 50 5 ~5 6 119 5179. 52 7 ~0 5181. 50.9 5183. ~9.2 391 0 125 5185 5187 5189. 45.5 5191. ~6.2 5195 5195. ~+5 5 ~2.2 124 7 5199. %5.q ~1 i 126 7 5207. 50.2 ~l 2 i&5 7 ~'~ ~;~::¢::~ ~:~:~:!i.,.~::~: ;~ ~" ~, ~ ~::~;:~ :%: :~>: ¢:~; :;::~ ~ ;Y ~ ¢: ;¢ ?': i: ~';: ~ ;~' ~:~:: ::;"::?:~ ~ :~: ~;:~;, ~: ::¢: ~':¢¢ ;~ t':: ~;~ 4~ ;~: ~:2~ '.¢:.,~:~ ~¢3~~¢~ ~3=;~ ~ ~:¢;;:: ;;~:~; ~ ;:: ~::::~::~ :::~ ::::'; ¢¢:: ~( :::: :::; ::: ~':( ;:~: :: :%: ' :; ;;:': ;': :~:: 5217. ~7.7 ~0.8 !28,,0 1~,5 PAGE 6,5 UNION OIL COMPANY OF CALIFORNIA D PTH GR1 Se .............. _&~__ REoC RILM _ R__~ ..... GR _._ £N ...... _I~N___DENP_____~L CORR 5219. 49.7 40.3 5221. 48.0 39 7 130 ~22~ 4R 5 5225. 48.7 40 2 5227 46 2 42 ! 126 ~229. 49.8 5251. 47.5 41 5 12 5255, 49 2 48 0 120 5235. 47 3 1.24 3 10 5237. ~5,~ 52~9. 5841. 45.9 5245 45 6 5257. q3...~.~ 38.6 12~1 ~0 0' -'~O ~ · .................. ..... ~261......~7,5 39.2 lq~_~l ~Sj~ 20.p P~.~ ~9-~ x.~_; 2~n x~ ~ o9 ~n , 5265. ~6.7 .~.6 134.0 ~ ~8.7 P~_~ ~ 3~_~ ~_n z, ,, ~-- n , 5267 ~8 ~ 39 2 127 PAGE 66 UNION OIL COMPANy___OE__.._EA~___!FORNI_A 'KU ~L3-6 ,, DEPTH FT A P ! ..................... ~/ ..................................................................................................... APl ............... ~~- ............ G_/.C ............... .'~. 5289, .. 5295. ~9,o ~,:~N. 1~5 5297, 50,5 ~.0~ ~ ~~ ~ ..... 5299, ~2,8 ~ 1. e ~~,~. 5307, 52.~ 6~ 107.2~ ~.8 .................................................................... 5313. 61 2 2 106 ~::: :::::~:~ :::: .:::: :: ::;~: :~::::: :: ::~:~:~::: ::::: :::. :: ::::: :: ::::: :: :: :::: : :::: ::: : 5315, 52,~ 57~,~ 107~6 ~:~::~:;~:~"~:;~:~'~:~: .... :::::?,.:~. ~: :~::::~::~:~:::.:~::~:::::?~.: :~.~:~:~~,~.~ ...... a~Z~- .......... 2,~2 ......... 27, ,2 .............................. .:::: ::::..,::::::::: : ::::::: ::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: PAGE 67 UNION 0IL COM_P_ANY__0F__.C.A.L.!_EORNIA. .................................................................................................................................... ~:~ ~s ~ u~ ~,uii'~..[il i. i ii'ii.'i~' iCi21_-_LT_71~_~i-~T:~7_.-.i_-_ i"-~i.__.:,_.--_i:,--_:i.iLC:iS'i_':' .......... .22 .... ._L-LT-'-_-.._-_- API ................................................................... , ......... : .................. ,, ....................... , ................. , .................... ._.,-- ......... 5335, 6 7 5337. ~.5 5339, 5341. ~4.7 5343. 5347. ~3~ 43.3 128~6 ~~.~ ~.n ~2~ ~-~ ~n ~l_~ ~ _ 5353. ~2.0 ~Q..2 !25~6 5355, 4~ 40,8 12~.9 10~9 !5,' ~ 47 5359., ~3 9 ~.9 123 ' ~5 120 4 7 8 44 ~5 PAGE 68 UNION OIL COMPANY OF CALIFORNIA__ KU 13-6 RUN WITH PTtt GR1 SP ~ RFOC RILM RILD _~_B. M_V API CN .....DEN OENP CAL CORR- 5369, ~3.8 ~5 5385. 0 9 5387, 5591. ~g 9 ~2 PAGE 69 UNION OIL COMPANY OF CALIFORNIA :RUN WiTH D D GR~ SP MV AC _ R~FOC RILM RILD 6R .. CN ]~EN BFNp £aL---CORR- .... /LPI ___~_ ....... G/C .... 5~19. ,9 ~7 2 5~2 52 7 5~33 ~8 3 ~2 2 11~4 5~5 5~37. ~5.5 PAGE 70 UNION OIL COMPANY OF CALIFORNIA KU GR1 IS RUiN WITH DIEL DEPTH ~Ri___ 5~7~. ~5,2 5475 5477 116 116 548~. ~5.2 62 6 116 5~85 5 6 5487 5~89, ~5.2 5491. ~5.2 5~95. ~5.2 q. 5 2 5502. 45 2 0~2 5505. ~5,2 60,7 5507, ~.~...~ 60,7 ~5 551 7 0 0 0 0 0 PAGE UNION OIL COMPANY OF CALIFORNIA AC ._RFOC RIL~ RTLD _GR _CN _DEN ~.L CORR- _ . __ AP ! % _.___G./F._ _-~ 0 0