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169-012
Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 13 50133206460000 214171 11/12/2022 Halliburton PERF CLU 05RD2 50133204740200 222092 11/11/2022 Halliburton PPROF KBU 22-06 50133205500000 205054 2/26/2022 Halliburton RMX KBU 22-06 50133205500000 205054 2/26/2022 Halliburton TMD3D KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton RMX KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton TMD3D KDU 4 50133201760000 169012 11/7/2022 Halliburton EPX KDU 4 50133201760000 169012 11/7/2022 Halliburton MFC24 KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton EPX KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton MFC24 Please include current contact information if different from above. By Meredith Guhl at 10:05 am, Nov 29, 2022 T37319 T37313 T37320 T37320 T37321 T37321 T37322 T37322 T37323 T37323 KDU 4 50133201760000 169012 11/7/2022 Halliburton EPX KDU 4 50133201760000 169012 11/7/2022 Halliburton MFC24 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 11:15:51 -09'00' 0 M Marathon MARATHON Oil Company August 27, 2008 is Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 SFP 7 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7tn Ave Anchorage, Alaska 99501 .ti Reference: 10 -404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Deep Unit #4 Dear Mr. Maunder: v Attached for your records is the 10 -404 Report of Sundry Well Operations for KDU -4 well. Marathon obtained permission to add perforations to KDU -4 under Sundry # 301 -007. Permission for this work was secured under the well name of KDU -4RD. Upon resent discussion with the AOGCC, this well's designation was changed to KDU -4 representing its correct status as an original wellbore. No work was performed under this request so this sundry is being closed out as a non - work operation. This report is a reflection of the well arrangement at the time of work consideration and does not represent the well's current configuration. Submission of this report is part of Marathon's ongoing effort to close -out the backlog of outstanding sundries. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, � SEP "IL 7 2008 Kevin J. Skiba Engineering Technician Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS STATE OF ALAS ALA *OIL AND GAS CONSERVATION COMUS G 2 9 1008 9 910'r REPORT OF SUNDRY WELL OPE q %as Cons. CofT1Mlssion I. Operations Abandon Repair Well Lj Plug Perforations L Stimulate r d Non -Work of Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver,❑ Time Extension ❑ Perforations Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re- enter - Suspended Well ❑ 2. Operator Name: Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑� , Stratigraphic ❑ Exploratory E] Service ❑ 169 -012 3. Address: PO Box 1949 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -00 ' 7. KB Elevation (ft): 9. Well Name and Number: 20.5' (95' above MSL) - Kenai Deep Unit #4 ' 8. Property Designation: 10. Field /Pool(s): FEDA 028142 - Kenai Gas Field / Beluga & Tyonek pools 11. Present Well Condition Summary: Total Depth measured 10,810' feet Plugs (measured) 8,000' & 8,955' true vertical 9,739' , feet Junk (measured) 8,965' Effective Depth measured 10,711' feet true vertical 9,643' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,243' 20" 1,264' 1,222' 1,530 psi 5,020 psi Surface 6,005' 13 -3/8" 6,026' 5,400' 3,090 psi 1,540 psi Intermediate Production 10,289' 9 -5/8" 10,310' 9,280' 6,330 psi 3,810 psi Liner 479' 7" 10,759' 9,685' 8,120 psi 7,020 psi Perforation depth: Measured depth: 6,655' - 7,697' - True Vertical depth: 5,970' - 6,902', Tubing: (size, grade, and MD) 3 - 1/2" N - 80 5,720' Baker 194 - 40 x 32 SAB Packers and SSSV (type and measured depth) Packer 5,579' 12. Stimulation or cement squeeze summary: Intervals treated (measured): No work was performed under this sundry. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑✓ Service ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ Gas Q - WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 301 -007 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin I Skiba Title Engineering Technician Signature Phone (907) 283 -1371 Date August 27, 2008 Form 10 -404 Revised 04/2006 " `��' Submit Original Only • M Marathon MARATHON Oil Company August 27, 2008 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 9071283 -1371 Fax 907/283 -1350 Mr. Tom Maunder SZANNED SEP 1 7 2008 Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10 -404 Report of Sundry Well Operations Field: Kenai Gas Field I "� Well: Kenai Deep Unit #4 Dear Mr. Maunder: Attached for your records is the form10 -404 Report of Sundry Well Operations covering the perforation additions to KDU -4 well. Thirty feet of perforations were added across the 6,428' — 6,458' MD zone. Marathon obtained permission to add these perforations in January of 2003 under Sundry # 301 -013. Permission for this work was secured under the well name of KDU -4RD. Upon resent discussion with the AOGCC, this well's designation was changed to KDU -4 representing its correct status as an original wellbore. This report is a reflection of the well arrangement at the time work concluded and does not represent the well's current configuration. Submission of this report is part of Marathon's ongoing effort to resolve the backlog of outstanding sundries. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, A � , 5 O AO--, Kevin J. Skiba Engineering Technician Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File KJS V ..,ew STATE OF ALASKA 9 9 -OP ALA -*OIL AND GAS CONSERVATION COMKOON AUG 2 9 ?_008 REPORT OF SUNDRY WELL OPERAT�QI�IS as a Oil & Gas Cons. Commission 1. Operations Abandon L Repair Well L Plug Perforations L Stimulate Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 - Re -enter Suspended Well ❑ 2. Operator Name: Marathon Oil Company 4. Well Class Before Work: Development 2 - Exploratory E] Stratigraphic ❑ Service ❑ 5. Permit to Drill Number: 169 -012 ' 3. Address: PO Box 1949 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -00 ' 7. KB Elevation (ft): 9. Well Name and Number: 20.5' (95' above MSL) - Kenai Deep Unit #4- 8. Property Designation: 10. Field /Pool(s): FEDA 028142 - Kenai Gas Field / Beluga & Tyonek pools 11. Present Well Condition Summary: Total Depth measured 10,810' feet Plugs (measured) 8,000' & 8,955' true vertical 9,739' feet Junk (measured) 8,965' Effective Depth measured 10,711' feet true vertical 9,643' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,243' 20" 1,264' 1,222' 1,530 psi 5,020 psi Surface 6,005' 13 -3/8" 6,026' 5,400' 3,090 psi 1,540 psi Intermediate Production 10,289' 9 -5/8" 10,310' 9,280' 6,330 psi 3,810 psi Liner 479' 7" 10,759' 9,685' 8,120 psi 7,020 psi Perforation depth: Measured depth: 6,428' - 7,697' True Vertical depth: 5,769' - 6,902' Tubing: (size, grade, and MD) 3 -1/2" N -80 5,720' Baker 194-40 x 32 SAB Packers and SSSV (type and measured depth) Packer 5,579' 12. Stimulation or cement squeeze summary: Added Perforations (ED Intervals treated (measured): MD TVD 6,428'- 6,438' 5,769' - 5,778' Treatment descriptions including volumes used and final pressure: 6,438'- 6,458' 5,778' - 5,796' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 - - - - Subsequent to operation: 0 - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development - Service ❑ 16. Well Status after work: Daily Report of Well Operations X Oil ❑ Gas ❑� - WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 301 -013 Contact Kevin Skiba (907) 283 -137 Printed Name Kevin J. Skiba Title Engineering Technician Signature 6 Phone (907) 283 - 1371 Date August 27, 2008 Form 10 -404 Revis 06 F BFL SEP j ' 2DDBSubmit Original Only A c. ( t M Marathon Operations Summary Report .eruTrrarr ,,Oil Company Well Name: KENAI DEEP UNIT Report Date: 1302003 Job Category. WELL INTERVENTION 24 Hr Summary RIH with gauge ring to 7690'. Didn't tag, but bottom very sticky. Ran SBHP survey. Attempted to set stop and to pull checmial injection valve without success. RDMO. Start Time End Time Our rs) 0 s Code Activity Code ops Status Trouble Code Comment 07:30 11:00 3.50 RUNPUL SLIK AF MIRU slickline. Conduct safety meeting. Test lubricator. 11:00 12:30 1.50 TAG_ BOTM AF RIH with 2.75 "" gauge ring. Very slow 7250'- 7690', excessive PtU weight. No tag, POOH. 12:30 17.45 5.25 RUNPUL SLIK AF RIH with gauges for static BHP surveu as per stop sheet. 17:45 18:45 1 1.00 IRUNPUL EQIP IAF I RIH with AD2 stop to 850'. Couldnt set. POOH. 18:45 19:45 1.00 RUNPUL EQIP JAF I RIH with F collar stop. Set in tree. POOH. 19.45 20:30 0.75 RUNPUL EQIP IAF I RIH with Daniels KOTto 50'. Would not go anyfarther. POOH. 20:30 21:30 1 1.00 RURD ISLIK IAF I RDMO slickline. Report Date: 13112003 Job Category. WELL INTERVENTION 24 Hr Summary Added M9 and M10 perforations 6428'- 6458'w/2- 112 "" Spiral Power Jet Strip gun (5spf, 45 deg) Start Time End Time Our rs) 0 s Code Activity Code ops Status Trouble Code Comment 08:00 11:30 3.50 Fill outwork permit. Hold operational meeting. Spot equipment and begin RU 11:30 13:00 1.50 Pressure test lubricatorto 2500psi. Test good. MU CCL and 20'2-1Q Spiral Power Jet strip gun (5 spf, 45 deg phase). 13:00 16:00 1 3.00 1 RIH wi spiral gun. Encountertight spot at 5608'. Able to pass. 16:00 16:30 0.50 Correlate on depth 16:30 17:00 0.50 Have production flowwell to apply drawdown priorto shooting. Pwh= 1100psi. Shoot w! positive indication (lost 50 Ibs tension). 17:00 18:00 1.00 POOH. Gun at surface. Pwh= 1100psi. All shots fired. PU 10' gun #2. 18:00 20:20 2.33 RIH 20:20 20:30 017 Correlate on depth Pwh= 1300psi. Have production flow to obtain underballance. Fire guns with Pwh= 1050psi. Lost 100lbs tension. Shut well in. 20:30 121 :30 1.00 POOH. Pwh =1150 psi. Encountered tight spot at 5560'. Able to work past. 21:30 12130 1 1.00 At surface. All shots fired. Pwh= 1200psi. RDMO Schlumberger www.peloton.com Report Printed: 8(20(2008 *Marathon Oil Company Alaska Asset Team Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON Oil Company Telephone 907/283-1371 MAY boo Fax 907/283-1350 Gas May 15, 2008 Anftrag*- Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 th Ave � �. �-� `�--���� � ,� Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: 01 C_ Qa `kc Marathon and the AOGCC have had discussions on the follow-up reporting needed to ' I close out 10-403 Sundry approved well work activities. Work has been ongoing to lqhsilc'4� identify the suspect well activities and complete the appropriate reporting. Submitted for your records-is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 th Ave Anchorage, Alaska 99501 Reference: 10 -404 Sundry Report Field: Kenai Gas Field Well: Kenai Deep Unit 4 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 RECEIVE I.AY Alaska Oil & Gas Cons, Commission Anchorage Attached is a Sundry Report 10 -404 for work performed on well KDU 4. A coil tubing velocity string was installed to help lift well. The 1 %" velocity string was hung off at a depth of 6784'. This work was authorized under sundry #303 -030. Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, Wayne . Cissell Well Work Over Supervisor Enclosures: 10 -404 Sundry Report cc: Houston Well File Operations Summary Kenai Well File KJS • J '% RECEIVE STATE OF ALASKA ALASAIL AND GAS CONSERVATION COMMINON MAY j 6 201-8 REPORT OF SUNDRY WELL OPERA919y'A Gas Cons. COmm;sc;,,.: 1. Operations Abandon Ll Repair Well Plug Perforations H Stimulate Ll Anc Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver[] Time Extension ❑ Installed 1.75" _ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ Velocity String 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ❑� Stratigraphic❑ Exploratory F1 Service❑ 169 - 012 - 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -0 7. KB Elevation (ft): 9. Well Name and Number: 95' KB MSL Kenai Deep Unit #4 - 8. Property Designation: ,C ®v? a 10. Field /Pool(s): 235' FNL, 4209' FWL, Sec. 7 T4N, R11 W, S.M. Kenai Gas Field, Beluga/Tyonek Gas Pool 11. Present Well Condition Summary: Hang off a velocity stting Total Depth measured 10,810' � feet Plugs (measured) 8,000' true vertical 9,73 - feet Junk (measured) 7,593' Top of Fish est'd Effective Depth measured 8,000' feet true vertical 7,18 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,264' 20" 1,264' 1,222' 1530 5020 Intermediate 6,026' 13 -3/8" 6,026' 5,400' 3090 1540 Production 10,310' 9 -5/8" 10,310' 9,280' 6330 3810 Liner 497' 7" 10,759' 9,685' 8120 7020 Perforation depth: Measured depth: 6,655'- 7,697' True Vertical depth: 5,970' -6902' 1.75" 0.125" WT HO 70 6795' Tubing: (size, grade, and measured depth) 3 -1/2" N -80 9.2 ppf 5,720' Packers and SSSV (type and measured depth) Baker SAB permanent PKR 5,8 14' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development .❑ Service ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ✓❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exem t: 303 -030 Contact Kevin Skiba (907) 283 -1371 Printed Name \ Wayne E. Signature V��VLA Form 10 -404 Revised 04/2006 Title Well work Over Supe Phone (907) 283 -1308 tv"Ut " Date 24- Jan -08 JUL 2 8 2009 Submit Original Only 0 0 Marathon Oil Company Page 3 of 5 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code Code Phase Description of Operations 2/14/2003 20:20 - 23:00 2.67 TRIP_ BHA_ CMPRUN small volume of water independently. Shut in, secure well, SDFN. 2/15/2003 08:00 - 11:30 3.50 RURD_ COIL CMPRUN NU coil tubing window. Move flowback iron to take returns off of wing valve below the swab valve. Note: Had 1.5 hrs of downtime getting the manlift working, which was needed to nipple up the coil window. 11:30 - 12:30 1.00 RURD_ COIL CMPRUN Attempt to install Weatherford pump -out plug onto the end of the 1 -3/4 ", 0.125" wall coil tubing. The portion of the pump -out plug that inserts into the coil is 1.520 ", which is too large to fit into the 1.500" ID coil tubing. 12:30 - 14:00 1.50 RURD_ COIL CMPRUN Turn down OD of the seal neck on the pump -out plug to 1.500 ". Also turn down O -ring grooves. Wait on plug to return from machine shop. 14:00 - 15:30 1.50 RURD_ COIL CMPRUN Install pump -out plug onto end of coil tubing. Straight end of coil to bypass chemical injection mandrel, but accidentally crimp pipe. Cut off pump -out plug, dress and straighten end of coil. Install pump -out plug (plug OD = 1.75 ", no -go = 1.265" ID) onto coil tubing using roll -on connector. 15:30 - 17:00 1.50 RURD_ COIL CMPRUN NU injector head. Conduct safety meeting. Pressure test lubricator and flowback iron to 200/3000 psi. 17:00 - 17:30 0.50 RURD_ COIL CMPRUN ND injector head. SDFN. 2/16/2003 07:00 - 08:00 1.00 RURD_ COIL CMPRUN Crew arrives, prepares coil unit for running velocity string. 08:00 - 09:30 1.50 SAFETY SMTG CMPRUN Held operations meeting to review in detail the procedure for runnin and hanainq the velocity string with BJ coil crew, Weatherford packer hand, and crane operator. 09:30 - 12:00 2.50 RURD_ COIL CMPRUN NU coiltubing injector head and lubricator onto 4 ", 10M work window. Test to 200/3000 psi, then purge test liquid. Function test BOPE and window, and visually inspect end of coil. 12:00 - 14:00 2.00 TRIP_ BHA_ CMPRUN RIH with 1 -3/4" coil tubing and pump-out plug to 6742' CTM (zeroed at THF). SITP = 1550 psi, bled to zero while running coil. Hanging weight = 8200 lbs. Close pipe rams /slips and lock -in. Continue to produce well from flowline beneath pipe rams. 14:00 - 14:45 0.75 NULL COIL CMPRUN Push /pull on pipe 5000 lbs to verify slips are holding. Bleed off pressure above the pipe rams and open the work window. Caliper coil tubing to verify no severe ovality. Make a cut into the coil with a hacksaw to check for internal pressure. Coil is on a slight blow (ounces of pressure) which appears to be caused by thermal effects. Make rough cut on coil tubing, install safety clamp on pipe stub. ND injector head. 14:45 - 16:15 1.50 NULL COIL CMPRUN Install motor head assembly onto coil in injector head and pull test to 24K lbs. Install coil connector, Weatherford PDH packer, and hydraulic disconnect onto the coil stub in the hole. MU motor head assembly to packer assembly, and NU injector head. Pull test coil connector to 21 K lbs. Remove safety clamp, close work window. Equalize across rams, and open pipe rams. 16:15 - 17:45 1.50 JET_ CMPRUN Circulate nitrogen down coil tubing at 1000 scfm to remove pump -out plug. While installing coil hanger, well was flowing independently and lifting liquids tro surface. Now lifting liquids at a strong rate using nitrogen. Recover 21 bbl of wellbore fluid before shutting down nitrogen and shutting in well. 17:45 - 18:45 1.00 TRIP_ TOOL CMPRUN RIH with PDH packer on coil tubing. Set down in adaptor spool at tree top. PU, try again and successfully pass through tree. RIH until PDH packer is 25' below the tubing hanger. PU 2' and slack off to set the PDH packer. PDH packer is set 23' below the THE at approximately 42' KB. The end of the 1 -3/4 ", 0.125" wall coil tubing velocity string is 6784' below the THE (approximately 6803' KB). Drop a 1/2" aluminum ball, Printed: 1/26/2008 10:13:46 AM 0 0 Marathon Oil Company Page 4 of 5 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase Description of Operations Code 2/16/2003 17:45 - 18:45 1.00 TRIP_ TOOL CMPRUN and pump 15 bbl of methanol water before ball set and released the hydraulic disconnect. PU above the master valve and close master valve. WHIP (below master valve) = 1100 psi. 18:45 - 23:00 4.25 RURD_ COIL CMPRUN Purge methanol water in coil tubing reel to catch tank. Blow down nitrogen pressure in reel. ND injector head, window, and BOPE. RDMO coil tubing. 23:00 - 02:00 3.00 FLOW_ TEST CMPRUN No activity. Well shut -in. 02:00 - 02:30 0.50 FLOW_ TEST CMPFLW Open up KDU -4rd to gas buster. SITP = 1540 psi. Blew down to atmospheric pressure in 15 minutes without carrying out any liquid. Continued to monitor for another 15 minutes, no sign of flow. Shut -in well, SDFN. 2/19/2003 07:30 - 10:00 2.50 RURD_ SLIK CMPFLW MIRU slickline. Conduct safety meeting. Test lubricator. 10:00 - 13:45 3.75 RUNPUL EQIP CMPFLW RIH with 1.125" tapered swedge to 6826' WLM. Set down, could not work deeper. POOH. 13:45 - 17:00 3.25 RUNPUL SLIK CMPFLW Run static BHP survey with stops @ 0', 4400', 6000', 6500', 6700', and 6800'. POOH. Survey good. RDMO. 2/24/2003 08:00 - 10:45 2.75 RURD_ SLIK CMPFLW MIRU slickline. Conduct safety meeting. Test lubricator. 10:45 -11:15 0.50 TAG_ BOTM CMPFLW PU 2.50" gauge ring, zero at ground level. RIH, tag top of coil tubing hanger at 19'. POOH. 11:15 -12:15 1.00 TAG_ BOTM CMPFLW RIH with 1" tapered swedge. Tag at 6828' wim (6848' KB). POOH. 12:15 -13:15 1.00 TAG_ BOTM CMPFLW RIH with 1.279" tapered swedge. Tag coil no-go @ 6824' WLM (6844' KB). POOH. 13:15 - 14:15 1.00 TAG_ BOTM CMPFLW RIH with 1" drive down bailer with flapper bottom. Set down at 6824' wlm, fell through to 6830' wlm. POOH. Marks on bottom of bailer as if hitting metal. Dress off bailer bottom. 14:15 - 15:15 1.00 TAG_ BOTM CMPFLW RIH with same, set down at 6831' wim, work for 20 minutes, no hole. POOH. Bailer loaded with water but no sooids. Same metal marks again. 15:15 - 16:30 1.25 TAG_ BOTM CMPFLW RIH with bailer with ball bottom. Set down at 6831' wim. POOH, more metal marks. 16:30 - 17:30 1.00 TAG_ BOTM CMPFLW RIH with limber string and chisel bottom. Set down at 6833' wlm. Appears that the helix in the coil tubing is making it difficult for wireline tools to exit the coil without running into the 9-5/8" casing. POOH. 17:30 - 18:30 1.00 RURD_ SLIK CMPFLW RDMO slickline. 3/18/2003 19:00 - 22:00 3.00 MIRU Schlumberger E -line. Pwh= 1000psi (previously supplied by jumper) 22:00 - 23:00 1.00 MU weight bar and PU lubricator 23:00 - 23:15 0.25 Pressure test lubricator to 250 /2000psi with methanol. Small drip found. Replace needle valve and re- pressure. Test good. 23:15 - 23:30 0.25 Held safety meeting. Enforce radio silence and arm chemical cutter. 23:30 - 00:50 1.33 Begin RIH. Tools not falling with WHP. Bleed WHIP to 750psi via production. Tools falling. 00:50 - 01:10 0.33 On bottom with chemical cutter. Pull in place to 6655'. Wait 20 minutes to ensure chemical temp is at least >45degress as required. 01:10 - 01:15 0.08 Fire cutter. Tension dropped off and surface indications good. 01:15 - 01:30 0.25 Not able to PUH. PU to 13001bf (10001bf overpull). Able to RIH w/ tool. Suspect sand /debris on top of cutter. 01:30 - 02:15 0.75 Flow well to production in an attempt to lift sand /debris from top of tool. Pwh= 1100psi. Able to flow rate >1.5MM. Well carrying water with indications of sand /solids in choke. Work tools. Still able to RIH, but unable to PUH. Work until tools will not RIH. Max pulled at 14001bf. Elect to SI production and call town to recommend pulling out of rope socket (1750- 1800Ibf weak point). Stuck with cutter at -6721'(18.6' Printed: 1/2612008 10:13:46 AM Page 1 of 1 • Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba @marathonoil.com] Sent: Friday, April 25, 2008 12:37 PM To: Maunder, Thomas E (DOA); Donovan Jr, Dennis M. Subject: RE: KDU 4 (169 -012) Tom, • There is a typo on the cement tag depth on 12/15/2007. The bailing procedure prior to the cement work only reached a depth of 6,762' MD. The cement top is should have been tagged at approximately 6,746' MD. As you are aware, the software that Marathon uses to track well work malfunctioned a few months ago. We have noticed some nuances in the system entries. Some of the data is duplicated. The operations summary for KDU - 4 has one of these duplications on 12/19/2007. A portion of the information stated on 12119/2007 is the same as the information entered on 12/18/2007. Please disregard the portion that has been duplicated. I hope that clears up the operational descriptions. Please contact me know if you have any other questions. Thanks, Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283 -1371 Cell (907) 394 -1332 Fax (907) 283 -1350 S I Gr4 APR 2 S 2008 From: Maunder, Thomas E (DOA) (mailto:tom.maunder @alaska.gov] Sent: Thursday, April 24, 2008 5:57 PM To: Skiba, Kevin J.; Donovan Jr, Dennis M. Subject: KDU 4 (169 -012) Kevin and Dennis, I am reviewing the latest 404 submitted for the well. The depths given on 12/15 sort of hop around, but that is probably par for the course. The coil summaries given for 12/18 and 12/19 are the same. Do you have any different info? Thanks in advance, Tom Maunder, PE AOGCC 4/25/2008 M Marathon MARATHON Oil Company April 21, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10 -407 Completion Report Field: Kenai Gas Field Well: Kenai Deep Unit #4 Dear Mr. Maunder: 0 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 RECEIVED APR 2 3 2008 Alaska Oil & Gas Cons, Commission Anchorage \�� SGANN APR � 8 2008 Submitted for your records is the 10 -407 Sundry Completion Report for KDU -4 well. Marathon re- completed KDU -4 into the Sterling Pool 6 zone, as proposed under Sundry # 307 -366. The Beluga formation was plugged back and perforations were added to the Sterling zone. These efforts were not successful at establishing a commercial flow rate from Pool 6. The well is presently shut in with 100 psi of tubing pressure. Please contact me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10 -407 Completion Report cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD STATE OF ALASKA 3-�8 ALA OIL AND GAS CONSERVATION COMM ION APR 2 3 2008 WELL COMPLETION OR RECOMPLETION REP01fca0aJ& FALSE Oil ❑ Gas Plugged ❑ Abandoned ❑ Suspended ❑ Recomplete into Sterling Pool 6 GINJ❑ WINJ❑ WDSPL❑ WAG❑ O'ther0 No. of Completions:1 1b. Well Class:1D�� Development Expl" oratory ❑ Service ❑ StratigraphicTest❑ 2. Operator Name: Marathon Oil Company 5. Date Comp., Sus .,nor , Abend.: 1/ 2. Permit to Drill #: 169 -012 Sundry #: 307 - 366 3. Address: PO Box 1949 Kenai Alaska, 99611 -1949 6. Date Spudded: 2/11/1969 13. API Number: 50- 133 - 20176 -00 -00 4a. Location of II (Governmental Section): Surface: I `� FNL, 4,209' FWL, Sec. 7, T4N, R1 1W, S.M. Top of Pro y� cti orizon: W 1,845' FNL, 3,092' FWL, Sec. 7, T4N, R1 1W, S.M. Total Depth: 3,180' FNL, 768' FWL, Sec. 7, T4N, R1 1W, S.M. 7. Date TD Reached: 6/7/1969 14. Well Name and Number: Kenai Deep Unit #4 8. KB (ft above MSL): 86.5' Ground (ft MSL): 66' 15. Field /Pool(s): ee k�nal t - , G g 9. Plug 5,410' M Dept hD4,849' ND 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x 275,109 y 2,361,744 Zone 4 TPI: x- 273,707 y- 2,360,329 Zone- 4 Total Depth: x- 271,731 y- 2,358,968 Zone- 4 10. Total Depth (MD + TVD): 10,810' 9,736' 16. PropirI4 Designation: FEDA 028142 11. SSSV Depth (MD + TVD): NA 17. Land Use Permit: 18. Directional Survey: Yes ET No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 1 NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94 # H-40 0' 1,260' 0' 1,217' 26" 1,100 sks of Class G NA 13 -3/8" 61 # J -55 0' 6,026' 0' 5,408' 17 -1/2" 3,259 sks of Class G NA 9 -518" 53.5 # P -110 0' 35' 0' 35' 1,415 sks of Class G NA " 43.5 # N -80 35' 4,194' 35' 3,746' " " 47 # N -80 4,194' 5,733' 3,746' 5,142' " " 47 # P -110 5,733' 8,206' 5,142' 7,372' 12 -114" " " 53.5 # P -110 8,206' 10,310' 7,372' 9,268' " 7" 29 # N -80 10,280' 10,759' 9,242' 9,688' 8 -3/8" 330 sks of Class G NA 23. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): MD TVD 4,967' - 5,077' 4,447' - 4,547' 5 spf 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2 -718" 5,250' NA 3 -1/2" 5,720' 5,573' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4,975' - 5,085' 49.5 bbls (250 sks) 15.8 ppg Cement Sqz. 5,866' - 6,855' 94 bbls, 15.8 ppg Cement Plug 26. PRODUCTION TEST Date First Production: NA Method of Operation (Flowing, gas lift, etc.): NA Date of Test: NA Hours Tested: Production for Test Period Oil -Bbl: 0 Gas -MCF: 0 Water -Bbl: 0 Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: 0 Gas -MCF: 0 Water -Bbl: 0 Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. $ O PT . APR 2 8 2008 6 28. GEOLOGIC MARKERS (List all formations and encountered): 29. M FORMATION TESTS NAME M TVD Well tested? E Yes If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost - Top detailed test information per 20 AAC 25.071. Permafrost - Base Sterling A8 3,987' 3,572' A9 4,028' 3,609' A10 4,057' 3,635' All 4,158' 3,724' B1 4,220' 3,780' B2 4,292' 3,845' B3 4,347' 3,894' B4 4,436' 3,976' B5 4,621' 4,144' Cl 4,944' 4,437' C2 5,128' 4,603' Formation at total depth: 30. List of Attachments: Operations Summary, Well Schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 -1371 Printed Name: 4 Dennis M.4 onovan Title: Production Engineer Signature: Phone: (907) 283 -1333 Date: April 21, 2008 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 it #: 169 -012 50- 133- 20176 -00 -00 .rtV Des: FEDA 028142 20.5' AGL (1996 w /o) 66' Spud: 2/1111969 8:00 hrs TD Reached: 6/7/1996 Rig Released: 6/2211969 8:00 hrs KDU 4 Pad 41 -7 235' FNL, 4,209' FWL Sec. 7, T4N, R11W, S.M. Tree cap: 4 -314" Otis (on dual tree) 150' of Blast Joints 4,967' - 5,077' TCP 5 spf (1/10/2008) 4,975'- 5,085' TCP 5 spf (1/2/08) (sqzd 1/6/08) M9/10 6,428'-6,458 (1/31/03) M14 6,655'-6,665 (2/6196) L3 6,800' - 6,808' (12/15/95) (frac'd 12/26/95) L3 6,825' - 6,844' (12110/95) (frac'd 12/26/95) L9 7,264'- 7,293'(11/19/95) L10 7,340' - 7,350' (11/25/95) L13 7,668' - 7,678'(11/11195) L13 7,683'-7,697 (11/11/95) 9,937'- 9,947'(6/69) 9,952' - 9,860' (6/69) 9,994'-10,002'(6169) 10,258'- 10,279' (6/69) 10,315'- 10,316'(sgzd 6/69) 10,428'-10,470'(6/69) 10,430' - 10,440' (6/69) 10,480'-10,490'(6169) Cast Iron BP @ 5,700' MD Tag cement @ 5,866' CTM Fill tagged @ 6,780' MD (12/14/2007) 157' of 1 -3/4" coil tubing @ 6,680' CTM Retainer @ 8,000' (10119/1995) Retainer @ 8,955 (10/1711995) JII I� III 1" PXN nipple @ 5,250' Mule Shoe @ 5,410' MD Tubing Conveyed 1 Perforating Guns 21 # {I 110' 3 - 114' 4 � 5 € al 6 c M ruwmior Drive Pipe 20" H-40 94 ppf 8rd !2R Bottom MD 0' 1,260' TVD 0' 1,221' 26" hole, Cmt w/ 1,100 sks of Class G Surface Casing 13 -318" J -55 61ppf Seal -Lock 12p Bottom MD 0' 6,026' TVD 0' 5,408' 17 -1/2" hole, Cmt w/ 3,259 sks of Class G Tubing String 2 -7/8" L -80 6.5ppf 0'- 302' MD 511 Hydril 302'- 5,250' MD Mod EUE ToR Bottom MD 0' 5,250' TVD 0' 4,704' Production Casing Kenai Deep Unit # 4 9 -518" N -80 Seal -Lock 0.. 35' 53.5ppf P -110 35' - 4,194' 43.5ppf, N-80 4,194'- 5,733' 47 ppf N-80 5,733'- 8,206' 47 ppf P -110 8,206' - 10,310' 53.5ppf P -110 To Bottom MD 0' 10,310' TVD 0' 9,268' 12 -114' hole, Cmt w/ 1,415 sks of Class G Tubing String 3 -112" N -80 9.2ppf IBT tubing 1 - Tubing top @ 5,555' 2 - Baker 80 -40 K- Anchor @ 5,572' 3 - Baker SAB Packer @ 5,573' 4 - X- nipple @ 5,622' ID = 2.813" 5 - X- nipple @ 5,687' ID = 2.813" 6 - Wireline Re -entry Guide @ 5,720' Liner Kenai Deep Unit # 4 7" N -80 29 ppf BTC DO-12 Bottom MD 10,280' 10,759' TVD 9,242' 9,688' 8 -318" hole, Cmt wl 330 sks of Class G Well Name & Number: Kenai Deep Unit # 4 Lease: Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations: Sterling Pool 6 Perf (MD): 4,967'- 5,077' Perf (TVD): 4,447' - 4,547' Angle @ KOP: 25 deg KOP (MD): 4,210' KOP(TVD): 3,760' Date Completed: 02116/03 Original Drilling K B: 13.2' THE RKB: 20.5' (1996) Prepared By: Kevin Skiba Last Revision Date: 4/10/2008 PBTD - 5,410' MD TD - 10,810' MD TD - 9,736' TVD Ope Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Event Name: RECOMPLETION Contractor Name: Rig Name: 1 I I 1 0.1 11/22/2007 08:15 - 09:34 09:34 - 09:53 09:53 - 10:16 10:16 - 10:25 10:25 - 10:29 10:29 - 10:34 10:34 - 10:39 10:39 - 10:44 10:44 - 11:33 11:33 - 12:07 12:07 - 14:21 14:21 - 14:35 14:35 - 14:38 14:38 - 14:40 14:40 - 14:48 14:48 - 14:50 14:50 - 15:14 15:14 - 15:32 15:32 - 15:35 15:35 - 15:46 15:46 - 16:24 12/11/2007 07:00 - 08:00 08:00 - 10:50 10:50 - 11:30 11:30 - 12:30 12:30 - 12:55 12:55 - 13:30 13:30 - 13:45 13:45 - 14:20 14:20 - 15:00 12/13/2007 07:00 - 08:00 08:00 - 17:30 17:30 - 18:00 12/14/2007 07:00 - 08:00 itions Summary Rer Start: 11/22/2007 Rig Release: Rig Number: o Descrjptjn Spud Date: 2/11/1969 End: 12/31/2007 Group: 1.32 SAFETY MTG_ PMPSWB Arrive at location. Held PJ safety meeting and obtain permit. Discuss job scope. 0.32 RURD_ OTHR PMPSWB Begin Cool down of N2 Unit 0.38 PUMP_ N2_ PMPSWB Unit ready, wait for operator to blow down well 0.15 PUMP_ N2_ PMPSWB Pressure test treating lines to 3000 psi 0.07 PUMP_ N2_ PMPSWB Bleed Pressure down 0.08 PUMP- N2 - PMPSWB Begin pumping N2 down 1.75" Velocity String @ 750scfm 0.08 PUMP_ N2_ PMPSWB Raise Pump Rate to 1000scfm. Tbg Press @ 500. 3750scf away 0.08 PUMP_ N2 PMPSWB Raise Pump Rate to 1500scfm. Tbg Press @ 1050. 11250scf away 0.82 PUMP_ N2_ PMPSWB Raise Pump Rate to 2000scfm. Tbg Press @ 1635. 18750scf away 0.57 PUMP_ N2_ PMPSWB Raise Pump Rate to 3000scfm. Tbg Press @ 2070. 116750scf away 2.23 PUMP_ N2_ PMPSWB Stop Pump. Tubing Press @ 2450. 218750scf away. Bleed down v- string to atmosphere and start making solids up string. Bleed to 0 psi. S/I well. Muster for Gas Alarm. Open annulus and start making fluids (5bbls) Start Pumping N2 @ 1000 scfm to help unloading of Annulus. Bleed annulus to 0 psi. Fluids tapered off. SD N2 pump 0.23 PUMP- N2 - PMPSWB Stop N2 pump, Route lines to pump down annulus. 0.05 PUMP_ N2_ PMPSWB Lines reversed, repressure test to 3000 psi. 0.03 PUMP_ N2_ PMPSWB Bleed pressure down 0.13 PUMP_ N2_ PMPSWB Begin Pressuring Annulus @ 1000 scfm 0.03 PUMP_ N2_ PMPSWB Raise Pump Rate to 2000 scfm. Tubing Press @ 300. 2000scf away 0.40 PUMP_ N2_ PMPSWB Approaching collapse pressure for this tubing. Shut down N2. Annulus Pressure @ 1700 psi 0.30 PUMP- N2 - PMPSWB Move lines back to the original position. 0.05 PUMP_ N2_ PMPSWB Pressure test treating lines to 3000 psi 0.18 PUMP_ N2_ PMPSWB Bleed pressure down 0.63 PUMP_ N2_ PMPSWB Restart pump at 1000 scfm. Pump 38000 scf of N2. Tubing Pressure left at 1450. Shut down job and RDMO 1.00 SAFETY MTG_ WBPREP MIRU Pollard wire line unit. Held PJSM and discussed operation with crew. Filled out work permit and job scope. 2.83 RURD_ SLIK WBPREP MIRU wire line unit, wait on correct tree connection from town. RU lubricator to well. MU 1.25" tool string with oil jars, 1.25" GR. PT lubricator to 1500 psig. Good test. 0.67 WORK SLIK WBPREP RIH with 1.25" GR. Sat down at tubing hanger. Work tool by hand would not pass. PU hole. Check tool string. Tools had mud sand strung up and down. 1.00 RURD_ SLIK WBPREP Wait for bailers to arrive from town. 0.42 WORK SLIK WBPREP MU 1.25' bailer with with same size tool string. Pumped 1 bbl fluid while waiting with Pollards PT pump. PT connection with PT sub. Good test. Open well. WHP= 1300 psig. 0.58 WORK SLIK WBPREP RIH tagged up same spot. Work bailer. PUH. Shut in well, blew down lubricator. check tool string. Mud in bailer. MU 1.0" bailer on the 1.25' tool string. . 0.25 RURD_ SLIK WBPREP RIH tagged up same spot. Work bailer. PUH. Shut in well , blew down lubricator. check tool string. Mud /sand in bailer. MU 1.0" tool string with 1.0" dd bailer. . 0.58 RURD_ SLIK WBPREP PT with pressure sub, Open well RIH tool string to light would not fall. Decide to rig down wire line. 0.67 RURD_ SLIK WBPREP RD wire line move to side of location. 1.00 SAFETY MTG CTBG Held PJ safety meeting and obtain permit. Discuss job scope. 9.50 RURD_ COIL CTBG MIRU BJCT, return tanks and hardline 0.50 SECURE WELL CTBG Secure well and location for night. 1.00 SAFETY MTG_ CTBG Held PJ safety meeting and obtain permit. Discuss job scope. Printed: 4/21/2008 1:43:35 PM 0 0 Marathon Oil Company Page 2 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code C de Phase Descnptlnn of.Operations 12/14/2007 08:00 - 12:00 4.00 RURD COIL CTBG Complete rig up of CTU and flow back iron. 12:00 - 13:30 1.50 TEST_ BOPE CTBG Begin BOPE test. Note: Test waived by Jim Regg on 12/11/07 @ 13:30 - 14:50 1.331 CIRC_ I CFLD 1 CTBG 16:30 hrs.) BOPE test finished. Open well and bleed v.s. psi off to gas buster. Velocity string psi = 1016#, bled down to 700#. Start pumping meth /wtr @ .3 bpm. Observe psi build to 850 psi before breaking back to 575 psi. 5 bbls away, swap to 6% kcl and bring up rate to 1.5 bpm @ 360 psi for 20 bbls. Swap back to meoh and pump 2 bbls. Shut down pumping and monitor v.s. psi. Cool down N2 unit. Pump N2 @ 500 scfm for 15 mins. to purge fluid from v.s. prior to setting plug. Shutdown N2, close swab and master valves, trapping 1000 psi on v.s. 14:50 - 16:20 1.50 TEST_ I TBG_ I CTBG 16:20 - 16:35 0.25 PUMP N2 1CTBG 16:35 - 17:00 I 0.421 SECUREI WELL I CTBG 13:45 - 16:30 1 2.751 WAITONI CMT_ 1 WBPREP 1 Stand by for cement. MU cement dump bailer. Mix cement. Load bailer. Secure well and loc. for night. 12/15/2007 08:00 - 08:20 0.33 SAFETY MTG_ WBPREP MIRU Pollard wire line unit. Held PJSM and discussed operation with dump cement. POOH with bailer. OOH with tools. 16:55 - 17:30 0.58 crew. Filled out work permit and job scope. CMT_ 08:20 - 10:50 2.50 RURD_ SLIK WBPREP PU wire line unit, RU lubricator to well. MU 1.25" tool string with oil pin, dump cement. POOH with bailer. OOH with tools. a ed 16' jars, 1.25" Px prong. PT lubricator to WHP 150 psig. Good test. cement plug in velocity string above plug body. 10:50 - 11:30 0.67 WORK SLIK WBPREP RIH with prong sat down at 6750', 30' high. POOH with prong. 08:00 - 08:45 11:30 - 12:30 1.00 WORK SLIK WBPREP OOH check prong. MU 1.25" LIB. Open well, RIH tagged at 6750' MD. 1.42 TEST_ EQIP CTBG Warm up hardline and PT all to 4000 psi 10:10 - 10:50 POOH with LIB. OOH check LIB, no fishing neck. MU bailer. TEST_ 12:30 - 12:55 0.42 WORK SLIK WBPREP RIH with 1.25" bailer with with same size tool string. Open well. 12:55 - 13:30 0.58 WORK SLIK WBPREP RIH tagged up same spot. Work bailer. Worked down to 6762' MD, Total loss = 5 psi 10:50 - 11:15 0.42 SAFETY MTG_ PUH. Shut in well , blew down lubricator. Fluid /Mud in bailer. Rig back coil, and review JSA with PWL 13:30 - 13:45 0.25 WORK SLIK WBPREP RIH tagged up same spot. Work bailer. PUH. Shut in well , blew down 12:15 - 13:05 0.83 TEST_ EQIP SLICK Go to well with lubricator, fluid pack and PT stack to 3k. lubricator. check tool string. Mud /sand in bailer. 13:45 - 16:30 1 2.751 WAITONI CMT_ 1 WBPREP 1 Stand by for cement. MU cement dump bailer. Mix cement. Load Printed: 4/21/2008 1:43:35 PM bailer. 16:30 - 16:55 0.42 DUMPB CMT_ WBPREP Take bailer to well head, open well. RIH to 6750' WLM, shear pin, dump cement. POOH with bailer. OOH with tools. 16:55 - 17:30 0.58 DUMPB CMT_ WBPREP Take bailer to well head, run#2, open well. RIH to 6750' WLM, shear pin, dump cement. POOH with bailer. OOH with tools. a ed 16' cement plug in velocity string above plug body. 17 :30 - 18:30 1.00 RURD_ SLIK WBPREP RD wire line move to side of location. 08:00 - 08:45 0.75 SAFETY MTG_ CTBG Held PJ safety meeting and obtain permit. Discuss job scope. 08:45 - 10:10 1.42 TEST_ EQIP CTBG Warm up hardline and PT all to 4000 psi 10:10 - 10:50 0.67 TEST_ CSG_ CTBG Open annullus valve, 0 psi, start pumping meoh into annullus at 500 psi intervals to 3000 psi. Shut down pump after 6 bbls. and monitor psi. Total loss = 5 psi 10:50 - 11:15 0.42 SAFETY MTG_ SLICK Rig back coil, and review JSA with PWL 11:15 - 12:15 1.00 RURD_ SLIK SLICK Rig up PWL 12:15 - 13:05 0.83 TEST_ EQIP SLICK Go to well with lubricator, fluid pack and PT stack to 3k. 13:05 - 14:10 1.08 RUNPUL SLIK SLICK Open well, WHP =800 psi, RIH with 1.34" guage ring. Tag at 6780' (fluid level 4260' ), POOH 14:10 - 15:00 0.83 RUNPUL SLIK SLICK RIH with 1.25" PXN plug body, no indication of latching into profile, POOH 15:00 - 15:45 0.75 RUNPUL SLIK SLICK Inspect plug body, all looks good, RBIH. Still unable to latch plug body discuss options. 15:45 - 16:30 0.75 PUMP_ N2_ SLICK PUH and pump n2 to attempt to clear fill from XN profile, pump 500 scfm for 15 min. RBIH from 6500' and attempt to latch plug. POOH 16:30 - 17:00 0.50 RUNPUL SLIK SLICK OOH, plug body released prematurely. 17:00 - 17:30 0.50 ENGAG14FISH SLICK RIH to fish olucl bodv Printed: 4/21/2008 1:43:35 PM 0 9 Marathon Oil Company Page of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 (Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Cade Sub Phase Description of Operations Coe 12/15/2007 17:30 - 17:45 0.25 INSPCT BHA_ SLICK OOH, repin plug assembly, 17:45 - 18:00 0.25 RUNPUL SLIK SLICK RIH and set plug at 6780' wl POOH 18:00 - 18:30 0.50 RUNPUL SLIK SLICK RIH with prong, spang off, PUH 200' to 6580', line up to PT plug with N2 18:30 - 18:50 0.33 TEST_ PLUG SLICK Pressure up v.s. to 3000 psi and hold for 10 min., 30 psi loss. 18:50 - 19:00 0.17 RUNPUL SLIK SLICK POOH 19:00 - 19:30 0.50 RURD_ SLIK SLICK R/D PWL 19:30 -19:40 0.17 SECURE WELL SLICK Well secured for night, turn in permit. 12/16/2007 07:00 - 08:00 1.00 SAFETY MTG_ WBPREP Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 09:00 1.00 RURD_ COIL WBPREP Uptained work permit and discussed environmental issues prior to start up. 09:00 - 10:30 1.50 RURD_ COIL WBPREP Pull test coil connector to 20,000 lbs 3 minutes, good test. Bled down pressure on well to verify cement plug held. WHP= 320 psig. Bleed to 0 psig, monitored for 45 minutes. Good test on plug. 10:30 - 11:00 0.50 RURD_ COIL WBPREP MU 3" GS on end of BHA. PU and go to well with injector. Pump Methanol water to PT shell, Low pressure test at 350 psig, pressured up to 2300 psig. Lost pressure. Rupture disc went above GS. Blew down pressure. 11:00 - 12:00 1.00 RURD_ COIL WBPREP Break Bowen connection, PU injector. Replaced the rupture disc. Go back to well and shell tested. Low 350 psig, high 3000 psig, good test. 12:00 - 13:00 1.00 WORK COIL WBPREP Problem with counter on reel. Fixed counter. RIH latched up on hanger. PU +8000 lbs. Vetco unlanding locking nuts on hanger. 13:00 - 13:20 0.33 WORK COIL WBPREP PU hanger, PU weight =7500 lbs. Move mandrel assy above BOP's. Close pipe and tubing rams. Run in manual pins. Bled down pressure. Closed in valve to flow back monitor for pressure build for 10 minutes. Good test. 13:20 - 14:00 0.67 WORK COIL WBPREP Break Bowen connection. Walk injector above hanger. Released GS with pipe wrenches. Take injector to ground to cut and install roll on coil connector. Cut coil and removed 3" mandrel assembly. Released Vetco. 13:00 - 15:00 2.00 WORK COIL WBPREP MU coil connector on coil above BOP's. Take injector to tree. MU coil connector to hanging velocity string. Pull test 10, 000 lbs. Checked roll on, verifed no stretch on connection. Reconnect lubricator. 15:00 - 15:20 0.33 WORK COIL WBPREP Open tubing and pipe rams. POOH with velocity string. 15:20 - 16:10 0.83 WORK COIL WBPREP POOH slowly. All personnel back away from coil reel. Coil connector above injector chains. Coil connector cleared the goose neck. 16:10 - 16:20 0.17 WORK COIL WBPREP Coil connector broke. Coil fell to back of tailer Velocity string above injector secured with BOP's. No pressure released. 16 :20 - 17:35 1.25 WORK COIL WBPREP Held discussion on how to proceed with the coil string removal from reel. Clamped off working string reel at end and pulled off reel with pickup truck. Cut up in to 15' pieces. Removed remainder of coil stinger off of the reel. 17:30 - 20:30 3.00 WORK FISH WBPREP Attach clamp to velocity string, pulled coil onto reel by chaining off coil to reel. Stabbed coil into reel side next to swivel connection on reel. Secured coil to reel with with clamps. Released clamps on coil. Start pulling out of hole with V string. 20:30 - 20:50 0.33 WORK COIL WBPREP Problem with counter, tighten down spring several times. Counter working, continue reel coil OOH. 20:50 - 22:10 1.33 WORK COIL WBPREP Coil at 3700' continue out of hole with velocity string. WHP= 680 psig, velocity string pressure @ 0 psig. 22:10 - 22:50 0.67 WORK COIL WBPREP Coil at 1000' continue out of hole with velocity string. WHP= 633 psig, velocity string pressure @ 0 psig. 22:50 - 23:30 0.67 RURD_ COIL WBPREP Coil at surface, shut in swab waive. Verified coil above swab valve. Velocity strring on reel and well secured. Printed: 4/21/2008 1:43:35 PM Marathon Oil Company Page 4 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To I Hours Code rS� b Phase Description of Operations 12/16/2007 23:30 - 23:50 0.33 RURD_ COIL WBPREP Take injector to ground, cut coil above the BHA. Secured coil to reel and finish securing well. Rig back the velocity string. 12/19/2007 23:50 - 01:00 1.17 RURD_ OTHR CTBG BJ crew left lease. WHP= 980 psig, coil at 335' with 700 psig on coil. 12/18/2007 07:00 - 07:45 0.75 SAFETY MTG_ CTBG S 07:45 - 12:00 4.25 RURD_ COIL CTBG Pull out CT reel with stinger, and bring in work reel for cem t job. 12:00 - 13:30 1.50 RURD_ COIL CTBG Stab pipe from work reel into injector 13:30 - 14:00 0.50 SAFETY MTG_ CTBG Review JSA with relief crew. 14:00 - 16:00 2.00 PULD_ BHA_ CTBG M/U cementing BHA SAFETY 16:00 - 18:00 2.00 RURD_ CMT_ CTBG MIRU BJ cementing equipment. RURD_ 18:00 - 20:00 2.00 TEST_ EQIP CTBG Begin testing hardline and fluid packing with MEOH. Fill coil with RURD_ COIL CTBG Stab pipe from work reel into injector 13:30 - 14:00 fresh water. SE,e SAFETY 20:00 - 21:00 1.00 RUNPUL COIL CTBG Open well, 900 psi, and RIH pu mg min. rate. ^ PULD_ 21:00 - 21:15 0.25 RUNPUL COIL CTBG Tag fill at 6855', PUH and re nfirm tag depth. RURD_ 21:15 - 22:11 0.93 PUMP_ CMT_ PLUGAB Start mixing 15.8 ppg ce nt TEST_ 22:11 - 22:46 0.58 PUMP_ CMT_ PLUGAB Cement up to weigh art down coil @ 1 bpm @ 2200# pump psi and fresh water. 20:00 - 21:00 800 whip. RUNPUL 22:46 - 22:53 0.12 PUMP_ CMT_ PLUGAB Cement @ le, pump 7 bbls and start puh @ 15 fpm from 6850'. RUNPUL COIL CTBG Tag fill at 6855', PUH and reconfirm tag depth. 21:15 - 22:11 Wt =16. coil psi= 2500psi, whp= 850psi PUMP_ 22:53 - 23:22 0.48 PUMP_ CMT_ PLUGAB 76b cement away, swap to water @ 6220', wt= 10.8k,coil= 1200psi, 12/19/2007 23:22 - 23:59 09:00 - 06:00 0.62 21.00 PUMP_ RURD_ CMT_ RIG_ PLUGAB RDMO PJSM:Prep beams to pull bridge cranes.Remove beam stop, remove cranes. Start working on removal of floor plates.Remove floor CtC rC S P plates. PJSM;Remove chain guards, chain from rotary.Remove rotary table. Drive pins from rotary beams and remove.Prep beams for inspection. Change out hook on red tugger. Rig down derrick board. Disassemble clutch and inspect. Work on cellar gradings. Remove flowline box. 07:00 - 07:45 0.75 SAFETY MTG_ CTBG Held PJ safety meeting and obtain permit. Discuss job scope. 07:45 - 12:00 4.25 RURD_ COIL CTBG Pull out CT reel with stinger, and bring in work reel for cement job. 12:00 - 13:30 1.50 RURD_ COIL CTBG Stab pipe from work reel into injector 13:30 - 14:00 0.50 SAFETY MTG CTBG Review JSA with relief crew. 14:00 - 16:00 2.00 PULD_ BHA_ CTBG M/U cementing BHA 16:00 - 18:00 2.00 RURD_ CMT_ CTBG MIRU BJ cementing equipment. 18:00 - 20:00 2.00 TEST_ EQIP CTBG Begin testing hardline and fluid packing all with MEOH. Fill coil with fresh water. 20:00 - 21:00 1.00 RUNPUL COIL CTBG Open well, 900 psi, and RIH pumping min. rate. 21:00 - 21:15 0.25 RUNPUL COIL CTBG Tag fill at 6855', PUH and reconfirm tag depth. 21:15 - 22:11 0.93 PUMP_ CMT_ PLUGAB Start mixing 151 ppg cement 22:11 - 22:46 0.58 PUMP_ CMT_ PLUGAB Cement up to weight, start down coil @ 1 bpm @ 2200# pump psi and 800 whp. 22:46 - 22:53 0.12 PUMP_ CMT_ PLUGAB Cement @ nozzle, pump 7 bbis and start puh @ 15 fpm from 6850'. Wt= 16.5k, coil psi= 2500psi, whp= 850psi 22:53 - 23:22 0.48 PUMP_ CMT_ PLUGAB 76 bbls. cement away, swap to water @ 6220', wt= 10.8k,coil= 1200psi, whp= 800psi' 23:22 - 23:59 0.62 PUMP_ CMT_ PLUGAB Cont. PUH displacing cement 12/20/2007 08:00 - 08:45 0.75 SAFETY MTG_ WRLN Review JSA's with BJ pumping services and Expro, obtain permit. 06:00 - 06:00 24.001 RURD RIG I RDMO PJSM;Cont. work on gratings, load out rotary beams, unplug pump room #3,load out pump #3. Move hanson tank. Steel seal floor plates, prep flow line box. Stage BOPE and start breaking apart. Work on frozen lines on camp. Work on generator heater. PJSM; Nipple down BOPE remove annular, double gate, mud cross, single gate, and bell nipple. Work on clutch actuator, chase threads, install new plates, and Printed: 4/21/2008 1:43:35 PM 0 0 Marathon , Oil Company Page 5 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code I Sub Phase Description of Operations 12/2012007 , 06:00 - 06:00 1 24.00 RURD_J RIG_ I RDMO 08:45 - 10:00 10:00 - 10:20 10:20 - 10:30 10:30 - 11:15 11:15 -12:00 12:00 - 12:30 12/21/2007 12/22/2007 12:30 - 12:40 12:40 - 13:45 13:45 - 15:30 15:30 -16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 19:00 07:30 - 09:30 06:00 - 12:00 G ` (kc\ 09:30 - 10:30 12:00 - 13:00 1n•n - 17•.ris 13:00 - 06:00 12:55 - 13:25 13:25 - 14:00 14:00 - 14:15 14:15 - 14:35 14:35 - 15:35 15:35 - 15:55 15:55 - 16:10 16:10 - 16:30 16:30 - 17:00 07:30 - 08:30 06:00 - 06:00 G \" 1.25 RURD_ ELEC WRLN 0.33 TEST_ EQIP WRLN 0.17 RUNPUL ELEC WRLN 0.75 RUNPUL ELEC WRLN 0.75 RUNPUL ELEC WRLN dies.Weld handle on center pin for rotary table and steel seal.Paint floor plates with non skid paint. Clean and chase threads on BOPE. Change oil #1 gen. Fuel heaters and equip. Stell seal rotary table. R/U Expro and Bj pumping services PT Expro surface equipment to 3000 psi. Open well, WHP =O, rih with 2.74" guage ring and ccl. Tag at 6064' elm, PUH logging collars and tubing jewelry. 0.50 PULD_ LOG_ WRLN At surface, lay down logging tools, du BJ pumping surfaces to pressure test cement plug. 0.17 TEST_ EQIP PMPSWB Pressure test surface lines to 4000 psi. 1.08 TEST_ CMT_ PMPSWB Start testing cement plug. Pressure up well to 1800 psi., block in all valves. Pressure dropping at an average of 20 psi every 7 min. 1.75 TEST_ CMT_ PMPSWB Reroute surface lines and valves to isolate leak off. Pressure up well to 1800 psi again, block everything. Begin test #2 1.00 TEST_ CMT_ PMPSWB Still seeing same leak off rate. Bleed off pressure, rerun hardline bypassing as many valves as possible. PT hardline to 4000 psi. 1.00 PMPSWB Start pressuring up well, shut down due to o -ring leak on BOPE x -over. Make phone calls, clean up leak. 1.00 TEST_ CMT_ PMPSWB Pressure up again to 1800 psi. Pressure bleeding off slower, but still unable to get a flat line. AOGCC inspector calls it quits, all involved agree to recement. SEA L�_C�c - sic` t�� 0.50 SECURE WELL PMPSWB Secure well for night, turn in permit. 2.00 SAFETY MTG_ CTBG AOL, start equipment, and review JSA's. 6.00 RURD RIG RDMO �3� PJSM;Finish up studs on single gate BOP. Tap floor plate holes on rig floor,prep steel seal rotary table. Strip kill valves, manual choke and A HCR off mud cross. 1.00 WAITON REGS CTBG Wait on permit. 1.00 SAFETY MTG RDMO CTBG Weekly safety meeting. Pick up lubricator, change o- rings, pick up injector and change 2.42 RURD_ COIL packoffs. 17.00 RURD_ RIG_ RDMO PJSM;Making cellar covers. Thaw sewer tank on camp trailers. Palletize and band, mud cross, valves, bridge cranes, and protectors. Sort and organize spare parts. Repair broken sound intinuation cover on #1 S � generator. Fix coolant leaks. Charge battery on carrier motors. Replace air control line on #1 air compressor. Paint rotary table. Move EPOCH shack and bottles. Remove, repair and install heater pump mud room. 0.50 RURD_ COIL CTBG Go to well with injector. 0.58 PUMP_ WTR_ CTBG Load coil with 4 bbls. meth /h2o, 25 bbls. kcl. 0.25 TEST_ EQIP CTBG PT stack 300 low/ 4000 high. 0.33 RUNPUL COIL CTBG Open well, whp =40 psi, RIH. Start pumping min rate. 1.00 CIRC_ CFLD CTBG O -ring failure on lubricator x -over at 500' in hole. Shut down pump, close pipe /slips and bleed off psi. Reroute returns to be able to circulate while discussing options, make phone calls, clean up fluids. 0.33 CIRC_ CFLD CTBG Displace kcl from coil with meth /h20. 0.25 FLOW CHEK CTBG Bleed off WHP, monitor psi. Well stable, open pipe /slips, POOH 0.33 RURD_ COIL CTBG At surface, close master and swab valves. Secure injector in cradle. 0.50 SECURE WELL CTBG Decision made to shut down for night, and start fresh next day with all flange type connections. Well and location secured for night. Turn in permit. 1.00 SAFETY MTG_ CTBG AOL, start equipment, and review JSA's. 24.00 RURD_ RIG_ RDMO PJSM;Clean up directional valves for top drive. Receive fuel. Fill camp water tank and fill water tank to preheat.Clean up and organize parts ACC Printed: 4/21/2008 1:43:35 PM Marathon Oil Company Page 6 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Event Name: RECOMPLETION Contractor Name: Rig Name: Date From -To Hours Code Cod Phase 12/22/2007 6:00 - 06:00 24.00 RURD RIG RDMO CTBG Pick up injector, go to well. 14:30 - 15:00 0.50 TEST 08:30 - 09:45 1.25 RURD_ COIL CTBG 2.17 09:45 - 10:40 0.92 RURD COIL CTBG 17:10 - 18:00 10:40 - 16:50 6.17 CIRC_ CFLD CTBG 16:50 - 17:00 0.17 SECUR WELL CTBG 12/23/2007 06:00 - 06:00 24.00 RURD RIG RDMO CTBG RBIH to 6075' 18:10 - 18:30 0.33 PUMP_ 07:30 - 09:00 1.50 RURD_ COIL CTBG 09:00 - 10:00 1.00 SAFETY MTG_ CTBG 18:30 - 18:45 10:00 - 10:45 0.75 RURD COIL CTBG 10:45 -11:30 0.75 CIRC_ CFLD CTBG whp =430 psi. 11:30 -13:30 2.00 TEST CMT CTBG Spud Date: 2/11/1969 Start: 11/22/2007 End: 12/31/2007 Rig Release: Group: Rig Number: Description of Operations house.Fuel heaters and equipment.Cont. to thaw directional drillers trailer.Continue to build cellar covers.PJSM; Salvage good parts of old flow Iine.Blow down dirctional drillers trailer and freeze protect.Fab target "T" for choke line for KBU- 4.Clean and steam out holes for sub structure supports.Write new and rewrite JSA's.Remove aluminum bows from mech. shop and parts house.Replace top drive air desicant houseing. Fuel heaters and equip. Work on water line heat trace. M/u x -over spool to injector stuffing box. Go to well with injector and attempt to flange up to BOPE's. Unable to align injector gooseneck with reel. Set injector back in cradle. M/U 4 1/16 bowen connection on BOPE's. Go back to well, make injector. Chase ice plugs, broken suction valves, etc. Attempt to free coil of ice plug. Decision made to wrap reel and heat up overnight. BJ supervisors to stay on location. Secure well for night. PJSM;Work on cellar covers. Change out exhaust fan in mechanics shop. Prep rig floor for paint. Fill camp water. PJS M; Dress holes in rotary beams and pins. Install rotary table and floor plates. Change oil, filter, and hyd. filter in hyd. pump.Paint floor in dog house.Fuel equip. and heaters.Paint non skid on rig floor.Prep boiler house floor for paint.lnsulate camp sewer tank. Chipping ice from matting boards. AOL, start equipment. Wait on permit, review JSA Obtain permit, pull night cap, pick up injector. Cut mule shoe at end of coil. Obtain emailed consent from Phil Rafferty to run "slick coil ". Circulate meth /h20 through all lines. Decide to attempt PT of cement plug before RIH. Same results as Printed: 4/21/2008 1:43:35 PM 13:30 - 14:00 0.50 CIRC_ CFLD CTBG Displace meth /h20 from coil with kcl. 14:00 - 14:30 0.50 RURD_ COIL CTBG Pick up injector, go to well. 14:30 - 15:00 0.50 TEST EQIP CTBG PT stack, 300 low /3500 high. 15:00 - 17:10 2.17 RUNPUL COIL CTBG Open well, RIH, WHP =175 psi 17:10 - 18:00 0.83 RUNPUL COIL CTBG Tag at 6080' CTM,PUH to 6065' pump bottoms up with kcl, 55 bbls. chasing into tubing tail. Start batching 18 bbls. 15.8# cement. 18:00 - 18:10 0.17 RUNPUL COIL CTBG RBIH to 6075' 18:10 - 18:30 0.33 PUMP_ CMT_ PLUGAB Pump 2 bbls. fresh water followed with 18 bbls. cement @ 1 bpm @ 3000 psi on coil, 450 whp. 18:30 - 18:45 0.25 PUMP_ CMT_ PLUGAB Displace cement with 2 bbls. fresh wtr. followed by kcl. coil =1650 psi, whp =430 psi. 18:45 - 18:52 0.12 PUMP_ CMT_ PLUGAB Cement @ nozzle. Pump 10 bbls cement out of coil. 18:52 - 19:04 0.20 PUMP_ CMT_ PLUGAB Start PUH at 15 fpm, 1 bpm, coil= 1300psi, whp= 420psi. 19:04 - 19:40 0.60 PUMP_ WTR PLUGAB Cement out of coil, call parked at 5740'. Pump 40 bbl. bttms. up at 1.5 bpm holding 450psi on well. 19:40 - 20:00 0.33 RUNPUL COIL PLUGAB Start POOH, stop to repair levelwind on reel, pumping at .5 bpm, whp= 450psi. 20:00 - 20:25 0.42 RUNPUL COIL PLUGAB At 3878' stop to repair levelwind again. 20:25 - 21:55 1.50 RUNPUL COIL PLUGAB Cont. POOH 21:55 - 22:15 0.33 CIRC_ CFLD CTBG At surface, trap 500psi on well. Set up to freeze protect coil. 22:15 - 22:45 0.50 CIRC_ CFLD CTBG Open well, RIH and freeze protect top 50' of well and wellhead equip. 22:45 - 23:00 0.25 RURD_ COIL CTBG At surface, secure well, trapping 500psi. Set injector in cradle 23:00 - 23:40 0.67 SECURE WELL CTBG Well secured for night, turn permit. 12/24/2007 06:00 - 06:00 24.00 RURD_ RIG_ RDMO Prep floor in pump room. Receive fuel. Start to paint boiler house floor. Fill camp water. Blow down line. Cut up and dispose of old pipe. Steel Printed: 4/21/2008 1:43:35 PM 0 0 Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Event Name: RECOMPLETION Contractor Name: Rig Name: athon Oil Company Page 7 of 14 ns Summary Report Spud Date: 2/11/1969 Start: 11/22/2007 End: 12/31/2007 Rig Release: Group: Rig Number: >e Description of Operations seal cellar covers. Charge battery on #2 carrier. Fuel rig and equip.. Adjust valve on portable hyd. pump motor.Clearing snow and ice from rig mats. Paint steam lines in boiler house. Held PJ safety meeting and obtain permit. Discuss job scope. Call ASRC to move crane. Blocking access to well for Expro crane. Move ASRC crane. MIRU Expro E -line equipment. PU lubricator. Carry to WH. PTest lubricator to 500 psi. Test good. RIH w/ 2.75" GR. Tag cement top . 5866' KB. POOH. OOH. Stand back Expro. RU BJ Pump unit. PTest lines to 3000 psi. Test good. Pressure up on plug to 1800 psi. Pressure falls to 1645 psi. Pressure up on plug to 1840 psi. Pressure 1752 psi. Pressure 1752 psi Pressure 1743 psi. BJ valves leaking. Flowline valve also leaking. PT number 3. Test both 3 -1/2" tubing�an 3 -1/2" X 9 -5/8" annulus. to 1860 psi. Tubing pressure 1860 psi. Annulus 1860 psi. Tubing pressure 1745 psi. Annulus 1850 psi. Tubing pressure 1733 psi. Annulus 1850 psi. Tubing pressure 1730 psi. Annulus 1850 psi. Tubing pressure 1713 psi. Annulus 1850 psi. Tubing pressure 1694 psi. Annulus 1850 psi. Tubing pressure 1681 psi. Annulus 1850 psi. Release pressure. Hold Explosives Safety Meeting. Shut down all radioes and cell phones on location. Station guards and signage at both gates to location. Arm setting tool. MU lubricator and RIH. Pull into position and set Owen's 3 -1/2" CIBP a@ 5700'_KB. Hold Explosives Safety Meeting. Shut down all radioes and cell phones on location. Station guards and signage at both gates to location. RU 2.70" Jet cutter. PU lubricator and RIH. Pull into position and shoot get cutter na 5555' E -line MD Good indication of cut. POOH. OOH. RD. RU BJ to reverse circulate 9 -5/8" csg. 12/24/2007 106:00 - 06:00 1 24.00 1 RURD_ RIG_ I RDMO 07:00 - 07:45 0.75 SAFETY MTG_ CTBG 07:45 - 08:45 1.00 WAITON EQIP CTBG 08:45 - 09:40 0.92 KURD_ ELEC CTBG 09:40 - 09:55 0.25 RURD ELEC CTBG 09:55 - 10:38 0.72 RUR_ D ELEC CTBG 10:38 - 10:50 0.20 RUNPUL ELEC CTBG 10:50 - 11:00 0.17 RURD_ ELEC CTBG 11:00 - 11:45 0.75 RURD_ CMT_ CTBG 11:45 - 11:55 0.17 TEST_ EQIP CTBG 11:55 - 12:00 0.08 TEST_ CMT_ CTBG 12:00 - 12:09 0.15 TEST_ CMT_ CTBG 12:09 - 12:15 0.10 TEST_ CMT_ CTBG 12:15 - 12:18 0.05 TEST CMT_ CTBG 12:18 - 14:45 2.45 TEST_ CMT_ CTBG 14:45 - 15:00 0.25 TEST CMT CTBG 15:00 - 15:05 0.08 TEST_ CMT_ CTBG 15:05 - 15:12 0.12 TEST CMT_ CTBG 15:12 - 15:18 0.10 TEST_ CMT_ CTBG 15:18 - 15:25 0.12 TEST_ CMT_ CTBG 15:25 - 15:30 0.08 TEST_ CMT_ CTBG 15:30 - 15:40 0.17 TEST_ CMT_ CTBG 15:40 - 16:00 0.33 TEST_ CMT_ CTBG 16:00 - 16:20 0.33 SAFETY MTG CTBG 16:20 - 17:25 1.08 RUNPUL ELEC CTBG 17:25 - 17:50 0.42 SETREL PLUG CTBG 17:50 - 18:00 0.17 SAFETY MTG_ CTBG 18:00 - 18:10 0.17 RURD_ ELEC CTBG 18:10 - 18:55 0.75 RURD _ ELEC CTBG 18:55 - 19:15 0.33 RURD ELEC CTBG 08:00 - 09:00 1.00 SAFETY MTG_ OTHER 09:00 - 10:45 1.75 RURD_ OTHR OTHER 10:45 - 15:00 4.25 PUMP N2 OTHER Pressure 1860 psi. Pressure 1860 psi. Pressure 1860 psi. Release pressure and RD. Turn in permit. Sign out. Leave location. PJSM;Prep. floor in pump room, prime. Cont. paint steam lines in pump room. Assiist with removing well houses for KDU -4RD. Paint floor in boiler house.PJSM; Fabricate and install exhaust system for portage system.Steel seal cellar covers. Fuel rig equipment. Remve snow and ice. Rebuild spare washpipe, for top drive. Inspect tong hanging lines. Held PJ safety meeting and obtain permit. Discuss job scope. Spot and RU N2 unit. Ru to purge Ct while reversing well. Purge CT while reeversing N2 into 9 -5/8" and taking returns through cut Pressure test 9 -5/8" casino, and 3 -1/2" CIBP in pa_ck to 1 Printed: 4121/2008 1:43:35 PM 19:15 - 20:15 1.00 RURD_ ELEC CTBG 20:15 - 21:30 1.25 CIRC_ CFLD CTBG 21:30 - 21:40 0.17 CIRC_ CFLD CTBG 21:40 - 21:45 0.08 TEST_ EQIP CTBG 21:45 - 21:50 0.08 TEST_ EQIP CTBG 21:50 - 21:55 0.08 TEST_ EQIP CTBG 21:55 - 22:00 0.08 TEST_ EQIP CTBG 22:00 - 22:45 0.75 TEST_ EQIP CTBG 22:45 - 23:00 0.25 SECUR WELL CTBG 12/25/2007 06:00 - 06:00 24.00 RURD RIG RDMO 08:00 - 09:00 1.00 SAFETY MTG_ OTHER 09:00 - 10:45 1.75 RURD_ OTHR OTHER 10:45 - 15:00 4.25 PUMP N2 OTHER Pressure 1860 psi. Pressure 1860 psi. Pressure 1860 psi. Release pressure and RD. Turn in permit. Sign out. Leave location. PJSM;Prep. floor in pump room, prime. Cont. paint steam lines in pump room. Assiist with removing well houses for KDU -4RD. Paint floor in boiler house.PJSM; Fabricate and install exhaust system for portage system.Steel seal cellar covers. Fuel rig equipment. Remve snow and ice. Rebuild spare washpipe, for top drive. Inspect tong hanging lines. Held PJ safety meeting and obtain permit. Discuss job scope. Spot and RU N2 unit. Ru to purge Ct while reversing well. Purge CT while reeversing N2 into 9 -5/8" and taking returns through cut Pressure test 9 -5/8" casino, and 3 -1/2" CIBP in pa_ck to 1 Printed: 4121/2008 1:43:35 PM 0 0 1 12/30/2007 Marathon Oil Company Page 8 of 14 24.00 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Pull Rotary table and beams. N/D Master valve head. Install spacer Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code ode Phase Description of Operations Double gate and Hydril. Make up choke and kill lines. Extend 12/2512007 10:45 - 15:00 4.25 PUMP— N2 — OTHER 3 -1/2 ". RD and release CT equipment. 11.00 15:00 - 16:00 1.00 RURD_ OTHR OTHER N2 to surface. RD and release N2 unit while blowing down N2 pressure 0.50 NUND TREE CMPPUL Pull Back pressure Valves. Set TWC. Test gas alarms. from well. 6.00 16:00 - 18:00 2.00 BLOWD BG_ OTHER Tubing to 0 psi. Cont RD and moving equipment off location for rig. 18:00 - 19:00 1.00 SECURE WELL OTHER All equipment off location. Well at 0 psi and secure. Close permit and and dig out for mouse hole. R/U mud lines. leave location. 12/26/2007 06:00 - 06:00 24.00 RURD RIG RDMO PJSM;Change out make up tong line. Fill camp water.Fuel rig equip. 0.50 SAFETY Shovel snow.Remove flow line on KDU -4RD. Grade pad, lay felt liner CMPPUL Hold safety meeting for new crew change out. Discuss the work over well plan and testing bop. and pit Iiner.Set up light plants. Place matting boards.PJSM; Clean up 1.50 NUND BOPE CMPPUL Complete nipple up of Choke and kill lines. Found loose bolts on oil spill. Shut down boiler, blow down steam lines. Prep parts houseto flanges. move. Fuel rig equip. 12/28/2007 06:00 - 16:00 10.00 RURD RIG MIRU Load out parts house, Mechanic shop. Move and spot pits and pump 12/30/2007 06 :00 - 06:00 24.00 NUND BOPE XMBO Pull Rotary table and beams. N/D Master valve head. Install spacer spool. and choke and kill line valves. Set Lower rams, Upper spool Double gate and Hydril. Make up choke and kill lines. Extend accumlator lines. 12/31/2007 06 :00 - 17:00 11.00 RURD_ RIG_ CMPPUL Set beaver slide and cat walk. R/U torque tube and top drive. 17:00 - 17:30 0.50 NUND TREE CMPPUL Pull Back pressure Valves. Set TWC. Test gas alarms. 17:30 - 23:30 6.00 RURD_ RIG_ CMPPUL Continue R/U top Drive. M/U service loop. Clean out cellar and set mouse hole. Install 2 7/8 rams. R/U bails and elevators. Clean out cellar and dig out for mouse hole. R/U mud lines. 23:30 - 00:00 0.50 TEST_ BOPE CMPPUL M/U 3 1/2 test joint and set in tubing hanger 00:00 - 00:30 0.50 SAFETY MTG_ CMPPUL Hold safety meeting for new crew change out. Discuss the work over well plan and testing bop. 00:30 - 02:00 1.50 NUND BOPE CMPPUL Complete nipple up of Choke and kill lines. Found loose bolts on flanges. 02:00 - 06:00 4.00 TEST_ BOPE CMPPUL AtternDt to pressure up and test bop. Choke line fast lock clamps leaking due to re routing of line with new bop stack configuration. Tighten up and retest. Continue testing BOP 250 /2000psi for 10min. 1/1/2008 06:00 - 10:30 4.50 TEST_ BOPE CMPRUN Continue testing BOP 250/2000 10min all componants passed. peform accumlator drawdown test. Witnessed waved Jim Regg AOGCC. and Tim Lawlor BLM. Gave notice 1330hrs 12 -28 -2007 10:30 - 12:00 1.50 BLOWD EQIP CMPRUN Blow down test lines top drive. Pump out stack to top of tubing hanger room and set. Set Generator, Stage sub and mud boat. Move and spot Boiler house and water tank. 16:00 - 06:00 14.00 RURD_ RIG_ MIRU Attempt to raise sub. Unable to pin Drillers side rear Cylinder. Trouble �t� shoot. No success. Continue to work on sub Cylinder. Crane up fuel ) tank. Run Steam air and electrical lines. Bleed Air from cylinder. Use crane to pin cylinder,no go. Set down sub on mattting boards.. Set mud boat and carrier. Fuel rig. Set camp and R/U. Due to well and location clearances rig up taking extended time 12/29/2007 06:00 - 10:00 4.00 RURD_ RIG_ MIRU Continue to trouble shoot sub lift cylinder. Steam out and clean up top of pin area on 10" support tube. .005 clearance. in tube. Clean out and pin tube. 10:00 - 06:00 20.00 RURD_ RIG MIRU Continue R/U GD -1. Fire boiler.Level carrier. Install tumbuckfes, raise mast to floor. Complete R/U of pits. Hold PJSM; For crane work. Set Dog house ,wind walls, back landing,stairs gray iron and choke house. Scope up mast. R/U guy wires for mast. Set trip tank. R/U choke lines and gas buster lines. Begin removing rotary table and beams to set BOP. Note Called AOGCC 1315hrs 12/28/07 24 hr. notice for bop test Jim Regg. Called ELM Tim Lawlor Gave 24hr. notice for BOP test 1330hrs 12 -28 -07 Printed: 4/21/2008 1:43:35 PM 0 0 Marathon Oil Company Page 9 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code Code Phase Description of Operations 1/1/2008 12:00 - 12:30 0.50 SAFETY MTG_ CMPRUN Hold safety meeting for new crew change. discuss workover and new bop confiruration. 12:30 - 14:30 2.00 RUNPU TBG_ CMPRUN R/U weatherford Tubing tools. Pull TWC and blank side of dual hanger. 14:30 - 20:00 5.50 RUNPU TBG_ CMPRUN Pull tubing side hanger. found tubing had control line for chemical injection mandrel. Also tubing was BTC not 8 RD Pull 3 1/2 BTC tubing and lay down to Jt # 87. Note Ck for NORM pulling tubing 20:00 - 22:00 2.00 RUNPU TBG_ CMPRUN Peform test run with hanger and 2 7/8 511 tubing by stripping in with 2 7/8 rams and annular preventor. Test Good. 22:00 - 01:30 3.50 RUNPUL TBG_ CMPRUN Continue Pulling and L/D 3 1/2 tubing From it # Jt 172 for a total of 5555' 01:30 - 04:00 2.50 RURD_ OTHR CMPRUN R/D tubing tongs and elevators. Re hang tong lines. R/U Tongs and and drill pipe spinners. 04:00 - 05:00 1.00 PULD_ DP_ CMPRUN P/U 10 jts HWDP and RIH for setting weight RTTS. P/U 2 jts 5 " drillpipe. 05:00 - 06:00 1.00 SETREL PKR_ CMPRUN P/U 9 5/8 RTTS and set at 60' 1/2/2008 06:00 - 20:00 14.00 NUND BOPE CMPRUN PJSM: Remove rotary table and beams. Nipple down choke and kill lines. N/D tubing hanger head . pick up stack with blocks and remove spool. Dress out 9 5/8 csg. stub. Install new tubing head . Test Void to 2000psi 10min. Set BOP stack choke and kill lines. Nipple up same. Set rotary beams,table and floor plates 20:00 - 22:00 2.00 TEST_ BOPE CMPRUN Function Test Bope. Peform Shell test 250/2000 10min. 22:00 - 23:00 1.00 SETREL PLUG CMPRUN u 23:00 - 00:00 1.00 RURD_ CSG_ CMPRUN Clear rig floor of tongs and spinners. R/U weatherford tubing tools 00:00 - 00:30 0.50 SAFETY MTG_ CMPRUN Hold PJSM discuss process of handling perforating guns and blast joints,. review running tally,and hazards 00:30 - 05:00 4.50 RUNPU TBG_ CMPRUN P/U and M/U Halliburton TCP perforating guns 5 shots per Ft. Total of 114' of guns run. Run 5 joints 2 7/8 tubing Then p/u and make up 5 Blast joints to 440.' 05:00 - 06:00 1.00 RUNPU TBG_ CMPRUN Run 2 7/8 6.5# 1 -80 8 rd Tubing to 1039'. at 0600hrs Note Change out Weatherford tongs. 1/3/2008 06:00 - 14:30 8.50 RUNPU TBG_ CMPRUN Continue Running 2 7/8 tubing For a total of 155jts. 14:30 - 16:30 2.00 LOG_ OTHR CMPRUN PJSM; Rig up wireline and log pert. guns on depth. 16:30 - 17:00 0.50 PULD_ TBG_ CMPRUN PJSM; Space out tubing to put guns on depth. Top shot at 4975' bottom_ shot at 5085' wireline depth. 17:00 - 18:00 1.00 RURD_ RIG_ CMPRUN PJSM;Change out bails, for logging. 18:00 - 19:30 1.50 PUMP_ N2_ CMPRUN PJSM; Rig up hard line and test to 3600 psi with N2. 19:30 - 20:30 1.00 PUMP_ N2_ CMPRUN PJSM; Pump 20,800 cu /ft. of N -2, to pressure up csg. to 150 psi and continue to pump up tubing to 3600 psi and bleed off to 0 psi to arm guns, Halliburton confirmed guns Fred and dropped after 23 mins. Note Gun may have fired 45min after caculated. 20:30 - 21:30 1.00 RURD_ PIPE CMPRUN R/D B/J hard lines andN2 unit. 21:30 - 00:00 2.50 RURD_ SLIK CMPRUN PJSM; rig up and test pollard slick line and lubricator. Test to 1100psi 00:00 - 04:30 4.50 SETREL PLUG CMPRUN Rih with X nipple prong on pollard slick line and set at4955'. POH. M/U n p ug rin attempt o set, no go. po w/ slick line and xn plug,found mud on tools . Clean up setting tool, rih failed to unlach plug. Make 2 more attempts no go. Poh clean tool 04:30 - 05:30 1.00 WAITON OTHR CMPRUN Wait on Pollard setting tool and weight bars. 05:30 - 06:00 0.50 SETREL PLUG CMPRUN M/U Xn plug with pollard slick line 1/4/2008 06:00 - 07:00 1.00 TRIP_ TOOL CMPRUN PJSM;RIH with XN plug on slick line and attempt to set. Unable to set plug. POH with slick line. Rig down pollard slick line tools 07:00 - 11:00 4.00 WAITON ORDR CMPRUN Wait on orders. Haul 8.5ppg brine from storage tanks 350bbls total 11:00 - 12:00 1.00 RURD_ SLIK CMPRUN PJSM;Rig up Pollard wireline. 12:00 - 13:30 1.50 SERVIC RIG_ CMPRUN PJSM; Service Blocks, crown, top drive, Repair Driller side tong Printed: 4/21/2008 1:43:35 PM 0 19:00 - 22:30 22:30 - 23:00 23:00 - 00:30 00:30 - 05:30 05:30 - 06:00 1/5/2008 06:00 - 07:30 07:30 - 10:00 10:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 17:00 3.501 PUMP_J WTR_ I CMPRUN I Pump 8.5# brine down casing to fill hole, took 309 bbls.. Monitor well Marathon Oil Company Page 10 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 TRIP_ Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: PJSM; Rig up Weatherford tongs, Lay down circ. head and (3) 2 7/8 Rig Release: Group: Rig Name: CMPPUL Rig Number: Date From - To Hours Cade Code Phase Description of djerations 1/4/2008 12:00 - 13:30 1.50 SERVIC RIG_ CMPRUN sheave, Monitor well POH and stand back 2 7/8 tubing. Hole fill 1 bbl more than 13:30 - 16:00 2.50 RUNPUL SLIK CMPRUN PJSM; with Pollard wireline, rig up slickline, test lubricator, RIH with with joint # 20 0.50 RUNPU bailer, POOH and laydown tools. CMPRUN 16:00 - 16:30 0.50 WAITON ORDR CMPRUN Wait on Orders, Clean up rig. 16:30 - 17:30 1.00 BLOWD CSG_ CMPRUN PJSM; Bleed down casing from 200 psi to 0 psi SLIK 17:30 - 19:00 1.50 REPAIR RIG_ CMPRUN PJSM; TRaw out frozen mud lines a een s and pipe an mud pump 19:00 - 22:30 22:30 - 23:00 23:00 - 00:30 00:30 - 05:30 05:30 - 06:00 1/5/2008 06:00 - 07:30 07:30 - 10:00 10:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 17:00 3.501 PUMP_J WTR_ I CMPRUN I Pump 8.5# brine down casing to fill hole, took 309 bbls.. Monitor well Printed: 4/21/2008 1:43:35 PM 17:00 - 02:00 9.00 TRIP_ and wait for air to work out. Keeping hole full. 0.50 RURD_ CSG_ CMPRUN PJSM; Rig up Weatherford tongs, Lay down circ. head and (3) 2 7/8 CIRC_ CFLD CMPPUL Break circulation. Circ. through trip tank to 500bbl seperator tank at pup its. 1.50 CHANGE EQIP CMPRUN PJSM; Change out long bails to short bails for POOH with 2 7/8 tubing. 5.00 RUNPU TBG_ CMPRUN Monitor well POH and stand back 2 7/8 tubing. Hole fill 1 bbl more than to 4980'. Pull Up and close annular preventor, Circulate through kill line caculated to'blaSt join I u5in Mud OBM. starting with joint # 20 0.50 RUNPU TBG_ CMPRUN POH Stand back blast joints. 1.50 TRIP_ TOOL CMPPUL POH Dress Blast joints and stand back. Hole fill 1 bbl more than 400psi continue to circ with no return At 50bbls away pressure was caculated. No Gain. 2.50 RUNPUL SLIK CMPPUL PJSM: R/U Pollard slick line and sheaves and RIH with 7.93 gage ring 386psi no returns Shut down pumps and hold pressure on Casing. to 4778', unable to work past. 4778 ( heavy OBM) POH with gage ring Pressure dropped to 277psi and held for 10 min. Start pumps and and stand back slick tools. No losses to hole. 2.50 WAITON ORDR CMPPUL Wait on orders, Install nipple tee and Pressure gage on 133/8X 9 5/8 annulus. Work on flow line from trip tank to pits. 0.50 RURD_ SLIK CMPPUL Rig down pollard slick line and tools. 1.00 REPAIR RIG_ CMPPUL Repair hydralic hose and replace compensator ram on top drive 0.50 RURD_ CSG_ CMPPUL R/D weatherford tubing tongs and elevators 1.00 RURD_ OTHR CMPPUL R/U drillpipe spinners. Hang rotary tongs and drillpipe handling tools 1.00 PULD_ DP_ CMPPUL Set pipe racks,load drillpipe and tally. Due to space on location, load 25 3.00 CIRC_ CFLD CMPRUN jts of drillpipe on racks at a time. 0.50 PULD_ BHA_ CMPPUL Make up Clean out BHA. 8 1/2 mill, 9 5/8 casing scraper and bit sub Printed: 4/21/2008 1:43:35 PM 17:00 - 02:00 9.00 TRIP_ DP_ CMPPUL P/U Drift 5" drillpipe RIH To 4975, Top of perfs. 02:00 - 06:00 4.00 CIRC_ CFLD CMPPUL Break circulation. Circ. through trip tank to 500bbl seperator tank at 2bbls per min ( limited by out put of trip tank pump. Rotate and clean up to 4980'. Pull Up and close annular preventor, Circulate through kill line Down into perfs taking retuns up the 9 5/8X 13 3/8 annulus. Inital pressure 252 psi at 1 bbl per min. at 20bbls away pressure increased to 400psi continue to circ with no return At 50bbls away pressure was 386psi no returns Shut down pumps and hold pressure on Casing. Pressure dropped to 277psi and held for 10 min. Start pumps and continue to circ. At 85bbls pumped pressure dropped to 225psi no returns. At 94bbls away pressure increased to 283psi. At 96bbls away 283psi established returns to 500bbl seperator tank Fluid returned was gell mud. Continue circulating with 100 % returns at 213psi. Continue to circulation until mud cleans up from 95/8 x 13 3/8 annulus. 1/6/2008 06:00 - 09:00 3.00 CIRC_ CFLD CMPRUN Continue circulating 9 5/8X 13 3/8 annulus. At 1bbl per min Annulus cleaned up after 351bbls pumped. 09:00 - 11:00 2.00 TRIP_ DP_ CMPRUN Rotate and wash f 4970'-50 perf area) no increase of torque during rotation and circulating. 11:00 - 12:00 1.00 TRIP_ DP_ CMPRUN RIH P/U drillpipe f 5088' -5432' 12:00 - 15:30 3.50 CIRC_ CFLD CMPRUN Break Circulation At 2bbl per min. Rig up to close annular preventor and circulate through tubing spool to 500bbl seperator tank. able to increase flow to 3bbl per min at 230psi. Circulate until well clean up. Printed: 4/21/2008 1:43:35 PM 0 0 Marathon Oil Company Page 11 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Sub phase Description of Operations code 1/6/2008 12:00 - 15:30 3.50 CIRC_ CFLD CMPRUN 15:30 - 16:30 1.00 MIX PILL CMPRUN 16:30 - 20:00 3.50 TRIP DP CMPRUN 20:00 - 01:00 5.00 RUNPUL SLIK CMPRUN 01:00 - 04:00 3.00 RURD ELEC CMPRUN 04:00 - 06:00 2.00 TRIP_ DP_ CMPRUN 1/7/2008 06:00 - 07:30 1.50 TRIP DP CMPRUN 07:30 - 08:30 1.00 SETREL PLUG CMPRUN 08:30 - 11:30 3.00 RURD PIPE CMPRUN 11:30 -12:00 0.50 CIRC_ CFLD CMPRUN 12:00 - 13:00 1.00 PUMP CMT CMPRUN 13:00 - 14:00 1.00 CIRC_ CFLD CMPRUN 14:00 - 14:40 0.67 BLOWD EQIP CMPRUN 14:40 - 17:00 2.33 TRIP_ DP_ CMPRUN 17:00 - 19:00 2.00 LOG OTHR CMPRUN 19:00 - 01:30 6.50 TEST_ BOPE CMPRUN 01:30 - 02:00 0.50 RUNPUL WBSH CMPRUN 02:00 - 03:30 1.50 TRIP BHA CMPRUN 03:30 - 04:30 1.00 TRIP_ DP_ CMPRUN 04:30 - 05:30 1.00 CUT_ WIRE CMPRUN 05:30 - 06:00 0.50 RURD_ PIPE CMPRUN 1/8/2008 06:00 - 08:30 2.50 TRIP DP CMPRUN Hvy OBM returned 30bbls + / -. Monitor well Pump KCL dry job. Blow down all mud lines top drive and Lines to 500bbl tank. POH with 5" drillpipe and stand back. B/O mill and 9 5/8 csg. scraper and UD. No gain /Loss. Correct hole fill. PJSM : R/U Pollard slick line tools and run 7.93 gage ring. to 5420' Poh with gage ring. Run 40 finger Caliper tool on slick line.5365 -4500' POH with caliper log on slick ine an nPrfnration5 at 4975 -5085' R/U expro wls and RIH W /Halliburton EZ drill 9 5/8 Bridge Plug on e- line and set at 512 1Y VVLM. FOH and rig down expro e- line tools PJSM: M/U Halliburton setting tool and EZ drill Cement Retainer. RIH on 5" dri pipe. Continue RIH with 9 5/8 EZ -drill retainer on drillpipe to 4938'. Break Circulation. Blow down all Mud Lines and cement hose and stand pipe. Space Out and set 9 5/8 EZ- Drill retainer at 4928. Set retainer by rotating 30 rightTand turns in drillpipe. Set down weight of 50k to confirm slips set. Pick up to 120k and hold , 140k, Then to 150k, EZ drill released. Set Down 70k on retainer, confirm retainer set. at 4928' R/U 2" steel flow lines and 2 " valves from 9 5/8 X 13 3/8 annulus to 500bbl seperator tank and Steel line from rig floor to 2" line to 500bbl tank , for reversing out cement in drillpipe. Make up 2" pump in sub and cement line. Cl ose annular preventer and circulate Through retainer up the 9 5/8x 13 3/8 annulus to 500 bbl tank. Established returns to 500bbl tan a er s pumped. Hold PJSM Cement Procedures and Hazards. Pump 3bbl 1-12o, Test Lines to 2500psi. Mix and pump 250sx 49.5bbls 15.8ppg Class G .With.3 %EC -1 +.6 0. . + o - . +. o + o R- 3. +.05 %Static Free.+ 1gps FP6L. With a yield of1.1.56cf /per sx. Close annular preventer and Squeeze' 3 bbL into perts. at .5bbip min.lnital squeeze pressure 941. Tlfin psi 784 CIP at 12:42 100% returns. Called AOGCC 1 -4 -2008 and 1 -5 -2008 witness waved by John Crist . Called BLM 1-4 -2008 Tim Lawlor and Greg Noble gave notice 1 -4 -2008. No returned call. Un sting from retainer,pull 2 stands. Reverse out drillpipe to 500bbl tank. At 84bbls saw trace of cement. Continue circulating clean out drillpipe. Blow down all mud,cement and flow lines. POH with 5" drillpipe. Lay down EZ drill running tool PJSM: R/U expro WLS and run temperatue log. R/D wire line tools of cement in 378 annulus at 4767'. M/U test jt. Set test plug. Test bope and all components 250/ 2000 5min. Preform accmulator drawn test. Test LEL 1-12s and PVT alarms All passed. Set wear bushing. PJSM: M/U mill. 2 boot basketsand bit sub with float. P/U 8ea 6 1/4 drill collars and crossovers and RIH. RIH with 5" drillpipe to 1826' PJSM: Slip drilling line Rig up 6" line into flow line from flow nipple. Continue RIH w Mill assy on 5" drillpipe To 4758' w ash f/4758 -4928' tag up on retainer No cement on top. Printed: 4/2112008 1:43:35 PM 0 9 Marathon Oil Company Page 12 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code C d Phase Description of Operations rpm's, tq 6 -8 k ft-Ibs, 150 gpm & 150 psi. Tag lower retainer @ 5113'& 18:00 - 19:00 1.00 TRIP_ oe CMPRUN WU 8 112 bit 2 junk baskets bit sub and 6 114 drill collars, RIH 1/8/2008 08:30 - 13:00 4.50 MILL_ PKR_ CMPRUN Mill /Drill on retainer f-4928'-4931'. Mill with 2 -17k weight 40 -70rpm 22:00 - 06:00 8.00 DRILL_ CMT_ CMPRUN 3.5 -4bbis per min pump rate. ( unable to pump more than 4bbls per min 12:00 - 13:30 1.50 DRILL_ CMT_ CMPRUN due to flow nipple overflowing) BOP configuration and height limits use 13:30 - 14:00 0.50 RURD_ PIPE CMPRUN of normal flow line and nipple. 1/9/2008 13:00 - 14:00 1.00 MILL_ JUNK CMPRUN Mill /Drill f- 4931- 4970' Tag cement at 4960' Stop circulation and 14:00 - 17:00 3.00 TRIP_ DP_ CMPRUN rotation, set W down confirm hard cement. Mill on junk and cement 07:00 - 10:00 3.00 DRILL_ CMT_ CMPRUN 4960' -49 0' Very little returns of rm led funk over shakers 14:00 - 14:30 0.50 MIX PILL CMPRUN Monitor well,pump dry job, Blow down top drive mud lines 14:30 - 17:00 2.50 TRIP_ DP_ CMPRUN POH w/ mill assy on 5" drillpipe 17:00 - 18:00 1.00 TRIP_ BHA_ CMPRUN Stand back 6 1/4 drillcollars Break out 8 1/2 mill and junk baskets. rpm's, tq 6 -8 k ft-Ibs, 150 gpm & 150 psi. Tag lower retainer @ 5113'& 18:00 - 19:00 1.00 TRIP_ BHA_ CMPRUN WU 8 112 bit 2 junk baskets bit sub and 6 114 drill collars, RIH 19:00 - 22:00 3.00 TRIP_ DP_ CMPRUN Continue RIH w/ 5" drillpipe 22:00 - 06:00 8.00 DRILL_ CMT_ CMPRUN Drill retainer'unk & cement f/ 4970'- 5111'. Drill w/ 5 -15 klbs, 50 -90 12:00 - 13:30 1.50 DRILL_ CMT_ CMPRUN rpm's, tq 7 -10k ft-Ibs, 150 psi. Max flow rate 235 gpm due to flow line 13:30 - 14:00 0.50 RURD_ PIPE CMPRUN restrictions. Re- routed flowline. Had difficulty drilling retainer junk. 1/9/2008 06 :00 - 07:00 1.00 TEST_ CSG_ CMPRUN PJSM: Rig up & test cement squeezed perfs f/ 4975' -5085' Coil 500 p si f/ 14:00 - 17:00 3.00 TRIP_ DP_ CMPRUN 30 min. 07:00 - 10:00 3.00 DRILL_ CMT_ CMPRUN I Con't drill retainer junk & cement f/ 5111'- 5113'w/ 5 -15 klbs, 40 -90 rpm's, tq 6 -8 k ft-Ibs, 150 gpm & 150 psi. Tag lower retainer @ 5113'& Printed: 4/21/2008 1:43:35 PM 10:00 - 10:30 0.50 WASH FILL CMPRUN Pick up & wash retainer junk down f/ 5115'- 5376'. Tagged up. 10:30 - 12:00 1.50 TEST_ CSG_ CMPRUN Rig up test pump to - x - annu us. our 2 gallons methanol into annular valve. Unable to fill. Remove test pump. Secure annulus. 12:00 - 13:30 1.50 DRILL_ CMT_ CMPRUN PJSM: Drill retainer junk f/ 5376'. Pushed junk down f/ 5376'- 5422'. 13:30 - 14:00 0.50 RURD_ PIPE CMPRUN PJSM: Monitor well (static). Pump dry job. Move flowline to trip tank. Fill trip tank. 14:00 - 17:00 3.00 TRIP_ DP_ CMPRUN PJSM: POOH w/ 5" drill pipe. Test 9 -5/8" x 13 -3/8" annulus while pulling out of hole by pumping 60 gallons methanol w/ Pollard test pump. Test to 500 psi f/ 30 min. final test pressure 500 psi. 17:00 - 19:00 2.00 PULD_ BHA_ CMPRUN PJSM: Lay dow x drill collars, 2 x junk baskets, bit sub & bit. Clear rig floor. Recovered cement & small pieces of metal. 19:00 - 22:00 3.00 TRIP_ DP_ CMPRUN PJSM: Pick up mule shoe & RIH to 5420'. Pick up pup jt & space out to 5410'. 22:00 - 22:30 0.50 SAFETY MTG_ CMPRUN PJSM: Rig up w/ BJ & crews. Discuss procedure for installing flow lines to blow down well w/ Nitrogen. 22:30 - 00:30 2.00 RURD_ PIPE CMPRUN Rig up BJ to pump Nitrogen thru tubing spool annulus. Install hard lines from rig floor to 500 bbl seperator tank & choke. Test lines 3000/2000 psi. 00:30 - 06:00 5.50 BLOWD CSG_ CMPRUN Blow down well by pumping total of 260,500 cuft nitrogen to displace 375 bbls of 8.5 ppg brine to 500 bbl seperator tank Displacement� complete @ 03:30 Bleed nitrogen from wellbore through seperator tank. Max pressure 2100psi. 1/10/2008 06:00 - 07:30 1.50 BLOWD CSG_ CMPRUN Continue to bleed off nitrogen from well. Complete bleed off. R/D steel lines and valves 07:30 - 14:00 6.50 PULD_ DP_ CMPRUN POH lay down 5" drillpipe f 5410' -0 178jts. Well stable. 14:00 - 14:30 0.50 RUNPUL WBSH CMPRUN P/U test joint ,pull wear bushing 14:30 - 15:00 0.50 RURD_ OTHR CMPRUN Clear rig floor of tongs spinners elevators and all drillpipe handling tools. 15:00 - 16:30 1.50 RURD_ CSG_ CMPRUN PJSM: Rig up weatherford tubing tongs and elevators. Prep rig floor for running 2 7/8 completion equipment 16:30 - 17:00 0.50 SAFETY MTG_ CMPRUN Hold PJSM w/ all personnel on board. Discuss procedure for handling perforating guns and blast joints. Review running tally and associated Printed: 4/21/2008 1:43:35 PM Marathon Oil Company Page 13 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 1/10/2008 16:30 - 17:00 0.50 SAFETY MTG_ CMPRUN hazards. 17:00 - 19:00 2.00 PULD PGUN CMPRUN P /U, M/U & RIH w/ Halliburton TCP perforating guns Total 1 10' OAL of guns run w/ shot density of 5 shots per ft. @ 60? phase. Run 5 joints 2 -7/8" tubing. 19:00 - 21:00 2.00 RUNPU TBG_ CMPRUN Dress out 150' of carbide blast rings on 5 jts of 2 -7/8" tubing. 21:00 - 02:30 5.50 RUNPU TBG_ CMPRUN RIH w/ 157 jts of 2 -7/8" 6.5 ppf Mod EUE completion tubing to 5068'. Top of TCP guns @ 4958'. 02:30 - 04:00 1.50 PULD_ LOG_ CMPRUN R/U & run Expro correlation log. Make correlation. R/D wireline. 04:00 - 05:00 1.00 PULD_ TBG_ CMPRUN Space out 8 -1/2' correction. Top of TCP guns @ 4966.5'. Bottom of g uns 2 5076.5' wireline depth. w ion 05:00 - 06:00 1.00 RURD_ OTHR CMPRUN PJSM: Change out bails on top drive. Change out steel lines for��� nitrogen. �# 1/11/2008 06:00 - 09:30 3.50 PUMP_ N2_ CMPRUN R/U steel lines from tubing spool annulus and rig floor to pressure up9 5/8 X 2 7/8 tubing annulus. Run steel lines from rig floor to BJ pump truck. Test lines to 3500psi.Pump 137,500cf nitrogen to pressure up 9 5/8x 2 7/8 tubing annulus to 700psi. 09:30 - 10:00 0.50 PERF_ CSG_ CMPRUN Pump down tubing with 10500 of Nitrogen and pressure up tubing to 2800psi on surface = 3000psi at 4963'. Bleed pressure off to 700psi. Guns fired after 10min. Pressure dropped in tubing to 700psi, noted surface indication of guns fired. After 30min pressure in tubing and annulus dropp ed to 230 psi. 10:00 - 12:30 2.50 RUNPUL SLIK CMPRUN PJSM: R/U Pollard lubricator & wireline tools. Pressure test lubricator to 500 psi. RIH w/ Xnipple & set @ 4963'. POOH w/ slickline. M/U prong & RIH. Bleed o t rogen rom p ugge ubing. 12:30 - 13:00 0.50 RURD_ SLIK CMPRUN PJSM: R/D Pollard slick line tools. 13:00 - 16:00 3.00 STRIP_ TBG_ CMPRUN PJSM: M/U 2 -7/8" tubing hanger & landing jt. Strip through stack f/ 4963'- 5250'. Install two way check valve. RILDS on tubing hanger. Bleed off stack. Note: 300 psi on annulus during stripping operat 16:00 - 17:00 1.00 RURD_ CSG_ CMPRUN PJSM: R/D Weatherford tools & clear rig floor. 17:00 - 19:00 2.00 CLEAN_ TANK CMPRUN PJSM: Clean out pits. Flush mud pumps, choke manifold, all surface lines & pop -offs. 19:00 - 20:00 1.00 REPAIR RIG_ CMPRUN Replace washed out nipple on mud manifold. Rebuild 2" Demco valve to cement lines. Con't cleaning pits. 20:00 - 22:00 2.00 RURD_ RIG_ XMBO PJSM: Change lower pipe rams to 5 ". Remove mouse hole & tie downs on stack. 22:00 - 00:00 2.00 NUND BOPE XMBO PJSM: N/D BOP stack & prepare to remove w/ crane through rig floor. Clean trip tank. 00:00 - 06:00 6.00 NUND BOPE XMBO PJSM: L/D choke line & kill line. Clear rig floor. Take flange bolts off bag, double gates & mud cross. Take out floor plate bolts. Remove rotary table. Take out floor plates. Remove rotary beams. 1/12/2008 06:00 - 12:00 6.00 NUND BOPE XMBO PJSM w/ crane operator: Continue nipple down BOPE. Rig up crane & remove annulars, pipe rams & mud cross through rig floor. 12:00 - 15:30 3.50 NUND TREE XMBO N/D 13 -3/5" x 11" spool adapter. N/U temporary tree. Test void & bonnet to 5000 psi for 10 min each (good). Note: 1/4" plug in tubing hanger leaking. Appears to be wrong plug for hanger. Decision made to install temp tree. 15:30 - 18:00 2.50 RURD_ RIG_ RDMO PJSM: Install rotary beams, flow box, rotary table, floor plates, rotary lock & rotary chain. Pickle mud pumps. 18:00 - 20:00 2.00 RURD_ RIG_ RDMO PJSM: P/U beaver slide to lower top drive & rail. Pickle drawworks brakes. Prepare to split pits. Lower gas buster lines across roof. 20:00 - 06:00 10.00 RURD_ RIG_ RDMO PJSM: Rig down top drive and torque tube. Blow down water lines. Install bop crane beams. 1/13/2008 06:00 - 06:00 24.00 RURD RIG_ RDMO Continue rig down GD -1. Remove beaver slide cat walk. Scope down Printed: 4121/2008 1:43:35 PM 0 0 Date From - To Hours Code C de Phase Description of Operations 1/13/2008 06:00 - 06:00 1 24.00 KURD RIG_ RDMO derrick. Pull service lines from rig floor, dog house and choke house. Marathon Oil Company Page 14 of 14 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: RECOMPLETION Start: 11/22/2007 End: 12/31/2007 Contractor Name: Rig Release: Group: Rig Name: Rig Number: 1/14/2008 06:00 - 06:00 24.00 RURD RIG RDMO 1/25/2008 09:00 - 10:00 1.00 RURD SLIK PR1 EVL 10:00 - 10:40 1 0.671 SAFETY I MTG_ I RDMO 10:40 - 11:40 1.00 RURD_ SLIK PR1EVL 11:40 - 12:10 0.50 RURD ISLIK PR1EVL 12:10 -12:50 0.67 RURD_ SLIK PR1EVL 12:50 -13:10 0.33 TEST EQIP PR1EVL 13:10 -13:40 0.50 RUNPUL SLIK PR1EVL 13:40 -13:48 0.13 RUNPUL SLIK PR1EVL 13:48 - 14:00 0.20 RURD_ SLIK PR1EVL 14:00 - 14:07 0.12 TEST_ EQIP PR1EVL 14:07 - 14:21 0.23 RUNPUL SLIK PR1EVL 14:21 - 14:30 0.15 RUNPUL SLIK PR1 EVL 14:30 - 14:40 0.17 RURD_ SLIK PR1 EVL 14:40 - 14:45 0.08 TEST EQIP PR1 EVL 14:45 - 14:50 0.08 RUNPUL SLIK PR1 EVL 14:50 - 14:52 0.03 RUNPUL SLIK PR1 EVL 14:52 - 15:00 0.13 RUNPUL SLIK PR1 EVL 15:00 - 15:25 0.42 RURD_ SLIK PR1 EVL 15:25 - 15:30 0.08 TEST_ EQIP PR1 EVL 15:30 - 15:40 0.17 RUNPUL SLIK PR1 EVL 15:40 - 15:47 0.12 RURD_ SLIK PR1 EVL 15:47 - 16:20 0.55 RUNPUL SLIK PR1 EVL 16:20 -16:25 0.08 TEST_ EQIP PR1EVL 16:25 - 16:30 0.08 RUNPUL SLIK PR1EVL 16:30 - 17:15 0.75 RUNPUL SLIK PR1EVL 17:15 - 17:20 0.08 RUNPUL SLIK PRIEVL 17:20 - 17:30 0.17 RUNPUL SLIK PR1EVL 17:30 - 17:42 0.20 RUNPUL SLIK PR1EVL 17:42 - 17:53 0.18 RUNPUL SLIK PR1EVL 17:53 - 18:05 0.20 RUNPUL SLIK PR1EVL 18:05 -18:16 0.18 RUNPUL SLIK PR1EVL 18:16 -18:21 0.08 RUNPUL SLIK PR1EVL 18:21 -18:45 0.40 RURD_ SLIK PR1EVL 18:45 - 19:00 0.25 TEST_ EQIP PR1 EVL 19:00 - 19:15 0.25 SECUR WELL RDMO R/D choke lines. Prep rig for crane work. Crane down back landing,stairways, wind walls,dog house, choke house and gray iron. Continue to pull electrical lines and service lines. R/D pit and pump units. R/U additonal mag heater (bearing overheated & heater caught on fire). Split pits, Move carrier off mud boat. Scope down sub and move off well center. Blow down and drain boiler. Stage water tank, boiler house and generator unit for load out. Weather conditions - 26deg. Hold safety meeting Cold weather and monitoring heaters. Rig released to Paxton #2 0600hrs. 1/14/2008 Crew arrived at location. Spotted equipment and went to get MEOH to use to PTest lubricator. Hold PJSM. Discuss Pollard JSA. Location is extemely slick due to recent rain and warm snap. Stop passing sand truck to sand location. PU lubricator. MU 1 " tool string. Carry lubricator to well head. Work tool string thru pack -off. Won't fall of it's own weight. Change to 1 -1/2" tool string. PTest lubricator w/ well pressure. Test good. Test lubricator to 750 psi. Test good. WHP 100 psi. RIH w' 1 -1/4" SB overshort. Tag prong @ 5252' wlm. POOH w/ prong. OOH w/ prong. PU 1 -1/4" GS overshot. Test QTS. RIH w/ 1 -1/4" GS. WHP 70 psi. Pull XN plug. POOH. OOH w/ XN plug. WHP 60 pdi. Test QTS. RIH w/ 3.13" blind box to determine fluid level. Tag fluid @ 3620'. POOH. OOH. PU 1 -3/4" DD bailer. Test QTS. RIH w/ 143/4" DD bailer to 4000'. OOH w/ sample. Fluid is whole mud( est 10 ppg) RU to run PT Survey. Test QTS. 5 min bench @ 21'. RIH @ 120 fpm to 5253' wlm. 5 min bench at 5253'. PUH @ 120 fpm to 4000'. 3 min bench at 4000'. PUH to 3000'. 3 min bench at 3000'. PUH to 2000'. 3 min bench at 2000'. PUH to 1000'. 3 min bench at 1000'. PUH to 21'. 5 min bench at 21'. POOH. RD lubricator. PTest tree cap. Secure well and location for the night. Turn in permit. Sign out and leave gas field. Printed: 4/21/2008 1:43:35 PM KDU4 Update • Maunder, Thomas E (DOA) • Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Tuesday, March 11, 2008 2:21 PM To: Skiba, Kevin J. Cc: lbele, Lyndon; kdwalsh @marathonoii.com Subject: RE: KDU-4 Update Thanks Kevin. From: Skiba, Kevin 3. [mailto:kskiba @marathonoil.com] Sent: Tuesday, March 11, 2008 1:44 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; kdwaish @marathonoil.com Subject: KDU-4 Update $CANNED APR 2 8 2008 Tom, I am providing this update in an effort to keep you informed about the status of KDU-4. • KDU-4 is not presently flowing • Efforts to convert KDU-4 to a Pool -6 producer has not produced the expected results • Options are currently being evaluated to determine a plan forward for this well We will contact you when the plan is finalized. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283 -1371 Cell (907) 394 -1332 Fax (907) 283 -1350 4/24/2008 0 0 Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba @marathonoil.com] Sent: Thursday, January 24, 2008 10:53 AM To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M. Subject: RE: KDU #4 (169 -012) Tom, Page 1 of 1 Our reporting system is operational again. The information that you are seeking is for work that happened during the system outage. Unfortunately, we still do not have database information available for that time period. Copies of the Job Logs, which were supplied with the 10 -404 Sundry, is the only documentation of the event activities for this work. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283 -1371 t i cANNW JAN Cell (907) 394 -1332 Fax (907) 283 -1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, January 24, 2008 8:32 AM To: Skiba, Kevin J. Subject: RE: KDU #4 (169 -012) 4 2000 Kevin, We exchanged a couple of emails regarding the work summary submitted with the 404 for work authorized by 307 -266. Your letter was dated 11 /28/07. There were problems with the Marathon reporting system. If the system is back up, could you send the more detailed reports? Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, December 04, 2007 3:52 PM To: Skiba, Kevin J. Subject: KDU #4 (169 -012) Kevin, This is one of the 10404s you recently submitted. Do you a "Marathon report" for this work? The BJ report is not very legible. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 1/24/2008 Subject: KDU #4 (169 -012) • Importance: High • / — Orl Kevin, Please pass this on to any of the engineers I missed. An attempt to pressure test the recently set coil cement plug in KDU #4 was not successful. As I understand, the plug was tagged at 6000' which is about 300' below the tubing tail. Based on discussions with the Inspector at the site and after examining the proposed procedure, it has been determined that Marathon should set another coil cement plug intending to squeeze if possible. The pressure test should then be redone. Setting another plug is felt prudent due to the age of this well. Also, prior to blowing the fluid out of the well the casing should be pressure tested with an Inspector present. Marathon should determine the appropriate surface pressure necessary to unload the fluid using nitrogen. Cali or message with any questions. Tom Maunder, PE AOGCC 4/24/2008 KDU Ord (PTD 169 -012) WO Rig BOPE Test Pressure Amendment Vest Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 18, 2007 2:19 PM To: Donovan Jr, Dennis M. Cc: Skiba, Kevin J. Subject: RE: KDU Ord (PTD 169 -012) WO Rig BOPE Test Pressure Amendment Request Dennis, et al, Changing the rig BOP test pressure as proposed is acceptable. I will put a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Donovan Jr, Dennis M. ( mailto :ddonovan @marathonoil.com] Sent: Tuesday, December 18, 2007 9:32 AM To: Maunder, Thomas E (DOA) Cc: Skiba, Kevin J.; Donovan Jr, Dennis M. Subject: KDU 4rd (PTD 169 -012) WO Rig BOPE Test Pressure Amendment Request Tom, Marathon is requesting a change to the drilling rig BOP test pressure for KDU 4rd workover. It is reflected in sundry 307 -366 that 3500 minimum BOP tests are required, and I understand why, since my procedure did not reflect test pressures. Marathon is requesting that the Rig BOP test pressure be amended to 250/2000 psi. This pressure test will be below the 3000 psi Wellhead but estimated reservoir pressure is 142 psig for Sterling Pool 6. The rig operations will only be involved with Sterling Pool 6. Marathon will maintain 250/3500 psi test pressures for all pre and post rig work for this workover (ie. coiled tubing BOP equipment) as planned. Thanks Dennis (Dennis 911. Donovan , fir Production Engineer I 907 -283 -1333 Office 907 -398 -1362 Cell 4/24/2008 Maunder, Thomas E (DOA) • Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Tuesday, December 11, 2007 4:23 PM To: Donovan Jr, Dennis M. Cc: Skiba, Kevin J. Subject: RE: KDU #4RD (169 -012) Gentlemen, If all goes well, I will have your approval in the morning. Tom From: Donovan Jr, Dennis M. [ mailto :ddonovan @marathonoil.com] Sent: Tuesday, December 11, 2007 4:18 PM To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M.; Skiba, Kevin J. Subject: FW: KDU #4RD (169 -012) Tom, I have one question, Do we need to have 403 sundry approval to proceed with removal of the currently installed v- string in KDU 4rd? I am unsure if this would apply under new rules or not? Thanks for the help, Dennis Dennis W. Donovan ,fir. Production Engineer I 907 -283 -1333 Office 907- 398 -1362 Cell From: Donovan Jr, Dennis M. Sent: Tuesday, December 11, 2007 3:22 PM To: Maunder, Thomas E (DOA) Cc: Skiba, Kevin J.; Donovan Jr, Dennis M. Subject: RE: KDU #4RD (169 -012) Tom, Attached is the separate document for KDU 4rd. Thanks, Dennis (Dennis Wit. Donovan A Production Engineer I 907 - 283 -1333 Office 907 - 398 -1362 Cell 4/24/2008 • Page 2 of 2 From: Maunder, Thomas E (DOA) (mailto:tom.maunder @alaska.gov] Sent: Tuesday, December 11, 2007 10:38 AM To: Donovan Jr, Dennis M. Cc: Skiba, Kevin J.; Arthur C Saltmarsh Subject: RE: KDU #4RD (169 -012) Here it is again. From: Maunder, Thomas E (DOA) Sent: Monday, December 10, 2007 3:44 PM To: Donovan Jr, Dennis M. Cc: 'Skiba, Kevin J.; 'Arthur C Saltmarsh' Subject: KDU #4RD (169 -012) Dennis and Kevin, We have received the 403 to abandon the Beluga perforations and complete in Pool 6. The procedure looks OK, however attaching the letter from 2000 for KU 14 -32 is confusing. While I understand the intent of your plan, it is appropriate to have a letter specifically for KDU #4RD. While the 14 -32 plan is generally applicable to KDU #4RD, there are some items definitely different, including 2 -7/8" tubing in KDU #4RD. A separate document for KDU #4RD should be prepared. Submitting via email is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC 4/24/2008 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com] Sent: Tuesday, December 11, 2007 11:09 AM To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M. Subject: RE: KDU #4 (169 -012) Tom, Unfortunately, we are still unable to access our operation summaries. Thanks, Kevin Sidba Production Technician Marathon Oil Company Office (907) 283 -1371 Cell (907) 394 -1332 Fax (907) 283 -1350 F • Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent ay, December 11, 2007 9:41 AM To: Skiba, K J. Cc: Donovan Jr, is M. Subject: RE: KDU #4 -012) Kevin and Dennis, Are you now able to access the opera s summary for KDU #4? Thanks, 7 Tom From: Skiba, Kevin J. [maiito:kskiba @marath .coma Sent: Tuesday, December 04, 2007 4:39 To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M. Subject: RE: KDU #4 (169 Tom, We had trqwble accessing the operations summary for this well. The BJ report is the only information tha a had availa_Wellto provide you, at this time. 12/11/2007 . 0 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 11, 2007 9:41 AM To: 'Skiba, Kevin J.' Cc: Donovan Jr, Dennis M. Subject: RE: KDU #4 (169 -012) Kevin and Dennis, Are you now able to access the operations summary for KDU #4? Thanks, Tom From: Skiba, Kevin 3. [mailto:kskiba@marathonoil.com] Sent: Tuesday, December 04, 2007 4:39 PM To: Maunder, Thomas E (DOA) Cc: Donovan Jr, Dennis M. Subject: RE: KDU #4 (169 -012) Tom, We had trouble accessing the operations summary for this well. The BJ report is the only information that we had available to provide you, at this time. Kevin Slaba Production Technician Marathon Oil Company Office (907) 283 -1371 Cell (907) 394 -1332 Fax (907) 283 -1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, December 04, 2007 3:52 PM To: Skiba, Kevin J. Subject: KDU #4 (169 -012) Kevin, This is one of the 10404s you recently submitted. Do you a "Marathon report" for this work? The BJ report is not very legible. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 12/11/2007 Marathon Oil Company Alaska Asset Team Marathon P.O. Box 1949 /+ Kenai, AK 99611 MARATHON Oil Company Telephone 9071283 -1371 Fax 9071283 -1350 November 28, 2007 RECEIVED Mr. Tom Maunder NOV 2 6 2007 Alaska Oil & Gas Conservation Commission 333 W 7 Ave Alaska Oil & Gas Cons. Commission Anchorage, Alaska 99501 Anchorage Reference: 10 -404 Report of Sundry Well Operations — Velocity String Installation — Sundry #307 -266 Field: Kenai Gas Field Well: Kenai Deep Unit 4 (PTD -169 -012) Dear Mr. Maunder. Enclosed is the 10 -404 sundry 307 -266. This sundry reports the installation of a 1.75" Velocity string to 6795' KBD to promote water unloading. Attached with the 10 -404 is the detailed operations summary report and current wellbore diagram. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398 -1362. Sincerely, 4s 7 z. Dennis Donovan Production Engineer Enclosures: 10 -404 Sundry of Well Ops 307 -266 cc: AOGCC Detailed Operations Summary Report Houston Well File Current Well Schematic Kenai Well File DMD KJS RECEIVED STATE OF ALASKA NOV 2 g 200 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSA(aska Gil & Gas Cans, Commiuion Anchorage 1. Operations Abandon U Repair Well Plug Perforations U StimulateLj Other Ld Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver[ Time Extension ❑ Installed 1.75" Change Approved Program ❑ Operat Shutdown ❑ Perforate ❑ Re -enter Suspended well ❑ velocity string 2. Operator 4. Well Class Before Work: 250 5. Permit to Drill Number: Name: Marathon Oil Company Development Q Exploratory F] 169-012 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. PO Box 1949, Ken ;i Alaska, 99611 -1949 0 55 50- 133- 20176 -00 -01 7. KB Elevation (ft): 9. Well Name and Number. 95' KB MSL Copies of Logs and Surveys Run N/A Kenai Deep Unit #4 8. Property Designation: j Development ❑✓ 10. Field/Pool(s): Daily Report of Well Operations X 235' FNL, 4209' FWL, Sec. 7 T4N, R11W, S.M. 16. Well Status after work: Kenai Gas Field, Belu afr onek Gas Pool 11. Present Well Condition Summary: Total Depth measured 10,810` feet Plugs (measured) 8,000' true vertical 9,736' feet Junk (measured) 7,593' Top of Fish esrd Effective Depth measured 8,000' feet true vertical 7,181' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,264' 20" 1,264' 1,222' 1530 5020 Intermediate 6,026' 13 -3/8" 6,026' 5,400' 3090 1540 Production 10,310' 9 -5/8" 10,310' 9,280' 6330 3810 Liner 49T 7" 10,759' 9,685' 8120 7020 Perforation depth: Measured depth: 6,428'- 7,697' True Vertical depth: 5,970' - 5,978 1.75" 0.125" WT HO 70 6795' Tubing: (size, grade, and measured depth) 3 -1/2" N -80 9.2 ppf 5,720' Packers and SSSV (type and measured depth) Bak SAB perman PKR 5,814' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 250 0 0 59 Subsequent to operation: 0 0 0 0 55 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development ❑✓ Service ❑ Daily Report of Well Operations X 16. Well Status after work: Contact Printed Name Signature Oil [I Gas Q WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ ie foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307 -226 Kevin Skiba (907) 283 -1371 Title Production Engineer Phone (907) 283-1333 Date 28- Nov -07 DUPLICATE Submit Original Only M. Donovan Jr Form 10 -404 R ' R DEC 12 2007 KQU 4rd Pad 41 -7, Kenai Gas Field I: 50- 133 -20176 , GCC: 69 -12 -MSL (Original Drig): 13.2' KB -THF -GL (1996 w /o): 20.5 i FNL, 4209' FWL c. 7, T4N, R11W, S.M. threads: ? ?? !e cap: 4 -3/4" Otis (on dual tree) - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' M9/10 - 6428'-6458'(1/31/03) M14 - 6655'-6665'(2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) Isolated Perfs 9937' -947' (6/69) 9952'-986'(6/69) 9994'- 10002' (6/69) 10258'-279'(6/69) 10315' -316' (sgzd 6/69) 10428' -470' (6/69) 10430'440' (6/69) 10480'-490'(6/69) _ _ � l x � X � Y x PBTD - 8000' TD - 10,810' 20 ", 94#, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" ttis4� 3�flts- af-3:5 ; $:4- ryp�L-- 88 tabirsg, droppruf 1043/9i}(does not exist, fished during 1995 Workover) 1.75" OD, 0.125" WT HO70 Flash -out coil tubing, 0' -6795' MD BHA= 2.50" OD BHA with 1.25" PXN Profile 157' of 1.75" OD, 0.125" WT Coil Tubing @ Approximately 7593' MD after we washed down to 7750' MD with Coil Tubing. (7750- 157 =7593' MD) Coil velocitv string detail I 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 157' CT fish in hole 3 ", Armco "seal -lock" prod. csg @ 10, w/ 1415 sks of class "G" 0' - 35', 53.5 #, P -110 35' - 4194', 43.5#, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5 #, P -110 Retainer @ 8000'(10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29#, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU 4rd I Lease: Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough I State/P,.wl Alaska I Country USA Perforations: (MD) Beluga (TVD): Angle / Perfs: I Angle @KOP and Depth: 25 deg KOP (TVD): Date Completed: 02/16/03 1 RKB: Prepared By: Dennis Donovan Last Revision Date: 11/28/07 DMD 1J - 1 0 4 Client: U� �� Weil: 1�v Job: 1 i r� BJ SERVICES COMPANY MIDDLE EAST COILED TUBING AND PUMPING JOB LOG Date: g'(-y - 7 BJ Sup: CT Unit: T ! S6`1 Client Rep: JPsf 6 f CT OD: / 3 14' Distance to Location: • C7 Event Description =0MMMM A� ���� .r���w��■i■�� -,■ter • C7 4 4dK UJ Client H06- well: k O w Y .41? Job: 6 z f BJ SERVICES COMPANY MIDDLE EAST COILED TUBING AND PUMPING JOB LOG Date: I - / ? - t7l CT Unit S / 4 c/ CT OD: l ;h BJ Sup: M' 1 Client Rep: / Distance to Location: Aaye- Z .?-Sc lr-r4w Syco 3Sd vd q so Coo ssoaa • F7 000 70 '73000 7paoa ??000 iL� °° Des cription Event - i Fluid T - • WM- Y/AFAT U13 W— W2 WTI rAm N "A W/1A� Hmm MAW- Mom RIM .?-Sc lr-r4w Syco 3Sd vd q so Coo ssoaa • F7 000 70 '73000 7paoa ??000 iL� °° r Client: G Weil: D V 4 1 A9 Job: G ,: , , ;rc/ BJ SERVICES COMPANY MIDDLE EAST COILED TUBING AND PUMPING JOB LOG Date: CT Unit: CT ( BJ Sup: 0 14. £g:,e 44 ,✓ Client Rep: )O f- Acs e 3 0.� Event �_. a ll a__ • 2C0 0000 ?..5owv p3o add 2 S2 li0c 9 UQ i Client: J" 01 Well: mou - 14 RD BJ SERVICES COMPANY MIDDLE EAST COILED TUBING AND PUMPING JOB LOG Date: $- jle> - 0 7 BJ Sup: /N, fRt !i= le. ! .../ CT Unit: 7/ 9 V Client Rep: As i b: CT OD: l l/! Distance to Time Event Description Depth From Cycle Run I CTP I WHP Weight Up To Event Weight I Liquid I Return I Fluid I I Volume Outer Dn Rate Rate Type Pumped Press 0 • KDlJ4rd Recompletion (PTD # 17) Pagel nf3 is Regg, James B (DOA) From: Walsh, Ken [kdvva naUhonoiicon] Sent Tuasday, January 2OO87�48A&1 W|�� ' ' ' � ( q", To: Regg. James 8(OCA ' \ Cc: Maunder, Thomas E(DOA);|bae.Lyndon ji[n. I apologize for just getting this to you. I wrote and sent it yesterday but found it in my Microsoft Outlook Outbox this morning. We have drilled through the perforated interval and obtained a good pressure test with KCL water. We are currently drilling out the cast iron bridge plug. &W Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team From: Walsh, Ken Sent: Tuesdmy, January 08, I008 7:43 AM To: Regg, James B(DOA) Cc: Maunder, Thomas E(DOA); Ibe|e, Lyndon Subject: RE: KDU4ndReconnp|etion/PTD#169-U12\ Ken D. Walsh Senior Production Engineer w C"='=°=~~ °"'` 11 ^~~~ C� �f�"r"°~�° '` C�0ve- _.— \" From: Regg,]anxa B(DOA) [maiKojino.regg@alaska.gov] Sent: Friday, January 04,2U086:33PM \~iuu To: Walsh, Ken �\ ` l/0/2008 ' KDU 4rd Recompletion (PTD #1 012) • Page 2 of 3 Cc: Maunder, Thomas E (DOA) Subject: RE: KDU 4rd Recompletion (PTD #169 -012) Ken — Thank you for the work procedure detailing plans to isolate the new Sterling Pool 6 perforations and then reperforate Sterling 6 as described in Sundry 307 -366. The work proposed as outlined below is within the overall objective of Sundry 307 -366 (recomplete from Beluga to Sterling 6 Pool). There is no additional sundry approval required. As we discussed, you are planning to verify the Sterling Pool 6 perforations with a caliper survey following the bit and scraper run (not included in procedure you sent). That will certainly add some certainty to the placement of your CIBP and retainer, and affect (to a lesser extent) the cement volume calculations. I would appreciate an update Monday on your work progress, and cement volume planned to accomplish the proposed work. I forgot to ask during our phone call about plans for verifying the annulus cement; I thought I heard you say the plan is for 500 feet above the perfs in annulus. Are you planning a bond log or other to verify cement top? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 - 793 -1236 fax: 907 - 276 -7542 From: Walsh, Ken [ mailto:kdwalsh @marathonoil.com] Sent: Friday, January 04, 2008 2:26 PM To: Regg, James B (DOA) Subject: KDU 4rd Recompletion (PTD #169 -012) M around Marathon believes that this drilling mud and cement came from the 9-5/8" x 13-3/8" annulus. The calculated cement top in this annulus is !!1 !! to r across and 500' above the current Pool 6 perfs to isolate this interval and then reperforate. Marathon's plan would be - PU and RIH with a bit and scraper on 5" drill pipe to tag the top of the dropped TCP guns and clean out the drilling mud and cement from the 9-5/8" casing. i - Attempt to circulate dawn the 9 -518" casing through the drill pipe and up the 9-5/8" x 13-3/8" annulus to surface with KCL water. - RIH with a cast iron bridge plug and set it just below the bottom pert at 5075' KB with eline. - PU and RIH with a cement retainer on 5" drill pipe. Bet the cement retainer about 10' above the top perforation at 4975' KB. 1/9/2008 KDU 4rd Recompletion (PTD #jlj-�012) Page 3 of 3 and 500' above in the 9-518" -3/8" annulus. After cement is plaO, close in 9-518" x 13-318" annulus and hesitation squeeze from 100 up to 500 psi. - POOH with drill pipe and WOC. - PU and RIH with bit on drill pipe. Drill out the cement retainer and cement down to the cast iron bridge plug and test to 500 psi with KCL water. Drill out the CIBP and push down to bottom (top of spent TCP guns). POOH. - RIH with open-ended drill pipe and reverse circulate KCL water out to tank with nitrogen. Bleed off all nitrogen pressure and POOH with drill pipe. - Rerun tubing-conveyed perforating guns on 2-7/8" tubing as previously run. - Pressure up 9-5/8" casing to 128 psi with nitrogen. Pressure up on tubing with nitrogen to initiat4 TCP firing and gun drop sequence. Bleed off nitrogen pressure from tubing, - Strip the rest of the tubing (about 270') into the well and hangoff. - Secure wellhead and RD MO Drilling Rig. We wish to secure your approval to proceed with this work today. We do not anticipate the need for sundry approval to perform this work but wanted to verify that our assumption was in agreement with the AOGCC regulation interpretation. Ken D. Walsh Senior Production Engineer 907-283-1311 (office) 907-394-3060 (cell) <<KDU 4rd WBD Proposed P6 WO 12052007.xls>> 1/9/2008 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: FROM: Jim Regg P. I. Supervisor Lou Grimaldi Petroleum Inspector DATE: December 24, 2007 SUBJECT: bbUNEI�' FEE Y 9 2GR Abandonment Plug's Verification Marathon, Kenai Gas Field Kenai Deep Unit 4 Redrill PTD #169 -012 Sundry #307 -366 December 23, 2007: i witnessed the successful second verification of abandonment plug and Cast Iron Bridge Plug placed in Marathon's well "Kenai Deep Unit 4 Redrill" in the Kenai Gas Field. This was the second attempt at plug ver4iGation:..(see "Wellbore Plug KDU 4RD 12 -19 -07 LG ") the earlier attempt failed with a steady 40 psi decline. A second cement squeeze had been performed yesterday. I arrived to find the E -line crew rigging up on the well in preparation for a tag of the cement plug. A tooistring consisting of a collar locater, weight bar, spang jars and a 2.75 gauge ring was run to 5866' RKB where it fetched up hard and with three attempts could go no deeper. This showed an additional 196' of cement in place. With the top perforation at 6428' RKB and r tubing tail at 5720' adequate cement appeared to be in place. All depths were tied into an existing SOS log, the packer and tubing tail were evident while making this tag. Once the E -line and tolls were retrieved a pressure test of the plug was attempted. The first attempt today seemed to have the same results as the previous test on 12/19/07 with a slightly less linear decline (2 psi /minute). The IA seemed to be raising pressure during this test. After discussing this with the Marathon rep. Mike Sulley the pumps were lined up on the IA and tubing and a combo MIT was performed. Due to the rigging of the pump iron and leaking valves we could not keep the IA and tubing tied together during the test. The results of this test were much better indicating a possible packer leak. I passed the pressure test of the abandonment on the condition that once the Cast Iron Bridge Plug (CIBP) was set in the packers tubing tail and the tubing above the packer was cut a more stable pressure test would be obtained. The CIPL was set at 5700' (RKB) which was below the second "X nipple" in the tubing tail. The tubing was "Jet Cut" at 5555' (RKB) which was in the first full joint above the packer. All E -line tools were retrieved and another pressure test was performed. This test had much better results with a loss of 10 psi in thirty minutes on an 1860 psi pressure test. Summary: I witnessed a successful pressure test of two abandonment plugs on Marathon's well "Kenai Deep Unit 4 Redrill" in the Kenai Gas Field. Attachments: None. Non - Confidential 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: FROM: Jim Regg �'e DATE: December 20, 2007 P. I. Supervisor t IZ�21�p 7 Lou Grimaldi SUBJECT: Abandonment Plug Verification Petroleum Inspector Marathon, Kenai Gas Field Kenai Deep Unit 4 PTD #169 -012 ✓ Sundry #307 -366 December 19, 2007: 1 witnessed the attempted verification of abandonment plug placed in Marathon's well Kenai Deep Unit 4 in the Kenai Gas Field. 1 arrived to find the E -line crew rigging up on the well in preparation for a tag of the cement plug. A toolstring consisting of a collar locater, weight bar, spang jars and a 2.75 gauge ring was run to 6064' RKB where it fetched up hard and with three attempts could go no deeper. With the top perforation at 6428' RKB adequate cement appeared to be in place. All depths were tied into an existing SOS log, the packer and tubing tail were evident while making this tag. Once the E -line and tolls were retrieved a pressure test of the plug was attempted. The original test pressure was to be 1500 psi, as the well originally had 800 psi I requested a test of 1800 psi be made. Three attempts were made to test this plug with the same results, a steady 40 psi decline in each 15 minute segment with no stabilizing trend. After conferring with Jim Regg and Tom Maunder (A.O.G.C.C. engineers) I directed Pat Grant (Marathon) that a squeeze would be required. I will be notified when the squeeze is in place and an opportunity to witness another pressure test is ready. Summary: I witnessed a failed pressure test of an abandonment plug on Marathon's well Kenai Deep Unit 4 in the Kenai Gas Field. Attachments: None. Non - Confidential Si'��MINED JAN 2 4 2008 0 0 zu ED AIASKA SARAH PALIN, GOVERNOR CO�L+��A IAS AN j S 333 W 7th AVENUE, SUITE 100 ►S 1. o� 1 �•• 1���� �� ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Anchorage, AK 99611 -1949 yv 1 Re: Kenai Gas Field, Tyonek Gas Pool, Kenai Deep Unit 4 ReDrill Sundry Number: 307 -366 &��� DE � � 2007 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31. 05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. F, DATED this day of December, 2007 Encl. • • a Marathon Oil Company December 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7' Ave Anchorage, Alaska 99501 Reference: 10 -403 Sundry Notice Field: Kenai Gas Field Well: Kenai Deep Unit 4 ReDrill Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 9071283 -1371 Fax 9071283 -1350 DEC 0 7 ?ot1 Alaska Oil & &a Enclosed please find a 10 -403 Sundry Notice application for KDU -4RD well with associated attachments. Marathon plans to pull the 1.75" Velocity String tubing and cement plug back the Beluga formation perforations. The cement plug will be placed at least 100' above the top Beluga perforations. The 3 -1/2" Production Tubing will be severed above the SAB Packer and removed. The Sterling Pool 6 (new zone) will be perforated utilizing 1 10' of 2 -7/8" Tubing Conveyed Perforation charges. The 2 -7/8" tubing will remain in the wellbore, at a setting depth of approximately 5,200' MD, and function as the exterior Concentric String tubing. A 1.75" coil tubing string will be inserted inside the 2 -7/8" tubing completing the Concentric String. If you have any questions or need additional information please call me at (907) 283- 1371. Sincerely, 4" "M , <5 0�" Kevin J. Skiba Production Technician Enclosures: 10 -403 Sundry Notice cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Operations Program KJS Low Pressure Packerless Prod. Letter DMD Marathon Oil Company Alaska Asset Team a Marmon P.O. Box 1949 Oil Company Kenai 99611 Telephone 9071283 -1371 Fax 907/283 -1350 December 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W P Ave Anchorage, Alaska 99501 Q Reference: Recompletion of KDU 4rd, Kenai Gas Field V, CE� Field: Kenai Gas Field ENAU-\ Well: Kenai Deep Unit 4 (PTD -169 -012) Dear Mr. Maunder. Marathon is proposing that KDU 4rd be recompeeted from a Beluga producer to a Sterling Pool 6 producer. We have evaluated the Beluga zones and see no other economic flow potential in this welibore. In light of this, addition of a Sterling Pool 6 take point and maximizing deliverability is the next resource for this weilbore. In performing a Sterling Pool 6 recompletion, a packerless completion would be needed to allow us maximum defiverability utilizing tubing and annular flow. The AOGCC has approved packerless completions for low pressure Sterling Pool 3, 4, and 6 wells in the past. Technical analysis and operational histories of other packedess Sterling Pool 3,4, and 6 completions demonstrate that corrosion and erosion are not of concern. Currently Sterling Pool 6 has approximately a 165 psig bottom -hole pressure. Sterling Pool 6 gas storage guidelines regulate reservoir pressure no higher than 300psi outlined in SIO 7A. This will ensure pressure containment is maintained and the well will be equipped with surface safety devices that will shut in the well automatically in the event of production upset. KDU 4rd Sterling Pool 6 producer will also include a concentric string for water removal. This is necessary due to the large annular flowpath and low reservoir pressure. In looking back at other Sterling Pool 6 completions, KU 14X-6 (PTD 181 -092) would serve as a "look - alike" to the KDU 4rd Sterling Pool 6 recompletion. Please send any pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398 -1362. Sincerely, < t /� P- Dennis Donovan Production Engineer 0 RECEIVED STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 7 200+' APPLICATION FOR SUNDRY APPROVAMsk Qil & C" r,'0! . C,0ff nission 20 AAC 25.280 A _ 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver Other ❑ After casing ❑ Repair well ❑ Plug Perforations Q Stimulate ❑ Time Extension ❑ Change approved program ❑ Pull Tubing ❑✓ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: Marath Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 169 -012 3. Address: PO Box 1949 6. API Number: Kenai, Alaska 99611 - 1949 50 133 20176 - 00 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ❑ Kenai Deep Unit 4 ReDritl Spacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA 028142 20.s (ss above MSL) Kenai Gas Field / 00age T onek pools 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,810" 9,739' 10,711' 1 9,643' 8,000' 8,956' Casing Length Size MD TVD Burst Collapse Structural Conductor 1,264' 20" 1,264' 1,217' 1,530 psi 520 psi Surface 6,026' 13 -318" 6,026' 5,400' 3,090 psi 1,540 psi Intermediate Production 10,310' 9 -5/8" 10,310' 9,280' 10,900 psi 7,930 psi 6,330 psi 3,810 psi 6,870 psi 4,750 psi 9,440 psi 5,310 psi Liner 497' 7" 10,759' 9,688' T 8 psi 7,0230 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,428' 7,697' gross 5,769' - 6,902' gross 3 - 1/2" N - 80 5,720' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 194.40 x 32 SAB packer 5,579' 13. Attachments: Description Summary of Proposal ❑ 14. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development Q Service [] 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 1211112007 Oil ❑ Gas Q Plugged ❑ Abandoned Ej WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skibe (907) 283 -1371 Printed Name Dennis M. Donovan Title Production Engineer Signature Phone (907) 283 -1333 Date 12/7/2007 COMMISSION USE ONLY �( /, Sundry Number: � b _ - 3V 6 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 �> �ti� �F v \ S 8FL DEC 13 2007 Subsequent Form Required: L�12 APPROVED BY OMMISSIO R THE COMMISSION Date: 0 - /,Z Approved by: Form 10403 Revised 06/2006 l� �� D UPL I C AT E Submit in Duplicate E a MARATHON OIL COMPANY ALASKA REGION • Kenai Gas Field KDU 4rd 2007 Pool 6 Recompletion Procedure (12 -07 -20071 1. Test Annulus. Before Rigup of Coil Tubing Unit, Test 9 -5/8" by 3 -1/2" annulus to 3000 psi. for integrity 2. RU Coil Tubing Unit. Remove 6795' of 1.75" coil tubing. �'s � N:mz, 3. Lay Cement Plug. Lay cement P&A plug across open Beluga perforations. TOC will be between 100' above top perforations and 100' below 3 -1/2" Wireline Entry Guide. WOC. 4. RU Slickline Pressure test and tag plug with AOGCC representative on site. Set an x -plug into either 5622' or 6687'X-nipple and blow down tubing.- 2. RU Ellne. RIH and Cut 3 -1/2" tubing above Baker 80 -40 SAB Paker. 3. RU N2 Puma. Pump down 9 -5/8" by 3 -1/2" annulus and reverse up 3 -1/2" tubing. Evacuate fluids from wellbore. Leave well dry and release to Glacier Drilling Rig. 4. RU Glacier Drilling. RU Glacier. POOH with 3 -1/2" Tubing. Vetco to replace hanger spool w/ 2 -7/8 ". RIH w/ 2 -7/8" and hydraulic fired TCP's. (110'). Shoot @ 4975' -5085' (110') with 130 psi of N2 gas on 9- 5/8" by 2 -7/8" annulus. Pressure up on 2 -7/8" tubing and fire with N2 pressure. TCP's will drop off and fall to bottom. RIH with Slickline and set a 1.25" PXN plug in 2 -7/8" pipe. Strip in remaining 5 joints of 2- 7/8" to provide a sufficient sump for the concentric string. Land hanger, RD BOP stack, install tree, RD Glacier. 4 N Est ';2> C) 5. RU Coil Tubing Unit RIH with velocity string (1.75" H070 pipe) to 10' above 1.25" XN plug. Land into hanger and RD Coil Unit. 6. RU Slickline. POOH with 1.25" XN plug located in the 2 -7/8" pipe, Pull through 1.75" coil that is installed in the well. RIH with 1.25" XN standing valve for operation of the concentric string. 7. RDMO. CONTACTS Dennis Donovan: 907- 283 -1333 (w) David Martens: 713- 296 -3302 (w) 907 - 398 -1362 (cell) 832- 472- 6249(cell) Lyndon Ibele: 907 - 565 -3042 (w) 907 - 748 -2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907 - 283 -1305 Emerciency Dial 911 • Permit #: 169 -012 API #: 50-133-20176-00-00 Property Des: FEDA 028142 KB: 20.5' AGL (1996 w /o) GL: 66' 2/11/1969 ched: 511911996 Tree cap: 4 -3/4" Otis (on dual tree) Active Perfs (Beluga Formation) M9/10 - 6428' -6458' (1/31/03) M14 - 6655' -6665' (2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264'-7293'(11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) 9937' -947' (6/69) 9952'-986'(6/69) 9994'-10002'(6/69) 10258' -279' (6/69) 10315' -316' (sgzd 6/69) 10428' -470' (6/69) 10430' -440' (6/69) 10480' -490' (6/69) 157' of 1 -3/4" coil tubing @ 6,680' CTM Fill tagged @ 7,720' CTM (5/1/07) Retainer @ 8,000' (10119/95) Retainer @ 8,955 (10117/95) KDU 4RD Pad 41 -7 235' FNL, 4,209' FWL Sec. 7, UN, R11W, S.M. • I ATHON Drive Pipe 20" H-40 94 ppf 8rd Toe Bottom MD 0' 1,264' TVD 0' 1,221' Cmt w/ 900 sks of Class G 1.75" OD H070 0.125" WT Flash -out coil tubing, 0'- 6,795' MD BHA= 2.50" OD BHA with 1.25" PXN Profile » ...... ..... " ... ..FISH ................... ». 157' of 1.75" OD, 0.125" WT Coil Tubing @ Approx 7593' MD after we washed down to 7750' MD with Coil Tubing. (7750 -157 =7593' MO) Well Name & Number: Surface Casing Lease: I Kenai Gas Field 13 -318" J -55 61ppf Seal -Lock Kenai Peninsula Borough Toe Bottom Alaska MD 0' 6,026' USA TVD 0' 5,408' Beluga Cmt wl 3,259 sks of Class G 6,428'- 7,697' gross Production Casing 5,769'- 6,902' gross 9 -518" N-80 Seal -Lock 25 deg 0' - 35' 53.5ppf P -110 4,210' 35' - 4,194' 43.5ppf, N-80 3,760' 4,194' - 5,733' 47 ppf N -80 02/16/03 5,733' - 8,206' 47 ppf P -110 13.2' THE 8,206'.10,310' 53.5ppf P -110 20.5' (1996) Toe Bottom Kevin Skiba I MD 0' 10,310' 12!7/2007 TVD 0' 9,268' Cmt w/ 1,415 sks of Class G Liner 7" N-80 ppf BTC Toe Bottom MD 10,280' 10,759' TVD 9,242' 9,688' Cmt w/ 130 sks of Class G Tubing String 3 -112" N -80 9.2ppf IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 212003 Baker 80 -40 K- Anchor @ 5,572' Baker SAB Packer @ 5,573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5,720' 1.75" OD H070 0.125" WT Flash -out coil tubing, 0'- 6,795' MD BHA= 2.50" OD BHA with 1.25" PXN Profile » ...... ..... " ... ..FISH ................... ». 157' of 1.75" OD, 0.125" WT Coil Tubing @ Approx 7593' MD after we washed down to 7750' MD with Coil Tubing. (7750 -157 =7593' MO) Well Name & Number: KDU 4RD Lease: I Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations: Beluga Perf (MD): 6,428'- 7,697' gross Perf (TVD): 5,769'- 6,902' gross Angle @ KOP: 25 deg KOP (MD): 4,210' KOP(TVD): 3,760' Date Completed: 02/16/03 Original Drilling KB: 13.2' THE RKB: 20.5' (1996) Prepared By: Kevin Skiba I I Last Revision Date: 12!7/2007 PBTD - 8,000' MD TD = 10,810' MD TD = 9,739' TVD 0 M KDU Ord MARATNom Proposed Concentric Pool 6 Pad 41 -7, Kenai Gas Field API: 50- 133 -20176 AOGCC: 69 -12 RT -MSL (Original Drlg): 13.2' KB -THF RT -GL (1996 w /o): 20.5' 235' FNL, 4209' FWL Sec. 7, T4N, R1 1W, S.M. Lift threads: ? ?? Tree cap: 4-3/4" Otis (on dual tree) 3.5" Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' PROPOSED TUBING 2 -7/8" Tubing String - 2 -7/8 ", 6.5# 8rd tubing -5235' M D 20", 94#, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" 1 tsh - -� jrtts of 3.5"" 9.4pp#-,t-80; JBT- tuning, dropped- UW23i9 (does not exist, fished during 1995 Workover) Coil Tubing Velocity String (for concentric) 1.75" OD, 0.125" WT HO70 Flash -out coil landed 10' above 1.25" profile in 2 -7/8" pipe - � 157' of .............,. .....1.75" FISH.,.....,..........,.., OD, 0.125" WT Coil Tubing @ , Approximately 7593' MD after we washed down to 7750' MD with Coil Tubing (7750- -�— 157 =7593' MD) Pool 6 TCP Guns (110') - Dropoff, Fired with N2 In a dry hole (cannot fire with bar drop due to a 1.25" PXN nipple above the guns) ADD Perf Depths- 4975' to 5085' E E Plug Set into X- nipple at either 5622' or 5687' , Active Perfs (Beluga Formation) M9/10 - 6428' -6458' (1/31/03) Pad 41 -7, Kenai Gas Field M14 - 6655' -6665' (2/6/96) Kenai Peninsula Borough L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 - L9 - 7264' -7293' (11/19/95) (TVD): L10 - 7340'- 7350' (11/25/95)_ L13 - 7668'-7678'(11/11/95) Angle @KOP and Depth: L13 - 7683' -7697' (11/11/95) Isolated Perfs ' 9937' -947' (6/69) 02/16/03 1 9952'-986'(6/69) 5c x 9994'-10002'(6/69) x X 10258'-279'(6/69) ' T 10315' -316' (sgzd 6/69) 10428' -470' (6/69) PBTD - 8000' 10430' -440' (6/69) TD - 10,810' 10480' -490' (6/69) 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 157' CT fish in hole Cmt Plug Set to isolate Beluga, Cmt top 100' above top of perfs to 100' below WE 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0'- 35', 53.5#, P -110 35' - 4194', 43.5 #, N -80 4194' - 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5#, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) P 29#, N -80, BTC liner 10,280' - 10,759' t w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease: Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State /Prov: Alaska Country: USA Perforations: (MD) Beluga (TVD): Angle / Perfs: Angle @KOP and Depth: 25 deg KOP (TVD): Date Completed: 02/16/03 1 RKB: Prepared By: 1 Dennis Donovan Last Revision Date: 11/28/07 DMD r Marathon MARpreON Ail Company September 18, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Reference: Workover of KU 14 -32, Kenai Gas Field Dear Mr. Wondzell: • Alaska n Domes oduction P.O. Box 196168 Anchorage, AK 99519 -6168 Telephone 907/561 -5311 RECEIVED SEP 18 2000 Alaska (A & Gas Cons. Commission Anchorage Attached is an Application for Sundry Approval for a workover of well KU 14 -32 in the Kenai Gas Field. As part of this workover, Marathon is proposing that the well be equipped to flow up the 9W production casing. This is the same concept that was performed in well KU 43 -6a in April 2000, which increased deliverability in that well from 6.3 MMCFD to 14 MMCFD. A tubingless completion of KU 14 -32 will economically benefit the Sterling Pool 6 and the Kenai Gas Field in several ways. It postpones the installation of additional compression at the Kenai Gas Field. It lowers the forecasted abandonment pressure of Pool 6,, increasing proven gas reserves and field life. On a dollar per MCFD basis, a workover such as this reduces Marathon's cost of developing deliverability by an order of magnitude compared to conventional alternatives. Purpose The objective of this workover is to increase gas deliverability from the Sterling Pool 6 by removing tubulars and completion equipment that are restricting flow. Because the Sterling Pool 6 is depleted to roughly 400 psi bottom,hole pressure, the friction pressure drop in small tubulars is enormous. When well KU 14 -321 was converted to annular flow in the Sterling Pool 6 in February 1998, the reduction in friction increased gas deliverability from 5.5 to 11.0 MMCFD. Similarly, removal of the remaining restrictions could improve deliverability of KU 14 -32 to as much as 25 MMCFD. The attached diagram shows the expected deliverability from well KU 14 -32 if flow occurs up 9 11 /e" casing or 7" tubing. As the diagram shows, even 7" tubing presents a significant restriction to flow in well KU 14 -32. Use of 7" tubing reduces deliverability by 26% compared to flow up the 9%" casing. There is also a cost savings associated with not having to purchase and install 7" tubing, but cost savings is not Marathon's key reason for making this request. This workover A siihsirtary of USX Corporation Environmentally aware for the long run. 0 Workover of Well KU 14 -32 Kenai Gas Field Page 2 • RECEIVED SEP 18 2000 Alaska 00 & Gas Cons. COMMIssion is an attempt to increase well deliverability, and Marathon'mq� reason for wanting to flow up the 9 casing is to maximize deliverability. Well Workover & Production Operations The procedure for the Workover of well KU 14 -32 is very similar to well KU 43 -6a. Marathon recommends that a 3,000 psig BODE test is adequate for this well. A diagram of the BOPE configuration is included in the attached Sundry Application. A back- pressure valve profile will be included in the proposed wellhead to make for a safer rig demobilization. During production of the well, there will be no "kill string" in place, but the low bottomhole pressure (1.5 ppg EMW) and high compressibility of the wellbore fluids make it easy to kill by bullheading fresh water. Sand production has historically not been an issue with any of the Sterling Sands in the Kenai Gas Field unless a well also produced a significant volume of water. The Sterling Pool 6 is a volumetric gas reservoir that produces minimal water. Second, as the table below shows, the expected peak flow rate of 25 MMCFD will be well below the calculated erosive threshold. The existing twin 3" flowlines will be replaced with a single 8" flowline, thereby eliminating erosion concerns in the flowline. Concerns Addressed Pressure Containment - The static bottom -hole pressure of the Sterling Pool 6 is approximately 360 psig (1.5 ppg EMW). The proposed wellhead and tree are rated for 3,000 psi. The well will be equipped with surface safety devices that shut in the well automatically in the event of production upset. The wellhead will be equipped with a 6" back- pressure valve profile. Precedent - This workover in KU 14 -32 is the same concept that was approved and implemented in KU 43 -6a in April 2000. Bottom hole pressure, corrosion/erosion potential, and other concerns related to converting well KU 14 -32 to tubingless flow are very similar to those addressed in well KU 43 -6a. Corrosion Potential - Analysis of the produced gas from the Sterling Pool 6 in the Kenai Gas Field confirms that there is virtually no corrosion potential. This is consistent with field observation. The partial pressure of carbon dioxide is 0.4 psi which is substantially below the commonly recognized corrosion threshold. Furthermore, there is no hydrogen sulfide gas produced in the Kenai Gas Field. Erosion Potential - The Sterling Pool 6 does not have a history of sand production. Erosion potential is minimal whether the well is produced up 9%" casing or 7" tubing, and either is an improvement over the current annular flow status. a Workover of Well KU 14 -32 Kenai Gas Field Page 3 A y 1 N +sty C tl t< 3 Pipe hisidn Tllro lia ; Location Diametet incies Fressure; psza` 1b(iayM ` ; , , ;;�'Fl� 9%" Casing 8.681 120 none 106.5 9%" Casing 8.681 120 0.5 82.3 9%" Casing 8.681 120 1.0 58.2 8" Flowlne 6.875 120 none 66.8 7" Tubing 6.366 120 none 57.3 Please contact me if you need any further information. Your prompt reply to Marathon's request is greatly appreciated. Please contact me if you need any further information. Sincerely, J: filer Completions Engineer 0 i Maunder, Thomas E (DOA) From:. Donovan Jr, Dennis M. [ddonovan @marathonoil.com] Sent: Tuesday, December 11, 2007 3:22 PM To: Maunder, Thomas E (DOA) Cc: Skiba, Kevin J.; Donovan Jr, Dennis M. Subject: RE: KDU #4RD (169 -012) Attachments: KDU Ord (PTD 169 -012) Pool 6 Packerless Recompletion.pdf Tom, Attached is the separate document for KDU 4rd. Thanks, Dennis Dennis 912. Donovan ,7r. Production Engineer I 907 - 283 -1333 Office 907 -398 -1362 Cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, December 11, 2007 10:38 AM To: Donovan Jr, Dennis M. Cc: Skiba, Kevin 3.; Arthur C Saltmarsh Subject: RE: KDU #4RD (169 -012) Here it is again. Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Monday, December 10, 2007 3:44 PM To: Donovan Jr, Dennis M. Cc: ' Skiba, Kevin I'; 'Arthur C Saltmarsh' Subject: KDU #4RD (169 -012) Dennis and Kevin, We have received the 403 to abandon the Beluga perforations and complete in Pool 6. The procedure looks OK, however attaching the letter from 2000 for KU 1432 is confusing. While i understand the intent of your plan, it is appropriate to have a letter specifically for KDU #4RD. While the 14 -32 plan is generally applicable to KDU #4RD, there are some items definitely different, including 2 -7/8" tubing in KDU #4RD. A separate document for KDU #4RD should be prepared. Submitting via email is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC 12/1 1/2007 0 T ALASKA OIL AND GAS CONSERVATION COMMSSION' Kevin Skiba Production Technician Marathon Oil Company PO Box 1949 Kenai, AK 99611 -1949 �, W " AUG 1 7 2007 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Re: Kenai Gas Field, Beluga /Tyonek Gas Pool, Kenai Dee pJ�i 44 Sundry Number: 307 -266 `A' Dear Mr. Skiba: Enclosed is the Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Receipt of Marathon's response to the Commission's letter of July 26, 2007 is acknowledged. The issues identified in that letter have been satisfied, however the Commission still reserves the option to pursue enforcement actions. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal) l ommission decision to Superior Court unless rehearing has been requested DATED this1day of August, 2007 Encl. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Alaska Department of Law • 0 A Marathon Oil Comp Alaska Asset Team Northern Business Unit P.O. Box 1949 Kenai, AK 99611 -1949 August 13, 2007 John K. Norman Chairman AOGCC 333 West 7 Ave Suite 100 Anchorage, AK Telephone 9071283 -1311 Fax 9071283 -1350 'ir hU t- '�c>v� hC9 S : �4 k G ok Cc o,?007 aka -Oil & Gas Col .3. Commission 99501 03 6k� CPL Re: Kenai Gas Field, Beluga/Tyonek, Kenai Deep Unit 4 Sundry Number: 307 -221 Dear Mr. Norman: Anchorage Marathon Oil Company has received your letter dated July 26, 2007 which specifies reasons why the AOGCC denied our sundry request to replace a coiled tubing velocity string in the KDU #4 well. The following addresses the concerns in your letter: 1) Three Form 10 -404s have not been filed for past 10 -403 sundry approvals. At your request, the 10 -404 forms that were not filed previously for the approved 10 -403 Sundry Form Numbers 301 -007, 303 -013, and 303 -030 are attached for your review and records. Please note that we have changed the first sundry form number to the proper number 301 -007 instead of the 301 -107 number to which you refer. The appropriate daily summaries also have been included for this work. Please note that no daily work summary was included for the 301 -007 application as this work was never performed under this application. Further, the activities for which missing Form 10 -404's were discovered occurred over 4 years ago, and due to personnel turnover, we cannot explain this oversight. However, we have undertaken several new steps to ensure compliance point - forward, and will continue to review our records and correct any past deficiencies promptly upon discovery. 2) No sundry approval was obtained for work performed between April 15 and May 7, 2007 Marathon has investigated and acknowledges that it did not submit a sundry application (Form 10 -403) for the referenced activities that occurred between April 15 and May 7, 2007, but strongly disagrees that a violation of statute occurred because past guidance from the Commission staff to Marathon was that the installation and removal of a coiled tubing velocity string did not require sundry approval. This is a new interpretation of the statutes of which we were unaware until quite recently. Marathon has made and continues to make a strong effort to seek clarification and interpretation of the statutes from the AOGCC staff prior to performing activities that are not clearly defined in the statutes. The staff has been helpful but it is clear that a more consistent interpretation of some of the statutes should be discussed and documented to avoid any misunderstanding in the future. We are submitting a Form 10 -403 for the referenced activities (4/15/07 - 5/7/07); however we believe that there was no violation of statute because staff guidance changed subsequent to that date. In fact, Sundry Number 307 -221 was submitted under the Commission staff's new interpretation that the installation, removal, change or movement of a coiled tubing velocity string now requires sundry approval. We will comply with a sundry application on a point forward basis for this type of work. However, we request the Commission to recognize that we may discover additional past instances (prior to June, 2007) where no sundry application was filed for similar activities, and any such occurrences should not be treated as violations of statute because we relied upon the guidance of Commission staff. 0 0 3) Please confirm that the Commission was notified of the BOP test performed on April 16, 2007. Marathon notified Jim Regg on April 14, 2007 of our intention to test the coiled tubing BOP on April 15, 2007. Please find attached a copy of the AOGCC BOPE Test Report completed and filed for this test. You can see from the report that Mr. Regg (misspelled on the form as Ress) waived witness of the test. Please also be aware that the work related to the BOP test that was conducted on April 15, 2007 would be recorded as the next day's date of April 16, 2007 according to Marathon's daily reporting convention. 4) Please confirm that the Commission was notified of the use of the BOP to halt flow from the well when the coiled tubing parted on April 20, 2007. Marathon has thoroughly investigated the incident on April 20 and believes that it does not match the definition of activities which require AOGCC notification under statute. At no time during this event was it necessary to close the blind /shear coiled tubing rams to control the flow from the well. Instead, after the coiled tubing was pulled loose from the bottom of the coiled tubing connector and the coiled tubing fell down hole, the well flow was still prevented by the seal of the coiled tubing in the packoff sub above the attached lubricator. The coil string attached to the reel was still secured in the lubricator by the injector head, there was no flow from the well and the well was under complete pressure control. The BOPs were not used to halt flow from the well. The decision to close the blind /shear rams was simply the first step in securing the well in a prompt and safe manner, rather than an emergency response. It was understood at the time that the master valves on the tree could have also been shut in to accomplish the same effect. Marathon respectfully requests that the AOGCC accept the re- submitted Sundry Number 307 -2221, and expedite its approval. Please send approvals to Marathon Oil Company, c/o Kevin Skiba, PO Box 1949, Kenai, AK, 99611 -1949. If you would like any other information or have additional questions, please contact me at 907 - 565 -3042. Sincerely, Y ndon C. Ibele, PE `Production Coordinator Enclosures: 10 -403 Sundry (1) 10 -404 Sundries (4) Operational Summaries (2) Well Schematic BOP Test Report cc: Houston Well File Kenai Well File KDW o*WeH File « .:: - Trip Rpt File » E. 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Date 4/14/07 Time Witness Coil Tubing 8FL 11107/05 SCANNED APR 2 8 2008 BOP Test 3 29 07 REC EIVE 11/07105 STATE OF ALASKA AUG 14 2007 OIL AND GAS CONSERVATION COMMISSION SM Test Report Alaska Oil & Gas Cons. Corn Subaru: to: iiM rggg@Amin.state.ak.us Anchorage aogcc prudhoe bav(d>admin.state.ak.us bohfleckenstein(dadmin.state.ak. us Contrector: Now Contractor Rig No.: DATE: 4/15/07 Rig Rep.: Brady Ri chaqdson Rig Phone: 190739436! Rig Fax: Operator RM ?ausr Op. Phone: 190739436' Op. Fax: Rep.: Mift Mullin E-Mail Well 'Name: 4 RD PTO # Operation: Drg: Workover: yes Explor.: Test: Initial: yes Weekly: Bi- Weekly Test Pressure: Rams: Annular: Valves: 4500 VAISC : TEST :RATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Res Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P DrI. Rig NA Lower Kelly NA PTO On Location I Hazard Sec. P Ball Type NA Standing Order Posted P _ Inside BOP NA BOP STACK: Quantity SmefType Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 9/16 TOT P Trip Tank P NA Annular Preventer I Pit Level Indicators P NA #1 Rams blind putter 1.75 TOT P Flow Indicator NA NA S2 Rams Pipesli 1.75 P Meth Gas Detector NA NA #3 Rams I H2S Gas Detector NA NA #4 Runs I $5 R rns I Quantity Test Rest Choke Ln. Valves 2 P Inside Rest valves 1 P HCR Valves NA Kill Line Valve 1 2x2ptugvalve P ACCUMULATOR SYSTEM: Check Valve NA Time/Pressure Test Rest System Pressure 2800psi P CHOKE MANIFOLD: Pressure After Closure 2500psi P Quantity Test Result 200 psi Attained 3sec P No, VON" 2 P Full Pressure Attained 5 sec P Manual Chokes 2 P Blind Switch Covers: All stations Y Hydraulic Chokes NA Nitgn. Bottles (avg): 2 battles 119111W gf Failures: Test Time: Tom Rom" 1!I Mk6jM Hours 1 Components acted Repair or replacement of equipment will be made within (done) days. Notify the North Slope I 7 ,foNow with wriftn confirmaticm to Su at: Lim recaBadmin.state.ak.us Tested -low 200psi,high 4500psi, tot treating iron, inside reelvatve,BOP shears"l,pipe slip, body, tested retum side 200psi low-1200 psi high-Failure was a 1502 seal replaced on location and o*WeH File « .:: - Trip Rpt File » E. 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Date 4/14/07 Time Witness Coil Tubing 8FL 11107/05 SCANNED APR 2 8 2008 BOP Test 3 29 07 ors k`i� RECEIVED p4,,� STA F ALASKA � ALA OIL AND GAS CONSERVAThA"G PN A PLICATI N FOR SUNDRY P ®l� 20 AAC 24. a 0" as ons. OMMISSon 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutAown ❑ MC to ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate [] Time Extension t ❑3a r� 13(iing Change approved program[] Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development 9 Exploratory ❑ Stratigraphic El Service ❑ 169 -012 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611 50 -133- 20176 -00 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No D Kenai Deep Unit # 4 reNcki 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): 1 mtUV'rk ��Or %'3 235' FNL, 4209' FWL, Sec. 7 T4N, R11 W, S.M. 1 0.5', 95' KB above MS1 Kenai Gas Field, Pad 41 -7 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,810' 9736' 8000' 7181' 8000' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1264' 20" 1264' 1222' 1530 psi 5020 psi Intermediate 6026' 13 -3/8" 6026' 5400' 3090 psi 1540 psi Production 10310' 9 -5/8" 10310' 9280' 6330 psi 3810 psi Liner 497' 7" 10759' 9685' 8120 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6428' -7697' 5970' -5978' 3-1/2' L -80 5720' Packers and SSSV Type: Packers and SSSV MD (ft): Baker SAB permanent Packer 5573' 13. Attachments: Description Summary of Proposal 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 29- Jul -07 Oil ❑ Gas E Plugged [] Abandoned ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name A Dennis Donovan Title Production Engineer Signature Phone (907) 283 -1333 Date 12- Jun -07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G ^ r7 Plug Integrity El BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ iJ� l C'"` Other: L_V��d® Q s, k�> C�� T' 44Z BFLAUG 17 2007 Subsequent Form Required: V 4 kM APPROVED BY L Approved by: R THE COMMISS104 Date: Form 10 -403 Revised 06/2006 . 0 R I G I N A L Submit in Duplicate _Dtj�� M arathon MARATHON Oil Company kci,:'A3 Oil & Gas Cans. Commission Anchorage June 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10 -403 Sundry Notice Field: Kenai Gas Field, Pad 41 -7 Well: Kenai Deep Unit # 4 redrill Dear Mr. Maunder: �i 1.n 4, f I �� 11 -7) We propose to run a 1.75" velocity string in KDU #4rd. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10 -403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398 -1362. Sincerel , Dennis Donovan Production Engineer Enclosures: 10 -403 Sundry Notice cc: AOGCC Operations Procedure Houston Well File Well Schematic Kenai Well File Proposed Well Schematic DMD Operation Summary KJS 0 0 MARATHON �' •' f AL Kenai Gas Field, Pad 41 -7 Kenai Deep Unit # 4 Will 2007 CT Velocity String Hangoff Procedure Notes: This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. • Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real -time Flowing Temperature - Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1- 11/16" real -time Spartec pressure- temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil Tubing Head. 3. Make flowline modifications for coil tubing velocity string. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back equipment including open -top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed -top 500 bbl Rain - for -Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubing unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple up BJ CT wellhead assembly (WHA). Dual -Combi BOP (dressed for 1 -3/4 CT). Function test BOP. Stab 1 -3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 lbs. Nipple up injector to WHA. 7. Pressure test surface lines and CT equipment with 6% KCL water. Pressure test pump iron (200 low /4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in wellbore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. Page 2 of 2 0 0. Nipple up injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 1. RIH with coil tubing velocity string and BHA with well flowing to sales up Tubing -Coil Tubing annulus. 2. Cut coil tubing. PUH to span WHA for final landing depth. Set CT in BOP tubing /slip rams. Lock tubing /slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 3. MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 lbs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O -rings to 5000 psig with hand pump pressure test unit ( Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Running Tool Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purge KCL water from CT remaining on reel trailer with nitrogen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump -off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump -off plug release and fall down hole. 17. Purge N2 from CT remaining in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. • A API: 50- 133 -20176 AOGCC: 69 -12 RT -MSL (Original Drlg): 13.2' KB -THF RT -GL (1996 w /o): 20.5' FNL, 4209' FWL 7, T4N, R11 W, S.M. Lift threads: ? ?? Tree cap: 4 -3/4" Otis (on dual tree) a Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 212003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' Active Perfs- (Beluga Formation) M9/10 - 6428' -6458' (1/31/03) M14 - 6655'-6665'(2/6/96) L3 - 6800'-6808'(12/15/95), frac'd 12/26/95 L3 - 6825'-6844'(12/10/95), fradd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11111/95) 9937' -947' (6/69) 9952' -986' (6/69) 9994'-10002'(6/69) 10258'-279'(6/69) 10315' -316' (sgzd 6/69) 10428'-470'(6169) 10430'-440'(6/69) 10480'-490'(6/69) • 20 ", 94#, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" rrpp to /2 -(does not exist, fished during 1995 Workover) 1.75" OD, 0.125" WT coil tubing, 4. 157' of 1.75" OD, O 125" WT Coil Tubing Hw4q #mot wea#ie4" P-G-H ;der @ 38' r14 M44+ -Q -OOH ' - (}OOH FWinq rf4pp4a-ac e4;4 of tea# 1-' in Hole sae --e -to = 14w Coil velocity string detail 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 15T CT fish in hole 4-�- Split shats 4 6664!- -KIR a4d. K-8 (app a*, asGGL-wa&ased)OOH 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5#, P -110 35'- 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206'- 10310', 53.5 #, P -110 Retainer @ 000'(10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29#, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU Ord Lease Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State /Prov. Alaska Country: Perforations: (MD) Beluga (TVD) Angle /Perfs I Angle @KOP and Depth 25 deg KOP TVD Date Completed: 02/16/03 RKB: 02/2 2/071 By DMD Prepared By: Gary Eller Last Re vision Date: PBTD 8000' TD-10,810' 'P .d 41-7, Kenai Gas Field API: 50- 133 -20176 AOGCC: 69 -12 RT -MSL (Original Drlg): 13.2' KB -THF RT -GL (1996 w /o): 20.5' FNL, 4209' FWL 7, T4N, R11W, S.M. Lift threads: ? ?? Tree cap: 4 -3/4" Otis (on dual tree) - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813 X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' INA Includes 2.W OD X 1.50" ID CT grapple :onnsc tor, 2,50" 00 X 1.50" ID X 10' tong box : box strataht bar, 1,91" OD X 1.25" PXN 1.185" n"o) profile nipple, and 3.50" OD x :.50" OD (1.50 tD top box x ZV tD bottom) dreline re -entry guide. M9/10 - 6428'-6458'(1/31/03) M14 - 6655' -6665' (2/6/96) L3 - 6800'-6808'(12/15195), fradd 12/26/95 L3 - 6825' -6844' (12/10/95), fradd 12126/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) 9937'-947'(6/69) 9952' -986' (6/69) 9994'-10002'(6/69) 10258'-279'(6/69) 10315' -316' (sgzd 6/69) 10428' -470' (6/69) 10430'-440'(6/69) 10480' -490' (6/69) PBTD - 8000' TD - 10,810' 20 ", 94#, H -40, 8rd surface csg @ 126 Cmt with 900sks of class "G" 4- a0 (does not exist, fished during 1995 Workover) Coil Tubing Velocity String 1.75" OD, 0.125" WT coil tubing, - 't0 157' of 1 75" OD, 0,925" WT Coil Tubing r4aeg #of for +P---4�;H 044'r-,A -44' I t q gvacind OH Q = # 4WOOH Faw 14 hales. -at- ` i- V- /W j00H I'X4 -X Sp4t 54w at 6659' ±&446)00111 at, 6424' 0114 POOH e at end of ro4 .@u 4904° In Hole _ tD-= 1 r. Coil velocity string detail 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2107 wl 157' CT fish in hole 44it4agge4- @ -6668X& - ,S#44g,aPA-. 1-. S shats 4 "- aAd- &4;23L -K- {apprex 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5#, P -110 35'- 4194', 43.5#, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206'- 10310% 53.5 #, P -110 Retainer @ 8000'(10/19/95) Retainer @ 8955 (10/17/95) [ 7T" — ,,2 1 9#, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough I State /Prov. Alaska Country: rforations: (MD) Beluga (TVD) Angle /Perfs Angle @KOP and Depth 25 deg KOP TVD ate Completed: 02/16/03 RKB: 02/22/071 By DMD Prepared By: Gary Eller Last Revision Date: ,T l I age 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 14, 2007 2:57 PM To: Lyndon Ibele Cc: 'Stephen F Davies'; 'Arthur C Saltmarsh'; Fleckenstein, Robert J (DOA) Subject: Processing Un- approved Sundries A , ° e a Lyndon, You and I met this morning. At that meeting you delivered multiple documents in response to Commission letters regarding several non - compliance matters with wells Beaver Creek 13 (203 -138), KU 14 -32 (182-'0 15) and KDU 4 (169 -012). For the latter two wells, you resubmitted copies of the sundries that had been returned unapproved requesting that they be processed. In the future, when a sundry is returned unapproved and a new approval is desired please submit a new form 10 -403. This will eliminate the need to cross -out superseded /changed information and provide blank space for the new sundry number. The documents you submitted this morning will be accepted for processing per Commissioner Foerster. Please pass this on to the staff at Kenai. Call or message with any questions. Tom Maunder, PE AOGCC 8/14/2007 STATE OF ALASKA ALAOOIL AND GAS CONSERVATION COMNOON REPORT OF SUNDRY WELL OPERATIONS RFr 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 21 I ted Performed: Alter Casing ❑ Pull Tubing E] Perforate New Pool E] Waiver ❑ Time ExtenA4 U 4 (P ubing Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ Strin 2. Operator 4. Well Class Before Work: 5. PA4006 I on$. Comssion Name: Marathon Oil Company Development ❑✓ Exploratory❑ Stratigraphic ❑ Service ❑ Aaftt0 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -00 7. KB Elevation (ft): 20.5' (95' above MSL) 9. Well Name and Number: Kenai Deep Unit 4 8. Property Designation: 10. Field /Pool(s): FEDA 028142 Kenai Gas Field / Beluga & T onek Pools 11. Present Well Condition Summary: Total Depth measured 10,810' feet Plugs (measured) 8,000' true vertical 9,739' feet Junk (measured) 8,956' Effective Depth measured 10,711' feet CANNEID APR 2 9 2008 true vertical 9,643' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surface 1,264' 20" 1,264' 1,217' 1,530 psi 520 psi Intermediate 6,026' 13 -318" 6,026' 5,400' 3,090 psi 1,540 psi Production 10,310' 9 -5/8" 10,310' 9,280' 10,900 psi 7,930 psi 6,330 psi 3,810 psi 6,870 psi 4,750 psi 9.440 osi 5.310 Dsi Liner 497' 7" 10,759' 9,688' 8,160 psi❑ 7,0230 psi Perforation depth: Measured depth: 6,428'- 7,697' gross True Vertical depth: 5,769'- 6,902' gross Tubing: (size, grade, and measured depth) 3 -1 N -80 5,720' Packers and SSSV (type and measured depth) Baker 194-40 x 32 SAB p ack i 5,579' 12. Stimulation or cement squeeze summary: Intervals treated (measured): None �F - (US� ���� \kyx__ J , Treatment descriptions including volumes used and final pressure: A" 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 NA 900 Subsequent to operation: 0 1150 2.9 NA 778 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ❑ Development 0 Service ❑ Daily Report of Well Operations NA 16. Well Status after work: Oil ❑ Gas ❑✓ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303 - 0 30 _ Contact Kevin Skiba (907) 283 - 1371 8 0 PR 2 S 2008 Printed Name Ken D. Walsh Title Senior Production Engineer Signature L vv "�� �° v Phone (907) 283 -1311 Date g/q ��� 0 0 Marathon Oil Company Operations Summary Report Page 2 of 5 Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To I Hours I Code Code Phase Description of Operations I 2/13/2003 08:00 - 16:00 8.00 RURD_ COIL [ CMPRUN I MIRU 1 -3/4" coil tubing and nitrogen unit on KDU -4rd. SITP = 1616 psi. MI tank for source water, and RU flowback iron. SDFN 2114/2003 08:00 -12 :30 4.50 RURD_ COIL CMPRUN Finish MIRU coil tubing. MU 2" wash nozzle onto coil. Held prejob t safety meeting. Blended 300 bbl of 6% KCI. Test BOPE to 200/3000 psi. 12:30 - 15:45 3.25 TRIP_ BHA CMPRUN RIH with coil tubing. SITP = 1600 psi. Begin circulating KCI water at 1.0 bpm and nitrogen at 500 scfm. Reach 7750' MD. Returns are strong, and weigh 9.4 ppg. 15 :45 -17:00 1.25 JET_ CMPRUN PU washing from 7750' into tubing tail at 5700'. Having some difficulty with choke plugging, but able to get it clear. Returns weighing as heavy as 12.1 ppg. 17 :00 -18 :30 1.50 JET_ I CMPRUN RIH continuing to wash at 1.0 bpm and 500 scfm to a depth of 7160', then POOH washing to 6630'. Returns are strong, 10.1 ppg. 18:30 - 19 :00 0.50 JET CMPRUN Shut down liquid pump at 6630', increase nitrogen to 1000 scfm while continuing to POOH. Continue circulating at 1000 scfm until enter the tubing tail at 5700', then reduce nitrogen rate to 750 scfm then to 500 scfm. Total fluid pumped = 274 bbl, total recovered volume = 263 bbl. 19:00 - 20:20 1.33 JET J CMPRUN RIH jetting at 500 scfm to 6650'. Pump pressure steady at 830 psi, j indicating we're not lifting any fluids. Increase nitrogen rate to 1000 scfm and continue to RIH to 7383'. POOH jetting from 7383' at 1000 scfm. Pump pressure indicates we're now lifting fluid. Begin getting liquid returns again at 6300'. Continue to POOH jetting to 5700' (inside tubing tail). Run out of nitrogen once we're inside the tubing tail. Total ` fluids recovered = 281 bbl. 20:20 - 23 :00 2.67 TRIP_ BHA_ i CMPRUN POOH with coil, allowing well to continue to unload. Bringing up some ori..md• nnnnm 'N id-09 AM Printed: 8/7/2007 11:14:09 AM Marathon Oil Company Page 3 o 5 Operations Summary Report- Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date Frortt'- To Hours Code de Phase ; Description of Operations 2/14/2003 20:20 - 23:00 2.67 TRIP_ BHA CMPRUN small volume of water independently. Shut in, secure well, SDFN. 2/15/2003 08:00 - 11:30 3.50 RURD_ COIL CMPRUN NU coil tubing window. Move flowback iron to take returns off of wing valve below the swab valve. Note: Had 1.5 hrs of downtime getting the manlift working, which was needed to nipple up the coil window. 11:30 - 12:30 1.00 RURD_ COIL CMPRUN Attempt to install Weatherford pump -out plug onto the end of the 1 -3/4 ", 0.125" wall coil tubing. The portion of the pump -out plug that inserts into the coil is 1.520 ", which is too large to fit into the 1.500" ID coil tubing. 12:30 - 14:00 1.50 RURD_ COIL CMPRUN Turn down OD of the seal neck on the pump -out plug to 1.500 ". Also turn down O -ring grooves. Wait on plug to return from machine shop. 14:00 - 15:30 1.50 RURD_ COIL CMPRUN Install pump -out plug onto end of coil tubing. Straight end of coil to bypass chemical injection mandrel, but accidentally crimp pipe. Cut off pump -out plug, dress and straighten end of coil. Install pump -out plug (plug OD = 1.75 ", no -go = 1.265" ID) onto coil tubing using roll -on connector. 15:30 - 17:00 1.50 RURD_ COIL CMPRUN NU injector head. Conduct safety meeting. Pressure test lubricator and flowback iron to 200/3000 psi. 17:00 - 17:30 0.50 RURD COIL CMPRUN ND injector head. SDFN. 2/16/2003 07:00 - 08:00 1.00 RURD COIL CMPRUN Crew arrives, prepares coil unit for running velocity string. 08:00 - 09:30 1.50 SAFETY SMTG CMPRUN Held operations meeting to review in detail the procedure for running and hanging the velocity string with BJ coil crew, Weatherford packer hand, and crane operator. 09:30 - 12:00 2.50 RURD_ COIL CMPRUN NU coiltubing injector head and lubricator onto 4 ", 10M work window. Test to 200/3000 psi, then purge test liquid. Function test BOPE and window, and visually inspect end of coil. 12:00 - 14:00 2.00 TRIP_ BHA_ CMPRUN RIH with 1 -3/4" coil tubing and pump -out plug to 6742' CTM (zeroed at THF). SITP = 1550 psi, bled to zero while running coil. Hanging weight = 8200 lbs. Close pipe rams /slips and lock -in. Continue to produce well from flowline beneath pipe rams. 14:00 - 14:45 0.75 NULL COIL CMPRUN Push /pull on pipe 5000 lbs to verify slips are holding. Bleed off pressure above the pipe rams and open the work window. Caliper coil tubing to verify no severe ovality. Make a cut into the coil with a hacksaw to check for internal pressure. Coil is on a slight blow (ounces of pressure) which appears to be caused by thermal effects. Make rough cut on coil tubing, install safety clamp on pipe stub. ND injector head. 14:45 - 16:15 1.50 NULL COIL CMPRUN install motor head assembly onto coil in injector head and pull test to 24K lbs. Install coil connector, Weatherford PDH packer, and hydraulic disconnect onto the coil stub in the hole. MU motor head assembly to packer assembly, and NU injector head. Pull test coil connector to 21 K lbs. Remove safety clamp, close work window. Equalize across rams, and open pipe rams. 16:15 - 17:45 1.50 JET_ CMPRUN Circulate nitrogen down coil tubing at 1000 scfm to remove pump -out plug. While installing coil hanger, well was flowing independently and lifting liquids tro surface. Now lifting liquids at a strong rate using nitrogen. Recover 21 bbl of wellbore fluid before shutting down nitrogen and shutting in well. 17:45 - 18:45 1.00 TRIP_ TOOL CMPRUN RIH with PDH packer on coil tubing. Set down in adaptor spool at tree top. PU, try again and successfully pass through tree. RIH until PDH packer is 25' below the tubing hanger. PU 2' and slack off to set the PDH packer. PDH packer is set 23' below the THE at approximately 42' KB. The end of the 1 -3/4 ", 0.125" wall coil tubing velocity string is 6784' below the THE (approximately 6803' KB). Drop a 1/2" aluminum ball, Printed: 8/7/2007 11:14:09 AM 0 Marathon Oil Company Page 4 of 5 Operations Summary �po°t Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Sub Phase Description of Speratiora Code ` 2/16/2003 17:45 - 18:45 1.00 TRIP_ TOOL CMPRUN and pump 15 bbl of methanol water before ball set and released the hydraulic disconnect. PU above the master valve and close master valve. WHP (below master valve) = 1100 psi. 18:45 - 23:00 4.25 RURD COIL CMPRUN Purge methanol water in coil tubing reel to catch tank. Blow down nitrogen pressure in reel. ND injector head, window, and BOPE. RDMO coil tubing. 23:00 - 02:00 3.00 FLOW_ TEST CMPRUN No activity. Well shut -in. 02:00 - 02:30 0.50 FLOW TEST CMPFLW Open up KDU -4rd to gas buster. SITP = 1540 psi. Blew down to atmospheric pressure in 15 minutes without carrying out any liquid. Continued to monitor for another 15 minutes, no sign of flow. Shut -in well, SDFN. 2/19/2003 07:30 - 10:00 2.50 RURD_ SLIK CMPFLW MIRU slickline. Conduct safety meeting. Test lubricator. 10:00 - 13:45 3.75 RUNPUL EQIP CMPFLW RIH with 1.125" tapered swedge to 6826' WLM. Set down, could not work deeper. POOH. 13:45 - 17:00 3.25 RUNPUL SLIK CMPFLW Run static BHP survey with stops @ 0', 4400', 6000', 6500', 6700', and 6800'. POOH. Survey good. RDMO. 2/24/2003 08:00 - 10:45 2.75 RURD SLIK CMPFLW MIRU slickline. Conduct safety meeting. Test lubricator. 10:45 - 11:15 0.50 TAG_ BOTM CMPFLW PU 2.50" gauge ring, zero at ground level. RIH, tag top of coil tubing hanger at 19'. POOH. 11:15 - 12:15 1.00 TAG_ BOTM CMPFLW RIH with 1" tapered swedge. Tag at 6828' wlm (6848' KB). POOH. 12:15 - 13:15 1.00 TAG_ BOTM CMPFLW RIH with 1.279" tapered swedge. Tag coil no -go @ 6824' WLM (6844' KB). POOH. 13:15 - 14:15 1.00 TAG_ BOTM CMPFLW RIH with 1" drive down bailer with flapper bottom. Set down at 6824' wlm, fell through to 6830' wlm. POOH. Marks on bottom of bailer as if hitting metal. Dress off bailer bottom. 14:15 - 15:15 1.00 TAG_ BOTM CMPFLW RIH with same, set down at 6831' wlm, work for 20 minutes, no hole. POOH. Bailer loaded with water but no sloids. Same metal marks again. 15:15 - 16:30 1.25 TAG_ BOTM CMPFLW RIH with bailer with ball bottom. Set down at 6831' wlm. POOH, more metal marks. 16:30 - 17:30 1.00 TAG_ BOTM CMPFLW RIH with limber string and chisel bottom. Set down at 6833' wlm. Appears that the helix in the coil tubing is making it difficult for wireline tools to exit the coil without running into the 9 -5/8" casing. POOH. 17:30 - 18:30 1.00 RURD_ SLIK CMPFLW RDMO slickline. 3/18/2003 19:00 - 22:00 3.00 MIRU Schlumberger E -line. Pwh= 1000psi (previously supplied by jumper) 22:00 - 23:00 1.00 MU weight bar and PU lubricator 23:00 - 23:15 0.25 Pressure test lubricator to 250 /2000psi with methanol. Small drip found. Replace needle valve and re- pressure. Test good. 23:15 - 23:30 0.25 Held safety meeting. Enforce radio silence and arm chemical cutter. 23:30 - 00:50 1.33 Begin RIH. Tools not falling with WHP. Bleed WHP to 750psi via production. Tools falling. 00:50 - 01:10 0.33 On bottom with chemical cutter. Pull in place to 6655'. Wait 20 minutes to ensure chemical temp is at least >45degress as required. 01:10 - 01:15 0.08 Fire cutter. Tension dropped off and surface indications good. 01:15 - 01:30 0.25 Not able to PUH. PU to 13001bf (10001bf overpull). Able to RIH w/ tool. Suspect sand /debris on top of cutter. 01:30 - 02:15 0.75 Flow well to production in an attempt to lift sand /debris from top of tool. Pwh= 1100psi. Able to flow rate >1.5MM. Well carrying water with indications of sand /solids in choke. Work tools. Still able to RIH, but unable to PUH. Work until tools will not RIH. Max pulled at 14001bf. Elect to SI production and call town to recommend pulling out of rope socket (1750- 18001bf weak point). Stuck with cutter at -6721'(18.6' Printed: 8/712007 11:14:09 AM 0 0 Marathon Oil, Company Page 5 of 5 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- Hours Cade Code Phase Description of Operations 08:45 - 10:30 1.75 PT lubricator with WHP, WHP =1400 psig. RIH with 1" DD bailer to 38' 3/18/2003 01:30 - 02:15 0.75 KB. Work tool string past to 6788' KB. Work bailer POOH with Bailer 10:30 - 11:00 tool string length). TOF =6703' WLM 02:15 - 02:30 0.25 OOH with 1" bailer, check bottom of bailer, found fish neck marks on Decide to work tools at higher tension for a period of time before pulling bottom of tool. No sand or mud 11:00 - 11:50 0.83 out of rope socket. 02:30 - 03:10 0.67 Work tools up to 16201bf w/ no progress. Elect to pull off of tool. Wire string. Sheared off fish with RS. POOH with tool string 11:50 - 12:30 0.67 came free at 17301bf. POOH. 03:10 - 04:00 0.83 string for 1 hour. Pu 1150 Ibs on jars set off jars, weight down to 950 RDMO SWS. Pwh= 1600psi 4/5/2003 08:00 - 08:45 0.75 Ibs. Sheared off fish. POOH with tool string. Fish did not move 12:30 - 14:25 Pollard wireline on location. RU on well. WHP = 1400 psig 08:45 - 10:30 1.75 PT lubricator with WHP, WHP =1400 psig. RIH with 1" DD bailer to 38' KB. Work tool string past to 6788' KB. Work bailer POOH with Bailer 10:30 - 11:00 0.50 OOH with 1" bailer, check bottom of bailer, found fish neck marks on bottom of tool. No sand or mud 11:00 - 11:50 0.83 MU 1" tool string with 1 1/4" RS. RIH latch fish @ 6788" KB, work tool string. Sheared off fish with RS. POOH with tool string 11:50 - 12:30 0.67 MU 1" tool string with 1 1/4" SS. RIH latch fish@ 6788' KB, work tool string for 1 hour. Pu 1150 Ibs on jars set off jars, weight down to 950 Ibs. Sheared off fish. POOH with tool string. Fish did not move 12:30 - 14:25 1.92 RIH with 1" tool string with a 1 1/4" SS, added an addtitional 3' stem. RIH latch fish@ 6788' KB, work tool string for 1 hour. Pu 1400 Ibs on jars set off jars, weight down to 1050 lbs. Sheared off fish. POOH with tool string. Fish would not move 16:00 - 17:30 1.50 RD equipment, Put well back to production. Printed: 8/7/2007 11:14:09 AM 169 -012 50- 133 - 20176 -00 -00 :rty Des: FEDA 028142 20.5' AGL (1996 w /o) 66' 2/11/1969 ched: 5/19/1996 KDU 4RD Pad 41 -7 235' FNL, 4,209' FWL Sec. 7, T4N, R11W, S.M. • '' MARATNOM 20", 94 #, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" Tree cap: 4 -3/4" Otis (on dual tree) - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' M9/10 - 6428'-6458'(1/31/03) M14 - 6655' -6665' (2/6/96) L3 - 6800'-6808'(12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" 157' of 1 -3/4" coil tubing @ 6,680' CTM Fill tagged @ 7,720' CTM 9937'-947'(6/69) 9952' -986' (6169) 9994'-10002'(6/69) 10258' -279' (6/69) 10315' -316' (sgzd 6/69) 10428' -470' (6/69) 10430'-440'(6/69) 10480' -490' (6/69) Well Name & Number: KDU 4RD Lease: I Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations: Beluga Perf (MD): 6,428'- 7,697' gross Perf (TVD): 5,769' - 6,902' gross Angle @ KOP: 25 deg KOP (MD): 4,210' KOP(TVD): 3,760' Date Completed: 02/16/03 Original Drilling KB:J 13.2' THE RKB: 20.5' (1996) Prepared By Kevin Skiba I Last Revision Date: 8/8/2007 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" 3-5/8", Armco "seal -lock" prod. csg @ 10,310' -mt w/ 1415 sks of class "G" 0'- 35', 53.5 #, P -110 35'- 4194', 43.5 #, N -80 4194' - 5733', 47 #, N -80 5733'- 8206', 47 #, P -110 8206- 10310', 53.5 #, P -110 PBTD - 8000' TD - 10,810' STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMISION � � nG` ,� D REPORT OF SUNDRY WELL OPERATIONS RE 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ O Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter SA Caa P Cons. Commission 2. Operator Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill NAfthrall Name: Development P Stratigraphic ❑ Exploratory F Service ❑ 169 - 012 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -00 7. KB Elevation (ft): 20.5' (95' above MSL) 9. Well Name and Number: Kenai Deep Unit 4 8. Property Designation: 10. Field /Pool(s): FEDA 028142 Kenai Gas Field / Beluga & T onek Pools 11. Present Well Condition Summary: Total Depth measured 10,810' feet Plugs (measured) 8,000' true vertical 9,739' feet Junk (measured) 8,956' .�4NED APR 2 9 2008 Effective Depth measured 10,711' feet true vertical 9,643' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surface 1,264' 20" 1,264' 1,217' 1,530 psi 520 psi Intermediate 6,026' 13 -3/8" 6,026' 5,400' 3,090 psi 1,540 psi Production 10,310' 9 -5/8" 10,310' 9,280' 10,900 psi 7,930 psi 6,330 psi 3,810 psi 6,870 psi 4,750 psi 9.440 psi 5.310 osi Liner 497' 7" 10,759' 9,688' 8,160 psi[] 7,0230 psi Perforation depth: Measured depth: 6,428'- 7,697' gross True Vertical depth: 5,769' - 6,902' gross Tubing: (size, grade, and measured depth) 3 -1/2" N -80 5,720' Packers and SSSV (type and measured depth) Baker 194-40 x 32 SAB p ack , 5,579' 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment descriptions including volumes used and final pressure: JJ 1 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1100 0.25 NA 250 Subsequent to operation: 0 0 0 NA 900 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ❑ Development ❑✓ Service ❑ Daily Report of Well Operations NA 16. Well Status after work: Oil ❑ Gas Q WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303 - 013 Contact Kevin Skiba (907) 283 - 1371 2008 Printed Name fp Ken D. Walsh Title Senior Production Engineer Signature Vj Phone (907) 283 -1311 Date 8 �9 /0 Marathon Oil Company Page 1,of 1 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: MAINTENANCE /REPAIR Start: 1/15/2003 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Pate From To Hours Code ©de Phase C?escription of Operations 1/15/2003 07:00 -16:15 9.25 RURD_ SLIK WBPREP Depart Shop Sign in @ KGF, Hot Work Permit, Procedure and Stop Sheet Depart Office for location Spot equipment, safety meeting: Difficult R/U R/U P.T.Lub, test -good RIH w/ 2.15" GR to TD @ 7641' WL, POOH RIH w/ Tandem Quartz Gauges, making pre- determined stops as per Stop Sheet Download Data - good, R/D, move to 21 -7 Printed: 8/7/2007 11:11:30 AM 0 0 Marathon Oil Company Page 1 of,5 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Event Name: WORKOVER Contractor Name: Rig Name: Date From -To Hours Code Code Phase 1/27/2003 09:00 - 17:00 8.00 1 PRDTST 1/2812003 107:00 - 21:30 1 14.501 1 PRDTST Spud Date: 2/11/1969 Start: 1/27/2003 End: 4/15/2003 Rig Release: Group: Rig Number: Description of Operations Rig up coil tubing on well head, spot flow back tank, Rig up choke and iron to tank. MU tree connection to tree. Vac truck Mixed up 250 bbls of 6 % KCL H2O. Spot Methanol tank for PT the coil lines. CT ready for clean out tomorrw RU BJ CT, Start up equipment discuss procedure and safety concerns. PU BOP to MU to tree. PT iron to 5000 psig. WHP= 1307 psig, Test BOP's tested good. RIH with CT, CT pump N2 @ 350 SCFM, CT @ 2000' PIP increased. Fluid returns to surface when CT @ 2700' caught sample, sample gray mud, mud weight at 9.6 lbs. CT at 6020' PIP = 863 psig, increased N2 @ 750 psig, 34, 000 SCF pumped. Fluid returns to tank. CT at 6267' PIP = 1000 psig, N2 @ 750 psig, 40, 500 SCF pumped. Very weak returns to tank. CT at 6410' PIP = 1091 psig, WHP = 188 psig, N2 @ 750 psig, 49, 800 SCF pumped. weak returns to flow back tank. CT at 7390' PIP = 1753 psig, WHP = 235 psig N2 @ 1000 SCFM, 88, 169 total N2 pumped CT at 7484' PIP = 1753 psig, WHP = 280 psig N2 @ 1000 SCFM, 93, 580 total N2 pumped Buster misting to much out of stack, decided to close choke reconnect the chicksan to diffuser connection. ** while shut in at choke, Before WHP = 430 psig pressure built to WHP up to 700 psig, may have lost some fluid back to well bore while changing connection. CT @ 7490' Continue pumping N2 @ 1000 SCFM, PUHoIe to 6725' WHP= 260 psig, total N2 = 139, 298 SCF RDH with CT, work down to 7113', PIP= 1521 psig, WHP= 401 psig, N2 rate @ 1000 SCFM, total N2= 158, 440 SCFM, Total bbls back to tank = 30 BBLS. CT at 7481', PIP= 1646 psig, WHP= 258 psig, N2 total= 168, 000 SCF Work down to taking 50' bites pulling up hole to 7646' work down to 7750' CTM set for 20 minutes on bottom. Small amount of returns to tank. PUHoIe to 7290', PIP= 1671 psig, WHP= 365 psig, total N2= 241, 274 SCF. CT at 6914', PIP= 1670, WHP = 335 psig. Rlhole with CT to 7750' PIP= 1521 psig, WHP= 236 psig, total N2 pumped 288, 359 SCF. Pump N2 for 20 minutes WHP increased to 310 psig. PUhole with CT WHP= 261 psig, total N2 pumped 294, 623 SCF. CT @ 7070', WHP =298 psig, total N2 pumped 325, 028 SCF. PIP= 1477 Continue up hole to 6910' PIP 1426 psig, WHP = 287psig, total N2 pumped = 330, 498 SCF, Drop N2 rate to 750 SCFM, RIHole with CT, total water to open top tank = 57 bbls ; CT @ 7284' PIP = 1216 psig, WHP= 309 psig. Total N2= 337, 000 SCF. CT @ 7750', PIP= 1323 psig, WHP =258 psig. total N2 = 344, 330 SCF pumped. Set at present depth for 10 minutes. POHole with CT Pirate = 750 SCFM, N2 pumped = 349, 967 scf. 59 bbls in open top tank. WHP= 217 psig., PIP = 1290 psig. CT @ 7350', WHP= 210 psig, PIP= 1180, Not much change in return tank, Increase PIR = 1000 SCFM, CT @ 6990', total N2 pumped= 363,160 SCF. WhenCT in tubing decrease PIR to 500 SCFM, S/D N2 POOH with CT. OOHole with CT. WHP= 300 psig. Lay down grease head secure well for night. Printed: 8/7/2007 11:12:26 AM • • Marathon Oil Company Operations Summary Report Page 2of51 Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/1111969 Event Name: WORKOVER Start: 1/27/2003 End: 4/15/2003 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code Code Phase Description of Operations 1/28/2003 - 21:30 ( 14.50! j PRDTST RD BOP'S. Finish RD on equipment and move off of lease on 1 07:00 1 Wednesday 29th. f I Made total of 61 bbls of water to open top tank 1/30/2003 107:30 - 11:00 3.501 RUNPUL' SLIK i PRDTST j MIRU slickline. Conduct safety meeting. Test lubricator. 11:00 - 12:30 1.501 TAG_ BOTM 1 PRDTST RIH with 2.75" gauge ring. Very slow 7250'- 7690', excessive P/U 1 12:30 -17:45 5.251 RUNPUL] 1 SLIK weight. No tag, POOH. i PRDTST j RIH w with gauges for static BHP surveu as per stop sheet. 117:45 - 18:45 j 1.00' RUNPU EQIP 4 PRDTST RIH with AD2 stop to 850'. Couldn't set. POOH. 118:45 -19:45 ! 1.00 RUNPUL EQIP PRDTST I RIH with F collar stop. Set in tree. POOH. 119:45 - 20:30 ().751 RUNPUL EQIP PRDTST { RIH with Daniels KOT to 50'. Would not go any farther. POOH. 120:30 - 21:30 1 1/31/2003 08:00 - 11:30 1.001 RURDI 3.501 SLIK PRDTST RDMO slickline. CMPPRF Fill out work permit. Hold operational meeting. Spot equipment and ( begin RU 11:30 - 13:00 I 1.50 i 3 CMPPRF i Pressure test lubricator to 2500psi. Test good. MU CCL and 20' } 13:00 -16:00 ( 3.00 2 -1/2" Spiral Power Jet strip gun (5 spf, 45 deg phase). CMPPRF RIH w/ spiral Encounter fight spot at 5608'. Able to 1 16:00 -16 :30 0.50 gun. pass. 1,CMPPRF 1 Correlate on depth 16:30 - 17:00 1 0.50 j j CMPPRF j Have production flow well to apply drawdown prior to shooting. } 1 17:00 - 18:00 i 1.00; i I I Pwh= 1100psi. Shoot w/ positive indication (lost 50 lbs tension). j CMPPRF POOH. Gun at surface. Pwh= 1100psi. All shots fired. PU 10' gun #2. 18 - 20:20 20:20 - 20:30 , 2.33 1 1 0.171 CMPPRF RIH j CMPPRF j Correlate on depth Pwh= 1300psi. Have production flow to obtain 1 I underballance. Fire guns with Pwh= 1050psi. Lost 100lbs tension. I 1 Shut well in. 20:30 - 21:30 ; 1.001 1 ! CMPPRF POOH. Pwh =1150 psi. Encountered tight spot at 5560'. Able to work i 22:30 I 1 r past. 'CMPPRF 121:30 - j At surface. All shots fired. Pwh= 1200psi. RDMO Schlumberger Printed: 8!712007 11:12 :26 AM Permit #: 169 -012 API #: 50- 133 - 20176 -00 -00 Property Des: FEDA 028142 KB: 20.5' AGL (1996 w /o) GL: 66' 2111/1969 ched: 5/19/1996 Tree cap: 4 -3/4" Otis (on dual tree) Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' fipple @ 5622' ID = 2.813" fipple @ 5687' ID = 2.813" reline Re -entry Guide @ 5720' Active Perfs (Beluga Formation) M9/10 - 6428' -6458' (1/31/03) M14 - 6655'-6665'(2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264'-7293'(11/19/95) L10 - 7340'-7350'(11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683'-7697'(11/11/95) Isolated Perfs 9937' -947' (6/69) 9952' -986' (6/69) 9994'- 10002' (6/69) 10258' -279' (6/69) 10315' -316' (sgzd 6/69) 10428' -470' (6/69) 10430' -440' (6/69) 10480' -490' (6169) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" 157' of 1 -3/4" coil tubing @ 6,680' CTM Fill tagged @ 7,720' CTM Well Name & Number: KDU 4RD Lease: I Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations: Beluga Perf (MD): 6,428'- 7,697' gross Perf (TVD): 5,769' - 6,902' gross Angle @ KOP: 25 deg KOP (MD): 4,210' KOP(TVD): 3,760' Date Completed: 02/16/03 Original Drilling KB: 1 13.2' THE RKB: 20.5' (1996) Prepared By: 1 Kevin Skiba I Last Revision Date: 8/8/2007 KDU 4RD � Pad 41 -7 235' FNL, 4,209' FWL Sec. 7, T4N, R11 W, S.M. 'M` MARATHON 20", 94 #, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" csg @ 10,310' 3 -5/8 ", Armco "seal -lock" prod pmt w/ 1415 sks of class "G" 0'- 35', 53.5 #, P- 35' - 4194', 43.5 #, N- 4194' - 5733', 47 #, N- 5733' - 8206', 47 #, P- 8206' - 10310', 53.5 #, P- PBTD - 8000' TD - 10,810' STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COMISION REPORT OF SUNDRY WELL OPERATIONS RECEIVED 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Oft 4 zAt Work Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension performed Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter S I nn2. C C 2. Operator 4. Well Class Before Work: 5. Permit to Drill Name: Marathon Oil Company Development Q Exploratory❑ Stratigraphic ❑ Service❑ 10 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611 -1949 50- 133 - 20176 -00 -00 7. KB Elevation (ft): 9. Well Name and Number: 20.5' (95' above MSL) Kenai Deep Unit 4 8. Property Designation: 10. Field /Pool(s): FEDA 028142 Kenai Gas Field / Beluga & T onek Pools 11. Present Well Condition Summary: Total Depth measured 10,810' feet Plugs (measured) 8,000' true vertical 9,739' feet Junk (measured) 8,956' Effective Depth measured 10,711' feet true vertical 9,643' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surface 1,264' 20" 1,264' 1,217' 1,530 psi 520 psi Intermediate 6,026' 13 -3/8" 6,026' 5,400' 3,090 psi 1,540 psi Production 10,310' 9 -5/8" 10,310' 9,280' 10,900 psi 7,930 psi 6,330 psi 3,810 psi 6,870 psi 4,750 psi 9.440 osi 5.310 psi Liner 497' 7" 10,759' 9,688' psi[] psi 7,0230 psi Perforation depth: Measured depth: 6,655'- 7,697' gross iCANNED APR 2 9 2008 True Vertical depth: 5,970' - 6,902' gross Tubing: (size, grade, and measured depth) 3 -1/2" N -80 5,720' Packers and SSSV (type and measured depth) Baker 194-40 x 32 SAB p acks 5,579' 12. Stimulation or cement squeeze summary: \-2:> Intervals treated (measured): None S Treatment descriptions including volumes used and final pressure: 'IT" 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 NA NA NA NA Subsequent to operation: 0 NA NA NA NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ❑ Development Service ❑ Daily Report of Well Operations NA 16. Well Status after work: Oil ❑ Gas Q WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. ]hereby certify that the foregoing is true and correct to the best of m knowledge. Sundry Number or N/A if C.O. Exempt: __. p i DDB 3011 -007 Contact K evin S ki ba (90 7) 2 -1371 (This was the sundry number assigned for 1/17/2001) Printed Name Ken D. Walsh Title Senior Production Engineer p Signature Phone (907) 283 -1311 Date i& o —1 Permit #: 169 -012 API #: 50- 133 - 20176 -00 -00 Property Des: FEDA 028142 KB: 20.5' AGL (1996 w /o) GL: 66' Lat: L ong: Spud: 2/11/1969 TD Reached: 5/19/1996 Tree cap: 4 -314" Otis (on dual tree) Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' Active Perfs (Beluga Formation) M9/10 - 6428' -6458' (1/31/03) M14 - 6655' -6665' (2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668'-7678'(11/11/95) L13 - 7683' -7697' (11/11195) Isolated Perfs 9937' -947' (6/69) 9952'-986'(6/69) 9994'-10002'(6/69) 10258' -279' (6/69) 10315' -316' (sgzd 6/69) 10428'-470'(6/69) 10430' -440' (6/69) 10480' -490' (6169) KDU 4RD * Pad 41 -7 235' FNL, 4,209' FWL Sec. 7, T4N, R11 W, S.M. 'M` MAw►rxoM 20"� 94#, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0 '- 35', 53.5 #, P -110 35'- 4194', 43.5 #, N -80 4194' - 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206'- 10310', 53.5 #, P -110 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" f T c C C rr� 157' of 1 -3/4" coil tubing @ 6,680' CTM �f c Fill tagged @ 7,720' CTM (5/1/07) Retainer @ 8000' (10/19/95) i.�._ Retainer @ 8955 (10/17/95) PBTD - 8000' TD - 10,810' Well Name & Number: KDU 4RD Lease: I Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations: Beluga Perf (MD): 6,428'- 7,697' gross Perf (TVD): 5,769'- 6,902' gross Angle @ KOP: 25 deg KOP (MD): 4,210' KOP(TVD): 3,760' Date Completed: 02116/03 Original Drilling KB: 13.2' THE RKB: 20.5' (1996) Prepared By: 1 Kevin Skiba Last Revision Date: 8/8/2007 ME 0 ALASKA SARAH PAUN, GOVERNOR oau[a►7NA 011L AND GAS 333 W. 7th AVENUE, SUITE 100 CONSE RVATION CODs U SSIO NT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED Dennis Donovan Production Engineer Marathon Oil Company , PO Box 1949 JUL '� 2007 t Kenai, AK 99611 -1949 Re: Kenai Gas Field, Beluga /Tyonek Gas Pool, Kenai Deep_,U1AA*#4 r Sundry Number: 307 -221 9. Dear Mr. Donovan: Enclosed is the Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry approval unapproved. No work will be approved for this well until the deficiencies noted below are corrected. A review of the file for the subject well has revealed that Marathon Oil Company has not filed Forms 10 -404 (Report of Sundry Well Operations) as required by Sundry Approval 301 -107 dated January 17, 2001, Sundry Approval 303 -013 dated January 24, 2003 and Sundry Approval 303 -030 dated February 7, 2003. You have also included an operations summary regarding work performed between April 15 and May 7, 2007. No sundry approval was obtained for this work as required by 20 AAC 25.280 (3). The deficient operations reports must be submitted not later than 15 days after the receipt of this letter. With regard to the possible violation of 20 AAC 25.280 (3), Marathon Oil Company should investigate this matter and submit a report of that investigation not later than 30 days after the receipt of this letter. Marathon Oil Company should also provide further information regarding the equipment test performed on April 16, 2007 and confirm that the Commission was notified as required by 20 AAC 25.286 (e)(8) of the use of the BOP to halt flow from the well when the coil parted on April 20, 2007. The Commission reserves the right to pursue enforcement actions regarding these matters. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day 0 Page 2 July 26, 2007 Sundry: 307 -221 KDU #4 following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. / DATED this 2� day of July 2007 Encl. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Department of Law UNITED STATES POSTAL SERVICE First -Class Mail Postage & Fees Paid LISPS, Permit No. G -10 K • Sender: Please print your name, address, and ZIP +4 in tffs box • ar a State of Alaska `n Postage Alaska OR and on Conservation Commission y, x.75 333 West 7th Ave., Suite 100 o , .+ rq E3 Certified Fee Anchorage, Alaska 99501 D y %” -' TI Return Receipt Fee �?ltil (Endorsement Required) V7 ' N o' > ❑ j;; , ,, 0 M Ln Ir , , i, i,,, i, 1, II,,,►„ Iltr li „l,i,i,,,l,tl „ i , ll m K N `n Postage $ x.75 0535 rq E3 Certified Fee f2 . %” "~ 19 O Return Receipt Fee �?ltil (Endorsement Required) > ❑ Restricted Delivery Fee co —0 (Endorsement Required) $0 Total Postage & Fees $ $ % Qs!F7 Ln U fit TO ' - C3 r� .� Apr No.; --------- ----- --- °----- - ---------- ----- or PO Box No. - -- ------•------ Clty. State Kw. ----------------------------------------•----------- PS Form :,r 200 ■ Complete items 1, 2, and 3. Also complete Item 4 if Restricted Delivery is desired. • Print your name and address on the reverse so that we can return the card to you. • Attach this card to the back of the mailpiece, or on the front If space permits. 1. Atka Addressed to: 2. Article Number (Transfer from service labeo A. SlprjOure X �(❑ Agent. V ❑Addressee ceived by (Printed Name) C. Da § of D livery D. Is delivery address( from hem i ❑ s If YES, enter delivery address below: ❑ No 3. Service Type ❑ Certified Mail ❑ Express Mail ❑ Registered ❑ Return Receipt for Merchandise Q Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 7005 1160 0001 5753 9530 PS Form 3811, February 2004 Domestic Return Receipt 102595- 02- M-1 M Marathon MARATHON Oil toVmpany June 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7" Ave Anchorage, Alaska 99501 Reference: 10 -403 Sundry Notice Field: Kenai Gas Field, Pad 41 -7 Well: Kenai Deep Unit # 4 redrill Dear Mr. Maunder: We propose to run a 1.75' velocity string in KDU #4rd. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10 -403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398 -1362. Sincere) , Dennis Donovan Production Engineer Enclosures: 10 -403 Sundry Notice cc: AOGCC Operations Procedure Houston Well File Well Schematic Kenai Well File Proposed Well Schematic DMD Operation Summary KJS • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283 -1326 Fax 907/283 -1350 RECEIVED JUN 2 7 2007 Alaska Oil & Gas Gans, Commission Ca{ chafage STATE OF ALASKA 6 Alk OIL AND GAS CONSERVATION COM &ION EGLIVEu JUN 2 7 2007 APPLICATION FOR SUNDRY APPROVALS Alaska Gil & Gas Cons. Commission 20 AAC 25.280 A--L- 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver Other Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ 9 Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ ;; Re -enter Suspended Well El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Nu er: Marathon Oil Company Development Stratigraphic ❑ Exploratory ❑ Service ❑ 9 -012 - 3. Address: 6. API Numbe/133-20176-00-9 PO Box 1949, Kenai Alaska, 99611 5 i 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Kenai De Unit # 4 re NkCill % 9. Property Designation: 6, ��� 10. KB Elevation (ft): 1 0.5', t 11. Field / Pool(s): U Sc. M'(OhQ _(0C'% �OO 235' FNL, 4209' FWL, Sec. 7 T4N, R11 W, S.M. 95 ' KB above MS a' as Field, Pad 41 -7 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): gs (measured): Junk (measured): 10,810' 9736' 8000' 7181' 8000' N/A Casing Length Size MD Burst Collapse Structural Conductor Surface 1264' 20" 1264' 1222' 1530 psi 5020 psi Intermediate 6026' 13 -3/8" 6026' 5400' 3090 psi 1540 psi Production 10310' 9 -5/8" 10310' 9280' 6330 psi 3810 psi Liner 497' 7" 10759' 9685' 8120 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tu ng Grade: Tubing MD (ft): 6428' -7697' 5970' -5978' 3- L -80 5720' Packers and SSSV Type: ckers an SV MD (ft): Baker SAB permanent Packer 55 ' 13. Attachments: Description Summary of Proposal [] 11 s a r q sed work: V Detailed Operations Program BOP Sketch ❑ r Development Service ❑ 15. Estimated Date for . ell t Q r posed work: 29- Jul -07 Commencing Operations: I 3 \' AG ❑ Gas ❑ Plugged ❑ Abandoned ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to a best of my kft0edge. Contact Kevin Skiba (907) 283 -1371 Printed Name A Dennis Donovan Title Production Engineer Signature Phone (907) 283 -1333 Date 12- Jun -07 COMMISSION USE ONLY Conditions of approval: Notify Commissi so that a representative may witness Sundry Number: Plug Integrity ❑ BO Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: FWM CWl JUL 3 0 2DD7 Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10 -403 Revised 06/2006 ORIGINAL S ubmit in Duplicate 0 0 M MaeareaN MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field, Pad 41 -7 Kenai Deep Unit # 4 redrill 2007 CT Velocity String Hangoff Procedure Notes: This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. • Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. 1. Obtain Real -time Flowing Temperature- Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1- 11/16" real -time Spartec pressure- temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil Tubing Head. 3. Make flowline modifications for coil tubing velocity string. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back equipment including open -top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed -top 500 bbl Rain- for -Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubing unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple up BJ CT wellhead assembly (WHA). Dual -Combi BOP (dressed for 1 -3/4" CT). Function test BOP. Stab 1 -3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 lbs. Nipple up injector to WHA. 7. Pressure test surface lines and CT equipment with 6% KCL water. Pressure test pump iron (200 low /4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. Cleanout fill in wellbore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off WHA. MU velocity string BHA to end of CT. Page 2 of 2 10. Nipple up iniector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubing velocity string and BHA with well flowing to sales up Tubing -Coil Tubing annulus. 12. Cut coil tubing. PUH to span WHA for final landing depth. Set CT in BOP tubing /slip rams. Lock tubing /slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 lbs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O -rings to 5000 psig with hand pump pressure test unit ( Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Running Tool Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purge KCL water from CT remaining on reel trailer with nitrogen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump -off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump -off plug release and fall down hole. 17. Purge N2 from CT remaining in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. o M 0 API: 50- 133 -20176 AOGCC: 69 -12 RT -MSL (Original Drig): 13.2' KB -THF RT -GL (1996 w /o): 20.5' 235' FNL, 4209' FWL Sec. 7, T4N, R11 W, S.M. Lift threads: ? ?? Tree cap: 4 -3/4" Otis (on dual tree) KDU 4rd Pad 41 -7, Kenai Gas Field - 3 -1/2 ", 9.2 #, N -80, IBT ico sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAS Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' M9/10 - 6428' -6458' (1/31/03) M14 - 6655'-6665'(2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683'-7697'(11/11/95) Isolated Perfs 9937' -947' (6/69) 9952'-986'(6/69) 9994'- 10002' (6/69) 10258'-279'(6/69) 10315' -316' (sgzd 6/69) 10428'-470'(6/69) 10430' -440' (6/69) 10480' -490' (6/69) • 20 ", 94#, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" dropped 194 (does not exist, fished during 1995 Workover) Coil Tubing Velocity String 1.75" OD, 0.125" WT coil tubing, 38' 680 VIVID 157' of 1.75" OD, 0.125" WT Coil Tubing � .... _ OH 1*X12" Split Shot at OOH VX12" Split Shot at OOH Landing nipple at end of Goo! @ 6801' In Hole no go 1 1) = 1.265" Coil velocity string detail 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 157' CT fish in hole x• 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5 #, P -110 35'- 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5 #, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) F Cm 29#, N -80, BTC liner 10,280' - 10,759' t w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease I Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State /Prov. Alaska Country: Perforations: (MD) Beluga (TVD) Angle / Perfs F Angle @KOP and Depth 25 deg K TVD Date Completed: 02/16/03 RKB: 12/22/071 By DMD Prepared By: Gary Eller Last Revision Date: IT L PBTD - 8000' TD - 10,810' tROPOSED KDU 4rV Pad 41 -7 Kenai Gas Field 50- 133 -20176 CC: 69 -12 RT -MSL (Original Drlg): 13.2' KB -THF RT -GL (1996 w /o): 20.5' 235' FNL, 4209' FWL Sec. 7, T4N, R11W, S.M. Lift threads: ? ?? Tree cap: 4 -3/4" Otis (on dual tree) - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 2/2003 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' 1 -3/4" OD Coiled Tubing Velocity String with tail at 7700' MD BHA includes: 2.50" OD X 1.50" ID CT grapple connector, 2.50" OD X 1.50" ID X 10' long box x box straight bar, 1.91" OD X 1.25" PXN (1.135" no -go) profile nipple, and 3.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re -entry guide. M9/10 - 6428' -6458' (1/31/03) M14 - 6655' -6665' (2/6/96) L3 - 6800'-6808'(12/15/95), frac'd 12/26/95 L3 - 6825'-6844'(12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) Isolated Perfs 9937' -947' (6/69) 9952'-986'(6/69) 9994'-10002'(6/69) 10258' -279' (6/69) 10315' -316' (sqzd 6/69) 10428' -470' (6/69) 10430' -440' (6/69) 10480'490' (6/69) PBTD - 8000' TD - 10,810' Coil velocity string detail 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 157' CT fish in hole 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5#, P -110 35'- 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5 #, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: 20 ", 94#, H -40, 8rd surface csg Lease Cmt with 900sks of class "G" County or Parish: Kenai Peninsula Borough I State /Prov. Alaska X23/96 (does not exist, fished rforations: (MD) during 1995 Workover) (TVD) Coil Tubing Velocity String 1.75" OD, 0.125" WT coil tubing, 38' 6804' MO ••wwaawrrrwwa« . w w FISH "a « wrwaawwwwwawaaawaw 157' of 1.75" OD, 0.125" WT Coil Tubing belew9rewnd levey -OOH M Q - 11 Few 1 4" ho at 6655' (3M OOH 1"X12" Sp Shot at 6655'(W4�0 OOH 1"X12" Sp Shot at 6423'(814/0 OH 6and R at end of Go @ 6891' In Hole Coil velocity string detail 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Coil no -go tagged at 6824' wlm, 2/24/2003 Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 Coil wash /jet biozan sweeps to 7750', 5/2/07 w/ 157' CT fish in hole 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5#, P -110 35'- 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5 #, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough I State /Prov. Alaska Country: rforations: (MD) Beluga (TVD) Angle /Perfs Angle @KOP and Depth 25 deg KOP TVD ate Completed: 02/16/03 RKB: 02/22/07F 2/22/07 By DMD Prepared By: Gary Eller Last Revision Date: — L • • Marathon Oil Company Page 1 of s Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 4/15/2007 07:00 - 08:00 1.00 SAFETY MTG CMPPUL Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 17:00 9.00 RURD_ COIL CMPPUL Spot and RU CT unit. Set pipe spools for old v- string, work string, and new v- string. 17:00 - 18:00 1.00 RURD_ COIL CMPPUL Secure location and leave. 4/16/2007 07:00 - 08:00 1.00 SAFETY MTG_ CMPPUL Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 09:00 1.00 RURD_ COIL CMPPUL 09:00 - 10:05 1.08 TEST_ BOPE CMPPUL PT pumps, lines, choke manifold. Complete full BOP test. 10:05 - 12:45 2.67 RURD_ COIL CMPPUL PU 2- 9/16" GS spear and stab injector onto well. test to 1000 psi. 12:45 - 13:10 0.42 RUNPUL COIL CMPPUL Latched packer and pulled into lubricator. Initial pull to move was 32,000 #. Final pull in lubricatorwas 26,000 #. 13:10 - 14:00 0.83 CIRC CFLD CMPPUL Attempt to circulate well dead. CT pressured up after 12 BBIs. 14:00 - 15:30 1.50 CIRC_ CFLD CMPPUL Bullhead 6% KCI down CT / Prod tubing annulus. Well dead after 40 Bbls. Well came back. Bleed gas and water. Bullhead 30 Bbls. Wait on gas to work up to surface. 15:30 - 17:30 2.00 RURD_ COIL CMPPUL Cut off packer from CT. Dress pipe ends. Install roll on conector on injector head end of CT. 17:30 - 18:00 0.50 RURD_ COIL CMPPUL Install connector on weoll end of CT aned stab 4' lubricator with cap for night. 4/2012007 07:00 - 08:00 1.00 SAFETY MTG CMPPUL Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 09:00 1.00 RURD_ COIL CMPPUL Uptained work permit and discussed environmental issues prior to start up. 09:00 - 11:00 2.00 WORK COIL CMPPUL MU coil connector to velocity string. Pull test coil connector to 20,000 Ibs 3 minutes, good test. MU working coil to velocity string with roll on connector. 11:00 - 11:30 0.50 WORK COIL CMPPUL Shell test to 1300 psig. Open slips. Pressure on well @ 1200 psig. 11:30 - 12:00 0.50 CIRC_ CFLD CMPPUL Pulled 36000 Ibs on coil, coil parted. Shut Rams, then shear blinds. Well secured. 12:00 - 12:30 0.50 SAFETY MTG_ CMPPUL Held safety meeting, prior to continuing with velocity string removal. 12:30 - 12:45 0.25 WORK COIL CMPPUL Bled down BOP's above blinds. Shut both masters after determining coil below the tree valves. 12:45 - 13:00 0.25 WORK COIL CMPPUL Pull injector off of well head. Go to ground with injector. Coil connector . between injector chain and lubricator. 13:00 - 13:20 0.33 RURD_ COIL CMPPUL Cut off coil connector with hack saw. Finish securing well. 13:20 - 13:50 0.50 RURD_ COIL CMPPUL Well secured. Held safety meeting to discussed plan forward. BJ crew left lease. 13:50 - 16:50 3.00 RURD_ SLIK CMPPUL Moblized PWS. Uptained work permit, held PJSM and discussed procedure. 16:50 - 17:20 0.50 RURD SLIK CMPPUL Spotted up equipment, PU 1.75" tool string with 2.7" LIB. 17:20 - 18:10 0.83 TEST_ WLHD CMPPUL PT lubricator to 1500 psig. Good test. 18:10 - 18:40 0.50 WORK SLIK CMPPUL Open well, RIH tag top of coil. Coil tagged at 96' KBD. Work twice, POOH with LIB. 18:40 - 18:50 0.17 WORK SLIK CMPPUL OOH, LIB good impression of coil. Coil laying against side of 3.5" tubing. 18:50 - 18:55 0.08 CMPPUL MU 2.70" overshot w/ 1.75" grapple X 3.5" GS skirted over shot baited with 3.5" GR. Add 10' stem and 10' lubricator to tool string. 18:55 - 19:00 0.08 TEST_ WLHD CMPPUL PU tool string, PT lubricator to 1500 psig. Good test. 19:00 - 19:15 0.25 WORK SLIK CMPPUL Open well. RIH with over shot, to top of fish at 96' KBD. Work tool string could not get overtop of coil. POOH with tool string. 19:15 - 19:20 0.08 WORK SLIK CMPPUL OOH with overshot. Face of 2.7" overshot had several dents on face. 19:20 - 19:30 0.17 WORK SLIK CMPPUL Grind off inside of overshot shirt to increase bevel. MU to tool string. 19:30 - 19:40 0.17 TEST_ WLHD CMPPUL PU tool string, PT lubricator to 1500 psig. Good test. 19:40 - 19:50 0.17 WORK SLIK CMPPUL Open well. RIH with over shot, to top of fish at 96' KBD. Work tool string could not get over top of coil. POOH with tool string. 19:50 - 20:00 0.17 RURD SLIK CMPPUL OOH with overshot. Face of 2.7" overshot had several dents on face from Printed: 6/12/2007 10:32:46 AM L • • Marathon Oil Company Page 2 of 8 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Cad Phase Description of Operations 4/20/2007 19:50 - 20:00 0.17 RURD_ SLIK CMPPUL hand jaring with spangs. RD Pollard. 20:00 - 20:30 0.50 RURD_ SLIK CMPPUL Pollard rig down and left lease. 4/22/2007 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 09:00 1.00 RURD_ COIL CTBG Uptained work permit and discussed environmental issues prior to start up. 09:00 - 09:30 0.50 WORK COIL CTBG MU dimple on coil connector to working string. Pull test coil connector to 42,000 Ibs 3 minutes, good test. Decide to test BOP's while waiting on motor from Anc 09:30 - 11:00 1.50 WORK COIL CTBG BOP test, rams low side 200 psig, high side 4200 psig. 11:00 - 11:30 0.50 RURD_ COIL CTBG PU additonal 20' lubricator above BOP's. 11:30 - 12:00 0.50 WORK COIL CTBG MU 2.70 overshot w/ 1.75 grapple, motorhead, 2 -1/8" motor, and 2 -1/4" pull disconnect. 12:00 - 12:15 0.25 WORK COIL CTBG PU lubricator. PT to 1000 psi. Tested good. 12:15 - 12:25 0.17 WORK COIL CTBG Open master valve. WHP = 1075 psi. Start in hole. 12:25 - 12:37 0.20 WORK COIL CTBG Tag fish at 79.7'. PU to 70'. Start motor at minimum rate 1/4 BPM. Start back in hole. 12:37 - 12:39 0.03 WORK FISH CTBG Tag fish at 80.2'. Stop motor. 12:39 - 12:45 0.10 WORK FISH CTBG PU coil tubing. No weight increase. Try again. 12:45 - 12:48 0.05 WORK FISH CTBG Start motor at 1/4 BPM. Start down hole. Tag fish at 81.9'. 12:48 - 12:51 0.05 WORK FISH CTBG Set weight on fish. 12:51 - 12:53 0.03 WORK FISH CTBG PU to 75.7'. Slip off fish. No weight increase. 12:53 - 12:56 0.05 WORK FISH CTBG Run back in hole. Tag fish at 82.1'. 12:56 - 13:00 0.07 WORK FISH CTBG Pull up on fish. 12,000 Ibs, slipped off, POOH 13:00 - 13:05 0.08 WORK FISH CTBG OOH to check tools. Left 2.0" GS on top of coil. MU 2.0" G spear on coil. PT lub to 1000 psig, RIH to top of fish. 13:05 - 14:11 1.10 WORK FISH CTBG Tagged top of 2.0" GS. Set down, PU good latch on fish. POOH, velocity string up to top of lubricator. 14:11 - 16:00 1.82 WORK FISH CTBG Close slips. Vent lubricator and coil tubing. Leaving a 15' stub of tubing. Laydown 20' lubricator. Reconnect tubing using a roll -on. 16:00 - 17:00 1,00 WORK FISH CTBG PU injector. PT lubricator to 1000 psi. Good test. 17:00 - 17:30 0.50 WORK FISH CTBG POOH until roll -on is at reel spool. 17:30 - 17:45 0.25 WORK FISH CTBG Attach muffler clamps on tubing at roll -on for safety catch. 17:45 - 18:05 0.33 WORK FISH CTBG POOH reeling v- string onto spool. Dragging heavy most of the way out of hole with coil, 24k. 18:05 - 18:30 0.42 WORK FISH CTBG Pump 6% KCL while pulling out of hole with coil at 1.0 BPM, pumped total of 56 bbls when coil at 4374'. WHP= 490 psig. 18:30 - 20:33 2.05 WORK COIL CTBG Coil at 335' CTM, hole in pipe across brass in BOP. Total fluid pumped down well = 80 bbls. WHP= 900 psig. 20:33 - 20:50 0.28 WORK COIL CTBG Attempt to bleed down gas pressure from well. 70% liquid to flow back tank. Let well set to swap hole. 20:50 - 21:00 0.17 WORK COIL CTBG Pump 40 bbls of fluid down well, Well pressure @ 920 psig. Total = 120 bbls. Open well some gas, KCL. 21:00 - 21:15 0.25 PUMP_ WTR_ CTBG Pumped 30 bbls of fluid, total 150 bbls down well. 21:15 - 21:30 0.25 WAITON OTHR CTBG Let well set overnight to let fluid swap in well. Watched coil overnight. 21:30 - 22:00 0.50 RURD_ OTHR CTBG BJ crew left lease. WHP= 980 psig, coil at 335' with 700 psig on coil. 4/2312007 08:00 - 09:00 1.00 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 09:00 - 09:15 0.25 RURD_ COIL CTBG Uptained work permit and discussed environmental issues prior to start up. 09:15 - 09:30 0.25 WORK COIL CTBG Guage fluid levels in tanks 220 bbls KCL. Open choke to bleed wellhead pressure WHP= 1000 psi. 09:30 - 10:00 0.50 WORK COIL CTBG Continue bleeding WHP thru choke. Pressure down to 65 psi. 10:00 - 10:05 0.08 RURD_ COIL CTBG Wellhead bled to 0. Close chokes. Monitor wellhead pressure Printed: 6/12/2007 10:32:46 AM 0 0 Marathon Oil Company Page 3 of 8 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code Code Phase Description of Operations 4/2312007 10:05 - 10:14 0.15 WORK COIL CTBG WHP built up to 20 psi. Start pumping down tubing. 10:14 - 10:25 0.18 WORK COIL CTBG Shut down pumps. Monitor pressure . Pumped 10 bbls. WHP 0 psi. Total fluid pumped down well was 140 bbls for pulling velocity string. 10:25 - CTBG 10:25 - 11:20 0.92 WORK COIL CTBG Open lubricator. No pressure. PU ejector head and set ct slips. Cut ctubing just above split shot 11:20 - 12:39 1.32 WORK COIL CTBG RD ejector. RU crane. Install clamps on Cut and lay down ctubing w/ crane and tagline. 12:39 - 13:20 0.68 WORK COIL CTBG Recovered 220' of 1 -3/4" coiled tubing. Left 157' coil in well. * *coil tubin fish. 13:20 - 13:30 0.17 WORK COIL CTBG Install night cap on CTU BOP. Secure well. 13:30 - 14:00 0.50 WORK COIL CTBG Pull velocity string out of injector and install working string back into injector. 14:00 - 16:00 2.00 RURD_ COIL CTBG Secured coil unit for night and cleaned up around area. BJ crew left lease. 4/26/2007 13:00 - 14:00 1.00 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 14:00 - 14:30 0.50 RURD_ COIL CTBG Uptained work permit and discussed environmental issues prior to start up. 14:30 - 16:30 2.00 RURD_ COIL CTBG Unload 2" concentric coil with crane. Transload to BJ trailer. 16:30 - 18:00 1.50 RURD_ COIL CTBG Unload and rig up ejector head. 18:00 - 19:00 1.00 RURD_ COIL CTBG Unload and rig up 2" BOP. 19:00 - 19:30 0.50 RURD_ COIL CTBG Shut in and suspend operations for the night. 14/27/2007 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 08:30 0.50 RURD_ COIL CTBG Uptained work permit and discussed environmental issues prior to start up. 08:30 - 13:00 4.50 RURD_ COIL CTBG RU 2" hardlines from CTU and flowback tank. 13:00 - 13:30 0.50 TEST_ BOPE CTBG Start BOP testing. Vac truck arrive. Dennis Donovan arrives. Conduct JSA orientation. Pressure test Blinds - 880/4820 psig. Pressure test Tubing rams 1000/4800 psig. 13:30 - 14:37 1.12 RURD_ COIL CTBG BOP testing completed. MU BHA and stab concentric into injector head 14:37 - 16:53 2.27 RURD_ COIL CTBG Stab Pipe into injector head. 16:53 - 17:35 0.70 CLNOUT TBG_ CTBG Pump 63 BBL to Cleanout Concentric Coil Tubing. BHA is Capped on the end to recirc into the flowback tanks. 17:35 - 17:47 0.20 CLNOUT TBG_ CTBG Steady returns - Full returns 27 bbl away 17:47 - 18:03 0.27 CLNOUT TBG_ CTBG Clean returns - Full returns 36 bbl away (63 bbl pumped) 18:03 - 18:11 0.13 TEST_ TBG_ CTBG Pump down 48 bbis and Pressure test outer coil 2" @ 1820 psig, Bleed off 18:11 - 18:18 0.12 TEST_ TBG_ CTBG Install sand vac tool to 1" CT, Pressure test to 5800 psig. Bleed off. 18:18 - 19:00 0.70 RURD_ COIL CTBG Stand down CT unit for change out 19:00 - 19:30 0.50 SAFETY MTG_ CTBG Hold BJ Shift Safety Meeting, JSA, Crance Safety, Slips, Trips, Falls (NEW Permit was issued and is good for 1900 hrs 4/26/2007 to 0700 hrs 4/27/2007 19:30 - 20:00 0.50 RURD_ COIL CTBG Crew familiarized with CT Rigup, Set Lubricator on wellhead 20:00 - 20:20 0.33 CLNOUT TBG_ CTBG Open to well and bring pumps online pumping 2000 to 2200 psig on 1" CT. WHP is 15 psig 20:20 - 20:30 0.17 CLNOUT TBG_ CTBG Monitor returns 520' CTM in hole. 0.3 BPM returns and 0.4 BPM pumping 20:30 - 21:00 0.50 CLNOUT TBG_ CTBG RIH @ 911' CTM, CTP -2033 psig, WHP- 11psig, in /out 0.3 bpm /0.3bpm, 60.5 bbl pumped, Outer Pressure - 7 psig 21:00 - 21:32 0.53 CLNOUT TBG_ CTBG Pull test from 1520' -1500' Up weight is 6800 lbs. CTP -2033, WHP -7, 0.3/0.3 bpm, 63 bbls pumped, Outer Press - 7 psig 21:32 -22:05 0.55 CLNOUT TBG_ CTBG Pull test from 4040' -4030' KB. CTP- 1500psig, WHP- 4psig, 0.3/0.3 bpm, Outpress- 7 psig 22:05 - 22:10 0.08 CLNOUT TBG_ CTBG Pull test from 5730' -5700' KB. CTP -1700 psig, WHP -15 psig, 0.3/0.3 bpm, Outpress - 15 psig. Printed: 6/12/2007 10:32:46 AM 0 0 Marathon Oil Company Page 4 of 8 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From -To Hours Code Cod Phase Description of Operations 4/27/2007 22:10 - 22:35 0.42 CLNOUT TBG_ CTBG Pick fluid rate up to .56 bpm @ 5850' KB, CTP -4915 psig, 0.55/0.5 bpm, OP- 30 psig 22:35 - 23:00 0.42 CLNOUT TBG_ CTBG Tag, Pull up, and RIH @ 6680' KB, CTP -4675 psig, WHP- 7psig, 0.55/0.5, 100 bbls pumped, OP -15 psig 23:00 - 23:15 0.25 CLNOUT TBG_ CTBG Tag Pull up and increase pump rate to 6679' KB, CTP -5000 psig, WHP -15 psig, .56bpm /37gpm, 115 bbl pumped, OP -15 23:15 - 23:42 0.45 CLNOUT TBG_ CTBG RIH to 6680' KB CTP -5000 psig 23:42 - 00:00 0.30 CLNOUT TBG_ CTBG 1/4 cup of sand collected, RIH @ 6680.1'KB 0.56bpm /33gpm, CTP -5000 psig, 137 bbl pumped, WHP -4psig 00:00 - 00:19 0.32 CLNOUT TBG_ CTBG Tagged hard @6680.9. No penitration since 22:35. Samples of returns decreased to 3 -4 teaspoons fine white sand and coal. Increase pressure to 5500psi. 00:26 - 00:27 0.02 CLNOUT TBG_ CTBG Supply tank 50" (206 bbls) Return tank 35" (124 bbls) 00:27 - 00:41 0.23 CLNOUT TBG_ CTBG Still no penitration. Solids in sample 2 -3 teaspoons. 01:15 - 01:24 0.15 CLNOUT TBG_ CTBG Discuss lack of penitration with BJ supervisor. Max weight on tool and increased pump rate have not helped. Decided to pull up hole 50'. Try to go down around obstruction. 01:24 - 01:32 0.13 CLNOUT TBG_ CTBG RIH. Tag up @6680.4'KB. 01:32 - 01:39 0.12 CLNOUT TBG_ CTBG Still no penitration. Decided to POH and check tool. 01:39 - 03:41 2.03 CLNOUT TBG_ CTBG OOH.. Close swab and master valve. (18.5 turns) Swab leaks. 03:41 - 04:00 0.32 RURD_ COIL CTBG Bleed pressure on lubricator. RD ejector head. 04:00 - 04:35 0.58 RURD_ COIL CTBG Inspect Sand vac tool. Some verticalscapes on nose of tool. Appear to be new. Pump thru tool @5000psi. to check fluid jets and tool function. Tool appears to be functioning properly. 04:35 - 05:10 0.58 RURD_ COIL CTBG Rig up ejector on tree. Prepare to RIH. Reinstall walking dogs. PTest lubricator to 1000psi. 05:10 - 06:00 0.83 CLNOUT TBG_ CTBG RIH. Pump p 2220psi, .3 BPM, WHP zero 4/28/2007 06:00 - 06:10 0.17 CLNOUT TBG_ CTBG RIH. Supply tank 250 bbls., Return tank 103 bbls 06:10 - 06:30 0.33 CLNOUT TBG_ CTBG RIH @5000'. PP 2900 psi., .42 BPM, WHIP 0 06:30 - 06:45 0.25 CLNOUT TBG_ CTBG RIH to 5700'. Increase pump rate to .56 BPM @ 4500 psi. 06:45 - 07:00 0.25 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 07:00 - 07:15 0.25 RURD COIL CTBG Uptained work permit and discussed environmental issues prior to start up. Day shift takes over from night crew. 07:15 - 07:19 0.07 CLNOUT TBG_ CTBG Tag fill @6687'. .57 BPM, 5400 psi., WHIP 0 07:19 - 07:30 0.18 CLNOUT TBG_ CTBG First sample recovered 1 teaspoon of sand 07:30 - 07:44 0.23 CLNOUT TBG_ CTBG PUH to 6667' and circulate. Sample 1 tablespoon of sand 07:44 - 08:05 0.35 RURD_ COIL CTBG RDH tag @6686.9'. 08:05 - 08:08 0.05 CLNOUT TBG_ CTBG PUH to 6667'. 08:08 - 08:42 0.57 CLNOUT TBG_ CTBG RBIH to 6686.9' Weight 7100lbs. 08:42 - 08:43 0.02 CLNOUT TBG_ CTBG 6687.3' Sample trace of sand. 08:43 - 08:50 0.12 TEST_ TBG_ CTBG 6687.8' Sample 112 teaspoon sand. 08:50 - 09:27 0.62 TEST_ TBG_ CTBG 6689.4'. Sample muddy with moderate viscsity. 09:27 - 09:49 0.37 RURD_ COIL CTBG 6689.5'. Pump pressure 5200, .55 bpm. Thick and muddy. 09:49 - 10:00 0.18 SAFETY MTG_ CTBG 6689.6'. Continue working tubing down. 10:00 - 10:06 0.10 RURD_ COIL CTBG 6690.3' 10:06 - 10:12 0.10 CLNOUT TBG_ CTBG 6691.2'. Sample dirty but no longer thick and muddy. 10:12 - 10:29 0.28 CLNOUT TBG_ CTBG 6695' String weight 7000 lbs. 10:29 - 10:49 0.33 CLNOUT TBG_ CTBG 6702.9'. Wt. 10,974. .55bpm, 5550psi 10:49 - 10:50 0.02 CLNOUT TBG_ CTBG POOH. String wt. 17,000 Ibs 10:50 - 13:00 2.17 CLNOUT TBG_ CTBG CT OOH. Close swab and master valve. 13:00 - 13:45 1 0.75 CLNOUT TBG_ CTBG RD and stand back ejector head. 13:45 - 14:00 0.25 CLNOUT TBG_ CTBG Rig down coil. 14:00 - 14:45 1 035 SAFETY MTG_ SLICK Hold TGSM with Pollard JSA, Full Safety Checklist, STandFalls, Printed: 6/12/2007 10:32:46 AM • Marathon Oil Company Page 6 of 81 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 4128/2007 14:00 - 14:45 0.75 SAFETY MTG_ SLICK Concurrent Ops 14:45 - 15:30 0.75 RURD SLIK SLICK Rig Up Wireline 15:30 - 15:45 0.25 TEST_ BOPE SLICK PT Lubricator to 1000 psig, GOOD test 15:45 - 17:00 1.25 TAG_ BOTM SLICK RIH w/ 2.75" LIB to 6616' KB and set down, Gave one small tap and fell down hole, RIH to 6658' KB, Hit down, POOH 17:00 - 17:10 0.17 TAG_ BOTM SLICK OOH with Impression of coil on LIB on low side of the hole 17:10 - 17:20 0.17 SAFETY MTG_ SLICK Hold Post Job TGSM with JSA, Discuss and Plan Rigdown 17:20 - 17:45 0.42 RURD SLIK SLICK Rigged down Wireline svcs, secured well and left location 17:45 - 19:00 1.25 WAITON EQIP SLICK NO ACTIVITY ON SITE, Wait -on BJ Svcs to RU 1.75" V- string 19:00 - 20:00 1.00 SAFETY MTG_ SLICK BJ, ASRC Crane, MOC TGSM and JSA for RU of Coil Tubing 20:00 - 06:00 10.00 RURD_ COIL SLICK Move in VMT for 30 bbl Biozan Slugs, Ship N2 from Anchorage, Bolt on BOPE's, Test 1.75" CT BOPE, Prep Injector Head and Stab Pipe into injector. (Change entire setup from Vac String to Conventional CT string setup.) 4/29/2007 06:00 - 07:00 1.00 RURD_ COIL CTBG Night shift RU 1 -3/4" ejector head. Threading coil into ejector. 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Hold Safety Meeting, JSA, Crane Safety, Slips, Trips, Falls. 08:00 - 08:30 0.50 SAFETY MTG_ CTBG Uptained work permit and discussed environmental issues prior to start up. Day shift takes over from night crew. 08:00 - 10:00 2.00 RURD_ COIL CTBG Continue rigging up . Test BOP's. Test good. Laydown liner for batch mixers. Spot batch mixers and flowback tank. Vac truck making 6% KCL water and filling work tanks. 10:00 - 12:00 2.00 RURD_ COIL CTBG Test 2" hard lines and return lines. RU gas buster on second returns tank. Continue mixing 6% KCL. 12:00 - 12:30 0.50 RURD_ COIL CTBG Pull test CT connection. Test good. MU Jet on CT nozzle. RU ejector head. 13:00 - 13:30 0.50 CLNOUT TBG_ CTBG PT lubricator to 1500psi. Test good. Open swab valve. Open upper master valve. (18.5 turns) 13:30 - 13:45 0.25 CLNOUT TBG_ CTBG Start running in hole. 13:45 - 14:00 0.25 RURD COIL CTBG RIH. Pumping minimum rate. 14:00 - 14:25 0.42 CLNOUT TBG_ CTBG RIH 4339'. Pumping minimum rate. 14:25 - 14:42 0.28 CLNOUT TBG_ CTBG RIH 5075'. Pumping minimum rate. Returns on the backside. 14:42 - 15:10 0.47 CLNOUT TBG_ CTBG RIH 6650'. Pumping minimum rate. Returns on the backside. 15:10 - 15:15 0.08 CLNOUT TBG_ CTBG Tag fish at 6661'. 62 bbls pumped. Increase rate to 1.5 bpm. 15:15 - 15:20 0.08 CLNOUT TBG_ CTBG RIH 6689.4'. wt 7000, Pumping 2200psi, WH 55 psi, 1.87 bpm 15:20 - 15:24 0.07 CLNOUT TBG_ CTBG 6690', Pumping 2200psi, WH 48 psi, 1.74 bpm. Returns to surface @4:30 15:24 - 15:30 0.10 CLNOUT TBG_ CTBG 6720'. Pumping 2226 psi, WH 44 psi, 1.75 bpm 15:30 - 15:38 0.13 CLNOUT TBG CTBG 6750' Pumping 2350 psi, WH 44 psi, 1.79 bpm 15:38 - 15:46 0.13 CLNOUT TBG_ CTBG 6771' Pumping 2400 psi, WH 66 psi, 1.7 bpm Pull test 15,400 15:46 - 16:00 0.23 CLNOUT TBG_ CTBG 6790' Pumping 2480 psi, WH 77 psi, 1.8 bpm Start 20 bbl Biozan sweep. 16:00 - 16:15 0.25 CLNOUT TBG CTBG 6790' Loose prime pressure and rate fall. Switch back to KCL to reprime. 16:15 - 16:20 0.08 CLNOUT TBG_ CTBG POH 6584' Pressure 2200 psi, WHP 55 16:20 - 16:25 0.08 CLNOUT TBG_ CTBG RIH 6600' Pumping 2350 psi, WH 48 psi, 1.5 by 16:25 - 16:27 0.03 CLNOUT TBG_ CTBG RIH 6728' Pumping 2490 psi, WH 40 psi, 1.5 bpm Sample milky returns Looks like Beluga fines. 16:27 - 16:30 0.05 CLNOUT TBG_ CTBG RIH 6728' Pumping 2490 psi, WH 40 psi, 1.5 bpm Sample milky returns Looks like Beluga fines. 16:30 - 16:45 0.25 CLNOUT TBG_ CTBG 6783' Pumping 1670 psi, WH 26 psi, 1.1 bpm Start Biozan sweep 16:45 - 16:50 0.08 CLNOUT TBG_ CTBG 6783' Pumping 2180 psi, WH 33 psi, 1.2 bpm 10 bbls. Biozan pumped. 16:50 - 17:00 0.17 CLNOUT TBG_ CTBG 6783' Pumping 2342 psi, WH 40 psi, 1.16 bpm 15 bbls. Biozan pumped. 17:00 - 17:04 0.07 CLNOUT TBG_ CTBG 6783' Pumping 2580 psig, WH 40 psig, 1.12 bpm 20 bbls. Biozan Printed: 6/12/2007 10:32:46 AM 0 0 Marathon Oil Company Page 7 of 8 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Sub Date From - To Hours Code Code Phase Description of Operations 4/30/2007 08:30 - 08:32 0.03 CLNOUT TBG_ CTBG pumped. Good returns. Pumping N2 @ minimim rate. 08:32 - 08:40 0.13 CLNOUT TBG_ CTBG 6955'. Pump KCL 1.4 bpm, 3470 psi, WH 291 psi, . Pumping N2 @ minimim rate. 08:40 - 08:45 0.08 CLNOUT TBG_ CTBG 6955'. Pump KCL 1.5 bpm , 3380 psi, WH 302 psi, . Increase N2 rate. Biozan on perfs. 08:45 - 08:48 0.05 CLNOUT TBG_ CTBG PUH 6929' Pull test. 15K 08:48 - 09:00 0.20 CLNOUT TBG_ CTBG 6986'. Pump KCL (25bbls away)1.5 bpm, 3380 psi, WH 340 psi, . Beluga solids in returns. 09:00 - 09:07 0.12 CLNOUT TBG_ CTBG RIH 6991'. Pump KCL 1.5 bpm , 2725 psi, WH 210 psi, . Lost drive coupling between hydraulic motor and downhole N2 pump. 09:07 - 09:10 0.05 CLNOUT TBG_ CTBG PUH 6956'. Pump KCL 1.5 bpm , 2543 psi, WH 200 psi, . Good returns. 09:10 - 09:15 0.08 CLNOUT TBG_ CTBG PUH 6936'. Pump KCL 1.7 bpm , 2640 psi, WH 136 psi, . Increase pump rate. 09:15 - 09:18 0.05 CLNOUT TBG_ CTBG PU into 3 -1/2" tubing. Pump KCL 1.7 bpm , 2732 psi, WH 114 psi, Assess situation. . 09:18 - 11:09 1.85 CLNOUT TBG_ CTBG Continue to circulate KCL water at 1.25 bpm. 11:30 - 12:15 0.75 CLNOUT TBG_ CTBG POOH. Continue circulating KCL @ 1.25 bpm. 12:15 - 12:20 0.08 CLNOUT TBG CTBG OOH. Close master valves. Close swab valve. (18.5 turns) 12:20 - 12:40 0.33 RURD TBG_ CTBG Rig down ejector head. Install tree cap on BOP's. Safe out well. Suspend operations. 5/2/2007 06:30 - 07:00 0.50 SAFETY MTG_ CTBG Held PJ safety meeting with night crew. Discuss job scope. Uptain Hot work permit. 07:00 - 07:30 0.50 CLNOUT TBG_ CTBG Coil at 7067'CMT, 3100 psi, 220 WHP, 1.5 bpm, 600 scf /min N2. Returns gray with some fine sand. 07:30 - 08:00 0.50 CLNOUT TBG_ CTBG Continue running in well with coil, good returns to flow back tank. Total N2 pumped = 503 K, H2O= 1303 BBLs. 08:00 - 08:30 0.50 CLNOUT TBG_ CTBG CT@ 7546' CTM. PIP= 3100 psig, WHP= 270 psig. PUW= 1500 Ibs 08:30 - 09:30 1.00 CLNOUT TBG_ CTBG Transfered fluid from return tank back to supply tank. WHP= 313 psig. 09:30 - 11:00 1.50 CLNOUT TBG_ CTBG Work coil down to 7750' CTM. PIP= 2800 psig. Pump 23 bbl gel sweep. 11:00 - 12:10 1.17 CLNOUT TBG_ CTBG Coil at 7750' CTM. WHP =320 psig. PIP= 2920 psig. N2 at 600 scfm. Good returns to flow back tank. 12:10 - 12:20 0.17 CLNOUT TBG_ CTBG Gel at surface, switch over to outside flow back tank. Returns sandy with gray slit. 12:20 - 12:30 0.17 CLNOUT TBG_ CTBG Drop 1/2" ball to increased PIR to 2.0 BPM. 20 bbls away cut PIR to 1.0 BPM. 12:30 - 12:55 0.42 JET_ N2_ CTBG Pressure up to 4400 psig; sub shifted. Back out fluid and switched to N2 at 800 SCFM. PU hole at 10 fpm. 12:55 - 13:00 0.08 JET_ N2_ CTBG Circulate N2 up hole, WHP= 202 psig, total N2 = 760, 000 SCF pumped. CTP= 2447 psig. 13:00 - 14:00 1.00 JET_ N2_ CTBG Good returns to flow back tank. Coil at 7495 ' CTM. N2 rate at 1200 SCFM. 14:00 - 14:50 0.83 JET_ N2_ CTBG PU hole at 10 FPM pumping N2 at 500 SCFM. Coil at 6550', WHP = 155 psig, PIP= 500 scfm. Returns slowed to very little. 14:50 - 15:15 0.42 JET_ N2_ CTBG PU hole with coil to 5730', PIP= 300 psig, WHP= 99 psig. RIH with coil. 15:15 - 15:30 0.25 JET_ N2_ CTBG Coil down to 6850' CTM, PIP= 330 psig, WHP= 33 psig 15:30 - 16:20 0.83 JET_ N2_ CTBG Coil tagged @ 7720' CTM. PIP= 1000 scfm, WHP= 18 psig. N2 rate @ 1000 SCFM. 16:20 - 16:35 0.25 JET_ N2_ CTBG POOH with coil at 30 FPM, PIP= 1107 psig, WHP= 35 psig, Total N2 pumped 890 K. 16:35 - 16:40 0.08 JET_ N2_ CTBG Coil at 6940 psig, no returns to flow back tank. WHP= 125 psig, PIP= 1140 psig, PIR at 1000 SCFM. 16:40 - 17:15 0.58 JET_ N2_ CTBG CT at 5720', cut N2 back, coil at 700 psig, WHP = 200 psig. Printed: 6/12/2007 10:32:46 AM 0 0 Marathon Oil Company Page 8 of 8 Operations Summary Report Legal Well Name: KENAI DEEP UNIT 4 Common Well Name: KENAI DEEP UNIT 4 Spud Date: 2/11/1969 (Event Name: WORKOVER Start: 4/14/2007 End: Contractor Name: Rig Release: Group: !Rig Name: Rig Number: Date From -To Hours Code Code Phase 5/2/2007 17:15 - 17:50 0.58 JET N2 CTBG 17:50 - 19:00 1.17 RUNPUL COIL CTBG 19:00 - 20:30 1.50 RURD COIL CTBG 5/7/2007 08:00 - 09:00 1.00 SAFETY MTG_ WRLN 09:00 - 11:00 2.00 RURD_ COIL WRLN 11:00 - 11:30 0.50 RURD ELEC WRLN 11:30 - 12:45 LOG OTHR WRLN 12:45 - 13:30 0.75 LOG OTHR WRLN 13:30 - 14:00 0.50 LOG_ OTHR WRLN 14:00 - 15:00 1.00 RURD ELEC WRLN Description of Operations Continue out of hole with coil, coil at 2650' CTM, WHP= 48 psig, coil 149 psig. no fluid in returns. Coil at surface, blow down coil to flow back tank. WHP= 44 psig. Shut in Bop's. Rig back coil unit, secured well. Monitor well during night to see if well pressures up. BJ left lease. Held PJ safety meeting with night crew. Discuss job scope. MIRU eline unit. Held PJSM and discussed well condtitions. MU lubricator, PU 1 11/16" Pressure/ temperature logging tool string. PT lubricator to 2000 psig. Good test. Open well, WHP= 110 psig, Well] flowing at 480 MMCFPD rate with some water. RIH logging, capacitance tool found fluid at 275'. Sat down at 7620' KBD. Temperature indicates cooling below 7620' KBD. FBHP @ 1275 psig. POOH with logging tool, OOH. RD unit. RD wire line unit. Expro personnel left ]ease. Printed: 6/12/2007 10:32:46 AM MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga / Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184 -109 KBU 23X -06 200 -023 KTU 32 -07 181 -153 KBU 31 -07 168 -049 KDU 2 195 -055 KBU 31 -07RD 184 -108 KTU 13 -05 174 -050 KU 14 -06RD 199 -024 KBU 33 -06 178 -055 KDU 5 195 -054 KTU 43 -06XRD 177 -029 KBU 13 -08 203 -066 KBU 43 -07X 185 -181 KBU 33 -07 199 -073 KTU 24 -06H 202 -043 KTU 32 -07H 195 -054 KBU 43 -06XRD 179 -029 KBU 41 -07 169 -012 KDU 4 184 -108 KTU 13 -05 179 -030 KBU 43 -06X 199 -024 KBU 33 -06 199 -025 KBU 42 -07 200 -188 KBU 24 -06 202 -025 KBU 41 -07X 200 -179 KBU 44 -06 c /A \NN E ,0 L26 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0AEXCELVW0GCC01.x1s A te 1. Type of Request: Abandon Suspend Operation Shutdown Re -enter Suspended Well Alter Casing Repair Well Plugging Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate Other X 2. Name of Operator 5. Type of Well: 6. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X 95' KB above MSL feet Unit or Property Name 3. Address Exploratory P. O. Box 196168, Anchorage, AK 99519 -6168 Stratigraphic _ Kenai Beluga Unit 8. Well Number 4. Location of Well at Surface Service _ 235' FNL, 4209' FWL, Sec. 7, T4N, R11 W, S.M. KDU 4 -7- At top of Productive Interval 9. Permit Number 69 -12 At Effective Depth 10. API Number Install velocity string 50- 133 - 20176 -010 11 Field /Pool At Total Depth 3035' FNL, 805' FWL, Sec. 7, T4N, R1 1W, S.M. Kenai Gas Field /Beluga 12. Present Well Condition Summary Total Depth: measured 10810 feet Plugs (measured) cement retainers at 8000' and 8955' true vertical 9739 feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface 1264' 20" 1100 sks 1264' 1217' Intermediate 6026' 13 -3/8" 3259 sks 6026' 5400 Production 10310 9 -5/8" 1415 sks 10310' 9280 Liner 497 7" 130 sks 10759 9688 Perforation Depth: measured 6655'- 6665', 6800'- 6808', 6825'- 6844', 7264'- 7293', 7340'- 7350', 7668'- 7678', 7683' -7697' true vertical 5970'- 5978', 6098'- 6105', 6120'- 6136', 6510' - 6536', 6578'- 6587', 6876'- 6885', 6889' -6902' Tubing (size, grade, and measured depth) 3.5 ", 9.2 ppf, N -80, IBT to 5720' - � Packers and SSSV (type and measured depth) Baker SAB permanent packer 5573' JAN 1 3. Attachments Description Summary of Proposal Detailed Operations Program — X BO — K 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: PsAm J \ o 6 � r Oil Gas X Suspended 16. If Proposal was Verbally Approved Name of Approver Date Approved Service 17. 1 hereby ce ify tha a foregoing is true d correct to the best of my knowledge. Signed Title Production Engineer Date 1/30/2003 FOR COMMISSION USE ONLY Conditions of Appr al. Notify Commiss n so representative may witness Approval No. Plug NAgrity _ OP Test _ Location Clearance _ Mechanical Integrity Test Subsequent Form Required 10- L -- �' r 3 - c7 :3 v ORIGINAL SIGNED By n Approved by Order of the Commission A4 L. EW Commissioner Date Form 10 -403 Rev. 06/15/88 FEB I I pom SubrAit i1i7ripficate 'MS 8FL i� Well KDU -4rd, Kenai Gas Field WBS WO.03.08214.EXP Install Velocity String Objective Install a velocity string in well KDU 4rd to keep liquids unloaded and increase gas production. Procedure 1. Shut -in well KDU 4rd. MIRU slickline on well KDU 4rd. Test lubricator. RIH with a "AD -2" tubing stop for 3 1 /2 ", 9.2 ppf, buttress tubing to 1000'. Set "AD -2" stop. POOH. 2. RIH with a Daniels kickover tool for a Camco sidepocket mandrel with a 1" chemical injection valve. Orient and latch chemical injection valve at 717'. POOH. 3. RIH with 3/16" orifice check valve and install in chemical injection mandrel at 717'. POOH. 4. Pump methanol through the chemical injection line to confirm that valve is operating properly. 5. RIH, pull tubing stop. POOH, RDMO slickline. Reopen KDU 4rd to flow. 6. MIRU 1 3 /4" coil tubing unit with 4- 1/16 ", 5M work window. Reel should consist of at least 8000' of 1 3 /4 ", 0.125" wall thickness, coil tubing with no butt welds. Conduct prejob safety meeting. NU BOPS, and test to 250/3000 psi. Install return line off of flowline flange below the swab valve. Purge coil tubing reel with nitrogen. MU Weatherford coil tubing pump -out plug with 1.268" nipple profile onto the end of the coil tubing. ND injector head. 7. RIH with coil tubing to 7300' K.B. ( Note : Will be unable to circulate with the pump -out plug installed onto the end of the coil tubing.) Unload well up the coil tubing annulus while RIH. Continue to produce well up coil tubing annulus until satisfied that the well will produce independently. 8. Set slips on 1 3 /4" coil tubing and close the pipe rams. Bleed off trapped pressure above the BOPE, and confirm that the slips and the pipe rams are holding as designed. Open the 4- 1/16" window to allow access to the coil tubing. Install safety clamp on coil tubing. Cut the 1 3 /4" coil tubing, and ND injector head with the cut tubing. Velocity String for Weli KDU 4rd WBS WO.02.08214.EXP Page 2 9. Install Weatherford PDH coil tubing packer onto the coil tubing stub in the work window. Install motor head assembly, Weatherford mechanical setting tool, and hydraulic releasing tool onto the coil tubing stub in the injector head. Pull test? Confirm required ball size for the hydraulic release before making up assembly. 10. NU injector head with mechanical setting tool and hydraulic release. Engage the PDH packer with the mechanical setting tool. When it is confirmed that the setting tool is engaged onto the packer, remove the safety clamp and close the work window. Equalize pressure across the pipe rams, then open the pipe rams. PU to coil tubing running weight, then open the slips. Keep the PDH packer up in the lubricator for the time being. 11. Pressure up on the coil tubing with nitrogen to blow out the pump -out plug. Once the pump -out plug is removed, jet well with nitrogen as needed to stabilize flow. Do not continue the procedure until confident that the well is unloaded and capable of independent flow. 12. Shut -in well KDU -4rd at the wing valve. RIH with the PDH packer to ±20' below the top of the tubing hanger ( ±41' KB). ( Note : Immediately below the tubing hanger is a 4' pup joint. A depth of 20' below the tubing hanger will put the PDH packer in the middle of the first full joint of 3 1 /2" tubing.) Reciprocate the coil tubing around the ±20' mark to set the mechanical packer. Apply coil tubing weight to verify that the packer is set. 13. Place a %" ball ( ?) into the coil tubing string, and displace with 6% KC1 to the hydraulic releasing tool. Pressure up to psi to release from the PDH packer. PU to verify that the coil is released from the PDH packer. Set back down on the PDH packer one more time to confirm that it is still in place. 14. PU above the swab valve with the coil tubing, and close the swab to isolate the coil. Reopen the wing valve to allow production up the velocity string. Displace reel with nitrogen while allowing the well to produce up the velocity string. Confirm that the well is producing as expected up the velocity string before allowing coil tubing to rig down. RDMO coil tubing. 15. Produce well KDU 4rd to the low pressure system. If well acts like it is loading up, jumper high pressure gas to the chemical injection line to assist in lifting water to get the well kicked off. J. Gary Eller - 1/30/2003 KDU 4rd a Pad 41 -7, Kenai Gas Field API: 50- 133- 20176 -01 AOGCC: 69 -12 RT -G L: 235' FNL, 4209' FWL Sec. 7, T4N, R11W, S.M. Tree cap: 4 -3/4" Otis (on dual tree) Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - 1" orifice check installed 3/26/96 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' Active Perfs 6655' -6665' (2/6/96) 6800' -6808' (12/15/95), frac'd 12/26/95 6825' -6844' (12/10/95), frac'd 12/26/95 7264' -7293' (11/19/95) 7340' -7350' (11/25/95) 7668' -7678' (11/11/95) 7683' -7697' (11/11/95) Isolated Perfs 9937' -947' (6/69) 9952' -986' (6/69) 9994'- 10002' (6/69) 10258' -279' (6/69) 10315' -316' (sgzd 6/69) 10428'-470'(6/69) 10430' -440' (6/69) 10480'-490'(6/69) 20 ", 94 #, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" Fish - 3 jnts of 3.5 ", 9.4 ppf, L -80, IBT tubing, dropped 10/23/95 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Fill tagged @ 7641', 1/15/2003 9 -5/8 ", Armco "seal -lock" prod. csg @ 10,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5 #, P -110 35' - 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310', 53.5 #, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State /Prov. Alaska Country: Perforations: (MD) Beluga (TVD) Angle / Perfs I Angle @KOP and Depth 25 deg KOP TVD Date Completed: I RKB: 01/27/03 Prepared By: Gary Eller Last Revision Date: .x L PBTD - 8000' TD - 10,810' ,r .:DU 4rd - Pro p ose MARATHON Pad 41 -7, Kenai Gas Field API: 50- 133- 20176 -01 AOGCC: 69 -12 RT -MSL (Original Drlg): 95' RT -GL (1996 w /o): 20.5' 235' FNL, 4209' FWL Sec. 7, T4N, R11 W, S.M. Tree cap: 4 -3/4" Otis (on dual tree) Tubing String - 3 -1/2 ", 9.2 #, N -80, IBT tubing Camco sidepocket injection mandrel @ 717' - orifice check installed 3/26/96 Baker 80 -40 K- Anchor @ 5572' Baker SAB Packer @ 5573' X- nipple @ 5622' ID = 2.813" X- nipple @ 5687' ID = 2.813" Wireline Re -entry Guide @ 5720' M9/10 - 6428' -6458' (1/31/03) M14 - 6655'-6665'(2/6/96) L3 - 6800' -6808' (12/15/95), frac'd 12/26/95 L3 - 6825' -6844' (12/10/95), frac'd 12/26/95 L9 - 7264' -7293' (11/19/95) L10 - 7340' -7350' (11/25/95) L13 - 7668' -7678' (11/11/95) L13 - 7683' -7697' (11/11/95) Isolated Perfs 9937' -947' (6/69) 9952' -986' (6/69) 9994'- 10002' (6/69) 10258' -279' (6/69) 10315' -316' (sqzd 6/69) 10428' -470' (6/69) 10430' -440' (6/69) 10480' -490' (6/69) 20 ", 94 #, H -40, 8rd surface csg @ 1264' Cmt with 900sks of class "G" Fish - 3 jnts of 3.5 ", 9.4 ppf, L -80, IBT tubing, dropped 10/23/95 Coil Tubing Velocity String 1.75 ", 0.125" WT coil tubing, 40'- 7300' Hung from Weatherford PCH packer @ 40' (approximately 20' below ground level) Landing nipple at end of coil @ 7300' ID = 1.268" 13 -3/8 ", 61 #, J -55, "seal -lock" int. csg @ 6026' Cmt w/ 3259 sks of class "G" Fill tagged @ 7641', 1/15/2003 Coil wash /jet to 7763', 1/28/03 9 -5/8 ", Armco "seal -lock" prod. csg @ 1 0,310' Cmt w/ 1415 sks of class "G" 0' - 35', 53.5 #, P -110 35' - 4194', 43.5 #, N -80 4194'- 5733', 47 #, N -80 5733' - 8206', 47 #, P -110 8206' - 10310% 53.5 #, P -110 Retainer @ 8000' (10/19/95) Retainer @ 8955 (10/17/95) 7 ", 29 #, N -80, BTC liner 10,280'- 10,759' Cmt w/ 130 sks of class "G" Well Name & Number: KDU 4rd Lease Pad 41 -7, Kenai Gas Field County or Parish: Kenai Peninsula Borough State /Prov. Alaska Country: Perforations: (MD) Beluga (TVD) Angle /Perfs Angle @KOP and Depth 25 deg KOP TVD Date Completed: I RKB: 01/27/03 Prepared By: Gary Eller Last Revision Date: ..aT L PBTD - 8000' TD - 10,810' KDU 4 add perfs Subject: KDU 4 add perfs Date: Sat, 18 Jan 2003 16:22:08 -0900 From: Tom Maunder <tom_ maunder @admin.state.ak.us> To: Denise Titus <dmtitus @marathonoil.com> Denise, have forwarded the sundry for approval. Please note that the start date in the "bos" is January 15 although you mention January 22 in the letter. Since only 1 commissioner will be here next week, this note is your "verbal" authorization to proceed. Also, we got another fax of the same 403 late in the day on Friday. I cannot see any difference between the 2. Good luck. Tom Maunder, PE AOGCC i Tom Maunder < tom maunder(ab-admin.state.ak.us Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission l 3 'SCANNED FED 1 0 2003 1 of 1 1/18/2003 4:22 PM 'Jan -17 -03 10.31am From - MARATHON'"' A Marathon MARATHDH Oil Company January 17, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 VII 7" Ave Anchorage, Alaska 99501 Reference: KDU 4rd Dear Mr. Maunder: +9155646489 T -746 P.02/05 F -51T Alaska Region Domestic Production P. Box 1961 Anchorage, AK 99519 -6166 Telephone 9971561.5391 Fax 9071564"6489 Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for Marathon well KDU Ord. The proposed work is to add Middle Beluga perforations in the M4, M9, and M10 zones as described in the operations procedure. The proposed start date for this work is January 22, 2003. If you need any additional information, I can be reached at 907 -283 -1333 or by e-mail at dmtitusmarathonoii.com. Sincerely, rte - ��.� Denise M. Titus Production Engineer R P"' �. C E, ,. ',JAN 17 2003 aska Oil & Ga OMRASSIon �� q SCANNED FEB 1 0 20011 " Jan -17 -05 10: Slam From- MARATHON`'" +9155646489 T -746 P.03/05 F -517 STATE OF ALASKA ALA SKA OIL. AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request; Abandon Suspend _ operation Shutdown Re-enter Suspended Well Alter Casing Repair Well Plugging Time Extension Stimulate Change Approved Program Pull Tubing Variance Perforate X Other 2. Name of Operator a. Type of welt: s. Datum Elevation (DF or KE) MARATHON Oil COMPANY Development X 80' GR feet 3. Address Exploratory _ 7. Unit or Property Name P.O. Box 196168, Anchorage, AK 99519 -6168 Stratigraphic Kenai Belu a Unit 4. Location of Well at Surface Servio9 8. Well Number 258' FNL, 4208' FWL, Sec. 7, T4N, R11 W, S.M. KDU 4rd At top of Productive Interval 8, Permit Numb9� 2968 FNL, 114V FWL, Sec. 7, T4N, RI 1W. S.M. 69.12 `� At Effective Depth 10, API Number /� 50 -133 -20176 At Total Dep Ad od Pe Ifo rati o rr 11. Fiel 1 3035' FNL, 805' FWL, S ec. 7, T4N R11W, S.M, Kenai Gas Field 12. Present Well Condition Summary Total Depth: measured 10810 feet � Plugs (measured) 8000' Retainer true vertical 9739 feet 8955' Cement retainer Effective Depth: measured 10711 feet ,funk (measured) 8965' MD (top of abandoned dual completion) true vertical 9643 feet Casing Length Size Cemented Measured Depth True vertical Depth Structural Conductor Surface 1264' 20" 2400sx 1264' 1217' intermediate 6026' 13• -318" 4950sx 6026' 5400' Production 10310 9 -518" 2100sx 10310' 9280' Liner 497 7 130sx 10759' 9688' Perforation Depth: measured 6655' - 6665', 6800' - 680$', 6625'- 6844', 72$4' - 7293', 7340' - 7350', 7668' -7697' true vertical 5970' - 5980 6097- 6105', 6122' -6138% 6510' - 6638', 6577' - 65137', $874 -6902' `Cubing (size, grade, and measured depth) 3 -112 ", 9.2#, N -80, 5720' Packers and SSSV (type and measured depth) Baker 194-40 x 32 SAS packer 0 5579' 13. Attachments Description Summary of Proposal — Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 1S. Status of Well Classification as: 1/15/2001 1 8. If Proposal was Verbally Approved Oil — Gas X Suspended 7~ tiltuc�ro Name of Approver Data Approved Service 17. I hereby ce ify that the foreg is t r y p and correct to the best of my knowledge. Signed 1r � f Denise Titus Title Production Engineer Date 1/17/2003 _VP FOR COMM ISSION USE ON Conditions of Approval: Notify Commission so representative may witness Approval N Plug Integrity BOP Test Location Clearance _ c Mechanical Integrity Test Subsequent Form Required 10- ,1� - © � OR IGINAL SIGNED BY Aep rovod by Order of the Commission M L. S1I1 Commissioner pate Form 10-403 FWY, CBMS ae `- 8ut mit in Trlpilcate FEB D 2 f a MI MS B F I Jan -17 -03 10:31am From - MARATHON ' +9155646489 T -746 P.04/05 F -517 a Marathon Oil Company Alaska Region KDU 4rd Kenai Gas Field, Pad 41 -7 Perforate Object Add Perforations to the M4, M9, and MIO Beluga zones. Procedure: 1. MI.0 MOC flowback iron including choke, gas buster, and an open top tank. 2, MIRU S+chlumberger electric line. 3. 'hest BON and lubricator to 2500 prig. 4. RIH w/ 2 -1 /8" PEJ Strip gun, 6 spf, 0 deg. phase. (Tie in with PDK. —100 log) 5. Perforate as follows: Zone MD M10 6442' -6458' (16') M9 6426' -6441' (15') M4 6150' -6160' (10') M4 6065' -6085' ( 6. RDMO electric line. Attempt flow to tank recording pressures and water volumes, 7. RU CT and jet well in if necessary. 8. Flow well as per engineer's instruction. ,s(;ANNED FEB 1 0 20", 1/17/2003 DMT Jan -17 -03 10:31am From-MARATHON I 'I, Dual Split Hanger (20.5.25.7, 00:8,000, ID:29841 Tubing (25.7.5719.1, OD;3,540. ID:2984) Proguction Casing (0,0- 10310.0, OaEI,025) Intermediate Casing (0.0.6026.0.OD;13.375) y Camco Injeatiom Mandrel (718.7.723.6, 0D;6.844. 113:29$4) Surface Casing (0,0- 1284.0, OD ;20.000) 80 - K.AnChor (6$72,1- 5573.1, 0D•A.750, IQ:3.250) Baker 194 -442 SA (5573.1 -5�•$, Op:8.125, 113 `�C{ i+r'\p.vrti Camw X Nipple (36222 5823.3, 01DA250, 113:2.813) Gamc4 X N (5686.2 - 50$7.2, OD:4.250, 10,2,$13) vAfireline Reentry G 4ide (5719.1 - X719,8, OD:3.876, 110 ;2.984) , v a'A _ bx- 11 h` f M14 Pod (8655.0. 6585.0) -- — L3 Pert (($800.0.8808.0) -- Fracture Treatment (0300.0.5844,0) P elf (662 5.0.6844.0) L9 Part (7254.0 - 7293.0) m - Pelf (7940.0 - 7350.0) _- _ X1 Lis PerF (7668.0. 1478.0) - -- — Red (1663 0.7687.0) Tz Fill (7978.0 - 8000.0, OD:8 681) T ' Retainer (8000.0.6007.0, OD:8.641) e,\ %MR API 50- 133- 201 -01 SCANNED F E B J. 2003 5/15/97 +9155646489 KDU Ord T -746 P.05/05 F -51T Jan -10 -01 02:19pm From - MARATHON 011 +9155646489 T -236 P.07 /11 F -540 , h � I �r 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 Well � Plugging _ Time Extension � stimulate Change Approved Program Pull Tubing Variance PArforate X Other 2. Name of Operator 5, Type of Well: s, Datum levation (DF or KB) MARATHON OIL COMPANY Development X 80' GR feet 7. Unit Or rop®Ry Name 3. A Tess 1_xploratory _ P.O. Box 196168, Anchora e, AK 99519 -6168 Stratigraphic - Kenai Selu a Unit 8. W ell Number 4, location of a at Surface Service 253' FNL, 4,209' FWL, Sec. 7, T4N, R11 W, S.M. KDU 4 At top of Productive Interval 9. Permit Number 2968 FNL, 1145' FWL, Sec. 7, T4N, R11 W, S.M. 69-12 At Effective Depth 1o. API N umber Add Perforations 5 °i . 2o, 76 1 Fi At Total Depth 3035 FNL, 805' FWL, Sec. 7, T4N, F311W, S.M. Kenai Gae Field 12. P resentWell Condition mm miry Total Depth: measured 10810 feet Plugs (measured) 8000' Retainer true vertical 9739 feet 8966' Cement retainer Effective Depth: measurod 10711 feet Junk (measured) 8965' MD (top of abandoned dual completion) true vertical 9643 feet Casing Length $hge Cemented Measured Depth True Vertical Depth Structural Conductor Surface 1264' 20" 2400ax. 1264 1217' Intermediato 6026' 13 -3/8" 4950sx 6026 6400' Production 10310 9-5/6" 2100ex 10310' 9280' liner 497 7 1808x 10759 9688' Perforadon Depth; measured 6655' - 6665', 6800' - 6808', 6825' - 6844', 7264 7293', 7340' - 7350', 7668' -7697' true vertical 6970' - 5980 6097'- 6105', 6122' - 6138', 6610' - 6536', 6577 6597', 6874' -6902' Tubing (size, grade, and measured depth) 3.1/2 ", 9,2 #, N -80, 5720' Packers and SSSV (type and reasurW depth) Raker 194 -40 x 32 SAR packer 0 5579' 13. A ttac ments Description Summary o roposal _ Detailed 5 0 — pe — raTioni Program __... BOP 8keWh 14. Estimated Date far Commencing Operation 15. Status of Well Classification as: 1/15/01 16, If Proposal was erbally Approved Oil Gas�X Suspended Name of Approver Date Approved Service 17, 1 hereby ify that the foregoing Is true and correct to the best of my knowledge. Si nod Denise Titus Title Production E Date 1/9/01 FOR COMMISSION USE ONLY Condltions of Approval: Noti Commission so representative may witness Approval No. SC) r �� Plug Integrity BOP Test Location Clearance Mechanical Integrity Test subsequent Form Required 10 - �AQ 4 � JRkC- INAL SIGNIED 131` A roved t)y Order of the Commission D Tai lc)r SeEll - nou ni Commissione pate v Form 16.403 Rov. 08116/98 sy it l in7 i rlpllcits R IECEVVE�] JAN 1 0 2001 ORIGINAL Alaska Oil � Gas Cons. Commission Anchorage Jan -10 -01 02:19pm From - MARATHON 0,'' +9155646489 A NLarathon Oil Company Alaska Region KDU 4rdw Kenai Gas Field, Pad 41 -7 Perforate Objective: Add Perforations to the M4, M9, and M10 Beluga zones. Procedure: 1. MIRU Schlumberger electric line. T -236 P.08 /11 F -540 2. Test BOPS and lubricator to 2500 psig. 3. R11-1 w/ 2- -118" PEJ Strip gun, 6 spf, 0 deg, phase. (Tie in wiTh PDK —100 log) 4. Perforate as follows: Zone MD M10 6442'-6458' (16') N19 6426' -6441' (15' ) M4 6150'-6160' (10') M4 6065' -6085' (20') 5. RDMO electric line, 6. Flow well as per engineer's instruction. 01108/01, AMT "RECEIVED JAN 1 0 2001 Alaska Oil & Gas Cons. Comrnission Anchorage Jan -10 -01 02:20pm From- MARATHON Oil Dust Split Hanger (20.5,25.7, 013:13.000, Q.2.884) Tubing (25.7 - 5710.1, OD;3,500, ID!2.984) Proauction Casing (0.0- 10310.0, ODt9.626) Intermediate Casing (D.046026.0, 00;18„ 675) Camco Injection Mandrel (716.7 - 723.8, OD:8.844, ID:2,9aa) Surface Casing (0.0- 1264,0, OD:20.000) 80.40 K Anohcr(5572.1.5573.1, 0DA750, 113:3.250) Balmr 194.4k32 SAS Packer (5573.1 - 5578.6, 013:8.125, ID:3.250) Camco X Nipple (5622.2.6623.3, OD;4,250, ID:2.813) Cameo X Nippin (5856.2 - 5587.3, 013:4,250, 12.2.613) 000ne Reenvy Riga (6719.1.5718.8, 01DA675, 113:2.884) +9155646489 T -296 P.09 /11 F -540 KDU Ord M14 P Orf (8655.0- d865,� — Port ("00.0- 6aos.a) U. Fracture Troatment (6800.0-6844.0) — pet} (6825.0 - 6944,E - - -- —„ L9 Perf (7264.0. 7293,0) Porf (7340.0.7350.0) — L10 Pert (768.0.7678.0) NO (7683.0 - 7607,0) Fin (7978.0.8000.0, OU8.661) Retainer (8000- $007.0, 0D,2. "1) API 50 -133- 20176 -01 5116197 rr R E C' E I V E � D JAN 1 0 2001 Alaska Oil &t Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA vIL AND GAS CONSERVATION CO,�,:MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging X Perforate X Pull Tubing X Alter Casing Repair Well _ Other X 2. Name of Operator S. Type of Well: 6. Datum Elevation (DF or KB) Marathon Oil Company Development X 10T KB feet 3. Address Exploratory Unit or Property Name P.O. Box 196168, Anchorage, AK 99519 -6168 Stratigraphic_ Kenai Beluga Unit 4. Location of Well at Surface Service_ 8. Well Number 253' FNL, 4209' FWL, Sec. 7, T4N, R1 1W, S.M. KDU 4rd At top of Productive Interval 2314' FNL, 2329' FWL, Sec 7, T4N, R11 W, S.M. @ 6800' 9. Permit Number /Approval Number - q— 72— At Effective Depth 10. API Number 2624' FNL, 1908' FWL, Sec 7, T4N, R1 1W, S.M. @ 8000' OR 50 -- 133 - 20176 -01 At Total Depth 11. Field /Pool 3034' FNL, 825' FWL, Sec 7, T4N, R11 W, S.M. @ 10810' Kenai Gas Field /Beluga 12. Present Well Condition Summary Total Depth: measured 10810 feet Plugs (measured) 8000'- retainer true vertical 9739 feet 8955'- cement retainer Effective Depth: measured feet Junk (measured) 8965'- top of abandoned dual completion true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface 1264' 20" 2400 SX 1264 1217' Intermediate 6026' 13 -3/8" 4950 SX 6026' 5400' Production 10310' 9 -5/8" 2100 SX 10310' 9280' Liner 497' 7 130 SX 10759' 9688' Perforation Depth: measured See Attached Perforation Summary true vertical Tubing (size, grade, and measured depth) 3 -1/2 ", 9.2#, N -80, 5720' Packers and SSSV (type and measured depth) Baker 194 -40x32 SAB Packer, 5579' U Y p , V z - ,,y 'LANh'd^ w � 13 Stimulation or Cement Squeeze Summary APR 4 Intervals Treated (measured) See Attached Perforation Summary, Operations Summary asbj Q2 5� ati a5 �`G a„ y 3�J'J 4iRNluS d�L Treatment Description Including Volumes Used and Final Pressure Anchorage 14. Representative Daily Average Production or Injection DataProduction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to Well Operation 600 259 Subsequent to Operation 5750 0 0 985 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil _ Gas X Suspended _ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 1 Title F'S, S L* A j Date 11 Form 10 -404 Rev. 06/15/88 Submit in Duplicate OPERATION SUMMARY REPORT WELL: KDU4 W/O . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY 10/07/95 1 0 9.200 ACCEPTED RIG FROM MOB AT 0600 HRS 10 -6-95. BLED ANNULUS FROM 825 PSI TO 0 PSI. SET BPV'S IN BOTH STRINGS. R/U AND CIRCULATED DOWN LONG STRING TAKING RETURNS ON ANNULUS. MONITER WELL, NO FLOW. BUILD MUD VOLUME. CBU. SET BPV'S. N/D TREE. N/U BOP'S. 10/08/95 2 0 9.200 N/U BOP'S. PULLED BPV'S. SET TWO WAY CHECK VALVES. TESTED BLIND RAMS 250/5000 PSI. PULLED TWO WAY CHECK VALVE ON SHORT STRING. M/U LANDING JOINT AND CONTINUE TESTING BOP'S. 10/09/95 3 0 10.000 FINISHED TESTING BOP'S. PULLED SHORTSTRING HANGER AND PUP TO FLOOR. RECOVERED 4.23 R/U ON LONG STRING, RIH WITH JET CUTTER AND CUT AT 9870' WLM. CIRCULATED AND WORKED PIPE. HAD INCREASE IN GAS. SHUT IN WELL. CIRCULATED ON CHOKE RAISING MUD WT IN STAGES TO 10 PPG TO CONTROL BACKGROUND GAS. 10/10/95 4 0 12.000 CIRCULATED ON CHOKE, RAISING MUD WT IN STAGES FROM 10.OPPG TO 11.6 PPG. OPENED HYDRIL. NO FLOW. CIRCULATED AND RAISED MUD WT TO 12.0 PPG. GAS INCREASED. PUT WELL ON CHOKE AND CIRCULATED 12.0 PPG MUD. 10/11/95 5 0 13.000 CIRCULATED ON CHOKE RAISING MUD WT FROM 12.0 PPG TO 12.6 PPG IN STAGES. OPENED ANNULAR AND CIRCULATED. GAS INCREASED TO 3000 UNITS. SHUT IN WELL. CIRCULATED AND CONDITIONED MUD ON CHOKE. RAISED MUD WT TO 13.0 PPG AND CIRCULATED ON CHOKE. OPENED ANNULAR, NO FLOW. STARTED CIRCULATING WITH ANNULAR OPEN. 10/12/95 6 0 13.000 CIRCULATED OUT GAS. RAN FREE POINTS. CIRCULATED OUT GAS. MADE CHEMICAL CUT AT 4477 CIRCULATED AND R/U TUBING HANDLING EQUIP. POOH L/D 3 1/2" TUBING. 10/13/95 7 0 13.000 FINNISHED L/D TUBING. M/U FISHING ASSEMBLY. LATCHED TUBING 4' BELOW WELLHEAD. COULD NOT PULL FREE OR CIRCULATE. MADE GUAGE RUN TO 9840 MADE JET CUT AT 9820 CIRCULATED OUT GAS. RAN FREE POINT TO 9723 POOH WITH FREE POINT. 10/14/95 8 0 13.050 POOH WITH W /L. CHANGED OUT W/L UNITS. RIH AND MADE JET CUT AT 9042 CIRCULATED AND WORKED PIPE. RIH WITH CHEMICAL CUTTER TO 8980 CUTTER MISFIRED. POOH. RIH WITH CHEMICAL CUTTER AND CUT TUBING AT 8982 POOH. TOOLS HUNG UP AT 2734 1476' AND AND STUCK AT 1171 PULLED OUT OF ROPE SOCKET. POOH AND R/D WIRELINE. POOH L/D TUBING. 10/15195 9 0 13.050 FINISHED L/D TUBING. M/U FISHING ASSEMBLY. RIH P/U 5" DRILL PIPE. LATCHED FISH AT 4777 COULD NOT WORK FREE. CBU. 10/16/95 10 0 13.050 CBU. RIH WITH CHEMICAL CUTTER CUT TUBING AT 9025 POOH WITH 5" DP. REPAIRED RIG. POOH L/D TUBING. TESTED BOPE. 10/17/95 11 8982 13.050 FINISHED TESTING ROPE. RIH WITH BIT AND SCRAPER P/U DRILL PIPE. TAGGED UP AT 8965 CIRCULATED OUT GAS. POOH. RIH WITH CEMENT RETAINER AND SET AT 89551. ai OPERATION SUMMARY REPORT WELL: KDU4 W/O . DATE RPT DEPTH I MUD WT. DAILY OPERATIONS SUMMARY 10/18/95 12 8955 13.100 SHEARED OFF OF RETAINER. CBU. SQUEEZED WITH 128 BBLS OF CEMENT. POOH TO 8772 REVERSED OUT. TESTED CASING TO 3000 PSI. POOH. SET RETRIEVABLE BRIDGE PLUG AT 961 N/D BOP STACK. INSPECTED TUBING SPOOL. N/U BOP STACK. TESTED BREAK TO 5000 PSI. 10/19/95 13 8000 13.200 PULLED RETRIEVABLE BRIDGE PLUG. RIH WITH REATINER, SET DOWN AT 180 POOH. RIH WITH BIT AND SCRAPER. CBU. POOH. RIH WITH RETAINER AND SET AT 8000 CIRCULATE. 10/20/95 14 8000 13.200 CIRCULATED. POOH. M/U BIT AND SCRAPER, RIH. TAGGED RETAINER AT 8000' BULLHEADED MUD DOWN LONG AND SHORT STRING OF KDU -2. REVERSED OUT MUD WITH FRESH WATER. PUMPED MUD DOWN SHORT STRING OF KDU-2 TAKING RETURNS UP ANNULUS. NEVER GOT MUD BACK. CLEAN PITS. 10/21/95 15 8000 8.330 CLEANED PITS. PUMPED CAUSTIC SWEEP AROUND. ROUND TRIPPED BIT AND SCRAPER. PUMPED CAUSTIC SWEEP, AND STARTED CIRCULATING SAME AROUND. 10/22/95 16 8000 8.700 CIRCULATED CAUSTIC SWEEP AROUND. TESTED CASING. MIXED AND DISPLACED HOLE WITH 6% KCL. POOH LAYING DOWN DRILLPIPE. 10/23/95 1 17 8000 10/24/95 18 8000 OPERATION SM44ARY REPORT: POST RIG WELL: KDU 4rd DATE RPT .DEPTH MUD; WT.: , DAILY _ OPERATIONS ::SUMMARY .:. 11/4/95 8000' RU WIRELINE AND SWAB WELL DOWN TO 5032'. 11/8/95 8000' RU WIRELINE AND REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE AT 716 11/11/95 8000 RU E -LINE AND PERFORATE 7683 -7697' (L13), 7668 -7678' (L13) W/ 2 -1/8" EJ3, 6 SPF, 45 DEGREE PHASING OFF BOTTOM, 22 GM CHARGES. Q= 887 MSCFPD, 470 PSIG WHP. 11/14/95- 8000' MU TANDEM ELECTRONIC GAUGES AND OBTAIN FBHP SURVEY 11/17/95 AND 72 HR PBU. Q= 887 MSCFPD @ 61% DD. 11/18/95 7500' RU CT AND PLACE SAND PLUG ACROSS L13. TAG PLUG AT 7500'. 11/19/95 7500' RU E -LINE AND PERFORATE 7264 -7293' (L9) W/ 2 -1/8" EJ3, 6 SPF, 45 DEGREE PHASING OFF BOTTOM, 22 GM CHARGES. 11/24/95 7500' MU TANDEM ELECTRONIC GAUGES AND MAKE SBHP SURVEY. 11/25/95 7500' RU E -LINE AND PERFORATE 7340 -7350' (L10) W/ 2 -1/8" EJ3, 6 SPF, 45 DEGREE PHASING OFF BOTTOM, 22 GM CHARGES. Q= 2.0 MMSCFPD, 9 BWPD, 275 PSIG WHP. 12/2/95 7620' RU CT AND ATTEMPT TO PLACE SAND PLUG ACROSS L9 /10. NOZZLE PLUGGED AT THE BEGINNING OF THE JOB RESULTING IN ABANDONING JOB. TAGGED FILL AT 7620 12/9/95 7126' RU CT AND PLACE SAND PLUG ACROSS L9 /10. TAG FILL AT 7126 PU TO 6500' AND BLOW FLUID OUT OF CT AND TUBING W/ N2. 12/10/95 6978 RU E -LINE AND PERFORATE 6825 -6844' (LOWER L3) W/ 2 -1/8" EJ3, 6 SPF, 45 DEGREE PHASING OFF BOTTOM, 22 GM CHARGES. TAG FILL AT 6978 Q= 550 MCFPD, 300 PSIG WHP. 12/13/95 7031' MU TANDEM ELECTRONIC GAUGES AND MAKE SBHP SURVEY. 12/15/95 6983' RU E -LINE AND PERFORATE 6800 -6808' (UPPER L3) W/ 2 -1/2" HOLLOW CARRIERS, 6 SPF, 60 DEGREE PHASING, 10.5 GM CHARGES. TAG FILL 6983'. Q= 761 MSCFPD, 1120 PSIG WHP, 0 BWPD. 12/26/95 >7000' RU FRAC EQUIPMENT AND FRAC L3 W/ 567000 20 40 CARBOLITE. RU E -LINE AND ATTEMPT TO PERFORATE M -14. TAGGED FILL AT 6601' - TOO HIGH. ABANDON PERF RUN. RU CT AND CLEAN OUT WELLBORE TO 7000 DISPLACE COIL AND TUBING W/ N2 FROM 5700 - 7000 Q= 1004 MSCFPD, 1175 PSIG WHP, 0 BWPD. 1/3/96 6820' RU WIRELINE AND REPLACE DUMMY VALVE W/ CHEMICAL INJECTION VALVE AT 717 TAGGED FILL AT 6820'. 1/23/96 6772' RU WIRELINE AND TAG FILL AT 6772'. �g1yy JJJ t.1Wi1 �AVF11A ^G tll LN1Mta k tv, i ]ICJI:91 ' �- i' mi l, v 4 I SM OPERATION SUMARY REPORT: POST RIG WELL: KDU 4rd DATE RPT DEPTH MUD WTu`. DAILY'OPERATIONS SUMMARY 2/6/96 6772' RU E -LINE AND PERFORATE 6655 -6665' (M -14) TWICE, W/ 2 -1/2" HOLLOW CARRIERS, 6 SPF, 60 DEGREE PHASING, 10.5 GM CHARGES. Q= 1.5 MMSCFPD, 2150 PSIG WHP, 0 BWPD. 3/1/96 6811' RU TANDOM ELECTRONIC GAUGES AND OBTAIN SBHP AND 4 POINT. AOF = 8.2 MMSCPFD. 0 , mss rev. 3/30/1996 KDU 4rd PERFORATION SUMMARY PERFORATIONS DATE MD TVD FOOTAGE SAND SPF GUN TYPE SQUEEZED: 10/18/95 9937 -9947' 8940 -8949' 10' D -2 4 10/18/95 9952 -9986' 8954 -8984' 34' D -2 4 10/18/95 9994 - 10002' 8991 -8998' 8' D -2 4 10/18/95 10258- 10279' 9229 -9248' 21' D -3 4 10/18/95 10428 - 10470' 9385 -9421' 42' D-4 4 10/18/95 10430 - 10440' 9385 -9394' 10' D-4 4 10/18/95 10480 - 10490' 9432 -9441' 10' D-4 4 NEW PERFS: 11/11/95 7683 -7697 6897 -6910' 14' L13 6 2-1/8" EJ3 11/11/95 7668 -7678' 6884 -6893' 10' L13 6 2-1/8" EJ3 11/19/95 7264 -7293' 6519 -6545' 29' L9 6 2-1/8" E.13 11/25/95 7340 -7350' 6588 -6597' 10 L10 6 2 -1/8" EJ3 12/10/95 6825 -6844' 6132 -6149' 19' LOWER L3 6 2 -1/8" EJ3 12/15/95 6800 -6808' 6109 -6116' 8' UPPER L3 6 2 -1/2" HC 2/6/96 6655 -6665' 5980 -5989' 10' M14 12 2 -1/2" HC 0 , mss rev. 3/30/1996 KDU Ord •...•......•• ............ Dual Split Hanger: 25.7 (OD:8.000 ID:2.992) ..........•------- ---- - -- ---- .. .... SL .................................................................................................................................................. .... ..... ........................................... PRODUCITON CASING: 10310.0 (OD:9.625) ..... .................................... ..................................... ............................................. SURFACE CASING: 1264.0 (OD:20.000) ------------------------ .... ................................... ---------- Tubing: 25.7-716.7 (OD:3.500 ID:2.992) ............................................... .................................................................................................. ---- . ..... ........................................... INTERMEDIATE CASING: 6026.0 (OD:13.375) .................................................................................................................................................. .... ................................................................................................................................................... .... ................... ................... ------------------------------------------ * -------- * -------- * --------------------- * .. .... ........................................... ---------------------------------------------------------------------------------------------------------------------------------------------------------- E . ..................................................... ................................................................................. .............................. ................... ---------- - -------- * ----------------------------------------------- ............................................... ......................................................... ------------ * ----------- -------------- ---------------------- * ---------- ------------------------------- Tubing: 723.6-5572.1 (OD:3.500 ID:2.992) . ...................... ............................... ......................................................................................................................................................... . ........... ............................... ......................................................................................................................................................... . ...................... ............................... ....................... ....................... ............................................................................. - ........... .............. ........ I ......................................... ................................................... ............................. . ..................... ............... ............ ........................ ....................................... ........ 80-40 K-Anchor: 5572.1-5573.1 (OD:4.750 ID:3.250) Py ............... ...... ............ . Baker 194 -4x32 SAB Packer 5573.1- 5578.6 (0 D: 8 12 5 ID:3.250) . ..................................................... .......................................................................... .............................................................................. ----------------------------- Tubing: 5578.6-5622.2 (OD:3.500 ID:2.992) ........................ ...... ...... . ...................... ............................... ....................................................................... ........................................ ........................................ ............ Camco X Nipple: 5622.2-5623.3 (OD:4.250 ID:2.813) .................................... . . ............................................... ..................................................... ............................. Tubing: 5623.3-5686.2 (OD:3.500 ID:2.992) ................................... ....................................................................... ................................................................................. . ..................................................... ......................................................................................................................................................... ....................... ............................................. I ......................... ......................................................... Camco X Nipple: 5686.2-5687.2 (OD:4.250 ID:2.813) ............... ............................................................................... .......... ............ ................................. . . ..................................................... ..................................................... Tubing: 5687.2-5719.1 (OD:3.500 ID:2.992) ....................... ....................................................................... ......................................................... . ..................................................... ................................................... ................................................................................................. ............................................................................................... ....................... ................................. Wireline Reentry Guide: 5719.1-5719.8 (OD:3.675 . . ..................................................... ..................................................... .............. ID:2.992) •.................................. . ..................................................... ...............• ........................................................................................................................................ . ..................................................... ......................................................................................................................................................... . ..................................................... ......................................................................................................................................................... . ..., ................................................. . ..................................................... ................................................................................................................................... ..................... . ..................................................... ......................................................................................................................................................... ......................................................................................................................................................... ............................................ ........ ......................................................................................................................................................... .......................................................... ......................................................................................................................................................... ........................._ .......I....................... . ......................................................................................................................................................... ......... - ............................................... ....................................................................................................................................................... - ....................................................... . ... ........................................................................................................................................................ .......................................................... ........................................... ............................................................................................................. ............ I .......................................... - ......................................................................................................................................................... ........ I ..... I ........................................... ......................................................................................................................................................... . .................................................. Perf 6655.0 - 6665.0 ............................................................................................................................................... ........ . .................................................. ......................................................................................................................................................... . .................................................. ......................................................................................................................................................... .......................................................... ........................................ ........................................................................................................................................................ ................. . ....................................................................... ................................................................................. .............................................. Fracture Treatment 6800.0 - 6844.0 . .............................................. • ...... ........................................................................................... ............................................................. Perf 6800.0 - 6608.0 .... .................................................... ................................................................................................................ •.•••..••............................... ..................................................................••••• .•. Perf 6825.0 - 6844.0 ....................•.............. .... ... ................................................ .................................................. ......................................................................................................................................................... 'i ......................................................................................................................................................... .......................................................... ......................................................................................................................... ....... .................... .......................................................... ......................................................................... ... * .......... * ....... ... .. .. . .................................................. 930 ---------- Perf 7264.0 - 72. ............................................................................................................................................................ .................................................. ......................................................................................................................................................... . . ................................. ................ ........................................... 0 ............................................................. ............................................ WE .. .................................................. Perf 7340.0 - 7350.0 ......................................................... ............................................................................................... .......................................................... ................................................... .......................................................................................................................................................... ......................................................................... Perf 7666.0 - 7678.0 .................................... .......................................................................................................................................................... .................................................. Perf 7683.0 - 7697.0 .......................................................... ......................................................................................................................................................... .......................................................................................................................................................... ........................... ............................... .......................................................... ......................................................................................................................................................... ....................................................................... .................................................................................. .............................. ........................... ..................................... .................................................................................................................... .......................................................... ................ .......................................................................................................................................................... ......................................... Retainer: 8000.0-8007.0 (OD:8.641) .... ... .........................................................•. ........................................................................................................................ ................................. weliview 5.0 60-133-20176-01 4/1/96 Alaska, jion Domestic Production M Marathon MARATHON Oil Company March 11, 1996 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: RLE Please find attached a completed Gas Well Open Flow Potential Test Report for Kenai Gas Field Well KDU 4rd. The test was completed on March 1, 1996. Marathon respectively requests this information be kept CONFIDENTIAL for a period of two years for strategic planning purposes. Sincerely yours, J _ Michael J. Stover Advanced Reservoir Engineer NJS/kz:ENG\-A0GCC2.LTR Attachment P.O. Box 196168;(1, +' Anchorage, AK 99519 -6168 Telephone 907/561 -5311; —� 1 3 1196 .. . .. A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a. TEST: INITIAL X hwPm 1b. TYPE TEST STABLILIZED NON STABILIZED ANNUAL Gravity Factor Fg MULTIPOINT X7 CONSTANT TIME Rate of Flow 0, Mcfd 1. SPECIAL 41.8 OTHER ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company 69-12 3. Address 8. API Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503- 3934 50- 133 -20176 4. Location of Well 9. Unit or Lease Name At surface Kenai Beluga Unit 10. Well Number 253' S 8 4209 E from NW comer, Section 7, T4N, R11 W, S.M. KDU Ord 0.9840 11. Field and Pool 666.26 Kenai Gas Field 5. Elevation in feet (KI3, DF etc.) 6. Lease Designation and Serial No. 95' KB A -028142 0.9786 12. Completion Date 13. Total Depth 14. Plugback T.D. 15. Type Completion (Describe) 11/95 8,000' 6,811' (Fill) Single tbg. string /cased hole 16. Csg. Size Weight per foot, lb. I. D. in inches Set at ft. Perforations: From To 9 5/8" 40,43.5,47# - 10,310' 6655 -6665' 6800 -6808' 6825 -6844' 7264 -7293' 17. Tbg. Size Weight per foot, lb. I. D. in inches Set at ft. 7340 -7350' 7668 -769r 3 %w 9.210 2.992 5720' 18. Packer set at ft. 19. GOR cf/bbl. 20. API Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 5573' - - 0.5611 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. XK Csg. ❑ 114 33 14.73 23. Length of flow channel (L) Vertical Depth (H) Ga. % CO2 % N2 % H2S Prover Meter run I Taps 5720' 5141' 0.204 0.58 0 X 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow NO (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1.1 3 X 13164 265.2 6.6 70 1850 53 - - 2.139 2. 3 X 16/64 265.2 6.4 74 1740 53 -- -- 2.050 3. 3 X 19.75/64 270.4 5.1 77 1580 53 -- -- 2.242 4. 3 X 23.25/64 280.9 6.1 83 1300 53 -- -- 2.011 5. X No. Basic Coefficient (24 -Hour) Fb or Fp hwPm Pressure Pm Flow Temp. Factor Ft Gravity Factor Fg Super Comp. Factor F v Rate of Flow 0, Mcfd 1. 48.6 41.8 279.9 0.9905 1.335 0.5611 2,030 2. 70.6 41.2 279.9 0.9868 1.335 2,910 3. 109.2 37.1 285.1 0.9840 1.335 666.26 4,050 4. 120.8 41.4 295.6 0.9786 1.335 343.13 5,000 5. No. Pr Temperature T Tr Z for Separator Gas Gg for Flowing Fluid G 1. 0.3980 530 1.545 0.9641 0.5611 2. 0.3980 534 1.556 0.9650 3. 0.4059 537 1.565 0.9650 lCritical Pressure 666.26 4. 0.4216 543 1.582 0.9649 lCritical Temperature 343.13 5. Form 10-421 Rev. 7 -1 -80 kz1NOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate t Pc 2,000 Pc= 4,000,000 Pf 2,334 Pf 5,447,556 No. Pt Pte Pc= - Pt Pw Pw Pct - Pw Super compressibility factor = J 1 /Z dimensionless Ps Ps Pf - Ps 1.1 1,850 3,422,500 577,500 — — — GOR 2,085 4,347,225 1,100,331 2. 1,740 3,027,600 972,400 — — — 1,950 3,802,500 1,645,056 3. 1,580 2,496,400 1,503,600 — — — Shut -in pressure at vertical depth H, psis 1,768 3,125,824 2,321,732 4. 1,300 1 1,690,0001 2,310,000 — — — Pt 1,507 1 2,271,0491 3,176,507 5. r ., yc �� Q Rate of flow, Mcfd (14.65 psia and 60 0F.)'w °wi'� ym,wJ Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin 25. AOF (Mcfd 8,170 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed � u Title Reservoir Engineer Date n 0.8643 3/8/96 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure Recommended procedures for tests and calculations may be found in the MANUAL OF BACK - PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev. 7 -1-80 kz1AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate opposite the producing face were reduced to zero psia. Fb Bask: orifice factor Mcfd/ 4 hw /Pm Fp Bask: critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor = J 1 /Z dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air = 1.00), dimensionless Gg Specific Gravity of separator gas (air = 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equiation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia iu Pf Shut -in pressure at vertical depth H, psis Pm Static presssure at point of gas measurement, psis"' ° '� � Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia I ;; Pt Flowing wellhead pressure psia Pw Static column wellhead pressure corresponding to Pt, psia r ., yc �� Q Rate of flow, Mcfd (14.65 psia and 60 0F.)'w °wi'� ym,wJ Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK - PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev. 7 -1-80 kz1AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate I KDU #4rd - L3/M14 (3/1/96) Pwf Pr Pres. Drop Downhole Results 4 -Point Test Results (psia) (psia) (psia) Drawdown ACTUAL Q Pwf Pr Pres. Drop Actual Actual Calc. Regression (mscfd) (psia) (psia) (psia) (Q) (Pr - 2 -Pwf "2) C (Q) 2,030 2,085 2,334 249 2,030 1,102,148 0.0122 2,053 2,910 1,950 2,334 385 2,910 1,647,236 0.0123 2,905 4,050 1,768 2,334 567 4,050 2,324,547 0.0127 3,913 5,000 1,507 2,334 827 5,000 3,177,606 0.0120 5,126 M= 1.1570 (psi - 2 /mcf) 7,727 584 Ave. Coeff. C 0.01236 75.00 1 /m = n = 0.8643 (mcf /psi - 2) 2,334 2,334 Regression 'C' 0.01231 AOF = 8,170 mscfpd KDU 4rd - L3 /M 14 03/01/96 10,000,000 I ca N . Q N 1,000,000 3 a N c L CL 100,000 1000 10000 Q, (mscfpd) • 4 -Pt. Test Regression Q Pwf Pr Pres. Drop % (mscfd) (psia) (psia) (psia) Drawdown ACTUAL 2,030 2,085 2,334 249 10.68 2,910 1,950 2,334 385 16.47 4,050 1,768 2,334 567 24.28 5,000 1,507 2,334 827 35.44 PREDICTION 51555 1,401 2,334 934 40.00 6,372 1,167 2,334 1,167 50.00 7,027 934 2,334 1,401 60.00 7,727 584 2,334 1,751 75.00 8,170 0 2,334 2,334 100.00 h:\excel\kenai\belugaKDU44PT.XLS 3/8/96 MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519 -6168 Telephone: (907) 561 -5311 Fax: (907) 564 -6489 Letter of Transmittal March 12, 1996 TO: Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 WELL LOGS Description Kenai Gas Field � r' KDU -4RD COMPLETION RECORD 2.5" HSD KBU 41 -7 COMPLETION RECORD l Beaver Creek Field BC -6 COMPLETION RECORD FROM: Chick Underwood Exploitation Department Print Film 2/6/96 1 1 2/8/96 1 1 2/4/96 1 1 TOTAL 3 This data is considered confidential until the normal release date. G (Marathon Oil) (RecellGee' - By) 3 �" (Date) (Date) MAR 1219'6 Alaska all & Gas Cons. COrllry lsSlo Anchorage i MARATHON OIL COMPANY 3201 C Street, Suite 800 P.O. Box 196168 Anchorage, Alaska 99519 -6168 Telephone: (907) 561 -5311 Fax: (907 564 -6435 Letter of Transmittal January 2, 1996 TO: Howard Okland Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Description I KDU -4RD PERFORATING RECORD PERFORATING RECORD K 31 -7RD PERFORATING RECORD PERFORATING RECORD " MULTIPLE ISOTOPE SPECTROSCOPY KBU 41 -7 SQUEEZE GUN " CEMENT RETAINER The data is considered confidential u FROM: Chick Underwood Exploitation Department Print 11/11/95 1 11/25/95 1 10/26/95 1 11/06/95 1 11/26/95 1 12/12/95 1 12/12/95 1 TOTAL 7 ntil the normal release date. CA r (Marathon Oil) //2 / (139(ce )Med By) (Date) (Date) Please Return 1 Copy by Either FAX or Mail to Marathon Film 1 1 1 1 1 1 1 7 Ki=L;tivF-D JAN Q 2 1"6 Alaks nil & Gas Cons. Commission Anchorage STATE OF ALASKA A y5i., OIL AND GAS CONSERVATION COMt 1.__ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation shutdown — Re -enter suspended well _ Alter casing _ Repair well _ Pluggin Time extension __ _ Stimulate )L Change approved program Pull tubing Variance _ Perforate X Other X__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Company Development Exploratory Stratigraphic 107' KB feet 3. Address 7. Unit or Property name P.O. Box 196168, Anchorage, AK 99519-6R67 Service Deep Unit 4. Location of well at surface 8. Well number 253' FNL, 4209' FWL, Sec. 7, T4N, R11W, S.M. KDU 4RD 9. Permit number At top of productive interval 2968' FNL, 1145' FWL, Sec. 7, T4N, R11W, S.M. 69 -12 10. API number At effective depth O RIG I NAL 50— 133 -20176 At total depth 11. Field /Pool 3035' FNL 805' FWL Sec. 7 T4N R11W S.M. Kenai Gas Field 12. Present well condition summary Total depth: measured 10 '1 810 feet Plugs (measured) true vertical 9,739 feet Effective depth measured 10,711 feet Junk (measured) Top of fill - 10 MD (1993 ) true vertical 9 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1264' 20:" 2400 SX 1264' 1217' Intermediate 6026' 13 -3/8 "' 4950 SX 6026' 5400' Production 10310' 9 -5/8" 2100 SX 10310' 9280' Liner 497' 7" 130 SX 10.759' 9688' Perforation depth: measured RE CE IV E D true vertical See Attached M AY 15 1995 M L.S. 3 -1/2 ", 9.2 # N -80 to 10,400 Tubing (size, grade, and measured depth) S . S . 3-1/2" 9.2 # N -80 to 9892' Alaska Oi & Gas Cons. COMM II Anchora Packers and SSSV (type and measured depth) 1. Gui berson Model RH -2 Dual-9875' MD 2. Guiberson Model RH -1. Single- 10,341' MD 13. Attachments Description summary of proposal _._ Detailed operations program _L BOP sketch X- 14. Estimated date for commencing operation 15. Status of well classification as: 8 -1 -95 Oil _ Gas X Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 1 Title A-1 ,,,..?5 Jd,. Date jk . F07MOMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. S .- Plug integrity �e' BOP Test .L`'' Location clearance _.._ Mechanical Integrity Test T Subsequent form required 10- Approved Copy Original Signed By a Ap proved by order of the Commissioner DaVid W. Johnston . Date Form 10 -403 Rev 06115/88 SUBMIT IN TMPL.ICATE s Form 3160 -5 r'. - D STATES OUBMIT IN T .l" ' TE• IMay lyxy) DEPAR_._j% . OF THE INTERIOR veerse aidejatruc re- T : BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT —' for such proposal,.) NORM APPROVED OMB NO. 1004 4)135 I:.xpires: September 30, 1990 5. LEASE DESIGNATION AND 4181IAL I90. A- 028142 _ B. IF INDIAN, ALLOTTEE OR T =INE NAME 1. 7. UNIT AGREEMENT NAME OIL WE El WEL ® Kenai Deep Unit WELL WELL OTHLR 2. NAME Or OPERATOR 8. FARM OR LEASE NAYS Marathon Oil Company 3. ADDRESS Or OPERATOR 9. WELL NO. P.O. Box 196168, Anchroage AK 99519 -6168 KDU 4 4. LOCATION OF N% ELL (Report location clearly and to accordance with any State requirements.• 10. FIELD AND POOL, OR WILDCAT See also space 17 below.) At surface Kenai Gas Field 253' FNL, 4209' FWL, Sec. 7, T4N, R11W, S.M. „C., T., R., M.. OR ELK. AND SURVEY OR ARIOA Sec. 7, T4N, R11W, S.M. 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. COUNTY OR PAAISj 13. S1TATZ 69 -12 I 107' KB Kenai AK 18. Check Appropriate Box To Indicaiie Nature of Notice, Report, or Other Data NOTICE Or INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT -OFF PULL OR ALTER C %SING X WATER SHUT -OFF REPAIR!NO WELL FRACTURE TREAT X \It LTIPLE ro%iPI.ETE X FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CRANGE PLANE (Other) (Other) (NO 'N O letRn or Re pt re m ultiple completion on Well p p letio port and Log form.) 17. DESCRIBE rrinruSED OR Co.NIPLETEI) 01'F:RATIO',f Wlearl.v state all pertinent details. and give pertinent dates, Including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and menstired and true vertical depths for all markers and ;ones perti- nent to this work.) • See attached addendum. RECEIVED MAY 15 1995 Alaska Ui1 & Gas Cons. Commission 18. I hereby certify that the foregoing is true and correct SIGNED TITLE DATZ (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side DATE Title 1S U.S.C. Section 1001, ;Oakes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, : icutleus cr `raudulent statements or representations as to any :natter wlth;n its Jurisdiction. KDU 4RD PERFORATIONS 9937' - 9947' 10' 4-1/2" HPF D -2 S.S. 9952' -9986' 34' 4-1/2" HPF D -2 S.S. 9994'- 10,002' 8' 4-1/2" HPF D -2 S.S. 10,258'- 10,279' 21' 4 -1/2" HPF D -3 S.S. 10,428' - 10,470' 42' 4-1/2" HPF D -4 L.S. 10 - 10,440' 10' 4-1/2" HPF D -4 DST L.S. 10,480' - 10,490' 10' 4-1/2" HPF D -4 DST L.S. All depths measured. Sand Tops: D -2 9925' M D D -3 10,239' MD D -4 10,428' MD ,Note SBHP = 815 psi 8 -17 -93 8922' TVD 9207' TVD 9379' TVD RECEIVED MAY 15 1995 Alaska OU & Gas Cons. Commission /nrs ra ;��, G: \CMN \DRLG \4RDPERF 7� 7 1� mom Existing Wellbore Schematic WELL KDU �4 IV V� A 1x 2 B o C D 3 x D-2 Sd. 4 D-3 Sd. "' 5 VII ex 7 8 0 9 D -4 Sd. VIII IX CASING a ABANDONMENT DETAIL 1. Elevation of Kelly Bushing at 0.0' I. Cameron Dual 3-1/2" Tubing Hanger at 13.20' III. 30', 1/2" Wall, Set in Clay at 41' IV. 20'. 941. H-40. 8rd ST &C Casing at 1.264' V. 13 -3/8'. 61*, J -55. Seailock Casing at 6.026' VI. Top of 7' Liner at 10.263.24' VII. 9 -5/8 43.5*,47*,53.5t, N-80,P -110 Casing at 10.310.00' Vlll. E.T.D. Top of Cement at 10,711' IX. 7', 291. N-80 Buttress Casing w /Mule Shoe at 10.759.78' TUBING DETAIL LONG STRING: 3 -112", 9.2 *, N -80 TUBING 1. Otis 'XO' Sleeve at 9,862.26' 2. Guiberson Model 'RH -2' Dual Packer at 9,874.85' 3. Otis 'XO' Sleeve at 9,915.75' -� 4. Blast Joints From 9,919.43' to 10.017.83' 5. Blast Joints From 10.233.18' to 10.292.18' S. Otis 'XO' Sleeve at 10.354.56' 7. Gulberson Model '131-1-1' Hyd. Packer at 10.391.30' 8. 'O' Nipple at 10.397.85' 9. Bottom of Shear Sub at 10,399.98' SNORT STRING: 3-112 9.2 #, N -80 TUBING A. Otis 'XO' Sleeve at 9,811.82' B. Guierson Model 'RH -2' Dual Packer at 9,877.70' C. 'Q' Nipple at 9.888.00' 0. Bottom of Shear Sub at 9,891.73' PERFORATION RECORD DATE INTERVAL CONDITION 6/17/69 10,480'- 10,490' DST D -4 Sd. 10,430' - 10,440' 6/18/69 10,428' - 10,470' D -4 Sd. Production 10,258' - 10.279' D -3 Sd. Production 9.994' - 10,002' D -2 Sd. Production 9,952'- 9,988' D -2 Sd. Production 9,937' - 9,947' 0 -2 Sd. Production * NOTE: Fill Tagged at 10,468' 718184 RECEIVED MAY 15 1995 Alaska Oil & Gas Cons. Commission Anchora -,- -� npawn B.A.W. ern i" WORKOVER PROCEDURE FOR KDU 4RD 1. R/U slickline. Open sliding sleeves at 10,355' AND 9915'. Close sliding sleeve at 9862' . 2. Bullhead KWM down long string. 3. Open sliding sleeve at 9862' and fill annulus and short string with KWM. 4. Set BPV in both strings. 5. Move in and R/U workover rig. 6. N/D tree. N/U BOP's and test to 250/3000 psi. 7. Clean out wellbore to 8500. 8. RIH w /retainer and set at 8500'. Squeeze off perforated intervals with 750 SX cement. (892 ft 3 ) Leave 75' cement on top of retainer. 9. Set production packer at 6000. 10. Run 3-1/2" production tubing. Set BPV. 11. N/D BOP's. N/U tree and test. 12. R/D and move out workover rig. 13. Perforate and evaluate L. Beluga (1-12 -15) 7594' to 7772. 14. Perforate and evaluate L. Beluga (1-9 -10) 7264' to 7350'. 15. After evaluation, sand back L. Beluga, perforate M. Beluga (M14 -1-3) 6642'- 6844'. 16. Evaluate M. Beluga Frac if required. 17. R/U CTU for clean up and flow tests. 18. Produced M -14 through L -15 commingled. /nrs G: \CMN \DRLG \4RDWOP RECEIVED MAY 15 1995 Alaska Oil & Gas Cons. Commission Anchora, KENAI GAS FIELD KDU 4 PROPOSED WELLBORE SCHEMATIC - AKR rm !1' HGR @ 13.2' 30 ", 1/2" wall @ 41' 20 ", 94 ppf, h40, 8rd ST &C Csg @ 1,264' Ab 13 3/8" 61 & 68 ppf, K55 @ 1,400' 3 1/2" tubing Packer set approximately 6,000' MD An initial Lwr /Mdl Beluga M14 -1-15 (6,642' — 7,772' MD) completion is envisioned. A portion of that interval, the Beluga M14 -1-3 (6,642' — 6,844' MD) will most likely be fracture stimulated. Additional M. Beluga M4 -10 (6,073'- 6,465' MD) is available uphole. andon hole below 8.500 MD 7" liner top @ 10,263' MD 9 5/8 ", 43.5, 47,53.5, N -80, P110 casing @ 10,310' 7 ", 29 ppf, N -80 liner @ 10,760' MD CAM 3/02/95 RECEIVED MAY 15 1995 Alaska .Oil & Gas Cons. Commission Anchom 'n ° o 6 , ° ° p0 • Abandon Tyonek D -2 Abandon Tyonek D -3 ° • ° °' o ° ° i °o. Abandon Tyonek D -4 •,i , °''° ° °a 13 3/8" 61 & 68 ppf, K55 @ 1,400' 3 1/2" tubing Packer set approximately 6,000' MD An initial Lwr /Mdl Beluga M14 -1-15 (6,642' — 7,772' MD) completion is envisioned. A portion of that interval, the Beluga M14 -1-3 (6,642' — 6,844' MD) will most likely be fracture stimulated. Additional M. Beluga M4 -10 (6,073'- 6,465' MD) is available uphole. andon hole below 8.500 MD 7" liner top @ 10,263' MD 9 5/8 ", 43.5, 47,53.5, N -80, P110 casing @ 10,310' 7 ", 29 ppf, N -80 liner @ 10,760' MD CAM 3/02/95 RECEIVED MAY 15 1995 Alaska .Oil & Gas Cons. Commission Anchom 'n EXHI IT A ECT1ON I PROPOSED BOP STACK CONFIGURATION 13 5 f B RSRRA CHOKE WING ucm 4 1111r-5 TYPE E CATS IAL1E HYDRn. 13 5 f 5' -waan GK ANNULAR BOP SCREW HEAD 13 5 15'- 10.90WSI HUB BM= CONNEC cm Ran 13 sle -5pon DOUBLE RAY BOP HUB CONNEC GNS 4 1/19- 5.000PSf SIDE OUXEM WITH MANUAL LQC* KILL WING `�--- YcE101' 3 1 /1a'— SAaoPS1 TYPE E GATE VALVE HYDRIL 13 5/8'- 5 NPL RAAf BOP HUB CONNECMNS 4 1/16'- 5.000M SIDE OU'i1M INTH MANUAL LDCKSS BLOW -our PREVENrER STACK PAA WORKOVER RIG RECEIVED MAY 15 1995 Alaska Oil & Gas Cons. Commission Anchorpa r, 13 5 /a'- 5.000Ps1 x 11'- �ao0 xa STATE OF ALASKA ALA�rCA OIL AND GAS CONSERVATION COMMIS�tON V'~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development AL) Exploratory Stratigraphic X _ feet 3. Address 7. Unit or Property name P.O. Box 190247, Anch, Ak-, 99919-1719A7 Service _ 4. Location of well at surface 8. Well number 253' S & 4209' E from NW cor., Sec. 7, T4N, R11W, S.M. 4L 9. Permit number /approval number At top of productive interval 2745' S & 3280' W of surface 69 -12 — 816 At effective depth 10. API number 50133 -20176 At total depth 11. Field /Pool 2764' S & 3406' W of surface Kenai Gas Field 12. Present well condition summary Total depth: measured 10810' feet Plugs (measured) true vertical 9739' feet Effective depth: measured 10711' feet Junk (measured) None true vertical 9643, feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1264' 20" 2760 CF 1264' 1217' Intermediate 6026' 13 -3/8 5701 CF 6026' 5400' Production 10310' 9 -5/8" 2430 CF 10310' 9280' Liner 497" 7 130 SXS 10759' 9688' Perforation depth: measured true vertical See attached Tubing (size, grade, and measured depth) 3 -1/2 9.2 #, N -80 to 10400' MD Packers and SSSV (type and measured depths . Guiberson model RH - dual - 987 5 ' MD D KE IV E 13. Stimulation or cement squeeze summary T 19 19$9 OC Intervals treated (measured) See Attached History bask 4.0ij ,& Gas Cons., CoMMISS1 Treatment description including volumes used and final pressure + ...,i tnChOB ag� ' 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 700 2 0 ±360 Subsequent to operation 0 1,400 0 0 +360 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations x Oil _ Gas x Suspended -! Service 17 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 0 ' L Sig ned Title Environmental Engineer Date 10 18/89 Form 10 -404 Rev 06/15/88 Roy D. Roberts 0 SUBMIT IN DUPLICATE UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of LEASE KENAI DEEP UNIT WELL NO. KDU -4 FIELD KENAI UNIT DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 10/02/89 10460' ETD CTM MIRU coiled tubing and nitrogen equipment. Test BOPE to 5000 psi -OK. RIH with 1 -1/4" coiled tubing and 1.5" wash nozzle. Circ with foam at 4500' CTM. RIH with foam to obstruction at 10460' CTM. Could not work thru with wash nozzle. Attempted several fluid sweeps without success. POH. RIH with 1 -1/4" C.T. and 1 -3/4" mud motor and 2.00" flat bottom mill. Tagged obstruction at 10460' CTM. Could not drill thru using either foam or 3% KCL water. Burned out motor pumping foam. POH for new motor. 10/03/89 10460' ETD CTM RIH with 2 -3/8" mud motor. Tagged fill at 10460' CTM and cleaned out with water to 10500 Saw pressure fluctuations on the short string and stopped cleaning at 10,500 Did not get sand returns to surface water only. POOH. RIH with a wash nozzle and tagged fill at 10,502' CTM. POOH to 4000' and RIH blowing the well dry with nitrogen to 10,350' CTM. Placed the L.S. in the test separator and choked to 1200 psi. Switched S.S. to the return tank. RIH and tagged fill at 10,500' CTM. POOH. RDMO. Released rig at 2100 hrs. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 U APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation shutdown _ Re -enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other-IL 2. Name Operator Oil 5. Tyy e of Well: 6. Datum elevation (DF or KB) neon Company of California (UNOCAL) Development X Exploratory _ Strati ic_ 80' GR feet 3. Addres�.0. Box 190247, Anch, Ak. , 99519-0247 7. Unit Rena� e D'eep %nit Servi_ Servi ce 4. Location of well at surface 8. Well number 253' S & 4209' E from NW cor., Sec. 7, T4N, R11W, S.M. 9. Permit number At top of productive interval 2745' S & 3280' W of surface 69 -12 10. API number At effective depth 50 - 133 - 20176 At total depth 11. Field /Pool 2764' S & 3406' W of surface Kenai Gas Field 12. Present well condition summary Total depth: measured 10810' feet Plugs (measured) true vertical 9739 feet Effective depth: measured 10711' feet Junk (measured) Top of fill-10460 MD true vertical 9643' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1264' 20" 2760 CF 1264' 1217' Intermediate 6026' 13 -3/8" 5701 CF 6026' 5400' Production 10310' 9 - 5/8 " 2430 CF 10310' 9280' Liner 497" 7 130 SXS 10759' 9688' Perforation depth: measured true vertical See attached R I V E ru" Tubing (size, grade, and measured depth) SEP 1 19 3-1/2", 9.2 # N -80 to 10400' MD y ka ail & Gas Cons. Go Packers and SSSV (type and measured depth) 1. Guiberson model RH -2 dual- 9875'MD Anchorag® 2. Guiberson model RH -1 sin 13. Attachments Description summary of proposal X Detailed operations program _ BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: After Sept. 20th Oil _ Gas x Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Environmental Engineer Date , 0 Ro Q FOR COMMISSION USE ONIN Conditions of approval: Notify Commission so representative may witness Approval No. 4046 Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test Subsequent form 10 _ required Copy Appe� ned G� ORIGINAL SIGNED BY Approved by order of the Commission LONNIF O. F;� Commissioner Date 9 — ssia Form 10 -403 Rev 06/15/88 SUBMIT IN TRIPLICATE ,� KDU 4 PERFORATIONS: 9937' -9947' 10' 4 -1/2" HPF D -2 sd S.S. 9952' -9986' 34' If D -2 sd S.S. 9994' - 10002' 8' " D -2 sd S.S. 10258 10279' 21' " D -3 sd S.S. 10428' - 10470' 42' " D -4 sd L.S. 10430' - 10440' 10' " D -4 sd DST L.S. 10480'- 10490' 10' " D -4 sd DST L.S. All depths measured. Sand Tops: D -2 9925' MD, 8922' TVD D -3 10239' MD, 9207' TVD D -4 10428' MD, 9379' TVD N Anticipated static bottom hole pressure: 850 psi. R ECEIVED SEP 1 4 1989 .ka oil s�ns. Gom�issiau Anchorage KDU 4L PROCEDURE: 1. MIRU Coiled tubing unit (1- 1/2 Test BOPE to 5000 psi. 2. Run coiled tubing to long string tubing tail at 10400' MD. L.S.= 3 -1/2 9.2 #, N -80 buttress. 3. Circ. and RIH to top of fill at + 10460 4. Circulate out fill using water and nitrogen as necessary. ETD is at 10711 Circ until returns are clean. (A small mudmotor may be necessary to assist in breaking up the fill) . 5. Make a wiper trip to the tubing tail. Check for additional fill. Clean out same as necessary. 6. Rig down coiled tubing equipment. 7. Return well to production. E N� E C E" N! R, SEP 1 4 1989 ..ELL D-; D -3 KDU #4 CASING & ABANDONMENT DETAIL I. Elevation of Kelly Bushing at 0.0' 11. Cameron Dual 3 -1/2' Tubing Hanger at 13.20' III. 30', 1 /2' Wall, Set in Clay at 41' IV. 20', 944 H -40, 8rd ST &C Casing at 1,264' V. 13 -3/8', 6146, J -55, Seallock Casing at 6,026' VI' Top of 7' Liner at 10.263.24' Vil. 9 -5/8', 43.546,4746,53.546, N -80,P -110 Casing at 10,310.00' VIII. E.T.D. Top of Cement at 10,711' IX. 7', 2946, N -80 Buttress Casing w /Mule Shoe at 10,759.78' TUBING DETAIL )NG STRING: 3 -112 ", 9.2 #, N -80 TUBING I. Otis 'XO' Sleeve at 9,862.26' ?. Guiberson Model "RH -2' Dual Packer at 9,874.85' 3. Otis "XO' Sleeve at 9,915.75' f. Blast Joints From 9,919.43' to 10,017.83' S. Blast Joints From 10,233.18' to 10,292.38' 3. Otis "XO' Sleeve at 10,354.56' t. Guiberson Model "RH -1' Hyd. Packer at 10,391.30' 3. "Q' Nipple at 10,397.85' �. Bottom of Shear Sub at 10,399.98' )RT STRING: 3 -112 ", 9.2#, N-80 TUBING 1. Otis "XO' Sleeve at 9,811.82' 3. Guierson Model 'RH -2' Dual Packer at 9,877.70' 'Q' Nipple at 9,888.00' ). Bottom of Shear Sub at 9,891.73' * NOTE: Fill Tagged at 10,468' 718184 Q ST DATE WELL KDU *4 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA DRAWN B.A.W. CKD. APP'D. SCALE NONE DATE 4/16/86 L r E I` V E Dek" P 1 1& aa, Cons. CoMdISSIOL �N RR.e11A.V6 �A�N e PERFORATION RECORD DATE INTERVAL CONDITION 6 x 6/17/69 10,480' - 10,490' 7 10,430'- 10,440' DST D -4 Sd. 8 ds ()s 6/ 18/69 10,428' - 10,470' D -4 Sd. Production 9 10,258'- 10,279' D -3 Sd. Production 9,994'- 10,002' D -2 Sd. Production 9,952'- 9,986' D -2 Sd. Production D -4 Sd. 9,937'- 9,947' D -2 Sd. Production * NOTE: Fill Tagged at 10,468' 718184 Q ST DATE WELL KDU *4 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA DRAWN B.A.W. CKD. APP'D. SCALE NONE DATE 4/16/86 L r E I` V E Dek" P 1 1& aa, Cons. CoMdISSIOL �N RR.e11A.V6 �A�N e E y I KENA I �. CT - (, EEE z�z N �� 0 88 r N r a 'Q N N N rNn al B Ob PF�� V A Lu A VA rllolv, pt�mbmfj 1C000 Z—, i L-. OLO -fi ew,�. P . E-+ �R. 0. ps. 6 (, P", E C E IV E D 1 zr� , it 4 Gas Cons. Commissiai� Anrhn e . Union Oil and Gas Division: Western Region Union Oil Company of 'fornia Q P.O. Box 6247, Anchorage, Alaska 99502 �< 1 U Telephone: (907) 276 -7600 'J r union A July,24 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE'S Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of Intention for KDU -4L, Subsequent for D -13, and Permit to Drill for KTU 42X -6. Please return the approved Sundry and Permit to the undersigned. Very truly yours, Lawrence 0. Cutting ENVIRONMENTAL SPECIALIST LOC /tj Attachments LL STATE OF ALASKA ALASKA LAND CAS CONSERVATION d iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ❑ COMPLETED WELL ❑ OTHER ❑ 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 69 -12 3. Address 8. API Number PO BOX 6247 ANCHORAGE AK 99502 50- 133 -20176 4. Location of Well 9. Unit or Lease Name 305 & 423 of NW Cor., Sec. 7, T4N, R11W, SM., Kenai Deep Unit 10. Well Number KDU -4L 11. Field and Pool Kenai Gas F ie ld 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 90' A- 028142 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ,® Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing Other Pulling Tubing ❑ (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). i SEE ATTACHED ADDENDUM I Alaska oil 8, Gas Ansci 14. 1 hereb certif at th orego' is true and correct to the best of my knowledge. Ke 41 Signed Lawr Title Environmental Specialist Date - 0741 - 818 The space below for Commission use Conditions of Approval, if any: Approved Copy 0 (w5 u L R tulr 1 �� Y X19 ?,,IE �. � ��� . By Order of Approved by COMMISSIONER the Commission Date__,_._._ CJ rurm lu-4uo Submit "Intentions" in Triplicate Rev. 7 -1 -80 and "Subsequent Reports" in Duplicate ,m 13.) PROPOSED PROCEDURE 1. ) Move rig to pad 41 -7, well KDU #4 RD, and rig up. 2. ) Kill well, install BPV's, remove tree, install and test BOPE to 3000 psi. 3. ) Pull and lay down existing 3 1/2 X 3 1/2 dual completion assembly. 4. ) Mill over and recover packer from + 9875 5. ) Clean out to + 10759' ETD. 6a.) Test following Tyonek sand group for sand entry: 10490 - 10480' 10470 - 10428' Squeeze off zone that is sand productive. 6.b) Test following Tyonek sand group for sand entry: 10279 - 10258' 10002 - 9994' 9986 - 9952' 9947 - 9937' Isolate sand intervals that are sand productive and squeeze. 7. ) Perforate and DST the Lower Beluga sands at the following intervals: 6800 - 6810' 6826 - 6848' 7265 - 7292' 7670 - 7680' 7282 - 7697' 8. ) If lower Beluga sands test at a combined rate less than 3.0 MMSCF /D perforate and DST the following Middle Beluga sands: 5957 - 5981' 5987 - 6020' 6070 - 6089' 6340 - 6355' 6430 - 6444' 6450 - 6462' 6643 - 6672' 9. ) Reperforate with 4 HPF the Tyonek intervals that were determined to be gas productive in Steps 6a and 6b respectively. 10.) Run dual 2 7/8" X 3 1/2 completion assembly. 11.) Install BPV's, remove ROPE, install and test tree. 12.) Place well on production. 13.) Rig down and move rig to next site. Union Oil and Gas Division: Western Region Union Oil Company of ornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276 -7600 C� union May 10, 1985 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 SUNDRY NOTICE SUBSEQUENTS Dear Mr. Chatterton: Attached are Sundry Notice Subsequents for KU 11 -6L, KU 44 -30L & KDU -4L, Kenai Gas Field for your information and files. Very truly yours, Lawrence 0. Cutting ENVIRONMENTAL SPECIALIST LOC /tj Attachments RECEIVED JUN 19 1985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA If ALASKA UAL AND GAS CONSERVATION C610MISSION SUNDRY NOTICES AND REPORTS ON WELLS Form 10 -403 Submit "Intentions" in Triplicate Rev. 7 -1 -80 and "Subsequent Reports" in Duplicate 1. DRILLING WELL ❑ COMPLETED WELL ❑ OTHER ❑ 2. Name of O erator UNION OIL COMPANY OF CALIFORNIA 7. Permit No. 69 -12 3. Address 8. API Number PO BOX 6247 ANCHORAGE AK 99502 50 -133 -20176 4. Location of Well 9. Unit or Lease Name 305 & 4231' E of NW Cor., Sec. 7, T4N, R11W, SM. Kenai Deep Unit 10. Well Number KDU - #4L 11. Field and Pool Kenai Gas Field 5. Elevation in feet (indicate KB, DF, etc.) RT 90' 6. Lease Designation and Serial No. A- 028142 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ Repairs Made ❑ Other Pull Tubing ❑ Other ❑ Pulling Tubing ❑ (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). 1.) Shut in well. 2.) Rigged up Dresser -Atlas 3.) Ran in hole with SSB II hollow carrier gun. 4.) Located on depth and reperfored f/10 10,465' @ 4 /HPF. 5.) Pulled out of hole. 6.) Rigged down Dresser - Atlas. 7.) Put well on production. RECEIVED JUN 19 1985 Alaska Oil & Gas (Cons. Commission Anchorage 14. 1 hereb cert' at tJx� -fore true and correct to the best of my knowledge.' Signed Lawrence 0. Cut ng Title ENVIRONMENTAL SPECIALIST Date 06 - - The space below for Comm u Conditions of Approval, if any: By Order of Approved by _ C t h e Commission Date__.. _,....___ Form 10 -403 Submit "Intentions" in Triplicate Rev. 7 -1 -80 and "Subsequent Reports" in Duplicate Union Oil and Gas Division: Western Region Union Oil Company 6 �;alifornia p Y P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276 -7600 union April 4, 1984 �L Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS Attached for your approval are Sundry Notice intentions for KDU -4L, KU 11 -6L and KU 44 -30L, Kenai Unit. Please return the approved Sundry Notice to the undersigned. Very truly yours, >g�f C;/- Lawrence 0. Cutting ENVIRONMENTAL SPECIALIST LOC /tj Attachments RECEIVED APR Alaska 00 & Gas Ocns. l;wmission Anchorage STATE OF ALASKA ALASKA` ail_ AND GAS CONSERVATION CLIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ❑ COMPLETED WELL ❑ OTHER X 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 69 -12 3. Address 8. API Number PO BOX 6247 ANCHORAGE AK 99502 5 133 -20176 4. Location of Well 9. Unit or Lease Name 305' S & 4231' E of NW Cor., Sec 7, T4N, R11W, SM Kenai Unit 10. Well Number KDU — #4L 11. Field and Pool Kenai Gas Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT ' A-028142 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing ❑ Other 4 Pulling Tubing ❑ (Note; Report multiple completions on Form 10 -407 with a submitted Form 10 -407 f or each complet 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). 1.) Shut in well. 2.) Rig up Dresser -Atlas 3.) Run in hole with SSB II hollow carrier guns, 0 phased, loaded 4HPF, and located on depth. 4.) Note surface stable shut in pressure (if pressure continues to build - stand by on firing guns until pressure stabilizes). 5.) Bleed off 20% of stable shut in pressure. 6.) Shut in well and reperforate from 10,248' - 10 7.) Pull out of hole with guns. 8.) Rig down Dresser -Atlas 9.) Put well on production. R ECHVED .APR �. 1885 Alaska Oil $ Gas Coats. Commission Anchorage 14. 1 hereby erti�hat ore ir 2 true and correct to the best of my knowledge. f) yj iJ vV r Signed Lawrence 0. Cutting Title ENVIRONMENTAL SPECIALIST Date 04 -03 -85 The space below for Commi u se Conditions of Approval, if any; i.." I ,.. ;cry turns BY LOWS f . Sq 5.d fl" By Order of // Approved by _ _ COMMISSIONER the Commission Date - 7.. Form 10 -403 Submit "Intentions" in Triplicate Rev. 7 -1 -80 and "Subsequent Reports" in Duplicate 11['i 10 -6f v STATE OF ALASKA AND GAS CONSERVATION CON AITTEg,. GAS WELL OPEN FLOW POTENTIAL TEST REPORT alult) -POINT TEST Test Initial ❑ Annual ❑ Special Field Reservoir Test Date Kenai Gas Field T Y onek 7 Operator Lease Well No. Union Oil Company of C alifornia A- 028142 KDU -4L County Location 253' S & 4209' E from NW Corner, Press. psig Completlon Date Total Depth T /Pay Prr.!u.:r= 1r.:er Kenai Sec. 7 > T R11W > S.M. 1 .0959 49 24 b -22 - 0,8 10MD 1 38' a i 10,42 Producin Thru Recervolr Wellhead CSG. Slx e 'R' t /Ft. l 111 ` I. D. 1 I �� 8 Set o) 13 88 1 0, 470' MD X G. CSG. Te 4aer. Te m perat ure er I 7 I 11 2 .0 9 21 16 I 6.184 4. I 10, 759' MD 2.250 TBG. Size \� t /Ft. O.D. I.D. Set r Gas Gravity Aq. Prod. GL Gac- Liquid H)drocarbcn I Grasi.', of 1/2 ` I .2 3.5 I 2.75 1 10,4 0 0 3. (Separator) 0.555 Length (L) 10 40 5772 Ratio )1(F per Bbl. 1 3 000 I Liquid -.4pi) 28 Pipeline Connection Type Taps I 4. Nikiski Pipeline Flange Multiple Completion (Dual or Triple) Type production from each zone Dual I Gas OBSERVED DATA Flow Data No. Time of Flow Hours (Prover) (Line) Size (Choke) (Orifice) Size Press. psig Diff. h w Tubing Press. psig Casing Press. psig Flowin.- Temp. OF ST 2200 0.95 1 1. 42 1 .0959 49 24 2. 27.696 I 173.790 I. 1 3 . 43 8 2.250 7.29 218 l 111 G. 1 I �� 8 2.2 13 88 I 2161 1 1 108 3. 1 3.438 2.250 �_ 29.00 21 16 -- -- 105 4. 1. .438 2.250 I I 0.48 201 102° FLOW CALCL;LATIONS No. Coeffi- eient (24 Hr.) h p w m Pressure psla Flow Temp. Factor t Gravity Factor g Compress. Factor i Rate of Flow pv I Q JIl FiD .6 6 126.641 2200 0.95 1 1. 42 1 .0959 49 24 2. 27.696 I 173.790 2176 0.9568 1 1.3423 1 1.1001 6800 s. 27 .69 6 248. 4 2131 0.9594 1.3 423 1.1004 ( 9757 4. 27.696 319.953 2028 0.9619 1.3423 1.1013 12601 PfIrSS('RE CALCULATIONS 28.900 MCF /D 1 .4462 CERTIFICATE: I, the undersigned, state that I am th e n g i n e e r of the. Union o i 1 Compan (company). and that I am authorized by said company to make this report: and that this report was pre- pared under my supervision and direction and that the facts stated rein are true, correct and complete to the best of my knowledge. .Z�1/ Signature Gary E. Carlson P F' w (Psfa> P= F Q (F Q) (1 X 1- e" s P= P -- P2 Cal. w P P :t r c c Q)= W c w w ! y t I c 2. 3. 4. Absolute Potential � n 28.900 MCF /D 1 .4462 CERTIFICATE: I, the undersigned, state that I am th e n g i n e e r of the. Union o i 1 Compan (company). and that I am authorized by said company to make this report: and that this report was pre- pared under my supervision and direction and that the facts stated rein are true, correct and complete to the best of my knowledge. .Z�1/ Signature Gary E. Carlson 1 2 3 4 5 6 7 S 9 10 20 110 40 50 60 70 90 go >o ' t no 77 771, .7 -�.I . . . . i _.. • rr 1 ` 1 _ G ILO✓ ._'+ _�._.- «--- .____,,...". ..-•1� _.__ •----- J- ".�,..__..._. �.. �- 4_. -- . _ _. �`._ _.._ -_ -,.. _ ...._ : ZUT o :w 2 a _. C`•! _... 4 ?o c�.. }. _ 1 ` _ ._�� .,� _ _ t _'__ l __ — 11 � ...`. .. �7, i.. a ° ...•.' -. . f � _ - x 3 31 + + 1 , 1 J 1 I .....! I { �. __ - 4 I I C3� CL 1 i , I . 7 . I _ , 1 � , ..� -._ - �,.._. i 1 i 1 C S , o a I 4 C — I — A T' T ,. 3 :: fir# lVE AT TH E qN 1°zl E L L. NO. k"d POOL Kenar Tyon�k 6 Pa / 7 , 1 • iT , i T; i p 0, mscF /D f { INTERPRETATION (3Y Li;Am {N RY i i • }.,_�.,__ �,.;_, � i °f l � � I I 1 1 f__ i j , ; t i I { � ��. .d. �� I D 1 2 3 4 a 6 -/ _ 6 910 20 30 FL OW RATE , 0 , nim scF / Day �'�'a,; d ; ju d ^„ 4 " '�j 0" GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska 0 b GCC Form No. G -I) Field Reset voir Test Date Kenai Gas Field (4) Q MCF D 1 -31 -70 Operator Lease Well No. Union Oil Co, of Calif. Anchorage 028142 KDU 4 -S Surface Test Data Test No. (I) P s i a (2) Pf. (3) (Ps Pf X 16 (4) Q MCF D I 3180 3140 25.28 1 5,798 2 3180 3035 90.12 8 3 3180 2880 181 14,829 4 3179 2800 226.60 17 Sub- Surface Test Data Test No. Subsurface pressures measured. (4) Q MCF /.D Subsurface pressures computed: Cullender -Smith Method of IOCC. Test No. (1) Pws psi a (2) P wf p,s i a (3) (Pws -Pwf X 10 - (4) Q MCF /.D 1 3854 3781 J 55,73 5 2 3854 3686 126.67 80993 3 3854 3599 190.05 14,829 .. 3854 3578 205.12 17,979 Nomenclature: Ps = Static surface pressure Pf - .= Flowing surface pressure Pws = "Static bottom -hole pressure (mid -point of perforations) Pwf = Flowing bottom -hole pressure (mid -point of perforations) Q = Flow rate, MCF per day at 60 ° F and 14.65 psia 1 -70 .1 v • . �, . v �,..,, k y ,, .. � ,_. ' �!� iF'1 tl � •.e n � .. � R �'. M' 1n� • (7 � STATE OF ALASKA SUBmrr IN DUPLICATE Form No. G -1 REVISED : JAN. 1, 1969 OIL AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4 -POINT TEST Test Initial ® Annual ❑ Special ❑ Field Time of Flow Hours (Prover) (Line) Size (Choke) (Orifice) Size Reservoir Kenai Gas Field Casing Press. psig Kenai T onek Gas Pool I Operator - 3.438 2.250 Lease Union Oil Co. of Calif. - Anchorage 028142 County Kena Location 253 and 4209? frm N.W. Corner Sec. 7 Completion Date Borou hl T4N R11W SM 124 2. Producing Thruu Reservoir 2.250 Wellhead CSG. Size '%Vt /Ft. I.D. Set @ TBG. I CSG. I Temperature 3.438 2.250 I' Temperature I I I I Total Depth Test Date 1 -31 -70 'Well. No. KDU 4 -S T /Pay Producing Interval Q _ 0 } 2' X 148 O F I0I - I'N 7" 2. 6,184 1 TBG. Size Wt /Ft. O.D. I.D. Set @ Gas Gravity Avg. Pro 5 90 d. GL Gas - Liquid Hydrocarbon Gravity of r' (Separator) I Length (L) Ratio MCF per Bbl. Liquid (Api) 3- ( /2" I 9.20 3 -1 /2 I 2_ . 992 9892 .555 9892 4 ° 3, 000. 27 Pipeline Connection I Type Taps Nikiski Flange Multiple Completion (Dual or Triple) I Type production from each zone Dual T 6) n iAA. Gas OBSERVED DATA Flow Data `o. Time of Flow Hours (Prover) (Line) Size (Choke) (Orifice) Size Press. psig Diff. h w Tubing Press. psig Casing Press. psig Flowing Temp. OF ST - 3.438 2.250 - - 3165 Packer - 1. 1 3.438 2.250 3027 8.00 3125 Packer 124 2. 1 3.438 2.250 2873 19.84 3020 Packer 118 3. 1 3.438 2.250 2492 59.40 2865 Packer 106 4. 1 .1 3.438 1 2.250 1 2203 1 96.60 f 2785 1 Packer 1 101 FLOW CALCULATIONS No. Coeffi- clent (24 Hr.) h p W m Pressure psis Flow Temp. Factor F t Gravity Factor F g Compress. Factor F pv Rate of Flow Q MCF /D 1. 27.6963 156.00 3042 0.9437 1.3423 1 5,798 2. 2.7.6963 239.40 2888 0.9485 1.3423 8,993 3. 27.6963 385.86 2507 0.9585 1.3423 1 14;P829 4. 27.6963 462.87 1 2218 1 0.9628 1.3423 1,0852 17,979 PRESSURE CALCULATIONS 84,000 MCF /D 1 0.817 CERTIFICATE: I, the undersigned, state that I am th Prod. Eng r of the Union O l l Co. of Calif. (company), and that I am authorized by said company to make this report; and that this repo # wt pi -; +r r- pared under my supervision and direction and that the facts stated therein a rue, Corr ct and cdinplef . the best of my knowledge. } __ Sgrature J. E. Chu P P w (psis) Pt F' (F Q)a ( X 1- e 's P tiv Pc .-- P w P PQ)"- W w P t c 1. 2. SEE ATTACHED s. 4. Al, solute Potential n 84,000 MCF /D 1 0.817 CERTIFICATE: I, the undersigned, state that I am th Prod. Eng r of the Union O l l Co. of Calif. (company), and that I am authorized by said company to make this report; and that this repo # wt pi -; +r r- pared under my supervision and direction and that the facts stated therein a rue, Corr ct and cdinplef . the best of my knowledge. } __ Sgrature J. E. Chu Form No. G•1 REVISED : JAN. 1, 1969 STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4 -POINT TEST Test Initial LK Annual ❑ SDecial Field Time Nf of Flow Hours (Prover) (Line) Size (Choke) (Orifice). Size Press. („«- I psig Reservoir Tubing Press. psig Casing Press. prig Flowing Temp. °F Test Date 1 58 , 0 9 2 ' M eter 1. 12-- 20--69 Operator InIon 01 Co. of Callif% 87 s. Lease A 022142 2. IWell ' o. County Location Su a� ® : 253' S $ 4209' E from NW 4652 Completion Date Total Depth T /Pay Produc Kenai _. Pac k er . .. _ — 4. I 1 810NDI 381 I nter v al 110-421 Producing Thru Reservoir ellhead CS . Size 't�'t /Ft• I.D. ` Set sti I Q 471 CSG. Temperature Tem erature �7" I r — X ( I 48 °F 78 � 88 ° F Lnr 29 6. 184 I 10 280 to s 10,759 759 MD TBG. Size ZVt /Ft. O.D. I.D. Set Gas Gravity Avg. Prod. GL Gas- Liquid Hydrocarbon Gravity of 3 -1 2 9.2 3.5 I 2.75 110,4001 (Separator) 0.555 Length (L) I 9892 1 Ratio lifF per Bbl. 3 Liquid (Api) 28 ° Pipeline Connection I P"Wpe Taps Multiple Completion (Dual or Triple) I Type production from each zone OBSERVED DATA Flow Data 1To. Time Nf of Flow Hours (Prover) (Line) Size (Choke) (Orifice). Size Press. („«- I psig Diff. h w Tubing Press. psig Casing Press. prig Flowing Temp. °F ST 1 58 , 0 9 2 ' M eter 1. 2965 0.9741 1-3423 87 s. 0 77 2. .. _. P�7 23.12 3137 4652 2245 3. 1 1 o g . 18 562 _. Pac k er . .. _ — 4. 0 60 2860 Pa FLOW CALCULATIONS No. Coeffi- cient (24 Hr.) h p w m Pressure psia Flow Temp. Factor F Gravity Factor g Compress. Factor Pv Rate of Flow Q MCF /D 1 . 1 58 , 0 9 2 ' x 2965 0.9741 1-3423 87 s. 0 77 .. _. P�7 4 . 04 22 06-9-6-3- 4652 2245 1 0 1 1 o g . 18 562 PRESSURE CALCULATIONS P p w Pa F Q (F Q)= Cal w (I�sia) (F Q).= X 1- � -s P- P? „- p? 1 , I, :t c e c w e w w F t c 1. 2 Sao Altached ., 4. Absolute Potential I n 14ICF /D CERTIFICATE: I, the undersigned, state that I am th Prod EnV f the U Ion O f I Co. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are tr , co et and complete to the best of my knowledge. Si ere J. E. Church 3— I ML GAS WELL OPEN FL OW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska 0 & GCC Form No. G -1) F i e l d Reser Woi.r Test Date Operato as Field Leasd<enai Tyonek G Pool I �11 T 1 N a✓v Ir — T r Test No. PS) t�sia Pf h i (3) (Ps Pf X . 1 5 4 (4) Q MCF /D 3177 313 25.25 6192 2 3177 3092 53.28 , 3 31177 297:) 124 .27 - , 118 4 3177 '2860 011.37 r Sub- Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender -Smith Method of IOCC. Test No. (I) Pws ps i s (2) 0 p,s i s (3) (Pws -Pwf X 10 - (4) Q MCF /D 44 2 :3876 3808 24.71 52 .25 r 3 38% r r Nomenclature: --- Ps = Static surface pressure Pf = Flowing surface pressure Pws = Static bottom -hole pressure (mid -point of perforations) Pwf = Flowing bottom -hole pressure (mid -point of perforations) Q = Flow rate, 14CF per day at 60 ° F and 14.65 psia *lsochr^onal Method 1 -70 q p ,F I- ur!II P SUBMIT IN D1jr-.u1CATE• STATE OF ALASKA ; See ether [n- struetions on 5. API NUD RICAL CODE OIL AND GAS CONSERVATION COMMITTEE reverse Sine 50- 133 -20176 WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 6. LEASE DESIGNATION AND SERIAL NO. A 025142 Ia. TYPE OF WELL: 0111 �1'F;1.1. � �.As WELL DRS Uther L 7. IF INDIAN, ALOTTEE OR TRIBE NAME b. TYPE OF COMPLETION: A..'WGUNT PULLED N$W won1C n DEEP n 0V ER U F.N �� PLr.c ❑ DIFF. BACK I:F.SVR. Other _ 8. UNIT,FA.RM OR LEASE NAME Kenai U n i t 2 . NAME OF OPERATOR Union Oil Co. of Calif 9. WELL NO. Kenai Deep Unit #4S(13-* 3. ADDRESS OF OPERATOR 5 _07 Northern Lights hts B! vd . 10. FIELD AND POOL, OR WILDCAT Kenai Tyonek Gas Pool I 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements) Ll t surface 253'S and 4209' f rm N.W. Corner Sec. 7 , T4N , RI I W, Sid 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) At top prod. Interval reported below Sec. 7, T4N , R 1 1 W, SM At total depth 12. PERMIT NO. 13. DATE SPUL)DED 14. DATE T.D. REACHED 1 15. DATE COMP SUSP OR ABAND. 16. ELEVATIONS (DF, RKB, RT, GR, ETC)* 17. ELEV. CASINGHEAD 18, 'I'0TAL DEPTH, MD & TVD 9. PLUG, BA'C'K MD & TV . IT MULTIPLE- COMPL., HOW MANY" 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS 2 1 1N'rk;NVA.U(�S), UL'' '1'H.1� t U1V1YL>r'1'lU1V -l'UY, bU'1 "1'UM, NA1V1L UV11J &NIJ 1'VL)- 6J. VVt O L12LL•1... .L .L V1V LiL SUR'VE'Y MADE 24. TYPE EL.ECT111C AND OTHER LOGS RUN 25. CARTNG RECORD ( Report all strings set in well) CASING SIZE WEIGHT, LB /FT. GRADE DEPTH SET (MD) HOLE SIZE CEit7LNT'ING RECORD A..'WGUNT PULLED 26, LINER RECORD 27. TUBING RECO11D SIZE TOP (MD) BO'.I'TOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET( YID PACKER SET (MD) 28. PERF'O.R.ATIONS OPEN TO PRODUCrIOX nterval, sire and number) 29. ACID, S iOT, F. - ZA T'URE, CaUENT SQUEEZE, ETC, DEPT'II IN'T'ERVAL (MD) Aiti1O ' -'r "I:NLI �F T UP MATF?iAL USED . .`..! Ti .. .� 1n is ^7 -•� 3o. PRODUCTION n� DA'Z'E FIR ST PRWDUCTION PRODUCTION 1VIL1.[ -IOD (Flowing;, L!,as lifi, purn,ping -size and type of pump) vvrl. t' u "r (Producing or :iaut -in) December, 1969 Flowing - Gas Well _ Pr du cinn DATE OF TEST, HOURS TES'T'ED C1°10-£E SIZE PIIOD'N FOR QIL�BDL. GAS -MCF. WATER BBL. GAS -OIL Ii..%TIO TEa'1' 1- i.IOD + FLOW, aurJ.,T U' CASING PRESSURE CALCULATED OII. --BBL. GAS-- TdIC'F. WATER -BBL. OIL GRAVITY -API (CORR.) T"I,ESS. 22 -HOUR RATE 81 • DISPOSI'T'ION OF GAS (Sold, used for fuel,vented, etc.) TEST WITNESSED BY Sold I L. Keen 32. LIST OF ATTACHMENTS See 0 en Flow Potential Test Repo i. I hereby certify that the fv eg.0"'I " and attached information is complete and correc as eterm ned from a available records r, SIGNET) _ L ,��� � __ TITLE --EEad=±1 Q n-_ F_nq 1 ne er -_.- DATE - Mraric -- , 2.4-x--1.97( *(See Instructions and Spaces for Additional Data on Reverse Side) 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement ": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). - 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED. PRESSURE DATA AND RECOVERIES OF OIL. GAS. WATER AND MUD I �! 35. GMLOGIC MARKERS NAME MEAS. DEPTH I TRUE VERT. DEPT11i 36. CORE DATA. AT`TACI1 BRIEF DESCRIPMONS OF L.ITIIOLOGY. POROSITY. FRACTURES. APPARENT DIPS- AND DWI'ECTED SHOWS OF OIL, GAS OR WATER. 11 1 - A ri N.7 A V r r AN ew W% L'%'L 6 Les W io .0 u dr. .11.jaska 9 96 11 P.0 J.Jrox 57 3 9 Q. C; ' C3 J q. A Jim - r 'K c *'oCLL NAME D U CA OXNER • M013[oNs 01 Co. FIELD DATE WNG EI-Ev. ---9..5'L co LINER PrSCW1;'TiCV ZERO PC:% - 10 412t - 1-0 4-N-) ° DEI oil 10 TUMM'. ETAI d1c.; 2 ova 0 '9862r' H 2, Data" C- slo'C'Va z-vic"d — .312- 1 PUIRMSE ElLpom to 5 t RES.'Ape.S, ELEMENT 4200--; SERIAL NO K CLCCA -204 00. ENGAGE STYWS --?-:.:L5.. CA 1-2 STYLUS _5.- "13 6' 12 c -ps. 330 o.s. -BUG. PRE ODS. CsG. PRESS. COR. T13c.. mzss. CDR. C50. Ilitcaps. 3 1 1 .4 r % m A PICKUP.• TI%IC 0% UOTIC0.1 00_" per.__ MAX. -F 150 WCLL STATUS Z10 1ill-I - -nd- St•tjW STABILIZAT 10% PER:SD S14UT IN 04 PRODUCTION GROSS O.L RATE Es " FIET Oft. RATE B/a FORMAT*% 04S • .4. ro to st TI ME DEPTH DEFL. GRAZ). A -10 GOR CC L GAS W C0 C- 3 • ins, 10. 45" 7 CIRCULAT 1 cT OIL DRY GRAVITY QAmi 13EAN SIZE CASING PRESSURE Of 13.7. ic-AIL TURING PRESSURE I. cb. 1-77— s1 a 1 a M. DEPTH V. CEp-.n Pr%rs2F6!LE - GRAZ- L P 'Flo-w f r si v!,i p S-1-2 0 45Q .1w4611 �� I i ss� �j P 2 9-7 -3 - 5- r sa-L. 10.24-5-01,379 114 S L - 2A60 I od. 10 1 L;1 0: oco". 0 1 374- '50 4' S � COMMENTS: Off bot4 3:43 p.n.. 12-22-69 • J A -92 $1970 e- Ir BY. YAY o r s E G, A' A V. E R , S E L I M E S Ru,,. V I C Ea P.O. fox 57 Kenai, Alaska 99611 283-7819 j � SUBSURFACE SURVEY OWNER UN ION OIL CO. _ FIELD K Gas Field WELL NAME K_ _DU CASING St' 1 0 1O E LEV. DATE s2 - -6 5 1 9 -- . t 3 -- — - -- LINER DESCRIPTION ) 10-2 8 ! ZERO POINT 1-2 Parfs. 10 1 - 47. 0 1 - -- DEPTH TUBING DETAIL 3 -L , " . x S l eeve R H 2 Dua `' ga77 2 z xo s le_eva ZONE Zliddle Kel -A D 0 9 15 -and 10,3 it R H 1 P,K.R. 10, Q nip le 10, ? shear sub 10,399 PURPOSE Static Gradient Survey REMARKS ELEMENT 4200 V. DEPTH SE RIALI ' NO. K - 2 9 3 402 CLOCK hr 1 -1 TURN ENGAGE STYLUS 5 :3 - 0 0 P. M. — ---- -- V - E ENGAGE STYLUS 8 :4 OBS. TBG. PRESS. ! 2 0 "'0 OBS. CSG. PRESS. COR. TBG. PRESS. 3 1 77;, L4 74 CO CSG P 31604 PICKUP (-' 1 4 — 5 .000 TIME ON BOTTOM 7 i 1V .P pem« _ MAX. ° F 1 WELL STATUS Sta SHUT IN 4s l0 p.m. 12 - -69 ON PRODUCTION 6� �� TIME DEPTH DEFL. P —T I GRAD. n/D TIME I DEPTH I DEFL. I P —T , GRAD, I n/D COMMENTS: ST PERIOD GROSS OIL RATE B/D NET OIL RATE B/D FORMATION GAS MCF/D GOR CFT/BBL CIRC ULATED GAS MC OIL DRY GRAVITY ° API BEAN SIZE CASI PRESSURE TUBIN PRESSURE M. uE.F'TH V. DEPTH PRESSURE I GRADIENT 0 0 1017 216.9 1000 2000 ! 2 0 "'0 L4 74 4000 --- 3° ,62 i c { 5- 5! -6 5 .000 3-5�2 6689 6� 60 00 6� �� ' 7 8 0 41 �yy 88 1 0 1 000 � 67i ! o°fo 8 000 1 0 91 0 00th ^ p - C 460 455 b1 ' 'a 0 164 � IpfN TA '1A-7 ' ; Y, ti ,`-� t ,. a '�. ., �, ' � � :V Y ��'11 4' �''cf7 F ,.� '�}:' '; •.;1� 11.71 It E. G. DRYERS( WIRE LINE SERVICE P.O. Box 57 Kenai, Alaska 99611 283.7819 SUBSURFACE PRESSURE SURI OWNER UNION OI CO . FIELD Kenai G as 'r - ie l d `_- WELL NAME K D V # 4 �^ CASING 9 51 8" 6 10 1 • - ELEV. - DATE - 12 -20-6 - -- LINER DES _ _j0 A 2_80 '1 `1 -- - - - . _ 2ERO POINT _ 2- 1 . -� - -- - Pe 10 ,422 • � .10 `P -, - - - -' -- - -- - DE PTH -- - - 10 -�`O- -- TUBING DETAI � X O sl® 9 862 - •, _R H_2 DLal q$ !�xo_ ZONE Mid Kenai _D ale . v e 0 991 5 1 and lo, 3.5 , R H 1 P.K .R. 10 � _ , Q nippy - - - - --- _ — 10.397 - she ar sub 1 PURPOSE 4 point tes - ' _ - - - -- REMARKS : E�}e L 420 h_r _ C look - - -...— - - - - - -- -- - , .. ._ _._•____ - - -' __ - - '� on - t3 4 IC TEMPERATURE • PICK UP @ -- MAXBRUM MPERATURE --_ • F>�. -- -- -- 2 4 6 8 t +fi o T'' t � }` t '/''` .r~.•� — -- -- - -•--_ -- - -- F .y. . 14 T W ell Head +�.+•_r•�- ....{- .....,...y J. �"w.- .. �� rl•d- 7 � •y- '- �' .♦ _,� S « •.T� ..1. F r .1 • 1 Y � r `+ STABILIZATI PERI Pre s 1 }.. � .... } ( }' ' l � ` t �a ! _ tr T 4 1+} }x '1 1 �Y 1 � L }. - i r f t " }} 7 "�'7.. ' t G ROS S OIL R AT E B/D � ..,+. , �.«.y. ...r ff ±:r♦ _ i }. _ I :: j... i 1 : �' 1' t + ' '� 6 f 7, ,. y �. , 7 y T i r ._ .-- - ,� ■ ", - i i .: 1 ' 1 ;� l r•r �,1:a`� -, :. • J r ,.: 1 r I 1 .j. I { ' l.: t, I t~ ,.t NET O IL R ATE B/D �✓vA .S F ORMAT I ON MCF/D -_- - -- 4- _ 4 . ��r ` ^ GOR CFT /B BL - - -- - �.. .� I ry I •... I _•. ` . { , r � � + �• � Y�^� CIRCULATED GAS MCF /D - - - -- -' .i''"' ,,,*. 7 t t t I ! � $ i i. , OI DRY GR AVITY 'API '1 +'T. B EAN SIZE -- - -_ - -- -- ++ • ;� • � 1 : � � } _' � I . 1 � ' � CA SING P T"v'y • 4 • � + • Y ,� . , , f � � S • TUBING PRESSURE 2800# 7 M. DEPTH V. DEPTH PRESSURE GRADIEN' C . _ �» 1 1 �• fi I ' Al t� .�•.��. ..A._ ...:..., _ _ r . ,,..y 'p^«'^ '�' ' 1•"' ' I. , ' - --- -- '-- -- --....___.. . - --._ -- MP 1 l { f Y F + � Neil y•,w MRr�'ha { , , t BY: Myers 1 2 3 4 5 6 7 8 9 40 20 30 40 50 60 70 80 90100 40O _ - I I . -. - � 1 -- - _ter . T _y _ _ .. - - - - -- - - -- -• -- ._ _. - -- - _ — _ - - - -- - - -� - -- -- �- , -- - - - - -- -- ' t _•_ ' 1-' -- �. � • _.1. t ly ( -. I 1 ._L__I _- .. F.. _ - • 1 .� r , I _ �� i �.. -..- -. I _ _ _�_. *- �-""�. T. _- _ -7 5 j� Jr - JJ - Sz• z_`L r l t ',j',�z: 1029' I I- 1! I I 77 1 77 7 _ T t� T • -- - - - - _. �. _. ba y r V - - - - 1 - - _ - - - _.._ _ - ~ r - qc -- - -, ... , N r, 3 N � •-- -- I -•�—�_ j - T - • -. ._— f�3 i I I III _.1.. �_. _' t .. _�.�1 - t TI t I --•— .i- - - I IT , � i �- 1.. ) - �-- ,l' I{ I ' _. I I I, � ' � I '• � I I L � I i.. , 7 • y if --.._ _.: O _ _ , J .. _ ._... ._. ., .. .... a 7. - Y— 6. II , ICf I . 5 f- I U 4 3 . 2 -1— i—•r —( T -f _ I _(_ I_' ._i TI.L. ! - II ..'I III i I I j Y � r • _._ t 7 UNION 0I1_ COMPANY OF C WESTERN RE GION ANCHO RAGE O1S TRI f KENAI,.. GA $. FICL,p DELIVERABILITY AT THE .S.4�s/OFAc� WELL N0. :.k,4U axle 0 �� G POOL 0, msc F/D (PWSi - PWf 2 ) INTERPRETATION BY DRAWN BY Sf*t;£' DATE 7 I .Jo 7 j z E. G. MYERS', WIRE LINE SERVICE P.O. Box 57 Kenai, Alaska 99611 283-7819 SUBSURFACE PRESSURE SUR OWNER UNION OIL CO. FIELD Kenai Gas Field WELL NAI11F K D U 4 CASING __"o _310 ELEV. DATE 12-22-6 LINER DESCRIPTION: 4 10 280 LINER 1 t- ZERO POINT 12' Perfs. 10.422' - 10.470' DEPTH 10 460 TUBING _ IL:3j" X0 Sleeve 4 9 2" R H 2 Dual - @ 9877* X0 ZONE Middle Kenai D sleeve A 9915'- and —1-0--.-334�� H 93991 1 P,K*Ro 10091'v Q nipple -10.3971, shear sub 10 PURPOSE Static Gradient REMARKS: Element 4209#, K - 2 02 6 hr clock PICK UP @ MAXIMUM TEMPERATURE -F d Pressure PSIG 0 3 0 ---3% L. 77 4.1 Qt L "I , T, Ell 4 4- Vsrtiaal ` '. -.L_� _' .r� +� L tQ +i • -H �L.- .- }I- i-- a:'F._...- ... .}.�_ }�._,., -• •, .,.. .�._ra- .,..�.r • -�l. ...f..w �., _ -- _.___._ Depth 4�1 . .1 1 1 1". 4; STABILIZATION PERIOD 1 I "It -11 11 f I -.. - ... 7: T jZift_CSLS OIL_ RATE CL NET OIL RATE B/D 2000 I FORMATION GAS MCF/D V - QgR /130L CIRCULATED GAS MCF/D OIL DRY GRAVITY *AP1 BEAN SIZE CASING PRESSURE TUBING PRESSURE 1 ,.. .. � }� i �, , 1. ..�....,- +.•f -. •' � .: � ` 1 t � :• M. DEPTH V. DEPTH PRESSURE GRADIEIN 60 00 0 0 3184 77. J 068 34 ? 4 5576 50PO 8 3671 77 7 --JOM 10 IM-53--949P.- -355Z--s-1-0-5- -"0 -9451--. 10 -�J '-A f 7.' '.7 1?- 000 B Y: Kenai Gas Field Back F sure Tests Well: AS Pool: Deep Survey Date: 7 -17 -75 1.0 .5( O .2( r•I x v C+4 a PA • . l( M u N = J �u �T a U � N 0X J N .01 .01 A 1.0 2 5 10 20 50 * 100 GAS FLOW RATE TAMCF /D '..I ,i.�tl i �t ;(; ,I. { . t ..�. t � i — t,• J .! i .. :;.' � . .. I � ;_i ' ' ( f l i . .. ..: .. ' i i l l i :' .: 'f._ :. .. i i .. , , r i r 1 _ - • t i t I t ^�� • i- .- }�- i� 1i, -i `f� 1'I�ri:lii !I! I ,. ( i.;i ; I: I� -r { r ,41f,i'i: .. I :,..,.: i. � i, r � � i �_-' t ._ .'� t_J '.. i' — I1• .I rr .i.;.� j ;{;} .,:. ; i:i .. .T. -:1 4 i t�' I ,Ftif +. �(�(i� '�l �; :' i � � ; 1,,, I f s I , i s t.�'Ji ; :. i (;•+ l :i::�:', ;.~i ! a : } -t I- ,-�I�f� �.i�i' � � •i I:r ! ...:! !,j�; ,., ; ,f,,,,�1. 1 .4.,�i, .; .,! ... f._( � �_�.. i � I ,. } , ' + 1111..1.., ., :: ,,.,. {.. I Lt 1 1� ._ . � + ,t •: i,. ,:.r•. I •..I i.t !t Ililll •lil il! --i--t-�_ }_;,_ }1-..' .! •, y,.. ..' � � I ��:::;r. .!.. .! .. .. .1..1. �1 1 �}. ,• l 1. , , .. .�. . i.J,, ,,.', I I„ • — ' }..i.i i'.� EITi .• „ _I,.. ... ., - I ' :' .. I — •..I ii I {. :! ,.'i ,I ,� ..1 ..,' :i.. .. •. 1 1 . -, , ,. 1. .L.. ; , . I,,l } f . I .... ,- � ,� ._ I I ,. .. . .,, '�.�1 I i, , I .1. .. _. •. 1 � -- -{f- i 1 l ( — I �•- - --!! - -- — t _ r ,. ., 1 1 { . .. .. 1. ! } , ....1 .rI .• TA is r , I y_``- j. -T -r� � 1 iI I i. ;I: �' '_: .. I i.i , 'i .. iii ( i�;, i i i .. •. .: _i: i , A 1 f:, ,J i'�A:1 i , .il• ,i,, : i ,11 i • 1. :I. ,.,. Ili�l ... . .. ( } I I .1J ; _.•,._. l } • ii.lis f - i r 1 ',i I ;. ?. i 1. 1 � li i I I ? 1 ._j I .i � J ;1. i ` _,.i .i, A.1 1 1 F : ...''•: ...? i, l:i' ' ' I' ♦. ,; , i } 1A, .,.!• fii� fI'' lil '� .. � _ .. :;_.. ,...I_I.1.. � � -� .�. { .,1 ' .' • � I .1:, :' '' .i i�, `.,; ;_,.: i i,:� il.i..'I ,. ; �:�1 I : i :': I :1 1 ,�,'� ' I ," '. :. ': ili'4il I,. I , -t , GAS FLOW RATE TAMCF /D GAS r L OPEN FLOW POTENT I AL TEST RED IT PRESSURE CALCULATIONS (Supplement to Alaska'0 b GCC Form No. G -I) F i e I d Ken ai Gas Fi Reser vo i.r Tyon ek Test Cate -1 - Operator Union Oil Company of California Lease A-o28142 16'e I I ':o. Kpu - 4S Test No. Ps) nsNa Pf h i (3) (Ps Pf X 10 (4) Q 1 2235 2192 19.04 3659 2 2235 2142 40.71 6191 3 2235 2076 68.54 8516 4 2236 1968 112.67 11544 Sub - Surface Test Quta C--� Subsurface pressures measured. Subsurface pressures computed: Cullender -Smith Iethod of I0CC. Test No. (1) Pws Ps i a (2) 0 ' ps i a (3) ( Pws -Pw f 2 ) X 10 - (4) Q Nomenclature: Ps = Static surface pressure - Rf,.= Flowing surface pressure . Pws = Static bottom -hole pressure (mid -point of perforations) Pwf = Flowing bottom -hole pressure (mid -point of perforations) Q = Flow rate, I.1CF per day at 60 ° F and 14.65 psia 1 -70 REV 10 -69 Y l STATE OF ALASKA AND GAS CONSERVATION COMMITTE " GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi -POIN'T TEST Test Initial ❑ Annual ❑ Special )Field Reservoir (Prover) (Line) Size (Choke) (Orifice) Size Press. psig Test Date Kenai Gas Field Tyonek Flowing Temp. OF Si 2192 ( 7 Operator Lease 2. 2220 i Well \o. Union Oil Company of California A- 028142 2.250 4.00 I KDU -4s I 108 County Location 253' S & 4209' from NW Corner, I 2.25 CompletlonDate Total Depth _.....__._.... _._ _.__. 108 T / Pay rr.:da:i -i Kenai Sec. 7, T4N, R11W, S.M. I 22.33 2061 i 6 -22 -69 110,810 4. 3 er +al ' 73 196 1 0,2.7' Producing Thru Re4trvolr Wellhead CSC. Size '« 't /Ft. I. D. Set (Li, 2. TI3G. X. CSC. Temperature I 148F Temperature I 10 •F 3 2 .0 � I 6.184 l 0 ' ,75� TI3G. Size \\'t /Ft. O.D. I.D. Set r (;as Gravity Avg. Prod. GL Ca;•Ligiitd Nldretar boa ra C.ity of I I I (Separator) I Lowlt (L) I I Ratio a1CF per Bbl. Liy :d Api) 1 9 .2 0 1 2 2 2 8 9 2 0 5 O 2 s4 go � 3, 000 2 7 Pipeline Connection Type Taps Nikiski Pipeline Flange Multiple Completion (Dual or Triple) Type production from each zone _ Dual Gas OBSERVED DATA Flow Data Xo. Time of Flow Hours (Prover) (Line) Size (Choke) (Orifice) Size Press. psig Diff. h w Tubing Press. psig Casing Press. psig Flowing Temp. OF Si 2192 Q -9568 1 1.3423 1.0984 3659 2. 2220 i 2142 03568 I 1.3 3.438 2.250 4.00 2177 I 108 2. � 1 3 � 438 I 2.25 I I 11.73 I 212 ��__ .._ _.....__._.... _._ _.__. 108 a. �- 3 .438 1 r 2.2 0 I 22.33 2061 i ! 100 ° 4. 3 2.250 I 1 4] . 0 19 53 97 ° FLOW CALCULATIONS No. Coeffl- clent (24 Hr.) --� P � ,Am Pressure psta Flow Temp. Factor t Gravity Factor g Compress. Factor I R of Flow Pw 1 Q MCF D 1. 27.696 93.638 2192 Q -9568 1 1.3423 1.0984 3659 2. 27 I 15 2142 03568 I 1.3 1.0 7 6191 ^ 8 1. 27 .696 21 0 2076 0.9636 1.3423 1.1042 1 16 4. 27.696 291.139 1968 0.9662 1.3423 _ 1.1039 1 11544 PlIrSSURE CALCULATIONS 0,000 MCF 1 .6335 CERTIFICATE I, the undersigned state that I am th engineer of the Un ion 0 i 1 Company (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated t ereln are true, correct and complete to the best of my knowledge. Signature Gary E. Carlson P P w (p�fa) P= F Q (F Q )= (F X 1- e' s P= P=, - P2 Cal. P w P t c c W c w P t c 1. 2. 3 i 4. t Abst )lute Potential I 0,000 MCF 1 .6335 CERTIFICATE I, the undersigned state that I am th engineer of the Un ion 0 i 1 Company (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated t ereln are true, correct and complete to the best of my knowledge. Signature Gary E. Carlson 1.0 .5( D ,2( v w m P-1 .1C . 0; I (r. x-i �u �r U Q N 0 x O N .02 .01 Kenai Gas Field Back P,'sure Tests Well: I •s . AL Pool: Deep Survey Date: 7 -17 -75 � .o MEMENE MEI m IN MINE I N ME ■t a 1,. 0 2 5 10 20 50 100 GAS FLOW RATE rIQvICF /D GA 'JELL OPEN FLOW POTENTIAL TEST f ? PRESSURE CALCULAT10,NS (Supplement to Alaska'O & GCC Form No. G -1) Field Reservoir Test Cate Kenai Gas Field T onek 7 Operator Lease ..e I 1 ;;o, Union Oil Company of California A- 028142 KDU - 4L Test No. (I) Ps ns i a (2) Pf h- i (3) (Ps Pf X 10 (4) 0 '.'CF /D 1 2221 2200 9.28 4924 2 2222 2176 20.23 6800 3 2217 2131 37.39 9757 4 2208 2028 7 6.25 12601 Su - Surfa T est Data Subsurface pressures measured. �] Subsurface pressures computed: Cullender - Smith IIethod of 1 0 Test No. (1) Pws ns i a (2) 0 i a (3) ( PWS -Pw f 2 ) 10 - 4 (4) Q Nomenclature: Ps = Static surface pressure ' Flowing surface pressure Pws = •Static bottom -hole pressure (mid -point of perforations) Pwf = Flowing bottom -hole pressure (mid -point of perforations) Q = Flow rate, I.1CF per day at 60 ° F and 14.65 psia 1 -70 F.Wrm P_7 , SUBMIT IN DTJPI.ICATE * STATE OF ALASKA ( see other in- structions on 5. API NUMERIC CODE OIL AND GAS CONSERVATION COMMITTEE reverse side) 50- 133 -20176 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 6. LF.4BE DESIGNATION AND SERIAL NO. GRADE A 028142 7. IF INDIAN, ALLOTTEE OR TRIBE NAME In. TYPE 011, ❑ GAS � DRY El Other b. TYPE OF COMPLETION: AMOUNT PULLED NEW WORIC DEEP PLUG RIFF. WELL OVER ❑ EN BACK ❑ r.ESVR. ❑ Other 8. UNIT FARM OR LEASE NAME I Kena i Un i t 2. NAME OF OPERATOR -Union Oil Co. of Calif. 9. WELL NO. t 1 Kena Dee Unit 1 y #4 ( (3 3. ADDRESS OF OPERATOR 10. FIELD AND POOL, OR WILDCAT Kenai T onek Gas Pool I 4. LOCATION OF WELL (Report locat clearly and in accordance with any St to requirements) * At surface Ir SEC., T., R., M., (BOTTOM HOLE �ee Form P - OBJECTIVE) At top prod. interval reported be ow Sec 7, T4N R 1 I �V SM ' Sub�n i tted 7 -8 -69 , , At total depth 12. PERMIT NO. 69 -J2 13. DATE SPUDDED 14. DATE T.D. REACHED 1 15. DATE COMP,SUSP,OR ABAND. 18. ELEVATIONS (DF, RKB, RT, GR, .-rC)► 17. ELEV. CASINGHEAD 18. TOTAL DEPTH, MD & TVD 9. PLUG BACK MD & TVD IF MULTIPLE COMPL., ' 21. INTERVALS DRILLED BY SACKS CEMENT* DEPTH HOW MANY* ROTARY TOOLS CABLE TOOLS 22. PRODUCING INTERVAL(S), OF THIS COMPLETION —Top, BOTTOM, NAME (MD AND TVD) Loper P ®rf s 23 AL Middle Kenai 1 0420� 1 !0410 MD; 9379 -9417 TO SURVEY MADE + Yes ') L f1 :. 1 S r L' L' . ,.., �.. 1 ilJ �.. l]1V L if 1 it •'• ^ LV'\I,7 "iY V i� CASING RECORD (Report all strings set in wEll) - CASING SIZE WEIGHT; LB /Ft. GRADE DEPTH SET, (MD) HOLE SIZE CEA LNTING RECORD AMOUNT PULLED 26. LINER RECORD 27. TUBING RECORD SIZE TOP (MD). BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) . PACKER SET (MD) 28. PERFORATIONS OPEN TO PRODU (Interval, size and number) w I� 29. ACID, SFIOT, FIRAC'TURE, CE24ENT SQUEEZE, ETC., DEPT'II';INTERVAL (MD) AMOUNT' AND. KIND OF MATERIAL USED ' 30. T 'PRODUCTION ' DATE FIRST PRODUCTION PRODUCTION ME'T'HOD (Flowing, gas lift, pumping —size and type of PUMP) WELL STATUS (Producing or shut -in) September. 1969 P Prd DATE OF TEST HOURS TESTED CHOICE SIZE J PROD'N FOR OIL--BEL. GAS --MtF. WATER —BEL. GAS -Olt RATIO 1 2- 20-69 db' � TEST PERIOD FLOW TUBING CASING PRESSURE CALCULATED OIL —BBL. GAS— MC'F., WATER—BBL. OIL GRAVITY -API (CORR.) PRESS. Va HOUR RATE ; I• DISPOSITION OF OAS (Sold used for uel, vented etc.) TEST WITNESSED BY Sold B. Watts 32. LIST OF ATTACHMENTS * C m^ ����1.: W,fti 1 1, t: 1 ,ft- 0 4* _46 - I 'r --.& M-.4611: - .L.1�. IA 1 -11— V- -- ^ '(bee Instructions and Spaces for Additional, Uata on Keverse bide) 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments. given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone- (multiple completion), so state in item 20, and in item 22 show the producing -interval, or intervals,'- top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30 - . - Submit a separate "report (pare) on this form, adequately identified, for each additional interval to be _ seperately, , produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement ": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. - Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED. PRESSURE DATA AND RECOVERIES OF OIL. GAS, WATER AND MUD 35. GEOLOGIC MARKERS -- NAME NIEAS. DEPTH TRUIM 36. CORE DATA. ATTACII BRIEF DESCRIPrMONS OF LITHOLOGY. POROSITY. FRACTURES. APPARENT DIPS I AND DETECTED S'IIOWS OF OIL, GAS OR WATER. DEPTH Form 9 -530 (Rev. 5 -60) U l E D STATES SUBMIT IN DUPL. .'E * Form approved. ( See other in- Budget Bureau No. 42- R355.5. DEPARTMENT OF THE INTERIOR structions on reverse side) 5. LEASE DESIGNATION AND SERIAL NO. GEOLOGICAL SURVEY A 028142 9 rPF TVnTAN AT.T.nmm AD 1 'VAUl T` WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Ia. TYPE OF WELL: 0I1, GAS WELL ❑ WELL ® DRY ❑ Other b. TYPE OF COMPLETION: WELL OVER ❑ DEEP- ❑ BACK ❑ P. SVR. ❑ Other 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR 507 Northern Lights Blvd, 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 253 & 4209 from NW Corner Sec. 7 T4N, R I I W, SM At top prod. interval reported below See 9 -330 Form Previously Submitted At total depth 7. UNIT AGREE \TENT NAME S. FARM OR LEASE NAME Kenai LLn_1 t 9. WELL NO. Kenai Deen Unit #4(13-7 10. FIELD AND FVOOL, OR WILDCAT OR AREA Sec 7, T4N, RIIW, SM 14. PERMIT NO. DATE ISSUED 12. COUNTY OR 13. STATE I PARISH 1 Kena i A I aska 15 DATE SPUDDED 1.6. DATE T.D. REACHED 17. DATE COMPL. (R eady to prod.) 18. ELEVATIONS (DF, RIB, RT, GR, ETC.)* 19. ELEV. CASINGHEAD 2-11-69 29. TOTAL DEPTH, MD & TVD 21. PLUG, BACK T.D., MD & TVD 22. IF MULTIPLE COMPL., 23. INTERVALS ROTARY TOOLS CABLE? TOOLS HOW MANY* I DRILLED BY 24 . PRODUCING INTERVAL(S), OF THIS COMPLETION —TOP, BOTTOM, NAME (MD AND TVD)* I 2 WAS DIRECTIONAL Lower I'e r f s SURVEY MADE Middle Kenai 10428-10470 MD; 9379-9417 TVD Yep 26. TYPE ELECTRIC AND OTHER LOGS RUN 27. WAS WELL CORED 23. CASING RECORD (Report all strings set in,well) CASING SIZE WEIGHT, LB. /FT. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD' AMOUNT .PULLED' 29: LINER RECORD '30. TUBING RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MA) SIZE DEPTH SET (MD) PACKER SET (MD) 31. PERFORATION RECORD (Interval, size and number) 32. ACID, SHOT, FRACTURE• CEMENT SQUEEZE; ETC.. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED * " " PRODUCTION' ( t ype of pump) WE L STATUs DATE FIRST PRODUCTION PRODUCTION METHOD Flow- gas lift, pumping —size a t or shut-in) I ;September. 1 69 1 Flow Prt�d�c i r,n DATE OF TEST HOURS TESTED CHOKE SIZE PROD'N. FOR OIL —BBL. GAS —MCF. WATER —BBL. GAS-Oft RATIO y I I I TEST PER FLOW. TUBING PRESS. CASING PRESSURE CALCULATED OIL —BBL. GAS' —MCF:' WATER —BBL. OIL' GRAVITY -API (CORR.) 24 - HOUR RATE 34. DISPOSITION.OF GAS (Sold, - used for fuel,. vented, etc.) TEST' WITNESSED BY Sold I L Wa t I 35. LIST OF ATTACHMENTS 7T - ' .a. . . 'See "Gas We'll QDen F l o w Potential Test Ren©rtr", Al aska Farm G- 36. I hereby certify that the foregoing nd attached Information is complete and correct as determined from all available records SIGNED �_ "�' ^ TITLE Producti Eng DATE � /p *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: 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 State agency, or both, pursuant to applicable Federal and /or State laws. and regulations. Any necessary special instructions concerning the use of this form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are shown below or will be issued by, or may be obtained from, the local Federal and /or State office. See instructions on items 22 and 24, and 33, below regarding separate reports for separate completions. If. not filed prior to the time this summary record is submitted, copies of all currently available logs -( drillers, geologists, sample and core analysis all types electric, etc.) , forma- tion and pressure - tests, and directional surveys, should be attached hereto, to the extent required by applicable Federal and /or State laws and regulations. All attachments should be listed on-this form, see item 35. _ _.. - _- Item" 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State - or Federal office for specific instructions. Item 18: 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. Items 22 and 24: If this well is completed for separate production from more than one interval zone (multiple completion)-, so - state in item 22, and in item 24 show the producing interval, or_.intervals, top (s), bottom (s) and name (s) (if any) for only the interval reported in item 33. Submit a separate report (page) on form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 29: "Sacks Cement ": Attached supplemental records for this well should show the details of any multiple stage cementing and the location -of the cementing tool. Item 33: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) U.S. GOVERNMENT PRINTING OFFICE: 1963 --0- 683636 UNION OIL & GAS DIVISION WESTERN REGION A N C H O R A G E DI S T R I CT TRANSMITTAL TO: State of Alaska DATE: 9Z30Z69 FROM. Union Oil Transmitted herewith are the following: Run No. Final Sepia Blue Scale WELL NAME: KDQ #4 Induction Electrical Log 1 ea . 1 ea. 211 Dual Induction*Laterlog Original hole Redrill BHC Sonic /Caliper Log BHC Sonic /Gamma Ray BHC Sonic /Caliper /Gamma Ray Log _ Formation Sonic Log (Fs) Compensated Formation Density ' Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDM Safety Print,; _ CDM or Printout CDM or P o l ywog P lot (; 1 OW CDM Polar P 1 o is DIVISION OF OIL AND GAS Proximity tilicrolog /Caliper Log ANCHORAGE Gamma Ray - Neutron Log Gamma Ray Collar Log Cement Bond Log Si.dewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No.� Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut RECEIPT ACKNOWLEDGED: DATE: RETURN RECEIPT TO: Union Oil & Gas Division - Western Region Anchorage District P. 0. Box 6247,, Airport Annex . Attn: Rochelle Carlton woo UNION OIL. CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. 1 LEASE Kenai Gas Field WELL NO. KDU 4 FIELD DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2-11-69 62 12 430 13 746 14 1264 15 1264 16 1264 17 18 19 1264 Spudded Kenai Deep Unit r4 with Coastal Drilling Company Rig No. 4 at 2000 hours 2- 11 -69. Drilled 15" hole from bottom of driven conductor at 41' to 62'. Drilled 15" hole to 400'. Ran Dynadrill. Dynadrilled and surveyed 1.5" hole to 4 -30' . Dynadrilled and surveyed from 430' to 746'. Drilled and surveyed 15" hole from 746' to 1264'. POH. Ran 26" hole opener to 412'. Opened 15" hole to 26" hole to 1264'. Started running casing. Ran 30 its. 20" 94' H40 8RD ST &C casing, landed at 1234' with first four collars spotted and joint T11 spotted. Centralizers on first four collars and collar on joint 28 and 29. Ran Howco stab. in mandrel on 4 -1/2" d. p. and found shoe 26' deep. Ran Dia log collar locater and found joints 8 and 9 to be parted (Dia log = 943' to 969'). Picked up additional joint (joint T31) of 20" casing. Ran in 26'. Closed gap between joint 8 and joint 9. Checked with Dia log, found joint 8 and 9 in contact. Set 20, 000` on casing. Cut off casing. Welded pick up lugs on stub above rotary table. Ran 17 -1/2" hole opener to 1261'. POH. Schlum- berger perforated with squeeze guns, 12-1/2" holes from 1261' to 1256'. Welded cement head on stub of 20" casing above rotary table. 20" Casing Detail Bottom Top Length No. Jts. Description 1264.70 1262.10 2.60 1 20" 1lowco "Stab -in" float shoe 1262.10 26.00 1236.10 30 20" 8Rb ST &C 94 H40 csg. 26.00 17.20 8.80 1 Jt. x-31 below ground 17.20 -0- 17.20 1 Landed below rotary table Joint 431 = 41.46' Cut off 5.00' , cut off 9.16' Cut off 9.80' Cut off 8.70' Rigged up B. J. and pumped 2400 cu. ft. Perlite mix (1 /2 cu. ft. Perlite per sack "G" cmt with 1% D31 and 6% gel), followed by 300 sacks class "G" cement. Mixed with fresh water. Displaced cement with 1815 cu. ft. mud (theoretical depth: 910') and held. Good returns to surface during job with approximately 900 cu. ft. excess. CIP at 0100 hours 2/18/69. WOC and prep to install head. Cut and drained conductor. Welded 20 "x2000:= Cameron casing head and tested to 500 psi ok. Installed hydrill, kill and choke lines. Shut rig doiwn for repairs to compound at 0600 hours 2-19-69. JUL 2 41 DIVISION OF OIL A4ID C 1 UNION OIL CO. OF CALIFORNIA DRILLING RECORD LEASE Kenai Gas Field WELL NO. KDU i�4 FI ELD. SHEET D PAGE NO. 2 DATE I E. T. D. ] DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 -23 1264 Rig shut down for additional rig up and repairs. 24 1264 Pressure tested 20 "x2000* Hydrill G. L. to 900 psi 10 minutes ok. Tested (10 hrs.) E. D. 920 Kelly Cock to 2000= 10 minutes ok. Tested mud system to 3000 =.`. Ran in hole, found top of cement at 920'. Circulated and conditioned mud. 25 1275 Tested Hydrill accu, time to close one minute, fifteen seconds, Drilled (18 hrs.) medium to firm cement from 920' to 1260`, Circulated and conditioned mud. 26 1859 Circulated and conditioned mud. Raised weight to 78'. Drilled through shoe at 1264' to 1275' with 15" bit. POH. Changed drilling assembly, RIH, circ, jets plugged. POH. Removed jets, RIH. Tested choke manifold, found frozen. Thawed and filled with diesel. Circ. , repaired compound one hour. Drilled and surveyed 12-1/4" hole to 1859'. Lost approximately 30 barrels mud at 1673'. Added Mica -Nut plug. 27 2526 Drilled and surveyed 12 -1/4" hole to 2526'. POH for bit change. Stuck at , 1878`, Worked pipe free. Picked up Kelly, drilled to 1918', twisted off drill pipe at 331' (middle of single) while drilling. Ran overshot with mill control, milled over ragged top. Unable to make overshot hold. Ran Dia log through ragged top for check, ok. 28 2526 Ran overshot with mill control and extension. Caught fish, POH with all drill pipe, B.S. , X -Over, stabilizer, and 2 SDC. Backed out of stabilizer. Ran Dia log to check casing and found it to be ok with no breaks. Mixed mud pit volume and picked up collars. RIH, screwed into fish at 1561', Jarred on - fish to 250, 000= for 1 -1/2 hours. Worked pipe from 1918' to 1850'. Pipe freed at 1850'. POH, laid down fishing tools and drill pipe, 3- 1 -69 2669 Continued laying down drill pipe. Changed drilling assembly, RIH . Hit fill at 1920', reamed and circulated from 1920' to 2526'. Drilled and sur- veyed 12 -1/4" hole from 2526' to 2669. POH to change drilling assembly to stop building tendency.. Found extremely tight hole from 1860' to shoe at 1264'. Tripped Dailey jars approximately 12 times coming out of hole, 2 3671 Changed drilling assembly, RIH, washed to bottom. Drilled and surveyed 12 -1/4" hole from 2669' to 3671`. 3 3957 Drilled and surveyed 12 -1/4" hole from 3671' to 3957'. POH to change bit - and d, a. Tight from 2000' to shoe. Made up d, a., RIH to 2200'. Tight from 2000' to 2200'. POH to repair mud line. Repaired mud line for 4 hours. RIH. .4 5003 Drilled and surveyed 12 -1/4" hole from 3957' to 5003'. Lost 1 -1/2 hours, Sand line unit down, changed shaker screen, lost �2 engine clutch. 900 Edits ! of gas from 4080'. 5 5540 Circulated and surveyed. POH, change bit and stabilizer. RIH. Drilled and surveyed 12 -1/4" hole from 5003' to 5540'. Circulated and POH. JUL 2 41 9 DIVISION OF OIL AND C. k ANCHOw L UNION OIL CO OF CALIFORNIA SHEET D DRILLING RECORD PACE NO. 3 LEASE Kenai Gas Field WELL NO. KDU FIELD DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 5540 POH to shoe, RIH, circulated. POH prep, to run logs. Schlumberger ran DIL, FDC -GR, SNP -GR, FN -OL. Schlumberger unit down one hour (defec- tive wiring) . Change d, a, picked up 17 -1/2" hole opener. 7 5540 RIH, opened 12-1/4" hole to 17-1/2" from 1241' to 2965'. Rig down 1-1/2 hours repairing rotary chain and stand pipe (3/4 hour each). 8 5540 Opened 12 -1/4" hole to 17 -1/2" from 2965' to 3846'. POIi, Changed hole opener. RIH, opened 12-1/4" hole to 17-1/2" from 3846' to 4036', 9 5540 Opened 12 -1/4" hole to 17 -1/2" from 4036' to 4337'. Opened very slowly 4 hours. POH. Changed hole opener. Rig down one hour repairing mag. on number one engine, RIH. Opened hole from 4337' to 4445'. 10 5540 Opened 12-1/4" hole to 17-1/2" from 4445' to 4820'. D1000 pump failed. Open -4820' Switched to GXR, and belts failed. POH to shoe. Tested Hydril, ok. Circulated while making repairs. 11 5540 Repaired compound. Opened 12 -1/4" hole to 17 -1/2" from 4820' to 5197'. 12 5540 Prep to POH. Stuck pipe at 5292' (50' off bottom). Bumper sub on top of Opened to collars was operable. Spotted pipe lax around bottom 200' of tools. 5342' Attempted to drive tools down with no success. Ran Dia Log, found free. point at top of 6-1/4" collars . Backed off at top of collars. 1; O H to pick up fishing tools. 13 5340 Picked up fishing strin8 s /Daile }- ji =rs, bumper sub, wall d.p. O to 8" collars. Scr - owe d into top o 6-1/4" col lars. Jarred up & down, 5342 . - /no success. Backed off top of collars after se -c-ond attempt. POii to at tempt washo y 14 5540 RIH =w, sash over pipe k /11 -1/4" sloe. Unable to wa sh over top of l5 O pen'--d to collars. POII. Run /4 -1/2" MIMP single and "J" unlutchi;,g s 5342 Screed sin.` le into top of sib on tap of 6 collars. RIH .ti -1J 4' cripp'_ed shoe w /up guide. 1 ; ached over from 4635 to 4S_35'. P011, fol-ind fish hid not be , n inside ;.ash pi . RIH ti•; J ''J'' latch stinger, bu:iiber sub, cil jars, Q" collars and heavy call. Attrnpted to jar fish loose with no � 4SVcL . 16 5540 POH w/fis :ing strinc. , . lade up 15" shoe on 9 -51811 IKO pipe. RIH to Ope.,ed to 46 rushed over to 4681 Unable to Hush deeper. P011 to run 53142 small s hoe w /guide 17 5540 R3Lt k/ l'0 Pipe .:/sin +gA.e of drill pips and drib collar spear and s? Min° 0 ;tined to guide. Latched into "J" tool o. sin tole above 6 -1/4" collars. S.,allo.tied SL47 both Sing and "J" tool. , Was hed o t 47 23 ' . Unable t 1-;ash deeper. Approx penetration rate 1' to 3' /hr. POIi, laid down.ttiash pipe and tools. Circ. Pren to plug hole. 18 4210 � =ith open end drill pipe hun. , 4620 Pr pd 200 cu ft water mixed tiy/ �V cG -?isi tc f alisW v v��t� -', liea �- ei:lcn mxd w S.r wato-Y 1; sand and ? CaC' ,. Ui rtplaced slurry w/ cu it „ater and 2S5 CU ft rt�d, C .T.P. � 0'.30 r�rs. PC I! w /dp. :Iade up d.a. to dress JUL 4 vuzy DIVISION OF OIL AND r. ": UNION_ OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. LEASE Kenai Gas Field WELL NO. =VDU °=4 FIELD DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS plug, and coed mud while ;IOC. Changed sp on rotary. R.I.II. while 111'X. Changed sprokets on rotary. RIH. Found cement 416 Drilled to 4210' . PO-Ti. 19 4210 Pulsed to sloe. Treated and cond mud. Staged to botto-m. Cond mud. tagged cep ent @ 4210' w / y5,0�00 and p :p running. PO11. Prep to dyna drill. Pulled into crown first stand Lnside shoe. Rig down for repairs to crown. 20 4210 Repaired croon @ 211)30 hrs . POI. 21 4360 °G11. Chanced d.a. R11_1. yna. drill. Dyna drilled and surveyed 12 -1/4" hole from 4210' to 4.> . P01-1. 22 5020 Changed d.a. RIH, drilled 12 -1j4 hole 'Zo 4413' and surveyed. Direction sti11 turning. Pulled back to 4210 Rea. ;ed hole to 4360'. Drld and sure --yed 12 -1 hole to 5020'. 23 5290 Drld and sureyed 12 1/4" ho le from 5020' to S'90' . Rig down 1 -1/4 hrs to repair rvtar;° driVe and pumps. Ciro, POH. Changed bit and d.a. ' t ti RIIH w /d- -na dr 24 5552 D drilled' 12 - hole from,: 5290' to 5355 Sur! P01 Changed d.a. RIH. Reamed from 5290' to 5355. Surveyed. Drld and survev d 12 - 1/4" hole from 5355' to 5562 25 6050 Drld and surveyed 12 -I /4" hole from 5562' to 6050'. Circ. Gas kick 5830' . cud cut fro;, 877": to 84 � cu ft. 26 6030 Rap. Schlu- DT.. Bridge failed. Ran FDC. Unable to get to bottom. S t o Aped 5359' . `Iadv c ean out run Ran DIL, FDC, SNP. FDC failed. Re - ran FDC. 1 ad, e up hole opener assembly. Ran into 416-5 Circ Prep to open hole. - 27 Opened 12- hoee to l7 -l j2'' hole fr om 4210' tp '4 Reared around dyna drill rus from ;210' to 4;60' tlnti! no torque encountered. Running --- 2 pips on hole D100 Emsco, D500 i~msco. Approx annulus velocit 70 FPM. 28 6050 Opened 12 -1/4" hole to 17- 1,12" from 4484 to 4940 Opened to 4940 29 6050 Opened 12 -1/4" hole to 17 -1 /2 " hole fro 4940' to 5220 Round tr Opened to to chance hole opened and reamer cutters @ 5026 5220 30 6050 Opened 12 -1/4" hole to 17-1 hole fromm 5220' to 5180' . Rig down Opened to 5 - 1/2 hrs repair inb D500 puMM, Down 1 hr cutting 3" off fl line 5480 pipe (Rag settling 31 6050 Opened 12 -1/4" hole to 17 -1 hale fro:, 5480' to 56S6 Rig doti.m Opened to - ?/4 hr starting mfotves and replacing valve in D500 pump, round trip 5686 to c1; ngi 10 cutters 20 JUL 2 41 ANC UNION OIL. CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. S LEASE Gas Feld WELL NO. k,Dil r FIELD DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4f if 69 6D50 Opened 12 -1 /�" hole to 17 -1 /2" hole from 5656' to 5871' . POii. Chngd pe neu to hole op. -ne and rollers in reamer. 5571 2 6050 RIH. OsJnd 12 -1/4" hole to 17-1/2" hole from 5871' to 6050 Circ palled to shoe. 5 -114 hrs. to change dril lbng line. RI}I. Circd. 3 6050 Cir:, and cr l. di Hole. POI, Fa. a+ d Ind 158 its 13 -3/8" J55 61" seal—lo, =; csg st,fba e?' Model "G" Differential sho- � 6026' and'. Baker Model "G" Differential collar 5048,70. Csg Intl t;T/3.99' above rotary tablo'. Centraliders located - 6 5990 5974'; 5572; 3949; 1752; 159'; 113'. 13-3 Cas; ag Detail jt. 1 3 -af8" Baer '��. it Dif_ferentia1 shoe 2.65' 6026.00- 6023.35 ft 3.,.9., 6 0��. �s- s .,��3.4s 1 Jt, 13 -3/8" 61 J55 Seallocr: ese a 2' 23 0 - 13 -3 i8" :aver ,� ,� �, ¢; ' .95' 59S3, 43 -59Si .48 ,. .1-od' G Diffe en' ai Shoe 1 156 it-s. 13--3/8" Jts. ` 1 2 thry3 4157 6i-# J55 5948.17' 5981.48- 33.31 - Seallock La 1 jtz , ?3 -/8" joint `158 below Casing Bead 1' 33.31- 16. SO - 1.5 -3/8" J oint `15S La nde.: Rtilov� R.T. _ - - _ 16.80 -- 0 158 Jess 6026.00' 3 600 3,99 -so a'Do F e R.T. wh l amed ed . Nally +iae'�Oii �Ts":;ii fiC'aCi had to be cut off. Cut offs s V an 10' ii j,xe :; 2 309 . %. CIass "G'' cm it S.; f . cu ft perlite-- per sack, 6 Jel and 10 D3 with fresh wtr to a 109'f 4618 cu ft sl :rry fo1lolb. ;ed by 950 sir Class "G" Come nt r ixLd ti : /fLresh water to ? 118 10:3 C -U f` slurry. Total s lurry 5701 cu ft c3 spIacc d W/ bbls m.d. Did no. b — 76p plug Csg dsisp?acc -m- , .t without. co- Mpres :,lon fact 91.2 =D��. Bled off Csg Floats 0K. CIP 10 p..;l, k; • >/69. (Good reiz.rns to surfrce) rem o�.�ed3 hydeil, cut- pitbh - i ;ipr,le. b04C► I;?S t ld ty p " A" Cameron slips and packing aro�us dl 13 csg ! 6026 c5� „- �"�� - ; 20" bo:.1. Cut off cs Il.stali�d sl sps Ind u;, apr,. ox. 1 90,000' , e� t lr, tyy>> : F Cabs= eror 13 -5/8" X 20" csg k :ca . Cnt had n ot fallen bac}: in 20" at tilY. slips were set. Tstca bottom, "P" seal to 2300`. 0*:. Top "P" seal to 1000 = OK, Sheds above 100,0 . Inst'd 13 -5/8" 5000" by c ri i and Shaffer BOP. Inst ld chok=e_ manifol w 5000" ball valv4 and Camcron HCR valve. Double valved ki ll line ei /check outboard of doub vat 'es. Instld ne-a accum, lines to hydlril and BM). 5 6050 Instld new accuin. lines to hydri1 and SOP. istd blind raiis, pipe rams, hydr11., Canneron. l %utomatic Vai've, choke - mm ni— and k elly conk to .3000:. Irst1 3a>;p Arne ar;1 i. �lt lane. R: C i1 r S t0 IIIl1d1 line a rlli derrick braces. 6 6050 Repair derrick braces, rotary .-nd puump drive. Mali e trip monels and Stab. on BOE w ur ree�ltickles . 21, hr down repairing �' o`..�'V ClA. ibi Foci i - 7 6050 Z"Air:e hrs P.11 with d.a. and rubk)er drill pipe. Pepair rig 21 hrs. (Pumas, ro,.a -..% etc.) 8 6050 RI HI - RubuLred drill n_ - o e. FoL1nd' cemLent `j 55E'W . Tstd kill l 0 _ 1 30 PSI. 0K. ET:r: GYR an u D1 fail J C..urin-, ts_ and , - Started to d r i l l - _=t . Ro did Tn t v ' att? D =7n 19 hrs , C: a: gdd o L ?., rar st,°er L? rota ; y. Ori l ? � to JUL2419 UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. { LEASE Kenai Gas. Field WELL NO. K1' )U i. 4 FIELD DATE I E. T. D. , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 th 11 6050 Repairs - change engi to diesels 12 6250 Finish re;oairg - drill out cm collar and shoe. Drill 12-1/ hole from 6050' to 6230 13 63451 P01 to chap e d -a. - Rag do "n 3 -1/2 hrs. to replace water tanks. R.I.H. ,ldy a drill_. Dyna drilled and surveyed 12 -1/4" ho?e from 62 5 0' to ' 0345'. 14 6431 Dyna drilled and sur 12 -1 /4 1' hole from 6345' to 6350' . P011 to chance bit and d.a. RIH with follow up asst'. Drilled and sur��eyed 12 -1/4" hole from 6380' to 6431 POH to change d.a. RIH %.; dyna drill. 15 6500 Dyna drilled and surveyed 12-1/4" hole from 6431 to 6500'. P011. Cha ,aed d. a. and bit. RIH. 16 6549 D and sum v yed 12 -1/4" hole from 6500' to 6530 Did not get expL:.ted turn on bottoi<a of dyna drill. Run again. POH. Change d.a. RIH with dy3na drill. Dyna drilled and surveyed 12 -1/4" hole from i 19 ' 0330 t. o 65 =�_� 17 6785 DD I2 -I,` hole frog G S9' to 65; 5' . Su_veyed and P011. RIH �; /loct:ed assembly. Drilled I2 -1/4" hole from 6575' to 67881. 1S 7152 D and S 12-1 hole from 6788' to 7055' . Dropped survey. P011 for bit change. RIH w/ne , bit. Drilled 12 -1/4" hole from 705:' to 7162 19 7465 Drid 12 -1/4" ho- f-rom 7162' to ' . Dropped survey. P011 fcr bit change. :RIH. Dr ld 1' -1/4" hole from 377' to 7465 Chanoed :cud nits to c irc th ru both. 20 7709 Drld 12- 1 /4't hone fr; - "65' to 7678 Dropped survey, P01I for bi t change. Rill. Rea ^ed fro � 6050' to 61S0 . RIH to bottom. Dri 12 -I l hoe from 1678' to 7Down 09. Don 1 hr. for repairs repairs on fuel lire 4 r't and D. 0;:. 21 7866 DrIal 12 -1/4" hole fro;. 7709' to 7565 . Dropped survey. POH for bit change . R1H to shoe. Rib do,% n to repair purmps (6 hrs.). 22 8066 RIH to boyto=�. Drld 12 -1/4'' hole from 7866' to 8066 Dropped survey. POH for bit charge. 23 8206 RIH. Drld 12 -1/4" hole fro 5066' to 8266 Down 2 hrs for repairs to headache post. 24 8373 Drld 12 -1/4" hole from 5266' to 5310'. POH for bit chance. RIH. Drld 1 . 2-1/ 4" Hole fr om S 31 0' L SJ73' Surveyed @ cS.76J' . �5 8 25 Drld 12 -1/4" hone from 5373' to 85?S'. Dropped surve P011 to change d.a. and bit. RIH �{ /net; d,a. and bit. Down 2 -1/2 hrs. worki;�-1 on 26 5740 bR IH. Drld 12- 1 hole from 5525' to 87 -,0' . JU UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. 7 LEASE Kenai Gas Field WELL NO. 1�4 FIELD - DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 27 8850 Drilled 12 -1/4" hole fro,:± 8740' to 8764 Dropped survey. POII for bit cha nge. RIH w /nee, bit. Drilled 12 -114" hole from 8764' to 8850' . 28 8916 Drilled 12 -114" hole from 8850' to 8916 Dropped survey. POH, changed drilling assembly and bit. Found bad connection on monels. Exchanged cone is . Down 2 hours work or drawworks . R? 29 9015 RIH, surveyed. Drilled 12-1/4" hole fro 8916' to 9015 Rig do-wn for repairs to swivel (9 hours). 30 9100 Completed repairs- to swivel (4 hours). RIH. Drilled 12 -1/4" hole from 9015' to 9100 S/ 1/69 _ 9304 Drilled and surveyed 12-1/4" hole from 9100' to 9304 POII for bit - change . 2 9390 Made rig repairs; drill-ed 12 -1/4" hole from 9304' to 9390 3 9564 Drilled 12 -1/4" hole frola 9390' to 9564 Dropped survey. POII for bit change. RIH. Made pump repairs. ' 4 9725 Drilled 12 -114" hole from 9564' to 9725 Dropped survey. POH for bit chin ge . 5 9999 R111. Found bridge at. 9513 - 9544'. Washed and reamed to bottom. Drilled 12 -1/4" hole frof.n 9725' to 9909 Dropped survey. POIi. 6 3 0,029 POH for bit change. RIH. Drilled 12 -1/4 hole from 9909' to 10,029' . Dropped survey. POH. 7. 10,246 POI. RIH w /:yew bit. Drilled 12-1/4" hole from 10,029' to 10,246 8 10 Drilled 12 -1/4" hole fron 10,246' to 10,282 Dropped survey. POI -I. Changed d.a. and bit. R 1 H. Drilled 12 -1/4" hale= from 10,282' to 10,3 9 10,410 Drilled 12 -1/4" hole froma 10,319' to 10,400 Dropped survey. POIi for bit change. RIH, drilled 12 -1/4" hole fron 10,400' to 10,410 10 10,549 Drilled 12 -114" hole fro.. 10,410' to 10 Dropped survey. POH for bit charge. R111, rearmed last 60 11 10 Drilled 12 -1/4" hole from 10,550' to 10 POH bit #31. 12 10 RIH >•., /bat 732. Drilled 12 - 114 " hole from 10,655' to 10,736'. POH. 13 10,836 POH. Chcugved bit. RIH w /bit r33. Drilled 12 -114" hole from 10,736' to 10 , 8 56' . 14 10,921 Drilled 12 -1/4" hole from 10,836 to 10,867' . Dropped survey, POH for bit change. RIH w /bit °34.' Drilled 12 -1/4" hole from 10,867 to 10,921 15 10,979 Drilled and surveyed 12 -1/4 hole from 10,971 to 10,979 16 11 Drilled and surveyed 12- 1 hole from 10,979 to 11,077 17 11,089 Pulled out of hole for bit cha;;ge at 11,077 1 . Hole ver; tight. Drlled up out of hole througa coal at 9066 and 8446'. Changed bit. RIH to 11,077 Drilled{ 12 -11/4" hole to II,0�9 Sv.ivel packyn out ' b1eo Made wiper trip to shloe. J 241 k I'D' UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. LEASE Kenai Gas Field WELL NO. I%DJ #4 FIELD DATE I E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 18 19 20 21 22 23 24 25 27 28 11,151 Ran back to bottom after wiper trip. Drilled 12 -1/4" hole from 11,089' to X 11,109' . Swivel packing blew out _gun. Made repairs. Drilled 12 -1/4" hole from 11 to 11,151 11,151 Dropped survey. POIN. Changed bit and stab. RIfi to shoe, changtid swivels. RIH, circ. and cond. mud to ruts logs. POH. 11,151 POH 50 stands. Several tight spots. Pulled to 340,000 #. RIH, circ. and cond. mud. POH, pulled to 7897 where pipe stuck. Attempted to drill up out of hole. Pipe parted 219' below RT.- Ran overshot bump^r sub and jars. Pipe dropped to bottom. Top of fish at 3254 Picked up fish G circulated. Pulled 2 stands and pipe parted. Screwed into fish. Pulled to 10,636' where pipe stuck. Unable to -jar fish free. WTLile jarring, pipe parted w/a loss of 100,000# measured out of hole. 11,151 Layed do approx. 150 jts. Bent drill pipe. N►ade up screw in single, b7�:per sub, dailey jar, 2 singles, hwdp, and oil jar on 15 singles, hwdp on 4 -1 /b' drill pipe. Ran in hole and screwed into fists at 9769' (Dia Log), circulated and jarred but unable to move fish. Rigged up Dia Log to back off. 11,151 Backed off a- 9828 Recovered 1 single h . dp. R131, screwed into fish at 9800 Backed off a, 9918 Rec.ov eyed 4 sing les h:ti}dp . 1 RIH, screwed into fist Backed cuff at 10 and recovered 3 jts. hvdp. RIH, sere: }ed into fish at 10,013 Pulled on fish; gained 20,000# wt. POH, recovered 13 jts. hwdp. Backed off 2 singles above collars. 11,151 RIH w/ fishing asse sly. Unable to screw into fish. PO'ri. Made up overshot on fishing ass'y. RIH, caught fish. Unable to :pork fish fret. 131 3% 151 Attempted to back off fish. Drill pipe unse.-e approx. .600 down and dropped approximately 4 Stripped one single over Dia -Log line, Screwed into fish. Backed off overshot. Attempted to pull drill pipe, stuck at 9746 bomked pipe. ;Jarred down until pipe loose. Fran pipe to bottom (10,412' tole of fish) . Shot Dia -Log dry pipe slot down in bLLPper sub u/ bumper sub extended. Shot bumper sub twice . \o success. Shot dry pipe shot at overshot, attempting to break up guide. Spudded and drilled down with overshot erg top of fish. Unable to stick or b - reak u - p overshot. Pulled up into tight spot a- 9746 Stuck pipe in keyseat to back: off pipe; while torqueing pipe, pipe Wnscre; red at approx. 1100' and dropped to bottom. Stripped 7 stands and 1 single of drill pipe over line. Screwed into fish. Recovered Dia -Log line. 11 POH w /dr i Il pipe. Found overshot. missing, which al lowed pipe to pull 10,409 ED through k.ey seat. Laid down approx. 65 bent jts drill pipe and 46 bent jts h ;gdp . Ladd down balance of bent drill pipe (total 250 jts). ti,casure in hole found top of fish at 10 Circulate for loos. 10 ED Circulate and condition for logs. POH. Run DIL and Sonic Log, RIII for SNP Log. round s -icki nb condition. Discontinued logging. RIfi . -1/4" bit to condition hole for casing. JUL? RE -. UNION OIL CO. OF CALIFORNIA DRILLING RECORD LEASE Kenai Gas Field WELL NO. KDD n FIELD SHEET D PAGE NO. Q DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 & 30 10,400 Strunig 10 lines for csg. RIH, circ. and cond. mud. Ran Dia -Log collar shot in sub above stab. Parted sub w/shot. POH, leaving top of fish at 10,400'. Ran and landed 251 its of 9 -5/8" Seallock csg w /Iiowco float shoe at 10,310' , Howco flo=at collar at i0, 232' and Howco self -fill collar at 10 I 230 Csg larded w/8.66' above RT. Centralizers located at 5986', 5946 5906 9 -5/8" Casing Armco Seallock -Bottom Trap Length Joints Descriptio 10 10,307.91 2.09 - -- Howco float shoe 10,307.91 1- 0,267.25 40.66 1 53.5# P110 Arr�yco Seallock csg. 10,2'67.25 10,231.52 35.73 1 53.5.# „ 10 10,229.70 1.82 - -- Howco float collar 10,229.70 10,.C.., 2.17 - -- Howco self. -fill piff. coliz 10,227.53 8 2 49 53.5" P110 Arriico Seallock csg. 8,206,05 5 2 61 47# P110 Armco Seallock csg. 5 4 1,539.74 37 47' N80 Armco Seallock csg. 4 35.03 4,158.65 101 43.5 ti80 Armco Seallock csg. 1 53.5 # = P110 Armco Seallock csg. 35.08 14.50 20.58 - -- Csg belo. ,.r landing head 14.50 - -_0- 14.50 Cs g landed below RT. 10,310.00 251 TOTAL 8.66 -csg. above table 23. 16=cut off i t. 9 --5/8" 53.50' Armco Leallock csg. Circulate prepare to cmt. Pumped 50 cu ft. water in front of crrt . Pu 1ped 915 sks class "G" c,-.qt w /l /2 cu.ft. Perlite per sack, 6° gel and I' D31 mixed w /fresh L=ater to a 94T slurry. This followed by 500 sks class „G„ cmt W/1% CF R2 mini xed w /fresh water to a 118# slurry. Total slurry 2 cu. ft. 100 cu. ft. water pumped behind cnt. Disp l.accd ;;/4077 cu. ft. mad. Btm-,ped p pressure. CIP at 9:00 a.m. S/30/69. Remo WE cut pitcher Nipple. Installed Cameron "CA" slips around 9 - 5/8" csg. Slips landed ; /a�,pprox. 250,000'. Cut off casino. Installed Caneron "DCB 13 - 5/8" 50M x l 0 ' 5000' tubing head type spool.. Packed X bush and tested to 5000. Test 01:. Installed 10" 5000? hydril and Shaffer BOP. Installed choke rigawifold - vr/5000� ball valve and Cameron 11CR valve. 31 Installed double valves in kill line w check valve outboard. Installed accunnu?ator lines to BOP. Tested blind rams to 35009. First test proluced leak in flange connection in lines. Second test ok. Changed pump liners from 6 -1/2" to 5-1/2 in both pumps. Laid down l joint damaged drill pipe, cleaned floor of casing tools. Picked up d.a. RIH. Strung drag line to 8 lines. 6/ 1169 Tested pipe rams and hvdril to 3500 ok. Tested choke and kill system ok. Drilled out cmt in ° -5/8'' csg from 10,224' to 10,340'. Found float collar at 10,228'. Cleaned out to top of fish at 10,400'. Found float collar at 10,228 Cleaned out to top of fish at 10,400 ,tiith open end drill pipe, hung at 10 pumped 125 sx 1_ CFR2 and "G" cmt. m ixed w /f.resh water to a 122# slurry. Displaced v; /.2.0 cu. ft. water and 790 cu. ft. mud. Pulled 3 stds. to 10 and circulated. MI, laying dotgn bent d - ri 11 pipe. 2 10,330 Laid dov n bent drill pipe. Changed bit. RIII ;ti� /bit '39. Found clot at 10,130 Drilled cm to 10,330 Circ. and P0 for Dynadrill. 3 10,451 RIH SY= /Dy-nadrill. and bit x`40. OriCnted,Dvnadril ±e� 8 -: ?K," hole from 10,3 0 to 10,364'. PO'� Laid down Dy; 4uri ll. RIII w, 'da an,% bi �til, Gri lled 8 -3 /8 TH hole 47 ro ? 10,304 tC? 10,451 �t i ri J u' 241 I r,.,,ISION nr � ; v f UNION OIL. CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE N O. 10 LEASE Kenai Gas Field WELL NO. `;DU � FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4 10,5f s 10,702 6 10,778 7 10,810 8 10,810 9 10,810 10 10,810 11 10,810 12 10,810 i3 10,810 Drilled and surveyed 8 -3/8" hole from 10,451' to 10,512 POH for bit change. Changed nonels. RIH w /bi #42.. Drld and surveyed 8-3/8 hole from 10-,512' to 10 POH for bit change. POH -RIH w, /bit #43. Drld 8 -3/s3 hole from 10,574' to 10,643' . POI-', for bit chang. RM w /bi.t X44. Drld 8 -3/8 hole from 10,643' to 10,702' . POH for bit change. RI,i w /bit #45. Drld 8 -3/8 hole from 10,702' to 10,753' . Dropped survey . POH for bit change. RIH w/bit R46. Drld 8-3/8" hole ftom 10, 759' to 10, 778 Drld 8 -3/8" hole from 10,778' to 10,810'. Circ and coed mud. P0. to log. SchlumLberger unable to get equipment to operate. Ulf to re- condition. ;cud. Circ. POH to rain logs. Schlumberger still having trouble w /equip. Ran DIL twice, one faiia --.-. Ran Sonic twice. No SP. Rap. di.pmeter, failed. Ran Dipmoter second time. Stud dip meter at 10,690' . Pulled 9500' 6 times on .ire 1iy, Yizllcd loose. Logged from 10,630'. RIH. Circ. and coed. to, run 7" liner. P01. Made up 483' 711 liner. RI Liner stopped at 10,335' . P011 w/ liner. Pulled and laid down line Found malleable bull nose off float shoe missing. RIH w /mi 11 on 3 ft rea> er to 10,81.0' . No indication of junk. Conditioned m.ud. POH and laid down mill assembly. Ran in hole w /locked up a.ssea:ibly w /tandem reamers on bottom to 10,810' . No restrictions. Reamed from 10,310' to 10,372 Ran 7" liner, stopped at 10,335' . Pulled liner. POH w/liner, RIH w / 1" collars and 7 -3/4 X 10" expandable 110. Opened 32 hole fro-? 10,0' to 10,373' . Circulated clean. POH. RIH v, w /r;�ul; shoe ext . on shoe. R1r. W1 TI bngr & w /liner on hydrae is set slips, J slot and no pack off. Found tight spot at 10,335 Rotated throucl3 it. Bottom Top Length r Joints Descri 10 10,755-78 4.00 1 7 29 Extens io a w /mule shoe 10 10,753.86 1.92 1 7 T11 Float Shoe 10 10 40.95 1 7 29� N80 Buttress csg. 10,712.91 10,711.88 1.03 1 T' TU' catch collar 10,711.88 10 41.76 10 7t 29:7 N80 But-tress csg, 10 10 13.20 1 7 T1111 Liner hanger 10,280.92 10 17.68 -- 7 setting tools 10 -0- 10,263.24 Landed below zero Ran 11 its 7" 29#7 N80 buttress casing Iry /7" T1 tv float shoe at 10,75-5 and 7 29 N 80 eX.:ension ',� /mul.e sh �Q al" 1 0 , _ Tlti�` eii i ch collar at 10,711 1 . Centralizers at 10 and 10,,258'. Landed bola -0- w/ top of line: at 10 Puriped 13+0 sxs "G I' cmt wll � CFR2 mixed %, /fresh water to a 116# , 1 -56 cu, ft , slur preceded by SO c:�. ft . water and fol lowed b, 10 cu. ft . wat CIP 4: 30 a.m. 6/13,/69. Pulled 4 stands. Circulated clean. POH. Laid do t tools and "Heyi ', drill pipe. Picked tip 9 - /Sz csg scrap RIH. F ound no ci•,t. in 9-S'8" Cs- to 10 , zoo , P01- � V1 . F7 1 _ �'ISt N UNION OIL CO. OF CALIFORNIA DRILLING RECORD LEASE Kenai Gas Field WELL NO. DU #4 FIELD SHEET D PAGE NO. 1 l DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 -14 -69 15 16 17 is 19 10,810 POH. Picked up 3 -1/2" d.p. and 7" csg scraper. Rlll. Drilled out cmt from 10,700' to 10, 7111. Circulated clean. POIi. Schlumberger ran correlation log and shot four 1/2" holes at 10,315' to squeeze li .-r lap. Rill w /Howco RTE'S tool. Set RTTS at 10,208'. Pumped 50 cu.ft. water at 17CIPM . at 3400 PSI. Mixed and pLV Pcd 130 sxs class „ G" cmt w11 CFR2 � /fresh water to a 1160, 156 cu. ft. slurry, followed w/6 cu.ft. ,,ater. PtU:ped 605 cu, ft . mud, close'l tool. Displaced w/222 cu.ft. mud at 16CFM at 3400 PSI. Shut down 10 min. Pressure bled back to 2500 PSI. Staged in 10 cu.ft. in 3 min. Pressure built to 3000 PSI. Shut down. 5 min. Pressure drop to 240 PSI. Staged in 5 cu.ft. in 3 min. Pressure to 3000. Shut down 10 min. Pressure drop to 2200 PSI. Staged in 5 cu.ft. in 2 ;yin at 2500. Shut down 30 ;yin. Pressure drop to 1800 PSI. Staged in 5 cu.ft. - bled back. Pulled tool loose. Reversed circulation and cleaned out drill pipe. 10,810 POH. RIF] ,./9 -5/8" casing scraper. Cleaned out cmt 10,209' to 10,280'. POH. Picked up and F.IH w /7" casing scraper. Cleaned out cmt. from 10 to 10,350 Circulated clean. POIi. RI11 w/Howco RTTS tool. Set tool 1 -0,209 1 . Piziped 50 cu.ft. water at I6CFNI at 3600 PSI. Shut dov7n 2 mein. pressu -re drop to 2200 PSI. Bled off. Ptt� ped 200 sxs crit. w/1 o CFR2 .- /fr ;.sh ,•rater to 118=`, 240 cu.ft. slurry. Pumped 8 cu.ft. t,at.cr. PtiT ped 5?6 cu.ft. mud. Closed tool. Displaced 298 cu.ft. to 38 00 PSI. Shut down S -Min . Pressure dropped to 3200 PSI. Staged 3 c_u.ft, in one min. to 3800 PSI. Shut doxn 5 min. Pressure dropped to 3200 PSI. Staged 3 cu.ft. in one min. to 3800 PST. Shut down 5 rein. Held 3800 PSI. Staged one cu.ft. to 4 +000 PSI. Shut down 2 rain. Pressure dropped to 3500 PSI. Bled off to 0 PSI. Pres- sured to 4000 PSI. 1leld for lb min. Palled tool loose. Reversed cir culat on. Circulated clean. POII.. Cleaned out crnt. to top of liner w /bit and scraper. 'T"0711 ED POH after cleanin out 9 -5/8" csg. Cleaned out 7" liner to 10,711' �: /bit ° U)910 TD and scraper. Test h dril, pine rags and liner lap to 25 +00" ok. Perforated from 10,480' to 10,4?0` w /Schlimberger h per - }et guns ,'/4 hpf. Ran, llcW-0 DST "l W /packer Set at 10,446' and tail at 10,459' . Opened tester for IF a- 4 :55 p.m. 6/17/69 for one hour w /no blob during test. Pulled tester and re -set wl'pa k at 10,536' and tail at 10,549 Opened tester for 5 gins. No blow. Pulled tester loose and POH. Rigged up Schlumber ger. Perforated from 10,430' to 10,440 . Rigged d own Schlu berger. Picked up Howco tester for DST #2. 10 E;? RIH w /lion =co DST Y 2 w /packer set at 10 , 334! and tail at 10 , 397' . Opened 10,810 TD tester for Initial Flow at 2:55 a.m. For 30 mill pressure at head increased to 350# at Close of IF period. Gas was flared and appeared to be dry. No rat hole fluid. Closed tester for ISIP at 3:25 a.m. for 90 reins. Opened tester at 4:55 a.m. for flow. Packer failed. Opened backsc>_Fttle valve. Bacl;siuttled, killed well. Ran, one std drill pipe in hole, 47" belo► perfs. Circulated bubble up. Mud weight cut from 96�` to 68# . P( w /tester. `Test " 2 : IH 6220 , IF 558, FF I ISI 4325 , Fie 6;73. Riaced up Schlumbesger. Perforated from 10,4"x`0' to 1 0 4 ; 11-11 1,3 10,279' to 10,258', 10,002' to 9994 , 9?85' to 9952 , 99= to 9937' w/4 hp f - 4 Hyper jets. RI.i. 1 j( 0 �� , ( ! \� 1 /� ED Rill w /6" bit a nd 7" C - si ng scraper. Tag,ed bb%ZO�! Circulated al iC� TD co nts..%: 1o.c:c. ,..tzw to run tuol R POr1. jai d do drill pip:.. Rigged up . to rt; n Lubin;, and picl.ed up eweIr a d tubing BcL an running tubing on lono st UL P 4 .1nm err UNION OIL. CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. 12 LEASE Kenai G F Leld WELL NO. KDU 1 DATE I E. T. D. I DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 -20 -69 ( 10,711 Ran 331 its 3 -1/2" :x`80 9.20: buttress tubing w /total depth of 10,:00' or. lon strina,. Tub ino larded in Cameron "DCB" 13 -5/8" x 10" 5000e` tubing head. w/Cameron "DC.B" 10" non . Tubing hanger wl3 -1/2" EUE 8RD top and 3 -1/2 Buttress bottom. Landed 13.20' b6l.o;: K.B. D tai 1 below. Botto;n Top Length # Joints D e scri p tion IG,399.98 10,399.18 .80 -- Shear Sub 10,399,18 10,397.85 1.33 -- 3 -102 Q 1%;ipple 10,387.85 10 6.55 -- 7 "x3" R11 1I; d packer 10 , 391.30 10,3 0 0.09 1.21 -- 3 -1/2 Butt 3 -1/2 EUE -8RD w /collar 10,390.09 10, 358.24 31.85 1 3 -1/2 "%'80 9.20" Butt. tbb 10 10,354.56 3.68 -- 3 -1/2 XO sleeve, 2.75 ID 10 10,292.38 62.18 2 3 -1/2 N80 9.20r Butt. tbg. 10,2692.38 10,233.18 59.20 3 4 -1/2 OD Blast its. 10,233.18 10,017.83 215.35 7 3 -1/2 N80 9.20" Butt. tbo. 10,011 3 9 98.40 5 4 -1/2 OD Blast its. 9 9 3.68 -- 3 -1/2 XO sleeve 9 9 30.76 1 3 -1/2 480 9.20# Butt. tbs. ' 91884.99 9 1 14 . 85 10.14 -- 9 -5/8 (3- 1/2x3 -1/2) R112 dual packer 9 9 2.72 -- 3 -1/2 Butt. x 3 -1/2 EU1- 8rd PVP i t. 9,8"2.13 9,865.94 6.19 -- 3 -1/2 N80 Butt. PNP it. 9 9 3.63 -- 3 -1/2 XO sleeve 9 14.20 9,848.06 320 3 -1/2 IN 9.20;: Butt. tbg. 14.20 13.20 1.00 -- C11 hanger. 3 -1/2 FUE 8RD NP 3 -1 /2 Buttress bottom 1.3 -0- 13.20 -- Elevatio'n K.B. Short String detail, 3-1/2 N8 9,20' Buttress tubing: 13a,tom Top Length Joints Descri 9 9 .79 -- Shear sub 9 9,8 S9.67 1.27 -- 3 -1/2 Butt. x 3 -1/2 EI1E 8RD 9,889.6' 9 1.67 -- 3 -1/2 Q Nipple 9 9 2.15 -- 3 -112 Butt. PVP jt 9 9 8.15 -_ 9 -5/8" (3 -1/2" x 3 -1/2 ") RI -12 d 3-1/2 E F, 8RD Snap latch 9,877.70 9 1.27 -- 3 -1/2 Butt, x 3 -1/2 Eut_ 8RD w /collar 9,876.41 9,815.50 60.93 2 3 -1/2 \cO 9.20 Buttress tag. 9 9 3.68 -- 3 =102 XO sleeve 9,811.82 21.76 9 320 3 -1/2 N80 9.20u Butt. tbg. 21.76 17.58 4.18 -- 3 -102 Butt. PVP jt. 17.58 14.20 3.35 -- 3-1/2 Butt. PVP j t . 14.20 13.20 1.00 -- C111 hanger, 3 -1/2 EUE 83AD UP 3 -1/2 Buttress bottom 13.20 -0- - 13.20 -- Elevation - K.B. Removed BOP's , removed d back pbessure valves. Packed hav er, nstal l ed C11' 10" 5000 (' - x 3 -1/ 21 dual tree. r.. UL F) 41� ".�r.4 UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD PAGE NO. 13 LEASE Kenai Gas s Fiel WELL NO. --'r'-? r 4 FIELD DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6-21-69 10,711 `lusted du--al tree to 500` ", test OK. Installed wing valves. Rigged line - to mud pit from dual tree. Di.sp mud w /3960 c_u.ft. wtr. Set 7" per in I.S. w/1500 psi. Ball sheared sub C 2500 psi. Press on s.s. held at 400 i = w=hile p rni ed l.s. to 320G fm cd s.s. to p - -�-� p psi for test on p�.r. P�.. p 1000 psi, bled back. Second & third at to pressure up s.s. also failed. RIH w /wireline to ck sleeve above pkr. Sleeve fnd open. Closed same. Pkr set 0 200 psi. Sub sheared @ 3000 psi. Test between pkrs _ & a bo e top pkr ` 1000 psi 0K, RIF1 w /wi i eline to open sleeves in opened top two sleeves. Unsure on bottom, sleeve. Flowed s.s. Died 30 min. ]~lowed I,S , died 10 min. Suction on annulus. Injected gas to a.ntiulus 14 00 psi. 'Flowed out s.s. Died 4 Ctrs. Injected gas from imu ir? 2500 psi.. Died; Injected 1800 psi crown s.s. tof low annulus. Blew `.. —n s.s. unti ~ u p. 22- 1 0 1 7111 Pres i� s r`e f '1 * 'e cI n l c lean. w �� ; c lo s e f .. ;� d I, -. �.,.11 ]_�.,; u� t�i� RI�i w/ �ir�. ne to G os all sleeves. Short strinz 2540 psi and one string to 3150 psi. Cameron o 1t lnst'" lll-d j a - _cac k pry- -s r v� lt'es. Installed protective cover over Wi l i lead eqilipmnent KE 71 WIN 0 UN ION OIL CO. OF CALIFORNIA SHEET C WELL RECORD PAGE NO S LEASE Kr"? \'Al GAS FIELD WELL NO. 0 04 FIELD KEN.%I GAS FIELD ev A V VKTP' O- T'TTDTATrq 0 , vf4n D 7l SIZE WEIGHT TH READ G RADE _ DEPTH REMARKS ' 3t3'' 1 2 . wal l None off 41 Set in clay at 41 20 94# 8Rd ST&C H 40 1.264 Howco stab in shoe on bottom 1 b l ,� Seal lock J 55 6 , 026 BaRer mod. G shoe on bot tom 9-5/8 43.5 Sealloc:: N 80 4 193 One jt. 53,5# n ton 9 -4 8" 47 # Se l ? ock DSO -P 0 20 %L 0 to 5 733 1 9 .986 - 9,95') rr rr Ge 6/ !S/ 69 W mco i 7" 29# Buttress IN 80 10 T1 1V Float shoe o n bot tom? w./mule shoe ext . AFRFnR A TMrC RFC O RT) DATE INTERVA PRESENT CO NDITION , 6/-14/69 10 3l - S u Ian off � y 7 O pen 70_10 430 DST O pen 6/18/ 10, Gas prod Open 6/18/69 10,279-10,258 258 Open 6/18 10,002- 9 ,r „ Opera 6, 1 8!69 9 .986 - 9,95') rr rr Ge 6/ !S/ 69 9. 7- G3-7 rr rr Open TUBI`G ST7 ;EIGHIP THREAD G RAIL) E DEPTH RE ? -1ARKS 3-1/2 9.20# Butt es_ N 80 10.400 Long string - soe history for packer sleeve detail 3-1/2 9.20' Buttres -_ iI 80 9.892 Short string - see history for packer Fr sleeve de tai L INI _ WELL HEAD ASSEMBLY TYPE: Cameron 5000 BFI's 1 `7"931842-75-3 File 9 -2815 - CASING HEAD: x 20'' s13D on w /t;�o 2" L P outlets w/2" 3000' ', Camerop ball valvo� CASING HANGER SDP and Se- Assembly "CA" 20" x 13 -3/8" O.D. Tye K. 20 20e0r V.P x 13 -5/8" 5000 #1 ii /2 -2" 5000 �%T studded outlets & P seal. CASING SPOOL: - TUBING HEAD: "D` 13-5/8" 10 " 5000 =` T - w /two 2" 5000 ;.T studded outlets. TUBING HANGER: r " " " 2" Na t" , r_ rr " „ K DCB ' �0 s�O' ° x 3 -1 j 2 x 3 - �./ � �a� � Bu t tress on 5- � /b�! -CC w, 10 x3 -1 2 i.v top x 3 -1 1 ' ' 2" But tress cross t � `- Ca..r on t o `` , e d u al t r• F " teaal string solid block snf ; :: ! MASTER VALVES: Two 3 -' j8" Lot? S'- ,ahb,nQ . a? ��es o:. S -S '6J" CC TRM . OKG 9 KLv O CO. O CPL 1 Hw►.c : DRILLING RECORD REL LEASE A 028142 W ELL NO. '' FIELD Kenai Gap,, Wield LOCATION Section 7, T N, R. 1W S�1. Kenai Penninsula Borough SF;EEI A PAGE NO 1 SPUD DATE 2/11/69 - COMP. DATE 6/2 CONTRACTOR Coastal Drilling Co. RIG NO. 4 TYPE UNIT Gas - Fmsco J 1250 DRILL PIPE DESCRIPTION 4-1/2" FH 16.60 ELEVATIONS: WATER DEPTH — `' y R. T. TO OCEAN FLOOR GF,oLTti1) 18.6 5 �' PERMIT NO. 9-12 SERIAL INTO. R.T. TO MLLW ' T.D. 10 'TD T.V.D. fill R. T. T O DEVIATION (B.H.L.) TO PRODU ' Oil' D COMPANY ENGINEER R.W. Rardin OFOILANDb LLME GW PROVED : 13.E DATE DEPTH BIT RECORD ZUD L. DEPTH Ez DEVIATION VERTICAL ❑ DIRE CTIONAL Q�; BIT NO. SIZE MAKE TYPE JET SIZE DEPTH OUT FEET HOURS ANN. / ET 2/12/69 41 1 15" Reed YT3A 3/22 400 400 6 82 195 Vertical 13 400 IRRI 11 is _ 11 3/24 746 346 12 60 148 DDrld 14 746 2 It It i t 3,122 1264 514 12 6.0 130 28 13 41 Hol 261f if Conv - Open 1.264 1264 20 28 0 - 28 25 920 17R 15 YT3A X75 355 8 115 Drld out cmt 12-1/4' I ughes OSC3IiJ 5 5 2 28 252_6 4 " Globe SS3AJ 3/15 2669 143 2 113 372 34 2 2669 4RR If if 11 3957 1280" 13 -1/ 113 372 29 - 27 4 3957 5 if of " 5003 1046 18 108 351 27 - 9 4 0 45 1 5 5003 3RR Hughes OSC3AJ open 5540 537 10 1031 24 0 45' 7 1241 1102 _1. Smith 6 pt open 3846 2605 29 50 34° max 8 3846 H03 Securt Conv �' 4337 491 14 55 34 max 9 4337 1104 " " " if " Lost in.hole. 1$ 1 4164 6 12 -1/4" Flulghes iOSCIGJ If 4210 46 1 50 Drld out cmt 18 1 4164 X1:05 17 -1/2" Smit 6 pt 4210 46 1 50 if 21 1 4210 71 12 =1/4" 1uQ11 es OSC3AJ 3/24 4360 150 3 -1/ 48 132 DDrld 22 1 43601 81 if Globe 1 ISS3AJ 3/15 5290 930 20 -1V 108 315 24 - 25 23 5290 9 Hughes OSC3AJ 3/24 5355 65 4 82 110 DDrld 24 5355 [ 7RR - 3/15 6050 695 15 108 315 Drld 26 4210 H06; 17 - 1/2" Sec 3 pt open 4026 816 27 65 Opened to 17 -1/2" _ 29 5026 1iJ7 1 " 1 " " " 5523 497 '28-3/L65/70 " 31 5523 1108 " 5871 348 29 65/70 4/l/69 5871 109 " 6050 179 8-1/1 8 5554 6RR{ 12 -1/4" Hughes OSCIGJ 6250 666 20 1 98 Drld out Cmt 13- 6250 10 " Reed. YR3r,J 3/24. 6380 130 11 98 120 DDrld 1t� 6380 ill " " It 3 /20 6431 •51 1-1/2 100 180 Follow up 14 6431 1 " 3/24 6500 69 10 100 120 DDrld 15 6500 12 " RTC 0SC311J 3/18 6530 30 1 100 220 Follow up 16 6530 12R1 " 3f24 6575 45 3 100 DDrld 17 6575 13 " Globe SS3J 1 /24, 2/' 1 3 705 480 17 105 250 OG 1/4 T3 B? 18 7055 14 " " /15,1./ 8 7377 322 18 100 275 T3 B3 26 0 30' S53N' 19 7377 15 Hu hes - It 7678 7866 301 188 16 -1/ 1 4 100 94 285 284 T5 B4 (BI) 24 0 30' T2 B3 23 0 30' 20 7678 16 it Reed YTIAGJ 11 21 7866 17 it Hughes OSC3AJ 3 -16 8066 200 19-3/4 96.5 284 T2 B3 22 8066 P18 Globe SS3A 3/16 83=10 244 19 -1 /% 95 284 it 24 8310 19 " Reed YT3A if 8525 215 21 -11 95 284- T3 E4 25 1 $525 20 ST3AJ /16,1/'8 $76� ?39 26 -1/% 95 220 T3 B6 27 8764 21 it Hughes X3A - V18 9 8/16 891 152 0 -2-1/2 95.5 210 T3 36Lost bearings 28 8916 22 11 Sec S35J 3/18 91001 184 18 95.5 210 T3 Bl OG 1/8 5/1./69 9100 23 Globe SS3 3/18 9304 204 20 -1/ 92 215 T3 B1 2 9304 241 HT OSC3 A4 /18 /It 956 21 94 180 T2B2 3 9564 2) 5 1 it it 3/24. 9725 161 19 94 130 T3 B3 4 9725 261 it Reed YT3 9909 184 15 94 120 T4 E3 6 9909 1 27 Globe SS3 10029 1 120 10 94 120 T3 B2 7 10029 28 1.TC OSC3 10282 253 20 94 120 T4 E4 8 10282 291 "' Globe SS3 3/28 10400 118 19 -1/2 94 T3 B3 9 10400 30 if Reed YR3 3/24 10550 150 13 -112 95 127 T4 B3 OG 5/16 10 10550 31 " 1iTC 0S";IG 10655 105 17 95 120 T4 B2 12 10655 32 OSC3 10736 -31 14 -1 /'2'j 95 120 T3 E2 13 10736 33f Reed YT3 10067 131 20 -1/4 94 12±3 13 E3 0(', 1/8 TZ 5? l4 10861 { 34: " Globe SST3 1097'9 112 �,0 94 1?J 16 10979 35 SS31 - -" 11077 98 1`' -I /2 94 120 17 11077 ; 36 " 1110 OS. 3/ '0 11151 74 ZO 19 11151 37 x 1:zed Y" 1_, 3 b ;11151 0 %�* Circ f t a r- �li 1 ^a .1 '7 ( ,V !l ) 3 � !� ? - 1 1 2 13 1h 1 - ^ I Dr" c.`:t :s s: ?oe -- t '34 I Y 11 i � t LEASE FIELD LOCATION— UN IOiN OIL CO. OF CALI FOi -\iq IA DRILLING RECORD WELL NO. -' -= 4 SPUD DATE CONTRACTOR - TYPE UNIT DRILL PIPE DESCRIPTION_ ELEVATIONS: NVATER DEPTH PERMIT NO. SERIAL NO. R. T. TO OCEAN FLOOR T.D. - T.V.D. R.T. TO MLL�'V R. T. TO DRILL DECK DEVIATION (B.H.L.) COMPANY ENGINEE R. T. TO PRODUCTION DECK APPROVED: DATE DEPTH BIT RECORD MUD VEL . DEPTH & DEVIATION VERTICAL ❑ DIRECTIONAL Cl BIT NO. SIZE MAKE TYPE JET SIZE DEPTH OUT FEET YOURS ANIT. JET 2/69 10330 40 8-3/8" eed YTIA onen 10364 34 3 ? DDrld 3 10364 41 Lughes OSC3J 3%15 10512 148 8 -1/2 155 190 4 10512 42 -u hes 3/13 10574 62 6 155 295 5 10574 43 10643 69 4-1/2 180 295 5 10643 44 .eed YTIA 10702 59 6 -1 -2 180 295 • 6- 10702 45 YS1 L0759 57 " 6 10759 46 'u^hes 0 W 1 11 1081 51 7 12 10810 ' 6RR " " open Run to btm ck Imle Crk 14 10810 SRR " .eed YTIA it CO cr..t 9-5/8 14 10810 47 6" Lushes 0SC1G 165 CO cmt 7" ` 15 10810 33R RI 8 -3/8" eed YTIA " CO cmt 9-5/8" 15 0810 ' 7RP 6" LTC: OSC1G ': " CO cmt 7" 01 ISI SHEET A PAGE NO. 2 COMP. DATE RIG NO._ LEASE Kenai Gas Fi elci TYPE LionosulPhon --ate UNIC. OIL. CO. OF CALIF'O, _.CIA MUD RECORD WELL NO. RDU 04 FIELD Kenai Gas Field DISTRIBUTOR Ba ro id DATE DEPTH WEIGHT I VISC. W. L. PH SALT OIL SAND SOLIDS REMARKS 2/1-1/ 235 70 57 9 7 600 0 3>> - 15" hole 12 551 74 53 9.6 7 700 0 4% - 15 hole 13 966 75 55 8.8 7 650 0 51Z - 15" hole 14 126? 77 50 9 7 1 0 6% - 15" dole, op ened to 2 CASiu CT :�1L I�G 20 csg D0 1N Er. R I G L` 25 1264 7 6 40 10.8 12 600 0 TR Drl�' cm 26 ?: ; .5 5C� 11, 2 12 600 c 5 l z -� �} hole 27 2520' 78 37 11.6 12 600 0 4 15Z " F IS' Sl /1 266C-? 7i . 53 7,6 12 600 0 3 - 12 -1 /4" hole 1050 + - Total. Vol 2 395' 80 68 6.4 12 600 0 3.5 18% 12 -1/4" hol - It 80 60 4 .4 10 . 51 600 0 3.5 18 -Z rf lr 4 5033 84 65 4.6 li 600 1 3.9 19% 5 5540 85 70 4.8 10.5 550 1 3 20;0 11 „ 6 5540 85 70 4. 10.5 150 1 3 20% 7 5540 87 63 4.5 10.5 5 70 TR 8 21% Opened to 17 -1/2' 8 50-.x: 86 70 4.8 10 610 i p, 21„ IS 1f 11 9 5540 8s; 70 4.6 10 620 TR 4 , 21% If f1 It 10 5540 86 60 4.8 10 450 TR 6° 23c> A. 5540 84 70 5.8 10 440 TR 27 20 Fished 15 5540 85 50 5.9 ji-0 300 2% 2 :% 20;� " 16 5540 86 53 5.9 10 300 1% 1% 19% 17 5540 85 71 5.8 10 300 TR 1 -3/ 20 ; " 18 & 19 4210 Fu 50 4.4 10.5 250 1/2 lei% Plished plug & conditioned mud REPk�I. RE 21 4360 86 50 4.0 10 300 - 1 1 7 % Drld 22 4413 8;6 60 5.0 11 250 - 2 18% 12 -1/4" hole 23 51 87 48 1 4.8 1; 4 00 - 2 19; 12- •1 /4 hole 24 3355 86 75 5 1.0.5 400 1- 2 19 12 -1/4" hole (oil fm mind oil) 25 5770 87 65 5.2 10.5 300 2 3 20% 12 -1-4" hole 26 6050 87 80 4.4 10.5 550 rR 3 20% to ^, DIL FDC, S.IP 27 6050 £7 80 '.4 4.4 1.0.5 550 - 3 - Ovened Mole to 17 -1! % 28 6050 86.5 50 5.9 10.5 500 TR 1.5 19„ it 29 6050 Sa 48 5,8 10.5 500 TR 1 1910 tt 1t 1► 3x0 60 30 86. 95 5.2 10.5 450 TR 1 19, tt I1 11 (clay) . 31 60 5, f) 87 60 3. 10 450 - 1.5 19/ 1, 11 It 411/69 600 86 58 8 5.6 10 0 - 400 TR 1.5 20/Z 1, lr ( ru 0 )0 1 0 7 58 5. 7 � t 400 TR .2 { tl 20:,Z it 11 11 3 6D S7 6 1 3 10 350 T 2 20'/ 13 -3/8" csg Pi,'` A #* T ;�P " � 3?r P: # iGli' � ' �- ACI%T - FA - - - �ii-x Lill "I _J 3 625? 85 ti7 51- 4.8 12.5 400 - 2 20% Drla c.rit 12 -1/4" hole 14 6350 F7 48 4.6 11 r 30 3 20 DDrld 5 6450 87 45 4.8 11 530 3 20; DDrl.d 6530 88 43 4.5 10. q 600 1.5 20;' 7 69 SA 4S 4 5 10 ' 60 3 1.5 20% 11 R 6952 95 7" 4. 5 10. S OO 4 30% Raised wt due to gas kirk 1v 7 450 9 5.S 7 4.8 10, 400 4 3f7% 12 role 7 - 700 units 67S 96 50 /80 4.5 10. 350 3.5 30 , tt 11 77 55 96 so 5 1 Ci 5 400 - 3 307 ? ,I 79 9. 5 5.? 5 6 10 4 10 - 3 300, ?� 0 5.0 1 ,n, 350 -- 3 27% ►t ,i *7 8 1 i0 95 50 5.0 10 350 " - 1.5 25% 25 8425 95 75 5.0 11 05 3:50 - 2.5 i - 26 8580 94 80 5 10 350 - 2 •2/ 27 8738 96 50 5 10 350 - 2.5 28 28 89 C }0 95 30 5.3 10 350 - 2.5 25 29 8975 x}5.5 05 513 IG 350 - .5 30 9015 94 57 5.1 10 350 - 2 2J . 511169 91 30 93+ 67 5.2 1.0 3 0 - 1.5 24 2 9380 94 49 4.3 10 350 1.5 4 3 Ad ded 40 s d le ei 3 9511 95 65 4.8 9 3 2'�: I.5 23 4 9 631 9 a 3 Y. 7sJ -)50 1i .� 5 -3 p /� R �`.!-, t t �ni�: ilZ s 5V JUls l �✓c= t. 1. �. 5 973 i,5 4.8 ��.5 3 ?C 1% 1 24 6 :,ono 60 3 ° 5 I 350 2, 1 0 ehls d . e SHEET B PAGE NO. 3 UN ICA OIL CO. OF CALL F'Oi .j� IA SHEET B MUD RECORD PAGE NO. LEASE TYPE_ WELL NO. KDU #4 - FIELD DISTRIBUTOR DATE DEPTH WEIGHT VISC. W. L. PH SALT OIL SAND SOLIDS REMARKS 518/69 101.00 94 50 4.8 9.5 350 2 1 24 9 10365 94 50" 5 9 400 2 2 1 24 10 10`;97 95 s0 5 9 400 2 1.5 22 11 10600 95 80- 5 9 400 2 1 -3J4 23 12 10655 95 79 4.8 9 425 2 1.5 24 13 10736 94 61 5 9.5 400 2 1 -31'. 22 14 108F 94 81 5 9.5 400 2 1.5 24 15 10 9 3 93+ 79 5 1.9.5 400 2 1 24 16 110 94+ 75 5 9 1 350 TR 2 21 17 ? 10_g5 9 7 67 5 9. 5 350 TR 1.5 24 1 111 .1. 11 94 • 71 5 9,5 400 TR 1. 22 19 111.51 9+ 78 5 9.5 350 TR 1 22 21 11151 94 78 5 9.5 350 TR 1 22 23 11151 94 S4 5.9 9.5 - 350 TR 1 23 27 10'409 93 55 5.8 9.5 350 0 1 23 Prep to I.o 28 10409 I (1G E 0 29 10409 93 67 5,5 9.5 350 TR 1 23 Prep for cs P_ Cs .T% NIPP 612169 10224 a 67 5.5 9 .5 350 1 23 3 i_0 `' ;? 93 45 ¢.3 1 3 350 1 22 Drld cmt 105 12 93 6. 4 1. 5 300 1 2? 5 , 0 "3 Q4 :7 5 .' l2 , ; �00 1.a1I 23 6 107354 46 5.4 12 , 5 1 1 -1; 23 1 10810 4 4�3 5 ,1_ 1.2 , 0�3 2 4 S 1. c = 4 4 8 4 .3 1 1 .5 4 =, 2 3 9 LOGt D -ll) R ` 7" C a 5, -, 10 10S O 94 48 5.2 12.E 180 0 1 -1 /' 2+ CO to run liner 11 1010 L 5 3 �_2 4n' - ; 2 5 � L 6 5.6 12.5 350 1 24 Ra 1 iner 1.0 �{0 1 r 4 � . � 1'' . , 400 It , 4 6. 12 4 00 p• 24 1 ^ISID 0 o; A2 i 0 2 350; -- 1 24 Sczd Inr 2nd tir.� s; 10 0. car 42 6 1 . 2 350 1 2 0 ? 5�� - 1 2' Prey to run, t ubing .R v" CHMA HLB LA OKG -IW 7,- RLY - =�.: ri{ 4: - F -l�— +� —I �r ~ + r r , -/ ��- -_ ._ L 1 - +y � ���4�1�i� i:s� i_ .�- it LL_i �� L. w U L I L. 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A 0 JO A- I R Q ri Q 41 A. on vr 11.9 jill W 4 —4699 42 •4.400.jr A so U I.ek. ".LA W— 3s) &�OP. cc ( C n V, 'I e) kA- a jo io RIP 4 4 24— =1.322-4-11W 0.4.111.5 t*_I.w 5 R A Tw %aA4 -*D 0 4PIP 48jDa*-00 .444, go 5.6 2 $4, 5121A 200. DO 52nn.nn V.2 0 :%'y 1 54-A 1. w,w. C; .5 4 3 2 201 Lrr 1) VA$ WN w I n 1 E Z 1: r T li 4.41 314-9 1 AliLIELT LILJMIIE-11,--� L NA -0 1-V r tj i4 LIU-I'M 1 -f j I 6 A %Ill *.CA4. 61 LL. 7.L-,!j 'IF (•I Cl JA Z. A-It —Ir 4-44.4 2- 0 in CL LIS %A-� 34 --.'I • OZ9t iW3-411 Q...0 43 Oa4, 0 0 -245.7-* Xj, " -L . CA q.: 1 6 i A tps 04 IN 0 A 1 U 2 1 65 IM 2.53. 7LS V 7 4 5 4 0 �Z - QO 00 3--i W AS 5 0:3 -4 I fin J;L ILL 444 -L4 a 100 4,40 MZ�VA-oj*. � -4.-2614-1131 ul' L Z-1 1 a 21. —25112*5US —2 71 2 1 ' 4 7 As r 4• Al I;. Vf 10.) V- F'T .C %'T!4 C; Ei j� ■.1'. L &.%.A QX I L --M U-rl VZ-- L3 ICA E —L-A-T.-ITWE COAR —4� J 12 7 C C-L - SL---m 71— 12 .. ;cl.. I i - 2 rj as 0 .6 o 3 — 4-4244 2. 0o . on .410 Q 4 oq -b- CIO Q4do ar-) -2750.,SRS 7 J.. w oo r- 4 4 1 00001:00 -273-3o 4 -.3 5 2.6 C W —4-0-3-45 0 0 aO 4 4- Q 4 0.11.o= Sl 4-0 - .3a 544 -alw 2 7 1022t 0200 - ou Voc". 00 2 7 A A 19 1 "11 E. • Q CAMP A ill V 4-6 14 Xi'.-L " A —X-1- _41- it'; 4 "ll &,S-1.456= A =—L. -------- Iml _3 CoJG__.*_!ljb 0 4.00 4A 4--4- At,07.2 v —.� 1�� jr�.17'r r"+A .�� '!7 '1�'i ...�ra {:ly � � C .. x� }� i �.��i:J �'!.� � � 3 re 0 0 4s �L. 19.4 —2,3 3 W dw I & --4,04104 -'rig joG a- Q 13 a 010 a 2 . c-I 0 w-2 Z o255 3 WELL COMPLETION OR RE COMPLETION REPORT AND LOG 6. LE DESIGNATLON.AND * A 028142 la. TYPE 011, (SAS x 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL WELI. DRY Other b. TYPE OF COMPLETION: Ell F NEW WORK DEEP PL UG WIFE. 8. UNIT FARM OR LEAS WELL El OVER EN BACK RESVR. Other 2. NAME OF OPERATOR Ke na i V nl t Union Oil Company of California 9. WELL NO. 3. ADDRESS OF OPERATOR Kenai Deep Unit #4 (13-7) 507 W. Northern Lights Blvd. , Anchorage, A . 99503 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and in accordance 'eolith any St (Ito requirements)* Kenai Gas Field At surface 4W 7 r' jVg ad , 253'S & 4209'E fm NW corner Sec. 7, 11. SEC., T., R., M., (BOTTOM HOLE T N , R 1 , S . OBJECTIVE) At top prod. interval reported below 270 3 0 8 0 . 3 0' W of surf location At total depth 2763'S & 3406 of surf. location. Sec. 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 13. DATE SPUDDED 1 14. DATE T.D. REACHED 15. DATE COMP, SUSP,OR ABAND, 16. ELEVATIONS (DF, RKB, RT, GR, .E C)• 17. ELEV. CASIN'GHEAD 2/11/69 6/7/69 6/22/69 R.T. 95' above MSL 80' above MSL A. 18. TOTAL DEPTH, MD & TVD 9. PLUG BACK MB - & IF MULTIPLE COMPL.,'' 21. INTERVALS DRILLED BY 1' 0 8 10-973" N HOW MTY* ROTARY TOOLS CABLE TOOLS 0 -TD 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -TOP, BOTTOM, NAME (MR, AND TVD)* 23. WAS DIRECTIONAL D3 - 10258' MD to 10279' MD 9222'TVD to 9241'TVD - Middle Kenai SURVEY MADE D2 - 9937' MD to 10002' MD 8932'TVD to 8990' TVD - Middle Kenai YES 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, SNP, SONIC, DENSITY, DIP METER 25. CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, LB /FT. GRADE DEPTH SET, (MD) HOLI i SIZE CE112T,'NTING RECOkRD AMOUNT PULLED 20" 94# H40 1264 26" 2400fto pr t, 360f none �� 6'1 j -55 6026 17 - 61 t pr t, 0 t ' ' none 9 -5 8" 3.5 47 ' 53.5 I N & P 0310' - 0 t t pr t, t none 26. LINER RECORD " 27., TUBING RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH'SET (MD) PACKER SET (MD) " 10 , 280 1 10 759' 130 3-1/2 9892 ' top 28. PERFORATIONS OPEN TO PRODUCTIO (Interval, size and number) 29. ACID, SFIOT, FRACTURE, CEMENT SQUEEZE, ETC. 9937-9947 4 1/2 hpf. , 1 D2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATEIUAL USED 9952 -9986 4 1/2 hpf 34' D2 10315- 1.0316 2 cmt scr s CFR -2 330 sx 9994 -10002 4 1/2" hpf 8' D2 test UK. 10258=10279 4 1/2" hpf 21' D3 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowin gas lift, pumping -size and type of pump) WELL STATUS (Producing or siiut -in) Shut In - pending of surface facilities shut in DATE OF TEST HOURS TESTED CHOKE SIZE j TE , S 0 jr D'NFOR OIL --BEL. GAS -MCF. WATER -BBL. GAS -OIL RATIO YEiIOD FLOW TUBING CASING PRESSURE CALCULATED OIL -BBL. GAS• -MCV. WATER --BBL. ; ;, §IL GRAV TYAPI (CORR.) PRESS. M -HOUR RATE ; � 31. DISPOSITION OF GAS (Sold, used for f uel , vented, etc.) TEST WITN B k Iry A ,v ,• 32, LIST OF ATTACHMENTS hereby certify that 0e foregoiU apj attach information is complete and correc t as determined f rom allpavallable records " ✓a SIGNED / TITLE Dist. Drlg - Supt- DATE 7 /8/ 69 „- *(See Ir>ructions and Spaces for Additional Data on Reverse Side) SHORT H HLB 4011* Form P 7 SUBMIT IN DUPLICATE- T STATE OF ALASKA ( ( See other in -� structions on r OIL AND GAS CONSERVATION C COMMITTEE 5 50 - 133 -20 ; 2. NAME OF OPERATOR Ke na i V nl t Union Oil Company of California 9. WELL NO. 3. ADDRESS OF OPERATOR Kenai Deep Unit #4 (13-7) 507 W. Northern Lights Blvd. , Anchorage, A . 99503 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and in accordance 'eolith any St (Ito requirements)* Kenai Gas Field At surface 4W 7 r' jVg ad , 253'S & 4209'E fm NW corner Sec. 7, 11. SEC., T., R., M., (BOTTOM HOLE T N , R 1 , S . OBJECTIVE) At top prod. interval reported below 270 3 0 8 0 . 3 0' W of surf location At total depth 2763'S & 3406 of surf. location. Sec. 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 13. DATE SPUDDED 1 14. DATE T.D. REACHED 15. DATE COMP, SUSP,OR ABAND, 16. ELEVATIONS (DF, RKB, RT, GR, .E C)• 17. ELEV. CASIN'GHEAD 2/11/69 6/7/69 6/22/69 R.T. 95' above MSL 80' above MSL A. 18. TOTAL DEPTH, MD & TVD 9. PLUG BACK MB - & IF MULTIPLE COMPL.,'' 21. INTERVALS DRILLED BY 1' 0 8 10-973" N HOW MTY* ROTARY TOOLS CABLE TOOLS 0 -TD 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -TOP, BOTTOM, NAME (MR, AND TVD)* 23. WAS DIRECTIONAL D3 - 10258' MD to 10279' MD 9222'TVD to 9241'TVD - Middle Kenai SURVEY MADE D2 - 9937' MD to 10002' MD 8932'TVD to 8990' TVD - Middle Kenai YES 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, SNP, SONIC, DENSITY, DIP METER 25. CASING RECORD (Report all strings set in well) CASING SIZE WEIGHT, LB /FT. GRADE DEPTH SET, (MD) HOLI i SIZE CE112T,'NTING RECOkRD AMOUNT PULLED 20" 94# H40 1264 26" 2400fto pr t, 360f none �� 6'1 j -55 6026 17 - 61 t pr t, 0 t ' ' none 9 -5 8" 3.5 47 ' 53.5 I N & P 0310' - 0 t t pr t, t none 26. LINER RECORD " 27., TUBING RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH'SET (MD) PACKER SET (MD) " 10 , 280 1 10 759' 130 3-1/2 9892 ' top 28. PERFORATIONS OPEN TO PRODUCTIO (Interval, size and number) 29. ACID, SFIOT, FRACTURE, CEMENT SQUEEZE, ETC. 9937-9947 4 1/2 hpf. , 1 D2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATEIUAL USED 9952 -9986 4 1/2 hpf 34' D2 10315- 1.0316 2 cmt scr s CFR -2 330 sx 9994 -10002 4 1/2" hpf 8' D2 test UK. 10258=10279 4 1/2" hpf 21' D3 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowin gas lift, pumping -size and type of pump) WELL STATUS (Producing or siiut -in) Shut In - pending of surface facilities shut in DATE OF TEST HOURS TESTED CHOKE SIZE j TE , S 0 jr D'NFOR OIL --BEL. GAS -MCF. WATER -BBL. GAS -OIL RATIO YEiIOD FLOW TUBING CASING PRESSURE CALCULATED OIL -BBL. GAS• -MCV. WATER --BBL. ; ;, §IL GRAV TYAPI (CORR.) PRESS. M -HOUR RATE ; � 31. DISPOSITION OF GAS (Sold, used for f uel , vented, etc.) TEST WITN B k Iry A ,v ,• 32, LIST OF ATTACHMENTS hereby certify that 0e foregoiU apj attach information is complete and correc t as determined f rom allpavallable records " ✓a SIGNED / TITLE Dist. Drlg - Supt- DATE 7 /8/ 69 „- *(See Ir>ructions and Spaces for Additional Data on Reverse Side) CASING SIZE WEIGHT, LB /FT. GRADE DEPTH SET, (MD) HOLI i SIZE CE112T,'NTING RECOkRD AMOUNT PULLED 20" 94# H40 1264 26" 2400fto pr t, 360f none �� 6'1 j -55 6026 17 - 61 t pr t, 0 t ' ' none 9 -5 8" 3.5 47 ' 53.5 I N & P 0310' - 0 t t pr t, t none 26. LINER RECORD " 27., TUBING RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH'SET (MD) PACKER SET (MD) " 10 , 280 1 10 759' 130 3-1/2 9892 ' top 28. PERFORATIONS OPEN TO PRODUCTIO (Interval, size and number) 29. ACID, SFIOT, FRACTURE, CEMENT SQUEEZE, ETC. 9937-9947 4 1/2 hpf. , 1 D2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATEIUAL USED 9952 -9986 4 1/2 hpf 34' D2 10315- 1.0316 2 cmt scr s CFR -2 330 sx 9994 -10002 4 1/2" hpf 8' D2 test UK. 10258=10279 4 1/2" hpf 21' D3 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowin gas lift, pumping -size and type of pump) WELL STATUS (Producing or siiut -in) Shut In - pending of surface facilities shut in DATE OF TEST HOURS TESTED CHOKE SIZE j TE , S 0 jr D'NFOR OIL --BEL. GAS -MCF. WATER -BBL. GAS -OIL RATIO YEiIOD FLOW TUBING CASING PRESSURE CALCULATED OIL -BBL. GAS• -MCV. WATER --BBL. ; ;, §IL GRAV TYAPI (CORR.) PRESS. M -HOUR RATE ; � 31. DISPOSITION OF GAS (Sold, used for f uel , vented, etc.) TEST WITN B k Iry A ,v ,• 32, LIST OF ATTACHMENTS hereby certify that 0e foregoiU apj attach information is complete and correc t as determined f rom allpavallable records " ✓a SIGNED / TITLE Dist. Drlg - Supt- DATE 7 /8/ 69 „- *(See Ir>ructions and Spaces for Additional Data on Reverse Side) 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowin gas lift, pumping -size and type of pump) WELL STATUS (Producing or siiut -in) Shut In - pending of surface facilities shut in DATE OF TEST HOURS TESTED CHOKE SIZE j TE , S 0 jr D'NFOR OIL --BEL. GAS -MCF. WATER -BBL. GAS -OIL RATIO YEiIOD FLOW TUBING CASING PRESSURE CALCULATED OIL -BBL. GAS• -MCV. WATER --BBL. ; ;, §IL GRAV TYAPI (CORR.) PRESS. M -HOUR RATE ; � 31. DISPOSITION OF GAS (Sold, used for f uel , vented, etc.) TEST WITN B k Iry A ,v ,• 32, LIST OF ATTACHMENTS hereby certify that 0e foregoiU apj attach information is complete and correc t as determined f rom allpavallable records " ✓a SIGNED / TITLE Dist. Drlg - Supt- DATE 7 /8/ 69 „- *(See Ir>ructions and Spaces for Additional Data on Reverse Side) *(See Ir>ructions and Spaces for Additional Data on Reverse Side) 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.. .. r Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachments. .__ Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the producing interval, or . intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report - (page) on this form, "adequately identified, for- each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement ": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the-cementing tool. Item 28: Submit a separate completion report on this for each interval to be separately produced. (See instruction for items 20 and 22 above). -_ 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS. WATER AND MUD 35. GEOLOGIC MARKERS NAME TRUr VERT. DEPTIi MEAS. DEPTH Top "D" . 9744 none 8760 D2 9925 8922 D3 10239 9207 36. CORE DATA, ATTACH BRIEF DESCRIPITIONS OF LITHOLOGY, POROSITY, FRACTURES. APPARENT DIPS AND DETEc SHOWS OF OIL, GAS OR WATER. none - b. TYPE OF COMPLETION: NE E• OVER EN EP BACK r. SVR. F1 Other 2. NAME OF OPERATOR Union Oil Company of California. 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd. , Anchorage, Ak . 99503 4. LOCATION OF WELL (Report location clearly and in accordance with any S.t (Ito requirements)* Atsurface -7 drilling pad, 253'S &4209'E fm NW corner Sec. 7, T4N, R11W, SM. At top prod. interval reported below 2745 .50'S , 3 2 80 . 2'4'W of surf location 8. UNIT, FARM OR LEASE NAME Kenai Unit i. WELL NO. Kenai Deep Unit #4 (1 -7) 0. FIELD AND POOL, OR WILDCAT Kenai Gas Field 1. SEC,, T., R., M., (BOTTOM HOLE OBJECTIVE) At total depth Sec. 7, T4N, R11W, SM. 2763.57'S &.,3406.05'W of surf. location 12. PERMIT NO, 69- 13. DATE SPUDDED 14. DATE T.D. REACHED 15. DATE COMP, SUSP,OR ABAND. 16. ELEVATIONS (D'F, RKB, RT, GR, -TC)• 17. EY.EV. CASIN'GHEAD ,2/11/69 6/7/69 5/22/69 " 9,5' above MSL 80' above MSL C HOW ,YE'COMPL., 21. o INTERVALS DRIL 10 810 9 7 3 9 TV � LED BY - DEPTH • 0 1 D TOO 18. TOTAL DEPTH, MD & TVD 9. PLUG BA & IF MULTIP I ROTARY TOO CABLE TOO 10711 �md & 9658 22:' PRODUCING INTERVAL(S), OF THIS 00- NPLETI0�4-- TQP;'t BOTTOM, � NAME,.,:,( VID AND TVD)• 23. WAS DIRECTIONAL SURVEY MADE -D -4 - 10428MD to;' 10;417QMD : 93.79TVD to 94'17TVD Middle Kenai J YES 24.' TYPE ELECTRIC AND OTHER LOGS'R.0 N' f ' + I ! DIL, SNP, SONIC_ D MMA RAY IP�ETER�� GA` ID,�NSTTY ' CASING-.RECORD" (Report all strings', set 'IA, well) CASING SIZE WEIGHT, LBAF•T.'T GRADE '., HL13 ° HOLE SIZE LONG AMOUNT PULLED TRM Form P--7 • 1264' ', OKG 1 2400ft prlt, 360ft , 'G" SUBMIT IN DUPLICATE 13 -3 8" ���-- STATE OF ALASKA ( See other In- 17-1 : 2' KL`L� OIL AND GAS CONSERVATION struc si on rever se si rever COMMITTEE 5. API NUMERICAL CODE • �• 1 �,,• + "..... ;! ) 50- 133 -20 WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 6. LEASE DESIGNATION AND SERI NO. - 12-rj /4"11 A 028142 _ 7. IF INDIAN, ALLOTTEE OIT: B N AM E 1 &. TYPE WE E W E ❑ WELL WELL DRY Other b. TYPE OF COMPLETION: NE E• OVER EN EP BACK r. SVR. F1 Other 2. NAME OF OPERATOR Union Oil Company of California. 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd. , Anchorage, Ak . 99503 4. LOCATION OF WELL (Report location clearly and in accordance with any S.t (Ito requirements)* Atsurface -7 drilling pad, 253'S &4209'E fm NW corner Sec. 7, T4N, R11W, SM. At top prod. interval reported below 2745 .50'S , 3 2 80 . 2'4'W of surf location 8. UNIT, FARM OR LEASE NAME Kenai Unit i. WELL NO. Kenai Deep Unit #4 (1 -7) 0. FIELD AND POOL, OR WILDCAT Kenai Gas Field 1. SEC,, T., R., M., (BOTTOM HOLE OBJECTIVE) At total depth Sec. 7, T4N, R11W, SM. 2763.57'S &.,3406.05'W of surf. location 12. PERMIT NO, 69- 13. DATE SPUDDED 14. DATE T.D. REACHED 15. DATE COMP, SUSP,OR ABAND. 16. ELEVATIONS (D'F, RKB, RT, GR, -TC)• 17. EY.EV. CASIN'GHEAD ,2/11/69 6/7/69 5/22/69 " 9,5' above MSL 80' above MSL C HOW ,YE'COMPL., 21. o INTERVALS DRIL 10 810 9 7 3 9 TV � LED BY - DEPTH • 0 1 D TOO 18. TOTAL DEPTH, MD & TVD 9. PLUG BA & IF MULTIP I ROTARY TOO CABLE TOO 10711 �md & 9658 22:' PRODUCING INTERVAL(S), OF THIS 00- NPLETI0�4-- TQP;'t BOTTOM, � NAME,.,:,( VID AND TVD)• 23. WAS DIRECTIONAL SURVEY MADE -D -4 - 10428MD to;' 10;417QMD : 93.79TVD to 94'17TVD Middle Kenai J YES 24.' TYPE ELECTRIC AND OTHER LOGS'R.0 N' f ' + I ! DIL, SNP, SONIC_ D MMA RAY IP�ETER�� GA` ID,�NSTTY ' CASING-.RECORD" (Report all strings', set 'IA, well) CASING SIZE WEIGHT, LBAF•T.'T GRADE '., DEPt SSEx (MD) HOLE SIZE CE11?L. NTING RECORD AMOUNT PULLED 20" 94# I -I40'_ 1264' ', 2:6" 2400ft prlt, 360ft , 'G" none 13 -3 8" 61# 5 6026' 17-1 : 2' 4618ft .. rlt 1083ft " G" none 9-5/8 K3.5,47, N ;! ) 53.5 # -. p,,�:, ;;' �10 : 310' '' 12-rj /4"11 �8 3 Oft prlt, 60Oft'... ��G�� none 26. LINER RECORD r 27. TUBING RECORD SIZF7 TOP (MD). SbZ'TOM, (1VID) . SACKS CEMENTS', SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 3-142 1 10 391 to PT 28. PERFORATIONS OPEN TO PRODUCTION" 1 nterval, size and number) `- 10,428' - 10,470' 4 1/ h f 42' D4 / p 10480' - 10490' 4 "10ilhpf - open but ineffective , see Dik #d" a , L�, ACID, SHOT, YRACTURE, CEMENT SQUEEZE, ETC, DEPTI1,INTERVAL (MD),.' AMOUNT AND.,,KIND OF MATE.R.IAL USED 1031`5 -10316 2. cmt s zs CFR -2� 330 sx 40 test - OK. 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTTION METHOD (Flowui.g, gas lift, pumping -size and type of pump) WELL STATUS (Producing or shut -in) Shut In - pending installation of surface facilities. _ Shut In DATE OF TEST. HOURS TESTED CTIOIfE SIZE PROI7`N FOR OIL =-HEL. GAS- 1VICF. WATER -•BBL. GAS -OII.+ RE1 TI0 TEST PERIOD FLOW TUBING CASING PRESSURE QALCULATED OIL-BBL. AS WATER --BBL. OIL GRAVITY -APL (CORK.) PRESS. -HOUR RATE ; I • DISPOSITION OF GAS (Sold, TITLE DI-st . Drlg . Supt. ions and Spaces For Additional Data on Reverse Side) DATE 7/8/69 32. LIST OF ATTACHMENTS 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.---16: Indicate which elevation . is used as reference (where not otherwise shown) for depth measure- - ments given in cther�- spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone_ -. (multiple completion) ): so state in item 20, and in item 22 show the producing interval, or intervals, - top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form; adequately identified, for each additional inter to be seperately produced, show -. ing the additional-data pertinent to such interval. ' Item26: "Sacks Cement ": Attached supplemental records for this well should - show the details of any mul tiple stage cementing and the .location of the cementing tool. Item 28: Submit a separate completion report on this form for - each interval to be separately produced. (See instruction for items 20 and 22 above).' _ 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS. _ _ WATER AND MUD 35. GEOLOGIC MARKERS ".- Test #1 D4 gas sand 10 =,480- 10,490 750# wtr cushion. ' Pkr - -@ 10.446', tail NAME - @10,459' .- :Tester open 1 hr, no recove MEAS. DEPTH TRUE VF.RT. DEPTH _ Complete draw down. -_Test dead. J Top "D" 9744 8760 D -.2 9925 8922 Test #2 D4 gas sand 1 0- ,430 -10- 440 No W cushion. Pkr @ -10, 384' , tail @ D -.3 _ 10239 9207 - 10397- opened for IF Gas to surf D -4 _ 10428 9379 immediately. Flowed dry-gas. 30 min closed for 1 -1 /2 hrs -, pkr failed. Test = discontinued. IH 6220, FF 710, - = FH 6373, IF 558, ISI 4325. Since flow was - :during IF period, no. - Tate obtained. Pkr failed when opening for final flow p riod . - 36. CORE DATA, ATTACH BRIEF DESCRIPITIONS OF LITHOLOGY. POROSITY, FRACTURES. APPARENT DIPS - AND DETECTED SHOWS OF OIL. GAS OR WATER. - Four: STATE OF ALASKA SUBMIT IN DUPLICATE 9 -3 REV. 9-3 0 - fi7 OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 OIL GAB WELL 11 WELL OTHER HLB �7 t TRM O 5. API NUMERICAL CODE KL.V 50 -133 -20176 - 6. LEASE DESIGNATION AND S 'SL N A 028142 7. IF INDIAN, ALOTTEE OR TRI EMWMF 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage 4. LOCATION OF WELL , Alaska 99503 43 -7 drilling pad, 253'S & 4209'E from NW corner, Sect. 7, T4N, R11W, SM. 9. WE" NO, Kenai Deep Unit # #4 (13 -7) 10. FIELD A'VD POOL, OR \WILDCAT Kenai Gas Field - Middle Kena "D 11. SEC., T., R., M., (130TT0 HOLE OBJECTIVE) Sect, 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. KENAI DEEP UNIT #4, JUNE 1969 RIH located top cmt 10130'. Drld out 10130' - 10330', kick off point. Circ clean. PO, Ran DDrl, DDRLD 10330' - 10364' sidetracking hole. Drld to 10810'TD. Condition for logs. Ran Schlum DIL, Sonic, & dipmeter. Conditioned hole, ran 483' 7" 29 ## N -80 lnr w /special clearance couplings..Lnr stopped @ 10335'. Pulled lnr, reconditioned hole. Ran locked in da to 10810', reamed, hit nothing. Reran lnr, stopped @ 10335. P0. Ran under reamer & ran HO, was able to wedge HO @ tight spot @ 10335. Ran 7" lnr w /mule shoe. Rotated same thru tight ' spot @ 10335. Ran lnr , hung w /shoe @ 10759', w /topof lnr set @ 10280'. Mixed & pumped 130 sx "G ". Displaded same w/915 cu.ft. mud. CIP 4:30 am 6/13/69. POH, layed down HW dp & dc's. Ran 9 -5/8" csg scraper. No: cmt above lnr hngr @ 10280'. Ran 7" csg scraper. Top cmt in 7" lnr @ 10700. CO to 10711. Circ clean, PO. Ran Schlum Gamma Ray Neutron Correlation log. Shot four 1/2" hpf in 7" lnr @ 10315'. Ran RTTS pkr, set @ 10208. Sqz cmtd lnr lap & holes @ 10315 w /130 sx "Gt', final press 3000 # #. Would not hold. Circ clean, P0. Ran 9 -5/8" scraper. Top cmt 102 w /stringers @ 10280. Ran 7" scraper. CO cmt in lnr 10280' - 10315'. Circ clean @ 10350'. Ran RTTS pkr @ 10209'. Resqzd cmtd lnr lap & holes @ 10315' w /200 sx "G ". Max press 4000 #, held OK. Circ clean. CIP 6 am 6/16/69. RI w /da & CO cmt to 10711. Tstd lap to 2500 ## OK. Tstd pipe rams & Hydril to 2500 #. POH. PU Schlum, perfd four 1/2" hpf 10480'- 10490'. Ran 7" Howco DST tools on 3 -11' and 4 -1/2" dp w/750 ## wtr cushion. DST #1: Pkr set @ 10446, set tail @ 10459, opened @ 5 PM 6/17/69, very light bubble blow, then dead, left open 1 hr. PU & reset pkr @ 10536. Open tool, well dead. PO charts OK, indicated complete drawdown IF & FF 750 #. Schlum perfd four 1/2" hpf 10430'- 10440'. Reran tst tools on dry dp. DST # #2: Pkr @ 10384' tail @ 10397'. Open for 30 min. IF @ 2:55 am 6/17. Gas surf immediately. Flowed dry gas, no liquid for 30 min. Surf press continually increasing. Shut tool in for 1 -1/2 hrs. ISI period @ 3 :25 am. 8. L IT, FAR.hI OR Kenai Unit P'OT771 NO. P-4 STATF nr- AI ACVO 0 TOT 9Tr rwT nT TVT Tr'A TT, - -- -- yr avivlvirx, a,. NLxco 11V nuLXc J1GP., l:AJ11VGi AN1J UkUVI NTING JOBS INCLUDINIG DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE, CONDITIONS. KENAI DEEP UNIT #4, JUNE 1969 Surf press 350 #. Opened tool for flow @ 4:55 am. Pkr failed. PO w /tstr. IH 6220 IF 558 FF710 ISI 4325, FH 6373. RU Sdhlum, perfd four 1/2" hpf hyper -jet 10470' - 10428', 10279'- 10258', 10002' - 9994 9986 9952 9947' - 9937' RI w /6" bit to 10711 PO & l.d. dp. RU & ran 331 jts 3 -1/2" N -80 9.2# butt. tbg (Long String) w /tail @ 10400', RH -1 pkr @ 10398, & RH -2 dual pkr @ 9885. Ran 8, 4 -1/2" OD blast jts across upper perfs. Tbg landed 13.20' below KB. Landed in Cameron DCB tbg head. Ran 322 jts 3 -1/2" 9.2# N -80 butt. tbg as short string. Stab into RH -2 pkr @ 9885'. Landed tbg. Removed BOE. Instld Xmas tree.. Press tstd to 5000 #. Displaced mud w /wtr. Set & press tstd pkrs OK. Depressed wtr w /gas fm KDU #2. Brought short string on & cleaned up. SI w/2840# surf press. Brought long string on and cleand up. SI w/3150# surf press. Blew annulus dry. Closed all sleeve valves. RIG RELEASED 8:00 AM 6/22/69. 14. I hereby certify that SIGNED___ A TITLE Dist. Drlg. Supt. DATE 7/14/69 NOTE — Report on dis form is1equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Mine is by the 15th of the succeeding month, unless otherwise directed. i "I 5. API NUI4ERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50- 133 -20176 MONTHLY REPORT OF DRILLING 6. LEASE DES:GNATION AND SERIAL NO. - AND WORKOVER OPERATIONS A 028142 1 7- IF INDIAN, ALOTTEE OR TRIBE NAME OIL ❑ GAS WELL OTHER 2. NAME OF OPERATOR 8. LTIN IT FARM OR LEASE NAME Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Kenai Deep Unit #4 (13 -7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field - Middle Kena 11. SEC., T., R., Al., (BOrrONI HOLE OBJECTIVE) Sect. 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 - -- -- yr avivlvirx, a,. NLxco 11V nuLXc J1GP., l:AJ11VGi AN1J UkUVI NTING JOBS INCLUDINIG DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE, CONDITIONS. KENAI DEEP UNIT #4, JUNE 1969 Surf press 350 #. Opened tool for flow @ 4:55 am. Pkr failed. PO w /tstr. IH 6220 IF 558 FF710 ISI 4325, FH 6373. RU Sdhlum, perfd four 1/2" hpf hyper -jet 10470' - 10428', 10279'- 10258', 10002' - 9994 9986 9952 9947' - 9937' RI w /6" bit to 10711 PO & l.d. dp. RU & ran 331 jts 3 -1/2" N -80 9.2# butt. tbg (Long String) w /tail @ 10400', RH -1 pkr @ 10398, & RH -2 dual pkr @ 9885. Ran 8, 4 -1/2" OD blast jts across upper perfs. Tbg landed 13.20' below KB. Landed in Cameron DCB tbg head. Ran 322 jts 3 -1/2" 9.2# N -80 butt. tbg as short string. Stab into RH -2 pkr @ 9885'. Landed tbg. Removed BOE. Instld Xmas tree.. Press tstd to 5000 #. Displaced mud w /wtr. Set & press tstd pkrs OK. Depressed wtr w /gas fm KDU #2. Brought short string on & cleaned up. SI w/2840# surf press. Brought long string on and cleand up. SI w/3150# surf press. Blew annulus dry. Closed all sleeve valves. RIG RELEASED 8:00 AM 6/22/69. 14. I hereby certify that SIGNED___ A TITLE Dist. Drlg. Supt. DATE 7/14/69 NOTE — Report on dis form is1equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Mine is by the 15th of the succeeding month, unless otherwise directed. i "I HLB TRM �J� P`orm No. P-4 .. . I w r v w --- -- -_ . �. r w .e.e� l it . /X��� r J 1 /'� I L V 1 I"�Lrw+��r� R r'V. 9 -90 -67 5. API NU CODE K`V OIL AND GAS CONSERVATION COMMITTEE 50- 133 -20176 HWK _ 6. LEASE DESIGNA AND RfLIAL NO. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS A 028142 1 7. IF INDIAN. ALOTTEE OR TTILE NAME OIL GAB WELL WELL X1 OTHER 2. NAME OF OPERATOR B. UNIT FAR1wI OR LEASE NAME Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Kenai Deep Unit #4 (13 -7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field - Middle Ker 43 -7 Drilling Pad, 253' South & 4209' East from NW 11. SEC.. T., R., M ., 0307TOM 110LE corner, Section 7, T4N, R11W, SM. OBJECTIV Section 7, T4N, RllWi SM. 12. PERMIT NO. 69 -12 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN Hoiz CONDITIONS. KENAI DEEP UNIT #4 MAY 1969 Drld 12 -1/4" hole from 9170' toll,151'TD. Circ & condition for "E" logs. Pulled 50 stands. Tight hole (coal) @ 9090', 8880', 8480'. Drld up and reamed same. Ran back to btm. Circ & condition hole. POH to log. Stopped @ coal bridge 7897'. Ream and drill up thru tight spot. While reaming, 4 -1/2" pin stripped out of box @ 219'. Drill pipe string dropped to btm. Ran overshot, caught fish. Circ fish -free. Pulled 180' off btm. While pulling up, lost 130,000# wt. Ran back to btm, screwed into fish. Pulled to 10636'. Pipe stuck. While working dp, string jumped w /weight loss 100,000 #. Drill pipe parted 3rd time. Did not attempt to.engage fish. POH. Recovered overshot & jars plus 25 its Hevi -wall dp (6 jt HW & 30 jts dp very badly kinked). Estimated top fish 9741' top collars 10439', btm 10636'. RI w /HW bent singles, bumper jars,'17 jts BY on dp. Layed down bent dp & replaced same. RIB, screwed into fish @ 9741'. Jarred without success. Ran dia -log. Unable to work tools below 9912' due to apparent severly bent dp. Attempt to back off @ 9888'. No sucess. Backed off @ 9828; POH. Recovered 4 its HW dp w /btm it severely bent. RIB, screwed into fish. Circ & condition mud. Backed off @ 10,013. POH. Recovered 3 its bent HW. RIH, screwed into fish. While torque to left to back off, fish unscrewed 2 singles above DC. Top fish @ 10412'. PO & recovered 13 jts 11W all bent. RIB, unable to screw into fish. POH, RI w /overshot - worked over fish. Circ clean. While working torque down hole for free point, dp backed off @ 600'. Pipe dropped 3'. Unable to move dia -log line. Strip over line & screw into dp. Released overshot, pipe free. Condition mud. PO w /overshot to check string. Stuck overshot @ 9794'. Jarred down, came free. Ran to btm. Attempted to stick overshot, no success. Attempted to blow off BS above socket. No success. PO11, stuck on purpose @ 9794'. Tighten string to right. Attempt to work left torque in string to back off overshot. Drill pipe parted @ 900' + -. P ipe fell to btm. Strirg in hole over dia -log line & screwed into fish. PU, pipe free. Pulled & recovered dia -log wireline. Pulled dp, tight spot @ 9794, worked thru same. Considerable drag indicating bent dp. POH. Discovered overshothad broken off when pipe dropped. All HW dp bent & 115 jts ai I Forth No. P-4 CTATG F (1 AI ACICA CTTTZTRrr TNT TITTPT.Tf'eT'F PAGE TWO IS. MZ1_UA.L' '1'Ul'A11 Al' ANu Ur' MUN1'tl, UMA.N( X;6 LN HULK 514E, UASINU AND C;1:MkNTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE, CONDITIONS. 4 -1/2" pipe bent. Layed down total 250 jts bent dp. PU 250 jts replacement pipe. RIH w /oedp, top fish @ 10,409' (Overshot on btm) . Started to circulate, swivel leaked. Pulled to shoe of 13 -3/8" csg. Repaired swivel. Ran to 10,409', circ & condition hole for "E" logs. POH. RU Schlumberger. Ran DIL & Sonic logs. Attempted to run SNP log. Very sticky. Stopped @ 9700'. Worked tool out of hole. Tight 9700' to 7000'. RIH w /bit & stabilizer on dp to 10,409'. No bridges, hole opened. Circ & conditioned for csg. Ran.dia -log collar shot. Shot off special sub leaving 12 -1/4" bit & stabilizer in hole. Top fish 10,400'. PO w /oedp. Ran 251 jts. 9 -5/8" 43.5 #, 47 #, & 53.5 # N -80 & P -110 seal lock csg. Hung w /shoe @ 10,310'. Cmtd w/915 sx ""G"" mixed with 1/2 cu.ft. perlite per sack, followed by 500 sx "G". CIP 9:00 a.m. 5/30/69. Removed 13- 5 /8 " Landed csg. Installed 13 -5/8" 5000# x 10" 5000# tbg head & 10" 5000# BOE. Press tst OK.,, RI w./ 8 -3/8" bit on dp. Locate top cmt @ 10 CO cmt 10 - 10,310', shoe @ 10,310'. Cmt 10,310' - 10 CO to 10,400'. POH. RI w /oed,p hung @ 10,397'. Plugged open hole with 125 sx "G" cmt w /15% sand. CIP 5:00 pm 6/2/69. 14. 1 hereby certify t e fore o' correct SIGNED TITLE Dist w Dr1g,. Supt. DATE _ 6/10/69 a ev NOTE PReport do this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & M erals by the 15th of the succeeding month, unless otherwise directed. 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING 6. LEASE DES:GNA?ION AND SERIAL NO. AND WORKOVER OPERATIONS 1. 7. IF INDIAN, ALOTTEE OR TRIBE NAME 01L ❑ GAB 'WELL WELL OTHER 2. NAME OF OPERATOR 8. UN IT FARM OR LEASE N.kME Union Oil Company of California 3. ADDRESS OF OPERATOR 9. WELL N O. Kenai Deep U nit #4 ( 13 -7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTITO1%4 HOLE OBJECTIVE) 12. PERMIT NO. 69 -12 IS. MZ1_UA.L' '1'Ul'A11 Al' ANu Ur' MUN1'tl, UMA.N( X;6 LN HULK 514E, UASINU AND C;1:MkNTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE, CONDITIONS. 4 -1/2" pipe bent. Layed down total 250 jts bent dp. PU 250 jts replacement pipe. RIH w /oedp, top fish @ 10,409' (Overshot on btm) . Started to circulate, swivel leaked. Pulled to shoe of 13 -3/8" csg. Repaired swivel. Ran to 10,409', circ & condition hole for "E" logs. POH. RU Schlumberger. Ran DIL & Sonic logs. Attempted to run SNP log. Very sticky. Stopped @ 9700'. Worked tool out of hole. Tight 9700' to 7000'. RIH w /bit & stabilizer on dp to 10,409'. No bridges, hole opened. Circ & conditioned for csg. Ran.dia -log collar shot. Shot off special sub leaving 12 -1/4" bit & stabilizer in hole. Top fish 10,400'. PO w /oedp. Ran 251 jts. 9 -5/8" 43.5 #, 47 #, & 53.5 # N -80 & P -110 seal lock csg. Hung w /shoe @ 10,310'. Cmtd w/915 sx ""G"" mixed with 1/2 cu.ft. perlite per sack, followed by 500 sx "G". CIP 9:00 a.m. 5/30/69. Removed 13- 5 /8 " Landed csg. Installed 13 -5/8" 5000# x 10" 5000# tbg head & 10" 5000# BOE. Press tst OK.,, RI w./ 8 -3/8" bit on dp. Locate top cmt @ 10 CO cmt 10 - 10,310', shoe @ 10,310'. Cmt 10,310' - 10 CO to 10,400'. POH. RI w /oed,p hung @ 10,397'. Plugged open hole with 125 sx "G" cmt w /15% sand. CIP 5:00 pm 6/2/69. 14. 1 hereby certify t e fore o' correct SIGNED TITLE Dist w Dr1g,. Supt. DATE _ 6/10/69 a ev NOTE PReport do this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & M erals by the 15th of the succeeding month, unless otherwise directed. Form No. P--4 i A &+ Li A REV. 9 %.11 IL v1 5. API NUI4ERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50 - 133 - 20176 KLVGY.,+, 6. LEASE DES:GNATION AND SERIAL NO. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS A 028142 1. 7. IF INDIAN, ALOTTEE OR TRIBE NAME OIL GAB WELL CELL 12 OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 W. Northern Lights Blvd. Anchorage, Ak 99503 Kenai Deep Unit #4 (13 -7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 43 -7 Drilling Pad, 253' South & 4209'East from NW Kenai Gas Field 11. SE ., (BOTTOM HOLE corner Section 7 , T4N , R11W, SM . Sect. 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ANZI VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLZ CONDITIONS. KENAI DEEP UNIT #4 (13 - APRIL 196 Opened 12 -1 /V hole to 17 -1/2" hole fm 5523 - 6050'. Circ for csg. Ran 158 jts 13 -3/8" J -55 61# seal lock csg. Hung w /shoe @ 6026'. Cmtd thru shoe w/2309 sx "G" with 1/2 cu.ft.perlite per sack & 6% gel, followed by 950 sx "G ". CIP 10:00 PM 4/3/69. Good cmt returns to surf. Rmv flydril, instl slips, cut off & landed csg. Instld 20" 2000# x 13 -5/8" 5000# csg head, 13 -5/8" 5000 #,double Shaffer & 13 -5/8" 5000# Hydrill. Press tst BOE, choke lines & kill lines 3000# OK. Prep to make up d.a. Rig Shut down for repairs on 4/5/69. Resumed operations on 4/12/69. Drld out cmt in 13 -3/8" csg f 5584 - 6026', shoe @ 6026'. CO to 6050'. Drld 12 -1/4" hole to 6250'. Circ clean. RIH w /DDrl. Oriented & DDrld to 6380'. POH• RI w /follow assembly. Drld 12 -1/4" hole 6380 - 6431'. POS=Y, reran DDrl & DDrld 6431- 6500'. P0, ran follow assembly. Drld to 6530'. DDrld 12 -1/4" hole to 6575'. POH, ran locked d.a. Drld to 6718', mud cut fm 88# to 79# carrying 800 units gas. Circ gas & raised mud weight to 91 #. Well dead. Cont drlg to 8916'. P0, fnd washout between morsel drill collars. Layed down drill collars & changed out same. Drld to 9170'. Now Drilling. HLB TRM OKG� KLVGY.,+, V HW,t( FILE MAY 15 1969 DIVISION OF OIL AND GAS ANCHORAGE 14. I hereby certify thM/I #e foi-fg*j is, true and correct SIGNED TITLE Dist. Drlg. Supt • DATE RECEIVED 5/13/69 NOTE to this folinerals is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & by the 15th of the succeeding month, unless otherwise directed. �r Perm No. P-A ..- . . . ^ - A REV. 9-30 -67 %.71r1%1 L_ v1 r_".rwi." --- - - -- 5. API NUl7ERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50- 133 -20176 6. LEASE DESIGNATION AND SERIAL NO. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS A - 028142 1. 7. IF INDIAN, AL.OTTEE OR TRIBE NAME OIL ❑ WE n WELL OTHER - 'WELL 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Kenai Unit Union Oil Company of California 3. ADDRESS OF OPERATOR 9. WELL NO 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 Kenai Deep Unit #4 (13 -7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 43 - 7 drilling pad, 253' South & 4209' East from NW corner 11. SE (BOTTOM HOLE Section 7, T4N, R11W, SM. Sec. 7, T4N, R11W, SM. 12. PERMIT NO. 69 -12 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLU1JING IJE.V'Iri SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOL IF CONDITIONS. Kenai Deep Unit #4 (13 -7), March 1969 RIH. Drld 12 -1/4" hole to 5540'. Circ & condition hole for electric logs. Ran Schlumberger DIL, Gamma Ray Density, & SNP Logs. Opened 17 -1/2" hole to 4820'. Rig shut down repairing pumps. Resumed operations 9 am 3/11/69. (Down 25 -1/2 hrs). RI w /110. Opened 12 -1/4 hole to 17 -1/2" hole to 5348'. Circ clean, prep to P0, stuck pipe while moving down @ 5296'. Good circ. Bumper sub action, but no jar action. Hole sloughed. Ran Dia -Log. Stuck @ 4468'. Backed off @ 467 2. P0, recovered all dp & bs. RI w /jars, screwed Into fish @ 4672'. Jarred without success. Attempted to washover fish with no success. PO, layed down all fishing tools. RI w /oedp & hung @ 4620'. Plugged across top fish w /500 sx Class "G" cmt 4/15% sand & 2% CaCl 2- CIP 2 :30 am 3/18/69. Theoretical top cmt 4370'. WOC. RI w /bit & HO. Located top cmt @ 4164'. Trimmed hard cmt 4164 -4210. Circulated and conditioned mud for DDrl. Ran to 42 10'_, Circulated. While POH, hit c rown w /blocks Severely damaged sheaves, wtr table, & broke several derrick welds. Rig shut down for repairs. Continued operations @ 11:30 pm 3/20/69. POH. RI w /DDrl & DDrld 4210 -4360' sidetracking prig hole. PO, RI w /da & drld to 5290'. DDrld to 5355'. Drld to 6050'. Circ for logs. RU Schlumberger, circ clean on btm. POH., Reran Schlumberger DIL, Gamma Density & SNP logs. RD Schlumberger. RI w/ 17 -1/2" HO to 4210' prep to continue opening hole. Mud pumps failed. Rig shut down. Resumed opera- tions @ 11:30 am 3/27/69. Opened 12 -1/4" hole to 17 -1/2" hole tch TRM Now opening hole. `` O KG APR 17 1969 KLV DIVISION OF OIL AND GAS RE1 ____� - " ANCflOW3E 14. I hereby certify TITLE - Dist. Drlg. Supt. DATE 4/15/69 ' /�1 /f�flil� :i��1 �11F71111':�►7 NOTE -R port on this fo is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & tinerals by the 15th of the succeeding month, unless otherwise directed. Form 9 - 3 n_a� IN EI P-4 u �r c_s STATE OF ALASKA SUBMIT DULIGATE ~ HlB �1 1 5. API NLJ14ERICAL CODE OIL AND GAS CONSERVATION COMMITTEE TRM 50- 133 -20176 MONTHLY REPORT OF DRILLING OKG 6. LEASE DESIGNATION AND SERIAL NO. AND WORKOVER OPERATIONS KLV A - 028142 HWK I REL r ( i. IF INDIAN, ALOTTEE OR TRIBE NAME OIL GA WELL WELL OTHER 2. NAME OF OPERATOR 8. L FARM OR LEASE NAME Union Oil Company of California r Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 W. Northern Lights Blvd., Anchorage, Ak. 99503 Kenai Deep Unit #4 (13 -7) 4. LOCATION Of WELL 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 43 - 7 Drilling Pad, 253' South & 4209' East from NW 11. SEC.. T., R., M., (BOTTONT HOLE corner Section 7, M, R11W, SM. OBJECTIVE) Sec. 7, T4N R11W, SM. L 69 PERMIT NO. -12 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HO CONDITIONS. KENAI DEEP UNIT #4 -- (13-7), FEBRUARY 1969 SPUDDED: 8 :00 PM 2/11/69. Drld 15" hole to 400 Ran DDrl, oriented & DDrld to 746'. Drld 15" hole to 1260'. Opened hole to 26" 0 1260'. Ran 30 jts 20" 94# H -40 8rd csg w /Howco stab -in shoe. Hung w /shoe @ 1234. Ran 1 t cmt, could not stab into shoe, sand in csg. Fabricated 20" cmtng head. Broke circ, free. RU Dia -Log. Ran collar locator, found csg parted @ 943' w /top of lower section @ 969' & shoe @ 1260'. Picked up jt #31, lowered top section 26' in hole, stab into lower section. Ran Dia -Log to re -check csg break. Could not locate break @ 969'. Ran 17 -1/2" HO on d.p. No restriction thru csg part @ 969'. Parted csg lined up. RU Schlumberger, shot 12 -1/2" holes between 1256' & 1260' (@ shoe). Welded on cmtng head. Free circ. Cmtd 20" csg w /800 sx Class "G" mined with 1/2 cu.ft. perlite per sack. & 6% gel, 1% D -31 followed by 300 sx Class "G ". Displaced w/1818 cu.ft. mud. Theoretical top cant 910', Good returns to surfacer CIP 1:00 AM 2/18/69. WOC. Cut off 20" csg. Instld slip on - w6ld Cameron 20 ", 2000# csg head. Tstd OK. Installed 20 ", 2000# G - K Hydril. RIH, tstd Hydril to 900# OK. Found top cmt @ 920'. Drld medium to firm cmt 920'- 1260'. Drld 121/4" hole to 2526'. PO for bit chug. Stuck d.p. @ 1878', worked free. Picked up Kelly, reamed hole to 1918 While reaming, twisted off d.p. @ 331'. Ran overshot & caught fish. PO & recovered all d.p. bumper sub, stabilizer, & 2 drill collars. Drill collar backed out of stabilizer @ 1561'. Ran Dia -Log. Checked surface csg string, all OK. RIH to screw into fish @ 1561' w /bumper sub &��jars. Jarred, worked pipe, PO & recovered all fish. Layed down all 4 -1/2 d.p. & picked up new drill pipe. �r� Now running in picking up drill pipe to drill ahead. . , 14. I hereby certify SIGNED and MAR 17 1969 DIVISION OF Oil AN D OAS ANCM`,.�E DATE 3 /11/69 TITLE Dist. Drlg. Supt. NOTE— Report on this ffirm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines FN Minerals by the 15th of the succeeding month, unless otherwise directed. Form P =3 pp Submit "Intentions" in Triplicate REV. 9 -30 -67 d & "Subsequent. Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT —" for such proposals.) 1. OIL W ELL � I WE LL 91 OTHER - RED 5. API NUMERICAL CODE TRM 50- 133 -20176 OKG.'' 6. LEASE DESIGNATION AND SERIAL NOK LV A- 028142 HWK — REL 7. IF INDIAN, ALLOTTEE OR TRIBE NAM 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME FILE Union Oil Company of California Kenai Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 507 W. Northern Lights Blvd., Anchoraee. Alaska 99503 1 Kenai Deep Unit # (13 -7) 4. LOCATION. OF WELL At surface (See Below) 13. ELEVATIONS (Show whether DF, RT, G.R., etc. 112. PERMIT NO. RT 90' 1 69 -12 14. Check Approp Box To indicate Mature of Nbtice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT -OFF PULL OR ALTER CASING WATER SHUT -OFF REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* _ REPAIR WELL CHANGE PLANS (Other) change surface location KX (Other) (NOTE : Report results of multiple completion on Well (` ompletion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and dive pertinent dates, including estimated date of starting any proposed work. Surface Location Change as Follows: ORIGINAL PROPOSED LOCATION 43 -7 Drill Pad - 305' South and 4231' Bast from NW corner Sec. 7, T4N, R11W, SM. ACTUAL LOCATION 43 -7 Drilling Pad - 253' South and 4209' East from NW corner Sec. 7, T4N, R11W, SM. C CF CAS pVYISQQ ;v 16. I hereby certify hf the f o le true and correct SIGNED Dist. Drlg. Supt. 2/19/69 � TITLE DATE — (This space for State & se) APPROVED d �v BY TITLBi DATE CONDITIONS OF APPROVAL, IF ANY: 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N. R11W. SM. See Instructions On Reverse Side DIVISION OF OIL AND GAS January 31, 1969 Re: Kenai Unit Kenai Deep Unit #4 (13-7) u ll io n ,oil Company of Calif., operator Robert T. An4erson Uniou Oil Company of Callfornia 2805 Deaali Street Anchorage, Alaska 99503 Dear Sir*, Enclosed, please find the approved application for permit to drill the referenced well. Well samples and core chips are not required Very truly yours, limier L. Durrell Director by 'rhomas R. Marshall,, Jr. Acting Director HLB:mac Enclosure FORM SA -IB MEMORANDUM T 0 : F H. Shepard Industrial Safety Lwpector Dart m at of Labor FROM: Amer L. Burrell Diroctnr by Thaw R. Marshall, Jr. Acting Director State of Alaska DIVISION OF OIL AND CAS DATE Janna ry 31„ 1969 SUBJECT: i Unit tmai Deep Unit #4 (13-7) Union ail Company of Calif., operator EncUmed is a +ropy of the approved application to drill for the above eaptiomw wells wo FORM SA -I B T0: r Dale Wallington covaissioner FROM: Homer L. Burrell Director by Thou" R. Marshall, Jr. Acting Director State of Alaska DIVISION OF OIL AND GAS DATE Janmry 31, 1969 SUBJECT: K,eimi Unit Kenal. Doop Unit 04 (13 -7) union Oil Company of Calif . ,, operator Eaclosed are the opproved application for permit to drills plat and a thec in the avow t of 50 for film feu.. elos+nrea P. I. 50- 133 -20176 SUBMIT IN TRF iTE Form P -1 (Other instruction i reverse side) REV. 9 -30 -67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK Ia. TYPE OF WORK DRILL U DEEPEN ❑ PLUG BACK ❑ b. TYPE OF WELL OIL OAS WELL WELL TN OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS (YF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL At surface 43 -7 Drilling Pad, approx. 305' South & 4231' East from NW pro corner . o e ' 7 ��T4 R11W, SM TOP D INTERVAL: 825 East & 3100 South from NW corner, Sec. 7, T4N, R11W, SM J ^ 5. 6. LEASE DESIGNATION AND S ERIAL NO. A- 028142 7. IF INDIAN, ALLOTTEE OR TRIBE NAME I 8. UN1T OR LEASE NAME Kenai Unit 9. WELL NO. Kenai Deep Unit #4 (13 -7) 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T4N, R11W, S.M. 13. DISTANCE IN MILES AND DIRECTION F,,OM NEAREST TOWN OR 1-0,51' 7 miles from Kenai 14. BOND INFORMATION: TYPE Statewi de Surety and /or No. Federal Insura Co. # 011-38-40 Am ount $100,000.00 I5. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17. NO. ACRE'S ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. 20 2 5 60 320 (Also to n ear e st drill, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION* 19. PROPOSED DEPTH 2O.' ROTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 4100' 11,870 & 10,600'VD Rota 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START* RT 90' 1 February 1, 1969 23 • P'ROPOSE'D CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Q UANTITY OF CEMENT - 30" Conductor - 20' D riven 26 20" 94# H -40 1200' _ 1 000 sacks C, 17 13-3/8 61# J -5.5 S400 5000 12 4 " 9-5/8" 140#.43.5# N -80 11 _ 3000 /i-.. / P -110 Drive 20' -30" Conductor. Drill 17 %" directional hole to 1200 Open 17?" hole to 26 hole. Cement 20 casing at 1200 Install 20 Hydrill. Drill 124" directional hole to 5400 Run, electric logs. Open 124" hole to 1712'" hole. Cement 13 -3/8 casing at 5400 Install 5000# BOE. Drill 124 1 l.directional hole to 11,870 Run electric logs. Cement 9 -5/8 casing at 11,870 Complete for gas production thru dual 3 2 " tubing string. Botbm Hole Location: Approximately 200 & 3610 from NW corner, Sec-7, T4N, R11W, SM IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface lo- cations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify that F,pregoing is T pup and Greet DATE January 28, 1969 TITLE District Land Ma nager (This space for State office use) CON.61TIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED OTHER, REQUIREMENTS: ❑ YES g NO f DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE C 1 YES ❑ NO �� Q / 7 SINGLE JR MULTIPLE ❑ ZONE ZONE PERMIT N ++ r-x(,)cu:iae Secretary r• APPROVED B %D `'� 2'c-+' ii` ;" l _. TITLE. DATE p L *See Instructions 33- 0 -4- - 44-30 I �l 1 1 32 3 3 32 i 34- 31 2 1 -6 313 i ` _ O A T5N -R I T4N- RIIW KDU 3 TARGET B o (21-5) TMD 9550 b PBHL_ TVD 8750' TMD 11 375' TVD 10,550 43 -6 r � l) I yyyyyyllllll���� �43 -6A I i + K D•U I 14 -4 I // I I 14 -6 21 II db -7 K_D.U.2 1 UNION OIL COMPANY OF CALIFORNIA i A LASKA DIST Cr K D.0 4 43 -7 WELL LOCATION PLAT KENAI GAS FIELD K.D.U. -3 +. 4 (21 -5) D A T E NOV, 1968 0 2000' J SCALE I " = 2000 -- ' T
