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Home My WebLink About182-015 Image'=l~roj,ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .L ~ ~- O ~_,-...~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grav.~,-~,-" [] Other, No/Type [] Other items scannable by large scanner 'J:::S ~uor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN VINCENT ~MARIA WINDY DATE:~ Project Proofing BY: ~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation BY: BEVERL~VINCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: / / ~! PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Stage 2 ~~YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY ROBIN VINCE~ARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLE~ SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned Ondividual page [special at~e~tlon] $ca;mtng completed) DATE'// ~-- -/ ~SI Ill Illllllllll II Ill RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or.Comments about this file: ISl Quality Checked (do.e) 12110/02Rev3NOTScanned.wpd M Marathon MARATHON Oil Company August 27, 2008 Mr. Tom Maunder • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~ ~~ Rh A' pm. Alaska Oil & Gas Conservation Commission 333 W 7t~ Ave ~ti ~, ~ ~ _ 200$ ~~~~ SEF f Anchorage, Alaska 99501 1 ~ ~~ Reference: 10-404 Report of Sundry Well Operations ~./ Field: Kenai Gas Field Well: Kenai Unit 14-32 Dear Mr. Maunder: Attached for your records is the 10-404 Report of Sundry Well Operations for KU 14-32 well. A total of 97' of perforations were shot across three intervals under Sundry approval # 300-297. MD TVD 5,287'-5,346' 4,583'-4,628' 5,442'-5,460' 4,702'-4,715' 5,530'-5,550' 4,768'-4,784' This report is a reflection of the well arrangement at the time of work completion 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, ~~~ s~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File KJS STATE OF ALASK~~~~' D ALA~OIL AND GAS CONSERVATION ~~ REPORT OF SUNDRY WELL ORATION(+S . ~ Ai.,~4a tlil ~ G8S C.•Ot1S. lrt3iTif7ilSS10 bandon Repair Well Plug Perfora ions St~g B Other Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ 'rogram ^ Operat. Shutdown ^ Perforate Q ' Re-enter Suspended Well ^ tlon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Development ~ ~ Exploratory^ 182-015 ' 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20351-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 87' (26' AGL) ~ Kenai Unit 14-32 - 8. Property Designation: 10. Field/Pool(s): _ A - 028055- Kenai Gas Field /Sterling Pool 6 11. Present Well Condition Summary: Total Depth measured 5,700' ' feet Plugs (measured) NA true vertical 4,gg7~ . feet Junk (measured) NA Effective Depth measured 5,585' feet true vertical 4,810' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 106' 106' Surface 1,830' 13-3/8" 2,020' 1,856' 3,090 psi 1,540 psi Intermediate Production 4,868' 9-5/8" 5,695' 4,894' 6,870 psi 4,750 psi Liner Perforation depth: Measured depth: 4,596' - 5,550' True Vertical depth: 4,034' - 4,784' - Tubing: (size, grade, and MD) NA Packers and SSSV (type and measured depth) NA 12. Stimulation or cement squeeze summary: Added Perforations t~ Intervals treated (measured): MD TVD 5,287'-5,346' 4,583'-4,628' Treatment descriptions including volumes used and final pressure: 5,442'-5,460' 4,702'-4,715' 5,530'-5,550' 4,768'-4,784' 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 0 ' Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas Q ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 300-297 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician ~ Signature ~ Phone (907) 283-1371 Date August 27, 2008 Form 10-404 ReviseathQ4~ ~ /'~ ~ {~ ! /~ S I~~'~- SEP ~ g 20D8 Submit Original Only ~ i`Z A r MARATHON OIL COMPANY ~ DAILY WELL OPERATIONS REt PAGE 1 OF 1 DATE: 12/8/00 FIELD: Kenai Gas Field WELL #: KU 14-32 FILL DEPTH/DATE: TUBING: CASING: DATE LAST WL WORK: TREE CONDITION: new WORK DONE: Perforate C-1 & C-2 Sands BENCHES OPEN: PRESENT OPERATION: WIRELINE CREW: OTHER: Hrs. SUMMARY OF OPERATIONS 1430 1700 1800 1930 2100 2300 0100 MIRU Schlumberger. RU R&K triplez pump to pressure test lubricator. Test lubricator to 2000 psig using methanol. SITP = 8 psig. PU 20' of 4.72", 12 spf, 135/45 degree phased guns loaded with 21.0 gm 34J-UJ charges (0.31" entrance hole) and RIH. Prior to tying in, decide that the existing GR/CCL correlation log is unacceptible. POOH, lay down guns. IPU and RIH with GR-CCL log. Correlate with DIL log, tag fill at 5571'. POOH. IPU 20' of guns again and RIH. Position guns 55301-5550' and fired. POOH. All shots fired, no change in tubing pressure. i8' of guns as described above and RIH. Position guns 5442 =5460' and fired. POOH. All is fired, no change in tubing pressure. 21' of guns as described above except the top 10' of guns loaded with 34B-CS charges ead. RIH. Position guns 5325' - 346' and fired. POOH. All shots fired, slight change in ping pressure from 8 psig to 10 psig. PU 18' of guns as described above with the 346 charges and RIH. Position guns 5307' - 5325' and fired. POOH. All shots fired, no change in tubing pressure. PU 20' of guns as described above with the 34B charges and RIH. Position guns 5287' - 5307' and attempted to fire. POOH. Replaced firing mechanism and reran gun. Position guns 5287' - 5307' and fired. POOH. All shots fired, no change in tubing pressure. IRDMO Schlumberger. Well still only has 10 psig SITP. Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: • M Marathon MARATHON Oil Company • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 August 26, 2008 ,b~ Mr. Tom Maunder ~~ ~~ :~:.~ Alaska Oil & Gas Conservation Commission 333 W 7th Ave AUG ~ ~r.,~,_ Anchorage, Alaska 99501 Alaska Oil ~ ~~ ~, .__ Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Unit 14-32 Long ~~,~N~~ SEA' 200 Dear Mr. Maunder: Attached for your records is the 10-404 Report of Sundry Well Operations for KU 14-32L well. Sundry # 300-225 was requested to patch a hole in the long string tubing. The initial work scope changed eliminating the need to patch this hole. This report is being submitted as a non-work sundry. Submission of this report is part of Marathon's ongoing effort to close-out the backlog of outstanding sundries. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, „QitT+~- °~.J Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS ~~~~1~V STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMIVI~~I ~ 20Q8 REPORT OF SUNDRY WELL~T(~~ns. Commission ~~~~~ 9-add' 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Non-Work of Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Tubing Patch Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ Sundry 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development Q Exploratory^ 182-015 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20351-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' (26' AGL) Kenai Unit 14-32 Lon 8. Property Designation: 10. Field/Pool(s): A - 028055 Kenai Gas Field /Sterling Pool 6 11. Present Well Condition Summary: Total Depth measured 5,700' feet Plugs (measured) NA true vertical 4,8g7' feet Junk (measured) NA Effective Depth measured 5,534' feet true vertical 4,772' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 106' 106' Surface 1,830' 13-3/8" 2,020' 1,856' Intermediate Production 4,868' 9-5/8" 5,695' 4,894' Liner Perforation depth: Measured depth: 4,596' - 5,550' True Vertical depth: 4,034' - 4,784' SS 3-1 /2" N-80 4,514' Tubing: (size, grade, and MD) LS 3-1/2" K-55 5,250' Baker Model A-5 Dual Packer 4,498' Packers and SSSV (type and measured depth) Baker Model D Packer 4,700' Baker Model D Packer 5,220' 12. Stimulation or cement squeeze summary: Intervals treated (measured): This work was never done. Sundry is being closed out as a non-work operation. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 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 ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 300-225 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ Phone (907) 283-1371 Date August 26, 2008 (~ ~~s~e~a~ aim ~> air a ~ cuuu Form 10-404 Revised 04/20 6 1-.' ~ ~ ~ ~ A L Submit Original Only ~~ ~~ !~ i • M Marathon MARATHON Oil Company August 26, 2008 ~~~ts~~~ ~~~ s ~ ~~~~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Kenai Gas Field Well: Kenai Unit 14-32 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 5 1~,~' ~ t RECEIVED AUG 2 8 2008 Aiaska Oil & Gas Cons. Commission Anchorage Attached for your records is the 10-404 Report of Sundry Well Operations for KU 14-32 well. Both tubing strings were removed under Sundry approval # 300-243. Submission of this report is part of Marathon's ongoing effort to close-out the backlo~.of outstanding sundries. Please contact us at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~'.~..8 s~.- Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Weil File KJS STATE OF ALASKA ~„~,~5 ~~~~~ , ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATION~G ~ ~ ~aC~B v3 1. Operations Abandon Repair Well Plug Perforations Stim I ~ °"' ' Performed: Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver^ Tirt~l'su~t^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oii Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development Q Exploratory^ 182-015 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20351-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' (26' AGL) Kenai Unit 14-32 8. Property Designation: 10. Field/Pool(s): A - 028055 Kenai Gas Field /Sterling Poo16 11. Present Well Condition Summary: Total Depth measured 5,700' feet Plugs (measured) NA true vertical 4,gg7' feet Junk (measured) NA Effective Depth measured 5,585' feet true vertical 4,810' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 106' 106' Surface 1,830' 13-3/8" 2,020' 1,856' 3,090 psi 1,540 psi Intermediate Production 4,868' 9-5/8" 5,695' 4,894' 6,870 psi 4,750 psi Liner Perforation depth: Measured depth: 4,596' - 5,550' True Vertical depth: 4,034' - 4,784' Tubing: (size, grade, and MD) NA Packers and SSSV (type and measured depth) NA 4 ~~ U 12. Stimulation or cement squeeze summary: ~.~~~yG ~~ ,GT S7~/i/4 U~' ~~ Intervals treated (measured): T wor as ne r don Sun is bei clos d o~ as a n-wor opera n. \ 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 - - - - Subsequent to operation: 0 - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 300-243 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ ~ Phone (907) 283-1371 Date August 26, 2008 Form 10-404 Revised 04/20061{ ~C ~ ~ ~ ~ ~ ~~~ SEP ~ ~~ 2~~8 Submit Original Only ~ `~~ ~ ~. WJ~ ~~ t T -w/ 000916x1s MARATHON OIL COMPANY DATE: 9/16/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: • DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 FIELD: Kenai Gas Field WELL #: KU 14-32 I&s TUBING: 3.5", 9.2#, L-80 CASING: 9-5/8", 47# TREE CONDITION: OK BENCHES OPEN: Tyonek PRESENT OPERATION: Make tubing cuts in preparation of workover. OTHER: Day #1 - AFE 9204499 SUMMARY OF OPERATIONS 11400 12045 MIRU APRS pipe recovery unit on longstring of KU 14-32. Bled KU 14-32 longstring, shortstring, and annulus to zero. RIH with jet cutter for 3-1 /2" tubing. Correlate, and fired jet cutter at 4718' MD (below model "D" packer). Tools stuck. Worked tools for two hours without success. RU to pump fresh water down tubing. Pull free when water pumped past tools. POOH. Tools had gotten blown uphole when we fired. Pulled off bad line, retied rope socket. RIH with another jet cutter. Tie in, attempt to fire jet cutter at 4525'. Cutter didn't fire. POOH, replace CCL. R(H with jet cutter, attempt to fire again. Cutter still not tiring. POOH, replace ail components. RIH, cutter failed to fire a third time!! POOH, rigorously inspect all components. RIH with jet cutter, Tie in at 4525' MD (below dual packer) and successful fired the iet cutter. POOH, stuck at XA sleeve at 4464'. Manage to pull tool string free POOH. hortstrina. RIH with jet cutter. Tie in, fired jet cutter at 4498' (above dual packer) .t to POOH, but unable to get past XA sleeve at 4457'. Work line for over an hour. well, SDFN. Veco crane. Hold onto lubricator with Veco crane. Pull on electric line until wire 9 out of rope socket. POOH, RDMO electric line and crane. tote: Tool string leff in shortstring is 15' long, valued at roughly 52500. - two 1-11 /16" weight bars - one 1-7/ 16" CCL - one 1-7/16" centralizer Vendor E uipment Dail Cost Cumulative Cost Alaska Pi a Recove electric line Misc. misc. Pollard mast truck Veco crane DAILY COST: CUM: REPORTED BY: G. Eller MARATHON OIL COMPANY . DAILY WELL OPERATIONS REF•~ PAGE 1 OF 1 DATE: 9/17/2000 FIELD: Kenai Gas Field WELL #: is-s2 FILL DEPTH/DATE: 5524', 2-10-98 TUBING: 3-1/2" 9.3# L-80 CASING: 9 5/8" 5695' 47# DATE LAST WL WORK: TREE CONDITION: Good WORK DONE: BENCHES OPEN: Sterling PRESENT OPERATION: Pull tool stuck tool sting PROBLEMS: may leave tools in hole SUMMARY OF OPERATIONS 0800 0930 1100 RU crane, had Pollard lay down sheeve on Ak Pipe Recovery Wire line unit. Mu crane PU sheeve, Discussed proceedure to pull out of rope socket if necessary . Pull 2800 LBS on wire tool string came free from lower X-nipple, PUH stuck in upper X-lock. Pull 3000 Ibs on wire, pulled out of rope socket. POOH with wire, leff the following tool string in well.. lea - rope socket (with 1"fishing neck) 12" long 2 ea - 1 11 / 16" stem 10' 1 ea - 1 7/16" CCL 1' 2" 1 ea -Centralizer 2' b" 1 ea -firing assy 8" 1 ea - madril 1' 1 ea -cutter body 8" total length = 17' ~RD Wireline unit, crane etc. WELL TESTS BEFORE: AFTER: COMMENTS: MMSCFPD BWPD TP CP DATE DAILY COST: CUM: REPORTED BY: Cissell • n~IARATHON OIL COMPANY ALASKA REGION ~ t3~ 81~ DRILLING REPORT SUMMARY AKR/Kenai Peninsuia/KU 14-32 27-Sep-00 Rig mob. Set rig mats, substructure, carrier, generator house, boiler house, mud pit trailer. Raised derrick.. R/U. 28-Sep-00 Rig mob. Fire up boiler. RlU mud pump and mudpit trailers. Circ. Water thru system. R/U top drive. 29-Sep-00 Accepted ricl to well KU 14-32 at 0600 hours 9-28-00. N/D tree. N/U BOPE and tested. Fili well with water. ~ ~ l 8 ~ - is- M.,MTHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKRlKenai Peninsula/KU 14-32 30-Sep-0O RIU to pull dual tubing and strings. POOH and UD dual strings. 1-Oct-00 Finished POOH and UD. Dual tubing strings and packer. Changed rams and tested. RIH with fishing assembly. Picking up drill pipe. 2-Oct-00 RIH to 4522'. Milled over top of 31/2" tubing and latched. POOH and UD fish. RIH with packer milling assembly. Mill over packer at 4693'. 3-0ct-00 CBU. POOH and UD milling tools. M/U spear and RIH. Latched packer and POOH. UD fishing tools and half of packer. R1H with overhot. Worked over fish. 4-Oct-00 RIH. Tagged fish at 4879' and chased to 5019'. POOH with no recovery. R1H and attempted to spear fish. No success. RIH and milled over and latched fish. POOH. 5-Oct-00 POOH with overshot. No recovery, Made up spear and RIH. Attempted to spear fish. POOH. Made up flat bottom mill and RIH. Broke circulation at 5,022'. AdUled fish from 5.022' to 5.028'. fi-Oct-00 Continued to mill on fish to 5.029'. Worked on PLC rig controls. POOH. Changed fshing tools. RIH with hollow mill and over shot. Tagged at 5,029': fish worked over ton. POOH. Layed down fishing tools. Rigged up Weatherford to lay down tubing. • • 1r~NRJ-THON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 14-32 Pik t'~3 ~--0/5 7-Oct-00 UD_ 15 JTS of tubing. R1H with mill and cleaned off top of packer RIH and milled over and latched Hacker. 8-Oct-00 POOH with packer. Tested ROPE. Made 8 1/2" mill run to 5300'. 9-Oct-0O POOH. RIH with 8 1/4" tapered mill. Washed and reamed to 5585'. Displaced with clean 3% KCL. POOH to 4572'. 10-Oct-00 POOH. With DP. LD BHA. RU and run scab liner. 11-Oct-00 Set scab liner. POOH UD drill pipe. Installed BPV. N/D BOPE. N/U tree. 12-Oct-00 Installed 2-way check in hanger. Tested tree to 3000 psi. Prep rig for demob. Note: Rig in for R & M. Restart November 1. L~ Marathon MARATHOM Oil Company May 15, 2008 ~~ jS~ ~~', v ; '~ ~ ~ a _~ ~ ,~= . ~ r,. .~~ -~ ~ ~~"~` ~" ~?~ ~' 2~~$ • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 i~AY ~ ~ ~ 7 Oil ~ ~~ ~~'~s' ~°~~~"`i~~~~t . ~ :~lask~ ~chor~~ ~ ~'' 1 Mr. Tom Maunder q ~ 5~~~ Alaska Oil & Gas Conservation Commission ~~h~S~ «~ ~~~~~~ 333 W 7th Ave (~''' ` ~ ' ~,,~ Anchorage, Alaska 99501 ~~ ~~~ ~~ ~~-~~°~~ ~ 5 / Reference: 10-404 Sundry Submittal List + r~~~~5~ u.~~ i~ ~S~~h~, ~~ ,~~- ~~5~~~ ~.«~~`• ~ ~e Dear Mr. Maunder: ~~~ < ~L(~ ` ~, ~ ~. ~ ~c~ ~- cJ c~"~ ~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to /~' ~-~ p p 9 ~~ close out 10-403 Sundry approved well work activities. Work has been ongoing to ~.~~~ 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, /~~~ ~ . ~~~ ~,~~~V ~'r Kevin J. Skiba Engineering Technician w~.'~~~~t,;:: ~~~~~~ ~~ ~`~ ~~~'~~° t?'+° 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 (~'~G~~i V ~ MAY 1 6 ~0~8 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Alaska Oi! & Gas ~~ns• ~~m~'tission An~horage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Unit 14-32 Dear Mr. Maunder: Attached for your records is the 10-404 sundry report for well KU 14-32. This sundry covers the setting of an inflatable plug over the C-2 perforations. The sundry is # 301- 035. The work was completed, the plug was successfully set. Please contact us 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 Operation Summary Kenai Well File KJS KDW STATE OF ALASKA ~~~~~~ 'Sv~~d' ALAS~IL AND GAS CONSERVATION COMMI ,I~I ~~ 20O$ REPORT OF SUNDRY WELL OPERATI S ~ t~ ~ ~ns. Commission 1. Operations Abandon Repair Well Plug Perforations e ~ ra~,er ~ Set Inflatable Performed: Aiter Casing ~ Pull Tubing ~ Pertorate New Pool ~ ~~ ~ Waiver~ ime Extension ~ Plug over C2 Change Approved Program ~ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ~ Perfs 2. Operator 4. Well Class Before Work: 5. Permitto Drill Number: Name: Marathon Oil Company Development 0 Exploratory^ 182-015 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20351-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87 - KU 14-32 - 8. Property Designation: ' 10. Field/Pool(s): ,r'~ A- 028055 Kenai Gas Field/ Sterling Pool 6 11. Present Well Condition Summary: Set inflatable above the C2 interval Total Depth measured 5,700 - feet Plugs (measured) 5410' true vertical 4,gg~ _ feet Junk (measured) N/A Effective Depth measured 5,571 feet true vertical 4,79g feet Casing Length Size MD TVD Burst Collapse Structural Conductor 106' 20" 906' 906' 2110 psi 520 psi Surface 2020' 13-3/8" 2020' 1856' 3090 psi 1540 psi Intermediate Production 5695' 9-5/8" 5695' 4894' 6870 psi 4750 psi Liner Perforation depth: Measured depth: 5596' - 5550' Gross True Vertical depth: 4593' - 4785' Gross Tubing: (size, grade, and measured depth) Straddle 7" 23 aaf L- 80 4563' - 4850' Packers and SSSV (type and measured depth) SLP isolation oacker 4563' SLP isolation aacker 4850' 12. StimulaHon 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 N/A N/A N/A N/A Subsequent to operation: 0 N/A N/A N/A N/A 14. Attachments: 15. Well Class afterwork: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ~ Daily Report of W ell Operations X 16. W ell 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.Q. Exempt: ~ 301-035 y/ Contact Kevin Skiba (907) 283-7371 Printed Name Wayne E. Cissell Title Well Work Over Supervisor Signature Phone (907) 283-1308 ~(,~,1 Date 01/2312008 ~ ~ ~~~ ,,U~ `~ ~ 2009 Form 10-404 Revised 04/2006 Submit Original Only + f~F~RATHON OIL COMPANY ~ DAILY WELL OPERATIONS REPURT PAGE 1 OF 1 DATE: 2/28/2001 FIELD: Kenai Gas Field ~ WELL #: ia-32 FILL DEPTH/DATE: 5565', 10/09/00 TUBING: CASING: 9 5/8" 5695' 47# DATE LAST WL WORK: TREE CONDITION: Good WORK DONE: BENCHES OPEN: Sterling PRESENT OPERATION: Set TRB plug between C-1 and C-2 Zones PROBLEMS: Set lu in wron location SUMMARY OF OPERATIONS 1255 1520 1620 Hold enviornmental, safety, and discuss proedure prior to starting job. RU Schlumberger eline with Baker TTRB plug. PT lub with WHP, WHP= 300 psig. RIH with Thru tubing retrievable bridge plug. Made several tie in passes to correlate setting depth. Set depth at 5410', Set plug, drop back down on plug to verify plug set at set depth. POOH OOH verified TfR6 plug gone. RD Schlumberger. ~Clean up lease WELL TESTS: BEFORE: AFTER: COMMENTS: MMSCFPD BWPD TP CP DATE n Cissell • M Marathon MARATHON Oil Company November 21, 2007 Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave ~~E~~ Anchorage, Alaska 99501 NOV ~ ~ ZOQ7 Reference: 10-404 Sundry Report Field: Kenai Gas Field Alaska Oil & Gas Gans. Commi~~~4n Well: Kenai Unit 14-32 Anchorage -~~~ ~~ V ~ 2007 ~'~ ~ ~ ~ Dear Mr. Maunder: ~~~~~~ NO ~~ Attached for your records is the 10-404 Sundry Report for KU 14-32 well. This report covers the velocity string installation work that Marathon completed under sundry #307- 265. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, , ` ~/ ~~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS DMD STATE OF ALASKA ~~ ~~~G~ ALA OIL AND GAS CONSERVATI N COMf~ION ° Nov ~ s zoos REPORT OF SUNDRY WELL OPERATIONS Alaaska ®il ~ Gas~on~- Cctmmi~ainn 1. Operations Abandon Repair Well Plug Perforations Stimulate Othe~ 6~S~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ~y~ Waiver^ Time Extension ~~11 Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development^ Exploratory^ 182-015' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20351-00-00 7. KB Elevation (ft): 9. Well Name and Number: 8T ~ Kenai Unit 14-32 J 8. Property Designation: 10. Field/Pool(s): ,~D A - 028055 Kenai Gas Field I Sterling Pool 11. Present Well Condition Summary: Total Depth measured 5,700' - feet Plugs (measured) 5,410' true vertical 4,887' - feet Junk (measured) NA Effective Depth measured 5,571' feet true vertical 4,799' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 106' 20" 106 106 2,110 psi 520 psi Surface 2,020' 13-3/8" 2,020' 1,856' 3,090 psi 1,540 psi Intermediate 0 0 0 0 0 0 Production 5,580' 9-5/8" 5,580' 4,807' 6,870 psi 4,750 psi Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 5,287' - 5,550' True Vertical depth: 4,593' - 4,785' Tubing: (size, grade, and measured depth) 1-3/4" QT-800 5,285' Packers and SSSV (type and measured depth) SLP upper isolation packer 4,563' SLP lower isolation packer 4,850' 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 2.5 54 psi Subsequent to operation: 0 436 0.5 128 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-265 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Do ovan Title Production Engineer Signature Phone (907) 283-1333 Date November 21, 2007 Form 10-404 Revised 04/2006 ~ ~~ ~~~ ~ ,~ 2~~/ ~ 11/}~ Submit Original Only 50-133-20351-00-00 Des: A - 028055 87' 17:30 hrs 2/16/1982 hed: 2/26/1982 ase :3/15/1982 3-1 /2" 8 Round - 6' of 7" 23 ppf, L-80 pup joint w/ re-entry guide - 6" type "H" BPV profile, min ID = 5.469" - 7" BTC lift threads KU 14-32 Kenai Gas Field 740' FSL, 1,759' FEL, Sec. 31, TSN, R11W, S.M. Stab Liner Set across 4,563' - 4,850' 7' L-80 23 ppf BTC casing SLP Deckers ~ Upper isolation pkr @ 4,563' Lower isolation pkr @ 4,850' Minimum SLP ID = 6.052- V-String BHA: - 10' Straight Bar - 1.25 XN Profile -Pump-Out -Plug Profile Drive Ploe 20" 94 ppf T~ Bottom MD 0' 106' TVD 0' 706' Surface Casino 73.3/8" K-55 61 ppf BTC Tom Bottom MD 0' 2,020' :~ TVD 0' 7,856' Hole siu = 17-1/2" Cmt wl 1,000 sks of Class G Production Casino 9.518" N-80 47 ppf BTC Top B om MD 0' 5,695' TVD 0' 4,894' Hole size = 12-114" Cmt wl 1,380 sks of Class G Tubina 1-314" DT-800 Work String ,TSp B om MD 0' 5,285' TVD 0' 4,581' 4,596' - 4,658' 8 spf (3/10/82) 4,775' - 4,790' (sgzd 3/8/83) 4,798' - 4'818' (sgzd 3/8/83) 5,287' - 5,346' 12 spf (12/8/00) 5,442' - 5,460' 12 spf (1218/00) 5,530' - 5,550' 12 spf (12/8/00) • M MARATNOM PBTD: 5,580' MD 4,807' TVD TD: 5,700' MD 4,897' TVD Well Name 8 Number: Kenai Unit 14-32 Lease: Kenai Gas Field, Pad 34-31 County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 4,596' - 5,550' (TVD): 4,034' - 4,783' Angle/Perfs: Angle @KOP and Depth: KOP (TVD): BHP (static): 430 psi BHT: Completion Fluid: FWHP: FBHP: FWHT: FBHT: Date Completed: 3/14/1982 RKB: 87' Prepared By: Kevin Skiba Last Revision Date: 1112112007 • KENAI UNIT 14-32 KENAI UNIT 14-32 WORKOVER BJ SERVICES BJ SERVICES Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To Hours Code Code I Phase 7/15/2007 14:00 - 14:30 14:30 - 15:00 15:00 - 17:00 17:00 - 18:00 ~ 18:00 - 18:30 7/16/2007 08:00 - 09:00 I 09:00 - 10:30 10:30 - 16:00 16:00 - 18:00 18:00 - 18:30 7/17/2007 07:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 17:30 Page 1 of 3 Spud Date: 1/15/1982 Start: 7/15/2007 End: Rig Release: Group: Rig Number: CT2 Description of Operations 0.50 SAFETY MTG_ WRLN Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA). 0.50 RURD_ SLIK WRLN MIRU Pollard Slickline. Held PJSM to review JSA and Safe Work Permit conditions. Move in to spot Coil Tubing equipment on KU 14-32 location. RU Crane and Move Well House off of Well Head Tree. Spot coil unit and equipment around well head. 2.00 RURD SLIK WRLN MU tool string and lubricator. Broke pin off in Jars. Send for Replacement Jars. Wait on Replacement Jars to Arrive. Install Jars and Tools to set Plug in Seating Nipple. Pressure Test Lubricator to 500 psi. Held Pressure. 1.00 RUNPU SLIK WRLN RIH with 1" tool string and Plug. Set Plua in Seating Nipple in 2-3/8" Coil Tubin 5285'. POOH with tool string. Blow down coil tbg to 0 psi to insure plug is set and holding pressure. Plug Held. 0.50 RURD_ SLIK WRLN RDMO Pollard Wireline. 1.00 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for Replacing 2nd 2" master valve, 2" Swab Valve, and Wing Valve with 4" Valve, Installing BOPE on Flowing Well Tree, Testing BOPE. 1.50 NUND WLHD CTBG Valcogray Installed Plug in 2-3/8" Coil and Removed 2" Top Master Valve, 2" Swab Valve and Wing Valve. Installed 4" Valve on top of Tree. 5.50 RURD_ COIL CTBG MIRU coil unit and equipment around well head. Nipple up BOPs on top of wellhead. LD liner to set tanks. Set Tanks and Flow back Manifold. 2.00 TEST_ BOPE CTBG Contacted Jim Regg with AOGCC @ 08:00 hrs 7/16/2007 about the BOPE Pressure Test on the KU 14-32. Jim gave us a waver from the commission witnessing the BOPE Test. Jim told me to go ahead and test the BOPE when I was ready and write on the form I file with the commission that he gave me a waver. F nction test BOPs. Pressure test BOPS. Hi h 3000 si .Low 2000 si .Held Pressure. 0.50 SECUR WELL CTBG Install night cap on BOP's. Safe out location and suspened operations for the night. 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations. 2.00 RUNPU COIL CTBG Vetco Gray Released Lock in screws on Tubing Hanger so we could pull coil tubing. Install Tubing Hanger Connection on Coil Tubing. Instal! GS Pulling Tool on Coil Tubing on Coil Tubing Unit. 1.00 RURD_ COIL CTBG PU Coil Tubing Injector and lubricator and install on BOPE Stack. 2.50 TEST_ TBG_ CTBG Tried Unsucessfully to Latch on to Tubing Hanger on Coil. Call for 3" Centralizer to install above GS Pulling Tool. Wait on Centralizer. Install Centralizer above GS Pulling tool. Install and Test Lubricator. Latch GS Pulling tool on to Coil Tubing in Well. Pressure test Lubricator. Held pressure Test. 1.00 RUNPU COIL CTBG Pull Test Connections to 25,000 # pull (11,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. PUH w/ Coil Tubing. Close BOPE 2-3/8" Pipe Rams and Slips. Bleed off Pressure. Remove Lubricator. 1.00 RUNPU COIL CTBG Remove Tubing Hanger Connection from Coil Tubing. Install Demple on Coil Tubing Collar Connection to connect 2-3/8" Coil Tubing velocity String in Well to 2-3/8" Coil on Coil Tubing Unit. Set Lubricator down on ROPE Stack. 2.50 RUNPU COIL CTBG Pull Test Connections to 25,000 # pull (11,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. POOH w/ 5285' KB 2-3/8" Coil Tubing. Close Swab Valve. Bleed off Pressure from Lubricator. Printed: 11/20/2007 12:15:19 PM L • Marathon Oil Company Page 2 of 3 Operations Summary .Report Legal Well Name: KENAI UNIT 14-32 Common Well Name: KENAI UNIT 14-32 Spud Date: 1/15/1982 Event Name: WORKOVER Start: 7/15/2007 End: Contractor Name: BJ SERVICES Rig Release: Group: Rig Name: BJ SERVICES Rig Number: CT2 Date From - To Hours Code ~ Svb I phase I Description of Operations Code 7/17/2007 15:00 - 17:30 2.50 RUNPU COIL CTBG Remove Lubricator. Remove BHA from Coil Tubing. 17:30 - 18:30 1.00 RUNPU COIL CTBG Shut in All Valve on Flowing Christmas Tree. Stand Back Lubricator and Set Down Coil Tubing Injector. 18:30 - 19:30 1.00 NUND BOPE CTBG RD Coil out of Injector and on to Coil Tubing Reel. Remove BOPE Stack from Wellhead. Install Blind Flange on top of 4" Valve on Wellhead. 19:30 - 20:00 0.50 SECUR WELL CTBG Secured well for night. SDFN. Signed out for the night. 7/18/2007 12:00 - 12:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre job safety meeting. 12:30 - 15:00 2.50 RURD_ COIL CTBG RD BOPE Slack. RDMO Coii Tubing and Crane. 15:00 - 15:30 0.50 SECUR WELL CTBG Secured well. Leave Well Shut in. 9/11/2007 07:00 - 07:30 0.50 SAFETY M7G_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 07:30 - 10:00 2.50 RURD_ COIL CTBG RD BOPE Stack. RDMO Coil Tubing and Crane. 10:00 - 10:30 0.50 SECUR WELL CTBG Secured well. Leave Well Shut in. Road CTU to KU 14-32. 10:30 - 14:30 4.00 RURD_ COIL CTBG MIRU Coiled tubing unit. Leave message w/Jim Regg at AOGCC for intent to pressure test BOPE stack. 14:30 - 16:00 1.50 NUND WLHD CTBG Vetco on location to install crown valve, flow tee. 16:00 - 19:00 3.00 NUND BOPE CTBG NU BOPE stack, convert pipe/slip rams over to 1.75". 19:00 - 19:30 0.50 SECUR WELL CTBG Secure well and location for night. 9/12/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 07:30 - 09:00 1.50 WAITON REGS CTBG Perform walkthru of hardline, valves, and procedure for testing BOPE's. Place another call to AOGCC. 09:00 - 10:00 1.00 TEST_ BOPE CTBG PT all hardline and shell test stack, still waiting on call from AOGCC. 10:00 - 11:15 1.25 REPAIR EOIP CTBG BOPE test witness waived by Chuck Sehve. PT against blind shears, won't hold. Try misc. options, still won't hold. Open doors, inspect upper seals, look worn, change out with used ones while waiting on new ones from shop. 11:15 - 12:30 1.25 REPAIR EOIP CTBG Blinds still not holding, Install new seals from BJ shop. Test again, still Ieak.,Further investiga ion r@yeals lower blade seal. ig worn out. New seals being shipped from N.Slope. 12:30 - 13:15 0.75 PULD_ BHA_ CTBG Make up dimple connector to coil, pull test to 10k. 13:15 - 13:45 0.50 SECUR WELL CTBG Secure well and location for night. 9/13/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 07:30 - 09:00 1.50 WAITON OTHR CTBG Wait on freight service to open to pick up BOPE parts 09:00 - 10:10 1.17 REPAIR EOIP CTBG Replace blind shear seals. 10:10 - 11:20 1.17 TEST_ BOPE CTBG Beain 7 1/16" BOPE test. 250/2500# on blinds. giaes. all halves. 11:20 - 12:05 0.75 NUND ROPE CTBG N/U 7" riser, P/U injector.M/U straight bar and no-go to grapple, install test plate and fill coil. 12:05 - 12:35 0.50 TEST_ EQIP CTBG Pressure test BHA to 2500 psi. 12:35 - 14:00 1.42 BLOWD COIL CTBG Go to well, blowdown coil ! 15 bbls. returned. 14:00 - 14:20 0.33 PULD_ BHA_ CTBG M/U 3.5" o.d. centralizer with friction fit and shear out plugs to BHA. 14:20 - 16:00 1.67 RURD_ COIL CTBG Go to well w/injector, open well, RIH to 5,285' and park coil. / W H P=120# --~- 16:00 - 16:20 0.33 SAFETY MTG_ CTBG Hotd PJSM and review JSA for m/u hanger, cutting coil, etc. 16:20 - 17:00 0.67 RUNPU COIL CTBG PUH 19', up wght=10k, hanging wght=5k. Close and lock in pipe slip combi's. 17:00 - 17:30 0.50 NUND WLHD CTBG N/D riser, pick up injector slipping chains.Vetco do space out, cut weep hole in coil. No psi, cut coil @ Vetco mark. Go to ground w/ injector. 17:30 - 18:30 1.00 PULD_ EOIP CTBG M/U Vetco grapple and hanger, BJCT dimple connector, GS spear. 18:30 - 19:00 0.50 NUND WLHD CTBG Go to well w/ injector, latch hanger w/ GS spear, pull 300# w/ crane to Printed: 11/20/2007 12:15:19 PM • Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 14-32 Common Well Name: KENAI UNIT 14-32 Event Name: WORKOVER ,Contractor Name: BJ SERVICES Rig Name: BJ SERVICES Date From - To ~ Hours Code ~ Sub i phase Code ___ 19/13/2007 18:30 - 19:00 0.50 NUND WLHD CTBG 19:00 - 19:30 0.50 SETREL LNR CTBG 19:30 - 19:45 ~ 0.25 ~ PUMP_~ WTR_ ~ CTBG 19:45 - 20:00 0.25 BLOWD~ICOIL CTBG 20:00 - 22:30 2.50 PUMP_I N2_ CTBG 22:30 - 23:15 0.75 RURD_ COIL CTBG 23:15 - 23:45 0.50 SECUR WELL CTBG Page 3 of 3 ~ Spud Date: 1/15/1982 Start: 7/15/2007 End: Rig Release: Group: Rig Number: CT2 Description of Operations insure GS latched properly. Walk injector down and NU riser. Open pipe slip combis, RIH and land hanger. screw in lock downs, pull 7.5k#, hanger locked in. Pump KCL water down coil, psi up to 900#, PUH and release from hanger. Online w/ N2 down coil, displacing kcl to flow back tank. Coil displaced of KCL, open swab and start pumpimg N2 to shear out plugs @ 600 scfm @ 200 pump psi / 140 whp. Having trouble keeping temperature on N2 unit.Finally ~h~ar ~ ~~~ o aF^ ; si. Close swab, bleed N2 from coil. N2 psi bled off, rig back injector, secure well, location for night. Well and location secured for night, leave location Printed: 11/20/2007 12:15:19 PM . ~ í1' fA\ í1' rE r¡}ì 16 Iß n ®(~ ,Q) U IA1 U lb ulu Lr~ lL Lru QÜ . / / / I I AI',ASIiA. ORAND G4S.- I CONSERVATION COMMISSION / l SARAH PALIN, GOVERNOR Kevin Skiba Production Technician Marathon Oil Company PO B?x 1949 4,";~"'t.:\NNED AUG 2 02007 KenaI, AK 99611-1949 1irP~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field, Sterling Pool 6, Kenai Unit 14-32 ,! Sundry Number: 307-265 ."\ . _.. ............ ~_OIS" \C6 cr 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 a Commission decision to Superior Court unless rehe has been requested. DATED this If day of August, 2007 Encl. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Alaska Department of Law . . Alaska Asset Team Northern Business Unit Re: Marathon Oil Company T ~~<¡:. €.~u~~ -\~ 'ðcc..~\~If\..\--, ... ......~.:- ~,.) \) "", \-\-(.: cl "I ~"'\ '> '. E.. \t<i..''- ¢ . ~ ëê!iVE .ç:\~ ~\- k.4~.\\-..o" ~'> <l)~\\<J ,L\UG 1 ,î 2007 \I-.J '1-~ ~C0\\(t\l~~ c~ *~ ... ..... .. .' '.~ -v-' &G:¡s co¡¡~, Comm¡SSWn (§;) ""\.f'o\-\":Þ ~ ~ "" ~ \ <.t \\-c '" cÂ .,." I;} b -0'1 . Anchorage r~U>W\f;\t~o..ppr-c~l o.ç.~~ :;:;~J Kenai Gas Field, Sterling Pool 6, Kenai Unit 14-32 Ã2.~ Sundry Number: 307-214 <6/ \~-C)'\. P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283·1311 Fax 907/283-1350 August 13, 2007 John K. Norman Chairman AOGCC 333 West ¡th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Norman: 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 KU #14-32. 1. Form 10-404 is missing for Sundry Approval 301-256 (August 30. 2001) and Sundry Approval 303-331 (November 13. 2003). The Forms 10-404 for Sundry Approvals 301-256 and 303-331 are attached for your review and records. Additionally, you have requested an explanation of the reasons for failing to provide the required information. The activities for which missing Form 1 0-404's were discovered occurred nearly 4 or more years ago, and due to personnel turnover, we regrettably cannot explain this oversight. However, we have undertaken several new steps to ensure compliance point-forward, including: better tracking tools, defined roles and responsibilities, a commitment to educate and review regulations. We will continue to review our records and correct any past deficiencies promptly upon discovery. 2. Form 403 should not be used to transmit well work reporting. Your attachment should be resubmitted using Form 404. It is understood that Form 404 is required for well work reporting. The operational summary that was attached to Sundry Number 307-214 was information that should not have been submitted to the AOGCC. Further, it is our understanding of the Alaska statutes that the disclosed operational activity did not require a Form 10-403 and therefore no form 10-404 is required. The operational summary should simply be disregarded as supplemental information that was unnecessary. Please excuse any confusion that may have resulted from submitting more information than was required. Additionally, upon receipt of your July 26 letter, we discovered and voluntarily disclosed that work activities had commenced on this well prior to receiving sundry approval from the AOGCC. I called Tom Maunder and disclosed this immediately upon discovery on July 31,2007. No work has been performed on this well since that date. With this letter, we have addressed the AOGCC's original concerns and we request approval of Sundry Number 307-214 so that work may proceed. It is understood that Marathon owes the AOGCC additional dialog relative to actions taken to ensure full compliance in the future. I have discussed many of these actions with Tom Maunder, and anticipate scheduling a meeting with Tom for additional discussion. . . Marathon respectfully requests that the AOGCC accept the re-submitted Sundry Number 307-214. 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. Enclosures: 10-404 Sundries Operational Summaries Well Schematic cc: Houston Well File Kenai Well File KDW . IiJ"T5 ó{{ ,t/l:, Rt::.G I::. I v t:.U . ~ ?-ft ø1 ST TE ALASKA - ~' ALA, OIL AND GAS CONSERVAvWlÎdo~ ION %:I;"" · ..(1.111 APPLICATION FOR S~U~QßìtMf?cisQ:~&n ;;)\) 20 AAC25.280 ". 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown U Pèrfórate 0 .;:t~ W'(vè~C:r!'" '."¡Pi';';Öii1~!r 0 Alter casing 0 Repair weil 0 Plug Perforations 0 Stimulate 0 A"'''''·' '..,'. t". ~. '",,'" . ',,' :', ~ Ti ExtenslonU "V-String ~ Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil COmpany Development 0 Exploratory 0 182-015 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20351-00-00 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: Spacing Exception Required? Yes 0 No 0 Kenai Unit 14-32 If", , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~r\\ v...,,:> Ç"'oo \ <.. ~-; 740' N & 1759' W of SE Corner of Sec. 31, T5N R11 W, S.M. 87' Kenai Gas Fiela, Pad 34-31 (S' 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): 5700' 4897' 5571' 4799' 5410' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 106' 20" 106' 106' 2110 psi 520 psi Surface 2020' 13-3/8' 2020' 1856' 3090 psi 1540 psi Intermediate Production 5580' 9-5/8" 5580' 4807' 6870 psi 4750 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5287'-5550' 4593'-4785' 7" L-80 4850' Packers and SSSV Type: SLP Isolation Packer and SLP Isolation Packer Packers and SSSV MD (ft): 4563' and 4850' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 29-Jul-07 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Com mission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Mickey Mullin Title Senior Production Engineer Signature _ J .., ..; ....... ~ Phone (907) 283-1337 Date 18-Jun-07 -,~/......,/ .~~ I . / COMMISSION USE ONLY -- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ ./' ... Plug Integrity 0 BOP Test jZl Mechanical Integrity Test 0 Location Clearance 0 307-~ Other: ~$C)a ~S\ \šDV -\-.~~+ 0.. s. ~ \ú 'C'... t--...2d Llor ¡jfl RBDMS 8Ft AUG 1 7 2DD7 Subsequent Form Required: APPROVED BY Date:ø:16,.Q Approved by: ~~ / ~ ,~NER THE GOMMIS$IPN ~rnll ~þ--- =, . r ()R"~'~'A' Submit in Duplicate Form 1 0-403 Revised 06/2006. . "J"'T 1_ t. J.Jí' t- . c ~) lV!arathon .. ___ 011 CompanV Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283·1326 Fax 907/283·1350 AJa$h Oil & G ~~ CfJM. ClImmi..ìo" AnCftöfigf! . RECEIVED AUG 1 4 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 1 June 18, 2007 A¡,dhHClg8 Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 34-31 Well: Kenai Unit 14-32 Dear Mr. Maunder: We propose to remove a 2 3/8" velocity string and install a 1.75" velocity string in KU #14-32. 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) 283-1337. Sincerely, ~/r'd~ 1t?/:JuNjo., MiCKe'Ç~~li,( '" Senior Production Engineer Enclosures: 1 0-403 Sundry Notice Operations Procedure W ell Schematic Proposed Well Schematic ~¡..~ti:i9 i'I5¥UJlary-.. cc: AOGCC Houston Well File Kenai Well File DMD KJS . . IM\ ~ MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 14-32 2007 Velocity String Removal and Hangoff Procedure (06-15-2007) WBS # WO.07.15639.EXP ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: · This procedure covers work to remove a 2-3/8" coil tubing string and replace it with a 1.75" OD coil tubing velocity strings to alleviate liquid. · Contact Vetco prior to MIRU to verify maximum hanger head ID & mandrel 00 measurements. BJ Coil Tech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. · G and G Machine will build a 1-3/4" BHA with 10' if weight bar, XN Profile and Centralizer 1. Set Profile Plugs into 2..3/8" Coil. MIRU Pollard Wireline. Hold PJSM. RIH and set 2 Plugs into CT BHA. Bleed down CT string the verify that the plugs are holding (Talk with Pollard about what style plugs need to be used, must have double block barrier) 2. Concentric Coil Tubing Head. Is installed 3. Flowline modifications for concentric coil tubing string. Is installed 4. MIRU MOC flow back equipment including open-top fowback 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. Removal of 2-3/8" CT 5. MIRU BJ coiled tubing unit with 2-3/8" coiled tubing stinger string. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple up BJ CT wellhead assemblv (WHA). WHA to include 4-1/8" - 5M X 4-1/16" - 10M DSA, 4- 1/16" -10M X 5' Flanged Riser, 4-1/16" -10M flow cross and 4-1/16" -10M Dual-Combi BOP (dressed for 2-3/8" CT). Function test BOP. Stab 2-3/8" CT into injector. Nipple up injector to WH/¿.. . . 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. MU Vetco 1.75" Coil Tubing Hanger and Baker GS Pulling Tool. Swing Injector and lubricator away from WHo Dimple-on a 2-3/8" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. PU 10' of 4-1/16" CO lubricator (or sufficient amount of lubricator to swallow BHA). . . Page 2 of3 9. Pick Up Tubing Hanger. Latch GS Pulling tool into Coil Tubing Hanger. Verify Latch. Vetco to unscrew hanger holding pins. PUH with tubing hanger. 10. Pull BHA into Lubricator. Close tubing rams/slips and bleed WH Pressure through coil flow cross. Release pressure on chains and roll chains to verify that they are not contacting the tubing (watch weight indicator and visual on ground). Break 6" Bowen connection and slowly with the help of the crane operator Boom Up Injector Head approximately 4 feet. This work window is necessary for connection of the 2-3/8" Roll-on connector. Saw Cut with a hack saw to remove the current tubing hanger that is in place. 11. MU 2-3/8" Roll-on on CT Connector. Connect 2-3/8" Stinger String to 2-3/8" Velocity String and Pull test to 25,000 Ibs using a pull plate. Slowly walk down lubricator back onto wellhead and make up Bowen nut. Pressure test lubricator (200/4500 psi). Bring chain pressure back up and equalize pressure across flow cross to release rams. 12. POOH with 2-3/8" CT. Spool used Coil String onto empty reel. Approximately 5285' of coil is in the well. Tag Brass on stripper and watch weight indicator for this. Close the swab valve and bleed down lubricator. 13. Unstab Lubricator and Boom Iniector toward the ground. Remove each piece of lubricator and remove the 2-3/8" BHA 14. Rig down 2-3/8" Coil Unit and RU 1-3/4" Coil Unit onsite 15. Vetco to replace 2-3/8" Coil Tubing Hanger Grapples with new 1-3/4" CT Hanger Grapples Installation of 1.75" CT 16. MIRU BJ coiled tubing unit with 1-3/4" coiled tubing that is approximately 13,540' (this is a used BJ Coil Tech work string). Rig up fluid and N2 pumps. RU pumping iron and flow back iron 17. Nipple UP BJ CT wellhead assemblv (WHA). WHA to include 4-1/8" - 5M X 4-1/16" - 10M DSA, 4- 1/16" - 1 OM X 5' Flanged Riser, 4-1/16" - 1 OM flow cross and 4-1/16" - 1 OM Dual-Com bi BOP (dressed for 1.75" CT). Function test BOP. Stab 1.75" CT into injector. 18. MU CT 1.75" CT BHA w/1 pinned shear plug and 1 forcefit pumpoff plug. PU 10' of 4-1/16" CO lubricator. MU velocity string BHA to end of CT. Nipple up injector to WHA. 19. 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. Open Swab Valve to Well 20. RIH with 1.75" coil tubing velocity string and BHA with well flowing to sales up Casing by 1-3/4" annulus (if desired). 21. Cut coil tubing. PUH to span WHA for final landing depth of +/- 5285' 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 with Boom. Install C plate above BOP and 1.75" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 22. MU Vet co Coil Tubing Hanger and Baker GS Running Too/. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger to hanging coil tubing with coil grapple. While Vetco is GO#3 CT Velocity String Hangoff Procedure DMD per KDW - 6/21/2007 7:58:03 AM . . Page 3 of3 making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 1-3/4" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. 23. Latch GS spear to Vet co mandrel after PU injector. Remove 1-3/4" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 24. RIH and land Vetco CT hanQer per Vet co 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. 25. Release GS RunninQ 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. 26. Pump N2 down 1-3/4"Velocity String until both plugs shear and fall to bottom of well. Vent the N2 to a Flowback tank and monitor the LEL. When methane is detected send well to production facility. 27. PurQe KCL water from CT remaininQ on reel trailer with nitroQen. Allow N2 to vent to flowback tank. 28. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. CONTACTS Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) David Martens: 713-296-3302 (w) 832-4 72-6249( cell) Lyndon Ibele: 907 -565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 EmerQency Dial 911 80#3 CT Velocity String Hangoff Procedure OMO per KOW - 6/21/2007 7:58:03 AM Tree c)(n: 31/2" 8rd hanger prepped wI : -6' of 7", 23 ppf, L -80 pup jt wI re-entry guide -6" type "H" SPV profile min ID =5.469" -7" BTC lift threads B-3 4596'-4658' ( 8+spf, 3/10/82) B-4 4775'-4790' (sqzd 3/8/83) B-4 4798'-4818' (sqzd 3/8/82) 2 3/8" Velocity w/ nipple for plug or standing valve to 5285' (mín 10=1.027") ,94# @ 106' @ 2020' & Lower isolation packers minimum 10=6.052" 7", 23 ppf, L-80 BTC casing SLP upper isolation pkr @ 4563' SLP lower isolation pkr @ 4850' ) Open Perfs below pluq: C-2 5442'-5460' (12spf, 12/8/00) C-2 5530'-5550' (12spf, 12/8/00) Cement retainer @ 5580' 95/8", 47ppf, casing @ 5580' P8TO @ 5580'MO/480TTVO Well Name & Number: or Parish: Perforations KU 14-32 BHP: Lease: GF, Pad 34-31 State/Provo (TVD) Fluid: Tree cxn: 31/2" Srd Tubing hanger prepped wi . -6' of 7", 23 ppf, L-80 pup jt w/ re-entry guide -6" type "H" BPV profile min 10 =5.469" -7" BTC lift threads 8-3 4596'-4658' ( 8+spf, 3/1 8-4 (sqzd 3/8/83) 8-4 4798'-4818' (sqzd 3/8/82) 95/8", 47ppf, casing @ 5580' PBTO @ 5580'MO/4801'TVO Well Name & Number: County or Parish: Perforations (MD) KU 14-32 Lease: GF, Pad 34-31 State/Provo Completion Fluid: 20",94# @ 106' 13 3/8", 61 #, Casing @ 2020' Cmt wi 1000 sx of Class G Upper & Lower isolation packers minimum 10=6.052" 7", 23 ppf, L-80 8TC casing SLP upper isolation pkr @ 4563' SLP lower isolation pkr @ 4850' C-1 5281'-5346' (12spf, 12/8/00) ) Open Perfs below pluq: C-2 5442'-5460' (12spf, 12/8/00) C-2 5530'-5550' (12spf, 12/8/00) Cement retainer @ 5580' r STATE OF ALASF4A • Al.ASKA 01L AND GAS CONSERVATlON COMMlSSfON ~~~j ~' VE Q REPORT OF SUNDRY WELL OPERATI4NS AUG 14 20~7 1. Operations Ab~nslan Repair YVeil Plug PerforaGOns Stimuiate Cnh~r ~ on '~ ~' ~~a: ~ c~~ ^ ~,~~ T~~~ ^~e~~e r~ ~~ ^ w~~~ Q Ai~A~~, Q4ns ~~ h ChanQe Approved Pro9tam Q Operat. Shutdawm ^ Perforate [~ Re-enter Suspended Wel~ ~ O~ 2. Opere4or Ki[~tOA ~il C0171(~1y N 4. Well Class Before Work: 5. Psrrrtif to Drill Number ame: Oeveiopment Q ExpbtatoryQ 182-015 3. Addreas: StraGgraphic ^ Service^ 6. API Number: - PC IiQX 1 AK ~61 t 50-133-20351-00-00 7. KB E1e~+ation (ft). 9. Weli Name and Numberi 8T Kenai Unit 1432 s. Pr~perty o~esigt-a~or-: FEDA Q28055 ~ o. ~ie~draoo~{s): T4Q' N& 1T59' W of SE Comer af Sec. 31, T5N R11W. S.M. K~nai Gas Field Ste~lin Poo16 i1. pt~ent Weli CondiOo~ Summary: Totaf Depth measausd 5700' feet Pl~s (measur~) 5410' (inflata4le) $ 5580' (cmt retsinsr} true vsrtic~ 489T feet Junk (measured) N/A E?tective DaP~+ measured 5571' fest true ~ticat 4799` feet Casing Length Size MD TVD Burst Coliapse StrucOual 0 0 0 0 0 0 Conductor 106' 20" 106' 106' 2110 psi 520 psi SurFace 2020' 13-3J8" 202Q' 1856' .. _ . 349Q psi- 1540 p~i Intem~ediate p p p p 0 p Produ~an 5693' 9-5/8" 5695' 4894' 6870 psi 4750 Ps+ Liner 0' 0 0 0 0 0 Perforation deplh: Measured d~tth; 5287'-5550' ~~'~`i~~~ :~~~ ~ ~ ~~ ~av~ Tnte Vuticxl depth: 4593'-47$5' Tubit~g: (sine, grads, ~r~ measured d~) 7" Stta~le 2Sppf, L-80 4563'-4850' 2-3/8" Cai Tubing V-String 0'-5285' PaCkers and SSSV (type and measured depth) SLP isol~ion Padc~' ~ 4563' and SLP Isoladon Pack~ 4850. 12. Slimulation ar r.~r-~t squesae aummary: ~ .~OC-~~~~, a~C~~vv~ -~~~ ~~,: wA a~ ~~ ,~,~ '1 C~k~-\y v~c~.s ~~ ~ccPSSO~ T xi ti s i - l tr M d ~ di d m u d fi l / p ree ns c on r ng v e c u es se na pressure: N u and A ~ ~y ~~ 13. R~resentative Oaity Average Produc6wn or Injection Data ~!-Bbl Gas-Mcf W~er'-Bbi Casing Prsssure Tubing P~essure Prior ~ weq operation: 0 N!A WA Q N/A Subsequent to op~ation: 0 N/A N/A 6 WA 14. Atk~Ghmetrts: 15. W eil Class aft~r w~k: Copies af Logs and Surveys 12un No W eil Operations ExploratorY ^ Developm~t Q Service (~ t3aily RepoR ssf Well Operations No WeQ Operatlana 16. Well Staws a~R~ wrxk: Oil ^ Gaa Q WAG ^ GINJ Q WINJ ^ WDSPL Q 1 T.1 hereby oer4fy tl~at t!~ foregoi~ is true and oorrect 6o tl~e best of my knowledge. Sundry Number or N/A if C.O. ExempC 303-531 _ - , co~raa Kavin slciba RriMed Name Oe~u-is M Doravan Title Produc~ion Engineer i (901}283-1333 W Signabure Phone (907}398-13Ei2 C Date &Aug-07 --,..r -._.. Fortn 10-404 Rewised t?~N2006 Submit Original Only R9~IS BFL au~ Z 4 2oos .~ ~~~~ • STATE OF AIASKA • ALASKA OIL AND GAS CONSERVATION CQMMISSIQN REPQR7 ~F SUNDRY WELL OPERATICENS RECEIVE~ AU~ 14 2oa~ e~~.49 n~i ~ Gas Cons. CO~MIBSSIOfl '1, ~aations ' Abandon Repair Well Plug Pe~forations Stimulate Other ~ V~~p(8 4 P~: Aftar Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver(~ Time Extension ^ Hung ~~" Ch~9g apP~~~ ~9r~n ^ OperaL Shutdown ~ Pertorate ^ Re-enter SuSpended Well ^ ~/ili ~It 2. ~ator Marathe~t Oil ~ml~anY N 4. Well Class Before Work: 5. Pertnit to Dri-i Number: ar-~: DeveaoPm~t Q Exp~orataY^ 182-015 3. A~: Stratigraphic ^ Service^ 8. APi Numb~: .~•~.~•-.•.- ro ewwc t~ ~c Nc ~s~ ~ so=133-20351-00-00 7. KB ElevaUon (R): 9. We11 N~me and Numtaer. 8?' Kenai Unit 1432 8. P~nperty Dsiignation: FEC1A 028055 ~ o. F~etdlPoo~(sa: l~i{?' N~'!~ s9' W of SE Corner of Sec. 31 T5N R11 W. S.AA. Kenai Gas Fiefd Ster~i Paol 6 11. Present W Condition Summaty: Ttrtal Oeplh measured 57~' feet Plugs (meaaured} 5410' (inflatable) & 5580' (ant ret~iner) true vertiql 489~' feet Junk (me~ured) WA Elfective Depth measur~ 5571' t~at true vatical 4799' feet c.as+ns ~er~n s~ze nno rw su~ ca~aa~ sm,~a,~~ o 0 0 0 0 0 ' Condudor 106' 2Q" 106' 106' 2110 psi 52Q psi Sutface 202Q' 13-3/8" 2020' 1856' 309~D psi 1540 psi ~ntermediate 0 p p p p p ~+~ 5$95' S-5f8" 5695' 4$94' 6870 psi 4750 psi Linar p p p p p p Perfo~atiar~ ci~-tA: Mea~xed de~h; 528T-5550' 7n~a Vertic~i de~rih: 4593'-4785' Tubi~g: (sizs, 9rads. and measuroc! depfh} 7" Straddle 23ppf. L-80 4568'-4$50' 2-3/8' Coil Tubing V-SMng 0'-5285' Packera ana sssv (type and me~,-etl ae~h) SLP IsWation Packer ~ 4583' and Si.P Isofation Padcer 4850' t2. Sdmu~ation a cornent wmmary: Itf2ervals treatsd {measured); WA Treatrr~nt desaiptions indt~aig volumes used ar~ finai preasure: W/A 13. R~ve Qaily Ave~age Production ar Injedion Oata OiGBbI Gas-Md Water-Bb1 Casing Pr~sure Tubing Pressure ~ar to ,~u o~arwr,: , o 0 0 o a Subsequerr# ~o op~ation: 0 Appropmate 1000 Approx <1 bbl 0 Appro~timate 150 psi 14. ' fr~: 15. Well Class s~ work: Copie~ of logs arx! Sunreys Itu~ No logs/Surveys Run ExP~waeorY ^ Dev~pm~nt Q Service ^ ~aiy ~ ot wau • ~ncu,aed ~ s. weu sc~a,s af~er won~: pil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ " 1T.1 kr~ra!-y qrtify 1Mat th8 foregoing is gue and com~ct ~ the bsst ot my knawl~e. Sundry Numb~ or N/A if C.O. fx~npt 30i-23li Contact IG~~+ir~ fkiba Printed Name Dennis M Donavan Title Pradur~ion Engineer l (9Q7}283-1333 W Signattue ~ Phone (~7}38&1382 C Qate 8-Aug-07 -•.. ~ Form 10-404 Revis~d 04l2Q06 ~~5+ ~~ AUG I 4 2009 SubmitOriginatOnly 'z~~~i7 • • teAARATHON 01L COMPANY DAiLY WEl.L OPERATIONS REP4R7 PAGE 1 OF 1 C~iTE: ~'l,~,_ FIELD: Kenai Gsg fi~d WELI #: KU~ 14-32 FLLL C-f:gTkUDATEt TUBING: GASING: _ ~tTE LA~T WL 1Nt3RMC: TREE CONDITfON: WORK L1QN~: ~'_; Pult Wu9 SENCHES OPEN: PR~$ENT C)P~ERATK~'+1: Compl~e WIRELINE CREV11: DilieY/6elden _~ t?THE~L: Hcs. g SUMl~IARI( C?F ORFhRATi~~ 15:30 Arriv+e on bcation~ spt equ#~nn~t, make up tod string. calt Shop for Tr~ Conn~ction 1~':00 R1N wt 1 1/4" Toot Strinp au~d 1 1/4' JUC to Plug f~ 5263' WL, latch Piug. POOH 19:t14 Re~rt tCd. RIH val 3~ne ~0 5283' WL, ~ot bites. POQH, aftet 1 h~ got Valve ZO:~'! R~ 21:A4 SeCU~'w!stl, fi~ squipment endor sM st umula#ive t PoNand Winiule It~c. 1 1!4" Jl1C Pbl#~d W'x~tir~e tnc. Unlt rwl ~ man crew DAlLY C.(~T: CUM: ..~.. RE~RTED `6Y: Biil Wolf MAKAih'KJNUtLtitJM!'~f+11VY ~ WNLt ~rcLa.vrr.~v-~~v.w...~•.•••~ ..._- . _ DATE: 9120/200t FIEID: Kst-ai Gas Field W ELL #: Kt1~ '~IC.L DEPTHJDATE: TU61NG: 2 3f8" CT CAS1NGc 9''a/$" w! 7' iinsr ~~ ~T yyp~; ~ $/~pq1 TREE CONL?ITION: _, New 1Nt"iitft D~: Han9 Vebt~tv Strir~ Nz U naw trse BENGHES C)PEN: ._. .~.-.~~ __ _ C-1 ~ . ~..._ . E~SEM' {#~ERA'T10N: Cotr~{ete ,. ; CT CR~W: s~M~•~r o~ a~~nc~ [}ow~1l-Key/Howell ~~s Ru os w a~s- cT ~b Pips, weid on CT cannedor Wa+t cm BOP: ~11! Mlait on BOPs from stope 9 ZQO Re-drass B~'3Ps and NU l11~ O~Q , t~ BQF''s 1 pt,~ RIH 111$ Qn bot~am. Taq irtflat8bi~ plug ~ corr+ela~ d~pth 1934 Cam~t ~pth. PU 12' (L~tl~ from h~ ~o abow BOPaj S~# ~i~s, Waik up inj~cficrr head. Cut ccilsd tubing. ~t~'~ ~/r C.Qf1~16C.t0~ ~3~ PuN fiest t~annsctor, iat~t C3S, uw~lk injactar dawn. Clpen slips RiH 12' t~ ~tt hsr~ R! locicscrsws. P-ts~t void to 50~psi ~qpq Rig daMm Inj. t~ad and BOPs 188D i~U 21/18' SM ~(2 gat~s~ Tae w! win9 vahre) P Test tc~e fia 34t)O psi. 1700 Continue to RD Dcrwuell 1900 Cla~n up ~c~tion. SDF?d ~ E~-11.Y COST: CUM: REP4RTED BY: 7itus ~ ~ M Tree cxn: 3 1/2" 8rd ~ s ' ~ .~ MARATNOM ~" Tubing hanger prepped w/ : -6' of 7", 23 ppf, L-80 pup jt ~' ~ ' ,; ,4 20~~, 94# Drivepipe @ 106~ w/ re-entry guide ; i -6" type "H" BPV profile ~~-• ,:~ min ID =5.469" "'' -7" BTC lift threads `~ '~. X" ' '~ 13 3/8", 61#, K-55, BTC Casing @ 2020' " ~~ Cmt w/ 1000 sx of Class G ~: , : ,; h r f. ~~ ~~ ~ Z~ '~ 7" Scab Liner 4563'-4850' Isolated Perfs: ~ SLP Upper & Lower isolation packers B-3 4596'-4658' ( 8+spf, 3/10/82) ; ,~ minimum ID=6.052" B-4 4775'-4790' (sqzd 3/8/83) f 7", 23 ppf, L-80 BTC casing B-4 4798'-4818' (sqzd 3/8/82) ~ . SLP upper isolation pkr @ 4563' ,,_ r SLP lower isolation pkr @ 4850' ~~ ~: 4 ~;~ .} / ~.~ ^ Producinq Perfs 2 3/8" Velocity string C-1 5287'-5346' (12spf, 12/8/00) w/ nipple for plug or :~ Inflatable Plug @ 5410' standing valve to "` '~ Baker tubing retrievable 5285' ~ - bridge plug (2/28/01) (min ID=1.027") - Open Perfs below qluq: C-2 5442'-5460' (12spf, 12/8/00) ~ '` C-2 5530'-5550' (12spf, 12/8/00) ; ,~ Cement retainer @ 5580' 9 5/8", 47ppf, casing @ 5580' PBTD @ 5580'MD/4807'TVD Well Name & Number: KU 14-32 Lease: KGF, Pad 34-31 County or Parish: State/Prov. Country: Perforations (MD) (ND) Angle/PerFs Angle @ KOP and Depth BHP: 430 psi (stati BHT: Completion Fluid: Date Completed: I age j u.l Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 14, 20072:57 PM To: Lyndon Ibele Cc: 'Stephen F Davies'; 'Arthur C Saltmarsh'; Fleckenstein, Robert J (DOA) Subject: Processing Un-approved Sundries \~'-:V 'f"\./ Q ~i?) ~"" f.. ,/,' 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 (182-015) 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 . ~V~VŒ (ID~ ~~~~[{~ . AI,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR CERTIFIED MAIL RETURN RECEIPT REOUESTED 333 W. 7th AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mickey Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 Re: Kenai Gas Field, Sterling Pool 6, Kenai Unit 14-32 Sundry Number: 307-214 \ ~¥O t!7 5CANNED JUL 3 1 2007 Dear Mr. Mullin: 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 Commission ffies witb regard to this request bas determined that Marathon on Company has not ffied Forms 10-404 (Report of Sundry Wen Operations) as required by Sundry Approval 301-256 dated August 30, 2001 and Sundry Approval 303-331 dated November 13, 2003. Also, Form 403 (AppHcation for Sundry Approvals) should not be used to transmit wen work reporting. Your attacbment should be resubmitted using Form 404 (Report of Sundry Wen Operations). The deficient operations reports and an expJanation of the reason for falling to provide the required information must be submitted not Jater than 15 days after the receipt of this letter. Tbe Commission reserves the rigb.t 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 following the date of this letter, or the next working day if the 23rd day falls on a holiday or end. A person may not appeal a Commission decision to Superior Court u he as been requested. S' cere , DATED this ~day of July, 2007 Encl. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Department of Law ......,_...~-_.__._..........--,~~--------~.__..~--.--_._--- .-_._----~-,,----.~-_.,'_..._----_.-. . -0 _____.. . ___._.__._.~.._.. .._. UNITED STATES POSTAL SERVICE .... ¡ "" First-Class Mall Postage & Fees Paid USPS PermIt No. G-10 · Sender: Please print your name, address, and ZIP+4 Irt'hls box · (11 ~ Q) g L. c: r ;t 20 State of Alaska . . g ~ Alaska Oil and Gas Conservation COoumSSIOtg. (I> . 100 CI (""") 333 West 7th Ave.. SUite ~ g Anchorage, Alaska 99501 tg Y' () o 3 3 ~. v> ëï <:,.,) ....... .--..) <:::) (::::I --.J ~ ~ (4 .lB~IIIII.JII"IIIIJI"II"IIIII"II1II1IIII1IIII"IIII," 30'1- ~\I-f .::r- n.J .::r- IT' T Lt' f'- Lt' U.S. Postal Service,r¡ CERTIFIED MAIL·, RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) ,....:¡ a a a Retum Receipt Fee (Endorsement Required) a Restricted Delivery Fee ..J] (Endorsement Required) ,....:¡ ,....:¡ Total Postage & Fees $ K'8 F9fR11 C I A L $0.75 $2.65 USE Postage $ Certllled Fee $2.15 $0.00 $5.55 Lt' a a f'- PS Form 3800. June 2002 See Reverse for InstnJctlons - .-----~-._------_. ---.---..- · CO,mplete 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 m~ilpiece or on the front if space permits. ' 1. Article Addressed to: ~~ ~ ÕJ. eøn~'(} f.O. &x ,Q4Q tí~ , N<-. qq IÞII ·IO¡~1 3. ~Ice Type !5( Certified Mall D Express Mall D RegIstered Iir Return Receipt for Merchandise D Insured Mall . D C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. ArtIcle Number (rransfer from service lab! PS Form 3811, February 2004 7005 1160 0001 5753 9424 DomestIc Return Receipt ,- 102595-02-M-1540¡ . . Marathon Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 RECEIVED June 18, 2007 JUN 2 5 Z007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 ¡\¡a:¡ka Oil & Gas Cons. Commission Anchorage Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 34-31 Well: Kenai Unit 14-32 Dear Mr. Maunder: We propose to remove a 2 3/8" velocity string and install a 1.75" velocity string in KU #14-32. 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) 283-1337. Sincerely, ~kL/~ r/c ~ ~~Ii.('" / / <f/.::r uN 0" Senior Production Engineer Enclosures: 1 0-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic Operation Summary cc: AOGCC Houston Well File Kenai Well File DMD KJS ~ A STATE OF ALASKA ~";;¡?-P~ ALAYA OIL AND GAS CONSERVATION COM~SION APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Commission 20 MC 25.280 Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D Abandon D Alter casing D Change approved program D 2. Operator Name: Marathon Oil Com an 1. Type of Request: Suspend D Repair well D Pull Tubing D Perforate D Stimulate D Time Extension Re-enter Suspended Well 5. Permit to D Exploratory D Service D 3. Address: Kt:\.Jt:1 V t:.U .JUN 2 5 2007 Other 0 V-String PO Box 1949, Kenai Alaska, 99611 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 D No 0 9. Property Designation: -¡¡//1./)1 10. KB Elevation (ft): 11. Field/Pool(s): <') ~ :\.,... "Q:.O' ~ 740' N & 1759' W of SE Corner of Sec. 31, T5N ~1W, S.M. 87' - K nai as F~d, Pad 34-31 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 5700' . 4897' 5571' 4799' N/A Casing Structural Conductor Surface Intermediate Production Liner Length Size 106' 20" 2020' 13-3/8" 5580' 9-5/8" MD 106' 2020' 5580' Perforation Depth MD (ft): 5287'-5550' Packers and SSSV Type: Perforation Depth TVD (ft): 4593'-4785' SLP Isolation Packer and SLP Isolation Pac Tubing Size: L-80 13. Attachments: Description Summary of Proposal D Detailed Operations Program 0 BOP Sketch D 15. Estimated Date for Burst Collapse 2110 psi 3090 psi 520 psi 1540 psi 6870 psi 4750 psi Tubing MD (ft): 4850' 4563' and 4850' Commencing Operations: 17. Verbal Approval: Com mission Representative: 29-Jul-07 Development 0 Service D proposed work: Gas 0 Plugged D Abandoned D GINJ D WINJ D WDSPL D Date: Contact Kevin Skiba (907) 283-1371 Signature Date Senior Production Engineer 18-Jun-07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a repres Sundry Number: Plug Integrity D BOP Test D D Location Clearance D Other: 4- Subsequent Form Required: RBDMS BFl JUL 3 0 2007 Approved by: APPROVED BY THE COMMISSION COMMISSIONER Form 10-403 Revised 06/2006 0 RIG 1 N A L Date: su~ D~ff)b7 . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 14-32 2007 Velocity String Removal and Hangoff Procedure (06-15-2007) WBS # WO.07.15639.EXP ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: · This procedure covers work to remove a 2-3/8" coil tubing string and replace it with a 1.75" OD coil tubing velocity strings to alleviate liquid. · 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. · G and G Machine will build a 1-3/4" BHA with 10' if weight bar, XN Profile and Centralizer 1. Set Profile Pluas into 2-3/8" Coil. MIRU Pollard Wireline. Hold PJSM. RIH and set 2 Plugs into CT BHA. Bleed down CT string the verify that the plugs are holding (Talk with Pollard about what style plugs need to be used, must have double block barrier) 2. Concentric Coil Tubina Head. Is installed 3. Flowline modifications for concentric coil tubina strina. Is installed 4. MIRU MOC flow back eauipment 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. Removal of 2-3/8" CT 5. MIRU BJ coiled tubina unit with 2-3/8" coiled tubing stinger string. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHA). WHA to include 4-1/8" - 5M X 4-1/16" -10M DSA, 4- 1/16" - 10M X 5' Flanged Riser, 4-1/16" -10M flow cross and 4-1/16" - 10M Dual-Combi BOP (dressed for 2-3/8" CT). Function test BOP. Stab 2-3/8" CT into injector. Nipple up injector to WHA. 7. Pressure test surface lines and CT eauipment 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. MU Vetco 1.75" Coil Tubina Hanaer and Baker GS Pullina Tool. Swing Injector and lubricator away from WHo Dimple-on a 2-3/8" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. PU 10' of 4-1/16" CQ lubricator (or sufficient amount of lubricator to swallow BHA). . . Page 2 of3 9. Pick Up Tubing Hanger. Latch GS Pulling tool into Coil Tubing Hanger. Verify Latch. Vetco to unscrew hanger holding pins. PUH with tubing hanger. 10. Pull BHA into Lubricator. Close tubing rams/slips and bleed WH Pressure through coil flow cross. Release pressure on chains and roll chains to verify that they are not contacting the tubing (watch weight indicator and visual on ground). Break 6" Bowen connection and slowly with the help of the crane operator Boom Up Injector Head approximately 4 feet. This work window is necessary for connection of the 2-3/8" Roll-on connector. Saw Cut with a hack saw to remove the current tubing hanger that is in place. 11. MU 2-3/8" Roll-on on CT Connector. Connect 2-3/8" Stinger String to 2-3/8" Velocity String and Pull test to 25,000 Ibs using a pull plate. Slowly walk down lubricator back onto wellhead and make up Bowen nut. Pressure test lubricator (200/4500 psi). Bring chain pressure back up and equalize pressure across flow cross to release rams. 12. POOH with 2-3/8" CT. Spool used Coil String onto empty reel. Approximately 5285' of coil is in the well. Tag Brass on stripper and watch weight indicator for this. Close the swab valve and bleed down lubricator. 13. Unstab Lubricator and Boom Injector toward the ground. Remove each piece of lubricator and remove the 2-3/8" BHA 14. Ria down 2-3/8" Coil Unit and RU 1-3/4" Coil Unit onsite 15. Vetco to replace 2-3/8" Coil Tubing Hanger Grapples with new 1-3/4" CT Hanaer Grapples Installation of 1.75" CT 16. MIRU BJ coiled tubing unit with 1-3/4" coiled tubing that is approximately 13,540' (this is a used BJ Coil Tech work string). Rig up fluid and N2 pumps. RU pumping iron and flow back iron 17. Nipple UP BJ CT wellhead assemblv (WHA). WHA to include 4-1/8" - 5M X 4-1/16" - 10M DSA, 4- 1/16" - 10M X 5' Flanged Riser, 4-1/16" -10M flow cross and 4-1/16" - 10M Dual-Combi BOP (dressed for 1.75" CT). Function test BOP. Stab 1.75" CT into injector. 18. MU CT 1.75" CT BHA w/1 pinned shear plug and 1 forcefit pumpoff plug. PU 10' of 4-1/16" CO lubricator. MU velocity string BHA to end of CT. Nipple up injector to WHA. 19. Pressure test suñace lines and CT equipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, 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. Open Swab Valve to Well 20. RIH with 1.75" coil tubing velocitv string and BHA with well flowing to sales up Casing by 1-3/4" annulus (if desired). 21. Cut coil tubing. PUH to span WHA for final landing depth of +/- 5285' 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 with Boom. Install C plate above BOP and 1.75" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 22. MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger to hanging coil tubing with coil grapple. While Vetco is GO#3 CT Velocity String Hangoff Procedure DMD per KDW - 6/21/2007 7:58:03 AM . . Page 3 of3 making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 1-3/4" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. 23. Latch GS spear to Vetco mandrel after PU injector. Remove 1-3/4" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 24. RIH and land Vetco CT hanaer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 25. Release GS Runnina 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. 26. Pump N2 down 1-3/4" Velocity String until both plugs shear and fall to bottom of well. Vent the N2 to a Flowback tank and monitor the LEL. When methane is detected send well to production facility. 27. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. 28. RDMO and release eauipment. RD flowback iron. Release tanks and all rental equipment to vendors. CONTACTS Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) David Martens: 713-296-3302 (w) 832-4 72-6249( cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emeraencv Dial 911 GO#3 CT Velocity String Hangoff Procedure DMD per KDW - 6/21/2007 7:58:03 AM Tree cxn: 3 1/2" Srd Tubing hanger prepped wI : -6' of 7",23 ppf, L-80 pup jt wI re-entry guide -6" type "H" BPV profile min ID =5.469" -7" BTC lift threads Isolated Perfs: B-3 4596'-4658' ( 8+spf, 3/10/82) B-4 4775'-4790' (sqzd 3/8/83) B-4 4798'-4818' (sqzd 3/8/82) 23/8" Velocity string wI nipple for plug or standing valve to 5285' (min ID=1.021") 20", 94# Drivepipe @ 106' 133/8",61#, K-55, BTC Casing @ 2020' Cmt w/ 1000 sx of Class G 7" Scab Liner 4563'-4850' SLP Upper & Lower isolation packers minimum ID=6.052" 7", 23 ppf, L-80 BTC casing SLP upper isolation pkr @ 4563' SLP lower isolation pkr @ 4850' Producinq Perfs C-1 5281'-5346' (12spf, 12/8/00) Inflatable Plug @ 5410' Baker tubing retrievable bridge plug (2/28/01) Open Perfs below pluq: C-2 5442'-5460' (12spf, 12/8/00) C-2 5530'-5550' (12spf, 12/8/00) Cement retainer @ 5580' 95/8", 47ppf, casing @ 5580' PBTD @ 5580'MD/4801'TVD Well Name & Number: KU 14-32 I Lease: GF, Pad 34-31 County or Parish: I State/Provo I Country: I Perforations (MD) (rvO) I Al1íifì! . ~ ,,,vr BHP: 1430 psi (stati BHT: I Completion Fluid: Date Completed: I Tree cxn: 3 1/2" 8rd Tubing hanger prepped wI : -6' of 7",23 ppf, L-80 pup jt wI re-entry guide -6" type "H" BPV profile min 10 =5.469" -7" BTC lift threads Isolated Perfs: B-3 4596'-4658' ( 8+spf, 3/10/82) B-4 4775'-4790' (sqzd 3/8/83) B-4 4798'-4818' (sqzd 3/8/82) 95/8", 47ppf, casing @ 5580' PBTD @ 5580'MD/480TTVD 20", 94# Drivepipe @ 106' 133/8",61#, K-55, BTC Casing @ 2020' Cmt w/1 000 sx of Class G 7" Scab Liner 4563'-4850' SLP Upper & Lower isolation packers minimum ID=6.052" 7", 23 ppf, L-80 BTC casing SLP upper isolation pkr @ 4563' SLP lower isolation pkr @ 4850' Producinq Perfs C-1 528T-5346' (12spf, 12/8/00) Inflatable Plug @ 5410' Baker tubing retrievable bridge plug (2/28/01) Open Perfs below pluç¡: C-2 5442'-5460' (12spf, 12/8/00) C-2 5530'-5550' (12spf, 12/8/00) Cement retainer @ 5580' (ND) Lease: GF, Pad 34-31 State/Provo Completion Fluid: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12:00 - 13:00 . . Page 1 of 1 Marathon Oil Com pany Operations Summary·Report KENAI UNIT 14-32 KENAI UNIT 14-32 MAINTENANCE/REPAIR 1.00 RURD_ SLlK WRLN . Date From- To Hours Code Sub Phase Code 4/11/2007 07:00 - 08:00 1.00 RURD_ SLlK WRLN 08:00 - 09:00 1.00 RURD_ SLlK WRLN 09:00 - 09:30 0.50 RUNPUL SLlK WRLN 09:30 - 12:00 2.50 RUNPUL SLlK WRLN Start: 4/10/2007 Rig Release: Rig Number: Spud Date: 1/15/1982 End: Group: Description of Operations MIRU Pollard Slickline. Held PJSM to review JSA and Safe Work Permit conditions. MU tool string and lubricator. RIH and tagged fill at 5321' KB with 0.94" OD pulling tool as a gauge ring. POOH with tool string. RIH with tandem 3/4" Memory Pressure-Temperature gauges to mid-perf depth of 5316' KB. Took static benches at surface, midway to the perfs, and at the mid-perf interval. POOH with gauges. Checked data-Good. RDMO Pollard Wireline. Printed: 6/19/2007 10:24:09 AM ~ . . Mªräthon OU.Gompany Pa~1 åf1 OperationsSummªry·lieport Legal Well Name: KENAI UNIT 14-32 Common Well Name: KENAI UNIT 14-32 Spud Date: 1/15/1982 Event Name: MAINTENANCE/REPAIR Start: 5/11/2005 End: 6/11/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From..To Hours Code Sub Phase ~ription of Operation$ COåe 5/12/2005 07:30 - 08:00 0.50 SAFETY MTG - PRDTST Sign in, discuss jobs, and issue work permit. 08:00 - 08:30 0.50 SAFETY MTG - PRDTST Spot equipment, fill out JSAlhold safety meeting. 08:30 - 10:00 1.50 RURD_ SLlK PRDTST RU slickline unit through wellhouse. 10:00-11:15 1.25 TAG - BOTM PRDTST Run 3/4" tool string. Tag bottom at 5291' WLM. 11:15 -11:30 0.25 PULD - LOG PRDTST Program and pick up 3/4" memory gauges 11 :30 - 14:00 2.50 LOG - eSG - PRDTST RIH w/ memory gauges to bottom gathering pressure data. 14:00 - 15:00 1.00 RURD_ SLlK PRDTST RD slickline unit and move to Pad 41-7 for a second pressure survey. Printed: 6/19/2007 10:22:33 AM . . MEMO WELLS PRODUCING IN KENAI., STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201-231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X ~to ?yJ1 -O~ ~ J- ~\d<O ·,'.b....·-·...· .. S\CANNED JUL 2 7 2007 ..., . AlaSka. Team Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 October 25,2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 cy~ h\~"~ÌÌ'-~"¡:;'Uì' ~VP~t:l'tiw.,,,,, C' C· C'<,,""- -ii 'h;'Ji U . t.........'" RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, . . Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production trom this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13 -6L 23X-6SAN 33-7S 3 1- 7X Þ~PI No. 5011331009001 5011331009101 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 . . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibele@marathonoi1.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Files Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage Marathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 6, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KU 14-32L Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals. The proposed work is to install a jet compressor downstream of the velocity string meter. The compressor will require the use of higher pressured gas to reduce velocity string flowing tubing pressure. The lower flowing pressure on the velocity string will facilitate efficient lifting of condensed water in the large casing. Any gas used to lift water will be appropriately metered and allocated. The ability to lift water that condenses in the wellbore is expected to result in improved annular gas rates. //''' This installation is expected to be started up the week of 10 November 2003. A simple schematic is included for your review. Please recall that you recently approved a sundry for jet compressor installations at KU 21-7 and KU 14-6RD. If you need any additional information, I can be reached at 907-283-1301 or by e-mail at b mse nette@ ma ratho noil. com. Brent M. Senette Production Engineer Enclosures OR GINAL O:\EXCEL\KU_14-32L_Sundry_AOGCC07.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon I 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 87 feet 3. Address Exploratory 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic__ Kenai Unit 4. Location of Well at Surface Service 8. Well Number · 740'N & 1759' W of SE Corner of Sec. 31, T5N, R11W, S.M. KU 14-32L At top of Productive Interval 9. Permit,/~umber 978' N & 235' E of SW Corner of Sec. 32, T5N, R11W, S.M. 82-15 At Effective Depth 10. APl Number Install Gas Jet Compressor 5o- 133-20351 / At Total Depth 11. Field/Pool 955' N & 930' E of SW Corner of Sec. 32, T5N, R11W, S.M. Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured 5700 feet Plugs (measured) (inflatable) @ 5410' true vertical 4897 feet Effective Depth: measured 5571 feet Fill (measured via DIL 12/08/2000) true vertical 4799 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 106' 20" Driven 106' 106' Surface 2020' 13-3/8" 1000 sks 2020' 1856' Intermediate Production 5695' 9-5/8" 1380 sks 5695' 4894 Liner Perforation Depth: measured C-1: 5298'- 5314', C-2: 5320' - 5327', 5330' - 5345', 5445' - 5455', 5539'- 5550' true vertical C-1: 4593' - 4606', C-2: 4610' - 4616', 4618' - 4629', 4705' - 4713', 4776' - 4785' . Tubing (size, grade, and measured depth) Straddle 7" 23 ppf L-80 from 4563-4850' .... i · ' '~'~='..' ;;;' i~,~" 2-3/8" CT HO-70 w/0.134" wall thickness to 5285' Packers and SSSV (type and measured depth) SLP Isolation packer @ 4563' i~0~¢_,.(t~,,~' SLP Isolation packer @ 4850' · .... 13. Attachments Description Summary of Proposal X Detailed Operations Program m'": ..'"ii BoP"sketc't~'''' , 14. Estimated,Date for/Commencing Operation 15. Status of Well Classification as: 16. If Pro °s~ Verbally Approved Oil ..... Gas X Suspended__ Name of Approver Date Approved Service 17. I hereby cease and corr_ect to the best of my knowledge. Signed ,//~'/~ B.M. SenetteFOR COMMISSloNTitle ProductiOnUsE ONLyEngineer Date 11/6/2003 Conditions ¢ Approval: Notify Commission so representative may witness JApproval No. Plug Integrity/ BOP Test Location ClearanceJ 3¢:::).,~ Mechanical Integrity Test__ S'~ubsequent Form Required 10--- ~O Approved by Order of the Commission Sal"ah P~ilJJr~ commissioner Date Form 10-403 Rev. 06/15/88 SU bm i~ ih Tr~21ica'te ORIGINAL KU 14-32L Gas Jet Gas Flow Diagram Compressed or high pressure gas I Motive Gas Meter I To low pressure production header or test separator KU 14-32L Annulus Production KU 14-32L Velocity String Production Meter Jet Compressor: Throttles high pressure p mOtive gas to drop velocity string flowing ressure below field suction levels Velocity string water and gas production / Annular Production t I I Well KU 14-32L .Au~'28-01 11:24am From-UARATHON OIL +0166646480 T-OT6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.03/05 F-912 1, Type of Request; Abandon Suspend_._. Operation Shutdown · Re-enter Suspended Well_.... Alter Casing -.-. Repair Well~ Plugging.._. Time E. xteneior'_~. Stlmulate__ Change Approved Program Pull Tubing~ Variance.... Perforate_.._ Other, X Name of Operator MARATHON OIL COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 ._ Location of Well at Surface , 740' N & l?6ej' W of SE Comer of Sec. 81, TSN, R11W, At top of Productive Irtterval 978' N & 235' E of SW Comer of Sec. 82, TaN, Ri tW, At Effe~ve Depth Install 2-3/8" Velocity String At Total Depth 955' N & 930' ~.. of SW Comer of Sec. 82, TSN, R11W, s. Type of Well: Development._~_X EXplorato~..~ Stratigmph[o~ Service Datum Elevation {,DF or KB) 87 feet 7, Unit or Property Name Kellai Unit a. Well Number KU 14-52L -~, Permit Nu/q3,be~,' 82.16 v 10. APl Number SC)-- 183-20351 11. Field/Pool Kenai Gas Fi.eld,, Pool 6 12. Present Well Condition Summary Total Depth: measured true veffk;al Effective Depth: measured true vertical 6700'feet ~ Plugs (meaSUred) (infi~mb~e) e 5410' 4897 feet 5671 feet Fgl (measured via DIL 12/08/2000) 4799 feet Casing Length Structural Conductor 106' Surface 2020' Intem~ediate Productio~ 5695' Liner Perforation Depth: mea~ured tree verfic~l Tubing (size, grade, and measured depth) ~tze Cemented Measured Depth 20" Driven 108' 13-$/8" 1 ooo aka 2020' 9-6/8" 1~8o sks 6695' C-1: 6298' - 5:514', C-2: 5320' - 5~27', 6330' - 5345', 6445' - 5455', 6~89' - 5550' C-1: 4593' - 4606', C-2; 4610' - 4616', 4618' - 4629'. 4705' - 4713', 4776' - 4786' Straddle 7" 23 ppi L-8O from 4563-4860' True Ve~(~al Depth 10~' 1856' 4894 Packers and SSSV (type and measured depth) 8LP Isolation packer @ 4668' SUP Isolation packer ~ 4850' la. Attachr~ents -- ' Dee~dpti(~ SUmmary of Proposal_._ .... beta,ecl opemtlons prog'ram.~.. BOP Sketch Suepended Date 8/~8/2001 14. Estimated Date for Commencing Operation 115, S .fetus of Well Classification 8/3o/2001 i 16. If Proposal was Verbally Approved Oil___ Gas. X_..X Name of Approver Date Approved .~ervice., . 17, I hereby certify that the foregoing is true ~nd coif&ct t~' the best of my knowledge; ' ~ Signed ~ }/J//~.. D.M. Tltu. T'~e Produ~on Engineer ...... FOR OOMI~II~$1ON use ONLY ~bndittons o! Approval: Notify, c°mmi~ion so repr 'e~tative may wltne.~ ~ .~'(:~(:::) .'. Plug Integrity BOP Test~_ Location Clearance~ .... Meo-h~nioal Int-~grity Test Subaequent Fo n~ Required 10-"--L~b % -- ORIGINAL 81G. N_...ED I Approved by Orde? of the Commission ._ . J, M, Heu_.. Commissioner Date /~,,~/ 10,403 Rev. 01~/tS/88 ~ubm'l~ In Tr[pllcg. te T-OT$ P.04/05 F-g12 MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 14-32 AFE # 0490901 VELOCITY STRING HANG OFF KU 14-32 was worked over to be a 9 5/8" tubingiess completion. The well will not flow at . predicted rates as it lo, ads up and cannot maintain eh?ugh velooity to lift water. Objective: Install a 2 3/8" velocity string to lift water_ Once water is lifted, proceed to flow up large casing. This is a preliminary step to a potential concentric lift string. Note: Smallest downhole. IO is 5,469" BPV profile. Straddle assembly is 7" 23 ppf from 4563-4850'. procedure: 1. Prepare weft for work (is. Remove wellhouse, set BPV, pump fluid sufficient to kill well---,60 bbl) 2. MIRU ABE Vetco, Remove 2"~ master valve (see attached sequence diagrams). Install CT hanger on tree. 3. MIRU CT unit w/2 3/8" pipe (w/wireline retrievable running plug installed). 4, RU to annulus and coil reel w/fluid pump. Install pressure gauge on opposite side of annulus. Pressure test lines and l~OPs to 250/1500p$i, 5. RIH to 5285'. Mark pipe. - 6. Measure distance from CT hanger look screws on tree to above BOPs. Plok up measured distance. 7. Close BOP slips and rams. Monitor well pressure on annulus to make certain pressure remains at 0 psi. 8. Break the connection above the BOPs and raise inje~or head (as per $ohlumberger CT Operating procedure) as needed to clear the hanger to cut CT and install CT hanger seal assembly. 9. Install C-Plate and dog collar slips on pipe. 10. Cut tubing and install CT connector, DFV, Hydraulic GS and CT hanger seal assembly. Pull test CT conneotor to 25,000 lbs. 10:51 ~M 08r28/01 N :'~D RLGkI~G IAW ELL~KU 14-32L~taagoff.(lo¢ Aug'~8-01 11:25am From-~RATHOH OIL +9166646489 T-O?$ P.05/05 F-gl2 11. 12. 13. 14. 15. 16. 17. Engage running tool in top of hanger. Remove dog collar and C-plate. Lower injector (as per Schlumberger CT Operating procedure)and make up riser to BOP. Pull Test connectors and hanger against slips to ~/-25000 lbs. (4000 lbs. Over pipe wt.) Slowly lower pipe to hangoff depth using mark on pipe as reference,' watch for drop off in weight to verify h~nger location. Check measurements, and land hanger on load shoulder. RU ABB Vetco to run in lock screws and torque per hanger .~pecifications. Verify seal integrity via pressure test ports in tubing head. Pump down CT 1.5 bpm ~to 2 bpm to release running to, o! and retract. RDMO Coiled Tubing unit. Mi Udelhoven to attach surface flowlines. Attempt to flow well to open top tank. If well will not flow, RU jumper line of high pressure gas to annulus. Inject gas until well breaks back (expect at around 750 psi). Re-attempt flowback to tank. .... · 18. Turn flowing well over to system per instruction of operator. 10:51 AM N: ~DRLO"~O'b'~WLrt.,LS~I(.U 14-321.,\h,'~ttgoff.ctoc Tree mn: 3 1/~" 8rd ~ ~'~' Tubing hangor prepped wi -6' of 7'. 23 ppf, L-S0 pup jt w/re-entry guido rain ID --5.459" -?" BTC lift threads RECEIVED RUG 2 8 2001 Oil &~ gomrnmmo~, ~ 20", g4~ Drivepipe @ 106' 13 3/8", 61#, K.55, BTC Casing @ 2020' Cmt w/1000 sx of Class G Isolated B-3 4596'-4658' ( 8.k~pf, 3/t0/82) B-4 4775'-4790' (sqzd 3/8/83) B-4 4798'-4818' (sqzd 3/8/82) 7" Scab Line,r 4563'.4850' SLP Upper & Lower isolation packers minimum ID--6.052" 7", 23 ppf, L-80 BTC casing SLP upper isolstion pkr @ 4565' SLP lower isolation pkr.@ 4850' 2 3/8" Velocity string w/nipple for plug or standing valve Producin~ Perfs C-1 5287'-5346' (12spf, 12/8/00) Inflatable Plug @ 5410' Baker tubing retrievable bridge plug (2/28/01) Open Perf~ beiow,,,.p_lu_q: 0-2 5442'-5460' (12spf, 12/8/00) C-2 5530'-5550' (12spf, 12/8/00) Cement retainer @ 5580' 9 5lB", 47ppf, casing @ 5580' PBTD @ 5580'MD/4807'TVD iWell Name & Number: I IOount)r or Parish: Angle/Perfs 1430 (smti~ IBHP: psi D~te Oompleted: KU 14.32 I Lease; I State~Prov. Angle ~ KOP and Depth ....... O'vo) BHT: ComPletion Fluid: KQF, Ped $4~1 Icou. : Og-14-ZOOt 09;56 Frola-ABB VETCO GRAY WELLHEAD EQUIPMENT PRESENTLY ON LEASE 7804904472 DIMENSIONAL 7 1/16-5000 ? 1/18- 3000 ~/~ 6--.3ooo 11--5000 T--~66 P.006/025 F-i?O i. DATA RECEIVE AUG 2 8 2001 ~80TrOM MASTER CLOSED ~6" H BPv Oe-14-ZOOl SWAB HEAD VALVE REMOVED INSTALLATION FOR 7 1/16-3000 1 ]-5000 '?804go4472 T-366 P.OIO/OZ5 F-6?g VGCTH-2 TUBING REC£1V rt..T) Gas ~ns. r~mm~,sto~ Anchorage 7 1 / 16-30oo BOTTOM MASTER CLOSED qlA l~6-14-2i]01 00:56 I:rom-A~, VETCO Gi~Y VOCTH-2 TUBING INSTALLED HEAD ~OTP.,~ 4= COed. TuBWI: ~ Ru~ AND ? ] / ] 6-3000 11-5000 760400447~ COIL T-366 P.011/025 TUBING BOP --COIL ~OP UNIT (NOT ALL SHOWN) ¢6CTH-2 CT I-ID 7 ~/] 6-3ooo F-979 05-14-100l -COIL TUBING IS SET' (LOCKSCREWS~ ENGAGED) -2" BPV PLUG INSTALLED IN TUBING HANGER -BOP REMOVED RECEIVED AUG 2 8 2001 ~ Oil & Gas Guns, uu..m~"." Anchoraoe H 8Pv VGCTM-2 HGR 1/16--3000 ~ ] / ~ 6- ~oo0 7 1 / 16-3000 11-5000 NOTES 1~3~8~ BaNl~JI ~t~la~, tue~¢ ~ & ,, BI~ d Og~14-~O01 Og :t~6 F ror'~D ~E?CO 0~¥ 7g0490447S .--.-TOP SECTION INSTALLED -BPV PLUG REMOVED FROM TUBING T-366 p.o13/0s5 ~-e~9 HANGER 2 1/~ e- 3000 RECEIVED AUG 2 8 2001 Alaska Oil & Gas Corm. UOfllmlSSlL. Anchorage ~2 1/16-3000 CHRISTMAS TREE 2 1/~ 5-3000 16-3000 1/16-3000 7 ~/~ s- 3ooo -500O mOTES r I i.&~OuT DF Ci. dliSl'a&& TRk~ ql& LI~UlUM~_IIIA IJ Ill~ IA Fmb-19-01, ~10:55am F rom-MAI~ATHON (, +$155645489 T-554 P.0Z/05 F-459 Alaska Re[, Domestic Production Marathon Oil Company P,O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 19, 2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KU 14-32L Dear Mr, Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for Marathon well KU 14-32L. If you need any additional information, I can be reached at 907- 564-6303 or by e-mail at rjaffinito@marathonoil,com. Sincerely, Ralph Affinito Production Engineer Faxed 02/19/01 RECEIVED ~-ss 2 o ~oo1 A subsidiary of USX Corporation Environmentally aware for the long run. F~b-lg-01 From-MARATHONO/~,~ +g15554848g T-$84 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.03/05 F-4$g 1. Type of Requeat; 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 Name of Operator MARATHON OIL COMPANY 8. Address P. O. Box 196188, Anchorage, AK 99519-6168 4. Location of Well at Surface 74o' N & 17B9' W of SE Corner af See. 31, T6N. R1 lW, $.M. At top of Productive Interval 978' N & 235' E of SW Comer of Sec. 32, TeN, R11W, S.M. At Effective Depth At Total Depth s,~,~' N & 9,30' E of SW Type of Well: Development~X Explorato~j Sbatigraphic Service TEMPORARY PLUG BACK C-2 PERFORATIONS Corner of Sec. 32, T6N. R11W, $,M, e. Datum Elevation (,DF or KB) 87 feet 7. Unit or Property Name Konai Unit 8. Well Number KU 14-32L ,, s, Permit Number 82-15 lO. APl Number 60-- 133-20351 11, Field/P0;gi K-hal Gas Field, Pool 6 12, Present Well Condition Summary Total Depth; measured true vertical S?00 feet Plugs (measured) 4897 feet Effective Depth: measured true vertical ,~571 feet 4799 feet Fill (meaaured vla DIL 12/08/'2000) Casing Structural Conductor Surface Intermediate Production Uner Pa#oration Depth: measured Length Size Cemented Measured Depth 106' 20" Driven 106' 2020' 13-9/8' 1000 sks 2020' 5695' 9-~/8" 1380 eke 6696' C,1: $298'- 5314', 0-2; 5320'- 5327', 5;330' - 5:345', 5445' - 5455', 5599' - 5560' true vertical C-1; 4-593' - 4606', C.2: 4610' - 4616', 4618' - 4629', 4705' - 4713', 4776' - 4785' Tubing (size, grade, and measured depth) Straddle 7" 23 ppi L-80 from 4583-4850' True Ve~ic~lDepth 106' t858' 4894 RECEIVE[ FEB 2 0 2001 Packers and 885V [type end measured depth) SIP Isolation pecker @ 4563' SLP Isolation packer @ 48S0' AlmSaOil a Gao Cons. Co~ Anchorage 13. Attachments Deacription Summary of Proposal ~ Estimated I~te for Commencing Operation 2/22/2001 16. If Proposal was Verbally Approved Name of Appmver Date Approved Detailed Operations Program X BOP Sketch Status of Well Classification as; O!1 Gas X Service, ~uepended._,.. 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. ., Si.cjned ~/t~~-~ .. ,R, Affin,to Title Production Engineer FOR COMMISSION U~E ONLY IConditions of Approval: Notify Commi~ion so mpresentalive may wlmess 'Plug Integrity BOP Test Location Clearance Mechanical In~"~ity Test...._ """-~ubsequent Form Required 10- -"~ , ~ ORIGINAL SIGNED Approved by O~ler of the Commission O T2vic~r Se~! ..~our~t Form 10-4~3~ Rev. 06/36/88 Date 2/19/2001 Commieajoner Feb-lg-01, I0:56am , From-MARATHONO~ +0166648480 T-$84 P.04/06 F-460 MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 14.32 AFE 9204499 Retrievable Plug Back of C-2 procedure _0b_iective: Utilize Schlumberger Electric Line to set a Baker through tubing inflatable plug over the perforations. Not~ Smallest downhole ID is 5.469" BPV profile. Straddle assembly ia 7" 23 ppf from 4563-4850', Refer to attached wellbore diagram. Procedure: 1. MIRU Schlumberger WL Hold Safety Meeting, RU ,5" lubricator and PT. 2, RtH w/Baker 4.25" OD through tubing inflatable retrievable bridge plug, Correlate depth to Schlumberger GR/CCL dated 12/08/2000. Set plug at 5410' KB, COH, RD service company, Secure well and clean up location. ' 3. Turn well to LP sales system. 7:44 Alii N'kDllLG~KGI~W ELLSIKIJ 14-32L~plu g$¢t, doc , From-MARATHON?~.,, Kenai Gas Field 'Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region Original RT-GL: 26.00' Workover RT-GL: 21,60' Workover RT-THF: 20.35' 740' N & 1750' W of SE Corner Sec. 31, TSN, RllW API #50-133-20381 Tree Connection - 3-112" 8rd Tubing hanger pr~pped with: - 6' of ?', 23 ppi, L-80 pup joint - 6" type "H" BPV profile rain ID --- 5,469" in BPV profile - 7" BTC lift threads Isolated P~rfs B.3 ~,'5'~'~r- 4658' (8+ spf, 3110182) ..,...,./ 11-4 4775' - 4790' (Sqzd3/S/82) g-4 47~8'- 4818' (Sqzd 3tBI82) r rodu cia g Peris ~2--i' ~-B~"--- ~'46' (12 spf, 12/8100) C-2 5442' - 5460' (12 8pf, 12111/00) C-2 5530' 5550' (12spf, 12/8/00) ?BTD ~, 55110' ID @ 5700' L 20", !}4# Drive pipe ~ 106' 13-3/8", 61#, K-$5, BTC Casing @ 2020' Cmt wi 1000 sk$ of Class O SLP upper isolation paok, r @ 7" Scab Liner 456Y- 4850' SLP ' p~'f-,&,-L-bwer Isolation Packers wi 6,052 min ID 7', 23 ppi, L-80, BTC casing @LP lower isolation packer @ 48~0' Tagged fill 5571' DIL (1218100) Cement retainer ~ 5580' 9-5/8", ¢?~, N-g0, BTC Casing @ 5695' Cml wi 1380 sks of Class O Last Rev' IOE, 12120100 Nov-2g-00 05:00pm From-MARATHON 0~,~,. +g15554548g T-g4? P.02/03 F-$$4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request; Abandon Suspend --.- Operation Shutdown Re-enter suSPe'nd'~d Well '--' Alter Castng Repair Well ~ Plugging, Time Extension ~ Stimulate ---. Change Approved Program .-.-- Pull Tubing ~ Variance ~ Pedorate .--- Other .~X ;~. Name ol-C~pemtor s, T~/pe of Wale e,-i~atum Elevati°n (DF or KEt)" ' MARATHON OIL COMPANY Development. X · i 3. Address Explorato~y 7, O~it or Properly 'Name P O BOX 196168, Anchor e AK g951~-61~8 Stratigraphlo ._.; ..... a~ ,....~' ../ ../~, · [ Kenai Unit 4. Location of Well at Surface "' Service"--- ~. V~II Number . 740' N & 1759' W of SE Comer of Sec. 81, TSN, R11W, S,M, KU 14-52L At top of Productive Interval '~. Pemlit lq~er 978' N &235' E of SWComerof Sec. 32. TSN, RllW, S.M, , 82-15 At Effective Depth 10. APl Number Add Perforations (see attached) .o-- ~s~-2o~ ,./ At Total Depth 1~. Field/P&ol 955' N & 930' E of SW Corner o! Sec, 32, TSN. R11W, S.M. Kenal Gas Reid, Pool ';i2. p~e~Sent Well C-6hditionSummary ....... ' -- ~ Total Depth: measured 6700 teat Plqg~ (measured) bus vertio~tl 4897 feet Effective Depth; measured s534 feet Junk (meaau¢ed) true vertical 4772 feet Casing Lenglh Size Cemented Measured Depth True Vertical Depth Structural Conductor 106' 20" Driven 10~' 1 Surface 2020' 13-3/8" 1000 ske 2020' 1858' Intermediate P roduction 5695' 9-.~I8" 1380 eke .~895' 4894 Liner Perforaticm Depth: measured C-1: 6298' - 5314', C-2; 5320' - 6327', 5330'. 5345', 5445' - 5455', 5539' - 6660' true veffical C.t; 4593' - 4606', C-2.; 4610' - 4616', 4618' - 4629', 4706'- 4718', 4776' - 4785' Tubing (size, grade, and measured depth) 3-1/2", 9.2~f, N-B0 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4498' MD Baker model D pa~ket @ 4700' MD Baker model D pack. er @ 522o' MD Attachmer~ts De~iiption Summary of Pmposal~ Detailed Operations Program X_..~' ORIGINAL B-OP',Sketch I ;~. ~stimated Date for Co~n~encing Operation 12/4/00 Nam-'e 5f Approv~r t, Date Approved ~ttue of V~II blaseification as: Oil Gas X Service Suspended_.._ 87 feet _-- ... , 17. ! hereby certify that t~e foregc~ng b true and correct to the best of my knowledge. Sick, ed Title Production Engineer ..... FOR COMMISSION USE dNLY '" ~%nditions 6f-Approval; 'r' Notify commission so representative may wl~ess ' Plug Integrity BOP Teet Location Clearance Mechanic~,l Int~ty Test ---~ubsequent Form Requirad Appro.,fod by Order of the Commlssioq Form IO-4o~ f~ev, oe~t ~oe ORIGINAL SIGNED BY' ' J. M. Heusser ....... Date 11/29/00 -. RECEIVED NOV 29 000 Nov-2g-O0 O5:OOpm F rom-MARATHON 0~1~: +gl $$84848g T-g47 F-864 WELL KU 14-32 KENA1 GAS FIELD PERFORATE C-1 & C-2 Sands .Obiectiv.~._: Repefforate (w/ additional perforations) in C-1 and C-2 sands. Proce, dure: 1. MIRU Schlumberger electric line. Test BOPs and lubricator to 2000 psig. KIH w/4.72", 12 spf hollow carrier guns. Tie in with GR/CCL. Perforate the sterling C-1 and C-2 sands as follows: MD TVD 5284'-5346' (62') 4582'-4630' 5442'-5460' (18') 4703'-4717' 5530'-5550' (20') 4769'-4755' Perforate with maximum underbalance. 2. POOH, RDMO electric line. 3. Flow well as per instrucfons of Production Foreman MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKU 14-32 7-Oct-00 L/D 15 JTS of tubing. RIH with mill and cleaned off top of packer. RIH and milled ov er and latched packer. 8-Oct-00 POOH with packer. Tested BOPE. Made 8 1/2" mill run to 5300'. 9-Oct-00 POOH. RIH with 8 1/4" tapered mill. Washed and reamed to 5585'. Displaced with clean 3% KCL. POOH to 4572'. 10-Oct-00 POOH. With DP. LD BHA. RU and run scab liner. 11-Oct-00 Set scab liner. POOH L/D drill pipe. Installed BPV. N/D BOPE. N/U tree. 12-Oct-00 Installed 2-way check in hanger. Tested tree to 3000 psi, Prep rig for demob. Note: Rig in for R & M. Restart Nov ember 1. MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKU 14-32 30-Sep-O0 1 -Oct-O0 2-Oct-00 3-Oct-00 PJU to pull dual tubing and strings. POOH and LID dual strings. Finished POOH and L/D. Dual tubing strings and packer. Changed rams and tested. RIH with fishing assembly. Picking up drill pipe. RIH to 4522'. Milled over top of 31/2" tubing and latched. POOH and L/D fish. RIH with packer milling assembly Mill over packer at 4693'. CBU. POOH and L/D milling tools. M/U spear and RIH. Latched packer and POOH. L/D fishing tools and half of packer. RIH with overhot. Worked over fish. 4-Oct-00 5-Oct-00 6-Oct-00 RIH. Tagged fish at 4879' and chased to 5019'. POOH with no recovery RIH and attempted to spear fish. No success. RIH and milled over and latched fish. POOH. POOH with overshot. No recovery. Made up spear and RIH. Attempted to spear fish. POOH. Made up flat bottom mill and RIH. Broke circulation at 5,022'. Milled fish from 5,022' to 5,028'. Continued to mill on fish to 5,029'. Worked on PLC rig controls. POOH. Changed fishing tools. RIH with hollow mill and over shot. Tagged at 5,029': fish worked over top. POOH. Layed down fishing tools. Rigged up Weatherford to laydown tubing. MEMORANDUM TO: THRU: FROM: Dan Seamount Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 30, 2000 Blair Wondzell ~~ P.I. Supervisor jeff Jones~ ~' ~.~_~ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Inlet Ddlling GD1 Marathon/KGF 14-32 182-0150 KGF/Sterling Operator Rep.: Daryl Greene Contractor Rep.: Mike Leslie Op. phone: 283-1312 Rig phone: 283-1315 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 3000 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P Standing Order: , pt Annular: 3,,0.00 Choke: 3000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly I P Lower Kelly 1 P Ball Type I P Inside BOP 2 P BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P ' Pipe Rams I 4" P Lower Pipe Rams 1 4" P Blind Rams 1 blind P Choke Ln. Valves 1 3 1/8" P HCR Valves I 3 1/8" P Kill Line Valves 2 2 1116" P Check Valve 1 2 1116" P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P ,, ,, Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P ACCU M ULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi P/F Quantity P/F System Pressure 3000 P No. Valves 12 P After Closure 1600 P Man. Chokes 1 P 200 psi Attained 35 sec. P Hyd. Chokes 1 P Full Pressure 2:57 P Blind Covers (All Stations): P N2 Bottles (avg): ,,4 (i~ 2400 psig Test's Details Saturday, September 30, 2000: I traveled to Marathon's Kcnai Gas Field to witness a BOPE test on rig # GD-1, where Inlet Drilling Co. personnel were preparing to perform a workover operation on well 14 -32. The testing went well with no failures. The gas detectors were tested and operated properly. Summary: I witnessed a BOPE test on Glacier rig #1 in thc Kenai Gas Field, preparing to work over Marathon's well 14 -32. Thirty-four components were tested; no failures were witnessed. Total Test Time: 2.5 hrs. Number of failures: cc'- 0_. Attatchments: _~ BOP Inlet Drlg GD 1 9-30-00 JJ.xls Alaska, ~on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 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: RECEIVED SEP 1 8 2000 Alaska O~; & Gas Cons. Commission Anch0m~e 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 9S/s'' 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 95/8" 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 subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OAEX CELV~OGCCO4.xls Cz,/' 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing m Repair WellI Plugging Change Approved Program Pull Tubing X Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other Name of Operator 5. Type of Well: MARATHON OIL COMPANY Development X Address Exploratory P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic Location of Well at Surface Service 740' N & 1759' W of SE Corner of Sec. 31, T5N, R11W, S.M. At top of Productive Interval 978' N & 235' E of SW Corner of Sec. 32, T5N, R11W, S.M. At Effective Depth Workover to Allow Flow Up 9-5/8" Casing At Total Depth 955' N & 930' E of SW Corner of Sec. 32, T5N, R11W, S.M. 6. Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 14-32L 9. Permit Number 182-15 10. APl Number 50-- 133-20351 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 5700 feet Plugs (measured) 4897 feet 5534 feet Junk (measured) 4772 feet ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented MeasumdDepth 106' 20" Driven 106' 2020' 13-~8" 1000 sks 2020' 5695' 9-5/8" 1380 sks 5695' C-1'5298'-5314', C-2:5320'-5327',5330'-5345',5445'-5455',5539'-$550' true vertical C-1'4593'-4606', C-2:4610'-4616',4618'-4629',4705'-4713',4776'-4785' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4498' MD Baker model D packer @ 4700' MD Baker model D packer @ 5220' MD True VerticalDepth 106' 1856' 4894 ' ,ECEIVE SEP 1 8 2000 Anchorage 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing OperalJon 115. Status of Well Classification as: 9/22/00 I Oil .... 16. If Proposal was Verbally Approved Name of Approver 17. I hereby .~~atthe for~,~,~~is true and Date Approved Service correct to the best of my knowledge. Gas X Gary Eller Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test ~ Location Clearance Mechanical Integrity Test Subsequent Form Required 10- Suspended Date 9/16/00 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED BY D TavIor Seamount Commissioner Date Submit in Triplicate RECEIVED WELL KU 14-32- AFE 9204499 KENAI GAS FIELD SEP 1 8 2000 PULL TUBING, FLOW UP 9%" CASING ~Ja~ka 0~I & Gas Cons. Commissm An~omge Objective: Perform a workover on well KU 14-32 to allow the Sterling C-1 Sand (Pool 6) to produce up the 9%" casing to increase deliverability. Procedure: 1. MIRU pipe recovery unit on KU 14-321. Test lubricator and BOPs. RIH, make jet cuts at 4522' (below dual packer) and 4720' (below single packer). POOH. RD from longstring, RU on shortstring. RIH, make a jet cut immediately above the dual packer at 4492'. POOH. RDMO pipe recovery unit. 2. Bleed off any trapped pressure on both tubing strings and the 9%" casing. Install BPVs in shortstring and longstring tubing hangers. 3. MIRU workover rig. Do not rig-up the top drive at this time (to allow blocks to swivel if needed). ND tree, NU BOPs. (Note: Upper pipe rams equipped with dual 3½" rams, lower pipe rams equipped with single 4" rams.) Fill hole and mud pits with fresh water. Pull BPVs, install 2: way checks, test BOPs to 3000 psig. Pull two-way checks. Lay out 5500' of 4", 14 ppf, HT- 38 drill pipe on the pipe rack, and drift the tool joints (box-end and pin-end) with a special 2.406" drift. 4. MIRU tubing handling equipment for dual 3½" strings. Attempt to release the Baker model A-5 dual packer on the longstring tubing. If the packer releases, lay down both tubing strings simultaneously. If the packer does not release, verify that the shortstring tubing is free from the dual packer. Circulate down the shortstring tubing to verify no fill is on top of the packer. MIRU pipe recovery unit on the longstring. RIH with chemical cutter for 3½" tubing. Tie in with CCL and make a chemical cut on the longstring tubing 20' above the dual packer (leaving adequate 3~" tubing to latch with an overshot). POOH, RDMO pipe recovery unit. Lay down all tubing. 5. Replace the dual 3½" pipe rams (upper pipe rams) with single 4" pipe rams. Install test plug and retest BOPs. Pull test plug, install wear bushing. RU top drive. PU string of 4" work pipe (14 ppf, S-135, HT-38) already drifted to 2.406". Note: With the drill pipe specially drifted, it can pass a 2%" chemical cutter for 3½" tubing if so needed during the remainder of the workover. 6. If the dual packer is still in the hole, latch it with an overshot and attempt to jar it loose. If needed, burn over and retrieve the dual packer. Also, retrieve the remaining 3½" tubing and blast joints down to the model D packer at 4700'. 7. PU a packer mill with packer-retrieving tool, two junk basket, and 4%" collars. Mill up the model D packer at 4700'. Circulate hole clean. TOH. LD packer, mill, etc. Be aware of possible lost returns. Well KU 14-32 Pull Tubing, Flow Up 95/8'' Casing Page 2 8. Retrieve the remaining tubing down to the model D packer at 5220'. 9. PU a packer mill with packer-retrieving tool, two junk basket, and 4%" collars. Mill up the model D packer at 5220'. Circulate hole clean. TOH. LD packer, mill, etc. Be aware of possible lost returns. 10. PU 8½" bit & scraper and TIH to bottom. Clean out fill to 5580' applying HEC gel sweeps as needed to clean the hole. 11. PU and TIH with 7", 23 ppf, L-80 scab liner to isolate perfs 4596' - 4818'. Set scab liner, TOH laying down work string. Pull wear bushing. 12. PU tubing hanger with one pup joint of 7" tubing. Land hanger and test. Install 6" 2-way check, ND BOPs and NU 7-1/16", 3M tree. Test tree. Note: Minimum ID in the tubing hanger is 5.469" in the BPV profile. 13. RDMO workover rig. Pull 2-way check when the rig is clear. 14. MIRU 1%" coil tubing and nitrogen. Test lubricator and BOPs to 2000 psig. RIH with coil tubing to 5580'. Jet well dry using nitrogen. Reverse out fluid if unable to lift fluids up the 9%" casing with 1%" coil tubing. 15. MIRU electric line. Test BOPs and lubricator to 2000 psig. RIH with 4.72", 12 spf hollow carder guns. Tie in with GR/CCL. Perforate the Sterling C-1 & C-2 Sand as follows: 5298'-5314' 5320'-5327' 5330'-5345' 5445'-5455' 5539'-5550' Perforate with maximum underbalance. POOH, RDMO electric line. 16. Flow well KU 14-32 as per instructions of Production Foreman. JGE September 11, 2000 C:~IyFiles~)rilling~KU14-321\procedur. WPD 'PROPOSE Kenai 6as Field Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region RT-GL: 26.00' 740' N & 1759' W of SE Corner Sec. 31, T5N, RllW API #50-133-20351 Tree Connection = ??? Tubing hanger prepped with: - 6' of 7", 23 ppf, L-80 pup joint with re-entry guide - 6" type "H" BPV profile - 7" BTC lift threads Isolated Perfs B-3 4596'- 4658' (8+ spf, 3/10/82) B-4 4775'- 4790' (Sqzd 3/8/82) B-4 4798'-4818' (Sqzd3/8/82) Producing Perfs C-1 5298'- 5314' (16 spf, 3/14/82) C-2 5320'- 5327' (16 spf, 3/14/82) C-2 5330'- 5345' (16 spf, 3/14/82) C-2 5445'- 5455' (16 spf, 3/13/82) C-2 5539'- 5550' (16 spf, 3/13/82) TD @ 5700' · 20", 94# Drive pipe @ 106' 13-3/8", 61#, K-55, BTC Casing @ 2020' Cmt w! 1000 sks of Class G 7" Scab Liner 4550' - 4870' SLP Upper & Lower Isolation Packers 7", 23 ppf, L-80, BTC casing Cement retainer @ 5580' 9-5/8", 47#, N-80, BTC Casing @ 5695' Cmt w/1380 sks of Class G Last Rev: JGE, 9/18/00 Kenai Gas Field Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region RT-GL: 26.00' 740'N & 1759' W of SE Corner Sec. 31, T5N, RllW Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. · Otis "XA" Sliding Sleeve @ 4457' ID = 2.750" Otis "XN" Nipple @ 4514' ID = 2.635" Shortstring Perfs B-3 4596'- 4658' (8+ spf, 4" csg guns, 3/10/82) Squeeze Perfs B-4 4775'- 4790' (Sqzd 3/8/82) B-4 4798'- 4818' (Sqzd 3/8/82) Longstring Perfs C-1 5298'- 5314' (16 spf, 2-1/8' Enerjet, 3/14/82) C-2 5320'- 5327' (16 spf, 2-1/8' Enerjet, 3/14/82) C-2 5330'- 5345' (16 spf, 2-1/8" Enerjet, 3/14/82) C-2 5445'- 5455' (16 spf, 2-1/8" Enerjet, 3/13/82) C-2 5539'- 5550' (16 spf, 2-1/8" Enerjet, 3/13/82) Note: Communication between long and short strings suspected 2/12/98. TD @ 5700' 20", 94# Drive pipe @ 106' 13-3/8", 61#, K-55, BTC Casing @ 2020' Cmt w/1000 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve @ 4464' ID = 2.750" Opened 2/25/98 for annular flow Baker A-5 Dual Packer @ 4502' Blast Joints 4581' - 4669' Otis "XA" Sliding Sleeve @ 4681' ID = 2.750" Baker Model D Packer @ 4700' Baker Model D Packer @ 5220' X Nipple @ 5228' ID = 2.750" Wireline Re-entry Guide @ 5250' Fill tagged @ 5524' WLM (2/10/98) -- Cement retainer @ 5580' · 9-5/8", 47#, N-80, BTC Casing @ 5695' Cmt w/1380 sks of Class G Last Rev: JGE, 2/26/98 IFIow Nipple i' i FIow LineI I 13 5/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer I........~ IPipe Ram I Operated Valves IBlind Ram I ~ 13 1/8" 5M Hydraulically ([ I Operated Valve 13 1/8" 5M Manually IPipe Ram I I IOperated Valve 13 5/8" 5M Single Ram Preventer Marathon Oil Company BOP Configuration 3" 5M Valves 2 9/16" 1 OM Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke Marathon Oil Company Choke Manifold Configuration Static Pressure Gradient Survey Well: KDU 51 Field: Kenai Gas Field Borough: Kenai Slickline Company: Pollard Wireline Bomb Type: McAIlister quartz Gauge Number: gauge #1 - #2061 Date: 1-Jun-99 Perfs: Sterling C-1 MPP: 5,162' MD 4,577' TVD KB-THF: 27.0' Depth Depth Pressure (MD) (TVD). (psia) O' O' 345.11 2,000' 1,936' 358.81 4,000' 3,631' 371.42 4,550' 4,080' 374.75 Pressure Temperature Gradient (deg F--) (psi/fi) 52.7 N/A 57.8 O.OO7 79.8 0.007 100.6 0.007 Temperature Gradient (De~/100 fl) N/A 0.263 1.298 4.633 MPP: 5,162' 4,577' 378.44 Datum: 5,250' 4,652' 378.99 Calculated Fluid Level: unknown 0.007 0.007 Annular flow Flowing Pressure Gradient Survey Bottomhole Surface Depth Depth Pressure Pressure Flow Rate Measured (MD) ('rVD) (psia) (psia) {MCFD) Delta-P (psiS) 4,550' 4,080' 359.12 284.71 6,817 15.63 Tubing flow 4,550' 4,080' 364.97 255.61 4,950 9.78 Field: KENAI GAS FIELD Date' Aug 31. 2000 Well.' KDU-51 - 9-5/8" Casing Flow vs 7" Tubing Flow File: KOU-SL T i t 1 e: POOL 6 INPUT DATA 400.0 , , , , , , , , , , , , , , , , CORNISH _ - DARCY CASED HOLE i ~ Gas 9rav 0.5570 C02 0.02 % N2 0.32 % ,H2S 0.00 % _ Hater grav 1.0000 ~ Cond-gas ratio 0.00 STB/MMCF '~ Htr-gas ratio 0.~0 STB/MMCF ~ 300.0 Maas depth 5~62. feet TVD 4577. feet ~ _ ADs Rough 0.00105 in ~ Pwh 150 psia D ' ~ Twh 53. De9 F ~ - Tbh 102. De9 F ~ - Res Press 370. psia Res Tamp 102. Oeg F ~ Drain radius 1440 ft 0 Net thickness 40. ft ~ Comp interval 40. ft ~ 200.0 Eff perm 1490. md ~ _ ~;~ Skin 4.80 o ~ ~...~~ ~~ OU ~ - Hellbore radius 6.1 in ~ ~- ~ ~ Shot density 8.00 SPF ~ Tunnel length 7.0 in Perf dia 0.33 in - CZ k/Res k 0,400 · Turb coef 1.082E+07 l/ft -- lO0.O I I I I , , ' I I I I I I I I I O. ~0000. 20000. 30000. 40000. 50000. Gas Rate. MCFD Tubing diameter A A 6.366 inches D-~ 8.681 inches Workover of Well KU 14-32 Kenai Gas Field Page 2 is an attempt to increase well deliverability, and Marathon's primary 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 BOPE 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. Workover of Well KU 14-32 Kenai Gas Field Page 3 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" Flowline 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. ~j.~~lle Sincerel i.~y' Completions Engineer RECENED /~a~a O~ & ~3a$ Con~. CommiSs'mn AnOa0ra%o l I~,~RATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 14-32 7-Oct-O0 8-Oct-O0 9-Oct-00 10-Oct-00 11-Oct-00 12-Oct-O0 L/D 15 JTS of tubing. RIH with mill and cleaned off top of packer. RIH and milled over and latched packer. POOH with packer. Tested BOPE. Made 8 1/2" mill run to 5300'. POOH. RIH with 8 1/4" tapered mill. Washed and reamed to 5585'. Displaced with clean 3% KCL. POOH to 4572'. POOH. With DP. LD BHA. RU and run scab liner. Set scab liner. POOH L/D drill pipe. Installed BPV. N/D BOPE. N/U tree. Installed 2-way check in hanger. Tested tree to 3000 psi. Prep rig for demob. Note: Rig in for R & M. Restart November 1. IVI~cLATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 14-32 30-Sep-00 R/U to pull dual tubing and strings. POOH and LID dual strings. 1 -Oct-00 Finished POOH and L/D. Dual tubing strings and packer. Changed rams and tested. RIH with fishing assembly. Picking up drill pipe. 2-Oct-O0 RIH to 4522'. Milled over top of 31/2" tubing and latched. POOH and L/D fish. RIH with packer milling assembly. Mill over packer at 4693'. 3-Oct-00 CBU. POOH and L/D milling tools. M/U spear and RIH. Latched packer and POOH. L/D fishing tools and half of packer. RIH with overhot. Worked over fish. 4-Oct-O0 RIH. Tagged fish at 4879' and chased to 5019'. POOH with no recovery. RIH and attempted to spear fish. No success. RIH and milled over and latched fish. POOH. 5-Oct-00 POOH with overshot. No recovery. Made up spear and RIH. Attempted to spear fish. POOH. Made up flat bottom mill and RIH. Broke circulation at 5,022'. Milled fish from 5,022' to 5,028'. 6-Oct-00 Continued to mill on fish to 5,029'. Worked on PLC rig controls. POOH. Changed fishing tools. RIH with hollow mill and over shot. Tagged at 5,029': fish worked over top. POOH. Layed down fishing tools. Rigged up Weatherford to lay down tubing. ,~ARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai Peninsula/KU 14-32 27-Sep-00 Rig mob. Set rig mats, substructure, carrier, generator house, boiler house, mud pit trailer. Raised derrick.. R/U. 28-Sep-00 29-Sep-00 Rig mob. Fire up boiler. R/U mud pump and mudpit trailers. Circ. Water thru system. R/U top drive. Accepted rig to well KU 14-32 at 0600 hours 9-28-00. N/D tree. N/U B©PE and tested. Fill well with water. Alaska. dion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 21, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference' KU 14-32L Dear Mr. Wondzell: Enclosed is the APPLICATION FOR SUNDRY APPROVALS for well KU 14-32L. Please advise if additional information is required. I can be reached at 564-6317 or e-mailed at dmtitus@marathonoil.com. Sincerely, Denise Titus Production Engineer Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. O:~EXCELV~OGCC03.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Re-enter Suspended Well__ Alter Casing Repair Well Plugging Time Extension Stimulate __ Change Approved Program Pull Tubing Variance Perforate Olher ~X 6. Datum Elevation (DF or KB) 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchora~le, AK 99519-6168 4. Location of Well at Surface ~- ~,, ~ 740' N & 1759' W of SE Corner of Sec. 31, T5N, R11W, S.M. At top of Productive Interval 978' N & 235' E of SW Corner of Sec. 32, T5N, R11 W, S.M. At Effective Depth At Total Depth 955' N & 930' E of SW Corner of Sec. 32, T5N, R11W, S.M. 5. Type of Well: Development X Exploratory Stratigraphic Service ORIGINAL 7. Unit or Property Name Kenai Unit 87 feet 8. Well Number KU 14-32L 9. Permit Number 182-15 10. APl Number 50-- 133-20351 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Deplh: measured true vertical Effective Depth: measured true vertical v/'5700 feet Plugs (measured) · ~'4897 feet 5534 feet Junk (measured) 4772 feet Patch hole in tubing and wash/jet to restore production Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 106' 20" Driven 2020' 13-3/8" 1000 sks 5695' 9-5/8" 1380 sks Measured Depth True Ve~ical Depth 106' 106' 2020' 1856' 5695' 4894 C-1-5298'-5314',C-2:5320'-5327',5330'-5345',5445'-5455',5539'-5550' true vertical C-1'4593'-4606',C-2:4610'-4616',4618'-4629',4705'-4713',4776'-4785' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4498' MD Baker model D packer @ 4700' MD Baker model D packer @ 5220' MD 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 8/29/00 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas X Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"/~ "~~ Denise Titus Title Production'Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test V~ Location Clearance Mechanical Integrity Test Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. O6/15/88 Date 8/21/00 IApprova No. Z OC) '" Commissioner ~bmit i~ Triplicate oRIGINAL SIGNED BY O Taylor Seamount Approved aetu_ . WELL KU 14-32L KENAI GAS FIELD PATCH HOLE IN TUBING AND JET Ob, iective: A hole has been confirmed in KU 14-32L at 4631'. This work will include setting a patch over the hole as well as the sliding sleeve located below. Following the patch work, the well will be jetted in or washed as need to restore production. Procedure: 1. RU Schlumberger 1 V2" Coil Tubing Unit on KU 14-32L. Pressure test to 2000 psi. 2. RIH w/2.70" casing scraper, motor, and mill to 4750'. Rotate if needed. POOH. 3. RIH w/XA nipple locator. Locate sliding sleeves (2.750" ID) at 4464', 4681', and 5228'. Tie in depth with PDS inspection log. 4. RIH 70' 2.70" O.D. tubing patch. 5. Set patch at 4620'-4690'. POOH. 6. PU wash nozzle and RIH. Jet well in with N2. Wash sand if needed. 7. Produce well per instruction of Production Engineer. AUG £ o ,:.~..'.'~."~: Anchorage RT-GL: 26.00' 740'N & 1759' W of SE Comer Sec. 31, T5N, RIlW Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. Shortstring Perfs B-3 4596'- 4658, .S. queeze Perfs B-4 4775'- 4790' B-4 4798'- 4818' Otis "XA" Sliding Sleeve ~ 4457' ID = 2.750" Otis "XN" Nipple ~ 4514' ID = 2.635" .(8+ spf, 4" csg guns, 3/10/82) Longstring Perfs C-1 5298'- 5314' C-2 5320'- 5327' C-2 5330'- 5345' C-2 5445'- 5455' C-2 5539'- 5550' (Sqzd 3/8/82) (Sqzd 3/8/82) (16 spf, 2-!/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/13/82) (16 spf, 2-1/8" Enerjet, 3/13/82) Note: Communication between long and short strings suspected 2112198. Kenai Gas Field Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region 5700' 13-3/8", 61#, K-55, BTC Casing ~ 2020' Cmt w/1000 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve ~ 4464' ID = 2.750" Opened 2/25/98 for annular flow Baker A-5 Dual Packer ~ 4502' Blast Joints 4581' - 4669' Otis "XA" Sliding Sleeve ~ 4681' ID = 2.750" Baker Model D Packer @ 4700' Baker Model D Packer @ 5220' X Nipple @ 5228' ID = 2.750" Wireline Re-entry Guide @ 5250' Fill tagged ~ ..... Cement retainer @ 5580' 9-5/8", 47#, N-80, BTC Casing @ 5695' Cmt w/1380 sks of Class G Last Rev: JGE, 2/26/98 g:~cmn\d rtg~kgt~wells~ku 14-321~,OGCC02a.xls STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate__ Plugging Perforate Pull Tubing Alter Casing Repair Well Other X 5. Type of Well: Development X Exploratory Stratigraphic Service 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 740' N & 1759' W of SE Corner of Sec. 31, T5N, R11W, S.M. At top of Productive InterVal 978' N & 235' E of SW Corner of Sec. 32, T5N, R11W, S.M. At Effective Depth Jet with Nitrogen to Restore Production At Total Depth 955' N & 930' E of SW Corner of Sec. 32, T5N, R11W, S.M. 6. Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 14-32L 9. Permit Number J 82-15 lO. APl Number ~ 50-- 133-20351 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical 5700 feet Plugs (measured) 4897 feet Effective Depth: measured true vertical 5534 feet Junk (measured) 4772 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth 106' 20" Driven 106' 2020' 13-~8" 1000 sks 2020' 5695' 9-5/8" 1380 sks 5695' C-1:5298'-5314', C-2:5320'-5327',5330'-5345',5445'-5455',5539'-5550' True Vertical Depth 106' 1856' 4894 true vertical C-1: 4593' - 4606', C-2: 4610' - 4616', 4618' - 4629', 4705' - 4713', 4776' - 4785' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4498' MD Baker model D packer @ 4700' MD Baker model D packer @ 5220' MD RECEIVED 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure ORIGINAL 1"/2000 Alaska 0il & Gas Cons. C0mmi~ Anchorage 14. Representative Daily Averaqe Production or Iniection Data OiI-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 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations[ X Oil Gas X Suspended 17. I hereby cer~'~hat the foregoin~lks true and correct to the best of my knowledge. Signed "~ ~~~% Gary Eller Title Production Engineer Service Form 10-404 Rev. 06/15/88 si0n Date 2/15/00 Submit in Duplicate,~ MARATHON OIL COMPANY DAILY WELL OPERATIONS REP~ PAGE I OF I DATE: 1/26/00 FIELD: Kenai Gas Field WELL #: KU 14-321 FILL DEPTH/DATE 5534' 5-94 TUBING: 3 1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80 DATE LAST WL WORK: 6-7-99 TREE CONDITION: WORK DONE: SBHP BENCHES OPEN: Sterling C-1 PRESENT OPERATION: CT unload water using Nitrogen OTHER: SUMMARY OF OPERATIONS Held safety and evironment meeting, discussed job scope. MU tool string on well. Had R&K on location with 10 ppg CaCL water to PT the coil. Fill the coil wih water. PT Rams, sm leak on tree flange. Hammer up the connection, Pt to 1500 psig. PT Rams, blind sheer1 & 2, and the N2 lines. PT good, blew down lines and coil with N2. Open well RIH with 1.75" CT with 2" nozzle. Pump N2 at 500 SCM. WHP=0 psig Run coil down to 5500 ', up punp rate to 750 scfm, taking water returns to the gas buster. lower nitrogen rate to 250 scfm to see if well responds. Well dying. PUH increase N2 to 500 scfm,. Getting water in returns again. shut down N2 to check for well flow. Still dying. start N2 at 800 SCFM. Getting much better water returns, and building about 50 psig wellhead pressure. POOH continuing to cirvulate nitrogen. Cut N2 rate "o 500 SCFM above the dual packer. shut down N2, Whp=0. Well flowing to atmosphere. Rig back CT unit, will RD in AM Note: Produced back approx. 5 to 6 bbls of 1-120 Flowed well into the gas buster for 1 hr 10 minutes.. Well did not gain well head pressure during flow back no water was produced through the buster during this time. Put well into the production test separtor, flowed well to atmosphere. Well not building much pressure with no H20 produced to separator. Stop B/D of well and put into the groduciton header. Well was flowing at 1.1 mmcfpc rate. Well pressure dropped off at 1830 ~rs. Well bled down, no response from well. Subsequent attempts to return well to production had no affect. RECEIVED FEB 15 ~_0O0 Alask~ Oil & Gas Cons. C0mmis Anchorage 'Vendor ' Equipment Daily Cost cumulative Cost Schlumberger Unit w/4 man crew $25,000 $25,000 Toloff crane $3,800 $3,800 M-I Drilling Fluids calcium chloride $2,2:00 $2,200 Weaver Brox. trucking $2,500 $2,500 R&K blending fluid $3,£.00 $3,000 Air Liquide nitrogen $4,¢,00 $4,000 Misc. $2,¢,00 $2,000 DALLY COST: $42,500 CUM: $42,500 REPORTED BY: Cissell Alaska R Jn Domestic Production Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 19, 2000 Mr. Blair E. Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Reference: Well Number KU 14-32L Dear Mr. Wondzell' Enclosed is the Application for Sundry Approvals for Well KU 14-32L. The work is scheduled for Tuesday, January 25, 2000. We would appreciate your prompt attention to this notice. If you have any questions, please call me at 564-6315. Sincerely, ~~on Engineer. RECEIVED j.".," 2'i 200.0 Alaska Oil & Gas Cons. Commissior, Anchorage Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O:'EX OEL~AOG CC02.xls~. 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging m Change Approved Program Pull Tubing Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 5. Type of Well: Development._~_X Exploratory Stratigraphic Service 740' N & 1759' W of SE Corner of Sec. 31, T5N, R11W, S.M. At top of Productive Interval 978' N & 235' E of SW Corner of Sec. 32, T5N, R11W, S.M. At Effective Depth Jet with Nitrogen to Restore Production At Total Depth 955' N & 930' E of SW Corner of Sec. 32, TSN, R1 lW; S.M. 6. Datum Elevation (DF or KB) 7. Unit or Property Name Kenai Unit 87 feet 8. Well Number KU 14-32L 9. Permit Number 182-15 10. APl Number 50-- 133-20351 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 5700 feet Plugs (measured) 4897 feet 5534 feet Junk (measured) 4772 feet ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 106' 20" Driven 2020' 13-3/8" 1000 sks Measured Depth 106' 2020' 5695' 5695' 9-5/8" 1380 sks C-1'5298'-5314', C-2:5320'-5327',5330'-5345',5445'-5455',5539'-5550' true vertical C-1'4593'-4606', C-2:4610'-4616',4618'-4629',4705'-4713',4776'-4785' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer @ 4498' MD Baker model D packer @ 4700' MD Baker model D packer @ 5220' MD True VerticalDepth 106' 1856' 4894 RECEIVED jA,~,I 2 l 2000 Naska 0il & Gas Cons. C0mmlssi0~ A n~hnra¢ll~. 13. Attachments Description Summary of Proposal__ Detailed Operations Program X BOP Ske}~}~ 14. Estimated Date for Commencing OperaUon 1/25/00 16. If Proposal was Verbally Approved ! Oil Date Approved / Name of~ Service 17. I'-~'~ereb~' c~e foregoin true and correct to the best of my knowledge. Signed ~ Noti~"bS~lmission 15. Status of Well Classification as: Gas X Suspended ., Conditions of Approval: Plug Integrity m Mechanical Integrity Test Gary Eller Title Production Engineer Date 1/19/00 FOR COMMISSION USE ONLY so representative may witness BOP Test ~ Location Clearance Subsequent Form Required 10- Approved by Order of the Commission ORIGINAL SIGNED BY Robert N. Chdstenson Form 10-408 Rev. 06/15/88 Commissioner Date Submit in Triplicate WELL KU 14-32L KENAI GAS FIELD UNLOAD WELL USING NITROGEN Objective: The KU 14-321 well is loaded up with water and unable to flow. The purpose of this work is to jet the well in with coil tubing and nitrogen to return it to flow. Procedure: 1. Shut in both sides of well KU 14-32. MIRU laA'' coil tubing and nitrogen on KU 14-32L. Test BOPs and lubricator to 1500 psig using calcium chloride water (for freeze protection). When finished BOP testing, displace brine to a surface tank for disposal. 2. RIH with coil tubing and jetting nozzle. Jet the well as needed to a surface tank until the well is flowing independently. Do not attempt to wash fill from the casing sump. When the well appears to be flowing independently, shut off nitrogen and switch the flow to the production system. POOH without shutting in the well. 3. RDMO coil tubing. Continue to flow well KU 14-321 as needed to keep it from loading back up. JGE January 19, 2000 N :~,DRLGLKGF~WELLSkKU 14- 3 2L\jet. WPD I EIVED RT-GL: 26.00' 740'N & 1759' W of SE Comer Sec. 31, T5N, R11W Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. Kenai Gas Field Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region / 20", 94# Drive pipe @ 106' 13-3/8", 61#, K-55, BTC Casing @ 2020' Cmt w/1000 sks of Class G Longstring Tubing: 3-1/2", 9.2//, N-80, Butt. Otis "XA" Sliding Sleeve @ 4457' ID = 2.750" Otis "XN" Nipple ~ 4514' ID = 2,635" Shortstring Perfs B-3 4596' - 4658, .(8+ spf, 4" csg guns, 3/10/82) Otis "XA" Sliding Sleeve ~ 4464' ID = 2.750" Opened 2/25/98 for annular flow Baker A-5 Dual Packer ~ 4502' Blast Joints 4581' - 4669' Otis "XA" Sliding Sleeve @ 4681' ID = 2.750" Squeeze Perfs B-4 4775' - 4790' (Sqzd 3/8/82) B-4 4798' - 4818' (Sqzd 3/8/82) .Longstring Perfs C-1 5298'- 5314' C-2 5320'- 5327' C-2 5330'- 5345' C-2 5445'- 5455' C-2 5539' - 5550' (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/13/82) (16 spf, 2-1/8" Enerjet, 3/13/82) Note: Communication between long and short strings suspected 2/12/98. ~ @ 5700' Baker Model D_P~c~er ~ 4700' IVED J~,[,J 21 2000 Baker Model D Packer @ 5220' X Nipple ~ 5228' ID = 2.750" Wireline Re-entry Guide @ 5250' Fill tagged ~ ..... g,%ivl ......... Cement retainer @ 5580' 9-5/8", 47#, N-80, BTC Casing @ 5695' Cmt w/1380 sks of Class G Last Rev: JGE, 2/26/98 g:tcmn~drlgtkgflwellstku 14-321~,ogcc01a.xls STATE OF ALASKA ~ ALASI~ OIL AND GAS CONSERVATION boMMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate Pull Tubing Alter Casing Repair Well Other X · ~ Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 740' N & 1759' W of SE Comer of Sec. 31, T5N, R11W, S.M. At top of Productive Interval 978' N & 235' E of SW Corner of Sec. 32, T5N, R11W, S.M. At Effective Depth Convert to Annular Flow At Total Depth 955' N & 930' E of SW Comer of Sec. 32, T5N, R11W, S.M. 5. Type of Well: Development Exploratory Stratigraphic Service Datum Elevation (DF or KB) 87 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 14-32L 9. Permit Number 82-15 10. APl Number 50-- 133-20351 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical 5700 feet Plugs (measured) 4897 feet Effective Depth: measured true vertical . 5534 feet Junk (measured) 4772 feet Casing Length Structural Conductor 106. Surface 2020' Intermediate Production 5695' Liner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured Depth True Vertical Depth 20" Driven 106' 106' 13-3/8" 1000 sks 2020' 1856' 9-5/8" 1380 sks 5695' 4894 C-1' 5298' - 5314', C-2: 5320' - 532?, 5330' - 5345', 5445' - 5455', 5539' - 5550' C-1. 4593' - 4606', C-2: 4610' - 4616., 4618' - 4629', 4705' - 4713', 4776. - 4785' R E C E i V 3-1/2", 9.2W, N-80 tubing to 5250' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer (~ 4498' MD Baker model D packer ~ 4700' MD Baker model D packer {~ 5220' MD ED MAR 19 1998 011 & Gas Cons. Commission Anchorage 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure ORiGiNAL 14. Prior to Well Operation Subsequent to Operation OiI-Bbl 0 0 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4,000 0 300 6,000 0 245 Tubing Pressure 228 245 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service 17. I herebY~ Signed '~ Form 10.404 Rev. correct to the best of my knowledge. Title Production Engineer Date 3/11/98 Submit in Duplicate Kenai Gas Field Well KU 14-32, Pad 34-31 Marathon Oil Co., Alaska Region RT-GL: 26.00' 740' lq & 1759' W of SE Comer Sec. 31, TSN, RI 1W Shortstring Tubing: 3-1/2", 9.2//, N-80, Butt. 20", 94//Drive pipe @ 106' 13-3/8", 61//, K-55, BTC Casing ~ 2020' Cmt w/1000 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve @ 4457' ID = 2.750" Otis "XN" Nipple @ 4514' ID = 2.635" Otis "XA" Sliding Sleeve @ 4464' ID = 2.750" Opened 2/25~98 for annular flow Baker A-5 Dual Packer @ 4502' Blast Joints 4581' - 4669' Shortstring Perfs B-3 4596'- 4658' (8+ spt', 4" esg guns, 3/10/82) Otis "XA" Sliding Sleeve @ 4681' ID = 2.750" Baker Model D Packer @ 4700' SqueezePerfs B-4 4775'-4790' B4 4798'-4818' (Sqzd 3/8/82) (Sqzd 3/8/82) LongstringPerfs C-1 5298'-5314' C-2 5320'-5327' C-2 5330'-5345' C-2 5445'-5455' C4 5539'-5550' (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-1/8" Enerjet, 3/14/82) (16 spf, 2-118" Enerjet, 3/13/82) (16 spf, 2-1/8" Enerjet, 3/13/82) Note: Communication between long and short strings suspected 2/12/98. TD @ 5700' BakerModel DPacker@5220' XNipple@5228' ID= 2.750" WkelineRe-entryGuide@5250' Fill tagged @ 5524' WLM (2/10/98) Cement retainer @ 5580' 9-5/8", 47//, N-80, BTC Casing @ 5695' Cmt w/1380 sks of Class G Last Rev: JGE, 2/26/98 980226.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF I DATE: 2/26/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Retrieve PX plug Kenai Gas Field WELL #: KU 14-32L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 OTHER: Day #9, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS RU Pollard Wireline on KU 14-32L. SITP = SICP = 290 psig. Short string is shut in. Test lubricator and BOPE to SITP. Master valve on tree is froze shut; thaw out ice plug with heater. RIH with JDC pulling tool, latch extended neck prong at 4677' WLM. POOH with prong. RIH with GS pulling tool. Latch P× plug body at 4679' WLM. POOH with plug body. RDMO slickline. --- FINAL REPORT--- RECEIVED irma,'-, 19 1998 Alaska 0il & Gas Cons. Commission Anchorage Vendor Equipment Daily Cost Cumulative Cost APC Fabrication, vacuum trucks $0 $2,513 Baker Oil Tool B shifting tool, check valve $0 $3,000 Dowell Nitrogen, coil tubing $0 $29,250 Misc. Lights, etc. $0 $3,000 Pollard Wireline Slickline $1,050 $9,925 Udelhoven Crane $0 $1,152 Weaver Bros. Trucking $0 $3,350 DALLY COST: $1,050 CUM: $52,190 REPORTED BY: J.G. Eller 980225A.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPURT PAGE 1 OF 1 DATE: 2/25/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KU 14-32L TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 Jetting out packer fluid with coil tubing OTHER: Day #8, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS 0800 1600 RU Dowell 1.5" coil tubing on KU 14-32L. SITP = 200 psig, SICP = 640 psig. Test BOPE and lines to 1500 psig. MU tool string with check valve and "B" shifting tool. RIH with coil tubing. Tag PX plug at 4652' CTM. PU weight is 11,000#, showing excess drag of 6,000#. Circulate nitrogen at 350 SCF/min down coil tubing, taking returns up tubing. Circulate for several minutes to verify that no water is laying on top of PX plug. PU to 4440' CTM, latch XA sliding sleeve with "B" shifting tool while circulating nitrogen at 350 SCF/min. Shift XA sleeve open with 24,000# of pull. After sleeve was opened, the "B" shifting tool slipped off and casing pressure fell quickly. RIH with coil tubing to 4652' CTM, increasing nitrogen rate to 500 SCF/min. Circulate out one large slug of packer fluid to surface. Continued jetting until returns are dry. Reduce nitrogen rate to 350 SCF/min, then 150 SCF/min, then shut off nitrogen altogether. No incremental packer fluid recovered at surface at any nitrogen rate. After shutting off nitrogen, let pressures equalize for 20 minutes, then resume nitrogen injection at 400 SCF/min with coil tubing on bottom. No incremental fluids to surface. Shut off nitrogen, POOH. RD coil tubing. SITP = SICP = 290 psig. Note: Recovered approximately 5 bbls of packer fluid from KU 14-32. Plan to move slickline on well KU 14-32L tomorrow to pull PX plug after pulling plug from KDU-5L. Dowell will leave coil tubing equipment in the field for a day or two until we successfully get wells KU 21-6L, KU 14-32L, and KDU- 5L back online. RECEIVED MAR 19 1998 Naska 0il & Gas Cons. Commission Anchorage Vendor Equipment Daily Cost Cumulative Cost APC Fabrication, vacuum trucks $213 $2,513 Baker Oil Tool B shifting tool, check valve $3,000 $3,000 Dowell Nitrogen, coil tubing $16,550 $29,250 Misc. Lights, etc. $0 $3,000 Pollard Wireline Slickline $1,625 $8,875 Udelhoven i Crane $1,152 $1,152 Weaver Bros. Trucking $1,500 $3,350 DAILY COST: $24,040 CUM: $51,140 REPORTED BY: J.G. Eller MARATHON OIL COMPANY~/'-'"~ DALLY WELL OPERATIONS RE?"'RT PAGE 1 OF 1 DATE: 02/24/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KU 14-32L TUBING: 3-1/2", '9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 Jetting out packer fluid with coil tubing OTHER: Day #7, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS 1300 1700 RU Dowell 1.5" coil tubing on KU 14-32L. Will not pick up injector head and test BOPs until work is resumed tomorrow morning. RU nitrogen on 9-5/8" casing of KU 14-32. Pressure 9-5/8" casing from 50 psig to 630 psig. Left pressure applied on casing. RD nitrogen. Secure well, SDFN. Note: In the morning, plan to RIH with a "B" shifting tool conveyed on coil tubing. Will shift open the XA sliding sleeve at 4464' MD while simultaneously jetting with nitrogen. RECEIVED 19 1998 ~ & Gas Cons. CommlaiOB Anchorage Vendor Equipment Daily Cost Cumulative Cost Dowell Nitrogen, coil tubing $4,000 $12,700 Misc. Lights, etc. $0 $3,000 Pollard Wireline Slickline $0 $7,250 DAILY COST: $4,000 CUM: $27,100 REPORTED BY: J.G. Eller MARATHON OIL COMPANY,'-'"; DALLY WELL OPERATIONS RE"-"W,T PAGE 1 OF 1 DATE: 02/16/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KU 14-32L TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 Testing tubing & casing with nitrogen OTHER: Day #6, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS Conduct safety training with Dowell personnel. MIRU nitrogen pumping equipment on 9-5/8" casing of KU 14-32. Test lines to 2500 psig. Initial pressures as follows: 9-5/8" casing = 175 psig 13-3/8" casing = 20 psig Iongstring tubing = 300 psig shortstring tubing = 300 psig Pressure test 9-5/8" casing to 1050 psig using 83,700 SCF of nitrogen. Volume of nitrogen pumped indicates fluid level in the casing is at approximately 4000' MD. Lack of fluid head in casing means that a 1000 psig casing test is adequate. No change in pressure on other strings. Blow down 9-5/8" casing to 50 psig. RU nitrogen lines on Iongstring. Test lines to 1000 psig. Attempt to blow down Iongstring tubing to catch tank; will not blow down. Either the PX plug is leaking or the Iongstring is communicated with the shortstring below the dual packer. Call office for instructions. Record following SITP: Iongstring = 300 psig, shortstring = 280 psig. Pump 23,240 SCF of nitrogen (approximately 4.5 tubing volumes) down Iongstring at 1000 SCF/min. Longstring pressure increased to 360 psig and held steady. Shortstring pressure increased to 285 psig. Shut down injection, Iongstring dropped quickly to 320 psig, shortstring remained unchanged at 285 psig. RD Dowell off of KU 14-32. Return shortstring to production. Left Iongstring shut in. Vendor Equipment Daily Cost Cumulative Cost Dowell Nitrogen, coil tubing $8,700 $8,700 Misc. Lights, etc. $500 $3,000 Pollard Wireline Slickline $625 $7,250 DAILY COST: $9,825 CUM: $23,100 REPORTED BY: J.G. Eller MARATHON OIL COMPANYY-'", DALLY WELL OPERATIONS RE'~'~RT PAGE 1 OF 1 DATE: 02/14198 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Setting PX plug Kenai Gas Field WELL #: KU 14-32L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 OTHER: Day #5, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS Diesel engine on slickline unit repaired overnight, and mast truck has new cable. RU slickline on KU 14-32L. RIH with 2.74" OD Bowen wirefinder out EOT at 5250' MD. POOH. No indication of any wire remaining in hole. RIH with PX plug on X-line running tool. Plug accidentally set in X-profile @ 4464' MD. POOH. RIH with GS pulling tool, latch plug, POOH. RIH with PX plug. Beat through nipple @ 4462' WLM. Unable to set in X-profile at 4681' MD. POOH. Repin running tool, rerun PX plug. Set PX plug in XA sleeve at 4681' MD. POOH. RIH with check-set tool, confirmed that plug is properly set in profile. POOH. RIH with extended-neck prong. Set in PX plug. POOH. RDMO slickline. Note: Moved slickline over to well KDU 5L. Will resume slickline operations and begin nitrogen operations on Monday, 2/16/98. PX plug has four 1/4" equalizing ports. RECEIVED M .R 19 1998 Alaska Oil & Gas Cons. Commission Anchorage Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,200 $6,625 Misc. Lights, etc. $500 $2,000 DAILY COST: $1,700 CUM: $13,275 REPORTED BY: J.G. Eller MARATHON OIL COMPANY~f~'"~ DALLY WELL OPERATIONS RF'-'"~RT PAGE 1 OF 1 DATE: 02/13~98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: FIELD: Kenai Gas Field TUBING: 3-1/2" Setting PX plug Day #4, AFE 0480698 - Convert to Annular Flow WELL #: KU 14-32L CASING: 9-5/8" TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 SUMMARY OF OPERATIONS 0730 1600 Spool off 100' of wire, retie knot. Attempt to RU slickline. Cable on mast truck slipped off of sheave and frayed. Spent rest of day spooling new cable onto mast truck. RD slickline unit, sent it to diesel shop for repair. Will resume operations when slickline is better prepared. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,225 $5,425 Misc. Lights, etc. $500 $2,000 DAILY COST: $1,725 CUM: $11,575 REPORTED BY: J.G. Eller MARATHON OIL COMPANY?"~ DALLY WELL OPERATIONS R~T PAGE 1 OF 1 DATE: 02/12/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: FIELD: Kenai Gas Field TUBING: 3-1/2" Fishing PX plug WELL #: KU 14-32L CASING: 9-5/8" TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 Day #3, AFE 0480698 - Convert to Annular Flow SUMMARY OF OPERATIONS RU slickline. RIH w/2.700" impression block. Tag @ 4622' WLM. POOH. Impression of fishing neck of PX plug with wire laying across top. RIH with center spear. Work on top of plug, POOH, no recovery. RIH with 2-prong wire grab. Grabbed hold of wire, jarred for one hour with oil jar hitting 300 lb licks before wire came free. POOH, recovered 5' of wire. RIH with same wire grab. Didn't feel any wire, POOH. Recovered 4 inches of wire. RIH with prong to the PX plug on a JDC pulling tool. Tagged plug with prong @ 4664' WLM. Used prong to beat plug downhole 11'. Plug moved easily. POOH. JDC was sheared, leaving prong in the plug. Having more trouble with diesel engine on slickline unit. Down 12 hours repairing Pollard unit. Repin JDC, RIH, latch prong and POOH. Prong came out freely without excess drag. RIH with impression block. Tag @ 4652', impression of wire. POOH. (Note: Impression block detected upper X-profile @ 4460' WLM, so correction to measured depth is +4'. So, the PX plug is on top of the X- profile at 4681' MD.) RIH with 2-prong wire grab. Grab wire @ 4677' WLM, POOH. Recovered 1.5' of wire. RIH with 2-prong wire grab again to PX plug @ 4677' WLM, no wire encountered, no recovery. RIH with 2.7" impression block. Tagged up at 4564' WLM, which is +100' higher than the previous run! Impression showed clean fishing neck on PX plug. RIH with GS pulling tool, latched plug, POOH. Had to jar plug through nipple at 4464' MD. Finish POOH. Full recovery of lost tools. Secure well, SDFN. Note: Plan to next run a Bowen wireflnder to the end of the tubing to make sure no stray pieces of wire are in the tubing. Then will attempt to reset PX plug. Throughout this fishing operation, it's become apparent that somehow we got blown uphole while trying to set the PX plug. The shortstring completion had been flowing while we were working, so perhaps there is communication between the long and short strings in the vicinity of the XA sleeve at 4681' MD. Shortstring is now shut in until this operation is complete. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,800 $4,200 Misc. Lights, etc. $500 $1,500 DAILY COST: $2,300 CUM: $9,850 REPORTED BY: J.G. Eller MARATHON OIL COMPANY'""'" DALLY WELL OPERATIONS RF~"~RT PAGE 1 OF 1 DATE: 02/11/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: FIELD: Kenai Gas Field TUBING: 3-1/2" Fishing PX plug Day #2, AFE 0480698 - Convert to Annular Flow WELL #: KU 14-32L CASING: 9-5/8" TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 SUMMARY OF OPERATIONS 730 33O 430 600 Met with Pollard Wireline supervisor. Changed strategy for retrieving fish. Decided to try to retrieve fish with wire intact rather than beating wire off of rope socket. RU slickline on KU 14-32L, test BOPE and lubricator to SITP. RIH with Otis BE pulling tool (designed to latch with wire stub intact). Latch fish @ 4609' WLM (about 20' higher than expected). Jar on fish several times, but pulling tool kept slipping off. POOH. Pulling tool had sheared off. RIH with split skirt JDC pulling tool. Latched fish, and jarred several times before fish came free. POOH. Had to beat fish some to get through the X-profile @ 4464' MD. Recovered entire fish (without PX plug) plus 4' of wire. Wire had several kinks in it consistent with getting blown up hole. RIH with 2.700" impression lock to 4624' WLM. Impression of wire. POOH. Wireline mast unit ran out of fuel. Standing by for Pollard to get fuel (one hour contractor downtime). RIH w/2-prong wire grab. Snagged wire on top of PX plug with 400 lb overpull. POOH, no recovery. RIH with same wire grab. Snagged wire again. Jarred 700 lbs with oil jars several times before wire came free. Recovered 3.5' of wire. Marks on end of wire grab may indicate that it's entering the PX plug body. Diesel engine on wireline unit having trouble. Secure well, SDFN. Mechanic is making repairs on unit, expect it to be operational in the morning. Note: In the morning, plan to run an impression block to see if the PX plug is clear. If clear, will run a GS pulling tool to retrieve PX plug. It's possible that wire is wrapped around the plug. If impression block shows wire then we will continue to fish with wire grab. RECEIVED 19 1998 AlasKa 0it & Gas Cons, Anchorage Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,200 $2,400 APC Fabrication, roustabouts $2,300 $2,300 Misc. Lights, etc. $500 $1,000 DAILY COST: $4,000 CUM: $7,550 REPORTED BY: J.G. Eller .. MARATHON OIL COMPANY~'-~ DATE: 02/10/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: DALLY WELL OPERATIONS RE,~RT FIELD: Kenai Gas Field TUBING: 3-1/2" Set PX plug Day #1, AFE 0480698 - Convert to Annular Flow PAGE 1 OF 1 WELL #: KU 14-32L CASING: 9-5/8" TREE CONDITION: Swab leaking BENCHES OPEN: Sterling C-1 & C-2 SUMMARY OF OPERATIONS 0~3C Held safety meeting. RU Pollard Wireline on KU 14-32L. Test lubricator and BOPs to SITP. RIH wi 2.720" gauge ring. Tag up on XA sleeve at 4464' (ID = 2.750"). Unable to work through. POOH. RIH with 2.700" gauge ring, pass through all nipples without any problem. Tag fill at 5524' WLM (10' higher than 5/9/94). POOH. RIH w/PX plug, work past XA sleeve at 4464', attempt to set plug in XA sleeve at 4681'. Plug seemed to set properly in profile, but not entirely certain. POOH, discovered that wire broke off at the rope socket. Depth counter indicates that all wire recovered. Wait on new tool string from Pollard shop. MU new tool string. RIH w/JDC pulling tool. Tag fish on top of X-proflie at 4681'. Unable to latch fish with JDC. POOH. RIH w/2.500" impression block. Tag fish, POOH. Impression of rope socket with wire sticking out of center. End of wire appears to be bent back along side of fish, as if tool string got blown uphole. Secure well, SDFN. Note: In the morning, plan to run a blind box and break off piece of wire on top of fish. Next run will be with a JDC pulling tool and jars to latch and pull fish (do not expect PX plug to be retrieved this step). If successful in retrieving fish, will likely run a Bowen wirefinder to retrieve remaining wire sitting on top on PX plug. Sample of wire obtained from Pollard to send to PTC for analysis. Twist test of 0.108" wire in Pollard shop showed that wire performed within expected parameters (32 to 39 turns before breaking). This spool of wire was previously used on only one other well, KU 11-8L. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $t ,200 $1,200 Weaver Bros. Trucking $1,850 $1,850 Misc. Misc. $500 $500 DALLY COST: $3,550 CUM: $3,550 REPORTED BY: J.G. Eller ~b3Yr B¥:~araZhon comp any STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS RECEIVFD ,JAN 2.'1 1998, I, Type of Request: Abandon Alter Camo Change Approved Program 2. Naive of Opei~tor MARATHON OIL COMPANY 3. Addrees P, O. Box 198168, Anchorage, AK . . 4. Lo~ation of Well at Surface Suepend__ Operatkm Shutdown Repair Well__ Pluggi~ .._._ Pull Tubing Variance -- Slraagraphlc_.. 740' N & 1759' W of SE Comer of Sec. 31, TSN, R11W, $.M. At top of Productive 978' N & 2~' E of SW Comer of Sec. 32, TSN, R11W, $.M. At Effective Depth Convert to Annular Flow At Total Depth 9S$'N & 930' E of SW Comer of Seo. 32, TBN, RltW, 8.M. ,i mas (measured) lZ, Pr~=nt wai Con~ti~ Total Depth: measured true vmtical 5700 feel Effeotive Depth: meaaured 5534 feat Junk (meaeured) true vertical 4772 feet ORI$1NAL Casing Length Size cemented Structural Conductor 106' 20" Drlwn Surfa¢e 2020' 13-3/8" 1000 sl~ Inlermedlale Produ~tlon 5695' 9-5/8" 1380 Liner Perforation Depth: measured C-1; $298' - 5314', O-2: 5320' - 5327,5330' - 5~4~', 5445' - 5455', 5539'. 5550' true vertical C4: 45~' - 4606', C-2: 46t O' - 46t6', 4618' - 4629', 4705' - 4713', 4T'~. 4785' Tubing (sEe, grade, and measured depth) 3-t/2", 9.2t/. N-e0 ~ Io 525~ MD Packers and $$$V (type and measured depth) Baker model A-5 dual packer ~ 4498' MD Beirut model O packer ~ 4700' MO Baker m. odel D paek~. ~ $:r'~' MD,, 13, Altachrfiei~ Dascript;~"i Surm~ery of Propesal~ ~4, Est;~;~e~ Date for CoiTimer~ing Operation 1/2~/98 lO. If Proposal wee Verbally/~pmved Name of Approver Date Approved I7. IVle~urad O~th TrUe Verllcal Depth 5695' 4894 RECEIVED JAN 2.'1 1998 Alaska 0ii & Gas Cons. Commission Anchorage .,,i i ii i, i Detailed Operatlona Program X' BOP-*,~ateh OI1~ Gas..~.X Suspended 8en4oe on Co~-,5 of Ap Title FOR COMMISSION USE ONLY 1 ac ~epr~niaiiVe may witness Approval No. Trot Location Clearance Integrity Te~t_._ Subssquent Form Required 10- ...~0'~ _A?_~,~. i~,,c~, by Order of Ihe Comrr~sslon Approved Copy Comml~bner ,, Date Dm lt20/98 ; 1-20-~8 ; 3:18P~ ; Ancl~or a~e-~ Alaska Region Domestic Production Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 20, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Well KU 14-32L Dear Mr. Wondzell: Please find attached a procedure for permitting annular flow in well KU 14-32L in Kenai Gas Field. The increased flow area of producing up the 9e" casing and the 3~" tubing simultaneously is expected to double the well's gas deliverability. Flow up the 9e" casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. This work is expected to commence January 23, 1998. Please contact me if further information is needed. A subsidiary of USX Corporation RECEIVED Environmentally aware tar the ion~ run., Alaska 0il& B,~s Cons t;omrmss~c~" SENT BY:Marathon 011 Company ; 1-20-98 ; 3'lgPM ; Anchorage-~ WELL KU 14-32L- AFE 0480698 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective;. Allow flow up the tubing-casing annulus in well KU 14-32L to increase gas deliverability. 1. Shut in both sides Ofwell KU 14-32. Pressure test 9%" casing to SITP of KU 14-32L (approx. 490-psig). When test is complete, bleed pressure off 9%" casing. 2. MIRU slicldine on KU 14-32L. Set PX plug in X nipple at 5228' MD. RD slickline. 3. MIRU nitrogen unit on KU 14-32L. Pressure test PX plug to 2,000 pslg. Maintain 2,000 psig pressure on tubing. RD nitrogen, 4. RU slickline. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve at 4464' MD. Shift open sliding sleeve at 4464' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. Bleed all nitrogen pressure off of tubing. 6. MIKU I~A'' coil tubing and nitrogen unit. Test coil with nitrogen to $00 psig, Line up to take returns to closed-top tank. RIH jetting with nitrogen to top of PX plug at 5228' MD. Continue to jet until all packer fluid is displaced from tubing. RDMO coil tubing and nitrogen. 7. MLRU slickline on KU 14-32L. Pull PX plug at 5228' MI). RI)MO slickline. 8. As soon as possible, produce Well at maximum flow rate to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. , t~9. Shut in KU 14-32L. Install flowline on casing side of KU 14-32L. When complete, flow / /L, casing side and tubing side simultaneously to test separator and compare with previous ' test. When testing is complete, produce az per instructions of Production Foreman. ~'~ 0~ JGE J'anuary 19, 1,998 @: 'g2&RCDRLO~KOI~ ~W~..L$~KU 14-~7,L~AS'lql~OW, WPD RECEIVED Alaska Oil & Gas Cons. Commission ~!~'1' ~¥'~aFaEhon ~I1 uompany ; l-zo-u~ ; ~:zu~m ; TU__BING DETAIL' LONG STR!NG- -- 1, 3 1/2" Otis XA Sleeve - 4464' 2. Dual 3 1/2" A-5 pkr - 4498' 3, 3 1/2" Blast Jts 4581-4669' 4, 3 1/2" Otis XA Sleeve - 4681' 5. Locator - 4696' 6. Model "D" pkr - 4700' 7, Seal Assembly - 4696-4707' 8, Locator - turned down - 5212' 9. Model "D" pkr - 5220' 10. Seal Assembly §212~5228' 11. 3 1/2" Otis "X" nipple - 5228' 12. Wire]ine Guide - 5250' 13 3/8"'C. 2020' SHORT STRING. A; 3 1/2" Otis XA Sleeve - 4457' B, 3 1/2" Otis XN Nipple - 4514' SHORT STR! NG B-3 sds '4596-4658' B-4 sds 4775-4790' 4798-4818' L . LONG STRING C-1 sds 529B-5314' C-2 sds 5320-5327' 5330-5345~ 5445-5455~ 5539-5550' ETD 5580~ RE'CEIVED ,lAN 2 l' 1998 9 5/8" C. 5695'Alaska Oil & Gas Cons. /~r,r, horage, KENAI UNIT #14-32 Spud' 2/16/82 Completed: 3/14/82 UNION OIL COM?AN¥ OR CALIF()I~NIA / ~ ,/~ STATE OF ALASKA ~ ~ ALASK~i_, zL AND GAS CONSERVATION C(....:'MISSION ~~. WELL COMPLETION OR RECOMPLETIoN REPORT AND LO .- -1. Status of Well Classification of Service Well . . _ OIL [] GASdel' SUSPENDED [] "' ABANDONED [] SERVICE [] : 2. Name of Operator 7. 'Permit Number · ' UNION OIL COMPANY OF CALIFORNIA 82-15 //~ 3. Address , 8. APl Number P.O. BOX 6247, ANCHORAGE, ALASKA 99502 50- 133-20351 4. Location of well at surface 740' N & 1759' W of SE Cor, Sec. 31, T5N, 9. gnit or Lease Name RllW, S.M. ,. ~ Kenai Unit AtTop Producing ~nterva~ 978'N & 235'E :.of.'. SW Cor, Sec..32,· T5N RllW, 10. Wel~ Number S.M. " KU #14-32 At Total Septh 955'N & 930'E of SW Cor, sec 32, T5N, RllW, S.M. 11o Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Ke~ai Gas Field KB 87' MSLJ A-028055 12. Date Spudded2_16_82 13. Date T.D. Reached2_26_82 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns3--14--82 feet MS L 2 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional SUrvey I 20. Depth where SSSV set 21. Thickness of Permafrost 5700' & 4897' 5580' & 4807' YES ~ NO []I feet MD 22. '¢~/pe Electric or Other Logs Run DIL- Sonic-FDC-CNL-GR-CBL-VDL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · 20" 94# Plain ~Surface "' 106' Driven Driven , 13 3/8" 61# K-55 Surface 2020' 17 1/2" 1000 sxs CL "G" 9 5/8" 47# 'N-80 ' Surface 5695_,- ~:~ Z2..t/4, 1380 sxs CL "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and .25. -. TUBING RECORD ~.. interval, size and number) ' ' s'IZI~ '-~ E~EPTH SET (MD) PACKER SET (MD) MD VD HPF 3 1/2" 5249' 5220' 5298 '-5314 ' 4593 '-4606' 8 3 1/2" 4514 ' 4502 ' 5539'-5550' 4776 '-4785' 8 ~ ' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5445 '-5455' 4705 '-4713' 8 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4596'-4658' ' 4041""4091' - . '-8 ~' ' ~ ': :'"'4'798,-4818, & 100 SXs CL "G" 5330'-5345' 4618 '-4629' 8 '4775 '-4790' 5320'-5327' 4610'-4616' 8 f -' : .~ . : , .- · . --, ,~ ': ~ , '_ :. , . , . 27. ' .. '.,'iE~ODuCT-I'0N TEST- ' .. .. Date Eirst Production I Method o¢ Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-DEL AA~;~I~5% WATER-DEL CHOKE SIZE GAS-OIL RATIO 3-14-82 .. 24 TEST PERIOD. . I~ - Flow Tubing. Casing Pr~essure' CALCULATED oiL-I~BL ". G.~'~Cb WATER-BEE OIL GRAVITY-APl (corr) Press. 800 . 24-HOUR RATE I~' · . .-11000 ~' ' 28. ' ' ....... "' 'C0Ri= DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. ~one ' '":/:" ~ska 0;1 &_ Gas Cons. Commissior~ ~Pt~hnr~nn Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/Sterling Fro. Gas Sands 4160' 3684' 5298'-5314', 760 psi surface pressure, 9.83 MMCFD, 6 hr. Test. T/Beluga Fm. 5572' 4801' Added 5539'-5550' and 5445'-5455', 800 psi surface pressure, 8.89 MMCFD, 4 hr. test. 4798'-4818', Open to atmosphere, 100 MCFD, 4 hr. test. 4775'-4790', Open to atmosphere, 100 MCFD, 4 hr. test. 4596'-4658', 900 psi surface pressure, 8.31 MMCFD, 8 hr. test 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /' ! ;__ "' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands' and leases in Alaska. Item 1' Classification o_f Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ~:orm ~ 0-40 / :' TUBING DETAIL: LONG STRING: 1. 3 1/2" Otis XA Sleeve - 4464' 2. Dual 3 1/2" A-5 pkr - 4498' 3. 3 1/2" Blast Jts 4581-4669.' 4. 3 1/2" Otis XA Sleeve ~ 4681' 5. Locator - 4696' 6. Model "D" pkr - 4700' 7. Seal Assembly - 4696-4707' 8. Locator - turned down - 5212' 9. Model "D" pkr- 5220' 10. Seal Assembly 5212-5228' 11. 3 1/2" Otis "X" nipple - 5228' 12. Wireline Guide - 5250' 13 3/8"'C. 2020' SHORT STRING: A'. 3 1/2" Otis XA Sleeve - 4457' B..~3 1/2" Otis XN Nipple - 4514' SHORT STRING B-3 sds 4596-4658' B-4 sds 4775-4790' 4798-4818' LONG STRING C-1 sds 5298-5314' C-2 sds 5320-5327' 5330-5345' 5445-5455' 5539-5550' ETD 5580' 9 5/8" C. 5695' DAT~. KENAI UNIT #14-32 Spud: 2/16/82 Completed: 3/14/82 UNION OIL COMPANY OF' CALIFOt'~NIA CLOD. ~ ^~'~' -N~A o^~ 1/5/83 UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Kenai Unit WELL NO. KU #14-32 FIELD Kenai Gas Field LOCATION: 740'N & 1759'W of SE corner~ Sec. 31~ T5N~ RllW, SM. SPUD DATE 2/16/82 CONTRACTOR Brinkerhoff TYRE UNIT Oilwell 96 SHEET A ~ PAGE NO... ~. .. ~ COMP. DATE 3/14/82 RIG NO. 59 DRILL RIPE DESCRIPTION 5" IF / 3 1/2" IF PERMIT NO. 82-15 TD 5700' MD DEVIATION (BHL) COMPANY ENGINEER Graham - McGee ELEVATIONS: WATER DEPTH SERIAL NO. A-028055 RT TO OCEAN FLOOR TVD 4897' - RT TO GL 26' R~.O DRIL~J~CK RT TO P~O~FTIO~C~Kj. . APPROVE~~/. ~~./j/~ CASING & TUBING~XRECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Butt. 13 3/8" 61# Butt Plain 106' Driven K-55 2020' i000 sxs el "G" cmt. 9 5/8" 47# Butt N-80 5695' 1380 sxs ol "G" cmt w/ 4% gel, , 3" 1/2 L~' ' 9.3# BUtt N-80 5250' 3 1/2 SS 9.3# Butt N-80 4514' ,5% A-5~,1% D-19~ 0.2%b-(~ Bkr pkr "A-5" ~ 4498.45' · Bkr pkr "A-5" @ 4502.01' PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 3/7/82 4798-4818' 5200' DST #2 2.1/8" enerjet guns B-4 sds 8 HPF 2 1/8" enerjet guns C-1 sds 8 HPF 3/5/82 5298-5314' 5580' DST #1 " 5539-5550' " C-2 3/8/82 4596-4658' 4724' DST #3 8-3 sds 8 HPF 3/10/82 4775-4790' 5580' B-4 sds Dry, Test 5445-5455' C-2 sds 8 HPF 5330-5345' 8 HPF 5320-5327' 8 HPF INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 3/14/82 SS 800 5.5 LS 800 10.0 WELL HEAD ASSEMBLY ~YPE: Cameron Iron Works CASING HEAD: 12" 3M x 13 3/8" SOW CASING SPOOL: TUBING HEAD: 12" 3M x 10" 5M DCB TUBING HANGER: TUBING HEAD TOP: Dual 3 1/2" MASTER VALVES: CHRISTMAS TREE TOP CONN: 3 1/2" EUE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETO ~, DETAILS'OF OPERATIONS, DESCRIPTIONS & RESULTS A 2/~/82 DAILY COST: ACC COST: AFE AMT: B 2/i0/82 DAILY COST: ACC-COST: AFE AMT: C 2/11/82 DAILY COST: ACC COST: · AFE AMT: D 2/12/82 DAILY COST: ACC COST: AFE AMT: E 2/13/82 DAILY COST: ACC COST: AFE AMT: F 2/14/82 DAILY COST: ACC COST: AFE AMT: G 2/15/82 DAILY COST: ACC COST: AFE AMT: $ 151,198 $ 151,198 $2,100:,000 20,543 171,741 $2,100,000 $ 14,839 $ 186,580 $2,100,000 $ 22,193 $ 208,773 $2,100,000 $ 23,376 $ 232,149 $2,100,000 20" D.106' $ 42,574 $ 274,723 $2,100,000 20" D~. 106' $ 20,555 $ 295,278 $2,100,000 COmmenced operations .~ 00:01 hrs .2/9/82. Set in subbases & drill floor. Set in FRS unit. Set der- 'rick on stand. Set OCT BRV's in KDU #5. Strung blocks & fabricated steam & blew down lines. General RU. Continued fabricating steam & blow down lines. Discontinued RU while repairing bearing on drum shaft in drawworks. Set in drawworks, upper doghouse, 3 engines, 2 mud pumps & mud tanks. Continued general RU. Set in support bldgs. RU BO cmtg equip. Raised derrick & continued general RU. RU & drove 20" 94# plain end drive pipe to refusal w/ 250 BPF e 106' (70' of soil. penetration). Continued to rig up - installed pump lines, windwalls, and drill floor. Cut off 20" drive pipe & welded on 20" 2000 psi X 20" SOW csg headw/ flange face ~ GL. Installed 20" Hy- dril w/ diverter valve & flow lines. Rulled BRV's from KDU #5. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. ~KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 2/16/82 DAILY COST: ACC COST: AFE AMT: 2 2/17/82 278'/192' 20" D. 105' 68 PCF 67 SEC $ 41,770 $ 337,048 $2,100,000 298'/0' 20" D. 106' 68 PCF 86 SEC DAILY COST: · $ 26,197 ACC COST: $ 363,245 AFE AMT: $2,100,000 3 2/18/82 460'/162' 20" D. 106' 68 PCF 146 SEC DAILY COST: ACC COST: AFE AMT: 4 2/19/82 DALLY COST: ACC COST: AFE AMT: $ 55,209 $ 418,454 $2,100,000 1134'/674' 20" D. 106' 67 PCF 75 SEC $ 28,523 $ 446,977 $2,100,000 Completed RU. Spudded well w/ 17 1/2" bit thru 20" drive pipe ® 17:30 hrs 2/16/82. CO drive pipe to 106' & drld 17 1/2" hole f/ 106' to 298'. Took drift surveys ® shoe of drive pipe - 1/4° & btm hole 1/4°. Circ & POOH. RIH w/ bit #2 on BHA #2 for Dyne drl run #1. RIH w/ steering tool & oriented dyne drl. Lost bearing on low drum clutch on drawworks. Pulled up into 20" conductor & repaired drawworks. Completed repairs on drawworks ~ 18:00 hrs. RIH w/ dyne drl. RU steering tool & oriented dyna-drl. Dir drld 17 1/2" hole f/ 298' to 460'. Continued to dyna-drl 17 1/2" hole f/ 460' to 825'. POOH. RIH w/ bit #3 on BHA #3 (30' belly). Reamed f/ 298' to 825'. Dir drld 17 1/2" hole f/ 825' to 1134'. Surveys: 891' 18° N74E 983' 20° N75E 1105' 22° 30' N75E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 2/20/82 DAILY COST: ACC COST: AFE AMT: 2/21/82 DAILY COST: ACC COST: AFE AMT: 7 2/22/82 DAILY COST: ACC COST: 2022'/888' 20" D. 106' 69 PCF 70 SEC $ 35,507 $ 482,484 $2,100,000 2022'/0' 20" D. 106' 13 3/8" C. 2020' 68 PCF 55 SEC $ 133,481 $ 615,765 $2,100,000 2022'/0' 20" D. 106' 13 3/8" C. 2020' 67 PCF 40 SEC $ 31,463 $ 647,228 Dir drld 17 1/2" hole f/ 1134' to 1438'. Trip for BHA change. RIH w/ bit #3RR on BHA #4 (locked up) & dir drld 17 '1/2" hole f/ 1438' to 2022'. C&C mud. Surveys: 1257' 28° N77E 1410' 35° N77E 1522' 34° 30' N78E 1738' 34° N79E 1924' 34° N79E POOH to run 13 3/8" csg. RU & ran 50 jts (2022.08') of 13 3/8" 61# K-55 buttress csg fitted w/ FS & stab-in FC. Set shoe ~ 2020' w/ FC ~ 1976'. Set plate & bowl on top of 13 3/8" csg & RIH w/ stab-in tool on 5" DR. Stabbed into FC ~ 1976' & broke circ. Pumped 40 bbls of caustic water ahead of 750 sxs of cl "G" w/ 10% gel & 2% CaCL2 followed by 250 sxs el "G" w/ 2% CaCL2. Displ cmt to 250' above FC. CIP ~ 17:07 hrs. POOH w/ DR. Removed Hydril. Cut off 13 3/8" ldg jr. Installed 12" 3M X 13 3/8" SOW CIW csg head. Installed 13 5/8" 5M BOPE to 3000 psi. AFE AMT: $2,100,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS' OF OPERATIONS, DESCRIPTIONS & RESULTS 2/23/82 3355'/1333' 20" D. 106' 13 3/8" C. 2020' 67 PCF 52 SEC DAILY COST: ACC COST: $ 45,885 $ 693,113 AFE AMT: $2,100,000 2/24/82 DAILY COST' ACC COST: AFE AMT: 10 2/25/82' DAILY COST: ACC COST: AFE AMT: 3985'/632' 20" D. 106' 13 3/8" C. 2020' 70 PCF 57 SEC $ 41,245 $ 734,358 $2,100,000 5022'/1037' 20" D. 106' 13 3/8" C. 2020' 73 PCF 74 SEC $ 34,562 $ 768,920 $2,100,000 Compl testing BOPE - testing WAA by Bill Hauser - USGS. RIH w/ 12 1/4" bit on BHA #5 (slick assy). CO FC¢ 1976' & cmt to 2010'. Press tested csg to 2500 psi - ok. Drld out FS $ 2020' & drld 10' of new hole f/ 2022 to 2032'. Pulled into shoe & per- formed leakoff test - shoe held 95 pcf mud equiv (380 psi). POOH & LD S-135 DR. RIH w/ bit #4 RR #1 on BHA #5 (locked up assy) while PU grade "E" DR. Dir drld 12 1/4" hole f/ 2032' to 3355'. Surveys: 2233' 33° N80E 2540' 31° 45' N82E 2847' 31° 30' N84E 3123' 31° N84E Dir drld 12 1/4" hole f/ 3355' to 3508'. POOH - hole was tight f/ , 2850 to 2100 . RIH w/ bit #5 on ! BHA #7 (30 belly). Dir drld 12 1/4 hole f/ 3508' to 3985'. Made short trip to csg shoe - hole tight f/ 3875' to 3040'. Incr MW to 70 pcf. RIH - trip was good. RIH after short trip. Dir drld 12 1/4" hole f/ 3985' to 4381'. Made 13 std short trip - trip slightly ragged. Dir drld 12 1/4" hole f/ 4381' to 4626'. Trip for bit change - trip out was slightly ragged. Trip in hole was tight @ 4260'. Dir drld 12 1/4" hole f/ 4626' to 5022'. Surveys: 3423' 30° N85E 3561' 30° 30' N85E 3745' 31° 30' N87E 3929' 32° N87E 4113' 33° N87E 4326' 34° 30' N88E 4540' 35° 30' N89E 4844' 36° 45' N89E 5153' 39° S89E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 'WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 2/26/82 DAILY COST: ACC COST: AFE AMT: 12 2/27/82 DAILY COST: ACC COST: AFE AMT: 13 2/28/82 DAILY COST: ACC COST: AFE AMT: 14 3/1/82 DAILY COST: ACC COST: 5700'/678' 20" D. 106' 13 3/8" C. 2020' 72 PCF 57 SEC $ 37,799 $ 806,719 $2,100,000 5700' TD 20" D. 106' 13 3/8" C. 2020' 72 PCF 59 SEC $ 82,030 $ 888,749 $2,100,000 5700' TD 5510' ETD (FC) 13 3/8" C. 2020' 9 5/8" C. 5595' 72 PCF 51 SEC $ 362,309 $1,251,058 $2,100,000 5700' TD 5610' ETD (FC) 13 3/8" C. 2020' 9 5/8" C. 5695' 72 PCF 50 SEC $ 36,535 $1,287,593 Dir drld 12 1/4" hole f/ 5022' to 5207'. Made short trip - 1st 8 stds were ragged. Dir drld 12 1/4" hole f/ 5207' to '5576'. Trip for bit change. RIH w/ bit #6 on BHA #7 & dir drld 12 1/4" hole f/ 5576' to 5700'.. C&C hole for logs. Circ & made short trip to shoe - ok. Circ & POOH. RU Schlum & ran DIL- Sonic & FDC-CNL-GR logs f/ 5700' to shoe of surf pipe. RD Schlum. RIH W/ BIT #6PR &circ hole clean. Circ clean & POOH. RU to run 9 5/8" csg. Ran 136 jts (5698.93') of 9 5/8" 47# N-80 butt csg w/ shoe ~ 5695' FC ~ 5610' Circ & pumped 20 , bbls of mud sweep ahead of 630 sxs cl "G" w/ 4% gel, 5% A-5, 1% D-19, .2% D-31, .3% A-2, .3% D-6 & 750 sxs cl "G" w/ 5% A-5, .8% D-19, 1% D-31, .5% A-2, .3% D-6 while reciprocat- ing the csg. Displ cmt w/ 419 bbls of mud.to bump plug on FC w/ 2200 psi. CIP ~ 23:05 hrs 2/28/82. Removed BOPE. Landed csg on slips w/ 225M#. Installed & tested DCB spool. Landed & tested BOP stack. LB 12 1/4" drlg assy. RIH w/ 8 1/2" bit & 6 1/4" DC's & tagged cmt ~ 5602'. CO to 5610'. Circ clean & POOH. AFE AMT: $2,100,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 3/2/82 DAILY COST: ACC COST: AFE AMT: 16 3/3/82 DALLY COST: ACC COST: AFE AMT: 17 3/4/82 DAILY COST: ACC COST: 5700 ' TD 5610' ETD (FC) 13 3/8" C. 2020' 9 5/8" C. 5695' 71 PCF 42 SEC $ 39,330 $1,326,923 $2,100,000 5700' TD 5580' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' 71PCF 42 SEC $ 35,934 $1,362,857 $2,100,000 5700' TD 5580' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' 63 PCF KCL FLUID $ 35,927 $1,398,784 Attempted to run DA CBL-VDL-GR log. Changed out recorder, logging tool, & panel & could not get a satisfac- tory log. RD DA. RU Schlum & ran CBL-VDL-GR log f/ 5610' to 1500'. RU Sperry Sun on Schlum & ran gyro survey. Completed running gyro survey f/ 5610' to surf. RIH w/ 8 1/2" bit & tagged FC ~ 5610' Attempted to test csg to 5000 ps~ - would not test. POOH. RIH w/ 9 5/8" RTTS pkr & set ~ 2800' Press up to 2000 psi - bled to' 1506 psi. Reset RTTS ¢ 4298' & press up to 2000 psi - bled to 1500 psi. Reset RTTS ~ 4905' & press up to 2000 psi - bled to 1200 psi. Discovered & repaired leak in surf line. Reset RTTS ® 5300' pumped in 2 BRM ~ 1800 psi. Reset RTTS ¢ 5600' & pumped in w i BRM 1800 psi. POOH. RIH & set cmt ret ~ 5580'. Mized & sqz'd w/ 150 sxs cl "G" w/ 30 gal/lO0 sxs D-45L, 4 gal/lO0 sxs R-12L, 2 gal/lO0 sxs D-6L. Displ 125 sxs below ret. CIP 8 19:00 hrs. POOH w/ DP. LD HWDP. Installed 3 1/2" rams & RIH w/ 8 1/2" bit on 9 5/8" csg scrpr while RU 3 1/2" DR. Circ & tested csg to 5000 psi - ok. Dumped & cleaned mud tanks. Mixed & chgd hole over to 3% KCL fluid. POOH w/ DR. RIH w/ 60' tbg tail & RTTS pkr on 3 1/2" DR. RU Howco test head. AFE AMT: $2,100,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE' ETD DETAILS OF'OPERATIONS, DESCRIPTIONS & RESULTS 18 3/5/82 DAILY COST: ACC COST:' AFE AMT: 19 3/5/~2 DAILY COST: ACC COST: AFE AMT: 2O 3/7/82 DAILY COST: ACC COST: AFE AMT: 5700 ' TD 5580' ETD (RET) 13 3/8" C, 2020' 9 5/8" C. 5595' 63 PCF 31 SEC $ 28,010 $1,426,794 $2,100,000 5700' TD 5200':ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5595' 63 PCF 31 SEC $ 20,053 $],445,847 $2,100,000 5700 ' TD 5200' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' 63 PCF 31 SEC $ 33,509 $1,480,455 $2,100,000 Tested surf lines to 2000 psi. Displ DP w/ N2. Set RTTS ~ 5190', tail ~ 5250'. Tested lub to 2000 psi. Bled DP press to 550 psi & RIH w/ 2 1/8" enerjet perf guns. Perfed C-1 sand f/ 5298' to 5314' DIL for DST #1. Flowed well for 6 hrs. Had a stabilized rate of 9.83 MMCFD ~ 750 psi. Shut well in & perfed C-2 sd f/ 5539' to 5550' DIL & 5445' to 5455' DIL. Opened well to test. Continued to flow test the C-1 & C-2 sds - had a stabilized rate of 8.89 MMCFD ® 800 psi. Released pkr & rev clean. RIH to 5570' &ciro clean. POOH. RIH w/ cmt ret on WL & set ret ~ 5200'. Setting sleeve would not shear. Pulled out of rope socket & RD Schlum. RIH w/ OS & oil jars & latched onto setting tool. POOH & rec setting tool. RIH w/ test tools. Displ DP w/ N2 & set RTTS @ 4624', tail ~ 4586'. Bled press to 575 psi. RIH w/ 2 1/8" enerjet perf guns & perfed upper part of lower lobe of B-4 sd f/ 4798' to 4818' DIL for DST #2. Opened well to flow - had 0 psi flowing press w/ a small flame. RIH w/ HR press recorder on WL & checked shut-in press. BH press incr f/ 772.2 psi to 789.3 psi in 2 hrs. POOH w/ recorder. Reperfed B-4 sd f/ 4798' to 4818' DIL - had no press incr& no flow. Rerfed upper B-4 f/ 4775' to 4790' DIL. Press incr to 150 psi while POOH guns. Opened well & flowed ~ 100 MCFD w/ a 2" stream of water. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO.' LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 21 3/8/82 DAILY COST: ACC COST: AFE AMT: 5700' TD 4724' ETD (RET) 13 3/8" C. 2020' 9:5/8" C. 5695' 63 PCF 30 SEC $ 74,861 $1,555,317 $2,100,000 22 3/9/82 5700' TD 5200' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' 63 PCF 30 SEC DAILY COST: $ 27,064 ACC COST: $1,582,381 AFE AMT: $2,100,000 23 3/10/82 5700' TD 5580' ETD (RET.) 13 3/8" C. 2020' 9 5/8" C. 5695' 63 PCF 30 SEC. DAILY COST: $42,183 ACC. COST: $1,624,564 Continued to rev circ to kill well. Hole was taking fluid. Spotted 35 bbl pill of safe-seal. POOH. RIH & set cmt ret'~ 4724'. Pumped into form w/ 7.5 BPM ~ 1200 psi. Pumped 20 bbls H20 followed by 100 sxs cl ',G" w/ 30 gal/lO0 sxs D-45L, 4 gal/- lO0 sxs R-12L, 2 gal/lO0 sxs D-6L ~ a rate of 6 BPM ® 900 psi. Had a final pressure of 1800 psi. CIP ~ 07:00 hrs. Rev out 20 sxs cmt. POOH. RIH w/ test tools & tested lines to 2000 psi. Displ DP W/ N2 & set RTTS ~ 4498', tail ® 4559'. Tested lub & RIH w/ 2 1/8" perf gun. Bled press to 575 psi & perfed B-3 sds f/ 4596' to 4658' DIL for DST #3. Opened well to flare - had rate of 8.15 MMCFD ~ 900 psi w/ 2 BWRD. Continued to flow test B-3 perfs f/ 4596' to 4658'. Had final rate of 8.31MMCFD ~ 900 psi w/ no water. Released RTTS & rev circ to kill well. RIH to 4680' &circ clean. POOH. Tested BOPE. RIH w/ 8 1/2" bit & drld ret ® 4724'. CO cmt stringers to 5200'. Ciro & POOH. RIH w/ 8 1/2" bit on 9 5/8" csg scraper.to 5200' & cite clean. Circ. clean and POOH. RIH w/ RTTS on DP. Displaced DP w/N2. Set RTTS ® 4682'. Bled off nitrogen to dry test B-4 perfs F/ 4775' to 4790' and 4798' to 4818' DIL-OK. POOH. RIH w/ 8 1/2" bit and junk subs and drilled RET. ~ 5200'. RIH to 5580' and circ clean. POOH. RU Schlum & reperfed B-3 sd f/ 4596' to 4658' DIL'w/ 4" csg guns (had i misrun). AFE AMT: $2,100,000 ' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 3/11/82 DALLY COST:. ACC COST: AFE AMT' 5700' TD 5580' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' PKRFLUID $ 148,608 $1,673'172- $3,000,000 Comp RD Schlum. RIH w/ 8 1/2" bit on 9 5/8" csg scrpr to 5580'. Ciro clean & POOH LD 3 1/2" DP. RU Schlum &'RIH w/ 8 1/2" GR & JB to 5300'. POOH. RIH w/ 9 5/8" model "D" pkr & set ~ 5220' DIL. RD Schlum. RIH w/ seals on 5" DP & tested pkr to 350 psi - ok. Pulled out of pkr & changed hole over to pkr fluid f/ 5220' to surf. POOH. RU Schlum & RIH w/ 9 5/8" model "D" pkr & set ~ 4700' DIL. POOH w/ WL.. RD Schlum. RIH w/ seals on 5" DP & tested pkr to 350 psi - ok. POOH LD 5" DP. NOW: LD 5" DP. 25 3/12/82 DALLY COST: ACC COST: AFE AMT: 26 3/13/82 DAILY COST' ACC COST' AFE AMT' 5700' TD 5580' ETD (RET) 13 3/8" C, 2020' 9 5/8" C. 5695' PKR FLUID $ 199,121 $1,872,293 $2,100,000 5700' TD 5580' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' PKR FLUID $ 51,004 $1,923,297 $2,100,000 Completed LD 5" DP. Pulled wear bushing & installed dual 3 1/2" rams. RU & ran dual 3 1/2" comp string w/ LS tail ~ 5249', SS tail 4514' & dual "A-5" pkr ~ 4502'. Tested model "D" pkr - ok. Set plug in "XN" nipple in SS ~ 4513'. Set "A-5" pkr & pulled plug. Tested pkr -ok. Installed BPV's. Removed BOP stack & installed & tested CIW tree. Pulled BPV's. Opened "XA" sleeve in LS @ 4680' & displ down LS & up SS w/ N2. Flowed SS until clean. SI & closed "XA" sleeve in LS. Flowed LS to clean up. RU Schlum & perfed C-2 sds f/ 5539' to 5550' DIL & 5445' to 5455' DIL w/ 4-1/2" HPF. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 10 LEASE 028055 WELL NO. KU #14-32 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 27 3/14/82 DAILY COST: ACC COST: AFE COST: 28 3/15/82 DAILY. COST: ACC COST: AFE AMT: 5700' TD 5580' ETD (RET) 13 3/8" C. 2020' 9 5/8" C. 5695' PKR Fluid $ 57,645 $1,980,942 $2,100,000 5700' TD 5880' ETD (ret) 13 3/8" C. 2020' 9 5/8" C 5695' $ 30,151 $2,011,093 $2,100,000 Perfed C-1 sds f/ 5330' to 5345' DIL & f/ 5320' to 5327' DIL w/ 8-1/2" HPF & reperfed f/ 5298' to 5314' DIL w/ 4-1/2" HPF. RD Schlumberger. Tested LS-had final rate of 8.81 MMCF/D ~ 770 PSI. Put SS into test meter-had rate of 5.8 MMCF/D ~ 770 PSI. Installed BPV's. Released rig to move rate ~ 09:00 Hrs. Removed wind walls and laid down derrick. Completed rig down. Re-leveled location. Released rig to KDU #5 at 24:00 Hrs. 3/15/82. UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Kenai Unit WELL NO. KU #14-32 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD ' DETAILS'OF OPERATIONS, DESCRIPTIONS & RESULTS : . 20" CASING DETAIL OTS DESCRIPTION LENGTH BTM TOP 3TS 20" 94# Plain end 20" Cut-off 20" 2M x 20" SOW osg head Face of flange at ground level DESCRIPTION 13 3/8" CASING DETAIL 118.00' 39.00' 1.00' LENGTH BTM 106.00' 27.00' 27.00' -12.00' below RT 26.00' TOP 49 B&W Float Shoe 13 3/8" 61# K-55 Butt Csg B&W Float Collar 13 3/8" 61# K-55 Butt Csg 13 3/8" Cut-off 12" 3M x 13 3/8" SOW osg head !.85' 39.71 ' 2.10' 1978.51 ' 30.17' 1.40' 2020.00' 2018.15' 1978.44' 1976.34' 28.00' 28.00' 2018.15' 1978.44' 1976.34' -2.17' below RT 26.60' Face of 12" 3M flange = 26.60' below RT UNION OIL COMPANY OFCALIFORNIA WELL RECORD LEASE Kenai unit WELL NO. KU-#14-32 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 5/8" CASING DETAIL JTS DESCRIPTION LENGTH BTM 12 2 12 12 B&W Float Shoe 9 5/8" 47# N-80 Butt Csg B&W Float Collar 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg ~9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" Butt Pup 9 5/8" 47# N-80 Butt Csg 9 5/8" 47# N-80 Butt Csg 9 5/8" Cut-off 12" 3M x 1~' 5M Csg Spool 94 1 TOP 1.57' 5695.00' 5693.43' 81.46' 5693.43' 5611.97' 1.58' 5611.97' 5610.39' 487.67' 5610.39' 5122.72' 24.60' 5122.72' 5098.12' 505.53' 5098.12' 4592.59' 15.02' 4592.59' 4577.57' 515.53' 4577.57' 4062.04' 19.80' 4062.04' 4042.24' 4002.61' 4042.24' 39.63' 41.11' 39.63' -1.48' 27.77' 1.93' 26.29' below RT 26.60' 24.67' Face of 10" 5M flange 24 67' below RT. Form D-lOO1-C LEASE Kenai Unit COMPLETION DATE 3/14/82 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET C PAGE NO. 1 WELL NO. KU #14-32 FIELD Kenai Gas Field APPROVED DATE E.T.D. STS DESCRIPTION DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS TUBING DETAIL - LONG STRING LENGTH BTM TOP 16 12 Baker Wireline Guide 3 1/2" 9.2# N-80 Butt Pups (2) 3 1/2" Otis "X" Nipple Baker Seal Assembly (w/ small locator) Baker 9 5/8" model "D" pkr 8 5220' 3 1/2" Butt .Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup Baker Seal Assembly Baker 9 5/8" model "D" pkr ~ 4700' 3 1/2" Butt Pups (2) 3 1/2" Otis "XA" Sleeve 3 1/2" Butt Pups (2) 4 1/2" OD Blast Joints 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pups (2) 9 5/8" x 3 1/2" x 3 1/2" Baker A-5 pkr 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Otis "XA" Sleeve 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) · 66' 5250.00' 5249.34' 19.83' 5249.34' 5229.51' 1.51' 5229.51' 5228.00' 16.50' 5228.00' 5211.50' 5.24' 5211.50' 5206.26' 492.96' 5206.26' 4713.30' 6.14' 4713.30' 4707.16' il.dO' d707.16' 4695.76' 11.33' 4695.76' 3.90' 4684.43' 11.38' 4680.53' 88.17' 4669.15' g0.35' 4580.98' 9.32' 4520.63' 12.86' 4511.31' 30.97' 4498.45' 3.90' 4467.48' 5.89' 4463.58' 368.09' 4457.69' 3.10' 4089.60' 119.64' 4086.50' 6.20' 3966.86' 122.58' 3960.66' 6.10' 3838.08' 4684.43' 4680.53' 4699.15' 4580.98' 4520.63' 4511.31' 4498.45' 4467.48' 4463.58' 4457.69' 4089.60' 4086.50' 3966.86' 3960.66' 3838.08' 3831.98' Form D-lOO1-C LEASE Kenai Unit COMPLETION DATE 3/14/82 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET C PAGE NO. 2 WELL NO. KU #14-32 FIELD Kenai Gas Field APPROVED DATE E.T.D. DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS OTS ~ DESCRIPTION ,, TUBING DETAIL - LONG STRING LENGTH BTM TOP 12 25 51 35 3 1/2" 9.2# N-80 Butt Tbg 3 t/2" Butt'Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt x .3 1/2" 8rd xo Tbg Hanger Landed below KB 368.54' 3831.98' 3463.44' 3.05' 3463.44' 3460.39' 794.44' 3460.39' 2665.95' 6.20' 2665.95' 2659.75' 1561.04' 2659.75' 1098.71' 4.15' 1098.71' 1094.56' 1068.48' 1094.56' 26.08' .65' 26.08' 25.43' .93' 25.43' 24.50' 24.50' 24.50' 0 Form D-lOO1-C LEASE Kenai Unit COMPLETION DATE 3/14/82 UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET C PAGE NO. 3 WELL NO. KU #14-32 FIELD Kenai Gas Field APPROVED DATE E.T.D. JTS DESCRIPTION DETAILS OF OPERATIONS~ DESCRIPTIONS & RESULTS TUBING DETAIL - SHORT STRING LENGTH BTM TOP 35 27 2O 15 19 3 1/2" Otis "XN" Nipple 9 5/8" x 3 1/2" "A-5" pkr 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" Otis :'XA" Sleeve 3-1/2" 9.2# N-80.Butt Tbg 3 1/2" Butt PUp 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt PUp (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt Pup (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt 'PUp (1) 3 1/2" 9.2# N-80 Butt Tbg 3 1/2" Butt x 3 1/2" 8rd xo Tbg Hanger Landed below KB 1.66' 4514.39' 4512.73' 10.72 ' 4512.73 ' 4502. O1 ' 6.12' 4502.01' 4495.89' 31.90' 4495.89' 4463.99' 3.18' 4463.99' 4460.81' 3.90' 4460.81' 4456.91' 1077.52' 4456.91' 33?9.39' 6.10' 3379.39' 3373.29' 830.22' 3373.29' 2543.07' 3.02' 2543.07' 2540.05' 155.07' 2540.05' 2384.98' 5.17' 2384.98' 2379.81' 89.88' 2379.81' 2289.93' 5.15' 2289.93' 2284.78' 615.49' 2284.78' 1669.29' 5.12' 1669.29' 1664.17' 180.58' 1664.17' 1483.59' 5.20' 1483.59' 1478.39' 182.79' 1478.39' 1295.60' 4.10' 1295.60' 1291.50' 465.76' 1291.50' 825.74' 4.05' 825.74' 821.69' 580.94' 821.69' 240.75' 4.25' 240.75' 236.50' 210.38' 236.50' 26.12' · 69' 26.12' 25.43' · 93' 25.43' 24.50' 24.50' 24'50' 0 March 4, 1982 Mr. Gary Bush Union Oil Company P. O. Box 6247 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16978 Well:' KU-14-32 (SEC31 T5N RllW). Kenai Gas Field Kenai, Alaska Survey Date: March 2, 1982 Operator: John Samec Dear Mr. Bush: Please find enclosed the "Original" and seven (7) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us ~this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager KB/pr EnclosUres APR 2 6 i982 0]1 & Gao Cons, ~.,PERRY-._LIN WELL .:,URVEYINE.; COMPANY F'AGE ANCHORAGE ALASKA i_IN I ON O I L CCI · OF CA L I ic ................. I<U 14-32 (SEC: 31 T5N R11W) L-:OMF'I_iTATION ELATE I<ENA I GA'S F I ELD MARCH 4., 1'---"=:'-':".. ,. ~ ALAF:KA VERTIC:AL 'SECTIEIN F:ALC:ULATED ALONG AZIMUTH OF 80.00 DEGREES ELATE.. OF SURVEY_. MARCH.. 2,. 17/82 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-1 KELLY BUSHING ELEV. = '38.¢)0 FT. OPERATOR-SAMEC TRUE .:,LIB-.:,EA I]:IiiI_IRSE I..UI. RoE MEAL=;URED VERTIE:AL VERTICAL INCLINATION DIRECTION 'SEVERITY DEF'TH DEPTH DEPTH DEB M I N DEGREES [lEG/106) TOTAL REL. TANI3L I_AR COFIRD I NATES VERT I C:P~ NARTH/SOLITH ..... E~ST./WEST ....... SEC:T I~ ] 0 O. O0 1 O0 100. O0 200 1 ?F/. ':-/9 300 299. ::,9 400 397. :B'?/ 500 4.'?':.-', 52 600 598.70 700 697.07 800 794.35 .c.'OC) 890.45 1000 985.35 1100 1 (.')78.73 1200 1169.84 1300 1258.05 1400 1342.97 1500 1425.67 1600 1508.05 1700 15'.-.? 0 · 93 1800 1674.08 1700 1757.30 2000 1840.87 2100 1725.11 2200 200'?. 79 2800 2094.53 2400 2179.45 2500 2264.6? 2600 2350.21 2700 2435.80 2800 2521,3? 2'..~00 2607.00 ~,.:,. (') 0 0 0 · 2, 00 0 ":' ,.,4 101. 'B'? 0 7 · -' ') ¢, 9 ~':' · .'(. i 0 3C) 1 :=:9 "-' · .. .:, 46 401 52 500.70 8 4 5?'9.07 11 55 ,-? :2::$ 6; 6. 14 4::: 792.45 17 16 :--:87. :A: '? '-': . ._, i ...._, ,. '780 73 c,.~, .-.,/. 1071. :--:4 26 11 1160. O.S. _ 2'.;' .~':',_, 1244. '?7 33 43 1327.67 34 41 1410.05 34 22 ..... · -::: 4.0 14.92 '~3 3J 1576.08 33 48 1AS'B 30 32 2:1 -- · '..~ ....... 1742 87 1827.11 32 7 1911.7'::' 32 8 __ I c.' 9/_-,. 53 32 0 2081.45 31 45 2166.69 _ 31 18 ..... 2252, 21 31 7 232:7.80 31 10 2423.39 31 _ 5 ~,0 .-.'. 00. 31 N 0. 0 E 0.0C) 0.00 0·00 ,:,,=,. :i:'.~' E 0,.., '=''',=, ('). 01 S C). 51 E N '-" .=,,' . 7.:,.,..(.) E 0 46 C).00 N 1 12 E N :-':7. ,..,C) E 0.85 0 ..07 N ':: )"' 2.£o E N 7:--:, 19 E 2,81 . O, 7.8. N ..........'{' 1/.-, .E ..... N 76. I0 E 2.21 2.68 N 14.:2:4 E N 69,50 E '2.'''~' 26 · .':~,::, 6.57 N .41 E N 71.. /=,9. ................. E ..:,,'-' 22.. c ....... 1.2..¢8._N ............ .43.,_34. E .... N 72, 50 E 2 · 8C-: 1':':),. 56 N A='. ,..,, 34 E N 75.17'/ E .,..'-' · .=,9_. 27.20 N 91 . ,=,'-"--',=, E N 74 '~" '-"=' '-'=' · ,=,(.) E 2, 15 _....:,.., · ...:.,._, N .122 .. 2.'.~_ E . _ N 75, 60 E 3, 02 44.46 N 156.84 E N 76 o,::, E 2 '-" ,=,0 54 ':'"' · ..--.,.:; N 1 ':76 E . 84 .' 0.0() C). 50 1. 10 2. C)6 · _6. :20 14.59 27.15 44 · ,~, ._l 67.74 95.21 126.57 162 1° · .F'O 3.26 N_.77...10. E ......... N 77.6? E N 78.10 E N 78. '"' · .,:,0.. E .... N 78.6O E N 80.. 0 E N .80. _:2;0_. E .... NS1. OE N 81. 0 E N 81.89 E N 82.19 E N. 82.10 E N.._E:2.. 60 N 82.50 N 83.50 N..84...10 N 83.80 3.78 .......... ~:4..80_ N ......... ..2.42.71, E . :3.76 76.:2:0 N 294.21 E O. '?'F' 88.08 N 349.18 E 0.51', .' ........ /~'~.. 43. N ..... 404.. 72_ E _ 0.70 . 110.39 N 459.59' E 0.7'). 120· 71 N 514.17 E .0.. 3.3_ ......... 1.30.. 19_ N ....... 568.,_77'_. E ....... 0.58 13'~.11 N 622. ?8 E 0.;~6 147.55 N 676.20 E 0.48 ........ 155..45 N ..... 728.80.E_ 0.21 '162.80 N 781.39 E 0.26 170.01 N 833.70 E _ .25C). 2G? 302 ':? '~.. 35'.-.-'. 17 41 ~ '='''~ 471.78 527.32 5E:2.76 6:37.67 691.55 744.72 7?7.78 850..5';5 E .... ' ..... 0,52 176,9..7_ N. oo=: 52 E .902 80 E O. 19 183.6.9 N '~36. '.~0 E .954.56 E O. 52 - 18'~, '.-.v9 N 988.24. E 1006.22 E. .~ O. 32 · .... 1':75, 58 N .... 103'R, 64_E .... 1057.81 E O. 16 201.02 N 10%-., 1.03 E 1107.36 UNION OIL CO. OF CALIF. KU 14-32 (SEC 31T5N RllW) KENAI GAS FIELD ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 4, 1782 VERTICAL SECTION CALCULATED ALONG AZIMUTH OF 80.00 DEGREES TRUE SUB-SEA COURSE COURSE DOG-LEG ,-'Il, ' P .~EVERITY MEAc,.RED VERTICAL VERTI_.AL INC:LINATION DIRECTION '~ ' DEPTH DEPTH DEPTH DEG MIN .... DEGREES_. .BEG/lO0 3000 26?2.73 , 25?4,73 30 3100 2778.75 2680.75 30 3200 2864.8? 2766'8? 30 3300 2951.07 2853.07 30 3400 3037.36 2737.36 30 3500 3123.75 3025.75 30 3600 3207.~1 3111.71 30 3700 3275.61 3177.61 31 3800 3380.?2 3282.~2 31" 3?00 3465.6? 3367.6? 32 4000 354?.?5 3451.75 32 4100 3633.74 3535.74 33 4200 3717.00 3617.00 '33 4300 377~.68 3701.68 34 4400 3881.76 3783.76 35 4500 3?63.32 3865.32 35 4600 ~4044.51 3746.51 35 4700 4125.18 4027.18 36 4800 4205.11 4107.11 37 4?00 4284.52 4186.52 37 5000 4363.21 4265.21 38 5100 4441.1~ 4343.17 38 5200 4518.40 4420.40 3~ 5300 45?4.88 44?6.88 40 5400 4671.00 4573.00 40 5500 4746.58 4648.58 41 5600 4821.80 4723.80 41 5700 48?7.08 47??.08 41 HORIZONTAL DISPLACEMENT = 2677.71 DATE OF SURVEY.-MARCH 2, BOSS GYROSCOPIC SURVEY dOB NUMBER'BOSS-16778 KELLY BUSHING ELEV.~,=. OPERATOR-SAMEC ... I-'AGE . 2.' ~ 1982 F.~8.00 FT. 50 Iq 84.30 28 . N'..,85. 34 N 85.8? 22 N 86.39 20 .... N. 85,60 12 41 23 46 23 52 7 34 51 36 16 35 36 57 54 32 15 _ 10 10 N 87.10 E N 86.89 E . ~N_87.69 E N 88.19 E N 88.50 E N..88.19 E N 87,-80 E N 89.10 .E. _N 88.80 E._. N 8?, 30 E N 89.10 E N .87,37 ..E -. S 89.89 E N 89..~9 E S_ 88..89 ,E .. S 88.60 E S 88.39 E - -S.87.80 E- S 87, 50 E. S.87, OE .. S 85,.89..-E-- - S85. OE S85. OE TOTAL ' RECTANGULAR COORDINATES VERTICAL · i-* ~ .......... " t-o IqORTH/~ LITH EA~TZWE~,Z ..... SECT I ON--. 0.40 206.36 N 1142.24 E 1160.72 0.89 ..... 210..72..N ...1193..04_.E 1211.51 0.10 214.35 N 1243.71E 1262.04 .33 217,76 N 1294.31E 1312..46 .41 ....... 221,.28._N .......... 1344~.72-..E ............ 1362.72 .78 224.49 N 1394.99 E 1412.78 0 .0 0 O. 68 0.56 O. 55 O. 72 0.41 0.66 0.87 0.70 0.63 0.47 .0.32 O, 86 O. 68 O. 80 1.03 227.15 ,.229.57 231.44 N ~32.97 N 234.52 N 236.42 N 237272 N 238.75-N 23?.8? N 240,70 N .-241,--47.N 241,72 N 241,72 N 241,19 N 23?.84 N 0,38' 238,20 1.02 ..... 236,09 0.'45 233,45 0,39 230,34 .... 1.02 .......... 226~28.. 0.60 221.05 0.00 215.32 N 1445.67 E 146:3.15 N ....... 1497.15-E .... 1514.27 1549.29 E 1602.31 E 1656.14 E- 1710.69 E 1766.05 E .. 1822-- 28 :;,.¢. 187'.;'. 40 E 1937.25 E ..,1995.62 E ....... 2054.71 E 2114.80 E · 2175.57 E- 2237.25 E 2277.87 E 2363.35 E 2427.73 E 2492, 50 E .... 2557-, 85.-E ....... 2623.52 E 2687.10 E ............... ....... rs)Oo FEET AT NORTH 85 DEG. 25' MIN. EAST AT M = 1565.~4 1618.43 1671.70 1725.75 1780.54 1836.0'~ 1':'o'-' 5(i) i_, .. ~. 1949 62 2007,23 2065.¢7 2124.65 2184.4I 2244.71 2306.2? 2368.44 2431.38 24?4.63 .2558.28 2622.05 2685.64 UNION OIL C'O. OF CALIF. I<U !4-:'-:2 (S:EC 31 T5N RllW) KENAI LA.:, FIELD ALA..-,KA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MARCH 4, 1982 PAGE ._,'--' · ~ t ,.?/,-,.-, DATE OF SURVEY..MARCH_ :..' ,.lOB NUMBER BOSS-16978 KELLY BUSHING. ELEV = o,-, . .... ; o. 00 FT OF'ERATOR-SAMEC I NTERF'OLATED VALLE;~-, FL R EVEN 1.000 FEET 'OF MEASURED r~EF'TH TRUE SUB-SEA M EA'.3LIRED VERT I C:AL VER'T I CAL DEPTH DEPTH DEPTFI TOTAL RECTANGULAR .. C:OORD I NATES: MD-TVD . NORTH/::,u JTH EAST/WEST DIFFERENCE ..... VERT. I.C:AL CORREOT I ON 0 O. O0 .98.00 .1. 000 985.35 887.35 2000 1:34C). :37 1742.87 3000 2692.75: 2594.73 4000 3549.95 3451.95 5000 4363.21 4265.21 5700 4897.08 4799.08 0.00 ......... O. 00 ........... C). 0(:) ...................................... .:,o.o.., N 1 ~z. 29. E 14.6.5 14 .65 1'"- . .~,:, E 159 1:3 144.47 o;~.11 N 622 ' '" .-, -/. .-.,/. ~:0:,. N .1142 24 E 3C)7 27 .................... 14,~,-14 ........ 25:4. ~'- . ... ..:z N 1656 14 E 450 ('~ 142.78 .~.z,.'.~ c,4 N 2237 · . ~._. E 636.7'.-.? 186. 75: 215 32 N 26.89 10 .E..: ""--' ..,4. .......... ............ ~C)~. '-',":' .1/.'-, 6..13. ................... THE C:ALC:ULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. UNION OIL CO. OF CALIF. KU 14-32 (SEC 31TSN R11W) KENAI GAS FIELD ALASKA :=,F ERRY-.=,UN WELL ._-,LII-~VEY I N_, COMF'ANY "* i --, i'* ANL. HORAE~E ALA.:,KA PAGE 4 ................................ DATE..~OF._SURVE~_MARCH..2,_.1982 COMPUTATION DATE MARCH 4, 1982 dOB NUMBER BOSS-16978 ....... KELLY.BUSHING ELEV._= _.98.00 FT. OPERATOR-SAMEC INTERPOLATED VALllE~ .... FOR .EVENllllOC)..FEET_OF ,-'IoLB=oEA,~' .DEPTH MEASIJRED DEF'TH TRUE VERT I C:AL DEPTH SUB-SEA TOTAL VERTICAL RECTANGIJLAR COORDINATES MD-TVD .. DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE ......... ~ER~.IOAL CORRECTION 0 198 3'..;8 498 599 700 803 907 1013 1120 1231 1346 1466 1587 1708 1828 1948 98.00 198.00 298.00 398,00 498.00 598.00 698.00 798,00 898.00 998,00 1098.00 1198.00 1298.00 1398.00 1498.00 1598,00 1698.00 1798.00 .,98.00 0.00 100.00 200.00 300.00 400.00 500,00 600.00 700,00 800.00 900.00 1000.00 .1100.00 1200.00 1300.00 1400,00 1500.00 1600,00 1700.00 O. 00 ................. O..QO ........ 0.01~'-' 0.49 E 0.00 N 1.12 E 0.07. N ....... 2.05 E 0.76 N 6.04 E -,.'--" 65 N 14.1:~. E 6 .~l ",/. ~4 N ........... -" ~',. 32 E 12.= · _,4 N 43.53 E 19, 85 N 66,'-~-' 2o E 27.80 .. N .......... .94.. 1,5 E 36.54 N 126.68 E 46.46 N 164.7.1 E 57.44..N .... '210.73 E 70.07 N 266. ' U~ E 84.13 N 3:30.44 E 98.10 N ........ 397.97 E. 111.33 N · .'464.21 E 123.49 N : . 529.94 E 1.34.7_0..N ......... 5.9_5, ;34 ..E ...... 1.50 ...80 .... 0.00 ........ : ........................... 0.00 0.00 0.01 0.00 0.01 ..... 0.01 ................. 0.10 0.09 ', 0.47 0.37 1.:9 ...................... o..82 .................. 2.95 1.66 5,78 2,83 9.91 ....................... 4.1.3 .................. 15.44 5.'54 ~' 22.91 7.46 ....... ~3~.56 ................10..65 ..... 48.56 15,'00 68.35 19.79 ........ 8~.82 .................... 21...~% ................... 1'10.50 20.67 130.79 20.29 20...0~ .................. UNION OIL CO. OF C:ALIF· KU 14-32 (SEC: 31 TSN R11W) KENAI GAS FIELD ALAoKA ,.F<c'~'~'c'v-¢'i, ,._, ,, ,. ,.., _.,f ~'~,, WELL c, URVEY I NL'; COMPANY ANC:HORAGE ALASKA L. UMF UTATI ON DATE MARCH 4., 1°'-"-'.'.',=,-'- PAGE 5' DATE OF SURVE¥._.MARCH '~' ~¢/o.-, .. ~. ..L.~ ,_lOB NUMBER BOSS-16.978 KELLY BUoHI .NG._ELE~ ...... _-- OPERA TOR-SAMEC 98.00 FT. INTERPOLATED VALJE.:, FOR EVEN 100 FEET OF .:,,.~-o~-~ MEA'SURED DEPTH TRUE VERT I C:AL I]EF'TH SUB-SEA VERTICAL ..... DEPTH TOTAL REL. TANuLILAR COORDINATES MD-TVB VERTICAL NORTH / ~,oUTH EAST/WEST D I FFERENCE CORRECT I ON 2067 2186 2304 2421 2538 2655 2772 2889 3006 3122 3238 3354 3470 3586 3702 3820 3938 4057 4177 1898.00 1978.00 2098.00 2198.00 2298.00 2398.00 2498.00 2598.00 26~8.00 2798.00 2898.00 2~8.00 3098.00 3198.00 3298.00 3398.00 3498.00 35~8.00 3698.00 1800.00 i900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 144. '"~' ,=,c~ N 659.3'B E 16;"--~. 154.41 Iq 721. 47 E 1~''''o,=,. 0,9 163. '" . . O r7 N 783 54 E 206 10 171 59 N ':'~M 07 E 223 179.~'='~, .... N 905 60 E 240 '" 187 39 N c~/-~ . ~ ~,~,. 52 E 257 . ,=,~'~' 194.13 N .......... 1025. ............... 61 E 274. '*'~' 200· 44 N 1''''~'=,.,c,¢ . 62 E 2S/1 . ~,=,"~' .~, 206.67 N 1145.37 E c,O~,.i4 211 ._o N 1204.o4 E 41~,.75 N 1263.23 E 21.~.54 N 1321.75 E 223.74_.N .......... 1380. O~ E .?, 226.76, N 1438 ~7 E 229.63 N 1498.59 E 231.77 N ........ 1557. S3 E 233.50 N 1622.81 E 235, 53 N ib87.17 E 237.72 .N _._ 1_753·~,0 E ...... 1~.1~ 18.0~ 18.02 17.72 .............. 17.17 16.6:4 _1~..~6 ............... 16.79 16.66 372..22 ............ 15..8.3 ...................... 388.13 15.9'0 -404.79 16.67 ........... _422... 0_7 ............. 17_...26'_ ........... : .............. 440.27 ,: .. 18.19 4~9.21 18.94 ....47_~...12 ....................... 1 ~_...91 ................... LINION OIL CO. OF CALIF. KU 14-3:2 (SEC 31 TSN Rt1W) KENA I GA'.:'; F I ELD ALAS, A / SF'ERRY-SUN WELL SLIRVEYING COMPANY COMF'UTATION DATE MARCH 4, 1982 DATE OF SURVEY.-MARCH 2, JOB NUMBER BOSS-1697L:: KELLY .BU~,H I N~5 ELEV.-. -= OF'ERATOR-SAMEC PAGE 6 1982 .9:_::. 0c). F T. INTERPOLATED VALUES FOR. EVEN_1.00.FEET OF SUB-SEA..DEPTH .................................... TRHE SUB-SEA MEASURED VERT I CAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR .... COORDINATES NORTH/SOUTH EAST/WEST ..... MD-TVD ......... VERTICAL ......... DIFFERENCE CORRECTION 4297 37.98.00 3700.00 238..93 4419 3898.00 3800.00 240.03 4542 3.9.98.00 3.900.00 241.0.9 4666 4098.00 4000,00 241.76 47.91 41.98.00 4100.00 241.71 4917 4298.00 4200.00 240..9.9 5044 43.98.00 4300.00 239.16 5173 44~8.00 4400.00. 236.75 5304 45.98.00 4500.00 233..33 5435 4698.00 4600.00 229.13 5568 47.98.00 4700.00 - 222.87 5700 48.97.08 479.9.08 215.32 _N ........ 1821.12 E .......... 499..96 ......... N 18.90.82 E 521.86 N 1.962.06 E 544.64 N ..... 2034.53 E .._568..14 N 2109.3.9 E 593.07 N 2185.95 E 619.01 N N 'N N N N ..20.84 .............. 22.79 .... 23,.50 .............. 24..93 25.95 2265.03. E ....... 646.52 ............ 27.5.1 ............... 2346,~..~ E 675,40 ~,~R 88 2430,37 E 706,0.9 30,70' 2515.56 E ........... 7~:7.53 ..... 31.43 .............. 2602.7.9 E ' 770.37 32.85 2689.10 E 802.92 32.54 THE CALCLILATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN'. THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS . Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16978 Well: KU-14-32 (SEC31TSN RllW) Kenai Gas Field Kenai, Alaska Survey Date: Marck 2, 1982 Operator: John Samec Scale: 1" = 1000' TBUE NOFITH -sob' oo 2697,71 .. soo'. oo ~oo~'. oo ~sol~. oo -500. O0 ~°ob. oo HOB I ZO.NTRL PROJECTION 5'100 250~}. O0 Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16978 Well: KU-14-32 (~EC31TSN RllW) Kenai Gas Field Kenai, Alaska Date of Survey: March 2, 1982 operator: John Samec .. Scale: 1" = 1000' 0.00 lO00. O0 2000. O0 3000. O0 ~.000. O0 5000. O0 j i 000. O0 20~)0. O0 570Q I 3000. O0 VER T.I CfqL PBOJE C T I ON sUggested form to be inserted in each "Active" well folder to check, for timely compliance with our regulations. o Well Name and Number Reports and Materials to be received by: Date · Required Date Received Remarks Completion Report Yes 5-- / 7-. ~ ~ Z~,~ ~--~' - , ~"_~3 amp les ..... Core Chips ~,, , ,, Core Description Registered Survey~a% , Inclination Survey Directional Survey Y J-PI Drill Stern ?est Reports .~5~ '/P~-~i~' ~ , ..... Digitized Data y ~.~' /7/-- / ~ --~;'~--, :6 /~:',,, ,. , , , , STATE OF ALASKA ALASKA ~ , AND GAS CONSERVATION C£~vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO . ' 1. Drilling well l~] Workover operation [] I/~ 2. Name of operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 82-15 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20351 9. Unit or Lease Name KENAI UNIT 4. Location of Well at surface , 740'N & 1759'W of SE corner, Sec. 31, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 95' MSLI A-O?R055 For the Month of. MARCH ,19__ 10. Well No. KU ~14-32 11. Field and Pool KENAI GAS FIELD 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Released rig 3/15/82 TMD 5700 ' 13. Casing or liner run and quantities of cement, results of pressure tests Tested 9 5/8" casing to 5000 psi - ok. 14. Coring resume and brief description None 15. Logs run and depth where run CBL-VDL-GR f/ 5610-1500' Gyro f/ 5610-Surface 1 6. DST data, perforating data, shows of H2S, miscellaneous data PerCed & sqz'd: 4798-4818' 4775-4790 ' Rerfed: 4596-4658' 5298-5314' 5539-5550 5445-5455' 5330-5345' 5320-5327' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED ~.',.,-~ ~--- e~,,l~ //~(~ TITLE DZST DRLG SUPT DATE 4/15/82 NOTE--Rep~]~t on this form is required fo/r each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Document Transmitt~' Union Oil Company of Cai ~a unlen DIATE SUBMI+IT~D ACCOUNTING MONTHI HAND DELIVERY 4-23-82 TO FROM Mr. Harry Kugler R.C. Warthen State.Oil & Gas ^T 3001 Porcupine Drive ^T PO Box 6247 Anchorage, Alaska Anchorage, AK 99502 TE'LE PHONE NO. TRANSMITTING ThE FOLLOWING: I I ~ I I I I KU-I 4-32: , ,, 1 ea. Radius of curvature direct'onal survev 1 ea. CBL 5". one bliJ~line, nnm ~nia ..... ~/- PI FASF SIGN ..... . . , ..... , . . . , i ~ i i i~ i i ~ ~ i i F'ORM 1-2M02 (REV. 1 1-72) PRINTED IN U.S.A. Document Transmittal Union Oil Company of Califc unlen DATE SUBMITTED ACCOUNTING MONTH HAND DELIVERY 4-21-82 TO FROM Mr. Harry Kugler R.C. Warthen · n~ D,,-,,, ~9A7 AT Stdtu 0~i & Gas ~ ^T . U~ -'-- I U I Jun u~ ~ 3001 Porcupine Drive Anchroage, AK 99502 ~lnrhnraop .......... .m TELEPHONE NO. tRaNSMITTING the FOLLOWING: KU 14'32 .__ 1 ea. Blueline and sepia of the followin · BHC 2" and 5" DIL 2" and 5" CNL-FDC 5" FDC 5" G-4 RD I ma. Rlimlin~ and seDia of the i:ollowinq .~-- /~ ACBL 5" ~ I PLEASE SIGN AND RETURN. ~F,, COPY DATE' ~'/c/ ' ~'.~ FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. ~ STATE OF ALASKA ALASKA ~,k AND GAS CONSERVATION CC,,,MISSIONoPERATiONS¢~ MONTHLY REPORT OF DRILLING AND WORKOVER · Drilling well [] Workover operation [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 7. Permit No. 82-15 8. APl Number so- 133-20351 9. Unit or Lease Name KENAT UNIT +740'N & 1759'W of SE corner, Sec. 31, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 95' NSL A-028055 10. Well No. KU #14-32 11. Field and Pool For the Month of. FEBRUARY , 19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations $ 00:01 hfs 2/9/82 Spud well $ 17:30 hfs 2/16/82 TNB ~ 5695' 2/28/82 13. Casing or liner run and quantities of cement, results of pressur9 tests Drove 20" 94# plain csg to 70' Ran 13 3/8" 61# K-55 butt csg to 2020' w/ 1000 sxs cl "G" cmt - tested to 2500 psi - Ran 9 5/8" 47# N-80 butt csg to 5695' w/ 1380 sxs cl "G" cmt .. 14. Coring resume and brief description · None 15. Logs run and depth where run DIL-Sonic & FDC-CNL-GR f/ 5700 to 2020' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED MAR 1 9 !982 Alaska Oil & Gas Cons. C0mmJssi0n 7. I hereby c,e,r.t-~ that the foregoing is true and correct to the best of my knowledge. SIG ED DATE ~o~~t 0~ t,,. ,cfm ,. ~..,red ,o~ .~ ~.,e~d~r mo.,,. ~e,~rd,e. o, t,~ ..'~, o' o,.~.,io~....d m~. Oil ~[~a~3as Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 Submit in duolicate January 21, 1982 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P., O, Box $147 Anchorage, Alaska 99501 l~e; l/enai Unit KU No, 14-11 Union Oil Company of Call fornia Permit l~o, 82-15 8ur. ~o. 730~, 1.900~W of SE cr Sec ~tt~Ole ~et 1250~, 900~E, of ~ er ~ee 32, TS~, R11W, .Dear Mr. Anderson l~nelosed is the approved application for permit to drill the above referenced wel I. Well samples and a mud log are not required. A continuous directional su~-vey is required as per 20 AAC 25.050(b)(5), If ava. liable, a tape containing the dii~itized log information Shall be submitted on all loins for copytnl~ except experimental lo~s, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawnin~f or migration of anadromous fish, Operations in these areas are subject to A~ 16.05.870 and the tribulations promuli~ated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by A5 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencinc operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. l~obert T, Anderson Kenat Unit gU No. 14-S -2- January 21, 1982 To aid us in s.cheduling field work. we would appreelate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the C~tssion may be present to witness testing of blowout preventer equipment before surface easing shoe is drilled. In the event of suspension or abandorunent, please give this of.fi_ce adequate advance notification so that we may have a witness present. Very ttmly yours, C. V. Chatterton Chs i~m~n of BY ORD;R O; T~E co~aU Alaska Oil and Gas Conse~'Vation Commission Department of Fish ~ G.at~e, l~abitat Section w/o enelo Department of Envl~o~ntal Conservation w/o anal. crc= be Union Oil and Gas ~son: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager Uanuary 18, 1982 Hr. Chat Chatterton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KU #14-32, A-028055 (8-86-71-5390-600978) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill KU #14-32 in the Kenai Gas Field. Also enclosed is our Check No. 19177 in the amount of $100.00 to cover filing fees. Very truly yours, sk Enclosures (4) cc: $. R. Callender A. Lannin-LA Office t £C£1VED JAN 1 ]982 Alaska 0il & Gas Cons. AnChOrage C°m~ission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~,.AISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL J~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS~J~ MULTIPLE ZONE JJi3 2. Name of operator JNION 0IL COMPANY OF CALZFORNZA 3. Address ~0 BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface 9. Unit or lease name ~730'N & +lgO0'W of SE Corner, Section 3i, TSN, RllW, SM. KENAI UNIT .- At top of proposed producing interval 10. Well number ~llO0'N & +lO0'E of SW corner, S.32 TSN RllW SM. KU ¢I14-32 '- At total dept~-- 1 1. Field and pool ~1250'N & +900'E of SW corner, S.32 TSN Rll~ SM. '-5. Elevation in'T~et (indicate KB, DF etc.) I 6. Lease designation and serial no. KB +_?0' MSLI A-028055 KENAI GAS FIELD 12. Bond information (see 20 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount $200,000.00 13. Distance and direction frOm nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 5 mi South miles +1250 feet well +1900 feet , ,. 16. PropOsed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6700' MD & 5900' TVD feet 2324·67 1/15/82 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 1000 . psig@__ Surface KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 38 o (see 20 AAC 25.035 (c) (2) ~__~l.'~._Qj~__~psig@._.~L0J~Lft. TD (TVD) 2~*Based on recent Sterllng new wells, Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY O'F CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ~ Driven 20 9Mi H-40 Plain 100' Surf I +100 ~ . I L7 1/2 13 3/8 61¢f K-55 Butt. 2000' Surf ~ +2000I 1400 sxs - tO surf. L2 1/4 9 5/8 47¢f N-80 Butt. 5700' Surf , 757001 1500 sxs - inside ~ - i 13 3/8" ,i ! I · I t ~ I 22. Describe proposed program: 1 Move in and rig up Brinkerhoff Rig #59. · DEPUTY CONSERVATION MGR. 2, Drive 20" to refusal ~ +100' & install diverter, ONSHOR~ FIELD OPERATIONS 3, Drill 17 1/2" directiOn~l hole to +2000'· 4. Run & cmt 13 3/8" csg to 2000', JAN .~ O 5, Install & test BOPE to 3000 psi, 6. Drill Z2 hoZ to R E C E I V E D 7, Run logs, - CON~t~tlv~?IONt DIVISION 8 Run & cmt 9 5/8" csg to +5700' JAN 1 )982 u,s, · ~ · ANCHOI~AGE, ALASKA 9, Test & complete well as a dual Sterling producer· Alaska Oil & 6as Cons. Commission '__ Anchorage 23.1 hereby~_~..~rego~m~is ~corr~C/to the best of my knowl~edge .... .~'~_~~/~¢/, ~-(-~"~'-' ~ / s~o~D--Robert T. Anderson / ~~l~J~E District Land Mgr DATE 1/15/82 The space below for Commission use / 6 CONDITIONS OF APPROVAL Samples required ' Mud Icg required Directional Survey required J APl number []YES ~.0 •YES [~0 [~ES r-iNOJ 50--/3~- ~_ Permit number /- Approval date ~-/"- J'~ 0~/~/~J~ J SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE .l'~n~mmr 9.1 by order of the Commission Form 10-401 Submit in triplicate R.v 7-1~RI3 ii ii i Ii I I I UNION OiL C0~F'ANY OF CALIFORNIA RECEIVED DEPUTY CONSERVATION ONSHORE FIELD OPERATIONS JAN 1'0 ]982 CONSERVATION DIVISION U.S. GEOLOGICAL SURVEY ANCHORAGE, ALASKA C, T RECEIVED JAN ! Q ]982 ~,laska. Oil& Gas Cons. Commission Anchorage Df, AWl4 ~ CKD. -- , _ I I (mlli ' : - I I II I CHECK V,~L V£ 5ooo Ps'~ ~%,~/~" %000 esl RECEIVED DEPUTY CONSERVATION MGR. 'JKN'I 0 !$87 'CONSERVAT'ION DIVISION · U.S. GEOLOGICAL SURVEY ANCHORAGE, ALASKA ,4#GL ED .FILL UP LllYS SO'O0 ' ~ HYDRIL' 1'5 ~/$" ""%" ."°"'"'R E C E 1 V E'I) ~t)oot. ~o'; 2ooo ,,t ~.o.~,,. JAN 1, a 1982' ~OTE ' AlasKa 011 & Gas Cons. Commission A~L CHANGES MUST HA~C~EN APPROVAL BY THS DISTRICT O~ILLING SUPERIHTEfloENT $CLt[ ,.~ 2.q ! .o RECEIVED DEPUTY CONSERVATION MCR. ONSHORE FIELD OPERATIONS JAI3.j,. O 1982 CONSERVATION DIVISION U.S.'GEOLOGICAL SURVEY ANCHORAGE, ALASKA ~-~ .4#GLEO .FILL UP L//~ ,.,. ~ HYDRIL' 13S.~'' £ooo ~'s'.~ . . · CHECK V.~L VE . ., \ 13S/s'' · GATE V4 L V£ PiPE RA,',~ ( s ') .... . H Y~ ~A I, iL IC ' OPEP~ TED VALV£. · .. LO-7'OR~U£ , ~0" Sa, oD ~'f,'~. x ~Si~~ ~eoo ~s'~. ~b~~ 20" zooo ~(~ ~ ~S/S" ~o e~t . Alaska 0il & Gas Cons· CommJssJ0~' HOTE~ Anchorage ALL CHANGES NU$T HAVE WRIT.TEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT ,,. j t ' J~ffD H BI. I F*OR~I 247 (NE~W I I II I J II i iii i ii q,' eo,~tT~V~ RECEIVED ' DEPUTY CONSERVATION MGR. ONSHORE FIELD OPERATIONS JAN 1 O i982, CONS ERVATIOI~I DIVISION U,S, GEOLOGICAL SURVEY ANCHORAG~E, ALASKA RECEIVEI) JAN 1 Q 1982 Alaska Oil & Gas Cons. Commission CKD. ~ AFl"Do DAT~ UNJON OIL COMPANY OF CALIFORNIA SHEETS ~ SHEET · / F~RM CR-13 1/72 CASING AND TUBING DESIGN CASING ~O S~..~ '~.~r,e:~J,CO~ STA~ ~-v~ _ DA~ ...I ,/q / ~,_. DESIGN BY ~.~ , .. - C,S~,O S~ SO~ S~Z3 ~ ~. I ~5 ,r~. ~D 0~. i .s~ ~si/~ ~ ~. II ~ ~D. 03. II ~J/ft.. M.S.?, INTERVAL LENGTH.. ~ DkSCRiPTION 5~3IGHT TENSION ~2NTMb~4 TDF COLLAPSE COLLAPSE CDP BUPST IIiTERiCAL ~ W/ BP -top of STRENG~ PRESS. ~ PZSIST. 'PRESSURE ~.~..'~!-~/~. :9ottom Top Wt. I.. Grade Thread W/O B-'~__~ section TEI~SION bottom tensio~ YIELD lbs lbs 1000 lbs psi psi psi , ,psi_ BDF PP_vCE PER PT. t t , . ;~o~o' o ~ooO (~1~ K-SS 15o-~st~ jzz;ooo izz,ooo : ~ q.S__..~.9 ~. ~90 _- 15q5 I. 5~ 2q%o 0 m Formulae: Collapse resistance in tension = X (Collapse pressure rati~) Burst Pressure = ~ + ~m ( ~a. s=. zz -.~) BF (BouyanCy Fac2or) = ~.oo - (o.o~5~ x ~ud Wt. z) Calculations: 'To~-iCost -- _ . RECEIVED ~asJ(a Oil & Gas Cons. ColTimissiort Anchorage :~ _~, .+_,_ . _ _~.-.L_ ___i~q],. F'TTTT, T:"-i-'i-T~-TF::'~,-F,'--I/"i~--FTT-F-F-i-i-IT['-FI ! i i .: i'i I 1. ! · !- I ]f~r-[-/~,-?l I I_~iiil Ti-T-]-T-T-T-TT ' '~,~'1~,,'-,""'::,~~ , 1'l ii i iii -:~I-L-;--4--I ~-L-i--L,,,,, !~..1~I ,-r,c/ ~-,~ ---4--~--?---t---+--4- ' - ' --?-- - '--L-.LIi i I."!, :]-i:T~i-~ '~' '+'-f-i'~-~L¥~' 'j' ~ ~' '1-I' :--t-T-i-I'-T-1--T~ ,. ~ :--k ;~H-,m--:-i-~.' ~--,Fi---Tm~l~ r~!~ ~-~ r ~.~ i ! ~-r r ~.i' i · ! . , r~ '~- , -' , ~,', , .,~1 I ~t . ,.1 ' i-i-'t I ! t : ~ : .', ~, ~_L~. !! i.i I_i ! I t J___Li 1. i i.i_! i !] [ ~'.d~L~D~_Lj__ _~;~] ; ] I- I t 1' ,' :i .:,, I . i. ,'.._ | ,ii!Ii, _ . xTi i I I 1. t.l Ii ! i ! I i I ! I I i ! t'LJI I [ . i l_j_4_l i! I I i I i'T~Ew.TT' I I ii ! I I t i -I ! i i !_J !'l~;F I ;] I "T-i t ' : , ! . I ! t i F.T-["i-T-fS! ! i i i ~ ~ ~YTF:-- i F: i i i i ~ i~! I I ! !3'1 I i ! I-1 t_L~; I I I ! I I I i I ; ' t ;i ~ ~ : ~ _-"~[ i'll Li_Li. ..... * ........ 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I ! l SITE RECEIVED DEPU'r'Y' CONSERVATI( ONSHORE FIELD OPEI~ JAN 1 8 ~98: -t-- CONSERVATION DIVI$1 U.S. GEOLOGICAL ANCHORAGE, ! ! II ! I ! ! ! ! ! ! I · l I ! ! ! ! s/~ $$ ~/ / / tJ ,m,m~ ~,, ,.. ./., u.., li ,w I 4-'--" Corm, CommJssior} lx~.c ...... -= F~ I I I ' ] [ unJsn ~mJmmlmlmlJmmmmmm . AIIiJll J ....... ~.. ..... :;'"~ .... KENAI GAS FIELD - -i---~.o-9,~ ,,,. PRODUCTION ~ACILITIE$ · i . CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. IT~ APPROVE DATE, (1) Fee ~~' /'/~'~ 1. .... (~thru 8) 3. 4. 5. 6. 7, 8. (~thru 11) 10. 11. (4) Cas~~ /--~-~12. t ru 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~2~ ) ~-7 ~-~ 2 21. ~21 thru 24) 22. 23. 24. (6) Add: ~~ /-/~--d~~'' 25. Is the permit fee attached .............................. ........... Is well to be located in a defined pool .......... .................. Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is well bore plat included .............. Is operator the only affected party ................................ Can permit be approved before ten-day wait ......................... Does operator have a bond in force ..... · .... Is a conservation order needed .... i i.~i[[i[ ~[!!!~[ii~i!i[ ii'i. Is administrative approval needed .i .·.o...i.. ........ .i..~..i, IS conductor string provided ..... ' ........................ Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons ............ ~ ....... Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension and burst· Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed ..................... . ..... Is a diverter system required .... · ................................ Are necessary diagrams °f diverter and BOP equipment Does BOPE haVe sufficient pressure rating - Test to ~d . .. Does the choke manifold comply w/API RP-53 (Feb.78).' ~.~g. Additional requirements ............................................ Additional Remarks: YES NO REMARKS Geology: Engineering: W , . ~r~,~ ,~. ,~ H K~ LC~~BEW~ ITA~ JK~RAD ~ rev: 01/13/82 [. INITIAL GEO. UNIT ON/OFF OOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX.' ,. No special'effort has been made to chronologically organize this category of information. o. ~----SCMLUMBERGER .... ~ ¥'ERIFICATION LISTING VP 009.H05 VERiFICATiGN LISTING PAGE I , RE~b HEADER ** ERVICE NAME :SERVIC ATE :82/03/10 RIGIN : EEL ~AME :REEL ID ONTINUATION ~ :01 REVIOU$ REEL : O~MEN'~S :REEL COMMENTS * TAPE HEADER ** ERVICE NAME :SERVIC ATE :82/03/10 RIGIN :1070 APE NAME~ :A6262:0 ONTINUATION # REVIOU$ TAPE : OMMENT$ :TAPE COMMENTS EOF * FILE HEADER ** 'ILE NAME :SERVIC.O01 ~ERVICE NAME : 'ERSION # 'ATE : ,AXIMUM LENGTH : 1024 'ILE TYPE 'REVIOUS FILE : INFORMATION RECORDS INEM CONTENTS }mmm mmmmmmmm IN : UNION OIL COMPANY OF CALIFORNIA 'N : KENAI GAS ~ANG: ~O~N: 5N ;EC~: 31 :OUN: KENAI ;TAT: ALASKA ~TRY: USA ~NE~ CONTENTS 'RES: NEDiT~F ** RECORD TYPE 047 UNIT TYPE CATE SIZE CODE mmmm mmim mmmI mmmm mmmm 000 000 03O 065 000 000 008 065 000 000 010 065 000 000 003 065 000 000 002 065 000 000 002 065 000 000 006 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 H,~5 YERIFICATIOi'~ 5ISTING PAGE ,P009.~'~ RECORD TYPE 047 ~ RECORD TYPE 047 ~ ~ CO~ENTS ~ OB # !0707.Ab2620 0MPANY NAM~ '~ = UNION OIL COMPANY OF CASIF. ELL NA~E = KO ~4-.32 IELD = KENAI GAS OUNTY -- KENAI ECTION = 31 OWNSHIP = 5N ANGE = 1 IW IL RU~'~ #1, hOGGED 27-FEB-82 DTTOM bOG INTERVAL -' 589:4.0 FT. oP o ASING-I~OGGER 13 3~5 IN. ~ 2020 FT. IT SIZE = 12.25 IN. YPE HOLE FLUID = X,,C POLY~ER' E~SITY = 9.7 ISCOSITY = 57 0 S .~ 9.~ LUID LOS,~ = 57.0 C3 M ~ MEAS. TEMP. = 4.750 OHMM @ 70.0 DF ~F ~ ~EA$. TEMP. = 6.670 OHM~ ~ 64.0 DF MC ~a MEAS. TEMP. = 4.150 OHM~ ~ 64.0 DF M ~ 8MT = 3.355 OMni ~ 102' DF ~P 009.H05 VERIFICATION LISTING PAGE 3 ~TRIX SANDSTONE DATA FORMAT RECORD ~ NTRY BLOCKS TYPE SIZE REPR CODE 4 I 66 B 4 73 9 4 65 0 1 66 ATUM SPECIFICATION BLOCKS NE~ SERVICE SERVICE ID ORDER# EPT FLU OIL ~M OIL LD P DIL R OIL T BMC P BHC R BHC PHI FDN HOB FDN RHO FDN ALI FDN R FDN RAT FDN CNL FDN CNL FDN UNIT 50G 'TYPE CLASS ~OD FT 0 0 OHMM ? 0 OH~i'4 7 0 O:HM~ 7 12 ~V 7 G~PI 7 US/F 60 ~V 60 GAPI 60 ~U 42 G/C3 42 G/C3 42 IN 42 GAPI 42 42 42 42 ENTRY 6O .lin 0 DATA EPT P ALI 5724,000 -71.813 -64,375 .-999,250 999,250 SFLU GR NPHI GR API ~P! API FILE SIZE NO. 0 0 0 4 0 0 0 4 0 0 0 4 46 0 0 4 1 0 0 0 4 31 32 0 0 4 52 32 0 0 4 1 0 0 0 4 31 32 0 0 4 68 2 0 0 4 35 1 0 0 4 44 0 0 0 4 28 3 0 0 4 31 32 0 0 4 42 1 0 0 4 ~4 92 0 0 4 34 93 0 0 4 'EPT P ,R C;,L 5700,000 -69,312 -64.375 11,727 570.500 SFLU NPHI GR 10.289 IbM 13,008 -64.375 DT I02,375 -999.250 RHOB -999,250 -999,250 NRAT -999,250 10.211 IbM 12,961 -64 375 DT 102.375 37:451 RHO~ 2,355 69.875 NRAT 3,373 PROCESS SAMPLE REPR LEVEL CODE 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 I 68 0 I 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 ! 68 0 1 68 0 1 68 0 1 68 12.555 BP 71 813 ; :250 NCNb '-999,250 IbD 10.211 BP '69,312 DRHO 0.048 NCNL 2048,000 VP 009.H05 V~RIFICATIO~{ LISTING PAGE 4 EPT 5~080,~00 SFLo P 9, 12 GR R 53,719 NPHI ALI 11.875 GR CNb 849.500 EPT 5500.000 SFLU P -51.750 GR R 53.469 NPHZ ALI 1"z.273 GR CNL 665'000 EPT 5400.000 P -5i.031 R 47,281 AbI 12.188 CNL 7~B.500 EP'I 5~00,000 P 60,031 R 5~,656 ALI I .I56 802.000 EPT 5200.000 .P -47,281 '~L 54.8 3 1 12.8 6 'CNL 597.000 ,EPT 5100,000 ,P -46,500 ;R 48,531 :Ab1 12.328 'CNb 554.000 ~EPT 5000.000 ;P -57,813 ;R 51.188 :AbI 12.031 'CNb 616.000 )EPT 4900.000 ;P -39.031 ;R 55.531 :AbI 12.273 'tNb 687.000 )EPT 4500.000 ;P -59,031 ;R 51,438 :ALI 12.156 'CNL 852.500 SFbU GR NPHI GR SFLU GR NPHI GR SFbO GR NPHI SFLU NPHi GR SFLU GR NPHI GR SFLU GR NPHi GR SFLU GR NPHI GR 34.344 53.719 2 563 43 6.496 53.469 31.738 53.375 6.961 50.656 9,3~2 53.656 28.955 51.844 14.547 54.813 3t~ 330 7,234 48.531 39.551 48.750 8.133 51.188 38.135 43.469 7 285 55:531 36 914 55:03i 13.500 51,438 26,318 43.21.9 DT RBOB NRAT IL~ DT NRAT IbM DT RHOB NRAT I~ DT RHOB NRAT IbM DT RHOB NRAT DT RH00 NRAT ibm DT RHOB NRAT IbM DT RHOB NRAT DT RHOB NRAT 30,250 106,563 2,285 2,721 6.855 111,188 2.211 3.076 7.480 98,000 2.209 3.033 1!.398 122.375 2.027 2.~89 16,312 96,375 2,359 3.t49 7,641 108,563 2,131 3.504 8.305 112.375 2,162 3.418 7,078 109.000 2,201 3,357 12.609 152.375 2.072 2.713 SP DRHO NCNb SP DRHO NCNb IbP SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb ILD SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb SP DRHD NCNL 27.609 -89'312 0.013 2444,000 6.949 -51,750 0,017 20!2,000 .5~ '406 .031 0.005 2474.000 12,070 -60.031 -0.006 2476.000 17.625 -47.281 0.008 2288.000 7.449 -46,500 0.012 2108.000 8.023 -57,813 0.029 2116,000 6.695 -39,031 0 010 2234:000 12,b25 -59.031 -0.003 2642.000 VP 009 HO5 VERIFiCaTI0f~ .blS~ING EPT 4700.000 SFbU P -13,516 GR R 62,500 NPHi AbI 12,953 GR CNL 490,250 EPT 4~00,000 SFLU 53,719 P GR R 54,594 NPHI CNL 84 ~000 EPT 45 p - R CNL 4 EPT ~P ;R :Abi ~EPT ~P ;R :ALI 'CN b ~EPT ;P ;R :ALI 'CNb )EPT ;R :ALI )EPT :CN L )EPT ;P ;R ;ALI 3 99 42.773 57,844 15,125 54;594 b,270 4,125 00,000 22,250 60469 12820 43000 NPHI GR 3,500 60,469 44,482 57;094 4400 '27 67 12 519 000 266 688 977 ,5o0 SFLU GR NPHI GR ~.641 67,688 40,479 61,844 4300.000 -26,516 55,938 13.383 475.000 SFLU GR NPHI GR 4.551 55.938 39.111 53.094 42 O0 93 58 12 1.~ .000 .375 ,438 ,430 .000 SFLU GR GR 45,344 58,438 17,627 51.344 41 O0 87 5O 12 O1 .000 .312 .188 .39B ,OOO SFbU GR NPHI GR 15.883 50,18~ 41,553 46,312 4000 '-52 63 12 .000 .312 .125 .609 .000 SFbU GR NPHI GR 6.512 63.125 44.87~ 50.813 3900 58 12 472 .000 .281 .750 .547 .750 SFbb GR NPH! 12.575 58,750 43,848 51,469 ILM DT RHOS NRAT IbM DT RMOB NRAT DT RHOB NRAT DT RMOB NRAT IbM DT RHOB NRAT DT RHOB NRAT DT RHOB NRAT IbM DT RHO8 NRAT IbM DT NRAT 4,582 111,750 ,262 .699 406 132i750037 2,713 2. 72 3.791 116~: 484 i88 2,262 3. 574 5. O20 117.000 2.197 3.506 44,344 167,375 1,976 2,141 16.766 129,375 2.111 3.619 7.785 i18.188 2.139 3.807 11.938 125,750 2.098 3,748 IDD SP DRHO NCNb ILD SP DRHO NCNb ILD SP DRHO NCNb IbD SP DRHO NCNb ILD SP DRHU NCNb $P DRMO NCNb SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb PAGE 4 762 024 l :ooo i6.125 -53,719 -0000 2426'000 , 5,840 -22,250 ,010 178 ,000 6,906 -27.266 0,028 1952.000 5.227 -26.516 0,003 1962.000 43 844 -0,005 3102,000 16 766 -87:312 22~ 0'004 6,000 8.094 52.312 0.019 72.000 13.375 -61.281 0.049 1819.000 O.~.H05 ¥~RIFICA~ION LISTING PAGE 6 EPT 3800.000 SFLO P -46.344 GR R 45.438 NPHI ALI 13.047 GR CNL 531.500 EPT 3700.000 SFLU P -91.063 GR R 46 1~5 NPHI AL1 12:1~ 8 GR 549.000 EPT 3600,000 SFbU P -83'312 GR R 51,~19 NPHI ALI 12. 19 GR CNL 564.000 EPT 3500.000 SFLU P -66.063 GR R 48.000 NPHI ALI 12.641 GR Ci~lJ %58.750 EPT 3400.000 SFLU P -76.875 GR R 46.344 NPHi ALI 12.320 GR CNL 484.000 IEPT 3300.000 SFLU .P -82.312 GR ;R 45,312 NPHI IAL! 12.312 GR 'CNL 538.000 ,~PT 3200.000 SFLU iP -6i.281 GR ;R 50.094 NPHI :ALI 12.633 GR 'CNL 495.750 ~EPT 3100.000 SFbU .P -91.063 GR ;R 44.781 NPHI IALI 12.063 GR 'CNL 557.500 ~EPT 3000.000 SFLU ;P -88.312 GR ;R 44.625 NPHI ~ALi 12,188 GR 'CNL 528.000 5.559 45.438 50,781 46'813 16.281 46.125 41 ~97 49:56 16,234 5i,219 38.330 47,594 10,328 48,000 4~,264 5 .781 12.656 46.344 45.850 40.656 14,172 45.312 42,285 44.094 9 164 50:094 40.186 55.250 15.750 44.781 39.648 47.500 12.922 44.625 41.357 42.625 IbM D~ RHOB NRAT IbM DT RHOB NRA~ IbM DT RHOB NRAf IbM DT RHOB NRAT IbM DT RtiOB NRAT DT RHOB NRAT Ih~ DT RHOB NRAT IbM DT RHOB NRAT DT RHOS NRAY 5.961 11!.000 2.166 4.145 17,641 133.375 2.092 3.625 17.89i 131.750 2 23 9.930 126.750 2.059 3.830 15.406 121.375 2.158 3.855 15.736 132,125 2.074 3.656 8.422 124.750 2.086 3.547 16.844 134,375 2,086 3,504 15.133 134,500 2.090 3.602 I~D SP DRHO NCNb IbD SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb IhD SP DRHU NCNL IbD SP DRHO NCNb I h D SP DRHO NCNb 6.074 -46.344 -0 O02 2324' .000 17.969 0,001 2 0.000 17 734 ,312 ,008 2088.000 9.930 -66.063 0.007 1946.000 16,125 -76.875 0,002 2094.000 15.883 '~2,312 0.005 2056,000 8 945 -61:281 0.011 1764,000 17.453 -91,063 -0.013 2132.000 15.180 -88.312 0002 o :ooo VP 009.H05 VERiFICATiON EPT 2900.000 SFLU P -62.844 GR R 51.406 NPHI AL1 13.211 GR CNL 381.250 EP'~ 2800.000 SFLU P -68.125 GR R 60.875 NPHI CNL 445.750 EPT 2700.000 SFLU P -69.312 GR R 55,312 NPHI AL1 13.117 GR CNL 489,250 EPT 2600.000 SFLU P -10i.063 GR R 41.906 NPHI ALI 12.312 GR CNb 639.500 ~EPT 2500.000 SFLU ,P -92.813 GR ;R 45,000 NPHI IALI 12.188 GR 'CNL 484.25U ~EPT 2_400 000 SFSU ;P -961625 GR IR 40.719 NPMi ',ALi 12,273 GR 'CN5 547.000 )EPT 2300.000 SFLU ~P -101.312 GR ;R 39.469 NPHI :ALI 12.352 GR 'CNL 543.500 )£PT 2200.000 SFLU ~P -96.063 GR ;R 42.719 NPHI ~ALI 12.609 GR 'CNL 538.500 )£P~ 2100.000 SFSU ~P -94.563 GR ;R 38.813 N~HI ~ALI I2.344 GR ~CNL 528.000 LISTING 6 06 51.074 5~.250 60 75 47,607 51.844 7,801 55.~!2 4~,994 5 .531 i 711 36,768 40.938 9.148 45 000 42~432 45.656 8.961 40.719 4~.40~ 36.656 9.133 39.469 43 115 39~406 9.328 42.719 41.0!6 42.1~8 8,766 38.813 44.092 38.344 DT RHOB DT DT RHOB NEAT IbM DT RHOB NEAT IbM DT NEAT DT NEAT I~M DT R~OB N~AT DT RHOB NRAT ID~ DT NEAT 7.715 129.375 2.063 4.164 9,16~ 126,375 2.012 3.959 8.898 130.125 2.033 3.773 11.273 124.000 2.i09 3.348 9.148 137.000 2,080 3.660 ~.922 139.125 2.070 3.717 8.359 145.125 2.i00 3.703 9.063 140.750 2,129 3.594 8,359 145.500 2.086 3.758 BP DRHO NCN5 IUD SP DEMO NCN~ SP DRHO NCN5 BP DEMO NCNL SP DRHO NCNL I~D BP DRHO NCNL ILD BP DRHO NCNL BP D~HO ILD SP DRHO NCNL PAGE 8.320 9,281 '68,125 0.001 1848.000 ,211 '6 ,312 0,012 1805,000 i1.195 '101,063 ;~,001 21 .000 8,945 -92.813 19~ 0'001 1.000 9.016 -96.625 -0,007 1987.000 8 406 -101~312 20] 0.003 5'000 9,055 -96.063 -0.006 2096.000 8.320 -94.563 mO.O03 2022.000 VP 009,H~5 VERIFICATION LiSTiNG PAGE 8 0.000 ILD 2000.000 EPT 2000.000 SFLU 6.6v6 IbM 20~09.78 P 26.703 GR 29.109 DT SP 26.703 R 29.109 NPHI -999.250 RHOB -999.250 DRHO -999.250 ALI -999.250 GR -999.250 NRAT -999.250 NCNb -999.250 CNL -999.250 EPT 1997.500 SFLU P 27.188 GR R 3~,531 NPNi ALi -99 .250 GR CML -999.250 559 2000.000 ILO 48.000 SP -999.250 DRHO -999.250 NCNb 2O0O 000 27 188 -99g 250 -999 250 * FILE TRAILER ** iL6 NAME :SERVIC.001 ERVICE NAME : ER$IO~ ~ ATE : AX~MU~i LENGTH : 1024 iLE TYPE : EXT FiLE MA~E : EOF * TAPE TRAILER ** ERVICE NAME :SERVIC :ATE :82/03/10 ,RIGIN :1070 APE i~AME :A62620 'ONTiNUATION # :01 EXT TAPE NAME : IOMMENT$ :TAPE COMMENTS * RECL TRAILER ** .ERViCE NAME :SERVIC ~ATE :~2/03/10 :EEb NAME :R~Eb ~D :ONTINUATION ~ :01 fEX? 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