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174-050
~ ( ~, MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl sand of the Tyonek FOID1ation and the Beluga FOID1ation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU5 195-054 KTU 43-06XRD 177 -029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-179 KBU 44-06 ~(Ç¡'0~~NlEK) ~JJ~~ 2 ~ 2004 I I Marathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907~564-6489 October 23, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KU 14-6RD 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.'l-he 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 3 November 2003. A simple schematic is included for your review. Please recall that you recently approved a sundry for a jet compressor installation at KU 21-7. . If you need any additional information, I can be reached at 907-283-1301 or by e-mail at b msen ette@ ma rathonoil, com. /8~'ent M. Senette Production Engineer Enclosures Gas C ORIGINAL G:\CMN\DRLG\KGF\WELLS\KU13-6L\KU-14-6RD AOGCC Sunc~ry.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging 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 259'N & 964'E of SW Cdr, Section 6, T4N, R11W, SM At top of Productive Interval At Effective Depth At Total Depth vertical well 5. Type of Well: Development X Exploratory, Stratigraphic , , Service Install Jet Compressor to Aid in Water Lifting 6. Datum Elevation (DF or KB) 20.05 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 14-6rd ~' 9. Permit ~lmber 74-50 ~ 10. APl Number 50- 133-10089-01 11. Field/Pool KENAI GAS FIELD/POOL 3 12. Present Well Condition Summary Total Depth: measured true vertical 15047 feet 15047 feet Plugs (measured) Effective Depth: measured true vertical 3843 feet 3843 feet Junk (measured) ,--'"3-3/8" gun assembly @ 3725'-3839' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 6O 3O78 4618 744 Size Cemented Measured Depth True Vertical Depth 20" 80 sacks 60' same 13 3/8" 7" 1720 sacks 3078' same 775 sacks 4618' same 90 sacks 4593'-5337' same 3540'-3574',3636'-3678',3700'-3740' ~" true vertical 3540'-3574', 3636'-3678', 3700'-3740' Tubing (size, grade, and measured depth) 2-3/8", 4.7 ppf, J-55, EUE 8rd to 3632' Packers and SSSV (type and measured depth) N/A ECE VELi' OCT Alaska Oil & Gas Cons. Commission 13. Attachments Description Summary of Proposal ~ Detailed Operations Programm ARcl~ketch 14. Estimated Date for Comr~encing Operation 15. Status of Well Classification as: 3-Nov-03 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby certify t)~at, th.efgre~rue and correct to the best of my knowledge. Signed /~ Brent Senette Title Production Engineer /c,' V FOR COMMISSION USE ONLY Conditions of/Approval: Notify Commission so representative may witness / Plug Integrity BOP Test Location Clearance / Mec~hanic~l I~t~ty Test '-~'ubsequent Form Required 10---fid ¢.~ Suspended Date IApproval 10/23/2003 NO. Approved by Order of the Cornrnission ................................ ORIGINAL Commissioner KU 14-6RD Gas Jet Gas Flow Diagram ICompressed or high pressure gas I Motive Gas Meter To low pressure production header or test separator KU 14-6RD Annulus Production KU 14-6RD Velocity String ProductiOn Meter \ Jet Compressor: Throttles high pressure \ motive gas to drop velocity string flowing pressure below field suction levels Velocity string water and gas production Annular Production Well KU 14-6RD ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI~rSCSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL~ GAS~] SUSPENDED~'~ ABANDONEDr~ SERVlCE[~ 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 Classification of Service Well Ii ' Permit Number 74-50 · APl Number 50-133-10089 4. Location of Well at Surfaco 259' FSL, 964' FWL, Sec. 6, T4N, R1 lW, S.M. At top of Producing Interval vertical well At Total Depth vertical well 5. Elevation in feet (indicate KB, DF, etc.) 21.00' DF-GL ~-~--'~ ,% ~%~ :."~-:( 19. Unit or Lease Name ~;~::;"::* .... "'~#~ I Kenai Unit -ii-,__~_~~ l 110' Well Number ~ :" ..... -~ ~"~' ~ I KU 14-6rd ; ';¢Er,~ .....-( .~~: ]11. Field and Pool ~ .... ~:r-~,~¢, ~, ~ Kenai Sterling Pool 3 ~6. Lease D;s~g~ti°~-n~ Sedal No. ~ Kenai Gas Field I A-028142 I N/A N/A 3/10/2003 I N/A feet MSL I one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 5345' (MD & TVD) 3839' (MD & TVD) YesF]N° F~ N/A feet MD N/A 22. Type Electric or Other Logs Run none 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE FOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 0 60 grouted N/A 13-3/8" 61 & 54.5 J-55 0 3078 17-1/2" 1720 sks N/A 7" 29 N-80 0 4616 8-1/2" 775 sks N/A 5" scab liner 15 L-80 3504 3641 N/A N/A N/A 125. TUBING RECORD 24. Perforations open to Production (MD+'FVD of Top and Bottom and interval, size and number) iSIZE DEPTH SET (MD) 2-3/8" 3475' N/A PACKER SET (MD) 6 spf, 2.5" Excape guns MD: 3636' - 3678', 3700'- 3740' TVD: same 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. Date First Production 13-Mar-03 Date of Test 3/13/2003 Hours Tested 24 Flow Tubing Pres. Casing Pressure 0 0 28. PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) flowing TEST PERIOD ~- 24-HOUR ~TE ~ IWATE°R-BBL ICHOKE SIZE] IIGAS-OIL N/A lOlL GRAVITY-APl (corr) IWATE~t-BBL I N/A RATIO Brief description of lithology, porosity, fractures, apparent dips and presenco of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal RECEIVED MAR 1 4 200~ ~a~s ~ & Gas Cons. Form 10-407 Rev. 7-1-8o RBDMS BFL ,~R 19 °~'r~'l,, ~ ~% .r~. N:\drlg~kgflwells\KBU33-6gAOGCO MPL.xls CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. RECEIVED 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey Signed Gary Eller Title Production Engineer Date 3/14/2003 .. \_ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg~sterling~su32-9~AOGCOMPL.xls DF-THF: 20,05' (2002 workover) APl: 50-133-10089-01 AOGCC: 74-50 256' FSL, 964' FWL Sec, 6, T4N, R11W, S.M Tree cxn: 4-3/4" Otis Lift threads: 2-3/8" EUE 8rd Wellhead & Tree Drawinq .,, Tubinq: 2-3/8", 4.7 ppf, J-55, EUE 8rd X-nipple - 3436' (ID = 1.875") Wire ine re-entry gu de - 3475 Tubing Tally Detail Peds(Sterlin~ Pool3): A8,3540'-3574' CBL (isolated w/scabliner) A10,3636'-3678'CBL All,3700L3740'CBL **Note: MD = CBL + 9'. Therefore, the peds given ~bove (CBL reference) are 9' deeper via pipe measurements. Slickline tagged fill @ 3821' WLM, 2/12/2003 KU 14-6rd PBTD-3839' TD ¢ 5345' Conductor: 20" @ 60', grouted ] Surface Casin~q: 13-3/8", 61 & 54.5 PPf, J-55, STC casing @ 3078' Cmt with 1720 sks of class G Scab liner w/ZXP packers, 3504' - 3641': 5", 15ppf, L-80, BTC liner isolating casing damage in the vicinity of the A8 perforations 3504 -3641 Scab Liner Detail Top of cut dual tubing strings @ 3839' Otis RHD dual packer @ 3843' Note: Longstring and shontstring tubings are pugged be ow he dual packer. 7", 29 ppf, N-80, LTC & BTC casing @ 4616' Cmt with 775 sks of class G Pluflflinq detail belo__w_ du:a_l j2_k.£ Well Name & Number: KU 14-6rd Lease Kenai Gas Field, Pad 14-6 PeRorations: (MD) (TVD) Angle/Peds I vertical Angle @KOP and Depth I KOP TVD I Date Completed: 01/22/031 RKB: Prepared By: Gary Elter I Last Revision Date: 02/18/031 MARATHON'oiLCOMPANy' "-- '- '."-- - - -Pagel-ofl:- - Daily_ WorkOVer Report._ '- "- '- ' - .. ,...~Well hot=...4..~-I=a n-o"* ' ' _ K~A} U~IT ~4-O~D 2~.0 ~.00 I 2~ 22 23-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS S~BS COST Gene Anderson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 50,879.00 729,002.62 Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS I ~S 24 HR FOREC~T Rig released 18:00 hrs, 01/2N03. RDMO to Abalone ~1. OPE~TION COMMENTS ND BOPE. Install & test tree. Install BPV. ND top drive. Demob rig. Release rig ~ 18:00 hrs, 01/2~03. SAFE~ SUMMARY . ~ ~4.00 ~ono ~/~ 5/2003 ~/~ 7/2003 ~/~/2003 I ~/~ 0/2003 ~ID~T SAFE~ ~O TOPICS: OPE~TIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP ~BL ' DESCRIP~ON ' 06:00 10:30 4.50 AF XMBO NUND ND BOPE & load out. 10:30 12:00 1.50 AF XMBO NUND Instil 2-1/16" 3M psi production tree. 12:00 13:00 1.00 AF XMBO TEST Install 2 way check valve. Test tree to 250 psi Iow/3000 psi high, OK. Pull 2 way check valve. Install BPV. 13:00 18:00 5.00 AF RDMO RIG Demob Rig, RD top drive. Release dg ~ 18:00 hm, 01/2~03. DENSIW(p~) I I PP J ECD JMUD DATAI-DNLYCOST J 0.00 ~ CUMCOST 22341.00 . P~RSO~ELD~TA - . - . . . "-.-~OB-~o~:oo: _' COMPANY SERVICE NO.' HOuRS ~ -"- COMPLY '- _ . SER~CE -- . NO. ' HOURS. Inlet Drilling Alaska 18 108.00 Weaver Bmthem (WBI) 2 18.00 Marathon 1 12.00 Atigun 2 12.00 M-I Drilling Fluids 1 6.00 ABB Vetco Gray 1 8.00 CASING SUMMARY - ~ -- '- ~. ' . . -- - ~ST BOP TEST: 1/17/2003 ~ST CASING TEST: NE~ BOP TEST: 7.000 (psi) ~ (pp~) I 4,~ I 4,~ 2~.oo Printed: 3/14/2003 10:19:10,AM ' . V~ellb°re~jean~ofit:: ~:' ~<ENAI UNIT 14-6RD 21.0 66.00 0 20 21 22-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/WBS COST Gene Andersen Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI DALLY WELL COST I CUM WELL COST KENAI 907-283-1312 100.0000 37,252.00I 678,123.62 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (fi) (in) @ 0 (fi) CURRENT STATUS / MTS 24 HR FORECAST qD BOPE. ND BOP. Install & test tree. RIs rig. OPERATION COMMENTS LDDP/DC's. RIH w/completion tubing. Displace hole to 3% KCL. Land tbg. ND BOPE. SAFETY SUMMARy' ~ MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? LAST RIG INSPECTION 306.00 None 1/15/2003 1/17/20031 1/9/2003I N 1/10/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running tubing. OPERATIONS SUMMARY - FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIpTIoN - 06:00 13:00 7.00 AF PCMP TRIP RU & POOH LDDP & DC's. 13:00 14:00 1.00 AF RCMP TRIP RU to run tubing. 14:00 16:00 2.00 AF RCMP TEST Install & test 2-3/8" rams, 250 psi Iow/3000 psi high. 16:00 22:00 6.00 AF RCMP ,TRIP PJSM. Strap & run 2-3/8" tubing f/derrick. PU 20 jts 2-3/8" tubing. Tag TOL @ 3504'. FTIH to 3760'. 22:00 00:00 2.00 AF RCMP CIRC RU & displace workover fluid to 3% KCI. Pump 40 bbl HEC pill ahead of completion fluid. 00:00 00:30 0.50 AF .RCMP TRIP POOH, LD 10 jts 2-3/8" tubing. WL guide @ 3474'. 00:30 02:00 1.50 AF RCMP NUND Dress tubing hanger, land tubing. Install BPV. 02:00 03:00 1.00 AF RCMP NUND Flush BOPE, mudlines, T/D, choke & surface equipment. 03:00 04:00 1.00 AF RCMP NUND ' Remove 2-3/8" rams and install VBR's. 04:00 06:00 2.00 AF RCMP NUND ND BOPE. DENSITY{ppg) J 8.50 [PPI ECD MUDDATAI DAJLYcOS¥I 1776.00 ; cUMC0sT 22341.00 28 / / /1.0 / I g.oo/ 15,500/8°1 1 ..... I BHA DfiSCRIPIION Taper Mill 6" x 2 3/4", Stdng Mill, Cross Over, .Junk Basket, .Junk Basket, Bit Sub, 4 3/4" Bumper sub, 4 3/4" Oil .Jar, 4 3/4" Drill collars (8), Acc. ,Jars, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP COMPANY SERVICE NO. : HOURS ~;::;;:: COMplY :' : SERVICE.' ~!: .;-.-: NO., :HOuRS~: Inlet Drilling Alaska 16 192.00 Weatherford 2 24.00 Marathon 2 30.00 Weaver Brothers (WBI) 1 12.00 M-I Drilling Fluids 1 24.00 Atigun 1 18.00 Baker Oil Tools I 6.00 CAS N SUMMARY :i i LAST BOP TEST: 1/17/2003 LAST CASING TEST: NEXT BOP TEST: Printed: 3/14/2003 10:19:07 AM MARATHON OIL CoMpANy -- _ i . ~.- Page1 '°f2_ _ · ' '- DailyWorkOver Report- ' _- ~ -_ ---~- '- · Weilbore Clean-o~t - -. - . i ' - - KF:NAI I.J~lT 14-ORD 21.0 ~.00 1~ I 20 21-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/~NBS COST Will Tank Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 I 26,248.40 640,871.62 Alaska Kenai I 7.000 (in) @ 4,~6 (ft) (in) @ 0 (~) CURRI=NT $1ATU$ / ~T$ I 24 HR FOR£CA$1 TOOH kD drillpipe.IFinish LD drillpipo. Run tubino. Displace w/3% KGL. oP~mVr~ON COM~tN'rS Finish out of hole with mills. Broak 8, LD fishin~ equipment, waitin~ for scab liner equipment. Run bottom half of scab liner. 'i'OOH. Wait on rodross of setting tool. ~un top half of scab linor. Test to backside to ~,000 psi. 'I'OOH LD D~. SA~='r~ . _ 304.00 Recordable 1/~ 5/2003 11/17/2003 1/~/2003 ~ 11/~0/2003 a¢¢~£u'r D~SCRIP'r~o~: Two fingers pinched on right hand caught botwoan pipe tongs. O~FR~IION$ SU~R¥ FROM TO HRS FROM TO SUB PHASE OP - TRBL DESCRIPTION 06:00 07:00 1.00 AF PCMP TRIP Out of hole with mills on BHA #11. Mills in guage. LD mills, junk baskets, jars, etc. 07:00 09:00 2.00 AF PCMP TRIP Breakdown and LD washpipe and Baker fishing tools off rig floor. 09:00 10:30 1.50 TA PCMP WAIT WOE Wait on scab liner equipment. 10:30 14:00 3.50 AF PCMP CSG PU 5" casing muleshoe, HMC liner hanger, ZXP liner hanger packer, and hydraulic setting tool on 4" ddllpipe. TIH with bottom part of scab liner. Saw very little drag through upper A-8 perfs. 14:00 14:45 0.75 AF PCMP CSG Put bottom section of scab liner on depth. Bottom of scab liner, the muleshoe, is at 3,641'. Establish circulation, drop ball, set hanger with 1,800 psi, liner packer with 2,500 psi, and energize with 3,800 psi. Rotationally release setting tool. 14:45 16:30 1.75 AF PCMP TRIP TOOH with setting tool on drillpipe. Send hydraulic setting tool back to Baker's shop for a re-dress for setting the upper portion of the scab liner. 16:30 22:30 6.00 TA PCMP WAIT WOE Wait hydraulic setting tool to be re-dressed and tested. (Note: Unable to get 2nd hydraulic setting tool from the North Slope due to weather conditions there.) 22:30 02:45 4.25 AF PCMP CSG PU 2joints 5", 15~, L-80, Buttress TKC casing and ZXP liner hanger packer (with hold up slips to prevent upward movement) on hydraulic setting tool and TIH. 02:45 04:00 1.25 AF PCMP CSG Sting into bottom seal bore. Drop ball and wait 30 minutes to drop. Pressure up and set hanger with 2,800 psi, energize with 4,000 psi. Test backside to 1,000 psi. Rotate and release hydraulic setting tool. Pressure up to 5,000 psi to shear out ball to catcher. 04:00 05:00 1.00 AF PCMP ClRC Break circulation. Fill trip tank. Blow down mudlines. Flush res pump. 05:00 06:00 1.00 AF PCMP TRIP TOOH laying down drillpipe. Pdnted: 3/14/2003 10:19:05 ,AM KENAI UNIT 14-6RD 21.0 66.00 0 19 20 21-Jan-2003 [~E,S~,(,,g) J a.50 J "" I ~ECDI MUD'DATAt.D~Ycos~ :~ ~494.00 I Cu~ coS* 20565.00 29 2/ / / /1.0 / 9.00/ / 15,500/80 BHA D[SCRI~IIO~ Tapor Miff ~" x 2 3/4", Stdn~ Mill, Cross Ovor, 0unk Baskot, Junk Baskot, Bit Sub, 4 3/4" Bumper sub, 4 3/4" Oil Jar, 4 3/4" ~rill collars (8), Acc. ~ars, 3 ~/2' IF-~ X HT-38-8,4" ~4ppf 8-~35 HT-38 ~ PERSONNEL DATA ' · POB ~ 06:00:. COMPANY SERVICE NO. HOURS : cOMPANY :: · SERVICE NO~ HOURS Inlet Drilling Alaska 16 192.00 Weathedord 1 4.00 Marathon 2 30.00 Hallibu~on 2 2.00 M-I Drilling Fluids 1 24.00 Weaver Brothem (WBI) 1 4.00 Baker Oil Tools 2 48.00 CASING SUMMARY .: ~ST BOP TEST: 1/17/2003 ~ST CASING TEST: NE~ BOP TEST: 7.000 (psi) ~ (pp~) I 4,g~O 4,~ 20.00 ~-S0 Injurod Inlot employee roturned to work durin~ his shi~ on light du~ as pmscigod by his physician. ~ote: Cost for Baker Oil Tools (s~b finer) and Woathefford not available at repo~ time. Printed: 3/14/2003 10:19:05 AM MARATHONOIL-COMPANY . -- - - :'-. DailyWork°ver Report . i _ . Wellbore Clean-oUt . ~ - KENAI UNIT 14-6RD 21.0 66.00 0 18 19 20-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPNVBS COST Will Tank Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC Wi NRI DALLY WELL COST I CUM WELL COST KENAI 907-283-1312 100.0000 32,943.00I 614,623.22 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF I Alaska Kenai 7.000 (in) @ 4,616 (fi) (in) @ 0 (fi) CURRENT STATUS / MTS J 24 HR FORECAST TOOH with mills.I Run scab liner. Start running completion. OPERATION COMMENTS Finish POOH with washpipe. Did not recover fish. Recovered pieces of casing. Run overshot. Latch fish (TCP guns). POOH, full recovery. RIH with taper mill / string mill to wipe casing. TOOH. SAFETY SUMMARYi 'l' I " MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 264.00 None 1/15/2003 1/17/2003 1/9/2003 N 1/10/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tdpping pipe OPERATIONS SUMMARY '. ' FROM TO HRS FROM TO SUB PHASE i OP TRBL · DESCRIPTION . 06:00 07:00 1.00 AF PCMP FISH Finish POOH with washpipe. Did not recover fish. Pulled several large (4" x 3") pieces of casing from the junk baskets. 07:00 09:00 2.00 AF PCMP TRIP Breakout and lay down washpipe and overshot. 09:00 10:00 1.00 AF PCMP RIG Service Rig 10:00 12:00 2.00 AF PCMP TRIP Dress overshot, pick up fishing BHA #10. Wait on extensions for overshot. 12:00 16:30 4.50 AF PCMP TRIP TIH with overshoton BHA#10. 16:30 17:00 0.50 AF PCMP FISH Work overshot onto TCP guns. Get positive pressure indication. 17:00 20:00 3.00 AF PCMP TRIP POOH with overshot. Had full recovery (TCP gun, crossover, auto release fidng head, drop bar partially milled up) 20:00 21:30 1.50 AF PCMP TRIP LD fish and overshot. 21:30 00:30 3.00 AF PCMP TRIP PU tapered mill and string mill BHA #11. TIH. 00:30 02:30 2.00 AF PCMP FISH Found casing tight starting at 3,561' - 3,574'. Washed and reamed 3,540'- 3,574' several times to clean up casing. TIH to 3,839'. 02:30 03:30 1.00 AF PCMP CIRC Circulate sweep and CBU. 03:30 06:00 2.50 AF PCMP TRIP TOOH with mills. DENSITY(ppg) I 8.50 [PPI ECD MUD DATAI DAILYCOSTt 625.00 I CUM:COST 19070.00 I I I I' 'sI/ca ' tcacl2(wt%l H2S' LIMEI ES- 6RPM FV PV/YP GELS WL/HTHP FC/T. SOL ONV- %Sand/MBT' Ph/pM Pf/Mf 28 /1 /1 / /1.0 / / 9.50/ / 15,5oo/8o I ' ! I I BHA ' - . . - . 11 303.68 BHA DESCRIPTION Taper Mill 6" x 2 3/4", String Mill, Cross Over, Junk Basket, Junk Basket, Bit Sub, 4 3/4" Bumper sub, 4 3/4" Oil Jar, 4 3/4" Drill collars (8), Acc. Jars, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP PERSONNEL DATA · · POB @ 06:00: COMPANY SERVICE NO. HOURS COMPANY . SERVICE NO. HOURS Inlet Drilling Alaska 16 192.00 M-I Drilling Fluids 1 24.00 Marathon 1 24.00 Baker Oil Tools 1 24.00 Pdnted: 3/14/2003 10:19:02 AM WELL NAME KB KENAI UNIT 14-6RD LAST BOP TEST: 1/17/2003 7.000 CASING SUMMARY .... ~ -~- LAST GASING TEST: NEXT BOP TEST: (psi) @ (ppg) 4,616 4,616 29.00 N-go REQUIREMENTS ~ - :~ - ' Based on casing damage found during fishing operations, decision made to run scab liner across upper A-8 perfs, instead of squeeze. Printed: 3/14/2003 10:19:02,AM SUPERVISOR mO NAME & NO. AUTH MD WBS S~BS COST Will Tank Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD N~E RIG PHONE MOC ~ NRI D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 37,767.00 581,680.22 STAT~PROV COUNt/OTHER ~T CASING'] N~ C~ING ~ L~KOFF I I Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / ~S 24 HR FORECAST TOOH with washpipe TOOH w~ashp pe. Retrieve TCP guns. Round trip mill. OPE~TION COMMENTS TIH with washpipe. Tag up 3,564'. Work washpipe. TOOH. PU mills and RIH. Clean up ~sing across peris. TIH to 3,723'. CBU. Round trip for washpipe. Wash over TCP guns. TOH with washpipe. SAFE~- SUMMARY: 2Og.00 ~ono ~/~ 512003 ~/~ 7/2003 ~/0/2003 ~/~ 0/2003 ACCIDENT DESCRIPTION: SAF~Y ~G TOPICS: OPE~TIONS sUMMARy FROM TO HRS FROM TO SUB PHASE OP ~BL : ~ : ~: DESCRIP~ON ' ~ ' ' 06:00 08:00 2.00 AF PCMP TRIP TIH with washpipe and rolling dog overshot. 08:00 12:15 4.25 TA PCMP TRIP MISC Tag up at 3,5~' (Sterling A-8 pedzone). PU and affempt to rotate through peds. Washpipe torquing up. TOOH ~th washpipe. 12:15 13:00 0.75 TA PCMP TRIP MlSC LD BHA ~7. Washpipe out ofguage on shoe. PU taper mill an( string mill BHA ~8 13:00 15:00 2.00 TA PCMP TRIP MlSC TIHwith mills, BHA 15:00 16:30 1.50 TA PCMP FISH MlSC Begin ro~ting at 3,500'. Seeing torque at 3,557'. Ream througk upper pedorations (A-8). Ba~ream ~rough upper perorations. No torque seen below A-8 peds. TIH and ~g at 3,723'. 16:30 19:30 3.00 TA PCMP TRIP MlSC CBU at 3,723'. POOH with mills BHA ~. Mills in guage. 19:30 20:00 0.50 TA PCMP TRIP MlSC LD mills. PU washpipe 20:00 01:00 5.00 AF PCMP TRIP TIH ~th washpipe, BHA ~. Tag TCP guns at 3,732'. 01:00 04:00 3.00 AF PCMP FISH Washover TCP guns from 3,732' - 3,838'. 04:00 04:30 0.50 AF PCMP ClRC Circulate and ~ndition hole. 04:30 06:00 1.50 AF PCMP FISH POOH with washpipe. (Note rolling dog overshot may have TOP gun with it on this tdp.) I 8.50 I "" I I.c l :MUD DATAI;0~[YcOs~ 625.00 CUMCOST~ 1~45.00 28 /1 / /1.0 / I / i _._0_ I I ~-,-'--/6° I ', I I 8HA ~fiSCRI?IIO~ Shoe, Washpipo (2), Rollin~ ~o~ overshot. Washpipe (2), Drive bushin~, Gross Over, Junk Basket, Junk 8askot, Bit Sub, 4 3/4" Bumper sub, 4 3/4" Oil Jar, 4 314' Ddll collars (g), Acc. Jars, 4 3/4~ Cutup out sug, 3 W2" IF-~ X HT-3g-B, 4" ~4ppf S-~35 HT-38 D~ P'ERSONNELDATA~: ~ : ~ ::: ;~ : : :: ~ .' ::PoB~O6;o0:~ , COMPANY SERVICE m NO. HOURS ~. ::~ ~OMpANy Inlet Drilling Alaska 16 i9Z00' Marathon 24.00 Pdnted: 3/14/2003 10:19:00 AM -; MARATHON-OIL COMPANY - _ -'- -_- -¥-.- -----Page 2 of 2 --: · Daily Work°Ver_.RePort . - . _;- _ -' . _. _. - _ ' Wellbore Clean;ot~t- ' -:'- - - - KENAI UNIT 14-6RD 21.0 66.00 0 17 18 119-Jan-2003 · PERSONNEL DATA - _ pOB @ 06:00:. COMPANY SERVICE NO. HOURS COMPANY SERVICE '' NO. HoURs M-I Drilling Fluids 1 24.00 Veco Alaska 1 2.00 Baker Oil Tools 1 24.00 Carlile Transportation Sy 1 2.00 CASING SUMMARy . ' LAST BOP TEST: 1/17/2003 LAST CASING TEST: NEXT BOP TEST: 7.000 J I (psi) @ (ppg) 4,616 4,616 29.00 N-80 REQUIREMENTS ' . Rig costs for all reports have been changed to reflect increased rig rate. Printed: 3/14/2003 10:19:00/NM · : ~:. !Daily Wo~k°Ver RePo~ :~.: ~::~. ::.i ~ ~: ~i~-i::-'i~ ~:! K[~AI U~IT ~4-0RD 2~.0 ~.00 ~0 ~7 ~g-Jan-2003 SUPERVISOR RIG N~E & NO. AUTH MD WBS SAP~BS COST Will Tank Glacier Ddlling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI J D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 ~ 38,271.60 543,913.22 STAT~PROV COUNt/OTHER L~T CASING NEXT CASING ~ L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (n) ~ 0 (fi) :CURRENT STATUS / ~S J 24 HR FORECAST TIH with washpipe.J Washover TCP guns. Fish guns. OPE~TION COMMENTS POOH with fish, full recover. TIH with bit. Stop at 347'. TIH with mill. Knock off junk at 347'. Tag sand at 3,555'. Mill junk, wash sand to 3,732'. Tag TCP guns. ShoA Lip and condition hole. POOH. Pedorm BOP test. Stad in ~th washpipe. SAFE--SUMMARY ~ : ...... ' ~: 2~3.00 ~ono ~/~ fi/2003 ~/~ 7/2003 ~/~/2003 ~ ~ ~/~ 0/2003 ACCIDENT DESCRIPTION: S~ETY ~G TOPICS: OPE~TIONS:SUMMARY ~ ~ ': : FROM TO HRS FROM TO SUB PHASE OP TRBL : ~ : DEsCRIP~ON : . 06:00 07:00 1.00 AF PCMP FISH Finish POOH with fish. Had ~11 m~ve~ (all of tail pipe on fish). 07:00 09:30 2.50 AF PCMP FISH LD and break out fish and fishing BHA. 09:30 10:30 1.00 AF PCMP TRIP PU and tally bit and BHA ~. 10:30 11:30 1.00 TA PCMP TRIP DOTH Sta~ in the hole ~th bit and BHA. Set down at ~7'. Drain s~ck and look for obstruction, nothing seen. 11:30 12:30 1.00 TA PCMP TRIP DOTH TOOH ~th bit. No ma~s seen on bit. (possible source of obstruction could be pie~ of unre~vered tubing from external tubing cut on 1/14/03). LD bit. 12:30 15:00 2.50 TA PCMP TRIP PU 6" milt and BHA ~. TIH ~ mill and set down at 347'. PU, s~H slow rotation of drill string and set back do~ on obstruction. Small amount of torque encountered and then the obs~ction fell away. TIH ~th mill and BHA. Not encountering any more obs~cfions. 15:00 16:30 1.50 TA PCMP DRILL MISC Tag up at 3,555', top of sand in ~sing (washed tubing from jet shot hole at 3,557'). Begin rotating and washing sand. Mill torqued up, milling on junk. Mill up junk, ~ntinue to wash sand. Had signifi~nt torque through A-8 pedoration zone. No torque seen in the ~o lower peal zones. 16:30 17:30 1.00 AF PCMP CIRC Tag up on TCP guns at 3,732'. Pump 30 bbl Flovis w/Safe~rb LCM pill. Getting sand in the returns. Circulate hole clean. 17:30 19:15 1.75 AF PCMP TRIP Sho~ trip to 3,427' (above A-8 peal zone) and back to boEom. Circulate boffoms up. 19:15 22:30 3.25 AF PCMP TRIP TOOH with mill and BHA ~6. Dumped junk baskets. Recovere~ 3 cuffer a~s, peal shot debris, and pieces of tubing. Mill was ~ under guage 15/16". 22:30 02:30 4.00 AF PCMP TEST Pull wear bushing. PU and ~n in test plug. Test Annular, uppe~ pipe and blind rams to 250/3000psi 10 min. Test inside and outside kill line valves, inside choke, HCR, check valve, and 1-12 choke manifold valves to 250/3000psi 10min. Test 2- 2 Printed: 3/14/2003 10:18:57,AM Kfi~AI H~IT ~4-OR~ 2~.0 ~.00 ~0 ~7 ~8-Jan-2003 FROM TO HRS FROM TO SUB pHASE oP :TRBL' :: 22:30 02:30 4.00 AF PCMP TEST 3/8" safe~ valves, 2- 2 3/8" IBOP valves, 4" safe~ valve, 4" IBOP, upper and lower TDS valves, 4" mud pump shut-in valves to 250/3000psi 10min. Pedo~ accumulator pedormance test. Test pit and gas ala~s. Test ~tnessed by Jeff Jones (AOGCC). Pull test plug, install wear bushing and blow down. 02:30 06:00 3.50 AF PCMP ~TRIP PU and tallywash pipe with rolling dog overshot (BHA ~7). RIH with wash pipe. I .5o I P, I CDIIMuD DATA1 DA~L~COsT~I 4352.00 I CuMcosT' 17820.00 FC~.SOL /MBT :ph/pM Pf~f CI/CacaCI2(~%~ H2SiLIME : ES 6RpM / / / .50/ / 5,000 / BIT/RUN S~E M~UF. ~PE SERIALNO. jETSORTFA ~; ~. ~ ~--OEPTH'IN DATEIN~ :~ ~ I-O-D.L~B,G~O.R~ . 1 /1 6.000 Hughes AT J-4 5007087 18/18/18/////// 3,555.0 1/17/2003 0-0 ..... 2/1 6.000 Baker Oil Tools mill 3,555.0 1/17/2003 0-0 .... · :; :~ : BHA~-:~: ;~: BHA DESCRIPTION Shoe, Washpipe (2), Rolling Dog overshot, Washpipe (2), Drive bushing, Cross Over, Junk Basket, Junk Basket, Bit Sub, 4 3/4" Bumper sub, 4 3/4" Oil Jar, 4 3/4" Drill ~llars (8), Acc. Jars, 4 3/4" Pump out sub, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP - : . ;. : PERSONNEL:DATA: COMPLY SERVICE: NO. : :;HOURs: :~ :::: :: COMply:: :~:: ::.': ::::~:::::: : ~SERViCE:::~ ~: :::::: .~ N0~:?~ .~:HoURS:: ; : : ~ . .~ .... , ~ . . ; : :.~ , Inlet Drilling Alaska 16 192.00 Alaska Propane 1 1.00 Marathon 1 24.00 Alaska Telecom, Inc. 1 8.00 M-I Drilling Fluids 1 24.00 Alaska Pipe Re~ve~ (A 2 1.00 Baker Oil Tools 1 24.00 ~Wildflowers and Resin 1 8.00 S&R Enterprises 1 2.00 HallibuAon 1 4.00 Alaska Oil Sales 1 1.00 AOGCC 1 4.00 CASING SUMMARY:: ;:~ LAST BOP TEST: 1/17/2003 ~ST ~ASING TEST: NE~ BOP TEST: SIZE (in) I ID (in) SHOE TEST,pPg~ - M~SlCP I MD-<")::: 7.000I I (psi) ~ (PPg)I 4,616 4,616 29.00I N-80 Pdnted: 3/14/2003 10:18:57,AM . . MARATHONOiLcoM.PANY' . - Daily W°rkover Report - _ wellbore Clean.oUt - WELL NAME KB GL I 24 HR PROG TMD TVD IDES DOE RPT # DATE KENAI UNIT 14-6RD 21.0 66.00I IO 15 16 17-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/WBS COST Will Tank Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI DAILY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 42,996.00 505, 641.62 STATE/PROV COUNTY/OTHER LAST CASING I NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft)J (in) @ 0 (ft) I CURRENT STATUS I MTS I 24 HR FORECAST POOH with fishI Pull fish. Clean out to TCP guns. Washover guns. OPERATION COMMENTS Finish RD coil. RU wireline. Made several runs with 1 11/16" and 1 9/16", could not get through tubing. Ran 1.46" cutter and perf tbg below Y-block. Pressured up and lost returns. Jarred fish free. Pumped LCM pill. Start out with fish. SAFETY-SUMMARY ' MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 339.00 None 1/15/2003 1/11/2003 1/9/2003I N 1 1/10/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS .SUMMARY ' FROM TO HRS FROM TO. SUB PHASE OP TRBL ' - DESCRIPTION 06:00 09:00 3.00 AF PCMP CLTBG Finish RD coiled tubing equipment. 09:00 10:30 1.50 AF PCMP RIG Change out unloader valve, adjust torque tube, change elevators. 10:30 11:00 0.50 AF PCMP CIRC Latch back onto drill pipe. Fluid Iow in ddll pipe. Fill up. Apply 1,000 psi pressure on drill pipe. Very slow leakoff. RU wireline (APRS). 11:00 12:00 1.00 AF PCMP WlRELN PUI 11/16" jet cutter. RIH. 12:00 12:30 0.50 TA PCMP WlRELN DOTH Jet cutter stopped at 3,525' (in middle of a tubing joint above the Y-Block). Made several attempts to get deeper, no success. (This tubing has had a 1.74" drag bit through it on coiled tubing.) 12:30 14:00 1.50 TA PCMP WlRELN DOTH POOH with wireline and cutter. RDwireline. Pull 10K tension on ddll pipe. RU wireline and run back in with 1 11/16" cutter. Set down at 3,525'. POOH with wireline and cutter. 14:00 15:00 1.00 TA PCMP WlRELN DOTH RIH with wireline and 1 9/16" tubing perforator. Set down at 3,525', as before. POOH with wireline and perf gun. 15:00 16:00 1.00 TA PCMP WlRELN DOTH RIH with wireline17/16" weight bar on top of1" weight bar. Wireline stdng went to 3,629' (equated to the PBTD established in the tubing cleanout via coiled tubing). POOH with wireline and weight bars. 16:00 18:45 2.75 TA PCMP WIRELN DOTH RDwireline. Call for l .46" jet cutter (not made to cut 2 3/8" tbg, hope to get through and punch hole in tubing). RU long bales for top ddve. RU wireline guide onto top drive. RU wireline unit. 18:45 19:30 0.75 AF PCMP WIRELN RIH wireline and 1.46" jet cutter. Wireline string went to 3,629' (equated to the PBTD established in the tubing cleanout via coiled tubing). Used collar Iocator to position cutter. Set off cutter at 3,557' (just below bottom perf of the A-8 sand). Good indication of cut. POOH with wireline. 19:30 20:15 0.75 AF PCMP CIRC Pressure up on drill pipe gradually. At 1,350 psi lost all ddll pipe 3ressure and backside fluid level began to drop quickly. Printed: 3/14/2003 10:18:54 AM 15 16 117-Jan-2003 OPERATIONSSUMMARY: i" - :: i -, FROM TO HRS FROM TO SUB pHASE OP TRBL : ~ i -~ DESCRIPTION_ ' 19:30 20:15 0.75 AF PCMP CIRC Attempted to keep backside full. Falling too fast. Attempted circulation with 3% KCL, no success. Pumped 40 bbl HEC pill, no circulation. 20:15 20:45 0.50 AF PCMP FISH Jarred on fish while pumping on drill pipe. Getting some gradua movement. Fish came free at 20:45. Pulled up I joint (max room available with long bales and wireline guide). Continued pumping on well. 20:45 00:00 3.25 AF PCMP LSCIRC Mixed and pump 2 - 35 bbl FIovis w/Safecarb LCM pills. Regained retums. RD wireline unit. 00:00 02:00 2.00 AF PCMP RIG Change back to short bales. Remove wireline guide. Build fluid volume back 3% KCL. 02:00 02:30 0.50 AF PCMP FISH Pull out 3 joints to get above upper perfs. 02:30 04:00 1.50 AF PCMP LSCIRC Spot 35 bbl Flovis w/Safecarb LCM pill and monitor fluid level. Blow down mud lines. 04:00 06:00 2.00 AF PCMP FISH Start POOH with Fish. (Seeing some drag, 20K) DENSiTY(ppg) I 8.50 I PPI IEcG IMUD DATAI DA~LYc°sT' 2917.00 I CUMCOST 13469.00 FV I PV/YP I GELS I WL/I'ITHPI FC/T. SOLI O/w Ij°/~a~d/MBT iPh/PM i:Pf/Mfl; :CI/ca: Icaci2(wt%I::H2S;iLiMEI:ESlI6RpM 28 /1 // / / 9.80i / 151000/80 I ' / BHA D[SCRI~/IO~ 5 3/4" Overshot wi2 318" grapple, 5 3/4" Overshot top ext., lop sub, 4 3/4" Bumper sub, 4 3/4" Oil Jar, 4 3/4" Drill collars (8), Acc. Jars, 4 3/4" Pump out sub, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP COMPANY SERVICE NO, :HOURS: : ; CoMPlY:: :i '?:: ::::::SERVice Inlet Drilling Alaska 16 192.00 Baker Oil Tools I 24.00 Marathon I 24.00 BJ Services 5 25.00 M-I Drilling Fluids 2 30.00 Veco Alaska 1 8.00 Alaska Pipe Recovery (A 3 36.00 LAST BOP TEST: 1/11/2003 LAST CASING TEST: NEXT BOP TEST: 7.000 (PSi)@ (PPg) 4,616 I 4,~1aI 20.00 Printed: 3/14/2003 10:18:54 ,AM · :D~ailYWo~k°veriRePo~:~: ~ i:!:i~ ~ ~i ~ ~:' :-WellbOreClean-~°~t i : ii ~ ~: :-~i i ,: KENAI UNIT 14-6RD 21.0 66.00 0 14 15 16-Jan-2003' SUPERVISOR RIG NAME & NO. AUTH MD I WBS SAP/VVBS COST Will Tank Glacier Drilling 1 WO.02.07939.EXP 36g,000 !FIELD NAME RIG PHONE MOO W1 NRI DAILY WELL COST I CUM WELL COST KENAI 907-283-1312 100.0000 54,821.00I 462,645.62 STATE/PROV COUNTY/OTHER I I~ST C.I~ING I NEXT C/~ING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST RD Coiled Tubing Unit Perf tbg below Y-Block. Circ out sand. Pull tbg. OPERATION COMMENTS Unable to jet past 3,529'. Run 1.82" mill and motor on coil. Unable to get past 1.875" profile in fishing BHA. Re-run motor with 1.74" drag bit. Clean sand out of tubing to 3,631'. TOOH with coil. Begin rigging down coil. - SAFETY SUMMARY ~ ~i~:.i : : ii ~ ~ :~.~ 422.00 None 1/15/2003 1/11/2003 1/9/2003 N 11/10/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: BOP Training OPERATIONS SUMMARY i ' : . ~ FROM TO ERS FROM TO SUB PHASE OP TRaE . :: ' :. : DEsCRIPTIoN. 06:00 08:30 2.50 TA POMP CLTBG DOTH Unable to make any progress beyond 3,529'. Pull out of Hole with Coiled Tubing. 08:30 12:00 3.50 TA POMP CLTBG DOTH Called for mill and motor for coil clean out. Set injector head off on dg floor. Wait on bit and motor. Have BJ coil crew go in for rest. 12:00 16:00 4.00 TA POMP WAFT DOTH Wait on bit and motor. Bit and motor on location @ 14:00 hrs. BJ crew ardves at 16:00 (as scheduled for rest period). 16:00 19:30 3.50 :TA POMP CLTBG DOTH Strap and caliper (OD&ID) coil BHA. Mill size is 1.82". Hold safety meeting for coil operations. PU injector head. MU coil BHA and test on surface. 19:30 20:30 1.00 TA POMP !CLTBG DOTH Run in holewith coiled tubing. 20:30 22:30 2.00 TA POMP CLTBG DOTH ~Set down at 3,220.5' (believe to be pump out sub in fishing BHA @ 3,223.5 tubing tally depth with calipered ID of 1.875"). PU and pump down to 3,220.5' Attempt to slide in without success. PU and attempt by pulsating flow, no success. PU and attempt to mill through restriction at 0.75 BPM. Appear to make progress to 3,221'. No further progress made, but motor is not stalled and pressure flucuations indicate some pump off at the restriction. Attempt to mill at 1.0 BPM and 1.5 BPM (max for motor), with same result at higher respective pump pressures but no stall. Go to 3,221.5' with 1.5 BPM before complete stall. PU and attempt to force through restriction with 3,000 lbs compression, no progress. (Note all pick up weights to get out of restriction are the same at 4,000 lbs tension.) Small loss in backside fluid level (pump out sub may have sheared and opened communication ddllpipe to annulus). 22:30 23:30 1.00 TA POMP CLTBG DOTH Pull out of hole with coiled tubing. Mill is undamaged and in guage. PU 1.74" drag bit and run in on same coil BHA. Send 1.82" mill in to be ground down to 1.7" (same as motor OD). 23:30 00:30 1.00 TA POMP CLTBG DOTH Run in hole with coiled tubing. Sawtop offish at 3,507' Printed: 3/14/2003 10:18:51 AM · . MARATHONOIL:COMPANY---_ .__ _'. -_ _"Page2-°f2 .' · Daily._ workoverReport-- - . .' .-' - ... __ -- - _ Wellbore Clean'out - ' KEN^I UNIT 14-6RD 21.0 66.00 14 15 10-Jan-2003 OPERATIONS SUMMARY: ' ' ' : ' - ' '- FROM TO HRS FROM TO SUB PHASE OP TRBL . ' DEscRIPTIoN. ' 23:30 00:30 1.00 TA PCMP CLTBG DOTH (previously saw at 3,502') and tagged sand at 3,534' (previously 3,529'). No drag through pump out sub restriction. 00:30 02:00 1.50 AF PCMP CLTBG Drill and wash sand from 3,534' to 3,631' (hard and soft streaks throughout). 02:00 03:30 1.50 AF PCMP CLTBG Circulate bottoms up 2 times. No indication of fluid increase on backside of drill pipe. Some sand in returns up the inside of drillpipe. (Only 0.4 bbl expected for tubing volume to clean out.) 03:30 04:30 1.00 AF PCMP CLTBG Pull out of hole with coiled tubing. Drop ball and open circulating sub. Displace coil with N2. 04:30 06:00 1.50 AF PCMP CLTBG Disconnect coil BHA and begin to RD coiled tubing equipment. DENSITY{ppg)I 8.50 IPPI ECD I I MUD.'DATAI DAILY COST I 675.00 I CUM cost 10552.00 30 /1 / / / / 10.00/ / 15,000/80 BHA' ' . . ' - - - '_ B HA~IO. I LE2No~.T0~ I EFF WT. PICK UP I SLACK OFIROT WT. ;rORQUE(?ax/min) I BHAHRS I JARHRS. IMWD H RS IMTR HRS-ISS HRS' BHA DESCRIPTION 5 3~4" Overshot wi2 3/8" grapple, 5 3/4" Overshot top ext., Top sub, 4 3~4" Bumper sub, 4 3/4" Oil Jar, 4 3/4" Drill collars (8), Acc. Jars, 4 3~4" Pump out sub, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP 'PERSONNEL DATA- _: -_ '- _ - --_ _ COMPANY SERVICE ' 'NO.-_ HOURSI - - _ COMPANY ---" ._SERVICE .... NO.. HOURS . Inlet Drilling Alaska 16' 192.00' BJ Services 5 120.00 Marathon 2 30.00 Randy's Glass 2 8.00 M-I Drilling Fluids I 24.00 Veco Alaska 2 12.00 Alaska Pipe Recovery (A 1 2.00 S&R Enterprises 2 10.00 Baker Oil Tools 1 24.00 CAS'lNG SUMMARY ' -- ' - . " - ~' . . LAST BOP TEST: 1/11/2003 LAST CASING TEST: NEXT BOP TEST: 7.000 (psi)@ (ppg) I 4616 I 461~I 29.00 REQUIREMENTS ' _ ' -. -. -: - - - - - ~ · Coil BHA (Top to Bottom): CT connector (Length 2.5", OD 1.501" ID 0.731") X-over (Length 5.63", OD 1.503", ID 0.731") Double Flapper Check Valve (Length 18.13", OD 1.687", ID 0.740") Hydraulic Disconnect (Length 16.438", OD 1.685", ID 0.5") Circulating Sub (Length 11.063", OD 1.686", ID 0.437") Motor (Length 116.0", OD 1.692", ID 0.731") Mill (Length 5.63", OD 1.82", ID 0.514") Total Length 177.51" Printed: 3/14/2003 10:18:51 AM Wellbore clean.out :.:; - ~. : ~ ;; KFNAI UNIT 14-6RD 21.0 66.00 I 13 14 1§-Jan-2003 ISUPERVISOR RIG N~E & NO. AUTH MD WBS SAP~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ N~ D~LY WELL COST J CUM WELL COST KENAI 907-283-1312 100.0000 62,094.00 J 407,824.62 Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / MTS 24 HR FORECAST Work 1.5" CT~3529'. Clean out 2 3/8" TBG. OPE~TION COMMENTS RIh w/overshot. Work stuck TBG and pressure up on DP and Annulus in aEempt to circ. Set slips w/7k over pull on TBG. Prep rig for ~iled tubing operations. ~U CT. RIH w/CT. Wash F~OF to 3529'. Attempt to wash past 3529'. SAFE. SUMMARY : : ~;~: 378.00 ~ono ~/~ 4/2003 ~/~ ~/2003 ~/~/2003 ~ ~ I~ 0/2003 sa~v ~o ,o~cs: Safe ~U 0~:00 0~:30 0.50 AF '~GM~ FISH RIH w/ovorshot assy. 0~:30 ~0:00 3.50 AF ~GMP FISH En~a~e fish. Work fish w/50k over work skin~ ~. Attempt to circ. do~ TBG w/2000psi. Prossum bled down to ~500psi ~th slight rotums. ~mssure up to 2000psi. Samo bleed off. , ~rossuro up to 2000psi on D~ and ~500 on Annulus. ~rossure in D~ oquilizod at ~ 500 psi samo as annulus pressuro(prob. ovorshot ~.O. ~oakin~). ~rossuro hold tight in Annulus. ~leed of D~ and annulus. Work stuck TBG w/50K over. ~ 0:00 ~3:00 3.00 AF ~GM~ GkTBG Set slips with 7k owrpull on T~G. ~rop. ri~ for coiled tubin~ operations. ~ 3:00 23:00 ~0.00 AF ~GM~ GkIBG ~SM p~or to ~ ~il tubing. BO~(250/3000psi). 23:00 03:30 4.50 AF PCM~ GkIBG GT ~ozo while pumpin~ plo. Thaw out GT. ~H GT injector. lost Cl rams on GT BO¢(350/3000psi). 03:30 05:00 ~.50 AF ~CM~ GkIBG RIH w/~.5~ GT. Wash ~om TOff to 352~'. 05:00 0~:00 ~.00 AF PCM~ GklBG 'Wo~ CT and a~ompt to wash ~ast 352~'. DENS,W(,p~) I 8.50 I PPI ECDI I MUD/_DATAJ~iLVCOs~.I 675.00 I cUMcos~ 9s77.00 26 /1 / / / / } :: 10~00/ :i~ I 14'800160 BHA D[SC~I~IIO~ 5 3/4" Overshot w/2 3/8" Orapplo, 5 3/4" Ovorshot top ext., Top sub, 4 3/4" Bumpor sub, 4 3/4" Oil Jar, 4 3/4" Drill collars (8), Acc. Jars, 4 3/4" ~ump out sub, 3 ~/2" IF-P X HT-3g-B, 4" ~4ppf S-~35 HT-3g D~ pERSONNEL DATA:: :: ~ ~: :~:: COMPLY SERVICE NO. HouRs: : ~: C0~p~y ::: :: -:sERViCE:: Inlet Drilling Alaska 16 192.00 Alaska Pipe Re~ve~ 1 1.00 Marathon 1 24.00 Baker Oil Tools I 24.00 M-I Drilling Fluids 1 24.00 Weaver Brothers 1 5.00 Pdnted: 3/14/2003 10:18:49AM WELL NAME KENAI UNIT 14-6RD GL 124 HR PROGITMD ITVD DATE 21.0 66.00 ~ 15-Jan-2003 BJ COMPANY I SERVICE PERSONNEL DATA 5 J 100.00 RandY s Glass .CASING' suMMARY :: :' :' ~'~.::: : ' - : . LAST BOP TEST: 1/11/2003 LAST CASING TEST: NEXT BOP TEST: I SIZE (in) I ID (in) SHOE TEST (ppg)J I / 7.000 MAxsICp : :: MD(fi) t:TVD(ff) ~ :wT(ib/ff) ,] . :G~DE ' (psi) @ (ppg) 4,616 ] 4,616 29.00] N-80 Printed: 3/14/2003 10:18:49AM : DailyW0rk°VerReP°~: i:! :: i~::i:;~: ~ :: ::~: i: : Wellb°reCle~n~t~': : i:-~i :: ~'i ":- 'i ' . KENAI UNIT 14-6P, D 21.0 66.00 0 12 13 14-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/I/vas COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI DAILY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 35,681.80 345,730.62 STATE/PROV COUNTY/OTHER LAST CASING J NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (fi) CURRENT STATUS / MTS 24 HR FORECAST ~IH w/overshot assy. Engage fish. Attempt to work free. OPERATION COMMENTS Engage fish @3234'. Work fish. Break circ. Pump sweep and circ. out. Fish came free while pullung 55K over. POOH w/fish. L/D 2 cut JNTS and 3 JNTS. M/U ext. cutter tool and RIH. MN.RSWORKED ACClOENTWPE ~ST SAFEW ~ ~OP PS, TEST ~TSTOPC.'~D^UD,T I RE~U~TORY~.SP? I~ST R,~,.SPECT,ON 278.00 None 11/13/2003 1/11/2003 1/9/2003I NJ 1/10/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pressure in tubulars that are full of sand. OPERATIONS SUMMARY i · ~ i ::-i~,i:::~ii~i::;ii, i FROM TO HRS FROM TO sUB pHASE:~: 0P : [~:i~B~;; .~'~:i: :. :~ ~ :: :i . ': : DESc'RiPTI~N~:; ~: i: :: :! : ~;: 06:00 07:30 1.50 AF PCMP FISH RIH w/overshot assy. 07:30 08:00 0.50 AF PCMP FISH Engage fish @ 3234'. Pull 55K over work string wt. Jar fish 4 times. Pressure up to 700psi pressure fell back 08:00 09:00 1.00 AF PCMP CIRC Circ. 4.5BPM w/195psi. Circulated up sand, mud cake and some gas. Printed: 3/14/2003 10:18:46AM ~2 ~3 ~4-Jan-2003 FROM TO HRS FROM TO SUB PHASE :OP TRBL : ~::. : DESCRIp~ON ~:: ' 09:00 09:30 0.50 AF PCMP CIRC Pump sweep. Circ. out sweep. Obse~ed some mud ~ke across shakers 09:30 10:00 0.50 AF PCMP ~FISH Pull 55K over string ~. Fish ~me free. No measurable increase in ~. Prepare to POOH. 10:00 12:00 2.00 AF 'PCMP FISH POOH. 12:00 13:30 1.50 AF PCMP FISH ~U/Wea~e~ord. PJSM prior to B/O tubing and ~D same. B/O first 2 3/8" TBG connection. Release fish from graple and ~D overshot assy. C/O elevators to 2 3/8" TBG. 13:30 14:00 0.50 AF PCMP FISH ~D the folowing 2 3/8" TBG: 2 cut stubs and 3 JNTS(APP 132') TOF now ~ +/- 3367'. TBG pa~ed due to damage while l washing over. 14:00 15:00 1.00 AF PCMP FISH ~D Weathe~ord and C/O elevators. 15:00 16:00 1.00 AF PCMP RIG Se~i~ TDS, blocks, ~o~, and ~ier. 16:00 17:30 1.50 AF PCMP FISH M/U cuEerassy. 17:30 20:00 2.50 AF PCMP FISH RIH and tag TOF ~ 3367'. 20:00 20:30 0.50 AF PCMP FISH Wo~ ~tter and washpipe over fish(stacked some weight wo~ing cu~er over fish). Tag up 6' high ~ 3519'. 20:30 21:00 0.50 AF PCMP FISH Pump sweep and drc out(ve~ li~e sand across shakers). P/U and pulled 20K over ~ 3514'. AEempt to make cut. 21:00 01:00 4.00 AF PCMP FISH BIowdo~ lines POOH. 01:00 02:00 1.00 AF PCMP FISH ~D 134' 2 3/8" TBG. Ddlled hole above each ~nnection to check for pressure. (4JNTS and 2 cut stubs, all tbg packed w/sand). New TOF 3501'. 02:00 02:30 0.50 AF PCMP FISH ~D cuEer and rack back washpipe(Iost 1 flipper dog and 4 knives out of cuEer tool). 02:30 03:00 0.50 AF PCMP FISH Dress overshot. 03:00 04:00 1.00 AF PCMP FISH P/U overshot assy. 04:00 06:00 2.00 AF PCMP FISH RIHw/overshot assy. I 0.s0 I,PI I col ;MUDDATAIDNLY;COs~I 1336.00 IcUM;CbST~ 9202.00 BHA D[SCRI~IIO~ 5 3/4" Ovorshot w/2 3/8" ~rapplo, 5 3/4" Overshot top oxt., Top sub, 4 3/4" Bumpor sub, 4 3/4" Oil Jar, 4 3/4" Ddl~ collars (g), Acc. Jars, 4 3/4" ~ump out sub, 3 ~12" IF-~ X H1-38-8,4" ~4ppf S-~35 H1-38 D~ COMPANY SERVICE NO. : HOUR~: ~:~ ::--: :COMpANy ;~ ' :: :~: SERVI~E: ;;:':: ; :;No; ::.', HOURs Inlet Drilling Alaska 16 192.00 Baker OiITools 1 24.00 Marathon I 24.00 Weathedord Completion 2 8.00 M-I Drilling Fluids I 24.00 Hallibu~on I 4.00 Alaska Pipe Recove~ I 1.00 S&R Enterprises I 1.00 cAS~N~ SUMMARY ~ ~ . LAST BOP TEST: 1/11/2003 LAST CASING TEST: NE~ BOP TEST: ,D<,n> I I I Pdnted: 3/t4/2003 10:18:46,AM Kfi~AI U~IT ~4-ORD 2~.0 gO.00 ~ ~ ~2 SUPER~SOR RIG NAME & NO. AUTH MD WBS S~BS COST RC Lawson Glacier Ddlling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 39,~4.46 310,048.82 STAT~PROV COUN~IOTHER ~ ~ST C~ING ~NE~ C~ING ~ L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS I ~S 24 HR FORECAST RIH W/overshot assy. Engage fish. OPE~TION COMMENTS M/U BHA~I. RIH. Engage fish. Dross cut and latch fish. Pull w/55k over work sking ~. Release ovemhot. POOH. UD ovemhot assy. P/U washpipe assy. RIH. Washover fish to top of Y-block. POOH. RIH w/ovemhot assy. SAFE'SUMMARY. ~ ~ ~ ~ :~'~: ~ ~ ~:~. ':~:~ .~ ' 2Og.00 ~one ~/~ 2/2003 ~/~ ~/2003 ~/~/2003 ~/~ 0/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPE~TiONs:SUMMARY ~ ~ ~ . FROM TO HRS FROM TO SUB pHAse OP ' ~BL ' : ~ DESCRIPTION ~ ':- : ~:. ::~ : 06:00 06:30 0,50 AF PCMP TRIP Cont. M/U overshot assy, 06:30 09:30 3,00 AF PCMP FISH RIH with overshot assy. 09:30 10:30 1,00 AF PCMP FISH Engage fish ~ 3234', Dross cut and latch fish, Work fish w/55k overpull, Release overshot, 10:30 12:00 1.50 AF PCMP ClRC CBU. Monitor well. 12:00 15:00 3,00 AF PCMP FISH POOH w/overshot assy, UD overshot, 15:00 16:00 1.00 AF PCMP TRIP P/U 5 3/4" washpi~, glO Tong line. 16:00 20:00 4,00 AF PCMP FISH RIH wi5 3/4" washpipe assy. Wash F/3178' to 3241 '(TOP,a235') 20:00 23:00 3,00 AF PCMP FISH Wash over fish F/3241' to 3525'(tag sand ~ 3370'), Pump a sweep~3487'. Tag top of Y-block ~ 3525'. 23:00 00:00 1.00 AF PCMP ClRC Pump sweep and circ, hole dean. 00:00 03:30 3.50 AF PCMP FISH POOH w/washpipe assy. Rack back 5 3~4" washpipe, 03:30 04:30 1.00 AF PCMP TRIP Dress overshot. 04:30 05:00 0,50 AF PCMP RIG BIowdo~ TDS and lines, 05:00 05:30 0,50 AF PCMP FISH RIHw/overshot assy. 05:30 06:00 0.50 AF PGMP RIG =Repair leak on tong line, OENSl~(ppg) I a.so [..~ ~CD ~MUD DATAI.-~~v cos~ ~ ~23.oo I~Cu~ cos~' 7~.00 BHANO.3 LENGTH291.03 EFFWT. IPICK UPI,S~cKOF~ROTWT'F;:~foR~UE;~a~i~:: 1BHAHRs:::I~ARHR~: ~IMW~HRS;IMTR;HRS~:ISS:HR~;:~ :' BHA DESCRIPTION 5 3/4" Overshot wi2 3/8" grapple, 5 3/4" Overshot top ext., Top sub, 4 3~4" Bumper sub, 4 3/4" Oil Jar, 4 3~4" Drill ~llars (8), Acc. Jars, 4 3/4" Pump out sub, 3 1/2" IF-P X HT-38-B, 4" 14ppf S-135 HT-38 DP PUMPi~HYD~ULIG~DATA~~::; :~:~: ~ : ~: ~ ~'~: ~ ~ NO. MAKE OF PUMP sTROKE (in) LiNER(]~) ~ :~S~M~: ~:~ (g~::: PRESS,:(Psi) '.TOTAL Q KILL SpM/~PRESSURE~:~ I NATIONAL 8.000 4.000 100 122.73 650 245.46 100 200 2 NATIONAL 8.000 4.000 100 122.73 650 245.46 100 200 Printed: 3/14/2003 10:18:43AM ' ' -Daily.W°rk°ver Report - · Wellbore Clean-out K~N^I U~IT 14-~RD 2'1.0 ~$.00 11 '12 13-Jan-2003 PERSONNEL.DATA- '- · ' ' _ ' POB @'06:00:' COMPANY SERVICE NO. HOURs COMPANY SERVICE NO.- HOURS Inlet Drilling Alaska 16 192.00 Alaska Pipe Recovery I 2.00 Marathon 1 24.00 Baker Oil Tools 1 24.00 M-I Drilling Fluids 1 24.00 Epoch Well Services I 2.00 - CASING SUMMARY - ' LAST BOP TEST: 1/11/2003 LAST CASING TEST: NEXT BOP TEST: Prinled: 3/14/2003 10:18:43 AM WellbOreClean~out ~i~i ~;:i~iii 'i '-;~ ii -~ .i:~ :'! i:i:i SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 40,005.36 270,204.36 STAT~PROV COUN~IOTHER L~T C~ING N~ C~ING ~ L~KOFF IAlaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) I CURRENT STATUS / ~S ~ 24 HR FORECAST M/U Baker Fishing BHA~I~ RIH W/BHA~I. Engage fish. AEempt to pull fish ~ee. OPE~TION COMMENTS ~IH and cut 2 3/8" TBG ~ 3235'. POOH ~D APRS. Circ. out gas. Rack back 2 3/8" TBG. ~D Weathedord. C/O upper pipe rams to 2 7/8" X 5 1/2" vadable rams. Test variable rams. P/U 4" DP. P/U fishing BHA~I. SAFE~SUMMARy' ~ · :~ · 2~ .00 ~one ~/~ 2/2003 ~/~ ~/2003 ~/~/2003 ~/~ 0/2003 OPE~TIONS SUMMARy ' ' · FROM TO HRS FROM TO SUB PHASE Op ~BL: DEsCRiPTiON 06:00 07:30 1.50 AF PCMP FISH RIH W/1 13/16" Jet cu~er. Cut 2 3/8" TBG ~ 3235'. POOH ~D APRS. 07:30 09:30 2.00 AF PCMP EQUIP Pull hanger to floor. Remove i~ from crown. ~D long bales and TDS ~reline ent~ sheave guide. 09:30 10:00 0.50 AF PCMP PLRNRP ~U Wea~edord and UD Vet~ TBG hanger. 10:00 12:00 2.00 AF PCMP CIRC Circ. out 3.2BPM W/426psi. Had gas ~ boffoms up. Finish circ. out ~rough choke. 12:00 14:30 2.50 AF PCMP PLRNRP Blow down choke and mud line. POOH rack back 2 3/8" TBG(103 jnts, 1cut jnt, and ~o pups pulled). 14:30 19:30 5.00 AF PCMP EQUIP ~D Weathedord. ~U dg manual tongs. C/O elevatom to 4" . DP. Adjust torque tube. C/O upper pipe rams Eom 2 3/8" to 2 7/8" X 5 1/2" variable bore rams. 19:30 20:30 1.00 AF XMBO TEST Run test plug and 4" test JNT. Test 2 7/8" X 5 1/2" variable rams 250/3000psi 10min. Pull test plug and UD test joint. Install vet~ wear bushing. ~U to P/U 4" DP. 20:30 00:00 3.50 AF PCMP TRIP PU 4" 14ppf s-135 HT-38 DP(rabbit all joints). 00:00 03:30 3.50 AF PCMP TRIP PJSM pdor to P/U DP. PU 4" 14ppf s-135 HT-38 DP(rabbit all joints)(120 jnts total). 03:30 04:30 1.00 AF PCMP ;TRIP Strap and ~lly BHA~I. 04:30 06:00 1.50 AF PCMP TRIP M/U Baker Fishing Assy ~1. DENS~(ppg) I ~.50 ~PPI LCDI MUDDATAI~D~L¥COST'I ~255.00 I:CUMc°s~ 5942.00 I 8~A ~ESCRI~IIO~ 5 3/4" Hollow mill w/cut lip ~uido, 5 3/4" Ovorshot w/2 3/8~ Orapple, 5 3/4" Overshot top oxt., Top sub, 4 3/4" Bumpor sub, 4 3/4" Oil Jar, 4 3/4" Drill collars (g), Acc. Oars, 3 ~/2" IF-~ X HI-38-B, 4" ~4ppf S-~35 HT-38 D~ Printed: 3/14/2003 10:18:40,AM ~i Daily workover.'Repo~ ii i · .. Wellbore Clean~O~t :' K[~I U~II ~4-ORD 2~.0 ~.00 ~0 ~ I ~2-~an-2003 : PUMPt HYD~UEIC DATA · PERSONNELDATA~ :~ ;: ~ ~ ~:: pOB~ 06:00~:: - COMPLY SERVICE NO. . HOURS : ~ COMpANy· SERVICE :: NO; ;:' HOURS Inlet Drilling Alaska 16 192.00 Alaska Pipe Re~ve~ 3 8.00 Marathon 1 24.00 Wea~edord Drilling &Int 2 16.00 M-I Drilling Fluids 1 24.00 Baker Oil Tools 1 18.00 ABB Vet~ Gray 1 5.00 !R&K Industrial 1 4.00 CASING SuMMARY~: ~ST BOP TEST: 1/11/2003 LAST CASING TEST: NE~ BOP TEST: 7.000 (psi) ~ (pp~) 4,~ I 4,~ 20.00 ~-80 Pdnted: 3/1412003 10:18:40,AM D ly'ai~ :---'-!WOrkoverReport:: :' ::: ~ ~' : . . WellbOre ~Clean;OUt: ~ . Kfi~AI U~lI ~4-ORD 2~.0 ~.00 ~0 ~-Jan-2003 SUPERVISOR RIG NAME & NO. A~H MD WBS SAP--S COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST J CUM WELL COST KENAI 907-283-1312 100.0000 26,165.00 ~ 230,199.00 STAT~PROV COUN~IOTHER I ~ST C~ING JN~ CASING ~ L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) I (in) ~ 0 (fi) CURRENT STATUS I MTS 24 HR FORECAST Prepare to RIH w/1 13/16" Jet cutter. Cut tubing and POOH. RIH and latch fish. OPE~TION COMMENTS Test BOPE. ~U and aEempt to pull 2 3/8" production TBG. TBG stuck. ~U to run FPI. Run 1 13/16" Gauge. Run 1 3/8" FPI. SAFE~ SUMMARY 287.00 None 1/11/2003 1/10/2003 1/9/2003 1/10/2003 ACCIDENT DESCRIPTION: SAFE~MTG TOPICS: E-line operations. OPE~TIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP ~BL DESCRIPTION 06:00 12:00 6.00 TA XMBO TEST BOP Flange connection be~een mud cross and double gate leaked. N/D ~nnection and repla~ ring gasket. 12:00 17:30 5.50 AF XMBO TEST Test Annular, upper pipe and blind rams to 250/3000psi 10 min.' Test inside and outside kill line valves, inside choke, HCR, check valve, and 1-12 choke manifold valves to 250/3000psi 10min. Test 2- 2 3/8" safe~ valves, 2- 2 3/8" IBOP valves, 4" safe~ valve, 4" IBOP, upper and lower TDS valves, 4" mud pump shut-in valves to 250/3000psi 10min. Pedorm accumulator pedo~an~ test. 17:30 18:00 0.50 AF XMBO TEST Pull TWC. M/U landing joint w/safe~ valve into tubing hanger. B/O tubing hanger lock downs. Remove i~ from derdck. Dig hole in ~llar for mouse hole. Found electi~l ~ble in ~llar. 18:00 00:00 6.00 AF PCMP RIG Remove crew from ~llar ~ile electrician investigates electdc ~ble. Electrician turned power ~ble off. Complete digging hole in cellar for mouse hole. Install trip tank hoses, pump, valve, actuator and turnbuckles. Blow down choke. H/U rota~ lock and floor draines. Air up flow line boots. Install mouse hole. 00:00 01:00 1.00 AF PCMP PLRNRP Pull 53K on 2 3/8" TBG. TBG stuck. Work stuck TBG. ~U 2 3/8" head pin and circulating hose. Pressure up to 2000psi on TBG. Bled down to 1985 in 5 min. Repeat with same results. ~D circulating hose. Pull 58K on TBG. TBG stuck. ~D LJ. 01:00 02:30 1.50 AF PCMP WIRELN ~U long bales and wireline ent~ sheave guide. 02:30 06:00 3.50 AF PCMP WIRELN ~U APRS. P/U LJ w/safe~ valve. Screw into hanger. PJSM 3rior to E-line operations. RIH w/1 13/16" gauge. Tag fill at 3248' POOH. RIH w/1 3/8" FPI. Free ~ 3009' and 3245' POOH. I I,.I I=c lIMUDDATAI:DAILYCOST] 1592.00 ICUMcoST 4687.00 Printed: 3/14/2003 10:18:38 ,AM DailYW°rko~er-RepO~ ~Wellbore clean'°~t i ~~,~.~ ~.o ~.oo I~"~ ~ · PERSONNELDATA:: COMPANY SERVICE NO. I HoURs '.coMPlY-. ;sER~CE: : NO. ~HOURS Inlet Drilling Alaska 16 192.00 AOGCC 1 12.00 Marathon 1 24.00 Alaska Pipe Re.yew 3 21.00 M-I Drilling Fluids 1 24.00 Weathedord Drilling & Iht I 1.00 ABB Vetco Gray 1 5.00 Sue Rask 1 8.00 :. cASING sUMMARy: ~ST BOP TEST: 1/10/2003 ~ST CASING TEST: NE~ BOP TEST: Printed: 3/14/2003 10:18:38AM WellboreClean~out~ ~. : : ~:i i~I~ i:i': : :/i::i SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI N~ D~LY WELL COST CUM WELL COST KENAI g07-283-1312 100.0000 26,072.00 204,034.00 . STAT~PROV COUN~IOTHER ~ ~ST C~ING ~ N~ CASING ~ LE~OFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / MTS 24 HR FORECAST Test BOPE. Test BOPE. Pull 2 3/8" TBG. OPE~TION COMMENTS N/U BOPE. Test BOPE. Trouble shoot koomey PLC and repair leaks on stack and choke and kill lines. sAFETY SUMMARY :~ ~ . . 254.00 ~one ~/~/2003 s~~o~o~cs: Winter hazards 0~:00 ~2:00 ~.00 AF XMSO ~H~D ~/~ ~" 3M X ~3 5/g~ 5M DSA and ~3 fi/8" 5M spa~r ~3 5/8~ Schaffer SRdA BO,(had to ~/~ all ~nnecfions, roustabout crow did not romove ~rease from ~n~ ~rooves). ~2:00 2~ :00 ~.00 IA XMBO ~U~D BO~ Removo choke and kil lino valvos from mud cross and cloan ~roaso from ~n~ ~rooves. ~/~ choko and kill line valves on mu, cross. Hammor up all flan~o bolts. Install koomoy lines. 2~:00 00:00 3.00 IA XMBO T~ST BO~ ~SM p~or to testin~ BO~E. Charoo up koomoy. ~ull B~V and install ~C. Func~on Stack. ~llers BO~ ~nsole not working. Trouble shoot k~mey whilo ~/~ bell nipplo and flow lino. 00:00 03:00 3.00 AF X~BO ~ Cont. ~/~ bell nipple and flow line while troublo shoot koomey problem(find C~ gad on PkC ~rd on koomey). 03:00 0~:00 3.00 1~ X~80 lfiSI BO~ ~ 2 3/8" tostjoint and test a~a~nst annular. Repair followino leaks: be~een mud cross and douglo oato, choko lino ote~ ~nnection, leak on kill lino manual valvo flanoo, and door seal on pipe rams. I .s0 MUDD~*~l°~cYc°sl 30os.00 IcUMCOs* 2~ /~ / / / / ~ ~0.00/ / / I ~s.°00~e°~l - co~v s~v~c~ ~o: ~.ou~s ~:.~ ~:::?. co~v.., ~:~ ~: :~s~v~c~ lnlot DdHin~ Alaska ~g ~2.00 M-I Drillin~ Fluids ~ 24.00 Marathon ~ 24.00 ASB Vot~ Gray ~ 5.00 Woavor Brothers ~ 3.00 AOGGG ~ 4.00 Veco Alaska 2 2.00 7.000 (ps) ~ (pp~) 4,~ ~ 4,~ ~ 2~.00 Printed: 3/14/2003 10:18:35AM 'MARATHON_OIL_COMPANY-_ ~. . . ' page1 of 2- Daily W°rkover Report -' '- - - - Wellbore Clean-out KENAI UNIT 14~6RD 21.0 66.00 09-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/VVBS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI DALLY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 36,974.00 177,962.00 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST N/U BOPE. N/U BOPE. Test BOPE. Pull 2 3/8" TBG. OPERATION COMMENTS Continue R/U rig. Pull BPV and fill TBG and Annulus. Set BPV. N/D tree. N/U BOPE. - SAFETY SUMMARY' - 265.00 None 1/9/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: N/U. OPERATIONS SUMMARY - . FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 12:00 6.00 AF MIRU RIG Function mud pumps. Switch wires on lube and flush pumps to correct positions. Reposition BOP stack and remove HCR and Kill line valves. PJU kill line and bleeder hoses to dg manifold. Function bddge cranes in sub base. Continue to trouble shoot top ddve. Found bad wire and releif valve sticking. 12:00 01:00 13.00 AF MIRU RIG Repair TDS and function test. R/U rig floor rotary tools. PJU super choke and pump sensors. Prep and start rig water circulation. Repair #1 mud pump rheostat. P,/U koome¥ lines. R/U tong lines. C/O rheostat in #1 mud pump. Function test TDS hydraulics and rotation. Function test ~ mud pump. Install 1502 hub connection on kill and choke lines. Function test~l mud pump. Dial in stroke counters. R/U Mud Eng. camp water. Remove plug from water circulation line in carrier. R/U gas detectors and test. 01:00 01:30 0.50 AF WBPR WLCNTL Check TBG X CSG annulus pressure 0psi. Remove gauge and open annulus valve. Small amount of gas blow. Close annulus valve. Prepare to pull 2" BPV. 01:30 02:30 1.00 AF WBPR WLCNTL PJSM pdor to bleed off well. Pull 2" BPV. No pressure below valve. R/U kill line to TBG and PJU choke line to annulus. Fill TBG w/lbbl 3%KCL. Pressured up to 200psi. Bleed off ~ressure and PJD kill line. 02:30 03:00 0.50 AF WBPR WLCNTL Bleed gas off of annulus through choke line(no pressure). PJD choke line and PJU kill line to annulus. Pump 1 bbl 3% KCL into annulus. Pressure up to 200psi. Bleed pressure off and PJD kill line. Set 2" BPV. 03:00 04:30 1.50 AF XMBO NUND PJSM prior to N/D/NIU. BIowdown lines. N/D tree. 04:30 06:00 1.50 AF XMBO NUND N/U BOPE. PERSONNEL DATA .' . PCB @ 06:00: COMPANY NO'6 I 192.00 IIMarathon 1 _4.00 Inlet Drilling Alaska Printed: 3/14/2003 10:18:33,AM Io · : :PERSONNEL DATA ~ ~ : ~ :: : POB:~ 06;00::~ COMPLY SERVICE NO. HouRS : ~coMP~Y ~ : SERVICE · ~ ' NO. : : HOURS Weaver Brothers 1 12.00 S&R Enterprises 1 1.00 Ve~ Alaska 2 6.00 Alaska Oil Sales 1 1.00 M-I Drilling Fluids I 24.00 ABB Vetco Gray 1 5.00 cAsING SUMMARY : ~ :~ : ~ :;. - . ::~ ~;~ :: ~;' ~ST BOP TEST: LAST CASING TEST: NE~ BOP TEST: SIZE(in)7.000 IID(in) SHOE TEST (ppg~ (psi)M~ SICP~ (ppg) I: MD(~):'14,616 wD (~)~ ::WT (Ibifl):14,616 29.00 G~DEN-80 IBURST (psi) Pdnted: 3/14/2003 10:18:33 AM :: ~ ~ellbore clean.°~t ::~ KENAI UNIT 14-6RD 21.0 66.00 7 0g-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD 'WBS S~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ N~ ~ D~LY WELL COST ~CUM WELL COST KENAI 907-283-1312 100.0000 J 24,938.00 ~ 140,988.00 STAT~PROV COUN~/OTHER ~ ~ST CASING ~N~ CASING I L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / ~S 24 HR FORECAST Trouble shoot electrical problem w~DS. Cont. ~U dg. Check well for pressure. N/D tree. OPE~TION COMMENTS Cont. rig up rig and prepare BOP stack. SAFE~SUMMARY ~ 2~2.00 I~ono ~/4/2003 OPE~TIONS SUMMARy FROM TO HRS FROM TO SUB pHASE OP ~BL ~ DEsCRIP~ON: . 06:00 12:00 6.00 AF MIRU RIG Clean and install torque tube turn buckles. Repair fan in mud pits. Weld grading in mud pits. Repair ~ charge pump. Run hyd. lines to tdp tank pump. ~U Epoch dg watch system. ~lnstall slide for top drive. Inspect tugger lines and P/U top drive. Se~ice dg. 12:00 00:00 12.00 AF MIRU RIG Raise ~ndwalls and prep de~ick board. Install snub post. Adjust torque tube. ~U top drive slidder and se~ice lines. new top drive se~ice line ~rp. Se~ice top drive. Mix 3% KCL ~n pi~. Instil dennison ddve line on ~ ~rder motor. Install bales. Tighten de~ck turnbuckle. N/U BOP stack (not on well). Set BOP stack close to sub. M/U s~ndpipe manifold and bleeders. 00:00 06:00 6.00 AF MIRU RIG Repair and install exhaust one2 gen set. Trouble shoot and repair lube pumps on mud pumps. Reposition BOP stack and remove HCR valve. Free up gates in mud ditch. Trouble shoot electri~l problem on top drive. . : pERSONNEL DATA ~:': COMPLY SERVICE NO. ~ 'HouRS ~.~ : '::COMPANy ~..: ~ ~ : ~ ~ S~RVlCE :~: ~ ~' N~: :, HOURS~ Inlet Drilling Alaska 16 192.00 Big G 1 2.00 Marathon 1 24.00 Ve~ Alaska 1 2.00 Alaska Petroleum Contra 3 36.00 M-I Drilling Fluids 1 24.00 Weaver Brothers 1 12.00 ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: Printed: 3/14/2003 10:18:30,AM MARATHON OIL-COMPANY ' ~.- Page1 of 1" I Daily Workover Report- '"-wellbore Clean-out ' _ . . KENAI UNIT 14-6IRD 21.0 66.00 6 07-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/WBS COST IRC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOO WI NRI I DAILY WELL COST I CUM WELL COST KENAI 907-283-1312 100.0000I 28,790.00 J 116,050.00 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (fi) (n) @ 0 (fi) I CURRENT STATUS / MTS I 24 HR FORECAST R/U rig.I Cont. R/U dg and camp. OPERATION COMMENTS Cont. PJU rig. SAFETY SUMMARY - . 282.00 None 1/4/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY . FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 12:00 6.00 AF MIRU RIG Install rotary hyd. motor. Begin IR/U ddllers console. 12:00 00:00 12.00 AF MIRU RIG Cont. R/U camp. Install 4" liners in pumps, clean welding debris from mud pits. Complete R/U of choke lines to choke house and degasser. Install splash guards. Run water line frorr well to rig. Hook up break linkage. C/O ball joint connector. Install cylinder socks on derrick hyd. cylinders. Thaw valves in pitts. Fill pits with water. Hook up drillers console. Apply heat to carder, thaw air lines. Start building torque tube. 00:00 06:00 6.00 AF MIRU RIG Cont. build torque tube. Thaw air on carrier to drum clutch. R/U septic alarm. Cont. to fill pits with water. · ' PERSONNEL DATA ' -:-- - * · -POB @-06:00: - COMPANY SERVICE NO. HOURS· ' COMPANY _ · _ SERVICE - _' i NO... -HOURS· Inlet Drilling Alaska 16 192.00 Weaver Brothers 1 12.00 Marathon 1 18.00 M-I Drilling Fluids 1 24.00 Alaska Petroleum Contra 3 36.00 CASiNG-SUMMARy - · : ..-' - :- '-. - i LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE (in) ID (in) SHOE TEST (PPgl .MAX SlOP t MD (ft) -I-VD (ft) WT'(Ib/fi) .. _:GRADE-' BUIRST (psi) 7.000! (psi) @ (PPg)I 4,616 4,616 I 29.00 N-80 Printed: 3/14/2003 10:18:28 AM · Daily_Workover Report-- - Wellbore clean-Out KENAI UNIT 14-6RD 21.0 66.00 4 5 06-Jan-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/VVBS COST RC Lawson Glacier Drilling 1 WO.02.07939. EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST KENAI 907-283-1312 100.0000~ 24,734.00 I 87,260.00 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (fi) I CURRENT STATUS I MTS 24 HR FORECAST R/U rig. Cont. R/U rig and camp. OPERATION COMMENTS Continue to PJU rig and camp. SAFETY SUMMARY ' .' . ' .' ' 222.00 None 1/4/2003 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY . FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIPTION 06:00 12:00 6.00 AF MIRU RIG Install tdp tank. Set cat walk. Install beaver slide and landing. Install back windwalls. Bolt on carder motor mufflers. Run water lines to camp. Heat trace and insulate 4" line for dg water tank. Take on water. 12:00 00:00 12.00 AF MIRU RIG Finish RJU of carrier motor mufflers and stacks. R/U steam,air and water lines. Pull and connect electric lines. Scope up derrick. Tighten tumbuckles. 00:00 06:00 6.00 AF MIRU RIG Heat up boiler slowly. Run steam around rig. Fix steam leaks. R/U carder tarps. R/U panic line. R/U poor boy degasser. Thaw out lift station. Check out centrifugal pumps. Inspect derrick. PERSONNEL'DATA '~ . · ' . _-'- - _ POB @-06:00:. , COMPANY SERVICE NO. HOURS . COMPANY SERVICE - · NO.' 'HOURS Inlet Drilling Alaska 16 192.00 M-! Drilling Fluids 1 12.00 Marathon 1 18.00 CASING SUMMARY - - ' - -. -' -' ' : - _ LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE(in) ID(in) IHOE TEST (ppgt MAXSICP ' MD(fi) TVD(ft) I WT(lb/ff)I 'GRADE' .BURST(psi) 7.000 (psi) @ (ppg) 4,616 4,616 29.00 N-80 Pdnled: 3/14/2003 10:18:26 AM - DailY WorkOverRePort i ~ ~WellbOre clean,out K[~AI U~IT ~4-OR~ 2~.0 ~.00 4 05-Jan-2003 SUPERVISOR RIO NAME & NO. AUTH MD ~WBS S~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST ~ CUM WELL COST KENAI 907-283-1312 100.0000 19,900.00~ 62,526.00 STAT~PROV COUNt/OTHER ~ST C~ING ~N~ CASING J LEAKOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi)~ (in) ~ 0 (fi) I CURRENT STATUS I MTS 24 HR FORECAST ~U rig and ~mp. Cont. ~U rig and ~mp. Will go on 24hr work today. OPE~TION COMMENTS Continue to ~U rig and camp. ~SAFE~ SUMMARy · . 2~7.00 ~one ~ ~/4/2003 ACCIDENT DESCRIPTION: SAFE~ MTG TOPICS: Safe rig moves. OPE~TIONS SUMMARY FROM TO HRS FROM TO SUB pHASE OP TRBL 07:00 19:00 12.00 AF MIRU RIG Instil sub outriggers. Raise windwalls. ~U flood lights and handrails. Set choke house on sub and ~U lines. Install ~ffier landings and stairs. ~U Rig floor stairs, flow line, and back landing. Raise derdck. Install electri~l ~alk and pull wires. Install BOPE mat under doghouse. Move in and set up ~mp trailers and generator house. Set and berm lift station and holding tank. Install new s~irs and landing for IMng quaders. Vecco crew modi~ing plumbing in living quaders. Change out de~ick climber line. Note: Safe~ meeting at gas field o~ce from 08:30hfs to 10:00hrs on rig move safe~. PERSONNEE DATA:. COMPLY sERvIcE, NO. HOURS; .... :- COM~Y -~ :~;:~ .: · -~ERVICE ~ :. ~ . ~ yNO.': :::HOURS Inlet Drilling Alaska 16 192.00 Alaska Petroleum Contra 4 48.00 Weaver Brothers 2 24.00 Ve~ Alaska 3 21.00 Marathon I 12.00 , ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg~ M~s,C. 7.000/ (psi)~ (PPg) I 4,616 I 4,616 29.00 U-80 I Printed: 3/14/2003 10:18:23 AM ~ DailyWOrk°verReP°~ :::. :iii~:i ~; ~i~::~ :~:ii~: :i.-i: KE~AI U~IT ~4-~D 2~.0 0~.00 3 04-Jan-2003 SUPERVISOR RIO NAME & NO. A~H MD WBS SAP~BS COST RC Lawson Glacier Ddlling I WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC ~ NRI D~LY ~LL COST J CUM WELL COST KENAI 907-283-1312 100.0000 19,900.00~ 42,626.00 STAT~PROV , COUNt/OTHER ~ST C~ING N~ CASING J L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / MTS ~ 24 HR FORECAST ~U rig.J Cont. ~U rig and ~mp. OPE~TION COMMENTS Cont. transpo~ rig equipment to Io~tion. ~U rig. SAFE'SUMMARy :~ ~; ~: ::~ ~ ~ ~ ~ - 2~8.00 ~ono ACCIDENT DESCRIPTION: SAFE~ ~G TOPICS: OPE~TIONS SUMMARY : ~ ~ 07:00 19:00 12.00 AF MIRU RIG , n bddge ~anes and lights in sub. Set remainder of of rig mats. Set mud pit trailer, generator house and boiler house. Set ~1 and ~ water ~nks. Set cuttings tank. Crane in rig fuel tank. Install doghouse outdggem and tmlly's. Instil floor plates, and v-d~r ~nd walls. Instil de~ck board. Spot ~rrier on mudboat. Remove more equipment from storage at office pad. Raise sub base and pin. Install sub doom. Load trailem at offi~ pad and prepare and tran~od to dg site. Set mech. shop and pads house. Set up welding house. Modi~ stack on ~ generator. Modi~ landing for electd~l ~res .; PERSONNEEDATA~/;;?.;';~:~'~ ~:~?:;~ :;~:.~; ~POB.~.~06~;~;00 :;~ COMPANY SERVICE ' , NO~ ~ [ ........... ~ ..... ; ........ ~ HOURS '~ ~;COMP~Y~ ~ -~ ~: ~ 'SERVICE ;~ .~ ~ :NO;' ~:HOURS- Inlet Ddlling Alaska 16 192.00 Marathon 1 12.00 Weaver Brothers 4 40.00 Alaska Petroleum ~ntra 2 24.00 cASINGSUMMARY~:'~ ~; ~ ':~;~: ~ ;~:~¥~:~;~;~/~;. ~ ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: 7.000 (psi)~ (pp~) 4,~ I 4,~ I 4,~.00 / ~-~0 Printed: 3/14/2003 10:18:21 AM - MARATHON OIL CoMPANY --"'-i'__:"- - '/ Pagel-ofl-. : ·Daily. Workover.Report-'__ _ - _ · Wellbore clean-oUt Kfi~AI U~lI ~4-OR~ 2~.0 ~.00 03-~an-2003 SUPERVISOR RIG NAME & NO. AUTH MD ~ SAP~BS COST RC Lawson Glacier Drilling 1 WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE MOC WI NRI D~LY WELL COST CUM WELL COST KENAI 907-283-1312 100.0000 20,150.00 22,726.00 STAT~PROV COUNt/OTHER ~ST C~ING'1NE~ C~ING ~ L~KOFF I I Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS I ~S ~ 24 HR FORECAST ~U rig.~ Cont. ~U dg. OPE~TION COMMENTS Rig released from modifi~tions at APC yard 01/0~2003. Move rig F/APC to Gas Field and begin ~U rig. SAFE~ SUMMARY ...... · 284.00 ~one ' OPfi~TIO~ S~~RY . ~ ' . FROM TO HRS FROM TO SUB PHASE Op ~TRBL ' DESCRIP~ON · 07:00 19:00 12.00 AF MIRU RIG Rig released from modifi~tions at APC yard 01/0~2003. Prop loads. Transpod dg ~mponents from APC yard to Kenai Gas Field. Set up change house and ~nnect electd~l ~ring and ~mp generator. Remove dg equipment from storage at Gas Field. Load rig mats. Lay liner and set dg mats. Stage loads and set sub base. Set mud boat. Set mud pump trailer. · . PERSONNEL DATA_ ' ~ - -; -'_ ' POB'~ 06:00: COMPAN~ SERWCE . NO. HOURS .' 'coMp~-' S~Rv~CE .. '- .O:' 'HouRs' Inlet Drilling Alaska 16 192.00 Marathon 1 12.00 Weaver Brothers 4 40.00 Alaska Peffoleum Contra 4 40.00 CASING-SuMMARY . . _- . _ _-- . ."- . _.. _. ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: 7.000 (psi) ~ (ppo) 4,~ I 4,~ I 2~.00 ~ ~-80 Printed: 3/14/2003 10:18:18,AM KENAI UNIT 14-6RD 21.0 66.00 1 20-Dec-2002 SUPERVISOR RIG N~E & NO. AUTH MD was s~s COST Wayne Cissell WO.02.07939.EXP 369,000 FIELD NAME RIG PHONE ~C ~ NRI D~LY WELL COST J CUM WELL COST KENAI 100.0000 2,576.00~ 2,576.00 STAT~PROV COUNt/OTHER ~ST CASING J N~ CASING J L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi)J (in) ~ 0 (fi) I CURRENT STATUS I MTS ~ 24 HR FOREC~T I OPE~TION COMMENTS Loaded tubing and annulus with 3% KCI. ~SAFE~:SUMMARy 0.00 ACCIDENT DESCRIPTION: SAFE~ ~G TOPICS: OPE~TIONS SUMMARY ' FROM TO HRS FROM TO- SUB PHASE ' OP' ~BE : : ~ ~ ~ ~: :DEsCRiPTiON.: : 09:00 17:30 8.50 AF WBPR ClRC RU BJ pumping unit on annulus. Test lines to 1000 psi. Loade( annulus with 91 bbls of 3% KCl using pump & bleed technique. RD from annulus onto tubing. Test lines. Pump 10 bbls of 3% :KCI do~ ~bing using pump & bleed. RDMO pump track. ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: 7.000 Printed: 3/14/2003 10:18:16 .i-THF: 20.05' APl: 50-133-i0089-01 AOGCC: 74-50 256' FSL, 964' FWL Sec. 6, T4N, RllW, S.M. Tree cxn: .4-3/4" Offs .iff threads: 2-318" EUE 8rd Tubing head drawing ITubin~: 2-3/8", 4.7 ppf, J-55, EUE 8rd Perfs {Stedin.q Pool 3): ~,8, 3540' - 3574' CBL Al0, 3636'-3678' CBL A11, 3700'-3740' CBL I PBTD - 3839' TD - 5345' =is.._.b.h: 3138" gun assembly, 3725' - 3839' rop of cut dual tubing strings @ 3839' Otis RHD dual packer @ 3843' Not_._~e: Longstring and shortstring tubings are )lugged below the dual packer. I7", 29 ppf, N-80, LTC & BTC casing @ 4616' Cmt with 775 sks of class G plu.q~in.cl detail below dual pkr Well Name ~ KU 14-6rd Last Revision Date: Kenai Gas Field, Pad 14-6 KOP TVD [ RKB: ] 10Ii 7/02[ KfiNA~ ~IT ~4-~RD 2~.0 00.00 ~5,047 ~5,047 0 24 22-~ov-2002 SUPERVISOR ~G N~E & NO. AUTH MD WBS S~ COST Wayne Cissell WO.02.07~4.EXP 553,550 =IELD NAME RIG PHONE M~ WI N~ J D~LY WELL COST CUM WELL COST KENAI 100.0000~ 2,756.00 391,690.00 STAT~PROV COUNt/OTHER ~ST CASING N~ C~NG I L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) I CURRENT STATUS / MTS J 24 HR FORECAST ~RIH to tag fill, bail out to veri~ if well bridged w/sand~ bail sand as far do~ as we ~n : OPE~TION COMMENTS Evaluate the fill in the tubing as to if bridge or mud behind tubing SAFE'SuMMARy ; .~ ~ ~ ~ : :~ '. 233.00 ~ono ~ 0/~ ~/2002 ~ 0/~ ~/2002 ACCIDENT DESCRIPTION: SAFE~ MTG TOPICS: ~OPE~TIONS SuMMARy ; . ~ · ~ . FROM TO HRS FROM TO SUB PHASE OP TRBL ' ' DEsCRIP~ON 07:30 19:30 12.00 RU WL unit on wellRU WL unit on well MU 1.75" dd bailer W/est barrel, RIH to 3243' KB. work bailer POOH OOH ~th bailer, bailer ~11 of mud & fluid. RIH ~th same tool string to 3252' KB, work tool string POOH OOH ~ bailer, bailer ~11 of mud & fluid. RIH ~ same t~l string to 3252' KB, work tool string POOH WoA tool sting all day repeating the above schedule worked tool s~ng do~ to 3265' KB No real progress RD tool string PERSONNELDATA ~;:.::: ~; ::: : ~; :. :: ~: ~ ~ POB ~:06:o0~: ~: . COMPLY SERVICE NO..~HOURS ~ ; C0Mp~¥: ~ ;::~. ;;: ' ~: SERVICE; ~: ;: :NO:~ ~' HOURs Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 Toloff Cranes 1 8.00 R&K Industrial 2 8.00 ~ST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 7.000 ~.27~ (psi) ~ (pp~) 4,~ 4,~ 2~.00 ~-80 7,240 Printed: 3114/2003 10:11:11 ,AM OailYReC°mPletion ReP°:~i :~ : Kfi~AI U~ll ~4-~R~ 2~.0 0~.00 ~5,047 ~5,047 2~ 2~-~ov-2002 SUPERVISOR RIO NAME & NO. AUTH MD WBS S~BS COST Wayne Cissell WO.02.07444.EXP 553,550 FIELD NAME RIG PHONE MOC WI NRI D~LY WELL COST CUM WELL COST KENAI 100.0000 3,880.00 388,934.00 STATWPROV COUNTY/OTHER ~ ~ST CASING N~ CASING ~ L~OFF Alaska Kenai~ 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) I CURRENT STATUS / ~S 24 HR FORECAST Complete Shut in to evaluate OPE~TION COMMENTS Re~vered tool string and all 1.25" wire out of hole. Tagged fill after mcove~ ~ 3265' KB SAFE~ SUMMARY, ~ MANHRS WORKED ACCIDENT ~PE ~ST SAFE~ ~G BOP PSI TEST ~ ~T STOP CARD AUDIT REGU~TORY INSP? J ~ST RIG INSPECTION I N I 233.00 None 10/16~2002 10/11/2002 ACCIDENT DESCRIPTION: SAFE~ ~G TOPICS: OPE~TIONS SUMMARY FROM TO HRS FROM TO SUB pHASE OP TRBL DESCRIP~ON 07:30 15:45 8.25 PUH PWL operatora~ived. Discuss todays opeations. Sta~ up unit, WHP = 0 psig on tubing and ~sing = 0 psig. Note: PU weight has gained 200 lbs ~en picking up on tool ;string. BoEom t~l string loose, boffoms out at 3193' KB (appeam to boffom out on bridge be~een the tool s~ngs). Sets do~ at 3231' KB. /tool stdng moving 38' before bo~oming out. Sta~ wo~ing tool string up to 3193' KB, No movement over night on tool s~ing. Tools seeing down at 3219' KB. Topping out at 3199' KB. Plug moving up hole ~th both tool strings. Tool sheared, pin weak from ~o days of jaring and wo~ing tool stdng. POOH OOH m pin tool RIH ~th 2" SB lat~ fish ~ 3131' KB. wo~ t~ls up and down, t~ing to get the bridge be~een tool stdngs to break loose. PU to 3106' KB. Tools ~me Eee p~h with fish. String stdp wire when tools at sudan. Work wire out of hole to fish. SLipped out 170', all wire re~vered. Lay down old tool stdng. MU a I 1/4" bailer to tag fill. RIH to 3265' KB, POOH. Recovered mud and water in bailer. , RD unit. '~. ~ PERSONNEL DATA . ~.. ~ ~ ~ .:~ ~ .: . ' : ~.POB~06~O0~ COMPLY SERWCE 'NO. HOu.s :eO~P~. : ::~ SE.V~CE ~ ~ .O:: :, HOURs Glacier Ddlling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 Toloff Cranes 1 8.00 R&K Industrial 2 8.00 Pdnted: 3/14/2003 10:11:09AM :DailY RecOmPleti°n Rep°rt:_ __ __-_ _ ~lncrease production 2~.0 66.00 15.047 WELL NAME KENAI UNIT 14-6RD CASING SUMMARY LAST BOP TEST: 10/11/2002 SIZE (in) ID (in) SHOE TEST (PPgl 7.000 6.276 / LAST CASING TEST: NEXT BOP TEST: MAX SICP I MD(fi) :l TvD(ft) WT(ib/ft) I GRADE (psi) @ (ppg) 4,616 I 4,616 26.00 N-80 10/18/2002 7,240 Pdnted: 3/14/2003 10:ll:09AM : DailY RecOmpletion'RePO~ ~ : :~/~ ~.: ~ ~i KENAI UNIT 14-6RD 21.0 66.00 15,047 15,047 0 23 20-Nov-2002 SUPERVISOR RIG N~E & NO. AUTH MD wes SAP~BS COST Wayne Cissell WO.02.07444.EXP 553,550 FIELD NAME ~RIG PHONE MOC ~ NRI D~LY WELL COST J CUM WELL COST KENAI 100.0000 3,486.00~ 385,054.00 STAT~PROV COUNt/OTHER ~ ~m CASING ~N~ C~ING ~ L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS I MTS J 24 HR FORECAST RIH to retreive broken oil jar, with rest of fishing tools~ retreive fishing tools and original fish OPE~TION COMMENTS Retrieve broken oil jars, continue to fish tool sting and ~re out of well, tool string at 3263' KB SAFE. SUMMARY ~ ~ ~ ~ 233.00 ~one I ~ 0/~ ~/2002 ~ 0/~ ~/2002 SAFETY MTG TOPICS: OPE~TIONS SUMMARY, : . ~ FROM TO HRS FROM TO SUB PHASE OP ~;~BL ' : DESCRIPTION 08:00 20:00 12.00 PWL operator a~ived. Stad up unit, WHP = 0 psig on tubing and ~sing = 0 psig. MU 1.75" LIB RIH to tag fish. Tag at 3234' KB. POOH with LIB, mark show OIL JARS. Mu 2" RS w/baited 1.75" Bowen overshot. Latch tools POOH w/fish ie ~m grab w/6" ~iled up wire around the wire grab. note: 6" wire re~vered only 150' more in hole MU baited Bowen finder, RIH to 3269' KB, latch wire shear off POOH. RIH with 2" SB to latch fish. Noti~d ~o sets of jars going off. , Shuck dog on SB. POOH. Rebuild 2" SB wi~ new dogs RIH latch up on fish. PUH to 3252' KB, work tools string. Note: PU weight has gained 200 lbs when picking up on tool string. Boffom t~l string I~se, bottoms out at 3193' KB (appears to bottom out on bridge be~een the tool sEings). Set~ down at 3231' KB. /tool stdng moving 38' before boffoming out. PUH to 3193' KB drop back to 3230' KB, leave tool string I~se over night S/D for night PERSONNEL DATA~; ;~ ~ ~ : : ~ ~: COMPLY SERVICE NO.:'~ HOURs ~ : . ~'C~MP~y ':~ ~. : SERVICE ~ ;~ ~ ~ ~;:NO~~ HOURS Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 ToloffCranes 1 8.00 R&K Industrial 2 8.00 cASING SUMMARY :' ;:~: ::~ ; ~ : ~ ~: LAST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 s~z~(i.) I ~D(~.)SHOETEST(ppg~ M~S~cP ~ MD~~)~ :~(~ I:~ WTqb/~) I ~E ]:BURs~'(pS~) Printed: 3/14/2003 10:11:06 AM WELL NAME KENAI UNIT 14-6RD "MARATHON-OIL CoMpANy '_- ' ' -Page- 2.°f2 - Daily Recomplotion RePort - ' Increase-Production ' - . KB GL 24 HR PROG TMD I 15,047 DES DeL I RPT # DATE 21.0 I 66.00 15,047 'rVD 0 0 I 23 20-Nov-2002 cASiNG~SUMMARY , . : LAST BOP TEST: 10/11/2002 SIZE (in) ID (in) SHOE TEST (ppg~ / 7.000 6.276 LAST CASING TEST: NEXT BOP TEST: MAXSICP i : MD(fi) , TVD(ft) I ~:w-r(lb/ff) , GRADE (psi) @ (ppg) 4,6161114,616 26.00 N-80 10/18~2002 7,240 Printed: 3/14/2003 10:11:06 AM KENAI UNIT 14-6RD 21.0 66.00 15,047 15,047 22 19-Nov-200~ SUPERVISOR RIG NAME & NO. AUTH MD WBS S~BS COST Wayne Cissell WO.02.07444.EXP 553,550 RELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST ~ CUM WELL COST KENAI 100.0000 4,830.00 I~ 381,568.00 STAT~PROV COUNt/OTHER ~T CASING ~N~ C~ING ~ L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) CURRENT STATUS / MTS 24 HR FORECAST :RIH to retrieve wire, tool string ~ntinue to fish wire line t~l string OPE~TION COMMENTS Continue to fish tool string and wire line tool string SAFETYsUMMARy:; .. :~ : ~ : ; ~ :..:~ 233.00 ~one ~ 0/~ ~/2002 ~ 0/~ ~/2002 SAFETY ~G TOPICS: opE~TIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL. DESCRIP~ON 08:00 18:40 10.67 PWL operator arrived. Sta~ up unit, WHP = 0 psig on tubing and ~sing = 0 psig. MU 1.83" LIB RIH to tag fish. Tag at 3246' KB. POOH with LIB, mark show sand. MU Bailer RIH to 3244', bailer fail to 3269' KB. POOH with Bailer. Water and mud in bailer. MU LIB (1.83") RIH to 3273" KB. shows wire on LIB. MU 2" prong grab to 3264' KB, unable to latch ~re. POOH. Mt baited ~re grabber, to 32~' KB. Unable to latch ~re POOH. RIH ~ 2" baited bowen ~re finder baited, grabbing wire but would not lat~ up. Keep slipping off, POOH to check tools. OOH ~th TS, RIH to 3265' KB. ~ pulled up to 1000 lbs. t~ to find wire, slipped off POOH to check TS. RIH with same baited tool. make couple runs in and out of hole. RIH with 2" SB to 3265' KB. PUH to 1600 lbs. set jars off. Tool sheared POOH wi~ TS. Re pinned SB. RIH Latch fish, PUH to 1700 lbs on TS, jar went offTS shot up hole, POOH OOH wi~ TS, opened swab found 1/2 off oil Jar broken off at the rod. Lay down tool stdng and lubri~tor for night. note: Plan to bring over shot out to fish out the oil jar body in the AM. We will MU 1.5" tool string from this point fo~ard. .; PERSONNELDATA ~ COMPLY SE.WCE NO. .ouES : .COMPA"~ Glacier Drilling 17 175.00 R&K Industrial 2 8.00 Marathon I 18.00 Weaver Brothers 2 24.00 Printed: 3/14/2003 10:11:04 AM WELL NAME KENAI UNIT 14-6RD . MARATHONOI. LcOMPANY -__ _-page=2.of2~ _ DailyRecOmpletionReport. . - - _ '- _ IncreaSe Production, = · . · I 21.0 66.00 15,047 0 0 I 22 119-Nov-2002 COMPANY SERVICE · Toloff Cranes PERSONNEL:DATA ;;: :-i : i:~ :;: POB@ 06::00:: CASING suMMARy LAST BOP TEST: 10/11/2002 SIZE (in) ID (in) SHOE TEST (PPgl 7,00O 6.276 / LAST CASING TEST: NEXT BOP TEST: 10/18/2002 MAX SlcP (psi) @ (ppg) MD(ft) I TVD(ff); :WT(ib/fi)::: i :G~DE 4,616I 4,616 26.00 N'80 ir BuRST(pSi)7,240 Printed: 3/14/2003 10:11:04 AM MARATHONOIL_COMPANY- ' _ ' ~ -- ~-i pagelof2 - - . .- '~/~. ~? '-.? ..... --- '. ~ ---- - -' - .i' - ~'-.~- ' -- - Daily Re'completi°n RepOrt . -- · _ -.- -.-*- _ _'- --- Increase~Pr°duction . · _ KENAI UNIT 14-6RD 21.0 66.00 15,047 15,047 0 20 1g-Nov-2002 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/WBS COST Wayne Cissell WO.02.07444.EXP 553,550 FIELD NAME RIG PHONE MOC WI NRI DALLY WELL COST CUM WELL COST KENAI 100.0000 2,900.00 376,738.00 STATE/PROV COUNTY/OTHER LAST CASING I NEXT CASING I LEAKOFF Alaska Kenai 7.000 (n) @ 4,616 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS I 24 HR FORECAST Continue to recover movement on wire line tool stringI continue to fish tool string SAFETY SUMMARY - . _ - ' 233.00 None 10/16/2002 10/11/2002 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SUMMARY . " . - ' ' FROM TO HRS FROM TO 'SUB PHASE OP TRBL .' - ' DESCRIPTION '. . 08:00 20:20 12.33 PWL operator ardved. Start up unit, WHP = 980 psig on tubing and casing = 100 psig. Previous night left 1600 lbs pull on wire. Wire had 300 lbs on weight indicator. Reeled up 15' on counter after unit started and warmed up. Continue to hold bind on wire at 1700 lbs. no movement on tool stdng. Unloaded the tubing pressure tp=850 psig, to tank. Made several attempts to get the tools to move. Trying to get the tool string to move. No luck getting the tools to move. No progress on establishing tool stdng movement. Contact Anchorage about dropping a cutter bar. MU 1 1/2" go devil, drop. Move wire to work go devil down wire as far as possible. MU 1" cutter bar, drop cutter. POOH with wire. Wire out of hole, retrieved the 1" cutter bar with wire. MU new 1 1/4" tool string. Wait for 2" RS from shop. FtlH to 3239' wlm, 3258' KB. Latch go devil pull OOH with tools. Retrieved the 2" go devil. MU 1.5" LIB RIH to fill, tagged at 3244' WLM, 3263' KB. POOH with LIB, no impressions on the LIB. MU 1.75" DD bailer. RIH to 3244' WLM, 3263' KB. Tools seem sticky at 3263' KB. POOH with bailer. Lay unit down for night. Note: Sample mud, no sand, some water on top of bailer. PERSONNEL DATA. ' - . - . POB- @ 06:00: COMPANY SERVICE NO. HOURs ' '~ - coMPANY ' ' SERVICE -" - ' NO. HOURS Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 Toloff Cranes 1 8.00 R&K Industrial 2 8.00 Printed: 3/14/2003 10:11:02 AM WELL NAME I KB KENAI UNIT 14-6RD I 21.0 Dail y Rec°mpletion-Rep0~; i' 'increase,PrOduCtion;; ;~ :: 66.00 15,047 0 0 20 18-Nov-2002 CASINGSUMMAR¥ : ~ LAST BOP TEST: 10/11/2002 s'~.:o~':' I'~.~' I~'-'°~'''~s''' LAST CASING TEST: NEXT BOP TEST: (psi) @ (ppg) 4,616 4,616 26.00 N-go 10/18/2002 7,240 Pdn/ed: 3/14/2003 10:11:02 AM . DailYReCompletiO~Rep°rt~ i :::: (:iii: ~i~i KENAI UNIT 14-6 01 87.00 66.00 / 15,047 15,047 19 17-Nov-2007 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS S~BS COS~ Glacier Drilling 1 907-283-1312 ! 15,047 WO.02.074~.EXP 553,550 CURRENT STATUS J MOC ~ J N~ D~LY WELL COST CUM WELL COST I 100.000q 3,100.00 373,838.00 24 HR FORECAST ACCIDENTS 24HR ~T SAFE~ ~G. BOP PSI TEST None 10/16/2002 10/11/2002 KENAII IAlaska Kenai 7.000 (in) ~ 4,616 (fi) I (in) ~ 0 (fi) OP COMMENTS: Clcle pressure on tubing with wireline in tension. At the end of the day, tools are 100' higher than at the sta~ of the day. OPE~TIONS SUMMARY ~ : FROM TO HRS DEPTH FM DEP~ TO SUB PHASE OP " DEscRiPTION; 08:00 10:00 2.00 TS WBPR SLICK WHP = 850 psi on tubing and annulus. Pull 1700 lbs tension on wire. Unload the ~sing to 100 psi; no movement on tool string. 10:00 19:15 9.25 TS WBPR SLICK SITP = 850 psi. Unload tubing, no movement on ~re. Pressure up on tubing to 800 psi, and some small movement on the ~m. Cycled six more times during ~e day, and each time get some wire movement ~during repressure operation. At the end of the day, had moved tool string 100' higher. SDFN. Note: Notice immediate rate drop in well KU 21-7 whenever KU 14-6rd is produ~d. pERSONNEL DATA: ~ COMPLY SERVICE NO.. HouRs : COMPLY : SER~CE ~- ~ ~ NO~ ~ ':HOuRs Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 ToloffCranes 1 8.00 R&K Industrial 2 8.00 CASING~SUMMARy . : ~::: ~. : ~ .:. ' ~ST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 7.000 ~.270 (pSi) ~ (pp~) 4,0~ 4,0~ 2~.00 ~-80 ] 7,240 Printed: 3/14/2003 10:11:22 AM .: . ~ DailYRec°mPleti0nRep°~ '~ ~ ,i ~':i:~'~I~:~II:':I. .ii :.'-:ii ': ii~i~. ~ KENAI UNIT 14-6 01 187.00 166.00 I / 15,047 I 15,047 I I I 18 16-Nov-200; SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD ]WBS S~BS COS' Glacier Drilling 1I 907-283-1312 15,047 I WO.02.07444.EXP 553,550 CURRENT STATUS',IMOC WI / NRI DNLY WELL COST CUM WELL COST ~ 100.000q 1,870.00 370,738.00 24 HR FORECAST ACCIDENTS 24HR ~ST S~E~ ~G. BOP PSI TEST None 10/1G/2002 10/11/2002 Kfi~AI Alaska Kenai 7.000 (in) ~ 4,~ (~) (in) ~ 0 (~) O~ CO~fi~IS: Attempt to flow well up tubin~ without suc~s. RIH with wiro, ta~ sand. RIH a~ain, t~ls am stuck. OPE~TIONSSUMMARY :~ ~:~ ~ : '~ ~ ::~ ~ : FROM TO HRS DEPTH F~ DEPTHTO SUB pHASE OP :~ : ~ -::;~DESCRIPTION : ; : : 12:30 13:00 0.50 TA WBPR FLOW Bullheaded gas do~ the tubing s~ng dudng the night. SITP = SICP = 850 psi. Flowed well into production header to get well to flow. Bled to system pressure with no sustained flow. Lined up to flow well to the open top tank, blew well down to atmosphere via tubing and annulus. 13:00 20:00 7.00 TS WBPR SLICK MIRU Pollard Wimline. RIH with 1.5" bailer tool string (rope socket, knuckle joint, oil para, spang jam, 1.5" bailer). Tag at 3583' KB. POOH with bailer full of sand. RIH a second time. Tag at 3674', wo~ tools. ~ Become stuck without spang action. Affempt to wo~ tools free without success. SDFN leaving wire in tension. Bullheading gas down tubing. PERSONNEL DATA : ~ : .~ ~: : pOE ~:06:00: COMPANY SERVICE ' NO. HOURS: ': : CoMplY :: : - : ~SER~CE :~ :: : :: :NO: .:: HOURS Glacier Drilling 17 175.00 Weaver Bmthem 2 24.00 Marathon 1 18.00 Toloff Cranes 1 8.00 R&K Industrial 2 8.00 ~ST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 7.000 a.27~ (psi) ~ {pp~) 4,~ I 4,~o I 2~.oo I ~-ao I 7,240 Printed: 3/14/2003 10:11:20 AM Daily Rec°m Pleti°n ~RopO~ :i' K[~AI U~IT ~4-~ 0~ 87.00 ~.00 ~ ~5,047 ~5,047 ~7 ~5-~ov-2007 SUPERVISOR RIO N~E & NO. J RIG PHONE AUTH MD WBS SAP~BS COS; Glacier Drilling 1~ 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS MOC ~ J N~ D~LY WELL COST ~CUM WELL COST 100.000q 12,760.00 368,868.00 24 HR FORECAST ACCIDENTS 24HR ~ST S~E~ ~G. BOP PSI TEST None 10/16/2002 10/11/2002 FIELD NAME J STAT~PROV COUNt/OTHER ~ST C~ING J N~ CASING L~KOFF PPG KENAII Alaska Kenai 7.000 (n) ~ 4,616 (fi) ( (in) ~ 0 (fi) OP COMMENTS: Uload well with nitrogen. Pedomte A-10 and A-11 Sands, flow well to tank. Set PX plug, pressure up tubing to pedorate A-8 sand. Pull plug, attempt to flow well without success. OPE~TIONS SUMMARY FROM TO HRS DEPTH FM DEPTH TO SUB PHASE OP , ': : : DESCRiP~ON~: 08:00 11:00 3.00 AF PERF N2LFT Finish RU of flowback iron to 2" wing valve. RU BJ nitrogen unit to annulus valve. Pressure test lines to 3000 psi. Held prejob safe~ meeting. 11:00 12:00 1.00 AF PERF N2LFT S~d pumping nitrogen at 500 sc~ ~th 750 psi, taking liquid returns off 2" wing valve. Gradually increased rote to 2000 scfm. Shut down nitrogen when geeing nitmgenin mtums. Fluid re~ve~ = 121 bbl. Shut-in returns and continue to pressure up wellbore to 1500 psi. 12:00 14:00 2.00 AF PERF PERF NU ~mline lubricator with drop bar. Release bar, and in 55 se~nds got obvious sign of lower 3-3/8", 6 spf guns firing (36936'-3678' CBL, 3700%3740' CBL). Open well to flow up the tubing string, and well flowing ~th 40 psi FTP. Gas sniffer ~nfirmed hydm~rbons in flowback ,stream. 14:00 17:00 3.00 AF PERF SLICK RU Pollard Wimline. RIH with 1.875" PX plug, and set in X-nipple at 3583'. POOH. Confi~ proper set with check-set tool. POOH. Pressure up on tubing string to 2900 psi with nitrogen. After 4 minutes, confirm upper guns have fired (2-7/8", 6 spf "lowside" guns, 3~0'-3574' CBL). Following firing, tubing pressure held steady at 2900 psi. 17:00 19:00 2.00 AF PERF SLICK RD ni~ogen pump. Bleed wellhead pressure from 2900 psi to 500 psi. RIH with slickline, pull PX plug. RDMO slickline. AEempt to unload well through tubing to tank, but well blew down ~thout producing. Hook up jumper line from high pressure well, build tubing pressure to 800 psi within 35 minutes. Blowdown to tank again ~th no sustained gas flow. Hook up jumper line again to pressure up with gas overnight. SDFN _ : ~ ; : ::' .~ ~ ~ : :~::-POB~ 06;00~ PERSONNEL DATA ~.~ Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 ToloffCranes 1 8.00 R&K Industrial 2 8.00 CASING:SUMMARY'/ LAST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 7.000 ~.27~ (psi) ~ (pp~) 4,g~ [ 4,~ 2~.00 ~-a0 [ 7,240 Printed: 3/14/2003 10:11:17 ,AM · . :. . : Daily ReCOmPletionRep°rt KENAI UNIT 14-6 . 87.00 J 15,047 17 D2-Nov-200; SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS SAP~ COS3 Glacier DHIling 1 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS J MOC ~ ~ NRI DNLY WELL COST CUM WELL COST I 100.000~ 12,530.00 356,108.00 24 HR FORECAST ACCIDENTS 24HR ~ST S~E~ ~G. BOP PSI TEST None 10/16/2002 10/11/2002 FIELD NAME STAT~PROV ~ COUNt/OTHER ~ST CASING JN~ CASING L~KOFF PPG KENAI Alaska~ Kenai 7.000 (in) ~ 4,616 (fi)J (in) ~ 0 (fi) OP COMMENTS: NU remaing tree valves and pressure test. Pull BPVs. OPE~TIONS ~SUMMARY FROM TO HRs DEPTH FMDEPTH TO SUB PHASE oP . 07:00 08:30 1.50 TA WBPR NUND Cut away pa~ of cellar grating to allow room for 7-1/16" side outlet valves. 08:30 15:00 6.50 AF WBPR NUND NU 7-1/16", 3M valve on side outlet. Pull BPV in side outlet, install 2-way check. Pull BPV from tubing hanger. Open master valves and swab valves, pressure test 7-1/16" valve to 250/3000 psi. Pull 2-way check from side outlet, NU 7-1/16" actuated valve on side outlet. NU 2-1/16", 5M ~ng valve and actuated valve. Pressure test to 250/3000 psi against master valves while side ou~et valves are open. PERSONNEL DATA COMPLY SERVICE NO: HOURS ~ CoMpANy '~ sERVICE : ' i :NO; ~ ' HOuRs Glacier Drilling 17 175.00 Weaver Brothers 2 24.00 Marathon 1 18.00 ToloffCranes 1 8.00 R&K Industrial 2 8.00 CASING SUMMARY LAST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 Pdn[ed: 3/14/2003 10:11:14 ,AM KENAI UNIT 14-6 01 93.30 | 15,047 15,047 16 18-Oct-2002 SUPERVISOR RIG NAME & NO. RIG PHONE IAUTH MD WBS SAP/VVBS COS, Randy Ratliff Glacier Ddlling 1 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS'1MOC W1 I NRI DAILY WELL COST CUM WELL COST I 31,850.00 343,578.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/16/2002 10/11/2002 FIELD NAME STATE/PROV COUNTY/OTHER'ILAST CASING I NEXT CASING LEAKOFF PPG 'Kenai Alaska KenaiI 7.000 (in) @ 4,616 (ft)I (in) @ 0 (fi) OP COMMENTS: Finish rigging down. .... ·:, .., . ~ - . . ..~. ,. ~ ~.::...: ,...-; ,....-:..-:.:,,.,:- ::. -.,.:::-~.:~=:i ;; ,.7:~=~-~- 7= ::--:- ......... ~ ............... ~'~--~- .-~'~- +--~--;':--':---~--~- ;: -~-=.~*: --->~.:-~-.<~-._~. -~-%.~d 06:00 00:00 '18.00 AF RDMO RIG Finish rigging down. Final report. Glacier Ddlling 17 175.00 Weaver Brokers 2 24.00 Marathon 1 18.00 Toloff Cranes I 8.00 R&K Industrial 2 8.00 ~ST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/1~2002 7.000 I 6.276 [ / (psi)e (ppg) / 4,616 / 4,616 J 26.00 / N-80 / 7,240 - Printed: 11/4/2002 9:26:50 AM KENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 15 17-Oct-2002 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS SAP/VVBS COS'I Randy Ratliff / Gary Eller Glacier Drilling 1, 907-283-1, 312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DAILY WELL COST CUM WELL COST Rigging down.I I 96,750.00 311,728.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/16/2002 10/11/2002 FIELD NAME I STATE/PROV COUNTY/OTHER LAST CASING I NEXT CASING LEAKOFF PPG KenaiI Alaska Kenai 7.000 (in) @ 4,616 (fi)I (in) @ 0 (fi) OP COMMENTS: TIH and spot TCP gun assembly. N/D Bop stack, N/U tree. Release rig. 06:00 08:30 2.50 AF RCMP PLRNRP Continue TIH with Y-block dual TCP gun assembly with 115 total joints of 2-3/8" 4.7# J-55 EUE 8RD tubing to 3738'. 08:30 10:30 2.00 AF RCMP LOG PJU wireline. Run gamma-ray correlation log. 10:30 12:00 1.50 AF RCMP PLRNRP Space out, and land tubing hanger with 2-3/8" EUE 8RD lift and suspension threads, positioning 34' of 2-3/4" 60 degree Iow side q'CP guns to perforate the A-8 Sand from 3542'-3576' DIL (3540'-3574' CBL), and 3-3/8" TCP guns loaded 6 SPF 60 degree phasing to perforate 42' o A-10 Sand from 3638'-3680' DIL (3636'-3678' CBL), and 40' of A-11 Sand from 3702'-3742' DIL (3700'-3740' CBL). Tubing string has an 1.875" X-nipple below the Y-block @ 3583'. Note: Guns have a drop bar firing head with an auto release feature. After firing and dropping the lower guns the re-entry guide will be the EOT @ 3632'. The upper Iow side guns will remain attached to the Y-block. 12:00 12:30 0.50 AF XMBO NUND L/D landing joint, install BPV in tubing hanger. 12:30 17:30 5.00 AF XMBO NUND N/D BOP stack. 17:30 19:30 2.00 AF XMBO NUND N/U 2-1/16" 5M tree, test void to 3M. Pull BPV and set 2-way check. Fil tree with methanol. Test tree to 250 / 3000 psi. Pull TWC, set and leav( BPV in hanger for rig down. Fill tree with methanol. Release rig @ 19:30 hours 10-16-2002. Note: Corrected top of new tubing head flange is 20.05' RKB. 19:30 06:00 10.50 AF RDMO RIG Rigging down. Glacier Drilling 17 216.00 Weaver Brothers 1 15.00 Marathon 2 24.00 Weatherford Completion 1 6.00 ADB Vetco Gray 1 8.00 HOWCO - TCP 2 12.00 R&K Industrial 1 12.00 S & R 1 1.00 LAST BOP TEST: 10/11/2002 LAST CASING TEST: NEXT BOP TEST: 10/18/2002 z.ooo (psi)@ (ppg) I 4,616 / / 26.00 / N-aO / 7,240 Pdnted: 11/4/2002 9:26:47AM KENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 14 16-Oct-2002 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS SAP/VVBS COS~ Randy Ratliff/Gary Filer Glacier Drilling 1 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DAILY WELL COST CUM WELL COST TIH with TCP guns.I I 58,840.00 214,978.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/16/2002 10/11/2002 FIELD NAME I STATE/PROV COUNTY/OTHER I LAST CASING NEXT CASING LEAKOFF PPG KenaiJ Alaska KenaiJ 7.000 (in) @ 4,616 (ft) (in) @ 0 (fl) OP COMMENTS: N/U and test tubing spool. P/U TCP gun assembly. 06:00 11:00 5.00 TA XMBO WAIT Rig on standby, waiting on custom wellhead delivery. Rig cost not charged to KU 14-6 while dg is on standby. 11:00 12:00 1.00 AF XMBO ClRC Take rig back on daywork. Circulate BTMS up. 12:00 13:30 1.50 AF XMBO PKRPLG IJD 3joints oftubing. M/U Bakerstorm packer assembly. Setstorm packer @ 45'. 13:30 21:30 8.00 AF XMBO NUND N/D and P/U BOP stack. Remove spacer spool. Remove casing valves from existing tubing spool. Install solid VR plugs and flanges. N/U custom 3M WP tubing spool W/7-1/16" 5M flanges on top of existing tubing spool. Spool has a 6-1/8" 3M towline outlet with a BPV and flange in place. N/U and run function test on BOP stack. 21:30 23:00 1.50 AF XMBO TEST Close blind rams, pressure up against storm packer. Test both tubing head flanges to 250 / 1500 psi, 5 minutes each test. Set test plug, test :BOP flange breaks to 250 / 3000 psi, 5 minutes each test. 23:00 00:00 1.00 AF XMBO I NUND Pull storm packer, L/D 8 total joints of 2-3/8" tubing. 00:00 00:30 0.50 AF WBPR EQUIP Change bails. 00:30 03:00 2.50 AF WBPR TRIP TOOH, L/D bitand casing scraper. 03:00 06:00 3.00 AF RCMP PLRNRP Hold safety and operations meeting. P/U TCP gun assembly. 20//I/1'/ t / I I I I * / / / BHA DESCRIPTION 6-1/8" Steel Tooth Bit, 7" Casing Scraper, Bit Sub, Cross Over Oilfield Hot Shot 1 1.00 Marathon 2 24.00 Weaver Brothers 1 g.00 ABB Vetca Gray 1 8.00 Weatherford Oompletion 1 8.00 Baker Oil Tools 1 4.00 HOWOO- TCP 2 8.00 R&K Industrial 1 5.00 Glacier Drilling 17 216.00 Alaska Oil Sales 1 2.00 LAST BOP TEST: 10/11/2002 LAST CASING TEST: NEXT BOP TEST: 10/18/2002 7.000 8.276 ! (psi)@ (ppg) 4,616 [ 4,616 / 26.oo / N-80 / 7,240 Printed: 11/4/2002 9:26:45 AM KENAI UNIT 14-6 01 93.30 / 15,047 13 15-Oct-2002 SUPERVISOR RIG N~E & NO. RIG PHONE A~H MD WBS ~BS COS' Randy Ratliff Glacier Drilling 1, 907-283-1312, 15,047 WO.02.07~4.EXP 553,550 CURRENT STATUS ~M~ ~ ~NRI D~LY WELL COST CUM ~LL COST Rig on standby~ J 3,020.00 156,138.00 24 HR FORECAST ACCIDENTS 24HR ~T S~E~ ~G. BOP PSI TEST Expect to recieve wellhead and resume operations today. None 10/14/2002 10/11/2002 Kenai Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) OP COMMENTS: Rig on standby, waiang on custom wellhead deliver. 06:00 06:00 24.00 TA XMSO WAIT Rig on standby, waiting on custom wellhead deliver. Rig ~st not ~arged to KU 14-6 ~ile fig is on standby. ?~'~'~t~;~l 8.35 I~1 ~l o.oo o.oo :-'2~'"/ .... z I:'""'-I ..... ; ..... I" ', 1 ; i ; I ........ ; ...... I--7 .... -'1 ; 1 BHA DESCRIPTION 6-1/8" Steel Tooth Bit, 7" Casing Scraper, Bit Sub, Cross Over ~l~cie~ O~illi~ / J ~7/2~.°° IIMara~°~ I ] ~/ 24.00 ~ST BOP TEST: 10/11/2002 ~ST CASING TEST: NE~ BOP TEST: 10/18/2002 "7.000 I 6.276 / (psi) ~ (ppg) / 4,616 / 4,616 / 26.00 / N-80 / 7,240 Printed: 11/4/2002 9:26:43 AM KENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 12 14-0ct-2002 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD IWBS ~AP/~,¥BS COS'l Randy Ratliff Glacier Drilling 1, I 907-283-1312, 15,047I WO.02.07444.EXP 553,550 CURRENT STATUS I MOC W! I NRI DAILY WELL COST CUM WELL COST Rig on standby.I I 2,600.00 153,118.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/12/2002 10/11/2002 FIELD NAME I STATE/PROV I COUNTY/OTHER LAST CASING'INEXT CASING LEAKOFF PPG ~KenaiI AlaskaI Kenai 7.000 (in) @ 4,616 (ft)I (in) @ 0 (ft) IOP COMMENTS: Rig on standby, waiting on custom wellhead delivery. 06:00 06:00 24.00 TA XMBO WAIT Rig on standby, waiting on custom wellhead delivery. Rig cost not charged to KU 14-6 while dg is on standby. /;'--'~iS'N~i~{~.-'~i!~:~ 8 35 ~i5~? i'i~-D~ ~ 0 O0 '¢-I, I', I , I , I , / , , , , / -I I BHA DESCRIPTION 6-1/8" Steel Tooth Bit, 7" Casing Scraper, Bit Sub, Cross Over Glacier Drilling / / 17 I 216.00 ~Marathon / / 1/ 24.00 LAST BOP TEST: 10/11/2002 LAST CASING TEST: NEXT BOP TEST: 10/18/2002 7.00o / 6.276/ | (psi)@ (ppg) [ 4,616 / 4,616 / 26.00 / N-60 / 7,24o Pdnted: 11/4/2002 9:26:41 AIM KENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 1 13-Oct-200;:, SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD IWBS SAP/WBS COS' Randy Ratliff Glacier Drilling 1 907-283-1312 15,047 I WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DALLY WELL COST CUM WELL COST I Shut down operations. Waiting on custom wellhead delivery.I 23,125.00 150,518.00 24 HR FORECAST J ACCIDENTS 24HR LAST SAFETY MTG. BOP PS! TEST I None 10/12/2002 10/11/2002 FIELD NAME STATE/PROV J COUNTY/OTHER J LAST CASING J NEXT CASING LEAKOFF PPG Kenai AlaskaL Kenai 7.000 in 4,616 ft __ in~_- OP COMMENTS: Change pipe rams, re-test stack. Make bit and scraper run, picking up production tubing stdng. Test casing. 06:00 07:30 1.50 AF PCMP EQUIP R/D dual stdng handling tools. 07:30 08:30 1.00 AF XMBO NUND Close blind rams. Change upper pipe rams from 2-3/8" dual to 2-3/8" single. 08:30 11:00 2.50 AF XMBO TEST Test upper and lower pipe rams, and annular to 250 / 3000 psi for 5 minutes each test. Run accumulator test. 11:00 12:00 1.00 AF XMBO Change cross-overs on floor safety valves. Clear dg floor. 12:00 13:00 1.00 AF WBPR CLEAN . M/U 6-1/8" steel tooth bit and 7" casing scraper assembly. 13:00 17:00 4.00 ,AF WBPR TRIP Hold safety meeting. TIH with bit and scraper, picking up 2-3/8" 4.7# J-55 EUE 8RD production tubing stdng to 3782'. 17:00 18:00 1.00 AF WBPR DRILL Wash in hole 57' to top of dual tubing string cut off joints @ 3836' WLM) 3839' tubing measurements (original RKB). 18:00 19:30 1.50 AF WBPR ClRC Reverse circulate. 19:30 20:30 1.00 AF WBPR TEST Test 7" production casing to 1550 psi with 8.35 PPG produced water. Monitor 25 psi pressure loss in 30 minutes. 20:30 21:00 0.50 AF ,WBPR ~TRIP L/D 3 joints of tubing. M/U TIW valve and circulating line. 21:00 06:00 9.00 TA XMBO WAIT Shut down dg operations. Wait on custom wellhead delivery. Rig cost not charged to KU 14-6 WBS with dg on standby. Rig crews performing needed maintenance on dg. ..... ..... ...................... .......... 0.0o 0.0o BHA DESCRIPTION 6-1/8" Steel Tooth Bit, 7" Casing Scraper, Bit Sub, Cross Over Glacier Drilling 17 216.00 Weatherfcrd ....... ~~ .... Marathon I 24.00 LAST BOP TEST: 10/11/2002 LAST CASING TEST: NEXT BOP TEST: 10/18/2002 -- 7.000 16.276I (psi)@ (ppg)I 4,6 6 / I 26:oo / N- O / .... __ Printed: 11/4/2002 9:26:39 AM KENAI UNIT 14-6 01 93.30 | 15,047 15,047 10 12-Oct-2002 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD WBS ~AP/VVBS COS~ Randy Ratliff/Gary Eller Glacier Drilling 1I 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS I MOC W! I NRI DAILY WELL COST CUM WELL COST Rigging down dual string handling tools.I I 24,295.00 127,393.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/11/2002 10/11/20 02 'FIELD NAME I STATE/PROV COUNTY/OTHER I LAST CASING J NEXT CASING LEAKOFF PPG Kenai Alaska Kenai | 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) OP COMMENTS: Test BOPE. Pull and lay down dual production tubing strings. 06:00 07:00 1.00 AF XMBO TEST R/U to test BOPE. 07:00 14:00 7.00 AF XMBO TEST Test BOPE. Test upper dual 2-3/8" pipe rams, blind rams, stack HCR and manual valves, kill line check valve, choke line and manifold, 2 IBOF valves, 2 TIW valves, upper and lower top ddve valves, and mud line to 250 / 3000 psi, 5 minutes each test. Tom Maunder - AOGCC, and Bo Brown - BLM, waived witnessing test. 14:00 14:30 0.50 AF XMBO TEST i Pull 2-way check valve out of long string tubing hanger. Pull plug from 1.875" X-nipple in short string, directly below tubing hanger. 14:30 17:30 3.00 ,AF POMP :EQUIP PJU dual tubing string handling tools. Set dual mouse hole. M/U dual landing joints, and circulating line on long stdng. Hold safety and operations meeting. 17:30 18:00 0.50 AF POMP PLRNRP Pull dual tubing hangers, finish pulling tubing strings free @ jet cuts in both strings @ 3836' WLM with 30K overpull. 18:00 19:30 1.50 AF POMP gIRO CBU thru long stdng with 8.35 PPG produced FSW. 19:30 20:30 1.00 AF POMP PLRNRP L/D landing joints, and tubing hangers. 20:30 06:00 9.50 AF POMP PLRNRP TOOH L/D 2-3/8" 4.6//N-80 Buttress tubing. Recover 240 full joints, 1 cut off joint from shod sting 24' long, 1-10', 2-8', 1-6', 2-2', 1-1' pup joints, 1-8' long cut off pup joint from the long string, 2 Otis 1.875" XA sliding sleeves, and 1-1.875" X-nipple from shod stdng side below tubing hanger. Note: Long string was cut in pup joint 8' below sliding sleeve @ 3828'. Shod string cut off joint was 24' long. Glacier Drilling 17 216.00 ABBVetco Gray 1 6.00 Marathon 2 24.00 Weatherford 3 24.00 Weaver 1 2.00 Oilfield Hot Shot Service 1 4.00 !Pollard Wireline I 2.00 Alaska Telecom 1 2.00 LAST BOP TEST: 10/11/2002 LAST CASING TEST: NEXT BOP TEST: 10/18/2002 7.000 6.276 J (ps)@ (ppg) J 4,616 I 4,616 J 26.00 J N-80 J 7,24C~' Printed: 11/4/2002 9:26:36 AM <ENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 9 11-Oct-200; SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS SAP/VVBS COS' Randy Ratliff / Gary Filer Glacier Drilling 1, 907-283-1312, 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DAILY WELL COST CUM WELL COST Prep to test BOPE.I I 16,600.00 103,098.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 10/10/2002 FIELD NAME STATE/PROV I COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG Kenai AlaskaI Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (fi) OP COMMENTS: N/D tree, N/U BOP stack. 06:00 10:00 4.00 AF XMBO NUND Accept dg on daywork @ 06:00 hours 10-10-2002. Stack up BOP stack. Remove upper and lower pipe rams. 10:00 14:00 4.00 AF XMBO NUND PJU slick line unit. PJU lubricator on short string. Pull XX plug with bras.~ body out of 1.875 X nipple directly below tubing hanger. Reset steel body plug in nipple. Run check set tool to vedfy set. Test plug to 3000 psi. PJD SLU. 14:00 19:00 5.00 AF XMBO NUND Continue fabricating bell nipple. Wait on dual pipe ram delivery. 19:00 21:30 2.50 AF XMBO NUND N/D dual tree. Inspect tubing hanger lift threads. 21:30 06:00 8.50 AF XMBO !NUND !N/U spacer spools and 7-1/16" 5M workover BOP stack. Install lower 2-3/8" pipe roms, and upper dual 2-3/8" pipe rams. Glacier Ddlling 17 216.00 Alaska Petroleum Contra I 4.00 Marathon 2 24.00 Pollard Wireline 2 8.00 Weaver 1 8.00 _AST BOP TEST: LAST CASING TEST: NEXT BOP TEST: ' 7.000 6.276I (psi)@ (ppg) J 4,616 ! 4,616 J 26.00 J N-80 J 7,240 Pdnted: 11/4/2002 9:26:34A, M KENAI UNIT 14-6 01 114.30 93.30 I | 15,047 15,047 8 10-Oct-2002 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD WBS SAP/¥~BS COS' Randy Ratliff Glacier Drilling 1 907-283-1312 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DAILY WELL COST CUM WELL COST Stacking workover BOP stack.I I 21,912.00 86,498.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None FIELD NAME STATEJPROV I COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG Kenai AlaskaI Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) OP COMMENTS: Finish rigging up rig. Glacier Drilling 17 216.00 Toloff 1 6.00 Marathon 1 24.00 Alaska Oil Sales 1 2.00 'Weaver I I 6.00 Alaska Petroleum Contra 5 44.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 7.000 / 6.276 I I (psi)@ (ppg) / 4,616 /4,616 / 26.00 I N-S0 / 7,240 Printed: 11/4/2002 9:26:32 AM KENAI UNIT 14-6 01 114.30 93.30 | 15,047 15,047 7 09-Oct-2002 SUPERVISOR RIG NAME & NO. RIG PHONE AUTH MD IWBS SAP/W~BS COS' Randy Rat]iff 15,047 I WO.02.07444.EXP 553,550 CURRENT STATUS I MOC WI I NRI DAILY WELL COST CUM WELL COST Rigging up.I I 16,600.00 64,586.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None FIELD NAME STATE/PROV I COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG Kenai AlaskaI Kenai 7.000 (in) @ 4,616 (fi) (n) @ 0 (ft) OP COMMENTS: Finish rigging down from KBU 41-7X. Continue rigging up @ KU 14-6 06:00 17:00 11.00 AF MIRU RIG Wait on high winds to subside before finishing rig down. Reinstall U-Tube in mud gas separator. Check and clean accmulator hydraulic screens. Repair boiler leak. Replace mud pump valves and seats. Hook up steam lines in pits, reinstall steam trap discs. Service #2 generator. 17:00 22:00 5.00 AF MIRU RIG , Finish rigging down off of KBU 41-7X. L/D wind walls and dog houses with crane. Finish rigging down rig carrier and substructure. 22:00 06:00 8.00 AF MIRU RIG Continue rigging up on KU 14-6 Iocaton. Set and raise substructure. Set carrier and raise derrick. Rig up this A.M. 50% complete. Glacier Drilling 19 240.00 Weaver 1 8.00 Marathon 1 24.00 Toloff 1 6.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 7.000 6.276 / (psi) @ (ppg) ! 4,616 / 4,616 ! / / Pdnted: 11/4/2002 9:26:30 A,M KENAI UNIT 14-6 01 114.30 93.30 | 15,047 6 38-Oct-2002 SUPERVISOR RIG NAME & NO. IRIG PHONE AUTH MD WBS ~AP/VVBS COS'l R.C. LawsonI 15,047 WO.02.07444.EXP 553,550 CURRENT STATUS J MOC WI J NRI DAILY WELL COST CUM WELL COST PJU rig and wait on wind to decrease to finish PJD on 14-7X location.J J 17,980.00 47,986.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST FUD rig move to new location and R/U rig. None 9/5/2002 FIELD NAME STATE/PROV J COUNTY/OTHER LAST CASING J NEXT CASING LEAKOFF PPG J Kenai AlaskaJ Kenai 7.000 (in) @ 4,616 (ft)J (in) @ 0 (ft) OP COMMENTS: PJD and move rig. 06:00 12:00 6.00 AF RDMO RIG PJD ddllers console. Remove exhaust manifolds. Scope down derrick, tie up lines, load trailers, R/D panic line. Remove lights from dog house. P/U location. R/D water tank, boiler, generator and fuel tank. 12:00 00:00 12.00 AF ! RDMO RIG Remove outriggers, prep load for transport to 14-6 pad. Move service buildings off of dg mats, transport generator house, boiler house, pump room and mud pits to 14-6. Set remainder of dg mats. Spot pump room, mud pits, gert house, boiler house and water tank, pull pump room and pits together. Begin hooking up electrical. 00:00 06:00 6.00 AF ~DMO RIG Cont. work on elec. hookup. PJU pump room and pits. glO worn valves in pits. Check out pumps. Shorten wires to VFD's. i.!!, ~..N. :S~(,,~j?~J 9.30 ~P'.:e?;J I~g=D~J I 0.00 0.00 Glacier Drilling 16 204.00 Weaver 5 60.00 Marathon 1 24.00 Veco 1 9.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 7.000 J 6.276 J / (psi) (~ (ppg) J 4,616J 4,616 / / / ' Pdnted: 11/4/2002 9:26:27AM KENAI UNIT 14-6 01 | 15,047 15,047 07-Oct-2002 SUPERVISOR RIG NAME & NO. I RIG PHONE AUTH MD JWBS ~AP/1A/BS COS' R.C. LawsonI 15,047I WO.02.07444.EXP 553,550 CURRENT STATUS MOC WI I NRI DAILY WELL COST I CUM WELL COST R/D rig.I 8,440.00 30,006.00 24 HR FORECAST ACCIDENTS 24HR LAST SAFETY MTG. SOP PSI TEST R/D rig move out. None 10/3/2002 FIELD NAME I STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING LEAKOFF PPG KenaiJ Alaska Kenai 7.000 (in) @ 4,616 (fi) (in) @ 0 (fi) OP COMMENTS: R/D rig. 18:00 06:00 12.00 AF RDMO RIG Accept well from KBU 41-7X @ 18:00hfs 10/06/2002. R/D Top drive and top ddve torque tube, degasser, choke lines, rotary motor, hyd.cylinder skins, carder tarp, steam, water and elec. lines. R/D Pitts, derrick board, mud lines. 0.00 ~ 'l ~, I',"' I' ,'1 , I , / , / ~,.00, I , I , I Glacier Ddlling 16 102.00 APe 2 8.00 Marathon 1 12.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: ?.000 16,276J (psi)@ (pp~) / 4,616 | 4,616 / I / Printed: 11/4/2002 9:26:25AM KENAI UNIT 14-6RD 21.0 93.30 15,047 15,047 0 01-Oct-2002 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/VVBS COST Wayne Cissell WO.02.07444:EXP, , 553,550 =IELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST KenaiI 4,500.00 I 21,56E~.00 Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) CURRENT STATUS ! MTS I 24 HR FORECAST I OPERATION COMMENTS Install new cellar and grating. 0.00 ~one ~/5/2002 ACCIDENT DESCRIPTION: S~ MTG TOPICS: 08:00 17:00 9.00 AF WBPR Pull out old ~llar and grating. ~so having to remove large chunks of ~ncrete. Install new grating and cellar. ;~:s,~(~)~l ~.~o I~&~l I~q o.oo o.oo ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: -' '~.000 / 6.2~ / (ps~)o (ppg) / 4,6~ / 4.~0 I I / Pdnted: 11/4/2002 9:26:23AM KENAI UNIT 14-6RD 21.0 93.30 15,047 15,047 0 3 29-Sep-2002 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/~/BS COST Wayne Cissell WO.02.07444.EXP 553,550 FIELD NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST Kenai~I 11,152.00 I 17,066.00 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF Alaska Kenai I 7.000 (in) @ 4,616 (fi) (in) @ 0 (fi) CURRENT STATUS / MTS I 24 HR FORECAST OPERATION COMMENTS Loaded hole with water. Make jet cut in Iogstring and shortstring tubing above the dual packer. Set BPV and XX plug to secure wellhead. 0.00 I None 9/5/2002 N :ACClDENT DESCRIPTION: SAFETY MTG TOPICS: 08:00 10:00 2.00 AF WBPR FLUID Finish loading the hole with produced water. Well took a total of 150 bbl to fill (including operations of 9/27/2002). 10:00 12:30 2.50 AF WBPR FISH MIRU APRS pipe recovery unit on Iongstring. Conduct prejob safety meeting. RIH with jet cutter. Tie in, cut Iongstring tubing at 3836'. Saw a good kick. POOH. RD from Iongstdng. 12:30 14:00 1.50 AF WBPR FISH RU APRS unit on shortstdng. RIH with jet cutter. Tie in, cut shortstring tubing at 3836'. Saw small kick. POOH, RDIMO APRS. 14:00 16:00 2.00 AF WBPR PKRPLG !Set BPV in Iongstdng tubing hanger. Set 1.875" XX plug in the shortstring X-nipple at 20'. SDFN LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: 7.000 I .276 I / (ps ) (ppg) I 4,6 6/ / t Printed: 11/4/2002 9:26:21 AM KENAI. UNIT 14-6RD 21.0 93.30 15,047 15,047 2 28-Sep-2002 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAP/1/VBS COST Wayne Cissell WO.02.07444.EXP 553,550 FIELD NAME RIG PHONE MOC WI NRI DAILY WELL COST CUM WELL COST Kenai 2,934.00 5,914.00 STATE/PROV COUNTY/OTHER LAST CASING NEXT CASING I LEAKOFF Alaska Kenai 7.000 (in) @ 4,616 (ft) (in) @ 0 (ft) I CURRENT STATUS I MTS I 24 HR FORECAST I OPERATION COMMENTS Set XX plug in X-nipple at 4095', and dump bail 5 gallons of cement on top of XX plug. Vedfy PX plug is in place at 3860' in the shortstring. ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: 08:00 08:30 0.50 ~F' ~'~ ~-i~ RU slickline on ,ongstring, conduct prejob safety meeting 08:30 10:30 2.00 AF WBPR PKRPLG RIH with 1.80" gauge dng, tag cement at 4372', POOH. RIH with 1.875" XX plug to 4080'. Set XX plug in X-nipple at 4095', POOH. RIH with check-set tool, vefihj that the XX plug is set properly. POOH. 10:30 13:30 3.00 AF WBPR CEMT RIH with 17' of 1.75" dump bailer full of cement to XX plug. Dump a load of cement on top of the XX plug at 4095'. POOH, repeat operation four more times until a total of 5 gallons of cement is dumped on the XX plug. POOH, RD from Iongstdng. 13:30 15:00 1.50 AF WBPR WIRELN RU slickline on shortstring. Pressure testlubficator. RIH with 1.65" impression block to 3841'. Tag and POOH. Impression block shows prong of PX plug (as expected). RDMO slickline. SDFN. 28 I /1 I / I / I / I / / / / 11.oo/ / / / / / / LAST BOP TEST: ~ LAST CASING TEST: NEXT BOP TEST: 7.000 6.276 J J (ps)@ (ppg) J 4,616 J 4,616 J J J Printed: 11/4/2002 9:26:18AM K~AI U~IT ~4-ORO 2~.0 ~3.30 ~5,047 ~,047 0 ~ 27-8~p-2002 SUPERVISOR RIG NAME & NO. AUTH MD WBS S~BS COST Wayne Cissell WO.02.074~.EXP, 553,550 FIELD NAME RIG PHONE MOC ~ NRI D~LY WELL COST J CUM WELL COST Kenai 2,980.00J 2,980.00 STAT~PROV COUN~IOTHER ~T C~ING N~ C~ING J L~KOFF Alaska Kenai 7.000 (in) ~ 4,616 (fi) (in) ~ 0 (fi) I CURRENT STATUS I MTS J 24 HR FOREC~T OPE~TION COMMENTS Set ~ plug in X-nipple at ~14' MD. Spot 90 bbl of water in wellborn. Dump bail 5 gallons of ~ment on top of ~ plug. SDFN. 0.00 ~ono ~/5/2002 ACCIDENT DESCRIPTION: S~E~ ~G TOPICS: 08:00 11:00 3.00 AF WBPR SLICK MIRU slickline on IongstHng. Test BOP, ~nduct prejob safe~ meeting. 1~:00 14:00 3.00 AF WBPR WlRELN ~RIH~ 1.80" gauge ~ng to 4610'. Tagfill, POOH. RIH wi~ 1.875" ~ plug to ~00', set plug, POOH. RIH wi~ 1.75" blind box to ~00', beat do~, POOH. RIH with che~-set tool to ~00', veH~ plug is set property. POOH. 14:00 15:30 1.50 AF WBPR FLUID Bleed dom trapped wellhead pr~sure, pla~ 90 bbl of pr~u~d water in the wellbore. 15:30 19:00 3.50 AF WBPR CEMT RIH~h 17' of l.75" dump bailer ~ll of ~ment to 4400'. Dump load of ~ment on top of ~ plug. POOH, repeat operation four more ~mes to dump a total of 5 gallons of ~ment on top of the ~ plug at ~00'. SDFN. ~ST BOP TEST: ~ST CASING TEST: NE~ BOP TEST: 7.000 6.276 J (psi)~ (ppg) J 4,6~6 J 4,~8 J J / Printed: 11/4/2002 9:26:16 AM G:\CMN\DRLG\KGF\WELLS\KU 13-6L~AOGCC01 .xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging X Change Approved Program Pull Tubing__ Variance Re-enter Suspended Well Time Extension Stimulate Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 259'N & 964'E of SW Cor, Section 6, T4N, R11W, SM At top of Productive Interval 5. Type of Well: Development Exploratory Stratigraphic Service At Effective Depth At Total Depth vertical well Squeeze Wet Perfs, Finish Recompletion to Pool 3 6. Datum Elevation (DF or KB) 20.05 feet 7. Unit or Property Name KENAI UNIT 8. Well Number / ,/ KU 14-6rd 9. Permit N,u_~ll~er 74-50 " 10. APl Number 50- 133-10089-01 11. Field/Pool KENAI GAS FIELD/POOL 3 12. Present Well Condition Summary Total Depth: measured true vertical 15047 feet Plugs (measured) 15047 feet Effective Depth: measured true vertical 3843 feet Junk (measured) 3843 feet 3-3/8" gun assembly @ 3725'-3839' Casing Length Structural 60 Conductor Surface 3078 Intermediate Production 4618 Liner 744 Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured Depth True Vertical Depth 20" 80 sacks 60' same 13 3/8" 1720 sacks 3078' same 7" 775 sacks 4618' same 5" 90 sacks 4593'-5337' same 3540'-3574',3636'-3678',3700'-3740' 3540'-3574',3636'-3678',3700'-3740' ' ,. 2-3/8",4.7 ppf, J-55, EUE 8~ to 3632' Packers and SSSV (type and measured depth) N/A RECEIVED DEC 2O 2002 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description Summary of Proposal X Detailed Operations Program X BOP Sketch X 14. Estimated Date for Commencing Operation 115. Status of Well Classification as: 2-Jan-03 I 16. If Proposal was Verbally Approved Oil Gas X Suspended~ Name of Approver Date Approved Service 117' I hereby ~t the f°~s true and c°rrect t° the best of my knowledge' I Signed "~~,.~x ~'~,,,, Gary Eller Title Production Engineer Date J - "'", 3 "' FOR COMMISSION USE ONLY IConditions of Approval: Noti-J~ Commission so representative may witness "~ O'~t,.~ D~,, ~-'v-~O~ '~-..~ JApproval No. Plug Integrity Location Clearance -- J ...~c~ 12/20/2002 IApproved Mechanical Integrity Test by Order of the Commission Form 10-403 Rev. 06/15/88 gEII]l S BFL Subsequent Form Required 10- '~0 g,~ BOP Test~ ORIGINAL SIGNED BY Commissioner Sul~mit in Triplicate Well KU 14-6rd Kenai Gas Field WBS WO.02.07939.EXP Clean Out Fill, Squeeze Wet Zone Objective: Clean out well KU 14-6rd and squeeze off the A-8 Sand. Return in the Sterling Pool 3 reservoir. Procedure: o . Mark on the tubing head with permanent marker the valves so they can be replaced in the same direction. Remove flowlines sufficiently to move in rig substructure. Leave valve on the annulus nippled up but blinded off. Blow down trapped pressure on KU 14-6rd annulus with 3% KC1 water. (Note: The and in the annulus.) 3. Set 2" BPV in tubing . spoo! 2 -way psi. below ' NU DSA single gate single 2~A'', test joint for testing ',-way check. for pulling 2%", 4.7 ppf, joint into tubing hanger. Load hole to pull 2sA'' tubing. If successful, stand back 2%" thread protectors on all 2%" tubing. that the 2¼" tubing does not come out with a straight are required. Skip the fishing steps outlined below if the easily. to pull 23A'' tubing, MIRU APRS pipe recovery unit. Conduct prejob RIH with a freepoint tool to the top of fill at +3252'. Determine freepoint of 2%" tubing. POOH. RIH with a chemical cutter for 2~A'', 4.7 ppf tubing. Make a chemical cut above the freepoint indication. POOH, RDMO APR$. 7. TOH standing back 23A'' tubing on the driller's side. Use thread protectors on all 2%" tubing. 'Well KU 14-6rd, Workover Procedure WBS - WO.02.07939.EXP Page 2 o 10. 11. 12. Close blind rams. Replace upper pipe rams with 5M variable bore rams (2vA" - 5½" capability). Open rams, install BOP test plug. Test BOPE as needed. Pull test plug. RU single elevators, slips, and tongs for running 4", 14.0 ppf, S-135, workstring. Lay out, tally, and rabbit 5500' of 4" workstring. PU adequate 53/4'' wash pipe to wash from the top of fish to the 5.94") at 3535'. TIH with wash pipe on 4" drill pipe. Wash the top of the Y-block assembly at 3535'. Circulate clean. 53/4" wash pipe. PU overshot for 23A'' tubing and fishing jars. TIH, latch LD overshot and any junked joints of 2%" tubing. assembly and the perforated pup joint. Keep guide to rerun later. TIH with 120' of 53A'' wash pipe on 4" 3%" guns at 3725'. Wash back drill of the up. overshot 29 ppf at 3843'. Circulate PU and at +3600'. Release from CIBP ;600' to 3440' (5.8 bbl) through the setting tool for the cement plug. Apply squeeze pressure up to a maximum squeeze pressure has been reached, d'hment from the work string. TOH. TIH. WOC until required compressive strength achieved. cement has set adequately, drill out the cement plug to the top of the CIBP. Pressure test squeeze perfs to 1000 psi (i.e. 13.8 ppg EMW) for 30 minutes. If pressure test is not successful, lay in another cement plug and repeat the squeeze process over again. If pressure test is successful, drill out the CIBP and push remnants to bottom. 19. TOH laying down drill pipe. *Well KU 14-6rd, Workover Procedure WBS - WO.02.07939.EXP Page 3 20. Close blind rams. Replace upper pipe rams with 2%" 5M single rams. Open rams, install BOP test plug. Test BOPE as needed. Pull test plug. 21. RU single elevators, slips, and tongs for running 2%" tubing. 22. TIH with 2%" completion string to 3630'. Rabbit 2%" tubing whil Completion string will be as follows: a. Wireline re-entry guide b. 1 joint (minimum) of 2%", 4.7 ppf, J-55, EUE 8rd c. Pup joint d. X-nipple (ID = 1.875") e. Pup joint f. 2%" tubing to surface g. Pup joint h. Tubing hanger 23. Install space out pups and tubin 24. tubing .-way BPV. 2002 7" onto the 2%" wing Hold prejob safety meeting. using not exceed 2000 psi surface [29 bbl. After unloading completion Pool 3 completion to flowback tank. Continue until up and produced to sales. When ready, RD flowback to sales. Marathon Oil Well KU 14-6rd BOP Stack IFIowNipple I 13 5/8" 5M Annular Preventer IFlow Line I IPipe Ram I IBlind Ram I 3 5/8" 5M Double RamPreventer I ~ 2 1/16" 5M Manually Operated Valves I 3 5/8" 5M Cross 3 1/8" 5M Hydraulically Operated Valve I Operated Valve DF-THF: 20.05' APl: 50-133-10089-01 AOGCC: 74-50 256' FSL, 964' FWL Sec. 6, T4N, RllW, S.M. Tree cxn: 4-3~4" Otis Lift threads: 2-3~8" EUE 8rd Tubing head drawing ITubing: 2-3/8", 4.7 ppf, J-55, EUE 8rd Tubing detail IPerfs (Sterline Pool 3): , A8, 3540' - 3574' CBL (sqz d) Al0, 3636'-3678' CBL A11, 3700'-3740' CBL KU 14-6rd - Proposed PBTD - 3839' TD - 5345' I.Conductor: 20" @ 60', grouted ISurface Casing: 13-3/8", 61 & 54.5 ppf, J-55, STC casing @ 3078' Cmt with 1720 sks of class G IX-nipple @ 3600' (ID = 1.875") I IWireline re-entry guide - 3632' Top of cut dual tubing stdngs @ 3839' Otis RHD dual packer @ 3843' Note: Longstring and shortstring tubings are )lugged below the dual packer. 7", 29 ppf, N-80, LTC & BTC casing @ 4616' Cmt with 775 sks of class G Plugging detail below dual pkr Well Name & Number: KU 14-6rd I Lease Kenai Gas Field, Pad 14-6 Perforations: (MD)I ('I'VD) Angle/Perfs Jvertical Angle @KOP and Depth I KOP TVD I Date Completed: 10/16/021 RKB: Prepared By: Gary Eller I Last Revision Date: 10/17/021 DF-THF: 20.05' APl' 50-133-10089-01 AOGCC: 74-50 256' FSL, 964' FWL Sec. 6, T4N, R11W, S.M. Tree cxn: 4-3/4" Otis Lift threads: 2-3/8" EUE 8rd Tubing head drawing ITubing: 2-3/8", 4.7 ppf, J-55, EUE 8rd Tubing detail IPerfs(Sterling Pool 3): A8, 3540'- 35741 CBL Al0, 3636'-3678 CBL A11, 3700'-3740' CBL KU 14-6rd PBTD - 3839' TD - 5345' IConductor: 20" @ 60', grouted ISurface Casing: 13-3/8", 61 & 54.5 ppf, J-55, STC casing @ 3078' Cmt with 1720 sks of class G Y-block at 3535' 34' of 2-7/8", 6 spf guns for A-8 Sand (3540'-3574' CBL) IX-nipple @ 3583' (ID = 1.875") IPorted pup joint @ 3620' Wimline re-entry guide - 3632' Fish: 3/38" gun assembly, 3725' - 3839' Top of cut dual tubing strings @ 3839' Otis RHD dual packer @ 3843' Note: Longstring and shortstdng tubings are )lugged below the dual packer. 7", 29 ppf, N-80, LTC & BTC casing @ 4616' I Cmt with 775 sks of class G I I Plugging detail below dual pkr Well Name & Number: KU 14-6rd I Lease I Kenai Gas Field, Pad 14-6 Perforations: (MD)I (TVD) I Angle/Perfs Ive~tica~ Angle @KOP and Depth I KOP TVD I Date Completed: 10/16~021 RKB: Prepared By: Gary EIler I Last Revision Date: 10/17/021 Form 3160-5 (June 1990i~ , UNI?'~.~ STATES SUBMIT IN DEPARTMEN JF THE INTERIOR TRIPLICATE* BUREAU OF LAND MANAGEMENT (Other instructions on reverse side) SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT-" for such proposals. SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas ~ Well ~'~ Well [~ 2. Name of Operator Marathon Oil Co. 3. Address and Telephone No. P.O. Box 196168, Anchorage, AK 99519, (907)561-5311 Other 4. 12. Location of Well (Footage, Sec., T., R., M., or Suvey Description) Surface: 259'N & 964'E of SW Cor, Section 6, T4N, R11W, SM TD: vertical well FORM APPROVED BUDGET BUREAU NO. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. A-028142 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Kenai Unit 8. Well Name and No. KU 14-6rd 9. APl Well No. 50-133-10089-01 10. Field and Pool, or Exploratory Area Kenai Gas Field, Pool 3 11. County or Parish, State Kenai Borough ! CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION Notice of Intent Subsequent Report Final Abandonment Notice TYPE OF ACTION ['~ Abandonment [~] Change of Plans ~ Recompletion ~] New Construction ~ Plugging Back ~ Non-Routine Fracturing ~ Casing Repair [~ Water Shut-Off r'--] Altering Casing r-"] Conversion to Injection ~ Other ~ Dispose Water (NOTE: Report results of multiple completion on Well Completion or RecomDletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* Marathon submitted a su~ndry,,n.o_~¢..~ ~p S..__eptember 26, 2002 to perform a recompletion of this well to the Sterlino Pool 3. That recompletion was made, b~{When the well was perforated it immeela[e~y sanoeo up ana was unable to produce. This is a ~sundry request to remobilize the workover rig to squeeze off the A-8 sand (3540'-3574') which is believed to be the source of the Th~s work ~s proposed to begin on January 2, 2003. 18. I hereby certif~,~he fore__true and correct SIGNED ~ \[~.~-~%. X.~_~,,~ RECEIVED DEC 2O 2002 Alaska 0il & Gas Cons. C0mmissi0~ Anchorage TITLE Production Engineer DATE December 20, 2002 (This space for Federal or .State. ffice use) APPROVED BY Conditions of approval, if any: TITLE DATE Title 18 U.S.C. Section 100i, makes it a cdme for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. *See Insstruction on Reverse Side O:\EXCEL\BLMSUND.XLS 6/96 G:\CMN\DRLG\KGF\WELLS\KU13-6L~AOGCC01.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 .~X Time Extension__ Stimulate Change Approved Program Pull Tubing Variance__ Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 259'N & 964'E of SW Cor, Section 6, T4N, R11W, SM At top of Productive Interval At Effective Depth At Total Depth vertical well 5. Type of Well: Development Exploratory Stratigraphic Service Plug back and recomplete to Sterling Pool 3 6. Datum Elevation (DF or KB) 20.3 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 14-6 9. Permit Number 74-50 10. APl Number 50- 133-10089 11. Field/Pool KENAI GAS FIELD/POOL 6 & Pool 5.1 12. Present Well Condition Summary Total Depth: measured true vertical 15047 feet Plugs (measured) 15047 feet Effective Depth: measured true vertical 4612 feet Junk (measured) 4612 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth True Vertical Depth '60 20" 80 sacks 60' same 3078 13 3/8" 1720 sacks 3078' same 4618 7" 775 sacks 4618' same 744 5" 90 sacks 4593'-5337' same 3904'-3923',3940'-3968',4000'-4024',4034'-4066',4455'-4590',4614'-4650' true vertical 3904'-3923', 3940'-3968', 4000'-4024', 4034'-4066', 4455'-4590', 4614'-4650' Tubing (size, grade, and measured depth) Long string: 2-3/8", 4.7#, N-80 to 4435' Short string: 2-3/8", 4.7#, N-80 to 3861' Packers and SSSV (type and measured depth) RDH dual packer at 3844', model WD packer at 4117', model WD packer at 4392'. 13. Attachments Description Summary of Proposal ~ Detailed Operations Program X BOP Sketch .~X 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 30-Sep-02 16. If Proposal was Verbally Approve~,/,-~ ., Oil Gas X Name of Approver ~ Date Approved Service 17. I here~,,~i~ that thefo~s true and correct to the best of my knowledge. Signed'~..,~,~~ ~,~ f.,, Gary Eller Title Production Engineer Suspended__ -- ~ - FOR COMMISSION USE ONLY Conditions of Approval:~ Commission so representative may witness 3 0 ~ ~ ~'~,:>~)~ -lr~.5~" Plug Integrity BOP Test ~ Location Clearance Mechanical Integrity Test Subsequent Form Required 10-"~.~ ~ Date 9/25/2002 Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ~.,,,~,NAL SIGNED BY D 'taylor Se_mount Commissioner Date SulSmit in 'l'riplica[e Well KU 14-6 Kenai Gas Field WBS WO.02.07444.EXP Recompletion to Sterling Pool 3 Objective: Recomplete well KU 14-6 as a single annular producer in the Sterling Pool 3. Procedure: o Mark on the tubing head with permanent marker the location of the short and long strings so they can be readily identified when the tree is removed. Remove wellhouse and ND flowlines sufficiently to move in rig substructure. Replace wooden cellar with corrugated steel cellar. 2. MIRU slickline on KU 14-61 (longstring). Pressure test lubricator. RIH with a 1.875" XX plug. Set XX plug in X-nipple at 4414': Note locations of other nipple profiles at 3828', 4095', and 4369'. UseCheCk-set tool to verify proper setting of plug in the X-nipple. POOH. 3. MU slickline dump bailer ade0ua~e' to ia minimum of 4.1 gallons (i.e. 25' in 2 ¼ .~ ~:~:o cement, bm dOfi~fload~th cement. Make a dry mn to the top of ~e?~!i ~?:~?:!~.4414'. !:~0 ~ :Blend dump b~ler cement (supplied by BJ) and . .~??'.:'::':::::~~i~!i an~ ~::~cement::'.~~ or'plug. POOH. . i~:?:::i ::::::::::::::::::::::::::::::::::: ::::::: ::i 1.8~5:~:':~ p g. Set'~:i ~lug and:: prong in X-nipple at 4095' che'~[::':~i;~601 to.::.:~:~:Proper s ..Of plug in the. X-nipple. POOH. · slic~}:: h~i~:::::::~d load W~:::~~: Need to dump a m(nimum of 4.1 ~: ..~ ~:....gallons (~..~.in 2~?:~g) of ce~e~:bn ~6p of~ plug at 4095. RIH and ~:.:::.~:.~::~.;~;:.:.:.:::::.:~?~:~ump ce~ :::?::::~n top.~~plug. PO0~:.::?:~ slickline from longstfing. slic ::¢~n SS.: ~S~e test lubricator. ~ with 1W' impression block to p~?:~3860'. ~::::::~(top of plug with impression block. POOH, verify that iSi~:~.::::~la;ee. PO~;:'~MO slickline. ::.. .. .'..:. : ..?.... :~ :?::: :?.:7~:::~: :::~nt plugs to set ovemi~t. Blow down trapped pressure on KU 14-6 :?:::.:~: ?~ :~ :~:~:g~ngs and a~ulus. : : ::~'.. 5'.: :~; :;2~:: ;,:' .~: 5..~::: ::: :: vac track. Load casing and tubing strings with filtered produced water. Hole volume is roughly 130 bbl. ~MO vacuum track. , MIRU APRS pipe recovery unit on the longstring. Hold safety discussion, and go to radio silence on pad 14-6. RIH with jet cutter for 2%", 4.6 ppf, L-80 tubing. Cut LS tubing at 3836' (Note: Make cut in 10' pup between RDH dual packer and sliding sleeve), POOH. RD on longstring, RU on shortstring. RIH with jet cutter Well KU 14-6, Workover Procedure WBS - WO.02.07444.EXP Page 2 for 2%", 4.7 ppf, L-80 tubing. Cut SS tubing at 3836', POOH. RDMO APRS unit. 10. Call out Vetco wellhead rep. Set 2" BPV in LS tubing string and bleed off surface pressure. Note that there is no BPV profile in the shortstring tubing, but a 1.875" X-profile is available immediately below the tubing hanger. Set 1.875" XX plug in the X-nipple below the tubing hanger on the shortstring using a dry rod. Use check-set tool to verify proper setting of plug in the X-nipple. 11. MIRU drilling rig. Prior to ND tree confirm that no trapped pressure exists below the longstring BPV. ND tree. Inspect lift threads on tubing hangers. (Note: Both strings should have 2%" IBT lift threads.) NU spacer spool and 7-1/16", 5M BOPs, and install dual mousehole. Upper pipe rams should be equipped with dual 2%", 5M pipe rams and lower pipe rams with ~3/,, ~/8 , 5M single pipe rams. Pull longstring BPV, set 2-way check. (Note: The XX plug in the shortstring holds pressure both ways.) PU dual joints of 2%" IBT tUbing and screw into tubing hanger for testing dual pipe rams. (Note: CoUld optionally screw a ported joint in the longstring and an unported joint in the~ShOrts~ng. This would prevent test pressure from reaching the XX plug in ~e'Shortstring0 Test BOPEtO 250/3000 psi. Pull 2-way check in LS. P~!tii~ p!IUg::!iin the shoasthng. 12. I~U:~ii ~ors, dual.~id~i ~g %ii-ar' and:iinte~ tongs for pulling both i ::~!:,': ::i!:~: :.:?:Load:::~::ii~I~::::~i~h 3% KC1 water:and eStablish circulation down · :: i!~ ::!~ ~tring ~ i~string mb~i ~ay dom all 2%" tubing (Note: No i:i~:~ t~:::::i~i d p ~ as string~ ~Ii be j~ed.). Take occasional :~...~easur~~ ...~r N ~hile TO~i i .':: i:3i ~ dual ~~ hand!~:i!~Uipment. ~ 81evators, slips, and tongs los,running · ii{'~}:i:i::i~:ii ~ ~i¢.::;.4~;ii:;::~:~'" 3 "~:' ':: '::: :i~':~ ':2 ' ~ 3 =.: ~=:~:.::=::'::~mngle stnng.o~2¼ mgm:: Lay out, tally:; and rabb~t 4000 of new 2¼ , 4.7 ppf, :::::::::::::::::::::::::::::::::::::::::::::::::::::: dual:~.i:::::~S'eholei?,~lb~e the blind rams. Replace the dual 2%", 5M rams in uppe~:::?~:~p',~pe rams ~:~':Single 2%", 5M pipe rams. Install single mousehole. i::::.::::i:::::.:.!.!iiii~e~:i ~i:~install test plug, and test BOPE as needed. Pull test plug. : ......... ;::.: ::?:!:5:~,~i:i~:g~i!i~':~:.:~it and casing scraper. TIH with bit and scraper on 2%" tubing. Tag top ::::: :~:.::.:~i:::.?!ii:??:!~:.::~!i::::~bing at 3836'. Circulate bottoms up. ..... ::::::::::::::::::::::::::::::::::::::::::::::::: down circulating. Close the upper pipe rams, and pressure test the 7", 26 ppf, N-80 production casing to 1500 psi. Following test, bleed offpressure and TOH standing back 2%" tubing. LD bit and scraper. Well KU 14-6, Workover Procedure WBS - WO.02.07444.EXP Page 3 a. If pressure test was not successful, prepare to run a CIBP on e-line to the tubing stub at 3836' to isolate potential communication below the dual packer. If pressure test is successful will not run a CIBP. 17. PU storm packer for 7", 26 ppf casing. RIH with storm packer on 2~" tubing to 1500' Set packer, TOH standing back tubing. 18. ND BOPE and spacer spool. NU new 7-1/16", 5M tubing head without pulling off old tubing head (l&l_ote' Confirm orientation of new tubing head with Todd Bulerdick, 283-1336.)~ all valves from old tubing head, install VR plugs and blind flanges. NU BOPE. Upper and lower pipe rams are still equipped with 2%", 5M single pipe rams. Test tubing head flanged connections to 250/I500 psi against RBP. Set test plug, test BOPE body to 250/3000 psi. Pull test plUg. 19. TIH with 2%" tubing. Pull storm packer at 200'. TOH, LD storm packer. 20. Prepare to PU Halliburton TCP guns, conduct prejob safety meeting. RIH with completion string on 2%", 4.7 ppf, J-55, E~ 8rd.:tubing. Completion string is as follows: : : . ...... : ''f ' 42' a..:...~ff:~:!~iio 33A'', 6 spf,.60°.~e ~S:'~(A-11.Sand, 3702 -37 ) 3 99 ": '' ========================================================================================= ,, "O 2.2:::::i:.i'~:: :.:. e :~'8::~o~i~3:~.:¼ , 6::::~60 ::~:i~has guns ~,i0 Sand, 3632'-3680') Wi! ~i::~! ~b'~ fifingii .i::. 3:;'" · :~'" :::" '.'.:. : ~i'!i:.'~' :::: ::. :::i:~. :e:~ :~:~ ase ::~.::.?fOr 3%" guns : i'i'i' i: i.'1:2 :: ::.....:. .... [X~::5 :- ::::: ::~ '" .,:~ ;:~:(' ' o~e~::" · of 2:~::.:: ~n (__') ...... i. I~:(1.87l::i.'~ii~6file) wit~:::~ ing: pups ..... X: .::.'~'~.:':s:.:..:. ':'--:;'::: ::: :.:'.:.:z: ........ k. Y¢~l~With$i~:i::i:Of2¼'', 60° low-side guns (A-8 Sand, 3542'-3576') m... ~:i ing to:::', e n:.::(?ii:~:~}i:~p j oint??::::!!~:ih by pin) hanger with BPV profile re? The 3¼" guns for the A-10 and A-11 Sands are equipped with a drop- head and auto-release head. After firing, total length of guns :::::::::::::::::::::::::::::::::::::::::::::: to bottom is approximately 120'. The Y-block guns for the A-8 Sand :..:.-:.::. ' are designed to detonate with an intemal pressure firing head. These guns i:'i::':::~::: remain attached to the Y-block. 21. MIRU electric line unit. Conduct prejob safety meeting. RIH with gamma ray correlation log. Tie in with CBL log of 7/1/84. Determine pipe movement required to put guns on depth. POOH, RDMO electric line. Well KU 14-6, Workover Procedure WBS - WO.02.07444.EXP Page 4 22. Install space out pups and tubing hanger. Land 2%" tubing. 23. Install BPV in tubing hanger. ND BOPE, NU tree. Pull BPVs, install 2-way check in tubing hangers. Test tree to 3000 psi using methanol or water (depending on temperature). Pull 2-way check, reinstall BPVs. RDMO workover rig. 24. Remove 7-1/16", 3M blind flange. Pull 6" BPV in tubing head side outlet. Pull BPV from tubing string. NU 7-1/16" 3M valve and remainder of tree valves. NU flowlines. 25. MIRU nitrogen pump onto the 7" casing and flowback tank onto the 2%" tubing string. MIRU slickline lubricator containing 10' long 1 ¼" drop bar, but make sure the swab valve remains closed until time to drop the bar. Pressure test lines and lubricator to 3000 psi. Hold prejob safety, meeting. 26. Reverse out completion fluid using nitrogen:: gh the ported pup. Do not exceed 2000 psi casing pressure.:...:T.otal e ated recovery = 126 bbl. After unloading completion fluid, shU~?~:? ret~sand continue, to pressure up with nitrogen.::tO~:;~3.300 psi to begin.:th¢i:~:d~to ofisequence on the Y-block guns. When ':~:::~sure is.~ ~ii~t-do%n ni~gen.pump' to make it easier to hear .... ?.ii~ ~ ~s de ~i?::::: ~um firing p~e~sure = 2700 psi, maximum firing !i ::i!! ~~ ~ ~:psi, ~:~ ~pected 7.mi~e delay for detonation once firing . :::::::::::::::::::::::::::::: d~t of ~?.:~lock gunS is Coafimed, open the swab valve to drop ::;::" 1 " ........... ::~' '"::~ ! i:iiiihe 1 t/4 B'ae;~:::? te: ~eflm~nimum Bf::iS00pSi:casing pressure when bar is : iiiaropped ~~ for ~ ~ease syst~i ~hVate.) Listen for confirmation of :': aetonati~ ~ 33Ail!il i When c°~ed, RDMO nitrogen and slickline. . :. . · .. .. 2:.':.:. i iii~g~iUnload ~.~t~::3!?:Comp~im flowback tank until well has adequately cleaned up. :: ~roduc~ii~~etion ~e~. ':::::.".:'.": ':":: ":::':: '¥:' :5:.:~:::: : .... · :.:...> · ::.. :. !~:: :S~ ~iii~::6, 2002 ':~ ::::: :' "":: ':..:::i! ?¥ :~:::~ :: :.:.:: ~ :¥::.?:~.~. ~. : .:::.. · ::.::: .::. ~.~5,: '.' :ii::". ::i'5 'i! . :::.:..: :...: ..~:. Tubin~q: 2-3/8", 4,6 ppf, 55, EUE 8rd | / 14-6 Workover - Proposed~ Directional Data: Vertical wellbore, very mited directional data. IY-block guns for A-8 Sand, pressure firing head 3-3/8" TCP guns for A-10 & A-11 Sands. Either pressure or drop-bar firing head. After release, top of guns at +1- 3702'. IX-nipple @ 3600' IPorted pup joint @ 3625' Gun auto-release Proposed end of tub ng- 3630' Top of CIBP @ +/- 3825' I7", 29 ppf, N-80 casing Well Name & Number: KU 14-6 Lease I Kenai Gas Field County or Parish: I State/Prov, Alaska Ic°untry: I Perforations: (MD) _ ('FVD) r'i _ Angle/Perfs I - Angle @KOP and Depth I KOP TVD I _ BHP: i.~ BHT: Completion Fluid: FwHP: / F~HP: I FWHT: I FBH~: IOther: Date Completed: RKB: Prepared By: Gary Elter I Last Revision Date; 08/29/021 Kenai Gas Field Well KU 14-6, Pad 14-6 Marathon Oil Company RT-TItF: 20.32' 255~67' N & 964.~22? E of SW Corner Sec. 6, T4N, RI lW Shortstring Tubing: 2-318", 4.6#, N-g0, Butt. Shortstrin B-3: 3904' - 3923' (5". 9 spf, TCK 7/22/84) 3940' - 3968' (5". 9 spf, TCP, 7/22184) B-4: 4000' - 4024' (5", 9 spf, TCP, 7/22/84) 4034' - 4066' (5", 9 spf, TCP, 7/22/84) 4050'-405T (Sqz 1016159) Isolated Lo~. _tr~i~jrfs,5 B-5: 4t55' - 4180' (TCP, 7115184) C~l: 4455*- 4590' (3-3/8", 4 spf, 7121/84) C~2: 4614' - 4650' (3.~3/8'~, 4 spf, '7/21/84) ~ :.,~?~:..~..,m 'h~ 4656~- 4658' (Sqz IOIi 1174) "xk~-. A bandoaed Lo ngstring Perfs Beluga: 4788' - 4808' (3-If8" l~tC, 4 spf, i0116!74) 4856' - 4868' (3-118" HC, 4 spf, 10/16/74) 4960' - 4970' (3-II8" Hr, 4 spf, I0116/74) 5076' - 5096 CBL (3-1/8' tlC, 4 spf, 10/12/74) 5139'- 5149' (3-ii8" }lC, 4 spf, t0/I6174) 5168' - 5188' CBL (3-I/8" HC, 4 spf, 10/12/74) Last Rev: JGE. 8/I7/99 (Shortstring) Otis "X" Nipple @ 20' ID = 1.875" 20" Conductor @ 60', grouted 13-3/8", 61# & 54.5#, J-55, STC Casing @ 3078' Cmt w/1720 sks of class G Fish - Drill string 8757' - ? (9/28/59) Open Hole - 5337' - 15047' Cement plugs 5337' - 5404' & 8604' - 8740' Fish: Brown packer @ 4736', Cut tbg @ 4686 5", 18#, I.-80, Hydril FJ-P Liner @ 4593' - 5337' Cmt w/90 sacks of class G Top of 5" Liner @ 4593' Tag fill @ 4612' WLM (9/30/99) Cement retainer @ 4680' (7/14/84) 7", 26#, N-80, LTC& BTC Casing (~ 4616' Cmt w/775 sks of Class G ,"a ~t 7~ ::,':~. 3534' - 3535' (Sqzd 7/17t84) Longstring Tubing: 2-3/8', 4,68, N-80, Butt. w/SCC Otis "XA~' SlidingSleeYe @ 3777 ..... g-li I l [~ --[1 I Otis XA' Sliding Sleeve@3828 ~~~~~ Blast Joints 3885' - 4068' ~ ~ Otis "XA" Sliding Sleeve ~ 4095' ~5 ID = 1.875" -_.,. '~ ~ Otis WD Packer ~ 4117 ':~'i::~::~':~ Otis ,,XA,, Sliding Sleeve . 4369' ~ . { ID= 1.875" , } -~ C~.l_....._ Half Muleshoe ~ 4435' Marathon Oil Well KU 14-6 Kenai Gas Field Workover BOP Stack I FIow Nipple 7-1/16" 5M Annular Preventer 7-1/16" 5M Double Ram Preventer I FIow Line IPipeRam ] IBlind Ram ] 2-1/16" 5M Manually Operated Valves IPipe Ram I 7-1/16" 5M Single Ram Preventer 3 1/8" 5M Hydraulically Operated Valve il 3 1/8" 5M Manually Operated Valve Marathon Oil Company Alaska Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 September 26, 2002 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Marathon proposes to recomplete well KU 14-6 in the Kenai Gas Field from a dual producer in the Sterling Pool 5.1 and Pool 6 to a single producer in the Steding Pool 3. The existing Pool 5.1, Pool 5.2, and Pool 6 perforations will be permanently plugged back using slickline-conveyed positive plugs with a cement cap. The new Pool 3 completion will be configured to produce up 2-3/8" tubing and the 7" casing. This wellbore configuration is very similar to previous completions in highly depleted Sterling Sands in the Kenai Gas Field. Included in this packet is a sundry application for the recompletion, a detailed procedure, a proposed wellbore schematic, an existing wellbore schematic highlighting the plugback methods for the existing perforations, and a BOP schematic. Marathon proposes to begin slickline operations right away, and rig operations by October 10, 2002. Please contact me if you have any questions. I can be reached at 907-564-6315 or igeller~marathonoil.com. Sincerely, Production Engineer Enclosure ORIGIB AL RECEIVED SEP 2 7' 2002 NOTE TO FILE Marathon KU 14-6 174-50 302-312 Marathon has applied to abandon certain perforations in the subject well, pull the existing completion and re-configure this gas well to allow annular flow as allowed by 20 AAC 25.200 (d). Completions of this type have been previously approved for wells in the Kenai Gas Field. Marathon has provided an attachment that... --Assesses the potential for erosion. A new tubing head will be installed on the well. The minimum ID at the VR (valve recovery) thread is 5.875" and according to Marathon has been sized to reduce the erosional velocity. Marathon estimates that erosion could occur if the flowrate were to exceed 40 MM scf and states that the well will be produced well below that rate. They also plan to conduct periodic thickness inspection of the wellhead and flowlines to investigate for any unusual wear. --Presents the gas analysis. Partial pressure of CO2 is less than 1.0 psi and no H2S is produced in the gas. Corrosion is essentially not present under the described conditions. --Provides bottom-hole pressure data. The shut-in bottom-hole pressure of the Sterling Pool 3 is slightly over 392 psi. Any casing stresses should be well below the capability of the production casing. Approval of this completion change should enhance the well's ability to flow and allow recovery of additional reserves that would likely not be recovered with the conventional completion. Approval of Marathon's request is recommended. Tom Maunder, PE Sr. Petroleum Engineer WELL KU 14-6 KENAI GAS FIELD, PAD 14-6 WORKOVER AND RECOMPLETE AS SINGLE ANNULAR PRODUCER POTENTIAL PROBLEMS ADDRESSED This workover will target gas from the Sterling A-8, A-10, and A-11 zones (Pool 3) in well KU 14-6. Production will be up 7" casing or a 2-3/8" velocity string. This is expected permit high gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing Solution The highest potential for erosive flow exists at the 7-1/16", 5M flanged outlet of the tubing head. The large side outlet on the tubing spool was selected specifically to reduce erosional velocity at the 5.875" ID of the valve recovery thread. Erosion could potentially occur if flow out an annular outlet exceeds 40 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline fi.om the existing robing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Shut in pressure for Sterling Pool 3 is 392 psia. Pressures imposed on the 7" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 8% of the rated casing burst or collapse. KU 146 WE) Subject: KU 14-6 WO Date: Thu, 3 Oct 2002 15:44:49 -0800 From: "Titus, Denise M." <DMTitus~Mar~onOil.com > To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Eller, John G." <JGEIier(~MarathonOil.com> Tom, The following is to address concerns regard'rog the KU 14-6 Workover. Static Bottom Hole Pressure: The last Pool 3 static survey completed 7/2000 indicates a bottom hole pressure of 2g2psia. This Steding sand is a homogeneous sand and historically shows consistent pressure field-wide. We will soon be completing a buildup test in the nearby KU 21-7 Pool 3 well in an effort to update this pressure. Erosional Velocity: Please see attached document which addresses erosional velocity. Casing Pressure Test: The procedure will be corrected to ensure the casing will not be subjected to pressure which exceeds the test value. Please let me know if you have any further questions/concerns regarding this well. Thanks, Denise M Titus Marathon Oil Company (907) 283-1333 <<.AOGC¢.Erosion Letter. doc>> i Name: AOGCC Erosion Letter.doc ~AOGCC Erosion Letter docl T.y. pe: WINWORD File (application/msword) ~ ' ...... ' :'1 Encoaing: base64 ]Description: AOGCC Erosion Letter. doc I of I 10/3/2002 4:07 PM g:Icmn~drlglkgflwellslku'1%Ss~AOGCCO1A.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 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 259'N & 964'E of SW Cor, Section 6, T4N, R1 lW, SM At top of Productive Interval 5. Type of Well: Development Exploratory Stratigraphic Service At Effective Depth At Total Depth vertical well Convert to Annular Flow 6. Datum Elevation (DF or KB) 20.3 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 14-61 9. Permit Number 74-50 10. APl Number 50- 133-10089 -.- C~ 11. Field/Pool KENAI GAS FIELD/POOL 6 12. Present Well Condition Summary Total Depth: measured true vertical 15047 feet Plugs (measured) 15047 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 60 20" 80 sacks 3078 13 3/8" 1720 sacks 775 sacks 4618 7" 90 sacks 744 5" C-1 Sand: 4455' - 4590', C-2 Sand: 4614' - 4650' Measured Depth True Vertical Depth 60' same 3078' same 4618' same 4593'-5337' same true vertical C-1 Sand: 4455' - 4590', C-2 Sand: 4614' - 4650' Tubing (size, grade, and measured depth) Long string: 2-3/8", 4.7#, N-80 to 4435' Short string: 2-3/8", 4.7#, N-80 to 3861' Packers and SSSV (type and measured depth) RDH dual packer at 3844', model WD packer at 4117', model WD packer at 4392'. Baker model F-1 packer @ 4363' MD ORIGINAL 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure · . Tubing' Pressure Prior to Well Operation 0 2189 0 0 110 Subsequent to Operation unknown, not yet tested 15. Attachments 116. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby_certify t~ the foregoing Pe~[rue and correct to the best of my knowledge. Form 10-404 Rev. 06/15/88~. % Suspended ~gineer Service Date 9/8/99 Submit in Duplic~ Kenai Gas Field Well KU 14-6, Pad 14-6 Marathon Oil Company RT-THF: 20.32' 255.67' N & 964.22' E of SW Corner Sec. 6, T4N, RllW Shortstring Tubing: 2-,3/8", 4.6#, N-80, Butt. Squeeze Perfs 3534' - 3535' (Sqzd 7/17/84) Otis "XA" Sliding Sleeve @ 3777' ID = 1.875" Opened 8/12/99 Otis Collet Catcher Sub @ 3852' Otis "Xl'q" Nipple @ 3860' ID -- 1.875", nolo = 1.791" PXN plug set 8/7/99 Shortstring Perfs: B-3: 3904' - 3923' (5", 9 spf, TCR 7/22/84) 3940' - 3968' (5", 9 spf, TCR 7/22/84) B-4: 4000' - 4024' (5", 9 spf, TCR 7/22/84) 4034' - 4066' (5", 9 spf, TCR 7/22/84) 4050'-4052' (Sqz 10/6/59) Isolated Longstring Perfs: B-5: 4155' - 4180' (TCR 7/15/84) Longstring Perfs: C-1: 4455' - 4590' (3-3/8", 4 spf, 7/21/84) C-2: 4614' - 4650' (3-3/8", 4 spf, 7/21/84) 4656' -4658' (Sqz 10/11/74) Abandoned Longstfing Perfs Beluga: 4788' - 4808' (3-1/8" HC, 4 spf, 10/16/74) 4856' - 4868' {3-1/8" HC, 4 spf, 10/16/74) 4960' - 4970' (3-1/8" HC, 4 spf, 10/16/74) 5076' - 5096 CBL (3-1/8" HC, 4 spf, 10/12/74) 5139' - 5149' (3-1/8' HC, 4 spf, 10/16/74) 5168' - 5188' CBL {3-1/8" HC, 4 spf, 10/12/74) Last Rev: JGE, 8/17/99 (Shortstring) Otis "X" Nipple @ 20' ID = 1.875" 20" Conductor @ 60', grouted 13-3/8", 61# & 54.5#, J-55, STC Casing @ 3078 Cmt w/1720 sks of class G Longstring Tubing: 2-3/8", 4.6#, N-80, Butt. w/SCC Otis "XA" Sliding Sleeve @ 3828' ID = 1.875" Opened 8/17/99 for Annular How Otis RDH Dual Packer (.-~ 3843' Blast Joints 3885' - 4068' Otis "XA" Sliding Sleeve @ 4095' ID = 1.875" Otis WE) Packer @ 4117' Otis "XA" Sliding Sleeve @ 4369' ID = 1.875" Otis WE) Packer @ 4392' Otis "X" Nipple @ 4414' ID = 1.875" Half Muleshoe @ 4435' Top of 5" Liner Cw. 4593' Tag fill @? 4610' WLM (3/9/95) Cement retainer @ 4680' (7/14/84) 7", 26#. N-80, LTC& BTC Casing @ 4616' Cmt w/775 sks of Class G Fish: Brown packer C~.. 4736', Cut tbg @ 4686 5", 18#, L-80, Hydril FJ-P liner @ 4593' - 5337' Cmt w/90 sacks of class G Fish - Drill string 8757' - ? (9/28/59) Open Hole - 5337' - 15047' Cement plugs 5337' - 5404' & 8604' - 8740' 990817.xls MARATHON OIL COMPANY i~AILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/17/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 2-3/8", 4.6#, L-80 CASING: DATE LAST WL WORK: TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Open sliding sleeve for annular flow OTHER: Day #6, AFE 0481798 - Annular Flow Conversion WELL #: KU 14-61 7", 26#, N-80 good SUMMARY OF OPERATIONS MIRU slicklineon Iongstring. Test lubricator and BOPEto SITP. RIH with 1.875" BO shifting tool to 381 6' WLM. Shift open XA sleeve at that depth, and made several passes to confirm that sleeve was fully shifted. Tubing pressure increased from 350 psig to 400 psig. POOH, RDMO slickline. 8/20 - 8/24/99 APC roustabouts installed annular flowlines and hydro-tested. ---FINAL REPORT--- Vendor Equipment Daily Cost Cumulative Cost Air Liquide I nitrogen $0 $2,126 APC Iflowlines, etc $3,500 $24,400 Dowell i nitrogen $0 $.8,996 Halliburton islickline, PXN plug purchase $1,196 $8,298 Misc. car rental, airline $500 $3,000 Vetco 2" gate valves $0 $1,300 Weaver Bros. trucking $0 $493 DAILY COST: $5,196 CUM: $48,793 REPORTED BY: J.G. Eller 990816.xls MARATHON OIL COMPANY I~AILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/16/99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 8/7/99 WORK DONE: PXN plug at 3860' PRESENT OPERATION: Purge casing with nitrogen OTHER: Day #5, AFE 0481798 - Annular Flow Conversion Kenai Gas Field WELL #: KU 14-6s 2-3/8", 4.6#, L-80 CASING: 7", 26#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS MIRU Dowell nitrogen unit on casing of KU 14-6 and test lines to 2500 psig. RU return lines on tubing of KU 14-6s. Held safety meeting. Pump nitrogen down casing taking returns on shortstring tubing. Pumped 70,770 SCF of nitrogen with a top pressure of 1400 psig before getting nitrogen returns on tubing. Recovered a total of 108 bbl of liquid. Allowed casing pressure to bleed to 400 psig before shutting well in. RDMO nitrogen unit. Vendor Equipment Daily Cost Cumulative Cost Air Liquide i nitrogen $2,126 $2,126 APC flowlines, etc $0 $20,900 Dowell nitrogen $ 5,081 $8,996 Halliburton slickline, PXN plug purchase $0 $7,102 Misc. car rental, airline $500 $2,500 Vetco 2" gate valves $0 $1,300 Weaver Bros. trucking $108 $493 DALLY COST: $7,815 CUM: $43,597 REPORTED BY: J.G. Eller 990812.xls MARATHON OIL COMPANY ~)AILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/12/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 2-3/8", 4.6#, L-80 CASING: DATE LAST WL WORK: 8/7/99 TREE CONDITION: WORK DONE: PXN plug at 3860' BENCHES OPEN: PRESENT OPERATION: Open sliding sleeves to communicate with annulus OTHER: Day #4, AFE 0481798 - Annular Flow Conversion WELL #: KU 14-6s 7", 26#, N-80 good SUMMARY OF OPERATIONS MIRU Halliburtonslickline on KU 14-6s. SITP = 1780 psi, SICP = 0 psig. Test lubricator and BOPs to SITP. RIH with 2" BO shifting tool and locate sliding sleeve at 3789' WLM. Shift open sliding sleeve. Tubing pressure dropped to 1600 psi, casing pressure increased to 1 150 psi. Continued jarring to verify sleeve is fully open. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC flowlines, etc $0 $20,900 Dowell nitrogen $0 $3,915 Halliburton slickline, PXN plug purchase $1,232 $7,102 Misc. car rental, airline $500 $2,000 Veco roustabouts $0 $180 I Vetco 2" gate valves $0 $1,300 IWeaver Bros. trucking $0 $385 DAILY COST: $1,732 CUM: $35,782 REPORTED BY: J.G. Eller 990811 .xts MARATHON OIL COMPANY BALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/11/99 FIELD: FILL DEPTH/DATE: TUBING: DATE LAST WL WORK: 8/7/99 WORK DONE: PXN plug at 3860' PRESENT OPERATION: Install new casing valves OTHER: Day #3, AFE 0481798 - Annular Flow Conversion Kenai Gas Field WELL #: KU 14-6s 2-3/8", 4.6#, L-80 CASING: 7", 26#, N-80 TREE CONDITION: good BENCHES OPEN: SUMMARY OF OPERATIONS BriefVeco roustabouts on job assignment and held safety meeting. Removed blind flange and old 2" casing valve. Installed two reconditioned 2", 5M gate valves on 7" casing outlet. Verified that no VR plugs were left behind in the tubing head. Move on to next well. Vendor Equipment Daily Cost Cumulative Cost APC flowlines, etc $0 $20,900 i Dowell nitrogen $0 $3,915 i Halliburton slickline, PXN plug purchase $0 $5,870 Misc. car rental, airline $500 $1,500 Veco roustabouts $180 $180 Vetco 2" gate valves $1,300 $1,300 Weaver Bros. Itrucking $0 $385 DAILY COST: $1,980 CUM: $34,050 REPORTED BY: J.G. Eller 990810.xts MARATHON OIL COMPANY BALLY WELL OPERATIONS REPORT PAGE 1 OF I DATE: 8/10/99 FIELD: Kenai Gas Field FILL DEPTH/DATE: TUBING: 2-3/8", 4.6#, L-80 CASING: DATE LAST WL WORK: 8/7/99 TREE CONDITION: WORK DONE: PXN plug at 3860' BENCHES OPEN: PRESENT OPERATION: Test casing, apply nitrogen pressure on tubing OTHER: Day #2, AFE 0481798 - Annular Flow Conversion WELL #: KU 14-6s 7", 26#, N-80 good SUMMARY OF OPERATIONS MIRU nitrogen unit. RU lines on 7" casing of KU 14-6. Test lines to 2500 psig. The 7" casing had 0 psig, the 13-3/8" casing had 230 psig. Pressure tested 7" casing to 500 psig successfully (pressured up immediately, so fluid level must be to the top). No communication with the 13-3/8" casing. Bled 7" casing to zero. RU nitrogen lines accidentally on the Iongstring tubing and pressure test. Attempt to pressure up but of course could not. RD lines and RU lines on shortstring tubing. Test lines to 2500 psig. Pressure up shortstring tubing to 1950 psig using nitrogen. RDMO nitrogen unit. Vendor Equipment Daily Cost Cumulative Cost Misc. car rental, airline $500 $1,000 Dowell nitrogen $3,915 $3,915 Halliburton slickline, PXN plug purchase $0 $5,870 Weaver Bros. trucking $160 $385 APC flowlines, etc $0 $20,900 DALLY COST: $4,575 CUM: $32,070 REPORTED BY: J.G. Eller Wireline Company: ,~,~"-.MARATHON WELL SERVICE REPORT ~,,~ V~-~ I I I 8-7-99 Well N~mher: 14-6 Short Halliburton Energy Services Location: Pad 14-6 KGF Work Being Done: Present Operations: Marathon Supervisor: Wireline Unit #: Zero Wireline at: Minimum Tubinq I.D. Set PXN Plug Well Shut in Wayne Cissell 2825 TBG Hanger 1.875 Time 07:00 09:30 09:50 10:00 10:20 10:41 11:00 AFE#1PO#: N/A Wireline Crew: Chandler/Hewston Total Wireline Miles: 2.64 N/A Fill Tagged at (KB): Well KB: Max Tool Strinq O~,D. I Operation Details On location spot equipment Rigged up and run in the hole with gauges ring Out of the hole with gauge ring Run in hole with PXN plug Couldn't get down pull out of the hole and rerun gauge ring Gauge ring has to be jarred through tight spot at 2794' Gauge ring out of the hole and start in the hole with PXN plug 11:45 Start in the hole with prong 12:00 Start out of the hole 12:20 At surface bleed off lubricator 13:00 Work St ,ring Detail: Rigged down and off location N/A 1.875" Description of any tools or debris left in the hole: Brief Summary of Total Work Completed: Ticket #; Dailv Cost: Well Downtime Hrs. Day #: Cumulative Cost: H25 Dom: ~ G:tCMN~DRLGtKGF~WELLS~KU13-6LtAOGCCOI.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__ 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 259'N & 964'E of SW Cor, Section 6, T4N, R11W, SM At top of Productive Interval At Effective Depth At Total Depth vertical well 5. Type of Well: Development X Exploratory Stratigraphic Service Convert to Annular Flow Datum Elevation (DF or KB) 20.3 feet 7. Unit or Property Name KENAI UNIT 8. Well Number KU 14-61 9. Permit Number 74-50 10. APl Number 50- 133-10089 11. Field/Pool KENAI GAS FIELD/POOL 6 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical 15047 feet 15047 feet Plugs (measured) feet Junk (measured) feet R C IV Alaska 0il & Gas Cons. C~ Length Size Cemented Measured Depth True Vertical Deptl~nch0rage 60 20" 80 sacks 60' same 3078 13 3/8" 1720 sacks 3078' same 775 sacks 4618 7" 90 sacks 4618' same 744 5" 4593'-5337' same C-1 Sand: 4455' - 4590', C-2 Sand: 4614' - 4650' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) C-1 Sand: 4455' - 4590', C-2 Sand: 4614' - 4650' Long string: 2-3/8", 4.7#, N-80 to 4435' Short string: 2-3/8", 4.7#, N-80 to 3861' RDH dual packer at 3844', model WD packer at 4117', model WD packer at 4392'. 13. Attachments Description Summary of Proposal X Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 7/19/99 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 c~ that the fore,~,]% true and correct to the best of my knowledge. Signed ~. ~ (~~ Gary Eller Title Production Engineer ' ~ %"" FOR COMMISSION USE ONLY Conditions of Approval: Notify Co..~mission so representative may witness Plug Integrity~ BOP Test Location Clearance Mechanical Integrity Test.__~ Subsequent Form Required 10- ~O(,f, Date 7/7/99 IAppr°valN,~ ¢¢---' // ~ Approved by Order of the Commission Form 10~403 Rev. 06/15/88 ORIGINAL SIGNED. By Robert ~u ~,._._.. _.,e~ .~ Cor~missioner Submit in Triplicate ED mml IO WELL KU 14-61- AFE 0481798 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective: Allow flow up the tubing-casing annulus in well KU 14-61 to increase gas deliverability. Procedure: 1. MIRU nitrogen unit on KU 14-6. Using nitrogen, pressure test 7" casing to 400 psig. Monitor 13%" casing for potential communication. When test is complete, bleed all pressure off 7" casing. 2. When casing is completely bled down, remove blind flange on tubing spool across from the existing 7" casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull off the old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 3. Shut in both sides of well KU 14-6. MIRU slickline on KU 14-61. Test BOPs and lubricator to SITP. Set PX plug in X nipple (ID = 1.875") at 4096' MD. RDMO slickline. 4. RU nitrogen on KU 14-61. Pressure up tubing with nitrogen and test PX plug to 1800 psig. When complete, do not bleed pressure off of tubing. RD nitrogen. 5. MIRU slickline on KU 14-61. Test lubricator and BOPs to SITP. MU tool string with XA shifting tool, spang jars, & oil jars. RIH and locate XA sliding sleeve (ID = 1.875") at 3828' MD. Shift open sliding sleeve at 3828' MD while monitoring tubing and casing pressure. POOH. RDMO slickline. 6. RU nitrogen unit on 7" casing of KU 14-6. Pump nitrogen down casing, taking fluid returns on longstring tubing to catch tank. Continue until nitrogen is blowing around the tubing. RD nitrogen. 7. MIRU slickline on KU 14-61. Test BOPs and lubricator to SITP. RIH and pull PX plug at 4096' MD. POOH, RDMO slickline. 8. As soon as possible, produce well at maximum flow rate up tubing to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. 9. Shut in KU 14-61. Install flowline to produce out both sides of the tubing head on KU 14-61. When complete, flow casing side and tubing side simultaneously to test separator and Well KU 14-61 Convert to Annular Flow Page 2 compare with previous test. When testing is complete, produce as per instructions of Production Foreman. JGE July 7, 1999 N:'~DRLG'uKGF~WELLS~<~U 14-61~ANNFLOW.WPD WELL KU 14-61, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling C-1 and C-2 Sands (Pool 6) in well KU 14-61 to be produced up the 2%" tubing and 7" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem I Solution Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing The highest potential for erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 12 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of CO2 is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Pressures imposed on the 7" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 23% of the rated casing burst or collapse. The 7" casing will be pressure tested in excess of maximum anticipated shut-in pressure. IV B2 6 10 v vi ¥11 WELL KU 1 -6 CASING & ABANDONMENT DETAil. I.) Rotary T;~ble Measurement at 0.00' I1.) Tubing Ha~ger at 20.32' III.) 20' Casing at 60° IV.) 13 318'~61~ &54.5~, J-55 Casing at 3078' V.) Top 5',18~, N-80 Liner at 4593' VI.) 7', 26.4~,'N-80 Casing at 4-~' VII.) 5' Liner Shoe at 5337' ~%\~o TUBING DETAIL LONG STRING: 2 3/8; 4.7~, N-80 TUBING fi'5" 1.) Otis 'XA' Sleeve at 3827.69' 2.) 3.) 4.) 5.) 6 .) 7.) 8.) 9.) '~o.) 1.) 12.) RDH Dual Packer at 3842.60' Baker Blast Joints from 3885.29' to 4068.17' Otis 'XA° Sleeve at 4095.62' Otis Straight Slot Locator at 4.109.45' 'WD' Perm. Packer at 4117.00' Molded Seals from 4112.66' to 4119.05' Otis 'XA' Sleeve at 4369.00' Molded Seals from 4382.30' to 4402.34' 'WD' Perm. Packer at 4392.00° Otis 'X° Nipple at 4413.76' Bottom of Mule Shoe at 4435.33' SHORT STRING: 2 3/8; 4.7~, N-80 TUBING A.) Otis 'XA° Sleeve at 3777.37' B.) RDH Dual Packer at 3843.96' C.) Collet Catcher Sub at 3852.84' D.) Otis 'XN° Nipple at 3860.83' PERFORATION RECORD DA TE IN TER VA L 3904'-3923' 3940'-3968' 4000'-4024' 4034'-4066' 4455'-4590' 4614'-4650' CONDITION B-3 Sd. production B-3 Sd. production B-4 Sd. production B-4 Sd. production C-1 Sd. production C-2 Sd. production 1 WELL KU 14-6 WELL SCHEMATIC UNION OIL COMPANY OF " CALIFORNIA ANCHORAGE. ALASKA APP'D, OAT; I I/0 8/84 Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 7, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Reference: Annular Flow Conversion of KU 13-6s and KU 14-61, Kenai Gas Field Dear Mr. Wondzell: Attached are sundry notices for the conversion of wells KU 13-6s and KU 14-61 to annular flow. Each includes a procedure, wellbore schematic, and a discussion of potential risks associated with the annular conversion. You will notice that there are squeeze perforations present above the dual packer in well KU 13-6. I am providing you with further information about the squeeze perfs to address concerns about their integrity and their potential to impact production. I trust that the following information will alleviate any concerns you may have. You will recall that we initially had similar concerns with regard to well KU 43-6al, and the 1998 annular conversion of that well did not compromise the squeeze perfs. The 9¥," casing in well KU 13-6 was perforated at 4080' MD on June 22, 1982 in order to perform a block squeeze. The hole was full of 9.7 ppg mud at the time. The first squeeze attempt on June 22 was unsuccessful. A second squeeze was performed on June 25 used 217 sacks of cement and was successfully tested to 1100 psig surface pressure (15.6 ppg EMVV). There has been no indication of these squeeze perfs having broke down any time since. The annular conversion procedure for KU 13-6s is written to minimize stress on the squeeze perfs and to minimize risk. The 9%" casing will be tested to 400 psig using nitrogen, which will test the squeeze perfs to a pressure of 440 psig to 1980 psig (depending on the fluid level in the annulus). The static bottom hole pressure of the Sterling B-3 Sand in KU 13-6s is only 295 psig. Therefore the initial pressure test exceeds the pressure that the squeeze perfs will be exposed to following the annular conversion. A subsidiary of USX Corporation Environmentally aware for the long run. Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission July 9, 1999 Page 2 Please contact me if further information is needed. I hope to commence this work on Monday, July 19, so your prompt attention is appreciated. Sincerely, J.G. Eller Production Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIbo~ON REPORT OF.SUNDRY WELL OPERATION 1. Operations performed: operation shutdown __ Pull tubing __ 2. Name of Operator Union Oil Co. of Calif. 3. Address PCB 190247, Anch, AK., 4. Location of well at surface Stimulate __ Plugging Perforate Alter casing __ Repair well __ I 5. Type of Well: (UNOCAL) Development .~X Exploratory __ I Stratigraphic __ 99519 - 0247 Service __ Other __ 6. Datum elevation (DF or KB) Pad 66' MSL 7. Unit or Property name Kenai Unit 8. Well number 256' N & 964' E of SW COrner Section ~topofproductiveinterval Section 6, T4N, RllW, SM ~ectivedepth At total depth K[7 I 4-Rf, 9. Per~ber~proval number (, 74-50/,9'-585 . 110. 50-- 133-10089-01 11. Field/Pool Kenai Gas Field feet 'ssl0r , 12. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet J u n k (measu red) Casing Length Structural Conductor 60 ' Surface Intermediate 3,078 ' Production 4,618 ' Liner 744 ' Perforation depth: measured 4,455 ' true vertical Same Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured depth True vertical depth 20" 80 sxs 60' 60' 13-3/8" 7" 5" - 4,590'; 1,720 sxs 775 sxs 90 sxs 3,078' 4,618' 4,593'-5,337' 4,614' - 4,650' 3,078' 4,618' Same RECEIVEI 2-3/8", 4.7#, N-80 4,435' Otis "WD" packer @ 4,392' OCT 1 91989 Alaska 0il & Gas Cons. C0mr~ Anchorage A 4,117'/Dual @ 3,84 13. Stimulation or cement squeeze summary Intervals treated (measured) 4,614' - 4,643' / 4,455' - 4,590' Treatment description including volumes used and final pressure Reperforated 4 SPF w/i-ii/16" W/L guns 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 + 2,410 ' _+ 10 0 + 3 6 0 Subsequent to operation 0 + 2,410 ' + 10 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations .~X Oil __ Gas ~ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Signed Ro~ D. Roberts Form 10-404 Rev 06/15/88 0 + 360 Service Title Environmental Engineer Date 10 / 13 / 8 9 SUBMIT IN DUPLICATE KENAI GAS FIELD KU 14-6L DAILY REPORT 1) 2) 3) 4) 5) 6) 7) RU D.A. wireline perforating guns over KU 14-6L. Pressure tested lubricator to 1,500 psi. RIH with 1-11/16" guns loaded, decentrallized. Located guns across 4,455' - 4,590' & 4,614' - 4,650'. Perforated well at balance. POOH & RD wireline unit. Returned well to production. 4 SPF, phased 0°, SBHP: 560 psi Well Control Fluid: Water NKS:trf 0669r-3/4 ' ~"-"~ STATE OF ALASKA "'-'~ .. /' .$KA OIL AND GAS CONSERVATION COME, ~ION U/i' I APPLICATION FOR SUNDRY APPROVALS' /I 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair we~.l __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other __ 2. Name of Operator 5. Type of Well: ~ 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL Development__ Pad 66' MSL Exploratory __ 3. Address Stratig~raphic~ 7. Unit or Property name P.O. Box 190247, Anch, Ak., 99519-0247 ~Se~WC~.~ Kenai Unit feet Location of well at surface 256' N & 964' E of At top of productive interval Sec. 6, T4N, RllW, At effective depth Attotal depth SW Corner SoMo 8. Well number KU 14-6 L 9. Permit number 10. APl number 50-- 133-10089-O1 il. Field/Pool Kenai Gas Field 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor 60 ' Surface Intermediate 3078' Production 4618 ' Liner 744 · Perforation depth: measured true vertical Size Cemented 20" 80 sxs 13-3/8" 1720 sxs 7" 775 sxs 5" 90 sxs 4455'-4590'; 4614'-4650 Same Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-3/8", 4.7#, N-80 4435' Measured depth True vertical depth 60' Same 3078 · Same 4618 ' Same 4593 '-5337 ' Same WD Paker @ 4392' & 4117' Dual @ 3844' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation July 14, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas .X_ SuSpended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Environmental Engineer FOR COMMISSION USE ONLY Date 6 / 7 / 8 9 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mc/.+ Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commissioner 0002[% 'i5 Form 10-4~3 Rev 06/15/88 0Ri~'~:~SI~NED BY Commissioner [Approva~l No. O, .~-.O, ~'- - -Returned .... _ Date ?-/c~- ~ , SUBMIT IN TRIPLICATE Kenai Gas Field KU 14-6L PERFORATING PROCEDURE 1. RU wireline perforating guns over KU 14-6L 2. Pressure test lubricator to 1500 psi 3. RIH with 1-11/16" guns loaded, 4 SPF, phased 0°, decentrallized 4. Locate guns across 4455'-4590' & 4614'-4650'. (Approximately 8 runs may be required since no more than 20' will be shot at a time.) 5. POOH & RD wireline unit 6. Return well to production. SBHP: 560 psi well control fluid: water 0062/16 WELL KU 14-6 CA Il.) III.) ~v.) v.) vi.) VlL) 2.) 3.) 4.) 5.) 6.) 7.) 8.) lO v vi VII SING & ABANDONMENT DETAIL Rotary Table Measurement at 0.00' Tubing Hanger at 20.32' 20' Casing at 60' 13 3/8~61~* &54.5~, J-55 Casing at 3078' Top 5',18~, N-80 Liner at 4593' 7', 26.4~,'N-80 Casing at 4618' 5' Liner Shoe at 5337' TUBING DETAIL LONG STRING: 2 3/8", 4.7~, N-80 TUBING 1.) Otis 'XA' Sleeve at 3827.69' RDH Dual Packer at 3842.60' Baker Blast Joints from 3885.29' to 4068.17' Otis 'XA' Sleeve at 4095.62' Otis Straight Slot Locator at 4109,45' 'WD' Perm. Packer at 4117.00' Molded Seals from 4112,66° to 4119,05' Otis 'XA' Sleeve at 4369.00' 9.) Molded Seals from 4382,30' to 4402.34' "10.) 'WD° Perm. Packer at 4392.00' 11,) Otis 'X' Nipple at 4413.76' 12,) Bottom of Mule Shoe at 4435.33' SHORT STRING: 2 3/8", 4.7~, N-80 TUBING A.) Otis 'XA' Sleeve at 3777.37' ; B,) RDH Dual Packer at 3843.96' C,) Collet Catcher Sub at 3852;84' D.) Otis 'XN' Nipple at 3860.83' PERFORATION RECORD DA TE INTERVAL CONDITION 3904'-3923' 3940'-3968' 4000'-4024' 4034'-4066' J J4455'-4590~ 4614'-4650' B-3 Sd. production B-3 Sd. production B-4 Sd. production B-4 Sd. production C-1 Sd. production C-2 Sd. production WELL KU 14-6 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA Form D-lOO1-A ORIGIfi UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A Rage No. LEASE Kenai Unit FIELD Kenai Gas Field WELL NO. KU 14-6 BEGAN 6/20/84 COMPLETED 7/26/84 PERMIT N0-."'7'4--~0 SERIAL NO.:-A-=O.-28i42 COMPANY ENGINEER. ~enhoffer/ SP~_O/_Zaxlpr/Abernathy_ APPROVED #331110. L~~ f.~_~_~_ ~. .... ~-_ ~ CONTRACTOR Brinkerhoff R~g #16 TYPE UNIT M & W Rig #12 ELEVATIONS: GROUND CASING HEAD · TUBING HEAO ROTARY DRIVE BUSHING CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 20" 60' 13 3/8" 3078' 54.5# & 61# 3-55 7" 4618' 26# N-80 5" 5337' 18# N-80 See Tubing Detail Conductor Driven Cmt w/ 1720 sx Construction Cmt Cmt w/ 775 sx Construction Cmt Liner Top BDt Hgr $ 4593'. Landing collar $ 5219'. Shoe ~ 5337'. Cmt w/ 90 sx Class ."G" w/ .5% D-19 PERFORATING RECORD DATE INTERVAL E.T.D. REASON 10/74 5175-5195' Beluga Sands 5085-5103' Beluga Sands 4960-4970' Beluga Sands 4856-4968' Beluga Sands 4788-4808' Beluga Sands 10/74 4656-4658' Isolation bet C-2 & Beluga 10/74 4615-4650' C-2 07/84 4614-4650' C-2 10/59 4590-4455' C-1 07/84 4590-4456' C-1 07/84 4155-4180' B-5 10/59 4050-4052' Isolation 07/84 4034-4066' B-4 4000-4024' B-4 07/84 3940-3968' B-3 3904-3923' B-3 07/84 3536-3538' Isolation below A-7 07/84 Short String (Pool 5.1) 3904-3923 ' B-3 3940-3968 ' 4000-4024 ' B-4 4034-4066 ' B-4 Lpng String (Pool 6) 4455-4590 ' c-1 4614-4650 ' c-2 PRESENT CONDITION -Ab~ndOned'6e'£ow-re~ $ 4680' ETD Abandoned below ret ~ 4680' ETD Abandoned below ret $ 4680' ETD Abandoned below ret $ 4680' ETD Abandoned below ret ~ 4680' ETD Sqzd w/ lO0 sx Open Reperfed 4 HPF Open Reperfed 4 HPF Tstd wet & sqzd w/ 200 sx Sqzd w/ 40 sx Open Open Open Open Sqzd w/ 100 sx 3.2 MMCFD 0 BWPD 2.5 MMCFD 0 BWPD WELL HISTORY PRIOR TO REPAIR /$Zx~h~ LAST COMPLETION NO. COMPLETION DATE: 12/23/74 PRODUCING INTERV'A-[i-LS-:-Beluge Sand~;-SS-:-"C-i-'~ C~2Se'nds INITIAL PRODUCTION: LS: 7.81MMCFD .i~/~ ....... LAST REGULAR PROD. & DATE: SS (Pool 6): 5.56 MMCFD, 1BWPD LS (U. Beluqa): 0 MCF Averaqe for 6/84 ~nchora~e CUMULATIVE PRODUCTION:_ Upper Beluga: 18.72 BCF; Pool 6:52.6 BCF REASON FOR REPAIR: To abandop the watered-out Beluga. and recomplete as a LS C-i&i.C-2, --SS B Sand dual ster~£ng_ gas producer. LEASE KENAI UNIT UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. KU #14-6 FIELD SHEET O PAGE NO. KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS KU 14-6 (UOCO 49.61%) A DAY 6/18/84 DAILY COST: $ .3,597 CUM COST: $ 3,597 AFE AMT: $1,040,000 B DAY 6/19/84 DAILY COST: $ 4,462 CUM COST: $ 8,059 AFE AMT: $1,040,000 5288' ETD 1 DAY 6/20/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 30,396 CUM COST: $ 38,455 AFE AMT: $1,040,000 5288' ETD 2 DAY 6/21/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL COMP FLUID) DAILY COST: $ 26,698 CUM COST: $ 65,153 AFE AMT: $1,040,000 5288' ETD 3 DAY 6/22/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 16,306 CUM COST: $ 81,459 AFE AMT: $1,040,000 AFE # 331110 MOBILIZING M & W RIG #12 (BRINKERHOFF RIG #1~ TO THE 14-6 PAD, WELL KU 14-6, KENAI GAS FIELD. CONTINUE MOBILIZING RIG ONTO LOCATION. RIG UP DERRICK & DRAWWORKS & MUD SYSTEM. DRL RAT HOLE & MOUSE HOLE. CONTINUE GENERAL RIG UP. FILL MUD PITS WITH WATER. ACCEPT RIG 8 20:00 HRS, 6/20/84. MIX 6% KCL COMPLETION FLUID. PREP TO KILL WELL. RIG UP OVER LS. PUMP 18 BBLS OF CACO3 (30 LBS/BBLS) FOLLOWED BY 6% KCL COMP FLUID. KILL LS. REPAIR LEAKS IN THE MUD SYSTEM PIPING. SET BPV IN LS. PUMP 11BBLS OF CACO3 (30 LBS/BBL) FOLLOWED BY 6% KCL DOWN SS. (C-l) & (C-2) SANDS STILL TAKING FLUID. TBG NOT STAYING FULL. PUMPED 18 BBL PILL OF CACO3 (30 LBS/BBL) FOLLOWED BY 6% KCL COMP FLUID. PRESS BUILT TO 250 PSI WHEN PILL HIT PERFORATIONS. TBG STAYING FULL. SET BPV IN SS. PULLED DUAL 2 3/8" X 2 7/8" X-MAS TREE. NIPPLED UR BOPE & TEST SAME TO 3000 PSI, OK. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5288' ETD 4 DAY 6123/84 13 318" 8 3078' 7" 8 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 34,711 CUM COST: $ 116,170 AFE AMT: $1,040,000 PULLED BPV IN SS. PU SS & TRIED TO RELEASE SAME FROM DUAL PKR ® 4391' WITHOUT SUCCESS. RU ARRS ON SS & RIH W/ i 13/16" TBG CUTTER. UNABLE TO GET BELOW 2 7/8" X 2 3/8" XO 8 ~354' WLM. POOH. PU & RIH W/ 2 1/4" CUTTER. STUCK CUTTER IN XO ® TBG HANGER. POOH & LEFT 2 1/4" FIRING CAR IN SS. RIH W/ SINKER BARS & JARS. RUSH 2 1/4" FIRING CAP TO 4354' POOH. RIH W/ 2 1/8" CUTTER TO 4350' WLM~ CUT 2 7/8" TBG W/ 40,000 LBS PULL ON SS TBG. POOH W/ WL. CIRC DOWN LS & UP ANNULUS. POOH W/ SS 2 7/8" TBG. 5288' ETD 5 DAY 6/24/84 13 3/8" ® 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6~ KCL) DAILY COST: $ 31,618 CUM COST: $ 147,788 AFE AMT: $1,040,000 PULL & LAY DOWN 4340' OF 2 7/8" TBG F/ SS. CHANGE BORE RAMS F/ 2 7/8" X 2 3/8" TO SINGLE 2 3/8". PULL BRV IN LS. RU & RIH W/ i 13/16" DUMMY ON ARRS WL. COULD NOT GET BELOW COUPLING ~ 4131' WLM IN LS. POOH. RU & RIH W/ i 13/16" OET TBG CUTTER. CUTTER STOPPED ~ 2744' WLM. RICK UR ON TBG PRIOR TO FIRING SET CUTTER AND FOUND LS TBG ALREADY FREE. POOH W/ SET CUTTER. POOH & REC 4136' OF 2 3/8" TBG F/ LS. 20 % OF THE 2 3/8" COUPLINGS WERE SPLIT F/ TOP TO BTM. 5288' ETD 6 DAY 6/25/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 23,840 CUM COST: $ 171,628 AFE AMT: $1,040,000 TST BORE TO 3000 PSI, OK. RIH W/ 2.70" ID OVER-SHOT. UNABLE TO ENGAGE LS FISH. POH. RIH W/ 3 1/8" ID OUTSIDE CUTTER & 4" WASH PIPE. TAG LS 8 4135' DPM. UNABLE TO GET OVER LS FISH. POH. 5288' ETD 4340' SS/ 4323' LS 7 DAY 6/26/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 24,807 CUM COST: $ 196,435 AFE AMT: $1,040,000 POOH & LD OUTSIDE CUTTER & 4" WASHPIPE. PU 5 ll/16" OD OUTSIDE CUTTER (4 3/8" ID) ON 5 3/4" WASH PIPE. RIH. WORK OVER LS 8 4135' DRM. BTM OUT 8 4340' DRM. PULL UR TO COLLAR & CUT LS 8 4323' DRM. POOH & RECOVER 188' OF 2 3/8" TBG. RU & RIH W/ 2 3/8" GRAPPLE. ENGAGE LS FISH 8 4323' DPM. RIH W/ I 13/16" SET TBG CUTTER. CUT LS BELOW DUAL PKR 8 4415' WLM. POOH W/ ARRS WL TOOLS. ATTEMPT TO RELEASE DUAL RKR BY TURNING TO THE RIGHT WITHOUT SUCCESS. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. , LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5288' ETD 4340' SS/ 4354' LS 8 DAY 6/27/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 25,355 CUM COST: $ 221,790 AFE AMT: $1,040,000 5288' ETD 4352' SS/ 4354' LS 9 DAY 6/28/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 27,460 CUM COST: $ 249,250 AFE AMT: $1,040,000 5288' ETD 4382' SS/ 4371' LS 10 DAY 6/29/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 36,259 CUM COST: $ 285,509 AFE AMT: $1,040,000 5288' ETD 4382' FISH ll DAY 6/30/84 13 3/8" $ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 26,832 CUM COST: $ 312,341 AFE AMT: $1,040,000 FINISH POOH. REDRESS GRAPPLE W/ LEFT HAND RELEASE (RIGHT HAND WICKER) & RIH. ENGAGE LS FISH 8 4323' DRM. WORKED IN 4 ROUNDS OF TORQUE WHEN GRAPPLE SPUN FREE. RESET GRAPPLE & RU TO RUN ARRS FREEROINT ON WL. WL TOOLS WOULD NOT GO BELOW 4330' WLM (TOP OF FISH). ' POOH W/ WL. ATTEMPT BLIND BACKOFF W/O SUCCESS. RIH W/ STRING SHOT & BACKED OFF LS 4354' DRM. POOH W/ WL. POOH & RECOVER 31' OF 2 3/8" TBG F/ LS. NOTICED SCALE & DIRT ON TOP OF GRAPPLE. PU i 1/4" CS HYDRIL TBG TAIL ON 3 1/2" DP. RIH. CLEAN OUT FILL (SCALE) F/ 4323-4380' DPM. CIRC HOLE CLEAN. POOH & LD i 1/4" CS HYDRIL TBG TAIL. RU & RIH W/ 2 7/8" GRAPPLE INSIDE OVERSHOT. DRESS TOP OF SS 8 4349' DRM & ENGAGE 2 7/8" GRAPPLE OVER TBG FISH. ATTEMPT TO RELEASE SS F/ DUAL BROWN H-2 HYD PKR W/O SUCCESS. RUN OUTSIDE STRING SHOT & BACKED OFF SS. (WL TOOLS SETTING DOWN ® 4380' WLM, DRM). POOH W/ SS FISH. TOP OF SS 2 3/8" TBG $ 4352' DPM. RIH W/ OS & GRAPPLE. ENGAGE LS $ 4354' DPM. ATTEMPT TO RELEASE DUAL HYD RKR W/O SUCCESS. OET CUT LS TBG ~ 4371' WLM. POOH W/ FISH. REC 16.8'. RIH W/ GRAPPLE & ENGAGE SS TBG ~ 4352' DRM. SET CUT SS ® 4382' WLM (OUST ABOVE TOP OF DUAL RKR). POOH & REC 30' OF SS. PU 60' OF 2 3/8" TBG TAIL ON 3 1/2" DR & RIH. CO FILL F/ 4380-4384' DPM. CIRC WELLBORE CLEAN. POOH W/ DP & TBG TAIL. RIH W/ OS & GRAPPLE. ENGAGE LS TBG $ 4371' DPM. ATTEMPT TO RELEASE RKR W/ 4 ROUNDS OF TORQUE $ THE RKR. RAN TWO STRING SHOTS AND FIRED THEM INSIDE THE PKR. DUAL HYD RKR WOULD NOT RELEASE. gET CUT LS ® 4382' WLM (OUST ABOVE DUAL RKR). POOH W/ LS FISH. REC ll' OF 2 3/8"TBG. MU 6' BURNOVER SHOE & RIH. SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD · LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5288' ETD 4383' FISH 12 DAY 7/01/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 38,028 CUM COST: $ 350,369 AFE AMT: $1,040,000 4386' FISH/ 5288' ETD 13 DAY 7/02/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) RIH W/ 6" OF BURNOVER SHOE. MILL OVER TBG STUBS F/ 4382-4383' DPM. EXPERIENCED HIGH TORQUE F/ 4382-4383' DPM. POOH. RIH W/ 6" CONCAVE STABILIZED MILL. MILL ON TBG STUBS F/ 4382-4383' DPM. CIRCULATED OUT TRACES OF CMT WHILE MILLING. POOH W/ MILL. RU & RUN SCHLUMBERGER CET LOG. TAGGED BTM W/ CET LOG ~ 4383' WLM. RUN CET/ CBL, VDL, CCL, GR F/ 4383' TO SURF. RIH W/ BURNOVER SHOE #2. MILL F/ 4383-4384.5' DPM. POH. JUNK BASKET FULL OF JUNK IRON, SCALE, & CMT. RIH W/ BURNOVER SHOE #3. MILL F/ 4384.5-4385' DPM. POH. RIH W/ BURNOVER SHOE #4. MILL F/ 4385-4386' DPM. DAILY COST: $ 26,948 CUM COST: $ 377,317 AFE AMT: $1,040,000 4386.5' FISH/ 5288' ETD 14 DAY 7/03/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) BURN OVER PKR F/ 4385-4386.5' DPM W/ SHOE #5. RUN SHOE #6. MILLED $ 4386.5 ON TOP OF PKR SLIPS. MADE NO FOOTAGE. DAILY COST: $ 23,606 CUM COST: $ 400,923 AFE AMT: $1,040,000 4386.5' FISH/ 5288' ETD 15 DAY 7/04/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) BURN OVER DUAL PACKER W/ SHOES #7 THRU #9. REDUCED ID OF BURN OVER SHOE'S BY 1/4" TO 4 3/4". OD OF SHOES STILL 6". PREPARE DUAL PKR FOR A DIAMOND BURNOVER SHOE. DAILY COST: $ 28,996 CUM COST: $ 429,919 AFE AMT: $1,040,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 5 LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4382' FISH/ 5288' ETD 16 DAY 7/05/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) RIH W/ BURNOVER SHOE #10. MILL OVER PKR ~ 4386.5' FOR 2 HRS W/ NO PROGRESS. POOH. PU & RIH W/ DIAMOND BURNOVER SHOE #11. MILL ON PKR ~ 4386.5'. PKR STARTED ROTATING. POOH. RIH W/ TAPER TAP & TAG TOP OF PKR ~ 4382' DPM. DAILY COST: $ 30,951 CUM COST: $ 460,870 AFE AMT: $1,040,000 4385' FISH/ 5288' ETD 17 DAY 7/06/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 31,143 CUM COST: $ 492,013 AFE AMT: $1,040,000 4412' FISH/ 5288' ETD 18 DAY 7/07/84 13 3/8" $ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) WORK OVER FISH 8 4382' DPM W/ TAPER TAP. TAPER TAP KEPT SLIPPING. POOH. PU & RIH W/ 6" BOX TAP. POOH & REC .37' 2 3/8" TBG, .62' OF X-OVER, .96' MANDREL. PU & RIH W/ TAPER TAP ENGAGE FISH 8 4385' DPM. POOH & REC TWO .55' EACH PIECES OF MANDREL. RIH W/ TAPER TAP. ENGAGE FISH 8 4385'. OAR ON PKR FOR 2 HRS. UNABLE TO GET LOOSE F/ PKR. RUN STRING SHOT & BACK OFF DP $ 4283' WLM. POOH W/ DP. RIH W/ NEW OARS & SCREW INTO DP FISH @ 4287' DPM. OAR & WORK FISH FOR 2.5 HRS WHEN PKR CAME FREE. POOH & REC BROWN DUAL PKR, ALL OF SS TAIL & 17' OF LS. PU WASH PIPE & RIH. TAG TOP OF LS ~ 4412' DPM. DAILY COST: $ 23,750 CUM COST: $ 515,763 AFE AMT: $1,040,000 4589' FISH/ 5288' ETD 19 DAY 7/08/84 13 3/8" $ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 30,359 CUM COST: $ 546,122 WORK OVER LS FISH W/ WP TO 4607' WHERE IT TORQUED UP. POOH & LD WASH PIPE. RIH W/ OVERSHOT & GRAPPLE. ENGAGE FISH ~ 4412' DPM. RUN FREE POINT. TBG PLUGGED 8 4641' WLM. POOH W/ FREE POINT INDICATOR. RIH W/ STRING SHOT & FIRE SAME $ 4585' WLM. BACK OFF LS ~ TOP OF 9TH BLAST $OINT. POOH W/ WL. POOH W/ LS FISH. AFE AMT: $1,040,000 LEASE KENAI UNIT UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. KU #14-6 FIELD SHEET D PAGE NO. KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4609' FISH/ 5288' ETD 20 DAY 7/09/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 26,514 CUM COST: $ 572,636 AFE AMT: $1,040,000 4629' FISH/ 5288' ETD 21 DAY 7/10/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 31,100 CUM COST: $ 603,736 AFE AMT: $1,040,000 4629' FISH/ 5288' ETD 22 DAY 7/11/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF (6% KCL) DAILY COST: $ 24,514 CUM COST: $ 628,250 AFE AMT: $1,040,000 4686' FISH/ 5288' ETD 23 DAY 7/12/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF 39 SEC DAILY COST: $ 22,734 CUM COST: $ 650,984 AFE AMT: $1,040,000 POOH & REC 177' OF LS TUBING & BLAST JOINTS. PU WASH PIPE & RIH. TAG & WASH OVER BLAST JTS F/ 4589' TO 4613' DPM WHERE PROGRESS STOPPED. POOH, LD WP & PU OVERSHOT. RIH & ENGAGE FISH ~ 4589' DPM. TRIED TO RELEASE PKR W/O SUCCESS. PERFORMED BLIND BACKOFF & POOH. REC ONE BLAST OOINT & A DRILL PIPE RUBBER STUCK IN OVERSHOT FROM PREVIOUS WORKOVER. PU WP & RIH. TAGGED TOP OF LS $ 4609' DPM. WASH DOWN TO 4613' DPM. WASH $ 4613' FOR 40 MIN W/O ANY PROGRESS. POOH. LD WASH SHOE. PU OS & RIH. TAG FISH $ 4609' DPM. RU APRS & RUN STRING SHOT ON WL. BACK OFF LS $ 4629' DPM. POOH & REC ONE BLAST OOINT. PU & RIH W/ 4 1/8" OD TAPER TAP MILL. DRESS 5" LINER F/ 4610'- 4628'. POOH W/ TAPER TAP MILL. POOH W/ TAPER MILL. PU & RIH W/ OVERSHOT & GRAPPLE. TAG TOP OF FISH 8 4629' DPM. UNABLE TO ENGAGE FISH. POOH. OVERSHOT HAD MARKS ON THE OUTSIDE INDICATING JUNK AROUND TOP OF THE FISH. PU & RIH W/ 4" OD X 3 1/8" ID WASH OVER SHOE. WASH OVER FISH F/ 4629-4687' DPM. POOH. RIH W/ NEW SHOE TO 4687'. WASH JUNK & SAND TO 4689' DPM. POOH W/ WASH OVER SHOE. TRIP FOR WO SHOE. RIH W/ SHOE #17 & MILLED ON JUNK F/ 4687' TO 4689'. TRIP FOR SHOE #18. WASHED FILL F/ 4688' TO 4689'. COULD NOT GET DEEPER. POOH. RIH W/ BHA #41 (OVERSHOT) & LATCHED ONTO FISH ~ 4629'. JARRED FISH LOOSE. COULD NOT CIRCULATE THRU FISH. DROPPED CIRC DART & BROKE CIRC. POOH - REC 20.78' OF BLAST JTS, .60' CROSSOVER , 31.96' OF 2 3/8" TBG, & 3.69' OF 2 3/8" TUBING PIECE. TEST BOPE. RIH W/ WASHPIPE & WO SHOE. WASHED OVER FISH F/ 4686' to 4690'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET O PAGE NO. LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4686' FISH/ 5288' ETD 24 DAY 7/13/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF 40 SEC DAILY COST: $ 24,205 CUM COST: $ 675,189 AFL AMT: $1,040,000 4680' RET/ 5345' TD 25 DAY 7/14/84 13 3/8" $ 3078' 7" ® 4618' 5" L. 4593-5337' 64 PCF 40 SEC DAILY COST: $ 31,939 CUM COST: $ 706,752 AFL AMT: $1,040,000 POOH. RIH W/ BURN SHOE #20. WASH OVER FISH F/ 4690-4690.5'. MILL $ 4690.5' (NO PROGRESS). POOH. RIH W/ BURN SHOE #21. MILLED F/ 4690.5'- 4691'. SUDDEN INCREASE IN TORQUE. POOH. FOUND SPIRAL CRACK IN BOTTOM 9' OF SHOE, LOST +.47' OF SHOE IN HOLE. RIH W/ OVERSHOT. TAG FISH ~ 4686' WASH DOWN TO 4688'. UNABLE TO ENGAGE FISH . POOH. LD FISHING TOOLS. RIH W/ 6" BIT & CSG SCRAPER. TAG LINER TOP ® 4593'. POOH. RIH W/ TAPERED MILL & 5" CSG SCRAPER. TAG FISH $ 4686'. POOH. RU APRS & RUN DIALOG 64 ARM CSG INSPECTION TOOL (5"). TAG FISH ~ 4686'-COULD NOT ACTIVATE TOOL ON BTM. POOH & RE-RUN 5" INSPECTION TOOL. TAG FISH $ 4686'. AGAIN COULD NOT ACTIVATE ON BTM. ACTIVATED IN RERFS $ 4650' & LOGGED UR TO LINER TOP ~ 4593' HUNG WIRELINE TOOL IN LINER HANGER. WORKE~ FREE $ 3000 LB AFTER 20 MINUTES. POOH. RIH W/ DIALOG 7" CSG INSPECTION TOOL. TAG LINER TOP $ 4593' & LOG TO SURFACE. RD ARRS. RIH W/ BAKER 5" CMT RET & SET ® 4680'. ATTEMPTED TO BREAKDOWN FORMATION THRU FISH. PRESS UP TO 1000 PSI BELOW RET (3000 PSI BHR) HELD FOR l0 MINUTES- NO BLEED OFF. POOH. 4290' RET/ 5345' TD 26 DAY 7/15/84 13 3/8" $ 3078' 7" ~ 4618' 5" L. 4593-5337' 64 PCF 4O SEC DAILY COST: $ 22,696 CUM COST: $ 729,448 AFL AMT: $1,040,000 RIH W/ BAKER 7" CMT RET & SET $ 4290'. PRESS TST CSG ABOVE RET TO 2000 PSI-OK. POOH. (CLEANI~ & TEFLON DOPING EVER OTHER ST). RU GEARHAR~T TBG-CONVEYED RERF GUNS, HALLIBURTON RTTS, BYPASS, HYDROSRRING & RIH (CLEANING & TEFLON DOPING EVERY OTHER ONT). RU GEARHART WIRELINE. RU BO HUGHES & PRESS TST LINES, LUBRICATOR & TST MANIFOLD TO 2000 PSI W/ N2-OK. TST DR TO 1400 PSI W/ N2-OK. SET RTTS ~ 4lO1' & RIH W/ GEARHART GR-CCL LOG FOUND TOP RERF SHOT TO BE ~ 4155' AS HOPED. POOH W/ WIRELINE. LD GR/CCL TOOL. INSERT FIRING 8AR IN LUBRICATOR. RU HR PRESS TOOL. PRESS DR TO 1350 PSI W/ N2. PRESS ANNULUS TO 400 PSI-HELD OK-BLED OFF. DROPPED FIRING BAR & RERFD THE B-5 SAND F/ 4155-4180' DIL. BLED TO FLARE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D RAGE NO. LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3565' RET/ 5345' TD 27 DAY 7/16/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 64 PCF 40 SEC DAILY COST: $ 26,986 CUM COST: $ 756,434 AFE AMT: $1,040,000 3480' ETD (CMT)/ 5345' TD 28 DAY 7/17/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 65 PCF 39 SEC DAILY COST: $ 27,815 CUM COST: $ 784,249 AFE AMT: $1,040,000 4076' ETD (CMT)/ 5345' TO 29 DAY 7/18/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 65 PCF 42 SEC (6% KCL) WELL DIED AFTER 1 HR 35 MIN. RAN HR PRESS RECORDER ON WL. FOUND SHUT IN BTM HOLE PRESS TO BE 1485 PSI. RIH W/ 7" CMT RET & SET SAME 8 4100' DPM. ABANDON THE B-5 SD W/ 200 SX CMT (CLASS G, 1.2% D-19, .25% A-2, 1% D-6L) BELOW THE RET. FINAL SQZ PRESS WAS 2200 PSI W/ PUMPS OFF FOR 2 MIN. CIP 8 18:05 HRS, 7/16/84. POOH RU & RIH W/ 7" CMT RET ON WL. SET RET 8 3565' DIL. POOH W/ WL. RU & RIH W/ PERF GUN. SHOT BELOW A-7 SAND F/ 3536-3538' DIL W/ 2HPF, 120° PHASING, 4" CSG GUNS. POOH W/ GUN. RU & RIH W/ 7" CMT RET ON DR. RIH & SET BAKER CMT RETAINER $ 3500'. RU BO HUGHES & TST LINES TO 3500 PSI-OK. STABBED INTO RET & BROKE DWN SQZ RERFS F/ 3536' TO 3538' DIL W/ 1250 PSI (.8 RSI/FT). MIXED & SQZD FOR A-7 ISOLATION W/ 100 SX CL "G" W/ 1.2% D-19, .25% A-2, 1% D-6L. CIR 8 02:40 HRS, 7/17/84. PULLED I STD & REV CIRC. POOH. WOC. RIH W/ 6" BIT & TAGGED TOP OF CMT ~ 3480'. CO CMT F/ 3480-3500' DPM. DRL RET F/ 3500'- 3502' DPM. DRL CMT TO 3563' DPM. TEST ISOLATION SQZ (A-7 SAND) TO 500 PSI, OK. DRL RET F/ 3563-3565'. CO OUNK & CMT TO 4076' DPM. CIRC. POOH FOR NEW BIT. RIH. DAILY COST: $ 22,504 CUM COST: $ 806,753 AFE AMT: $1,040,000 4680' ETD/ 5345' ID 30 DAY 7/19/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 65 PCF 38 SEC DAILY COST: $ 34,180 CUM COST: $ 840,933 DRLD CMT F/ 4076-4100', RET 4100-4102', GOOD CMT 4102-4147', & CMT STRINGERS TO 4193'. TAG RET ® 4229'. CIRC. CLOSE ANNULAR & TST B-5 ABANDONMENT SQZ TO 500 PSI-OK. POOH. RIH W/ PLUG PLUCKER & BURNED OVER & & RETRIEVED RET. (TIGHT SPOT ~ 4225'). RAN BIT & SCRAPER TO TOP LINER ~ 4593' (TIGHT SPOT OK). CIRC & POOH. RIH W/ 2 7/8" STINGER. AFE AMT: $1,040,000 SHEET D PAGE NO. LEASE KENAI UNIT UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4680' ETD/ 5345' TD 31 DAY 7/20/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 65 PCF 39 SEC DAILY COST: $ 22,952 CUM COST: $ 863,885 AFE AMT: $1,040,000 4680' ETD/ 5345' TD 32 DAY 7/21/84 13 3/8" S 3078' 7" $ 4618' 5" L. 4593-5337' 65 PCF 37 SEC DAILY COST: $ 88,325 CUM COST: $ 952,210 AFE AMT: $1,040,000 RIH & TAGGED RET S 4680'. PLACED SATURATED SALT/BRIDGE-SAL PILL UR TO 3500'. POOH. RIH W/ BRIDGE PLUG & SET $ 60'. TESTED SAME TO 500 PSI & POOH. REMOVED OLD "DCB" TBG HEAD DUE TO UNAVAILABILITY OF MATCHING HANGERS & REPLACED SAME. TESTED NEW 7 1/16", 5000# X 13 5/8", 3000# HEAD TO 3000 PSI. PULLED BR & ATTEMPTED TO TEST BORE-TEST PLUG WOULD NOT SEAT (DIAMETER TOO LARGE) RESET BP S 120'. LIFTED BORE TO CHECK FIT ~F TEST PLUG THROUGH XO SPOOL BETWEEN DCB & BORE-PLUG WOULD PASS THROUGH SPOOL BUT WOULDN'T FIT IN DCB. REINSTALLED BORE. TESTED BORE. RETRIEVED BP. RU SCHLUMBERGER & REPERFED C-2 (4614-4650') & C-1 (4580-4590') SANDS W/ 3 3/8" GUNS, 4 HRF, 90° PHASING. CON'T RERERF C-1 (4456-4580') W/ 4" GUNS, 4 HRF, 90° PHASING. RD SCHLUMBERGER, RU GEARHARDT. RAN GAGE RING &OUNK BASKET TO 4430'. RAN & SET 4" BORE OTIS "WD" PERM RKR S 4392'. RIH W/ STINGER, STABBED INTO PKR & TESTED TO 250 PSI-OK. POOH. RAN & SET 4" BORE OTIS "WD" PERM RKR S 4117'. RD GEARHARDT. 4680' ETD/ 5345' TD 33 DAY 7/22/84 13 3/8" ~ 3078' 7" S 4618' 5" L. 4593-5337' 65 PCF 34 SEC DAILY COST: $ 72,486 CUM COST: $1,024,696 AFE AMT: $1,040,000 RIH W/ STINGER, STABBED INTO PKR S 4117' & TESTED TO 250 PSI-OK. POOH. RIH W/ PERFING ASSY: STINGER; DRILL PIPE FOR SPACING; 5", 9 HRF, 120° PHASING GEARHARDT TBG-CONVEYED GUNS; i 3T TBG: RTTS; FULL-FLOW HYDROSPRING; RUMP-OUT SUB: DC'S; DR TO SURF FILLED DR W/ ll70' WATER CUSHION, REMAINDER DRY. STABBED INTO RKR. INSTALLED DR LUBRICATOR, SURFACE CONTROL VALVES, & TEST CHOKE MANIFOLD & TESTED SAME TO 2000 PSI. SET RTTS & OPENED HYDROSRRING. DROPPED BAR TO FIRE GUNS & RERF THE B-3 (3904-23', 3940-68') & B-4 (4000-24', 4034-66'). FLUID TO SURFACE IN 5 MIN. UNLOADED WATER CUSHION FOLLOWED .BY GAS, SAND, & MUD FILTRATE THEN GAS & APPARENT FORMATION WATER. SHUT IN TO LIGHT FLARE. OPENED UP TO FLARE- FLAME WAS YELLOW, APPROXIMATELY 30' HIGH. REROUTED PROD TO TEST SEPARATOR FOR 2 HR TEST: 3.9 MMCFD RATE S 753 PSI, NO APPRECIABLE WATER CUT. SHUT WELL IN & BULLHEADED SATURATED SALT/ BRIDGE-SAL COMPLETION FLUID TO KILL. RELEASED RTTS & CLOSED HYDROSPRING. SHEARED OUT PUMP- OUT SUB W/ 1500 PSI & CIRC GAS-CUT MUD THRU CHOKE. CIRC 3 TIMES, NO GAS AFTER FIRST CIRC. RD SURF EQUIP. POH i STAND, DP BEGAN TO BUBBLE OVER, ANNULUS CALM. RIH & CIRC ONCE AROUND THRU CHOKE. SI, NO PRESS. CIRC ANOTHER HOLE VOLUME, SHUT IN-NO PRESS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4680' ETD / 5345' TD 34 DAY 7/23/84 13 3/8" $ 3078' 7" $ 4618' 5" L. 4593-5337' 67 PCF 34 SEC DAILY COST: $ 20,101 CUM COST: $1,044,797 AFE AMT: $1,040,000 4680' ETD / 5345' TD 35 DAY 7/24/84 13 3/8" $ 3078' 7" $ 4618' 5"L. 4593-5337' DALLY COST: $ 185,805 CUM COST: $1,230,602 AFE AMT: $1,040,000 POOH, LD GUNS (ALL FIRED). RIH W/ 2 3/8" TBG THROUGH BOTH RKRS TO 4420'. POOH TO 4387' & SPOT 60 BBLS OF SAT SALT COMRL FLUID TREATED W/ RARAFORMALDEHYDE. POOH TO 3870' & CIRC 1 HOLE VOLUME THROUGH CHOKE. POOH LD DP. CHANGE TO 2 3/8" DUAL RAMS, RU TO RUN TBG. FUNCTION TEST DUAL RAMS. MAKE DUMMY RUN OF DUAL HANGER INTO DCB-OK. RAN DUAL 2 3/8" COMPL ASSY, STABBING INTO PERM PKRS. STRIPPED OUT THREADS IN LANDING JOINT RECEPTACLE OF SHORT STRING HANGER. BORED OUT OLD THREADS & CUT NEW ONES WHERE 8PV THREADS WERE. REINSTALLED HANGER W/ OTIS "X" NIPPLE BELOW SS HANGER. LANDED TBG. SET BPV IN LS. DROPPED BALL IN SS & SET OTIS RDH DUAL PKR 8 3848' W/ 900 PSI & SHEARED OUT 8 2200 PSI. TSTD BACKSIDE OF RKR TO 350 PSI-OK. SET "XX" EQUALIZING PLUG IN "X" NIPPLE & TESTED TO 800 PSI-OK. RD TBG EQUIP. 4680' ETD / 5345' TD 36 DAY 7/25/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' DAILY COST: $ 26,672 CUM COST: $1,257,274 AFE AMT: $1,040,000 4680' ETD / 5345' TD 37 DAY 7/26/84 13 3/8" ~ 3078' 7" ~ 4618' 5" L. 4593-5337' REMOVED BOPE & INSTALLED TREE, TESTING TO 3000 PSI. PULL LS BRV. RU OTIS, TESTING LUBRICATOR TO 3000 PSI. PULLED SS "X"-RLUG BELOW HANGER. OPENED LS "XA" ~ 3830'. DISPLACED DOWN LS W/ WATER UNTIL ANNULUS RETURNS CLEAN, THEN DISPLACED ANNULUS W/ llO BBLS RKR FLUID. OPENED "XA" ~ 4098', CLOSED "XA" ~ 3830'. TSTD ANNULUS TO 1000 PSI-OK, LUBRICATOR TO 3000 PSI. DISRL LS W/ N2 TAKING RETURNS UP SS TO UNLOAD BOTH STRINGS. ROUTED PRODUCTION TO FLARE-WELL CLEANED UP IN APRROX 15 MIN. SOME APPARENT WATER ENTRY (YELLOW FLARE, ESR LS). BLEW DOWN WELL FOR i 1/2 HRS, SWITCHING FROM LS TO SS EVERY 20 MIN. SI WELL ¢ 23:40 HRS, W/ 650 PSI ~ SURFACE. CLOSED "XA" ~ 4098'. OPENED SS TO FLARE ~ 01:30 HRS. SI SS & OPENED LS ~ 02:00 HRS, SI LS ~ 04:30 HRS. SET OTIS "X" PLUG BELOW SS HANGER & TEST TO 3000 PSI. SET BPV IN LS. RELEASE RIG ~ 08:30 HRS, 7/26/84. DAILY COST: $ 8,673 CUM COST: $1,265,947 AFE AMT: $1,040,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D RAGE NO. ll LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS OTS 115 LONG STRING TUBING DETAIL DESCRIPTION Half M/S Guide 2 3/8" Butt Pup 2 3/8" Eue Box XO 2 3/8" Butt Pin Otis "X" 2 3/8" Eue Pin x Pin 2 3/8" Butt Box XO 2 3/8" Eue 2 3/8" 8utt Pup 3 1/2" NU 10rd Box XO 2 3/8" Butt Pin Seals above "WD" ~ 4392' DRM Seals above "WD" ~ 4392' DRM 2 3/8" Butt Box XO 3 1/2" NU 10rd Pin 2 3/8" Butt Pup 2 3/8" Eue Box XO 2 3/8" Butt Pin Otis "XA" 2 3/8" Eue Pin x Pin 2 3/8" Butt XO 2 3/8" Eue 2 3/8" Butt w/ SC Couplings 3 1/2" NU 10rd Box X 2 3/8" Butt Pin Seals below "WD" 2' Seals above "WD" ~ 4117' DPM Otis St Slot Loc 2 3/8" Butt Box XO 3 1/2" Eue Pin 2 3/8" Butt Pup w/ SC Coupling 2 3/8" Eue Box XO 2 3/8" Butt Pin Otis "X-A" Eue Box X Pin 2 3/8" Butt Box X 2 3/8" Eue Pin 2 3/8" Butt Pup W/ SC Coupling 2 3/8" Butt Pup W/ SC Coupling 2 3/8" Butt Pup W/ SC Coupling 2 3/8" Eue Box XO 2 3/8" Butt Pin Baker Blast Ots 2 3/8" Eue Box x Pin 2 3/8" Butt Box X 2 3/8" Eue Pin 2 3/8" Butt w/ SC Coupling 2 3/8" Butt / 2 3/8" Eue (Double Pin) Coupling Mandrel below pkr RDH Dual Pkr 2 3/8" Eue X 2 3/8" Butt (Double Pin) 2 3/8" Butt Coupling 2 3/8" Butt Pup w/ SC Coupling Otis "XA" - Double Pin Butt 2 3/8" Butt SC Coupling 2 3/8" Butt Pup w/ SC Coupling 2 3/8" Butt Pup w/ SC Coupling 2 3/8" Butt Tbg w/ SC Coupling 2 3/8" Butt Pup w/ SC Coupling 2 3/8" Butt Tbg w/ SC Coupling 2 3/8" Butt Pup w/ SC Coupling XO 2 3/8" Eue Pin to Butt Pin CIW Tbg Hgr 2 3/8" Eue Top & Bot RT to DCB LENGTH BOTTOM TOP .68' 4435.33' 4434.65' 19.64' 4434.65' 4415.01' .47' 4415.01' 4414.54' .78' 4414.54' 4413.76' .68' 4413.76' 4413.08' 10.03' 4413.08' 4403.05' · 71' 4403.05' 4402.34' 16.04' 4402.34' 4386.30' 4.00' 4386.30' 4382.30' .75' 4382.30' 4381.55' 9.65' 4381.55' 4371.90' .46' 4371.90' 4371.44' 2.44' 4371.44' 4369.00' .67' 4369.00' 4368.33' 248.57' 4368.33' 4119.76' .71' 4119.76' 4119.05' 6.39' 4119.05' 4112.66' 2.00' 4112.66' 4110.66' 1.21' 4110.66' 4109.45' .79' 4109.45' 4108.66' 10.12' 4108.66' 4098.54' .46' 4098.54' 4098.08' 2.46' 4098.08' 4095.62' .67' 4095.62' 4094.95' 6.12' 4094.95' 4088.83' 10.05' 4088.83' 4078.78' 10.03' 4078.78' 4068.75' .58' 4068.75' 4068.17' 182.88' 4068.17' 3885.29' .84' 3885.29' 3884.45' 32.02' 3884.45' 3852.43' 2.30' 3852.43' 3850.13' · 41' 3850.13' 3849.72' .79' 3849.72' 3848.93' 6.33' 3848.93' 3842.60' 1.44' 3842.60' 3841.16' · 71 3841.16' 3840.45' 10.16' 3840.45' 3830.29' 2.60' 3830.29' 3827.69' .71' 3827.69' 3826.98' 8.52' 3826.98' 3818.46' 10.12' 3818.46' 3808.34' 155.99' 3808.34' 3652.35' 8.12' 3652.35' 3644.23' 3619.65' 3644.23' 24.58' 2.42' 24.58' 22.16' 1.06' 22.16' 21.10' .78' 21.10' 20.32' 20.32' 20.32' 0.00' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE KENAI UNIT WELL NO. KU #14-6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3TS 64 SHORT STRING TUBING DETAIL DESCRIPTION Otis "X-N" 2 3/8" D Pin Butt 2 3/8" SC Coupling 2 3/8" Butt Pup 2 3/8" Eue Box XO 2 3/8" Butt Pin Collar Catcher Sub 2 3/8" Butt Box XO 2 3/8" Eue Pin 2 3/8" Eue Box XO 2 3/8" Butt Pin Mandrel below RDH RDH dual pkr Est above RDH 2 3/8" Butt Box XO 2 3/8" Eue Pin 2 3/8" Butt "XA" 2 3/8" SC Coupling 2 3/8" Butt 2 3/8" Butt Pup 2 3/8" Butt 2 3/8" Butt Pup w/ SC Coupling Otis "X" 2 3/8" Eue/ 2 3/8" Butt CIW Tbg Hgr rebored w/ 2 3/8" Butt Top no BRV threads $ 2 3/8" Eue Bot (Double Pin) RT to DCB LENGTH BOTTOM TOP .81' 3860.83' 3880.02' .71' 3860.02' 3859.31' 5.08' 3859.31' 3854.23' .46' 3854.23' 3853.77' · 93' 3853.77' 3852.84' .69' 3852.89' 3852.15' · 44' 3852.15' 3851.71' 1.42' 3851.71' 3850.29' 6.33' 3850.29' 3843.96' · 21' 3843.96' 3843.75' .68' 3843.75' 3843.07' 63.11' 3843.07' 3779.96' 2.59' 3779.96' 3777.37' .71' 3777.37' 3776.66' 2014.77' 3776.66' 1761.89' 6.06' 1761.89' 1755.83' 1732.03' 1755.83' 23.80' 2.10' 23.80' 21.70' · 60' 21.70' 21.10' · 78 21.10' 20.32' 20.32 20.32' 0.00' ELL KU ,, '~ GA$1NG & ABANDONMENT DETAIL ~' 1! 11 I.) Rotary Table Measurement at 0.00' i i, '11.) Tubing Harjger at'20.32' III ~ ~ III.) 20" Casing at 60' , I IV.) 13 318'~6.1~ &54.5~, J-55 Casing at 3078' i~ ~ V,) TOp 5',18~, N-80 Liner at 4593' IV, ~ i VI.) 7', 26.4~,'N-80 Casing at 4618' VII.) 5' Liner Shoe at 5337' ^ ~ ~ TUBING DETAIL ~--, ~ LONG STRING: 2 3/8 , 4.7~, N-80 TUBING 1.) Otis 'XA' Sleeve at 3827.69' ' 2.) RDH Dual Packer at 3842.60' B2 i ~ 3.) Baker Blast Joints from 3885.29' to 4068.17 ~ ~ 4.) Otis 'XA° Sleeve at 4095.62' [ , · ~ 5.) Otis Straight Slot Locater at 4109.45' := c cc,~ 6.) 'WD'. Perm. Packer at 4117.00 ~_ 3 7.) Molded Seals from 4112.66'*to 4119.05' D XN 8.) Otis 'XA' Sleeve at 4369.00' ! x_~ 4 9.) Molded Seals from 4382.30' to 4402.34 I 10.) 'WD' Perm. Packer at 4392 00' o 12.) Bottom of Mule Shoe at 4435.33' _~ ! SHORT STRING: 2 3/8", 4.7~ N-80 TUBING ixA~ 8i A.) Otis 'XA' Sleeve at 3777.37' B.) RDH Dual Packer at 3843.96' lO :~:::~~~X C.) Collet Catcher Sub at 3852.84' ~ D.) Otis ~XN" Nipple at 3860.83' ~-~ PERFORATION RECORD i I ~ DA TE INTERVAL CONDITION i: l~ 2 3904'-3923' B-3 Sd. production 1 .-- .-- -- 3940'-3968' B-3 Sd. production ¥. -i - v~ _ _ 4000'-4024' B-4 Sd. production ; , : 4034'-4066' B-4 Sd. production '~ 4455'-4590' C-1 Sd. production , 4614'-4650' C-2 Sd. production v~ d REV. DATE · DRAWN WELL KU .14-6 , SCALE NONE WELL SCHEMATIC - UNION OIL COMPANY oF CALIFORNIA 2_." 5ooo~- J .... RX 57 ® WF 11 STATE OF ALASKA ~-' ALASKa, OIL AND GAS CONSERVATION L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 74-50 3. Address P. O. BOX 6247, ANCHORAGE, ALASKA 4. Location of Well 99502 8. APl Number 5o!33-10089-01 9. Unit or Lease Name KENAI UNIT 256'N & 964'E of SW Cor, Sec 6,T4N,RllW,SM 5. Elevation in feet (indicate KB, DF, etc.) Pad 66'MSL I 6. Lease Designation and Serial No. A-028142 10. Well Number KBU #14-6 11. Field and Pool Kenai Gas Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate J~ Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well J~ . Change Plans [] Repairs Made [] Other Pull Tubing J~ Other [] Pulling Tubing C~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. 18. 2. 19. . 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Rigged up over KBU 14-6. Killed well, installed BPV's, removed dual tree, installed & tested BOPE to 3000psi. Flowed well for clean-up. Reinstalled BPV's & released rig for rig down. 14. 15. 16. 17. Removed BOPE, installed & tested tree to 3000psi. ertif¥ that _the~r?~g is tru~and correct to the best of my knowleOge. T~p~elo~ for-Comm~ission use o~i°ns of Approval if ;'nv: Recovered & laid down dual 2 3/8" X 2 7/8" completion assembly. Cleaned out to 4383'WLM. Ran CET-CBL, VDL, CCL, GR Log f/4383 WLM to surface. Cleaned out to 4686. ~,~4 Set cement retainer at 4~80 & 4290. Perf'd & tested B-5 sand f/4155-4180 OIL. ~ ~- Sqz'd 8-5 sand W/2OOsxs cl "G" cmt. Set cement retainer at 35~5. Perf'd & Sqz'd for isolation f/3536-3538 w/lO0 sxs cl "G" cmt~ Cleaned out to 4~80. Reperfed: C-2 sands f/4614-4650 w/4HRF C-1 sands f/4456-4590 w/4HRF ~ Set Perm packer at 4117. Perf'd & tested B-3 sands f/3904-3923 & 3940-3968 w/gHRF. B-4 sands f/4000-4024 & 4034-4066 w/gHPF. Ran dual 2 3/8" cOmpletion assemblies. By Order of Approved by COMMISSIONER the Commission FOrm 10-403 Date 8-29-84 Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ALASK. 31LANDGAS CONSERVATION ~ "MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERAI'IONS · Drilling well [] Workover operation 2. Name of operator 7. Permit No. OIL COMPANY OF CALIFORNIA 3. Address 8. APl Number 1 PO BOX 6247 ANCHORAGE AK 99502 50_50-i33-i0089-0 4. Location of Well at surface 256' N & 964' E of SW Corner of Sec 6, T4N, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 66' MSLI A-028142 9. Unit or Lease Name Kenai Unit 10, Well No. KU #14-6 11. Field and Pool Kenai Gas Field For the Month of. JULY '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~ Continued fishing completion assembly down to 4686'. Set retainer in 5" liner at 4680'. Tested B-5 sand wet and squeezed to abandon. Shot and squeezed A-7 sand to isolate. Reperfed C-1 and C-2, added new perfs in B-~ and B-4. Ran tubing and released rig at 0830 hfs, 7/2/84. 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE RECEIVED AUG 1 6 1984 Alaska 0il & Gas Cons. Commission Anchnra~ne ,1 6. DST data~ perforating data, shows of H2S, miscellaneous data B-5 Sand (4155,4180') - tested wet, BHP=1485 psi. A-7 Sand (~536-~5~8') - shot and squeezed C-1 (4456-4590') & C-2 (4614-4650') - reperfed 4 HPF B-3 (3904-3923' & 3940-3968') & B-4 (4000-4024' & 4034-4066') - shot 9 HPF 17. I hereby ~( that the_f°reg~:ng._. is true and correct to the best of my knowledge· "- S,GNED__ ~~....'~~_~?_-_&~--~,tITL~ISTRICT DRLG SUPT DATE 08/10/84 NOTrl~--~/:t on this form is required fOr each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil ~llNil~as Conservation Commission by the 1 §th of the succeeding month unless otherwise directed, Form 10~,04 Submit in duplicate .~---'., STATE OF ALASKA ~.--., ~ "OI THLY ALASK~ _AND GAS CONSERVATION C' ISSlONoPERAi. iON . r REPORT QF DRILLING AND WORI OVER ~. ~ ~ ~ Workove--------~ operatio~ ~ ' i . 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247. ANCHORAGE AK 99502 4. Location of Well at surface 256' N & 964' E of SW Corner of Sec 6, T4N RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) PAD 66' MSL 6. Lease Designation and Serial No. A-028142 For the Month of 3une ,19__ 7. Permit No. 8. APl ~8?lr~_i008~_Oi 50-- 9. Unit or Lease Name KENAI UNIT 10. Well No. ~./.._ KU I 14-6 '7-- 5-0 11. Field and Pool Kenai Gas Field 84 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations e 20:00-Hrs, 6/20/84 Killed Well Fished and Pulled Tubing Top o¢ Long and Short String Fish ~ 4382' on 6/30/84 ETD 5291' 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE .1 6. DST data, perforating data, shows of H2S, miscellaneous data History: Orig TD 15,047'; 4577' PBTD (10/59) CO to 4710' KOP, sidetracked to 5345' 5" liner to 5337', ETD 5291' (10/74) RECEIVED AUG 0 1 1984 r....!~s,:a Oil & Gas Cons. Commission I I 17. I h ere(y cttify that the foregoN is~l~nd correct to the best of my knowledge. ,~horage ; DISTRICT DRLG SUPT 7/24/84 , SIGNE_L~'! ~'.~,'_~'~,'~' - . · %------...----?-~,~,~._ DATE NOT/~port on this form is required for each calendar month-~-regardless of the status of operations, and must be filed in duplicate with the Alaska Oil ~j/IGas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. For~l 0~,04 Submit in duplicate 9-3;31 1973 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use t.~s form tot DroDosa;S to C~rHI or !O oeeoen or =~ug paCK t~ a o,rterent reservoir. Use Form ~J--331--C tot such oroposals.} · 1. o,I .-~ gas ~ ,,veil ~ welt~ other 2. NAME OF OPERATOR UNTON OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR PO BOX 62A7 ANCHORAGE AK 99502 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.'l AT SURFACE: 256'N & 96fl'E of SW cornez',~ AT TOP PROD. INTERVAL: AT TOTAL DEPTH: 16. CHECK APPROPRIATE =OX TO INDICATE NATURE OF NOTICE. REPORT. OR OTHER DATA REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST ;"CATER SHUT-OFF ._~ , , FRACTURE T'R EAT L__ L_J --""I SHOOT OR ,-'.ClDIZE . : ~_~F-~ REPAIR WELL ~ 71 PULL OR ALTER CASING ~ MULTIPLE COMPLETE ,~ .. ,,~ CHANGE ZO,*,~ ES .~ ~ ABA N DON = , .~ [] (other) 5. LEASE A-028142 6. IF INDIAN, ALLOTTEE CR TR!BE NAME 7. UNIT AGREEMENT r~AME KgNA;[ UNIT 8. FARM OR LEASE NAME 9. WELL ;','0. 10. FIELD OR V'/ILDCAT NAME KENAI GAS FIELD 11~ SEC.." R., M., OR BLK. AND SURVEY OR AREA eSec. 6; T4N: R11W, SM. 12. COUNTY OR PARISHi 23. STATE KE~AI ' AK 14.. APl NO. 50- l_~-I nnn9-o]., 15. ELEVATIONS (SHOW DF, KDB, AND ',VD) P~_d 66' (NOT[; Reoort results of mult~ole comotet)on or :one change on Form 9-3303 17. DESCRIBE PROPOSED CR COMPLETED OPERATIONS (Clearmv state all pertinent details, and give pertinent Dates, il'l¢iUd;~_~ estimated date of star~m~f any proDoseO work. If well is direct~onatly drilled, ~;ive subsurface Iorat~ons aha measurea and true vertical deptlss for all markers and zones pertinent to th~s work.)~ (See Attached) RECEIVED DEP~, MiNEILALS MANAGER ONSHORE FIELD OPERATIONS J U L 1 9 ]983 k~NERAL~ MA&GEMENT SERVICE 411 W. 4TH AVE., SUITE 2A ANCHORAGE, ALASKA Subsu~tetv Valve: Ma~nu. and Type ret @ - 18. l~ereo.y/certdy tha/t~er,,~o~g ~S true and correct _~~'~/~~..~ . DIST DRLG SUPT 7/18/8~ SIGN~ ~~z ' TL ' ' CONDITIONS OF App~A[. IF ANY. - / - ~ ¢ Ft. 'See lnstruCtmonl on Reveese KU #14-6 Sundry i~otice July 18, 1783 17. PROCEDURE: 1. Move rig over KU #14-6 and rig uo. 2. Kill well, install 8PV's, remove ~uai tree, install and test BOPE. 3. Pull and lay down dual 2 3/8" x 2 7/8" completion assembly. 4. Clean out to 5288' ETD. 5. Squeeze Beluga perfs for abandonment thru retainer at ~4750'. 6. Isolate "C" zone perfs with briOge plug at +~300' and perforate and test "B" zone sands individually as follows: B-5 +4160' to +4200' 8 HPF B-4 +4000' to +4065' 8 HPF 8-3 +3905' to +3965' 8 HPF 7. Reperforate C-1 and C-2 sands as follows with casing guns: C-1 +4455' to +4590' 4 HPF C-2 +4615' to +4650' 4 HPF 8. Set and test 7" production packer at +4400'. 9. Run dual 2 3/8" x 2 7/8" completion assemgly. 10. Install 8PV's, remove 8OPE, install and test tree. 11. Place well on production. STAT[. OF AND GAS CONSERVAIION COM~H'IE · · GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi-POINT T~,ST Test Initial r-1 Annual O' Special Field [ Reservoir Kenai Gas Field Pool 6.0 Test Date 8-04-75 Operator J Lease J V.'eil Xo. Union Oil Company of California A-028142 , KU 14-6S E of SW Corner, rounty t Locati,,n 255.67' N & 964.22' I C°mpleLt°n D':' I T°tal Depth I T/PaY trr''!'~ :rto . iC.:er:,: Kenai Sec. 6, T4N, Rl lW 10-23-74 5288 170' 4455'-4630' T~G. CSG. Itmpe a r~ ~ 102. r ~F 5 18 5337' 2 7/8 6.50 2 7/8 2.441 44081 ,~.,..~,~ ,,,,,. ,,, ,.,,o ,,, ,,,,.,~.,,,: . Pipeline Connection [ Type Taps Nikiski I Flange .~Iultiple Completion (Dual or Triple) i Type production from each zone Dual J Gas _ OBSERVED D.&TA Flow Da~a Time of Flow Hours (Prover) (Line) Size (Choke) (Orifice) Size Press. psig 3.826 Diff. h Tubing i Casing [ FlowinK Press. Press. Tern p, pslg psig 'F 1426 ! 44° 4. 2. 500 2. 500 2.5oo 2.500 3.826 3.826 2.25 4.00 6.76 6.06 FLOW CALCULATIONS 3.826 1407 1395 ! i 44o 1378 J ~ 43° 1385 ] .... ! 43° , , , · ,LO , ~ Coeffi- cient (24 Hr.) ]. i,.34-,147 , , ~. ! 34.147 ~; ! 34. 147 4. : :J 34,.., 147 . 56.564 75. 100 97.040 i. 92.10~ Pressure psis 1422 1410 1393 14OO Flow Temp. Factor F t i.o157 !.o157 1.O168 1.0168 Gravity ~J Compress. Factor j Factor ' Rate of Flow g pv 1.~42] I 1.1372.., ! .. 2994 1 3423 ~ 1 1362 I 3~72 1.3423 J 1. 1360 ! 5138 1. 3423 J 1. 1149 .. I 4872 PRESSURE CALCULATIONi w Ca I. , w ~p (psla) P'~.t F~Q (F c Q): (Pc Q): X 1-e's paw P~o -- P:W ' P w J P t[ c ,. I .......... t ,, i i , ,, Aba-lute Potential 26,000 MCF.'D .6008 CERTIFICATE: X. the undersigned, state that I am the ,engineer of the Union 0il Company (company), and that I am authorLZed by said company to make this report; and that this report was pre- pared under my supervisWn and direct/on and that the fact~ stated tkel'ein are true, correct and complete to the best o! my knowledge. . · . Carls. GA.c 'ELL OPEN FLOW POTENTIAL TEST R ]RT PRESSURE CALCULATIONS (Supplement to Alaska'O & GCC Form No. G-I) - Field Reservol. r Tesl Date Kenai. Gas Field Pool 6.0 8-04-75 _ - Operator Lease ;'~ell Union Oil ComDanv of California A-O28142 KU I~T6S _ -- , , (I) (2) (3) (4) Test Ps pf (ps2_ pt2) 0 No. nsia ._~$ie X 104 ~.~CF/D , 1 , 1441 1422 ~.~8 2~4 , 2 1441 . 1410 8.84 3972 3 1442 1393 13.89 5138 4 1441 1400 11.65 4872 · · Sub-Surface Test Data Subsurface pressudes measured. ,~ o Subsurface pressures computed' Cullender-Smith ~..lethod of ~C '' (i) (2) (3) (4) Test Pws 0 · (Pws2_pw~ 2 ) Q No. ps i a ps i a X 10- z~ ,.,u' '~'F/,'3~. ...... .... , , , : . . , ,., ,,. , ,. , ,, Nomenc Ia ture: Ps : Static surface pressure '~f___: Flowing surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day at 60~F and 14.65 psia 1-70 . 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[ '.~',,~. ;i~;~, . -: ,' :~ .I:':~ ;'~:':~.~t :ri':.;i::~F_~::::'~::.dSl:!~'~:';:,~.::t~:'. ~-~:F~ ~;'"~'[:~-~ ~:::':/:: .? ~::[::::: ::::::::::::::::::::::::::::: ':~'~:~ ":,' .:i":' ':u:.;:: .':~: "Z ~_.t:'.2:.l~-';.'::~:-.,-i,2:,-;i:_;:::i:;::r:;,;~:;'.: :L':. ;L'. /::::~;:;' ;;:. ::.:: ;::_: ;~:.: :~z;i:.;.;;~ ;L:;~;;;:: ~;;!_;:_.i; '::;,;;:;'~:t;;:71:: '. 7'; :'I;; :.;:; ;:;. !.;:; ::: ;;7; ...': :::7; ::.; :~:!~',-2-~i:i;~ I:,:11..;-i; ::':':,: .1 ':~.:'I, ~; : /~ ':::tl i: ~:~;t.; :i ;-~ ;_i'~:'il; ::':i ]iH ~;.':~':xt:.::~:L:':.. :': :'~'.i'; ;':::! ,:.' ~;~.:::: ~:-: ~:~ :;.::t~:~ :~ .':: :;" ::.;~ ~' ;: ; :' ;.t~4.1 !-!l~1 .It.t.tLi.,,l...~:i, I.;i.;; ~iI., , ~il ;- 1:,~ --1---,:,, LI.~ ..il ~,.~ ~--;-i .......... ;-, ,.[.', J.,'. .:..,, I~, ..... ~ ;.;4 .... ;,,.I ..... t ............... ~ ....... ~-+-t-l-~.~ Il-.. i~.t-.~.~;t:i ..... ;~, t.~;::,.,~.!;.. ~ ',,,i-;-.~,;:: -.- ~.-,-~ '--~; iii.; ..;, ~.. ~-i ....... ; ....... ;; ........ [.:t,.i.,:.i, i .......... 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'1;~"-'*'~' ,e',':: ....... ~ ...... :'1,~::.'~' ,' ...... I .... [' '~ ~:'; ';"~'~: ~ :: ............ ~ ....... :"':'~' '~ '~ ' '".'~ ' ' ..... .............. ~ ......... : . . ~ ...... 1~,~ ..... .,~ ,- * .. , - . , .................... ~ ................ ........... , ...... ;;. - ,..,..; ..... ; ........ [ ...... ; ........ ' ...... * .... .............. ~ ............. ' ........................ I ........... . . _~., ..... ,,~.~ ..... ,] ....... , ..... ~ .... ~ ,;: ......... ;. ;[.~ .'.; ;.~ ........... : , ..... ; ..... ,, .... I: ...... , ~.. ., .... I ..... t ........... ............ t ........................ ........................... t ............................................ I ..., ......... _ '~'!t .... ~' 't ..... ' ': .... ~,:' ~::~ '' : ":":l ...... ~-:1::"~1" ' : .... ; ..... : ~'~t t::: :"~' ':: ..... :' ~''~ ''t !.'::: '", ':'l~::' :: t;:t: "' --~:- - ;~;-. _, ;~;.;:: ~ .;; i.;X ;~'i; i .;N..~:[.~; ~,;. L~:.; ;..; ~;';; : -:-;:.:i.; ;2;,;;;;;: .... ;~;, ,.;-:;;, ;;; ;;;; i;,, ;...,; ... :;.;; .... .... tz_~ ........ 4 ................... ~ ............................... ]-*; ........... ; .... ; ..... ~,.~, .............. ,...~ .... :~ ; .............................. -- , -*-~--;4--I [ ~.;;,;~.~ : .... ~..,; ,; t.;~ ;;.~ '-~;' t-""..' ;;" ~ .... 1,I . ,, ;.-.~ .... l... ,., .... ~;t~iilt ..,~.,,; ~;,,, .. , .,, ~; .... i .................... · .... - ~, - -~- i- ,. ; .... ., ..... ;..., i : , ~ ,~ ~ I. ,,,,i. ,.,, ...... ~ , ....... ;i ............... ,;.. ,;,- .,~ ..... -?l-i"-lt ~; ~t ,~;: '';";-: '~ .... ;'! ;~ ..... ~ ~ ..... :.. ~,.: ., ~ .,. I~,. .... ~.,~;; '~;;i~;:," ,: ...... ~ ........ t' t't~ ..... '"1 ............ ;'; ''';'-'~ -~--- ~ .... :11 I,., ~ ..... ~., ................ : ......... ~+,-J H., ..... .:---, ........ '.. ~,-.',, t ,.,,~,., ......... , ~., : ......................... ,. ,, .I .......... , ........ . ......... ...... ,- -, .... I. , .......... ................... 4 ...... .i .................... , ................ , .... ~ ' '~ , I ' ' it '~'' I ~ .... ' ' . '. ' , ' ~ ,' '. , . - ~ ......... ; .......... , . ' . t 'i' ~ ........ ; . .' ......... [ ,~ .... l ..... .~ .... /~*~ ~ ' "/ ' -' ' ~'~'~*** ' '* ' '~ ...... ' ..... -* '' .... ~ - ""* *~ ....... ''.~'~ .... t ' "".~' ~' ' ......... . ......... '" '. 02 1..o 2 ~ ].o 2o ~o GAS FLOW RATE MMCF/D STATE OF ALASKA (See other tn- st ructions on reverse side,~ OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: Oil, WELLL__] WELL DRY Other b. TYPE OF COMPLETION: xEw [] woni ~, DE~P- [] PL~ [~ ,Irt. ~--] R edrill WELL OVER EN BACK RESVR. Other 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3, ADDRESS OF OPERATOR _ 909 West 9th Avenue, Anchorage, Alaska 9950] 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* · t,~a~ 255.67'N & 964.22'E of theSW corner. Section 6: T4N, RllW, S. M. At top prod. interval reported below At tota~ dep~ Same as above-nearly vertical well. 5. APX NUMERICAL 50-133-10089-~ 6. LEASE DESIGNATION A.ND SERIAL NO. A~028142 ~. IF INDIA.N, A.I-,LOTTEk OR TRIBE NA.M.E 8. UNIT,FAIllVI OR LEASE NAME Kenai Unit g. WELL NO. KU 14-6 Redrill 10. FI. ELD A.ND POOL, OR WILDC~KT Kenai Gas Field-Beluga 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) Section 6: T4N, RllW, S.M. 12. PERMIT 1~O. 74-50 ELEVATIONS (DF, RKB, RT, GR, ~lq~:)"]17. EL,EV. CASINGHEAD 90 'RT~ 79.3' I-{OW1VIANY* ROTARY TOOLS CABLE TOOLS 5345'TMD 529 i'TMD Dually X 22. PRODUCING !NT~ERVAL(S>, OF TI-lIS COMPLETION--TOP, BOTTOM, NAME (1VI~ AND D)' 23. WAS DIRE~ONg SURVEY MADE C-1 4455~-4590~, (Previously producing in KU 14-6-Redesignated as KU 14-6 R ~ No. 3 1/2° C-2 4630~-4650~'~ 5083~-5103~' 5175~-5195~' 5139~-5149~' 4960~-4970~' I TD ~ 5345 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN FDC, CNL, GR (5404'-4200') -- ~5. - ' CASING I~EC'.ORD (Report all strings set in well) CASLNG SIZE ,,, 20" 13 3/8". 7" 26. 54.5~ & 61#l J-SS ] [ 26# & 29# ! N-80l LINE~ F, EC O~D DEPTH SET (MD) 60' 3078' 4618' 5345' "' ~ '~ ' ' size and number) PE~OE. ATIO~'~ 5P~ T6 PRObU~ON (interval, Beluga 5083'-5103', 5175'-5195', 5139'-5149', 4960~-4970', 4856',48~8', 4788'-4808'. C-2 4630'-4650'. ~C-1 4455'-4590' (PreViOusly producing in KU 14-,~-~da~igna~ad a~ KIT 14-6 Rod~ill% . ~oouc~o~ [ 6 1,/8" $CF~EEN (BID) SIZE DEPTH SET (IV.D) ~ PA. CI~EI'{ SET (~D) 2 7/8" .... l 4407' 4390' 2 3/8" ~ 473~' 472]' DATE FIRST PI%ODUCTION 10/24/74 DATZ OF TEST. [HOURS TESTED "[CIiOI<.E SIZE [PP. OD'N FOR I i I ITEST PEI~L! O D 10/25/74 [ 24 ] 2 3/8" ] ~' FnOW, ~mNG }ca~a ~ESSURE iC*L~T~ %~S~L. I 1 1125 0 0 ~. ~m~osmor or ~as (~o[~, used ;or ~uei, vented, ~'.) Vented - Beluga ZOne Test. PI%ODUCT1ON ME'iHO'D (Fiowii~g, gas lifi, p~trnping--size and type of pump) Fl°wing [ V/ELL STATUS (Producing or ~nut-ln) ~roducina oIL,--BDL. G,a~S~-~CF. WA'I'EI-~--BBL, GAS-OIL I o I7.800] 18 £ GAS~MCF. WATER--BBL. ~ OIL GRAVITY-APl (CO1q~.) 7,800 I 18 TEST ~VITNES~ED BY ] Don Wester 32. LIST OF ATTACHMENTS Summary of~WO & Redrill operations. Completion sketch. 33.'I hereby certify] that the foreg~ing~,nd attached information is complete and correct as d~ter'~nined from all-available records SIGNED ~ ~~-~LE Dist. Drilling SuPt. 1/21/75 [ Jim R. G, allender '~,,' ' DATE *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,.,,,,ell completion report end log on alt types of lancJs and leases in Alaska. '-~.:~i :~:" Item: 16: Indicate which elevation is used as reference ;(where not otherwise shown) for depth measure- ments given in c, lEer spaces on this form and in any a~tachments. Item~ :20, ~,d :2'~:: If this well is completed for separatc preduction from more th~n o:~?:interval zone (multiple completion:), so state in item 20, and in item 22 show the prcJuci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each addilional interval to be seperately produced, show- ing the ackJitional data pertinent to such interval. Item:26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item '/8: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above) 34. sUMMAI{Y OF' I,~ORMATiON TF_,S'I'S IN(TL,UDIN(; INTEI~.VAI., TF`~'$TED, r~HES. SIJRE DATA ~ '~COVERIF_.S OF OIL, GAS. ,~ 35. G I~OL~)G I C M A R Kl~a~ WATE~II AND MUD NAME afl. COH.E DATA. Aq'I'ACII I]RIEF D~CRI:PI~ONS OF LITIIOLOGY. POROSITY, FRACWR~. App~ DIPS' AND DE'PEC~EI} SHOWS OF OIL. G~S OR WA~I. SUBMIT IN Df. .CATE* STATE OF ALASKA (See other tn- st ructions on reverse side; OIL AND GAS CONSERVATION COMMITTEE ii i i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* .... ,,i, .... 7q .... la. TYPE OF WELL: ' t;AS ' · · WELL I__.J WELL DRY Other b. TYPE OF COMPLETION: NEW ~ WORK ~1 DEEP-[] PLUG [--~ DIFF.[] V,' lq L I, OVER EN BACK EESV R. Other __ 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3. ADDRESS oF OPERATOR 909 West 9th Avenue~ Anchorage~ Alaska 99501 4. LOC^r~ON OF WrLL (Report location clearly and in accordance with any State requirements)* At su~ace 255.67'N & 964.22'E of the SW corner. At top prod. interval reported below Section 6: T4N, RllW, S. M. At total depth 5. API NU1VLFA~CAL CODE 50-133-10089-01 ~. L~S~. D~SI~NX~O~' ~ND S~.R:A~ ~O. A-028142 7.IF INDiA. N, A.LJ.,OTTEE OR TRIBE NA_M.E 8.UNIT,FAR1VI OR L~_,ASE NAME Kenai Unit 9. WE~,L NO. KU #14-6 Rd. 10. FIELD A/~D POOL, OR WILDCA. T Kenai Gas Field-Beluga. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 6: T4N, RllW, SM 12. PgRNIIT NO, Same as above-nearly vertical well. ~1 ~/z/-- ~'O 13. DA. TE SPUDDED '114. DATE T.D. I~E~CHED 115. 1>ATE CO~iViP SUSP O~ ABAND. 116. E~EVATIONS (DF, RKB, 17. ~V. CASINGHEAD 9/22/74 I 10/9/74 ! lO/24/74 ! RT 90' . 79.3 18. TOTAL DE.H, N~ & TVD~9. PLUG, BACK MD & ~D~. ~'~LT~ CO~L., [ 21, riNTERVALS 'DR[bLED BY ~ [ ~OW~Y* J ROTARY TOOLS '~ CABI,E TOOLS 5345~TMD J 5291~TMD j Dually I X ~.gQ~I~.~.<~:~::~S), OF ~IS CO~:TION--TOP, BOSOM, NA~E (~ AND ~)* 23. WAS DI~E~ONAL c~.Czl_~4~¢[~,.~s~..59~01j C-2 46151-4650~, Beluga 5083~-5103~, 5175~-5195~, : su~w~ 5139'-5149' 4960'-4970' 4850'-4868' 4788'-4808' [NO.T~ ~;, O 24. TYPE EI-A::CT~IC AND OTHEt~ LoGS RUN FDC, CNL, GR (5404'-4200') _ ~. '"' ' CASING ~ECORD (R;port all strings set in well) c~s~c; size wEmav, DZmm SET (m)) aOL~ SZZE 20" 13 3/8" & 61# 307 7" 26. LINER RECO~ SlZl~ TOP (~[D) EOTTONI (MD) 5I! CEh~[LNTING RECOR~ 5345' )0 sx. cmt. 27. SACKS CEME?~T* SCF~EEN (MD) SIZE I Ak~IOUNT PULLED 28. PERFORATIONS OPF-/N TO (interval, size and number) Beluga 5083'-5103', 5175'-5195', 5139'- 4656'-4658' 5149', 4960'-4970', 4856'-4868', 4788'- 4808'. C-2 4630'-4650'. 30. PRODUCTION DATE FIRST PIZODUCTION [: I:rI~ODUCTION MEI'I{OD (Flowii~g, gas lif~, pumping--size and type of pump) 10/24/74~ Flowing OIL-~BEL. G.~S--IV~CF. ACID, SHOT, FZiACTURE, CEZ, IENT SQUEEZE, ETC. 1NTE~VAL (MD) AMOUN£ £~ND k:!ND OF MA. TE?,'AL USED · 95 sx. Cla~qs "G" cmt ..... [WELL STATUS (Producing or ~,~t-~m Producing wArfER~-BBL. ] GAS-OIL 1 18 DATE OF TEST, ii. OURS TESTED ICHOI{E SIZE [PROD'IT FO,Il [ i 2-3/8,, JTES'I ~EraOD 10/25/74 24 . ~' FLOW', TUBING ICA:I. NG PRESSLrRB/CALCUZ~TIKD oIL--BBL. I~I~ESS ' 1 : [24-HOUR RAT~ 112.5 ! 0 , I ~ o 31.. DISPOSmqON Or ~aS (Sold, used Ior ~uel, vented, etc.) 7,800 Vented GAS--N~CI~. _ [ 7.800 32. LIST OF ATTACHMENTS 1 WATER--BBL, ! OIL GRAVITY-AP1 (COI:I~,) ITEST WITNESSED BY Don Wester Summary of WO ~ Redrl~. ooerations. 33. I hereb~ ee,~,H~ that the foregojn~g2d a~ttaehed information is complete and correct as determined from all-available records '~~~~/~. ~.~ Disl Drlg Supt. ~i~~74 S IG NE D~/~/~ ~~TITLE ' . ' - ..... .,, //-,B~ R/Ca,llender- -- ~ ~ ~ ~ ~ : *(SeelnstructionsondSpacesiorAdditiona' Dotoo. R~se~d~ ~' ~ I~J TUBING RECOl>d) DEPTH SET (MD) ~ PACKER SET (MD) , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lanJs and leases ir', Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than., one nterval zone (multiple completion), so state in item 20, and in item 22 show the p,c. Juci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in it,em 30. Sulbmit a separate report (page) on this form, adequately identified, for each additional inte, val to be seperatety produceJ, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the dsi. ails of any mul- tiple stage cementing anti the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above) ' '34. SUMMAI~Y OF I~ORMATION TF,~'I'S INCLUDIN(; INTERVkL TESTED, PH~SSURE DATA ANT).RECOV'E-q:~IES OF OIL'. GAS.' 35. GD~GIC MARK~ WAT~ AND MUD NA~ MEAS. ., . · 38. COH. E, DATA. Aq'I'ACll~ ORIEl' D~.~I~I~ 0~., L.ITIIOLOGY; PO~O~TY, AND, l)~i~g~El), SIIOWS O~ OIL. G~' OR. " , DST #1 B-4 Sand Ran Schlumberger 4" shaped charge gun, shot 4 holes (E-log 4050'-4052') (csg. 4042'-4044'). Ran Howco tester and set pkr. @ 4006' w/ tail to 4021'. No cushion. Test #1: 20 mins. ISl. Opened tool on 1/4" bean, gas to surface 2 mins. Gas broke thru in annulus, pulled tool loose, started Pooh. Found hole in DP, 5 singles from top. Replaced & ran back in. Reset pkr. @ 4006'. No cushion. Tester opened on 1/4" bean @ 6:15 pm. Gas to sUrface in 2 rains. Blew gas & mud to sump for 1 hr &'27 rains. During blow, surface bean was 1/2" & bottom hole choke was 1/4". Surface press. 650#. Blow estimated 4,000 MCF. Turned to scrubber. Needle valve for Shaffer bean broke, repaired same & turned to scrubber with 2" orifice plate. SI to put in 3/4" orifice plate. Maximum SI press. 1850#. Resumed flaring w/ orifice plate', flow press. 650#. SI well to drill hole in orifice flange. Resumed flaring. Changed to 3/8" bean on bottom. Surface bean remained 1/2", orifice 3/4". Estimated rate 4100 MCF, 650#, 6600 MCF-1050#. SI well for 20 mins FSI. Pulled tester & Howco equipment. IH ISI IF FF FSI Top Chart 3999 ~570 2295 1750 (1/4) 1710 (3/4) 1865 (Inside) Howco corrected 2592 2296 1664 (?) 1709 1857 Bottom Chart 4020 (Outside) Howco corrected 2635 2330 1775 (1/4) 1775 (3/8) 1800 2623 2309 1783 1754 1866 DST #2 C-1 Sand Schlumberger 4" shaped charged gun, shot 4 jet holes (Gamma Log, csg. 4580'- 4582'). Ran 7" Howco tester, set pkr. @ 4552' w/ tool @ 4567'. Test #2 @ 4588'-4590': ISI 25 mins, gas to surface in 2 rains. Flowed through 1/4" bottom bean for 2 hrs. & 35 mins w/ 1/2" Shaffer bean @ wellhead. Press. @ wellhead 300#. Flowed estimated 1900 MCF rate. Flowed through 3/8" bean for 1 hr. & 56 mins. Wellhead press, on 1/2" Shaffer bean varied between 935# & 950#. Estimated rate of 6000 MCF. FSI 22 mins. Howco equipment. Top Chart 4545 3030 2425 2035 (1/4) 1880 (3/8) 2115 (Inside) Howco corrected 3005 2393 1990 1700 2104 Bottom Chart Failed Howco corrected Mud gas cut to 83#,:s~ung in 95# mud from surface, circ. & cond. mud. Furm P- 7 ' I _~. SUBMIT IN ~, ,CATE* STATE OF ALASKA :See other structions on OIL AND GAS CONSERVATION COMMITTEE r~,,~,'~e Mde; j 5' AP1 N:C~ CODS 50-133-10089-01 WELL cOMPLETION~ECOMPLETION REPORT AND LOG* "' WELL OVER EX BACK RESVR. Other ~ ~ ~ ~m. 2. NaME Or orgRSTOg UNION OIL COMPANY OF CALIF. 3. ADDRESS OF OPERATOR 909 West 9th Avenue A. nchorage, Alaska 99501 4. LOC^TION OF WELL (Report location c~early and in accordance with any. State requirements)* ~tsu~ace255.67'N & 964.22'E of SW corner. Section 6: T4N, R11% S. M. At top prod. interval reported below Same as above At total depth Same as above · Not directionallv drilled. i~A'rg CO,lViP-$USP. O1{ ABAND. ~3. DATESPUDD~ Jt4:DAT'ET.D.R~OHED[1~.5/28/59 [ 9/25/59 J ~~ - ~OW ~Y* ROTARY TOOL8 j5,047' J 4606' . si~le PRODUCING !N~VAL(S), O.F ~IS COMP~TIO~--TOP, BOSOM, NAME (~ AND ~)* 6.LEASE DESIGNATION /kND SERIAL NO. _ A-029142 IF INDiA. N, ALLOTTEE OR TRIBE NA~ 8. UNIT,FA-RNI OR LEASE NAME Kenai Unit 9. WELL NO. KU #14-6 10. FIEL~ AND POOL, OR WIL~DCAT Kenai Gas Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6: T4N, RllW, S. 96'RT . ~ 79.3' 23.WAS DIRECTIONAL ~ SURVEY MADE ,1 No 24. TYPE ELECTRIC AND OTH~I:{ LOGS RUN Sonic, ML, Gam, ma-_R,ay Nuetron Lo~. 25. CASING RECORD (Report all strings set in w~l'l) ' ' ' 20" ' "0:0' 26" Hn'r~ ,".~* uJ/ CaC, 12 7"' I ~.~ -~ "i ~-anl 46:6' l:: :'/a,, 1.775 sx. Per manent-c~ns-~--~ction cmt,' ........ I , " I ! I [ - -' ".1 ' Nor,--_ tslz~:e ~ TOP (MD).,, : "" '[ Otq'BOTTONJ[' (interval,(MD) [ SACKS CEMENT* 28. PERF6RAT[ONS OPF_kNI TO PRODU size and number) " IllI I I I I I I 30. PRODUCTION SIZE /t441' J -- I i i ii i 29, ACID, Si:OT, F.~.ACTURE, C~-'~IENT SQUT'XZ~, ETC. . D"""""""""""""""""""~/"Ii 1NTERVAL (MD) / AMOUN.P id,ID I':'IND OF MA'I~?.TAL USED 4050 'MD 150 sx. Permanent Cons~:. crrlt, DAT'E FIRST Pi~ODUCTION [ PI~ODUCT1ON ME'iI{O,D (Flowi:~g, gas lifL, pumping--size and type of pump) IViELL STATUS (Producing or 10111/59 I Fl°Wing __.:~/:l/sgj :z h~l34/36 FLOW,t~SS.~BING IJCAS~G PR~SURE I24-HOURJdAL~T~RA~ IOI~BBL' GA~Z~CF. WA~BBL. IOIL GRAVITY-~I (CO~.) ~s~ I , ~00 I ~ [ I ~/A I 1 SI. v~seosmuo~ o~ ~s (~o~d, use~ ~or yue~, ve~ted, etc.) ......... ~ ..... DST ~1 & DST ~2. 33. I hereby ce~ that ~he f~regoi~ and attached information is complete and correct as determined fro~ al~avatlable record~ "~ t ~ tgX[ *(See Instructio,s and Spaces for Additional Data o. Reverse Side) ~9~iCN ~ oil a~ INSTRUCTIONS General: This form is designed for submitting a complete and correct ,.,,,ell completion report end log on all types of lands and leases in Alaska. Item: 16,: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items :20, and :22:: If this well is completed for separatc, prcduction from more .than one interval.zone (multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce.J, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. ,~ Item 28: Submit a separate completion report on this form for each interval to be separately produced · -' .- . .... .... 4f, .. (See instruction for items 20 and 22 abOve). '" 34. SUMM'~,t~'Y (DP PO~MATIO'N TESTS INCLUDIN(; INTERVAl- TF,,STED. PI~ESSURE DATA A.I~'~OVIERIES OF' OlI','i OAS.- ~;:;? 35. G I9OI~OG IC M AR KIEP~ WATER AND MUD ......... ,, NAMlg MEAs. __ · 38. CORE DATA, A~'I'ACIi BRIEF DESCRIPIT1ON$ OF LIT[IOLOG¥. POROSITY. FRACTURES. API~A~RIgNT DIP~ AND DETEC~I'EI) $}[OWS OF OI1~. G~S OR lVATE}I. .. UNF'"~ED STATES DFPARYMEN ~' OF THE iNTERIOR , reverse side) GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R355.5. LEASE DESIGNATION AND ~ERIAL NO. A-028142 6. IF INDIAN, ALLOTTEE OR TRIBE NAME WELl.. COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF W~;LL:_ au, ~ c.~s -.l-~r ........... ...... WELL--[~'-- W};LL ~ DRY b. TYPE OF COMPLE~ON: NEW ~ WORK 2. NA~E oF OPERATOa ~! UNION OIL COMPANY OF CALIFORNIA - a. A~mI~.SS oF m'ERA~9~ ....................................................................................... 909 West 9th Avenue, Anchorage, Alaska 99501 4, I~)CATION OF WELL (Report location ciearlll and in accordance with anlt ~tc~te requirements)~ . .~ At:surface 255.67'N & 964.22'E of the SE corner. : ' ' ~ Section 7: T4N, RllW, At:top prod. interval reported below At ltotal depth Same as above-nearly vertical well. ] ~4. P~m~.T68_5~O. DATE ISSUED 7. UNIT AGREEMENT NAME Kenai Unit 8. FAR.',t OR LEASz NAMI~ _. ._ ~). WELL NO. KU #14-6 Rd. 10. FIELD AN.D POOL, OR WILDCAT Kenai Gas Field 11. SEC.. T.. R., M.. OR BLOCK AND SURVEY OR AREA . . .. Section 6: T4N, RllW, SM 12.COUNTY OR [13,STATE PARISH ]. Kenai Penn. Alaska 9/22/74 10/9/74 10/24/74 RT 90' 19. ELEV. CASINGHEAD 20. TOTAL DEPIlg, .%eD & T~D 21. PLU~, BACK T.D., MD & TVD 22. IF MULTIPLE COMPL., [[[ 23. INTERVALS , HOW MANY* f ~ DRILLED BY [ 5345'TMD 4710'TMD Dually , > X 24. PRODUCING INTERVAl. iS). OF THIS COMPLETION---TOP, BOTTOM, NAME (MD AND TVD)* _.'. .~ CT~ 4455'-4590~MD, C-2 4615~-4650~, Beluga 5083~-5103~,-~175~-5195~, .:. . 5)39~-q149~ 49~-4~70~, 4850~-~868~,4788~-4808~ .... 20. T~'PE ELECTRIC AND OTHEK LOG8 RUN -' } : .... , r · ~NL ~ GR (5404'-4200') ROTARY TOOLS CABLE TOOI,S WA8 DIRECTIONAL SURVEY MADE Yes 27. WAS WELL CORED '- No .-.,, 20" t 60' ' 13 3/8" ,54.5 & 61# j 3018~ 7"~ ~ 26 & 29~ ~ 4618' I I 5345' 29. ' LINER RECORD I~IZE 5 l! · TOP 459.3' , BOTTOM (MD) [ SACKS CEMENT' 5291' 90 sx. , 31. PERFORATION RECORD (fnterval, aizq and number) Beluga-5083'-5103', 5175'-5195", 51'39'- 5149' 4960'-4970' 4856'-4858' ..4788~4808 , , C-2 - 4630'-4650'. ~-~;' I Previously set (80 sx cm~.)-- ' .1171/2" ' ' I ' ' (I 7 ~ 0 S X 11'3/4,, I - . . (775 sx cml.) 6 1/8" ,~x ~mt[ ' 30. TUBING RECORD 2 7/8" 4407' 4~90' 2 ]/8" 4716' 4721' ACID. SHOT, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH 'INTERVAL (MD) -4656'-4658' 95 sx-.Class "G" cmt. 33.* PRODUCTION ,t.~'~ .. DAT~ rXRST PaODUCTION [ PRODUCTION METHOD (Flowing, gas lilt, pulmping SiZe and tYpe,of pump) ] WELL STATUS (Producin~ or 10/24/74......... [ '-FloWin~f ................................................. ; - i I '~"'"'") Pr0dt_~p~ 10125/7~ I 2~ 2 3/8" ~ 0 ~ 7,800 18 __1225__ ~_ . ~ 0 7.800 I 18 .......... 34. vxs~osrrlO.,,' or aAS (Sold, ~sed for.fuel, vented, etc.) Vented I T EST WITNESSED BY I' Don Wester LIST OF ATTACHMENT~q . ---i e¥'~'~y~a[~¥~e~Tg~d,/ ~ ZJ .. ~ttac~e~'~m~ls~. complete and correc, an determined from all available re~ords sm~z,~~'~' ~~~ Dist Drlg. Supt. ' ' 11/10/74 *(See Instructions and Spaces lot Additional Data on Revere Side) "~ .. FLUID SAMPLE" DATA '~n_l'Z_-//I 599140 ~mpler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C~s ' of Job HOOK WALL District ANCHORAGE cc. Water Tester MR. BOATI~N Witne~ MR. WESTER :cc. Mud .. Drilling Tot. Liquidcc. ControctorKENAI DRILLING COMPANY DR S 'Gravity * Ap! @ °F. E Q U I P M E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested .Be1 uga RESISTIVITY CHLORIDE Elevation 78' GL Ft. · CONTENT. . Net Productive Interval 4788'-4970' Perf. Ft. Recovery Water ' @ °F. ~~ppm Ail Depths Measured FromKelly Bushing 92'. Recovery Mud ~ @ _ °F. ~ppm Total Depth 50] 5' RBP _ . .Ft. Recovery Mud Filtrate __ @ °F. ppm Main Hole/Casing Size 7"-5" .Mud Pit Sample @ °F. ppm Drill Collar Length - I.D. Mud Pit Sample Filtrate @ ,., °F. ppm Drill Pipe Length 896'-4116' ..... ~.D. 2.151"-2'764" PackerDepth(s) 4720 ' Ft. Mud Weight ,, vis , cp Dept. h Tester Valve Z~{~8' Ft. TYPE AMOUNT Depth Back Surface Bottom 'Cushion . 97~# PSI Ra.R FtT ., Pres. Valve Choke 1/2-3/8' Choke 5/8" Recovered Feet of · Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of , Remarks SI[ PRODUCTION TEST DATA SHEET .. ,, ,. , ~='~' C~ugeNo. 611 GougeNo. 3'637 GaugeNo. 3636 TEMPERATURE TIME .... g~,,h: 4703 F.t..D, ept.h:.. 4707 Ft., aec,h: 4732 Ft. 12 "o~ ao~k 48 Hour aock 48 ~our C~k To~ '10-17-~,.~. Est- _ °F. ,.].Blanked Off NO ,,~, , ',,manked Off No Blanked offYes Opened 8'23 P.M. 4741t Opened 10-18-~. Actual.. ~ OF. j Pressures Pressures Pressures .,. Bypass 4' 41 P.M. 'J Field Office Field Office Field Office Reported ~.ompu~ed lnitioll Hydrostatic .__ 2422 2421 2429 2440 2445 ~i"ute' Mi,ute, "~ F~o~, ~nmo~ 369 1028 493 1101 749 ' r~- 1983 _ 999 1028 1009 1028 1029 41 .,40 C~o~ed in I 1888 1 897 1900 1902 1 890 19_07 60 58 ~ ~.itio~ j 1093 1096 1103' 1138 1140 c o Flow - , ~°'c Final · - 1146 1629~ _____]_6_31 1634 1643 704 704' ~ 'Clo~ed in 1900 1902 1890 1.908 593 416 In hal , ?o F~o,~_ .~' CHART--T-~[. EXPIRED .. ~losed in " --Final H~drosfatic ......... - i "2'421 2424 2440" 2438_ ' ..... , .... , , ..... [ .~ Ticket : FLUID SAMPLE DATA Dote 10-17-74 Sa--~pler Pressure P.S.I.G. *at .S~frface i' Kind Halliburton WALL ReCovery: Cu. Ft. C~s ..... of..._.Jgb.. - . HOOK District ANCHORAGE cc. Oil , ,, .,,, .. .. .... :~. ...... cc. Water 'Te~ter MR. BOATMAN Witness MR, WESTER · cc. Mud · " Drilling Tot. Liquid cc. Contractor KENA! DRILLING COHPANY DR S Gravity °AP! ~ 'F. EQUIPMENT & HOLE DATA , · Gas/Oil Ratio · . cu. ft./bbl. Formation Tested · RESISTIVITY CHLORIDE Elevation Ft ' CONTENT Net Productive Interval Ft. · . Recovery Water (~ CF.. ppm All Depths Measured From Recovery Mud @__ °F. ppm Total Depth Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size . Mud Pit Sample @ ~ CF. ppm Drill Collar Length I.D, Mud Pit Sample Filtrate @ °.F. ppm Drill Pipe Length I.D. Packer Depth(s) .Ft. Mud Weight , vis .... cp Depth Teste~..Valve .... Ft. TYPE .... AMOUNT Depth Back. Surface Bottom Cushiom Ft. Pres. Valve Choke Choke Recovered Feet of · Recovered Feet of ..... Recovered Feet of ' ~ Recovered Feet of ;j Recovered Feet of Remarks . . FOURTH Gauge No.597 Gauge No. Gauge No. TEMPERATURE TIME · Depth: 47~6' Ft. Depth: Ft. Depth: Ft. , 12 Hour Clock Hour Clock Hour Clock. Tool A.M. Est. 'F. 'Blanked Off yes Blanked Off Blanked Off Opened P.M. Opened ,6,.M. __Actual CF. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Com~'u~ed -Initial Hydrostatic 2428 2438 Minutes' Minutes ..~o Initial 1045 809 ~'r. Flow. ~-~... Final 1010 1020 Oosed ir, 1895 1898 ~co Initial 1 127 l 131 Sr. Flow., .. Final 1189 ~.~ ..... Closedin CHART TII~iE EXPIRED ~ Flow-. Initial ~.__ Final Close. d in . --F i-'~a I Hydrostatic ' , , IroflM lit'III--PaINTED IN U,I.A. TI'CT PLATA · LITTLIt'I ltttl IONI Casing perfs~ .... Bottom choke Surf· temp 'F Ticket No. ~] 40 Gas gravity ' ,Oil gravity ....... 'GOR , .St>ea. gravity ,, , Chlorides ppm Res, , @ 'F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ....... . . . "PAGE 2 . ~)ate Choke Surface Gas Liquid Time a.m. SiZe Pressure Rate Rate Remarks p.m. psi MCF BPD 1 -45 /2" 670 ' 2_-00, ' 675 .3,510 2:15 ' 675 3,620 , , 2 -25 ~/4" 450 2 '40 ' 425 · 2 '55 " 425 3,930 _ 3 '10 " 425 4,000 3 '25 I/2" 575 3:40 " 710 , 3: 55 " 700 4 :lO ~' 710 3,750 4:25 " 710 ..i 3,800 I 4: 40 " 7.10 3,800 .... 4:55 ' 710 3,800 5-16 ' 710 3,850 5: 25 3/8" 990 , 5 · 40 " 1050 5 -55 " 1050 6' 10 " 1050 3'140 6: 25 I,, 1050 3,170 · _6:40 " 1050 3,220 ~ ,, . 6: 55 " 1060 ,3,220 ,,, 7:10 " 1050+ 3,140 , 7:25 1/4" 1270 .... 7:40 ..... " 1410. 1,470 8 O0 ,, 1390 , , 'Casing perfs~ ....... Bottom choke ..... Surf. tamp .°F Ticket No .599140 Gas gravity ....... Oil gravity .... GaR . .. i Spec. gravity ~ .... Chloride~ - .... pPm Res ..... @ eF · INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ,, , ', . , ~. PAGE 3 ~ , i Date Surface ' Gas' Liquid · ' Choke 'i . ' ' Remarks ~ime a.m. Size Pressure Rate Rate '., i D.m. -psi MCI:: BPD !,.8:05 1/4" ..1550 ., L. ine f..r. eezin~l , 8: 35 " 1500 : . .8: 55 " 1400 , , ., 9 ' 10 " 1390 1,260 9: 25 " 1400 1,800 9:40 " 1390' 1,750 9:48 " Closed in 4:41 Pulled loose ,,, ·., ,,, ,,, · , · ........ · ,., ' _ Gauge No. ,, , 61.] ...... Depth 4703' .... Clock No. 672.9 . .. 12 hour No. 5..99140 ............ ~.. Fi rst Firs t Second Second Th i rd l'hi rd ~ F!o~..,P,eriod, CIo?,ed In. P,r.,,essure ~. Flow,. . ~ Period.~., , Closed In Pressure FIo ,w, Period Closed !n, P,,re, ssu, re Time Deft. PSIG Time Deft. t -j-.*:~ PSIG Time Deft. PSIG Time Deft. Log~ PSIG Time Deft. PSIG Time Deft. . t Log Temp. Temp. Temp. Temp. Temp. Temp. ~ uog~ .000" COrr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000" Corr. .000" Corr. o' j'O00 369 .000 ....... 999 , 000 10'~'3 . ' ' ..... , ...... , ~ .035 1299 0141 1868' .5195. 981 2 (.068 1368S) .0422 1~86 1.0109 1061" ~ - ' ....... ~ . 070 · 1342 .0~63 1~90 1 50--23 1099 ~, ..... ' ' ' ~ 105 '~ 74-1 ..0984 ~ ii' 1893 _[1._802 i1'i3C)I .... ,, , ' .... , . , , s . ~;I0 624 .1-2-~5 "1'~§4 1.9937 995 6i . 175 807 .1546 ' 1895 (.~.,2!2 995~.).',2] ' ....... , .... ,' . 7i .210 993 .1827 1896 2.4851 ' 1146 si..245' 1185 '~2108 .... 1897,,. (2.'491 ' l146Ci.'~.',,. '","', ....... ,,' ' ' '' 9, .280 999 ' .2389 1897 2.9765 ' ...... · ..... ~o ...... .2670 ,, 1897 13.4679 ,.~ · ,, , ~ .2951 1897 i 3". 9593" . ..... ~2 3232 1897 4.4507 ~3 .3513 .... 1897 4.9'42 ...................... ~ " .3794 1897 ~ CHART T',[M~ ............ .... is ....... .4080 1897 EXPIRED AFTER .............. . ' ' , 355-'MINUTES ................. Gguge No. 3637 Depth .4 0~, .... Clock ,,No. 1 ;)861 bo,ur o .000 493 -~.000 "' 1009 .000 1103 .000 1'631 I ....... ~ 0085 1287 .0034 1875' .1250 985** .0404 ' 1808**~ "2 ( .015 1368S~ .0103 1.887 .2432 1064 .0876 1813 ...... " .. · 3 .0170 !337'' 1'0172 1893 .3614 1105 1348 1821 ' ,, ~.025F~ 719 .0241 1897 (.443 1120£~ .1820 1826. 5 . 0340 613 1.0310 1899 .4796 1009 ' .2292 1833 ,. " . a.0425 783 .0379 1900 (.543 1007£/ .2764 1842 7!. 0510 983 .0448 1902 :5978 1153 .3236 ' 1849 ,.~ 8 . 0595 1168 .0517 . 1902 .7160 1162 .3708 1857 e - 0SRO 1009 .0586 1902 (.747 1162 .4180. 1868 , ~o~ .0655 .......... !902._._, ~.83¢.2_-_1325~ .~4652 1878 .. ] i II .0724 1902 (.950 1375C~ .5124 1885 . · ~2 .0]793 1902 .9524 1462 .5596 1888 ~3 .0~62 1902 1.0706 1682 .6068 1895 ~4 .0931 1902 .1.189 1631 .6540 1899 ........ ~s ........ lO(lO 1902 .7(11 1902 . , , Reading lnte~a!. 5 ,' 'J 4 70 · 28 ·.. REMARKS: S-Surface closur~ c-choke 'chanae .. * First interval equal to 2 minutes **-7.4 mintues ***-24 minutes ii i i i mi ii · i I I , i mR i i i im ] mml m i III m i mi i i SPECIAL PRESSURE DATA LITTt.~'$ JJm?J 7~G J/74 · Gouge No. 3636 Depth 4732' , ClOck No. 9300 38 hour No. 599140 I F~ I First Second Second Thlrd Third rst Flow Period{ Closed In Pressure Flow Period " Closed In Pressure Flow Period Closed In Pressure ~ ..... PSIG PSI~ ' ' ..... Time Deft. ~PSIG j Time Deft t -{- {9 Time Deft. Tirne Deft. Log t-I- e Jemp. ,, ' Log Temp. Temp.~ Temp.PSIG Time Deft. Temp.PSIG Time Deft. Log t .000" Corr. I .000 ~) Corr. .000'° Corr. .000" Corr. .000' Corr. .000'° ~ Corr. , o .000 749 ' ,0_.0_0 10_29 .(10_0 . '1140 .(ZOO 1643 ..... ] 0084 1355 )1.0934. 1879' .1259 1020'* .0408 1813'**lJ ' 2 (.014 13.82S 01_0_2 .. 1_8.94 .,2450 1103 .(ZS_8.z~ 1817 . 3 0168 1064 ·0170 1899 ,3641 1143 . 1.360 1824 . 4 .0252 713 .0238 1903 (,444 1160C). .1836 . .. 1832 . . . , . 5 .0336 706 .0306 1905 .4832 1057 .2312 183_7 .. 6 .0420. 87.7 .0374 19_07 (.548 lgz~5___C)~ 2788 1846' . . 7 .0504 1061 .04_42 1907 ,6023 1193 ' .3264 1852 8 .0588 1202 .0510 1907 ,7214 1200. ,_;3740 1861 9! ,0670 1029 .C~578 1907 (.751 1200C~ 4216. 1872 .. 70 · .0646 1907 .8405 1399 .4692 1881 ~l ~.0714. I 1907 (,955 1401C) ,5168 1890 ..]2i . .0782 1907 ,9596 1520 . .56.44 . 1894 73: .0850 1907 1.0787 1687 ,6120 1899 . . 74: .0918 1907 1,1980 1643 .6596 1905 · 75, .0980 . 1907 ,7070 1908 . .. Gauge No. 597 Depth 4736' Clock rio. 4485 h°ur . 12 o .000 809 .000 1020 ,000 1131 I · ].0338 1308 ,0136 1868' .5021 1014'* 2(.066 1'375S~ ,0408 1888 ,9771 1094 3 .0676 1371 ,0680 1891 1.4521 1137 4. 1014 730 ,0952 1895 1.747 1152C) s .1352 643 .1224 1896 1,9271 1048 6. 1690 820 .1496 1897 (2,145 1050C) 7 . 2028 991 .1 768 1898 2. 4021 1189¢T 8 . 2366 1191 .2040 1898 2.8771 , , 9.2700. 1020 .2312 189.8 3,3521 . . . ]o... ,' 2584 1898 3,8271 .. ] 7 ,2856 1898 4,3021 · , · ]2, ,3128 1898 4,777 , 73 ,3400 1898 CHART T: ME ]4 .3672 1898 EXPIRED AFTER .. 75 .3950 1898 357 MIN JTES ,Reodinc, I Interval 5 4,, 70 ,1 , , Minute,,? ~^~s: S-Surface ciosure C-Choke change *-2 mJnutes **-74 m~nu~es IrORI4 I~3-1111~PRINT~'O IN SPECIAL PRESSURE DATA Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ' Drill Pipe ......................... 2 -7/8" Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... 3 7/8" Du~l ClP ~ompler .................. Hydro-Spring Tester ................... 3 7/8" _. Multiple ClP ~mpler ............... 7 " e~m~.~o~rAP. RUNNING CASE.. 3 /8 AP ~unning ~a~ ' 3 7/8" vR ~fety Join .................. ...3 7/8" Pressure Equalizing Cr~vet ......... P:':k~r ~.~uy .../ ........ T.'. ...... 3.87" ~,~PERFS .................. 2 7/8" Pecker Assembly ................ :. . Flush Joint Anchor ................. 'Pressure Equalizing Tube ....... - ..... Blanked-Off B.T. Running Case ' 3 7/8tm ~H <~H~s AP.. RUNN I NG .CASE ..... 3 7/8" Anchor Pipe ~fety Joint ...... , ...... 1.75" 2.151"-2.764" .87" ~ m. , 62" 3II J . 3.1' 896'-4116' 0.2' 5.76' _ 4.58' ,,L 4,157' · .. 5.11' 3,22' 3,56' 8.79' .. 4,06' 4,09' p_~m-x~FE.MP .... RE.C. QI~DER .... ,3 7/8" .4 Distributor ........................ Packer Assembly 1,11' Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 5991.~O DEPTH · 4692' ,4698' 4703' ~707', ,4720' 4732' 4736' 4741' LIT?LI'I lei1II 'lie Ticket F L U I D S A M P L E D A T A Date 10-1 3- 74 Number 5991 38 Sample.' Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C~s of Job HOOK WALL District ANCHORAGE ' cc. Oil ~'~. cc. Water Tester MR. BOATMAN Witness MR. WESTER cc. Mud Drillinn Tot. Liquid cc. Contractor KENAI DRILLING COMPANY DR S Gravity ° APl @ °F. EQU I PME N T & HOLE DATA C~3s/Oil Ratio cu. ft./bbl. Formation Tested Beluga z i RESISTIVITY CHLORIDE Elevation 78' GL Ft. --~ CONTENT Net Productive Interval 5083 ' -5103 ' -5175 ' -5195 ' Ft. Recovery Water ~ @__ °F. ppm All Depths Measured From Kelly Bushing 92' Recovery Mud ~ @~ °F. ppm Total Depth 5288' PPD Ft. Recovery Mud Filtrate ~ @__°F. __ ppm Main Hole/Casing Size 7 5/8" - 5" · Mud Pit Sample @ °F. ;:,-ppm Drill Collar Length - I.D. - ' _ Mud Pit Sample Filtrate @ °F. " ppm Drill Pipe Length 896' -4120' I.D. 2.151 "- 2. 764" :. Packer Depth(s) 5043 ' Ft. Mud Weight vis cp Depth Tester Valve5020'Ft. TYPE AMOUNT Cushion gas 1000 PM Depth Back 4' Surface Bottom Pres. Valve 501 Choke 1/2_3/8_ 1/i~hoke 5/8" Recovered Feet of ~ / · Recovered Feet of Recovered Feet of ~ ~:~-- Recovered Feet of ~ z Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET C Cx~uge No. 3382 C~uge No. 2857 C~uge No. 3381 TEMPERATURE TIME Depth: 5026 Ft. Depth: 5030 Ft. Depth: 5055 Ft. 48 Hour Clock 24 Hour Clock 48 Hour Clock Tool A.M. O Est. 'F. Blanked offNo Blanked Off No Blanked offYes Opened 6-02 P.M. cD Opened A.M. Actual 80 °F. Pressures PreSsures Pressures Bypass 9' 11 P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 2592 2589 2604 2579 2625 2605 Minutes Minutes Initial --~ Flow 1686 350 1724 530 1718 700 r"r- Final ~-~. 1782 1763 1748 1748 1816 1811 36 35 Closed in 2283 2287 2286 2284 2282 2292 60 58 ~ Initial c o Flow . 1734 1729 1724 1716 1767 1 782 u°'F_ Final r-- ~Z 2211 2223 2188 2215 2233 2228 492 384 , Cl°sed in 2283 2285 2286 2279 2282 2287 401 431 Initial ' ' -~313 ._...o_ Flow ,, ~_~. Final Closed in Final Hydrostatic 2592 2591 2604 2_5_87 2625 UTR llTR-11rahl~ tn r~,arl FLUID SAMPLE DATA Date 10-13-74 Number 599138 Sampler Pressure .P.S.I.G. at Surface· Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester MR. BOATI~,N Witness MR. NESTER cc. Mud Drilling Tot. Liquid cc. Contractor I~ENAI DRILLING COMPANY DR S ., Gravity o APl Gas/Oil Ratio cu. ft./bbl.: Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From Recovery Mud @ °F. ppm Total Depth Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size Mud Pit Sample .. @ °F. ppm Drill Collar Length ..: I.D. ' Mud Pit Sample Filfr'6~te @ °F. ppm Drill Pipe Length " I.D. · : Packer Depth(s) Ft, Mud Weight vis cp Depth Tester Valve" Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke · Recovered Feet of . Feet of Recovered Recovered Feet of ~ Recovered Feet of Recovered Feet of Rerr~rk~ Fell IR'l'l~ ' Gauge No. 2856 Gauge No. Gauge No. TEMPERATURE TIME Depth: 5059 Ft. Depth: Ft. Depth: Ft. 24 Hour Clock Hour Clock Hour Clock Tool A.M. Est. 'F. Blanked Of lyes Blanked Off Blanked Off Opened P.M. : Opened A.M. Actual °F. Pressures Pressures Pressures Bypass P.M. ,, Reported Computed Field Office Field Office Field Office Initial Hydrostatic 2599 2559 Minutes Minutes ._~o Initial ~.r_ Flow 1 700 808 ;r~e Final 1 796 1801 Closed in 2 258 2280 ~ Initial 1748 1 772 c o Flow ~o.~. r~na~ 2209 2221 Jco~ Closed in 2258 2287 ~ Initial ~ o Flow _:e Final Closed in -. _ Final Hydrostatic 2599 2611 , ,o..,,,..,-.,...o,.u..... FC')RMATIC)N TF~T DATA ~,..~..,,,,,,,o../,, Casing perfs.__ Bottom choke Surf. temp *F Ticket NOL 5.991 38 Gas gravity 0il gravity GOR Spec. gravity. Chloride-~ ppm Res. INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Choke Surface Gas Liquid Pressure Rate Rate Remarl~ Time a.m. Size .psi MCF BPD . F;:O?_ 1000 Opened tool, closed at surface 6 · 05 1800 6:07 1/2" _ OPened at surface , 6 -10 1/2" 1050 6.20 ,, 1050 6 · 30 " 11 O0 6 · 35 " 11 O0 6 · 38 _ " C1 osed tool .. 7 · 38 , Reopened tool 7 · 40 " 1200 7 '45 " 1150 8 · O0 " 11 75 8 '15 " 1175 8 · 30 " 1200 8 · 45 " 1 200 9 -00 " 1225 6~180 9 · 15 " 1225 9 · 30 " 1 250 .. 9-45 " 1250 Chan§e to 3/8" choke 1 O' OD 3/8" 1600 1 O' 15 " 1675 1 D: 30 " 1675 1 0:45 " 1675 .~ 1 1 '00 " 1675 ll'15 " 1675 4,890 .. ,, 599138 Casing perfs. Bottom choke Surf. tamp 'F Ticket No. Gas gravity Oil gravity. ,GOR Spec. gravity Chlorides ppm Res, @ *F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks r~.m. psi MCF BPD 11'30 3/8" 1675 11 '45 ,, 1675 ,..,. 12 O0 " Change to 1/4" choke 12.10 1/4,, ~:~: 1975 12-15 !:i,:~ 1975 12'30 1975. 12-45 ~' 1975 1 -00 1975 1 -15 1975 -- 1 ' 30 1975 2,000 1 -45 1975 _. 2:00 1975 Closed in at surface 2 · 30 C1 os ed tool 9'11 Pulled loose : · Oauge. N..o..... 3382 Depth 5026' Clock No. 13861 18 hour No. 599138 .. Fi rst Fi rs t Seco nd Second Th i rd Th i rd Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. PSIG Time Defl. t Jr ~ P$1G Time Defl. PSIG Time Defl. t Jr ~ PSIG Time Deft. PSIG Time Defl. Log t Jr 8 PSIG Temp. Log Temp. Temp. Log Temp. Temp. Temp. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. o .'000 '" 350 .000 1763 .000 1729 .000 2223 1 (.008 2117S1) .... 00.17 2280 .0709 1832'* .0017 2261 2.012 1722 .0034 2283 .1350 1851 .0034 2273 3 .024 .!727 .0051 2285 .1991 1866 .0051 2276 4.036 1743 .0068 2287 (.238 1871C) .0067 .2278 ........ 5 048 17.60 ..... .0085 2287 .2632 2048 .0084 2280 ...6.060 !763 .0102 2287 .3273 2050 .0101 2283 7 .0119 2287 .3914 2050 .0118 2285 8 ...0137 2287 (.444 2050C) .0135 2285 .9 ............ 0154 2287 .4555 2209 .0152 2285 lo .0171 2287 .5196 2216 .0169 2285 ~1 .0'3'4'1 ..... 22'87 .5837 2221 .40186 2,285 ~2 .0512 2287 .6480 2223 ~ 19'5'7 2'285 ....... , ..... 13 .0683 2287 .3728 2285 14 .0853 2287 .5499 2285 75 ... ~0'9g0 2287 .7270 2285 ,i;[! ,, Gauge NO. 2857 ,,, Depth 5030' Clock No. 1 3829 hour 24 o 000 .530 .. '.000 I 1748 'I ,000 1716 .000 2215 i I ~ ('.,01.7 .2056SC ,0034 ...2271 .139.2 1817'* .0033 2254 " 2.0238 ..1836 .... 0068 2276 .2652 1836 .0067 2264 3 , 0476 1704 ,0101 2279 .3912 1848 .0100 2267 ... 4,071..,4 1724 ,0135 2281 (.469 1853C) .0133 2271 5 , 095.2 1746 .,0169 2284 .5172 2037 .0167 2274 6 . 1190 I 748 ,0203 2284 .6432 2039 .0200 2276 7 .... 0237 2284 .7692 2039 .0233 2279' 8 .0270 2284 (.874 2039C) .0267 2279 9 ,0304 2284 .8952 2200. .0300 2279 lo .0338 2284 1,0212 2208 .0333 2279 11 .0676 2284 1.1472 2210 .0367 2279 12 .. ,1014 ......2284 1,273 2215 /3'8'68 .... 2279.... 13 ,1 352 2284 .7368 2279 ~4 ,1690 2284 1.0869 2279 ~ . .1"96'0 '2284 1,4~70 2279 ,,Reading I n,t,ervol7 * 38 *** Minutes REMARKS: SC-Surface closure C-Chok'e' change *-First 10 'intervals equal to 1 n~inute each; next 4 intervals equal to 10 minute each' last interval equal to 8 minutes **-42 nlinutes ***- First 11 intervals equal t;o 1 minute each: last 4 intervals equal to 105 minu£es each. ,,,, FORM II,I-RI--PRINTI[O IN U.I.A. SPECIAL PRESSURE Ticket Gau. ge No. . 3381 ..... DePth 5055° Clock No. ....... 9300 ~,8 hoUr No. 599138 II First First II Second Second Third Third Flow,,,,Period Closed In P,ressure ,I! Flow Period CloSed In Pressure ..... Flow Period Closed In Pressure Time D~fl. PSIG Time Deft. t Jr ~ PSIG Time Deft. PSIG Time Deft. t Jr ~ Time Temp. Log Temp. Temp. Log Temp. Temp. Lc~g Temp. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000~' Corr. .000" ~ Corr. ° . 000 700 .000 '1811 ,000 1782 .000 2228 ~UTR UTR ,0017 2277 .0715 1880'* .0017 2265 2 .012 !743. ,00.34 2287 .1362 1900 .0034 2275 3' 024 1767.. ,0052 ..2289 .. .2009 1914 .0051 2277 4 . 036 1787 ,0069 2292 (. 240 1 919C), 0068 2279 " ~i::,:~ii~ ..... si. 048 1806 .0086 2292 .2656 2071 .0085 2282 a!. 060 1811 .0103 22'92 .3303 2074 .0102 2284 7 ,0121 2292 .3950 2074 .0119 2287 ~UNABLE TO .0138 2292 (..450 2076C) ,0136 2287 9 READ SURFACE .0155 2292 ,4597 2213 .0153 2287 ...... lo CLOSURE ,0172 2292 ,5244 '2221 .0171 2287 11 ,'"0345 2292 ,5891 2226 ,0!.88' ...... 2287 .12 ... ,0517 2292 ,6540 2228 .1978 2'2'87 .... ~3 .0690 2292 .3769 2287 ..... ~4 . ,0862 2292 I .5559 2287 Ts ......... i'"l~)0 ..... i. '22'92 .7350 2287 Gauge No. 2856 Depth 5059' Clock No. 8420 hour 24 o .000 '808 .000 1801 I .000 1772 ,000 2221 1 1 (.017 2063S, ~.0034 2270 ~ .1411 1862'* .0034 2263 2 : 0238 1780 .0068 2273 .2688 1891 .0067 2268 3 . 0476 1755 .0101 2275 .3965 1906 .0101 2273 4 0714 1777 .0135 2277 (.477 1913C) .0134 2275 ~ . 0952 1797 .0169 2280 .5242 2061 .0168 2277 6. 1190 1801 .0203 2280 .6519 2063 .0202 -2280 ' .... 7 .0237 2280 .7796 2066 .0235 2282' 8 .0270 2280 (.888 .2066C) .0269 2285 9 .0304 2280 .9073 2204 ,0302 2287 ~.~ lo .0338 2280 1.0350 2212 .0336 2287 ~i .0676 ....... 22'8'0 1.1627 2219 .0370 2287 12 .1 O14 2280 1. 290 2221 "3897 "' 2287 ~ .1 352 2280 .7425 2287 1~ .1690 2280 1.0952 2287 .. ~s .1960 '" 2'280 1.4480 2287 Reading Interval 7 * ;~ *** Minutes REMARKS~-~urfa£e closure C-Choke chanae * First 10 intervals eoual to"l minute each: next 4 intervals eaual to lf} minut~_~ ~_ach: last interval eoual to 8 minutes **-42 minutes ***-First 1'] intervals equal to 1 minute each: i n~×t 4 interval_~ ~n~nl tn ICIR minut~ ~nnh ..... . I ORMII,-RI--PI INTIDIN,.I.A. SPECIAL PRESSURE' DATA ""'"' .... · Drill Pipe or Tubing ................ Reversing Sub ...................... Oo Do 3.88" 2 7/8" Jo Do 1.75" 2.151 "-2.764" Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIF Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ............... 3 7/8" 3 7/8" .87" .62" 3" Multiple CIP Sampler ............... E~;~Y,,X. AP Running .case AP Running Case Hydraulic Jar .................... 3 7/8" 3 7/8" 3 7/8"?i~ 1.25" 1.9" 2.4" VR Safety Joint .............. 3 7/8" Pressure Equalizing Crossover ......... Packer Assembly 3.87" TICKET NO. LENGTH 3.10' 896'-4120' 6.2' 5.76' 4.58' 4.57J 5.11' .3.22' 3.56' 599138 DEPTH 5014' 5020' 5026' 5030' 5043' Distributor ............ ............ 2 7/8" 8.79' Perfs. Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... 3 7/8" x~~ .A..P..RUN. NI.NG. CASE... 3 7/8" Anchor Pipe Safety Joint ............ 4.06' 4.09' 1.11' 5055' 5059' 5064' ~x~~. T.emp:..Re.c.o.r.d. er. 3 7/8" Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... Each Horizontal Line Equa p.s.~. Ticket F L U I D S A M P L E D A T A Date 10-14'74 Number 599139 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C_~3s of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester C.H. BOATMAN Witness D. WESTER cc. Mud Drilling Tot. Liquid cc. C°ntr°ct~rENAI DRILLING COMPANY SM S Gravity ° APl @ 'F. EQ U I PM E N T & H OLE DATA Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT ,, Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From Recovery Mud __ @~ °F. ppm Total Depth Ft. Recovery Mud Filtrate __ @~ °F. ppm Main Hole/Casing Size . Mud Pit Sample @ °F. ppm Drill Collar Length I.D. Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length I.D. Packer Depth(s) Ft. Mud Weight : vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Bock Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of · Recovered Feet of Recovered Feet of < O Recovered Feet of Recovered Feet of Remarks FOURTH GAUGE GaUge No. 597 Gauge No. Gauge No. TEMPERATURE TIM'E Depth: 4623 F.t. Depth: Ft. 12 Hour ClOck Hour Clock Hour Clock Tool A.M. Est. 'F. ""Blanked Off yoc; Blanked Off Blanked Off Opened P.M. Opened A.M. Actual 'F. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 2380 2391 Minutes Minutes *-~o Flow Initial 1210 1217 _~'r_ Final 714 729 Oosed in · 1 647 1648 ~ Initial 832 840 c o Flow ~o 'z Final ~ - 1248 Closed In ~o~ Initial .~__o Flow ~.~ Ftnol Closed in Final Hydrostatic _ _ FLU ID SAMPLE DATA' Ticket .~' Date 10_14_74 Number 5qq139 '*- Sampler Pressure .P.S.I.G. at Surface Kind Halliburton .~ Recovery: Cu. Ft. Gas' of Job HOOK WALL District ANCHORAGE cc. Oil' CC. Water Tester C.H. BOATMAN Witness D. WESTER cc. Mud Drilling Tot. Liquid cc. Contractor KENAI DRILLING COMPANY SM $ Gravity ° APl @ °F. EQU I PM E N T & H O L E DA TA Gas/Oil Ratio cu. ft./bbl. Formation Tested C-2 RESISTIVITY CHLORIDE Elevation Ground level 78 Ft. CONTENT Net Productive Interval Holes at 4722-4742' Ft. Recovery Water ~ ~__ 'F. ppm All Depths Measured From Kelly bushing 92' Recovery Mud @__°F. ppm Total Depth Retrievable bridge plug 4750' Ft. Recovery Mud Filtrate __ @ __°F. ppm Main Hole/Casing Size 7" & 5" . Mud Pit Sample~ @ ~ °F. ppm Drill Collar Length - I.D, Mud Pit Somple~Filtrate @~°F. __ppm Drill Pipe.Length 896 - 3676' ~.D. 2.151 -2.764" ... Packer Depth(s)_ 4607' Ft Mud.'Wei. g, ht, , vis , cp Depth Tester Valve 458~' Ft. TYPE AMOUNT Depth Back Surface 1/2, 5/8,Bottom Cushion Ga s 1100# PS I Ft. Pres. Valve Choke 3/8,1./4"Choke 5/8n RecoVered Feet of Recovered Feet of Recovered Feet of Recovered Feet of ~< ~.~ Recovered Feet of Remarks SEE PRODUCTION TEST DATA SHEET . z , Gauge No. 3637 Gauge No. 611 Gauge No. 3636 TEMPERATURE ' TIME Depth: 4~qn Ft. Depth: 45q4 Ft. Depth: 4619 Ft. O 48 Hour Clock 1 2 Hour Clock 4~ Hour Clock Tool 1 0-1 4 AXt~-X Est. °F. Blanked Off I~O Blanked Off nfl Blanked Off VpC; Opened 3 · 1 .~J P.M. ~-~ 46281 ~ Openec~ 0_ 15 A.M. -r' Actual q_~ °F. Pressures . Pressures Pressures Bypass 1 2' 1 2 P.M. Field Office Field office Field Office Reported Computed Initial 'Hydrostatic ?]52 ?-'~ ~ 1 2~61 2373 24(33 24(31 Minutes Minutes ~ Flow Initial 1027 529 1 2ll5 1203 1027 RR1 .=~ Final 702 709 692 703 735 734 64 59 Closed in 16'29 1651 1640 1649 1652 16.~6 101 103 ~ Initial m ~0Flow 822 818 796 Al2 ~ R63 R55 r- u°'c Final oo 1543 1545 1227 1561 1553 552 553 Closed in 1629 1649 - CTE 1652 1654 542 544 Initial ~ Flow ~_~. Final ClOsed in Final Hydrostatic 2352 2374 CTE £TF 24fl3 23q? ~TF = c, qart timr r-ur.-;;-~4 Casing perfs. Bottom choke Surf. ter~2r 'F Ticket No., 599] 39 Gas gravity, Oil gravity GOR Spec. gravity Chlorides ppm Res. INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED D~te Choke Surface Gas Liquid Time a.m Size Pressure Rate Rate Remark~ p.m. psi MCF BPD 3:13 PM 1/2' 1100 Opened tool 4:17 " 450 Closed tool 5:58 " 450 Opened tool, closed in at surface 6:05 " llO0 Opened at surface , 6:30 ,, 550 ~?~1.2,620 7'00 " 590 2~780 7'09 5/8' . Changed to 5/8" choke -- 7' 15 " 440 2~930 7' 30 " 425 3,060 7'45 425 3~180 -- 8' O0 440 3 ~ 280 8:1 5 450 8'30 460 3,410 8:45 480 -- ,, 9-00 490 3,510 9-15 490 9- 30 500 3,630 9- 45 500 1 O' O0 500 10-15 510 10-30 510 3,770 10:45 525 · 11' O0 5/8" 480 11'06 3/8" Changed to 3/8" choke ll- 15 820 3,150 i i ,:: ~ i ii iii . i ill i i i i il i ii Casing parrs, Bottom choke Surf. tamp .*F Ticket No. ~0C)1 .'~C) .... Gas gravity Oil gravity GaR . Spec. gravity Chloride~ . ppm ees~ @ 'F Page 2 INDICATE TYPE AND SIZE OF GAS N~EASURING DEVICE USED ....... , m , i , · -- - C~te Choke Surface Gas Liquid !Time a.m Size Pressure Rote Rote Remarks psi MCF BPD .. , Dim. . .... - 11-30 3/8" 935 11'45 940 3,190 12'00 940 12- 15 940 · 12.30 940 · , 12'45 940 1'00 3/8" 940 3,190 1'08 1/4" Changed to 1/4" surface 1'15 1375 1-30 1375 1 '45 1375 - .,., 2-00 1375 1,460 2-15 1375 2:30 1375 2'45 1375 3'00 1375 1,470 3- lO Closed in 12:12 ~ Pulled = ...... · . Oau~ie No. 3637 .... Depth 4590' Clock No... 13861 48 hour ...No. 599139 ..... First Fi rst Second Second Th Jrd Th i rd Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. PSIG Time Deft. t -{- ~) PSIG Time Defl. PSIG Time Deft. t -I- ~ PSIG Time Deft. PSIG Time Deft. t -I- ~ PSIG Temp. Log Temp. Temp. Log, Temp. Temp. Log Temp. .000" Corr. .000'T Corr. .000" Corr. .000" ~ Corr. .000' Corr. .000" ~ Corr. ..... o .0000 529 .0000 709 .0000 818 .0000 1545 ] .0153' 344 .0034 1636 (.0100-~C 1271) .0168 1637 2 .0322 529 .0068 1639 .0978*~ 803 .0337 1639 3 .0492 661 .0101 1643 (.1190-: 812) .0505 1641 .... 4 .0661 699 .0135 1644 .1905 776 .0674 1641 s .0831 683 .0169 1646 .2832 822 .0842 1643 6 .1000 709 .0203 1646 ,3759 856 .1010 1643 7 .0237 1646 .4686 880 .1179 1643 8 .0270 1646 (.5200-; 892) .1347 1643 9 .0304 1648 .5613 1223 .1515 1643 ~0 .0338 1648 .6540 1232 .1684 1643 ~ .0608 1649 ( 7260-~ 1237) .3'553 1646 12 .0878 1649 ,7467 1519 .5422 1646 131 .1149 1651 .8394 1540 .7291 1648 ~4 .1419 1651 .9320 1545 ~9160 1649 i!~i' ,~ s .174'0 1651 I i ., Gouge No. 611 Depth ,, 4594' Clock No. 6729 2 hour ... 0 .0000 1203 .0000 703 ,0000 812 ~ 1 .0658* 340 .0138 1631 (,0570-~C 1275)J 2 .1388 464 .0277 1539 ,4092*~ 797 Nonel recorde,i · 3 .2118 621 .0415 1640 (.4750-; 806) 4 .2849 694 .0553 1642 ,7973 769 Charl- time e:<pired ~ .3579 675 .0691 1643 1,1854 818 a 4310 703 .0830 1644 1,5735 852 7 .0968 1644 1.9616 875 8 · 11 06 1644 ( 2.1100. C 882) .... 9 .1244 1645 2.3497 1222 10 .1382 1645 (2.5190:~**1227) ~ .2489' 16'46 '2.7378 - 12 .3595 1646 3,1259 - ... 13 .4701 1647 3,5140 - ... 14 .5807 1647 3,9020 - ~. '~71'"20 ....1649 ....... i .. · ,,R, eadin~ Interval 10 *~[ 5 5 ****, ,, , ,Minutes_ REMARKS: *First interval is equal ~0 9 minutes. *aFirst 10 intervals are equal to 2 minutes each; next 4 interval_~ equal to 16 minutes each. last interval i~ ~n~l tn !9 ..minutes_ .qt. = surface nlosL!re C = choke chanae **First inter, is'equal to 58 minutes. *~*Read at the end of'-a-pPro-ximately 357 minutes when chart time expired. ****F~rst 10 interval · ,_ _ ' · · '"' ..... i a.~ i i i ~..~,..l-,,~m," ~ ,,] ,,,. ,, i,, .,, ~'~O~M Ill-RI--PRINTED U.·· LITTLIE'I 1117:1 .. Goucje No. First Flow Period Temp. .000" Corr. o 881 361 . 4 8 9 10 11 12 13 .0000 .0153' .0322 ·0492 · 0661 · 0831 .1000 C;auge No. 3636 .0000 ·0633* j Depth First Closed In Pressure Time Defl. .000" .0000 L tq-8 °gT PSIG Temp. Corr. 734 0034 1630 551 . 0068 1645 .0102 1648 4619" Second Flow Period Time Deft. .000" · 0000 (.0100, .0985~ (.1190- PSIG Temp. Corr. 855 685 720 709 734 489 638 712 695 729 SC 1287 :* 833 ,C 844) · 0136 1650 .1919 811 .0170 1650 .2853 863 Clock No. 9300 Second Closed In Pressure Time Deft. .000" · 0000 .0170 PSIG Temp. Corr. 1553 1643 .0339 1645 .0509 1645 .0678 · 0848 1647 1647 .0204 1652 .3787 897 .1017 1647 .0238 1652 923 .1187 1647 .0272 1654 .0306 1654 .4721 (.5230- · 5655 ,C 934) 1248 1 256 .1356 .1526 .1695 .3577 .5459 .C 1259 1527 .6589 (.7310- .7523 1654 .0340 .0612 1654 .0883 1654 1648 1648 1648 i650 1650 .1155 1656 .8457 1548 .7340 1654 · 1427 1656 .9390 1553 .9220 1654 1656 .1750 J Ticket 48 hour No. Third Flow Period Time Deft. PSIG Temp. Corr. ;99139 I Third Closed In Pressure PSIG Time Deft. Log Temp. .000" Corr. 2 597 Depth 4623' Clock No. 4485 1.2 hour 9 10 11 12 .13 14 15 · 1 336 .204O .2743 · 3447 .4150 1217 . 348 . · · · · J · 0000 0134 0268 O402 0536 0670 0804 0938 1072 1206 729 .0000 840 1626 1637 1639 1642 (. 0370- .3956~ (.463O- .7707 1643 1. 1458 1643 1.5209 1643 1.8960 1644 (2.0470- 1644 2.2711 .SC 1277 824 C 835) 804 856 892 917 C 926' 1241 None Char' recorde( time e: (pi red ' 1340 2412 3483 4555 5627 1644 1645 1647 2.6462 '2.6930~ 3.0213 1246 '** 1248 1647 3.3964 - 1647 3·7715 - · 6900 t648 J ,Reodin~ Interval 10 *a 55 **** Minutes RE~LARKs:WFirst ini:erval is equal to 9 minutes· *a - First 10 intervals are equal, to. 2 min, u, tes e.ac? .~ next 4 Sn,tervals are equal to 16 minutes each, last interval~ is equal to 19 minutes. SC = sur, face cl:osa, r,e C : choke ch,~n,-q~e **Fi,,rst in.terv, al is equal to 58 minutes. ***Read at the endl of approximately 3.95, mi~nu, tes when, cha, rt ti:me e, xpSre~. ~F$mst ~ i~terva are equal ~o, l~'m,i~es each. ~as.~ ~ ~~. x[e~~~i6~uk~~- '~' ,o,:, ..... , .... ~,o ,, ~...,. J_ _~ _ _~____~ ~__~' ~,~.., .,,,, ,,: ,/,. .... IS TICKET NO. 599139 Drill Pipe or Tubing Reversing Sub ...................... Water Cushion Valve ................. Drill Pipe ........................ Drin Com~=--. p~ pe ................ Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... <--xt~n~om.k~tAP. Ru. nni n.g .cas.e .. AP Running Case .................. Hydraulic Jar .................... VR Safety Joint .............. Pressure Equalizing Crossover ......... Packer Assembly ................... O. D. 3.88" 2 7/8" 3b" 3 7/8" 3 7/8" 3 7/8" 3 7/8'' 3 7/8" 3 7/8, . 3.87" 2 7/8" mstr~l~torP, er.f.s .................. Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... DI. ~,~C.o!~ a iqj II II Anchor Pipe Safety Joint ............ 3 7/8" 3 7/8" Packer Assembly . .Temp.... re.c.o.~d.e~. Distributor ........................ Packer Assembly ................... 3 7/8" Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ' Blanked-Off B.T. Running Case ........ Total Depth ....................... 1.75" 2,151" 2,764" 3" 3" 1.25" l" 1.9" 2.44" LENGTH 3.10' 896' 3670' 6.2' 5.76' 4.58' 4.57' 5.11' .3.22' 3.56' 8.79' 4.06' 4.09' 1.11' DEPTH 4579' 4585' 4590' 4594' 4607' 4619' 4623' 4628' TIME Each Horizontal Line Equal to 1000 p.s.i. Form D-100I-A UNION OIL CO. OF CALIFORNIA SHEET A REPAIR RECORD PAGE NO. 1 LEASE KENAI UNIT WELL NO. ~ CONTRACTOR__~Kenai Drilling Co,,, Rig #3 FIELD Kenai Gas Field TYPE UNIT Oilwell 52T BEGAN:,, 9/20/74 COMPLETED: 10/23/74, , ELEVATIONS: GROUND See PERMIT NO. 68--5 SERIAL NO. A-028142 CASING HEAD Previous COMPANY ENginEER .I~es~, Hess,, ----- TUBING HE)kD Report APPROVED.,· ._ .~/"_~'/L~. /___~_~__~/~.~FE #341112 ROTARY D,..R. IVE BUSHING ~;~im R. Callender CASING & TUBING RECORD -'SIZE DEPTH., "'"' WEIGHT ,,GRADE ., REMARK~ , 20" 60' Conductor Driven 13 3/8" 3078' 61-54.5# J-55 Cmt'd w/ 1720 sx. Construction Cmt. 7" 4618' 26.40# N-80 Cmt'd w/ 775 sx. Construction Cmt. 5" 5337' 18# N-80 Liner-BOT Hgr. @ 4593'. Landing Collar @ 5219'. See Tbs. Detail Shoe @ 5337'. Cmt'd w/ 90 sx. Clss "G" w/ .5% D-19. .... ,,, ,~ .......... ~, , .... : ..... ~,m t PERFORATING RECORD DATE '"INTERVAL E.T.D. REASON PRESENT' CONDITION 10/4/59 4050'-4052' 4577'RBP DST #1 Sqz. w/ 40 sx. Construction Cmt. 10/8/59 4588'-4590' 4604'RBP DST #2 C-1 Sd. - Open for gas production. · 10/9/59 4455'-4590' 4606'Cmt; Production C-1 Sd. - Open for gas production. 10/11/74 4656'-4658' 5291'LC WSO Sqz. for bond between C-2 & Beluga Sd. 10/12/74 5085'-5103' 5291'LC DST #1 Beluga Sd. - Open for gas production. 10/12/74 5175'-5195" 5291'LC' DST #1 Beluga Sd. - Open for gas production. 10/14/74 4630'-4650'' 4750'RBP DST #2 C-2 Sd. - Open for gas production. 10/16/74 5139'-5149' 5291'LC Production Beluga Sd. - Open for gas production. 10/16/74 4960'-4970' 5291'LC DST #3 Beluga Sd. - Open for gas production. 10/16/74 4856'-4868' 5291'LC DST #3 Beluga Sd. - Open for gas production. 10/16/74 4788'-4808' 5291'LC DST #3- Beluga Sd, - Open for gas production. 10/16/74' 4615'-4630' 5291'LC Production C-2 Sd. ~ Open for gas production. INITIAL DATE ' ! . INTERVAL NET OIL' [ CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS · . · DIV;SIC N '-~ OIL AND OR8 4,NCHORAG~ ,~, , ~ .... , , t ....... WELL HISTORY Pi~IOR TO REPAII~ COMPLETION DATE: 10/11/59 LAST COMPLETION NO. ,Original PRODUCING INTERVAL: C-1 INITIAL PRODUCTION: LAST REGULAR PROD. & DATE:,, C-1 10,623 mmcf/,d Sept. 1974 CUMULATIVE PRODUCTION:. 30,145.,205 mmcf thru Sept. 1974 REASON FOR REPAIR: To d~ill out csg. shoe-open hole & set liner thru C-2 & Beluga Sds. Form D-IOO1-B UNION OIL CO. Of CALIFORNIA REPAIR RECORD Sh EET B PAGE NO LEASE KENAI UNIT COMPLETION DATE: 10/23/74 DATE' ' I E.T.D. WELL NO. #14-6 FIELD APPROVED' KENAI GAS FIELD ,Tim .iR' .C,.allend,e..r. DETAILS OF OPERATIONS',' DESCRIPTIONS & RESULTS DEC 1 1 tgT~ D~\"!$1CN ,.,.F OIL AND OA~ AN~HORAG~ TYPE: Cameron WELL HEAD ASSEMBLY CASING HEAD: Cameron 12"-3000# CASING HANGER: CASING SPOOL: Cameron WF 12"-3000# to' 10"-5000# w/ 2-3" outlets blind flanged. TUBING HEAD: Cameron 10"-5000# DCB w/ 2-2" 5000# WKM valves TUBING HANGER: Cameron split 2 7/8" X 2 3/8" TUBING HEAD TOP' Cameron 8"-5000# MASTER VALVES: Cameron Block.Tree w/ 1 master. & I wing valve each side. CHRISTMAS TREE TOP CONN.: CIW Cameron 2" X 2 1/2" . . UNION OIL COMPANY OF CALIFORNIA WELL ItCORD LEASE KENAI UNIT NO, 14-6 FIELD KENAI GAS FIELD DATE 9/20/74 9/21/74 9/~2/74 9/23/74 9/24/74 9/25/74 9/26/74 9/27/74 9/28/74 9/29/74 ETD 15,047'TD 4,606'ETD 15,047'TD 4,606 'ETD 15,047'TD 4,606'ETD 15,047'TD 4,606'ETD 15,047'TD 4,606'ETD 15,047'TD 4,606'ETD 15,047'TD 4,760'ETD 15,047'TD 5,003'ETD 15,047'TD 5,218'ETD 15,047'TD 5,404'ETD DETAILS OF OPERATIONS, DESCRIPTIOHS g RESUI_TS (Footage 0') RU BJ. Bullheaded 20 bbls-20#/bbl Dril-S 73#/ cu. ft. WO fluid. Followed by 8#/bbl WO fluid (73#/cu. ft.) dwn. tbg. Killed annulus w/ 100 bbls 73# WO fluid. Tbg. dead-annulus had 200 psi surface press. Started Turnkey rig move from KU #43-7 to KU #14-6 @ 5:00 pm, 9/20/74. (FOotage 0') Turnkey rig move from KU #43-7 to KU #14-6 con- tinued. (Footage 0.') Completed Turnkey rig move @ 3:00 pm, 9/22/74. Opened Otis circ. sleeve @ 4373'. Circ. & killed well w/ 73# salt wtr. Removed x-mas tree. (Footage 0,) Completed installing BOPE & testing to UOCO specs. (Footage 0') 'Tied into 2 7/8" tbg.. Unable to pull out of perm. pkr. @ 4406'. Press. tbg. to 750 psi & worked up hole 10'. Unable to pull tbg. Cut 2 7/8" tbg. @ 4356' (50' above perm. pkr.) Pooh & laid dwn. tbg. PU OS & jars. (Footage 0') .PU 3 1/2" DP. TIH w/ OS. Latched onto fish @ 4356' & jarred free. Pooh. Rec. all of fish. TIH w/ BO mill & pkr. picker. Milled over & retrieved perm. pkr. @ 4406'. (Footage~0') TIH w/ 6 1/8" bit. Tagged top of cmt. @ 4611'. Circ. & cond. mud. Drlg. cmt. from 4611' to shoe @ 4616'. Drlg. shoe @ 4616' & cmt. to 4649'. Made bit trip. CO old hole from 4649' to 4744'. Pulled up to shoe @ 4616'. Circ. btms. up. Reamed from 4616' to 4744'-no fill. CO from 4744' to 4760'. (Footage 0') Drlg. out cmt. in 9" hole w/ 6 1/8" bit from 4774' to 4804'. Circ. btms. up-Pooh for bit trip. TIH to 4802' & had 2' of fill. Drlg. form. & cmt. from 4804' to 4908'. Circ. btms. up. Drlg. & CO from 4908' to 5003'. Circ. btms. up. Dropped survey. Pooh for bit change. Slipped drlg. line. (Footage 0') RIH to 4800'. Reamed to 5003'. Had 12' of fill. Drlg. from 5003' to 5100'. Circ. btms. up w/ reduced pump rate for laminar flow. CO old hole. Drlg. from 5100' to 5218'. Circ. btms. up. Pooh. Repaired pump. (Footage 0') Comp. repairs on mud pump. Slipped drlg. line. TIH w/ 6 1/8" bit to 5216'. Had 2' of fill. Drlg. from 5218' to 5404'. Circ. btms. up. Pulled to csg. shoe. Ran back to 5404'. Circ. hole clean for logs. Dropped. survey. Pooh. DEC ! ! 197 DIV!SION OF OII. AND GAS ANCI"iORAGIE -. UNION OIL CC P 4Y OF CALIFORNIA. I ECORD PAGE LEASE KENAI UNIT l'~Lg NO, #14-6 FIELD KENAI GAS FIELD DATE 9/30/74 10/1/74 10/2/74 10/3/74 10/4/74 10/5/74 10/6/74 10/7/74 10/8/74 ETD 15,047'TD 4,949'ETD 15,047'TD 5,310'ETD 15,047'TD 5,310'ETD 15,047'TD 4,750'ETD 15,047'TD 4,919'ETD 15,047'TD 4,694'ETD 4,895 'TD 4,710'KOP 5,058'TD 4,710'KOP 5,280'TD 4,710'KOP DETAILS OF OPERATIONS, DESCRIPTIOHS & RESLILTS (Footage 0') RU Schlumberger. Ran FDC, 'CNL & GR Logs from 5404' to 4200'. RD Schlumberger. TIH w/ OEDP to 5404'ETD. Circ. hole clean. Mixed & spotted 100 sx. of Class "G" cmt. w/ 0.5% D-19 & 10% Sd. Pooh. WOC TIH w/ 6 1/8" bit. Tagged hard cmt. @ 4949'. (Footage 0') Drlg. firm. cmt. from 4949' to 5310'. Circ. & cond. mud to run 5" liner. Winds gusting 60 MPH. WOW 9 hrs. Pooh. (Footage 0') Pooh. RU Go-Int'g. Logged btm. of 7" csg. & line @ 4400'. RD Go-Int'l. RU & ran 16 jts. of 5" 18# N-80 Hydril FJ-p csg. w/ BOT hyd. liner & screw set pkr. Circ. while RIH @ 1600', 2600', 3600' & 4600'. Circ. csg. dwn. in open hole from 4700' to 5161'. Csg. stopped @ 5161', lower csg. hanger slips sheared. Pooh w/ 5" liner. Left in hole 11 5" X 6 1/2" centralizers & rubber from screw set pack-off. TIH w/ 6" bit. (Footage 0') TIH w/ 6 1/8" bit. Found top of centralizers @ 4916'. Unable to move dwn. hole. Circ. & cond. mud. Pooh. TIH w/ OEDP to 4903'. Mixed & laid 35 sx. of Class "G" cmt. w/ '0.5% D-19 & 10% nut plug. Pulled up to 4620'. Circ. & cond. mud. Pooh. Estimated top of plug @ 4750'. (Footage 0') .Ran 6 1/8" OD tapered mill. Dressed out C-1 Sd. perfs, from 4455' to 4590'. Ran 6 1/8" bit #7 on 5" OD w/ 2~ kick sub. Tagged top of cmt. @ 4721'. Dress off plug to firm cmt. @ 4778'. DD to 4784'. Broke thry. DD to 4905'. Bit locked. Pooh. Had junk fouled in bit. Laid dwn. DD. Ran 6 1/8" bit #8 on angle building assy. Drlg. from 4905' to junk @ 4916'. Drlg. junk to 4919'. Junk trying to stick DP. (Footage 0') Pooh. Ran 60' of tbg. stinger on 3 1/2" DP open to 4903'. Batch mixed 50 sx. of Class "G" cmt. w/ 10% sd. to ll9#/cu, ft. Spotted cmt. plug in open hole. Pooh w/ DP. (Footage 185') Ran 6 1/8" bit #9 on 5" OD. DD w/ 2° kick sub. Tagged cmt. @ 4694' & dressed off to firm plug @ 4710'. Sidetracked well w/ DD @ 4710'. DD to 4827'. Ran survey 2 1/2° . DD to 4832'. Pooh. Laid dwn. DD. Ran 6 1/8" bit #10 on angle building assy. Drlg. from 4832' to 4897'. (Footate 163') Drlg. tripped & surveyed from 4895' to 5058'. (Footage 222') Drlg. & tripped from 5058' to 5280'. DI~$1~,N CF 01t. AND ~A$ AA!CHORA~F. I011 OIL COFIPANY OF CALIFORNIA I LCORD ['AGE 5 LEASE KENAI UNIT I,~LL NO, #I4-6 FIELD KENAI GAS FIELD DATE 10/9/74 10/10/74 10/11/74 10/]2/74 DEC '] DIVISION OF o1 ANCHORi ]o/13/74 ETD · DETAILS OF OPERATIONS, DESCRIPTIOIIS-& RESt. II_TS 5,345'TD 5,291'ETD 5345'TD 5288'ETD 5345'TD 5288'ETD 5345'TD 5291'ETD AND GA'~ 5345'TD 5288'ETD (Footage 65') Drlg. from 5280' to 5345'. Made wiper trip & Pooh to run 5" liner. Survey @ 5345'-3 1/2° . RU & ran 5" 18# Hydril FH-P Liner on 3 1/2" DP & set @ 5337'. Checked top of liner @ 4593' (3' below C-1 Sd. perfs.) Hung off 5" liner @ 4593' . (Footage 0') Circ. btms. up. Batch mixed 90 sx. Class "G" w/ 5% D-19. Pumped 50 cu. ft. H20, 102 cu. ft. cmt. & 20 cu. ft. H20. Displ. w/ 43 bbls WO fluid. Got indication of shear out on liner wiper plug. Failed to latch up on calculated displ. Pumped 1 additional bbl. & shut dwn. CIP @ 1:30 am. Set mechanical pkr. on liner top. Pooh. PU BHA #9. TIH to 3035' w/ 6 1/8" bit. 12 hrs. WOC. CO to top 5" liner @ 4593'. No cmt. Circ. btms. up & Pooh. PU 8-3 1/4" DC & 4 1/8" bit & 5" csg. scraper + 30 jts. 2 7/8" DP. TIH. Tagged top of cmt. @ 5150' (15 cu. ft. cmt. in liner) CO firm cmt. to 5202'. (Footage 0') Pooh. Checked out meas. on DP. TIH w/ bit #16. Drlg. cmt. from 5202' to 5288' (top of Id. collar-DPM). Circ. btms. up. Pooh. RU Go-Int'l. Ran Neutron CBL Log from 5291'WLM Id. collar to top of 5" liner @ 4593'. No bond between "C" Zone & Beluga Sds. Perforated from 4656' to 4658' FDC-Neutron meas. for Block sq. #1. Ran 5" Baker fullbore pkr. on 2 7/8" DP stinger (27 its.) & 3 1/2" DP. Set tool @ 4698' & tested csg. to 2000 psi-ok. Reset tool @ 4610'. Broke dwn. perfs, from 4656' to 4658' w/ 1500 psi. PI 17 cfm @ 1200 psi. Batch mixed 100 sx. Class "G" cmt. w/ .5% D-19 & 10% sd. 120#/cu. ft.-Displ. 95 sx. below tool to a final press, of 1500 psi. Bleed off to 1250 psi. Released 'tool & Pooh. CIP @ 11:00 pm. (Footage 0') Pooh w/ 5" sq. tool. Ran 6 1/8" bit & scraper to top of 5" liner @ 4593'. (no cmt. on top of 5" liner). Pooh. Ran 4 1/8" bit & scraper to top of Id. collar @ 5291' No cmt. in 5" liner. Pooh. RU Go-Int'l & reran CBL Log from ETD @ 5291' to top of 5" liner @ 4593'. Had good bonding between "C" Zone & Beluga Beluga Sds. w/ 3 1/8" cased carrier from 5085' to 5103' & from 5175' to 5195'-Schlumberger FDC-Nuetron 9/30/74. 5076' to 5096' & 5168' to 5188' Go-Int'l CBL #2 10/12/74. Ran Howco DST tool #1. Ran DP Dry. (Footage 0') Set tool @ 5043'. Charged DP w/ 1000 psi gas press. Opened tool @ 6:02 am w/ surface closed in. Surface press, inc. to 1600 psi-5 mins. Opened surface valve in 1/2" choke & flowed well. Fluid to surface @ 6:13 am @ 1050 psi. SI @ 6:37 am for ISIP w/ll00 psi. Reopened tool @ 7:38 am w/ 1550 psi on 1/2" choke. 8:00 am turned flow into test seperator. Rate - 6.75 mmcf, 10:00 am flowing w/ 1275 psi on 1/2" choke-changed to 3/8" choke & flowed well @ 1675 psi.-rate 4.8 mmcf for 24 hrs. 12:00 Noon changed to 1/4" choke & flowed well @ 1975 psi-rate 2.12 mmcf- 1.9 mmcf. SI surface @ 2:00 pm. Press. inc. to 2050 psi in 30 mins 2:30 pm. SI tool for final build-up Released pkr. @ 9:00 pm. Rev. out gas cut mud @ 5225'DPM & Pooh. (final flow time 6 hrs. 22'mins. Total test time 14 hrs. & 56 mi. ns.) OIL CC ANY OF CALIFORNIA 'LLL I ECOt D [~AGE fk), ':L[~[ KENAI UNIT l'~_LL NO, #14-6 FIELD KENAI GAS FIELD DATE 1.0/114/74 10/15/74 10/16/74 10/17/74 10/18/74 ETD 5345'TD 4750'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD DETAILS OF OPERATIONS, DEscRIPTIOtlS g RESUI_TS (Footage 0') Pooh w/ 5" DST tool #1. DST Charts-Beluga Zone perfs. IHH-2604 psi, IFP-1748 psi, ISIP-2286 psi, IFFP-1724 psi, FSIP-2286 psi, FHH-2604 psi. RU & perf. the C-2 Sd. 4630'- 4650'FDC meas. using a 3 1/8" csg. carrier in original hole. Ran Baker 5" RBP on DP & set @ 4750' above Beluga Sds. Ran 5" Howc° DST #2 on dry DP & set @ 4615'. Press. DP to 1100 psi & opened test tool @ 3:15 pm. Cleaned up well on 1/2" choke. Put well into test seperator @ 6:30 pm for production test. 1/2" choke 590 psi 5/8" choke 3/8" choke 940 psi 1/4" choke 1375 psi 2.7 mmcf/d no cut. 2.9 inc. to 3.8 mmcf/d 3.2 mmcf/d no cut. 1.5 mmcf/d no cut. no cut. (Footage 0') Completed DST #2 on C-2 Sd. perfs 4630'-4650' DIL or FDC meas-. Final flow rate 3/8" choke, 3.19 mmcf/d @ 940 psi. 2 hr. flow test on 1/4" choke, 1.5 mmcf/d @ 1375 psi. SI well @ 3:10 am for 9 hrs. final SI period. Released test tool @ 12:01 pm. Rev. out gas & Pooh w/ DST tool. Ran Baker retrieving tool. Tagged 5" RBP @ 4750' & PU same. Pooh. Lost 5" RBP while Pooh. RU WL & checked RBP @ 4643'. Reran Baker retrieving too].. Unable to pick-up 5" RBP @ 4643'. Pooh. (Footage 0') Ran 4 1/8" OD OS w/ 2" grapple. Chased 5" RBP to ETD @ 5283'DPM. Pooh w/ OS-no rec. Reran Baker retrieving tool Had to work thru tight 7" csg. @ 4552'. Worked by junk in 5" csg. @ 4643'. Latched 5" RBP @ 5283'. Pooh. Rec. 5" RBP w/ 3 pieces of metal junk on top of RBP. (configuration of 7" csg.) RU Go- Int'l. perf. the Beluga Zone 5139'-5149', 4960'-4970', 4856'-4868', & from 4788'-4808'DIL-FDC. Perf. the "C" Zone (C-2 Sd.) from 4615'-4630 'DIL-FDC. (Footage 0') Set 5" RBP @ 5000' & Howco 5" DST tool @ 4715' for DST #3 on Beluga Sd. perfs 4788'-4808', 4856'-4868' & from 4960'- 4970'DIL meas. Charged dry DP w/ 975 psi gas press. Opened tool @ 3:23 am for IFP. Surface press, inc. to 1110 psi. Opened surface valve @ 8:35 am. Rathole fluid to surface @ 8:50 am. SI well @ 9:05 am for 1 hr. ISIP. Reopened tool @ 10:05 am. Cleaned up well & stabilized' flow rate for production test. 2 hrs. 1/2" choke 710 psi 3.85 mmcf/d no cut. 2 hrs. 3/8" choke 1050 psi 3.22 mmcf/d no cut. 2 hrs. 1/4" choke 1400 psi 1.80 mmcf/d no cut. (Footage 0') Completed FSI on DST #3 (Upper Beluga Zone). Rev. out gas in DP. Released tool @ 5:00 am, 10/18/74. Ran to 4945' & circ. btms. up. Pooh w/ DST tool.. Ran Baker 5" retrieving too]. Had 45' of sd. fill on top of RBP @ 5000'. Washed to top of RBP @ 5000' & Pooh w/ RBP. Set 7" RBP @ 11500'. Removed BOPE to change out tbg. head. *NOTE: See attached sheet- DST #1, #2 ~~.~~ ~~ SI 11t:'I' l] I'AGE UNION OIL CCFPANY OF CALIFORNIA I',ELL I ECOI LF. ASE KENAI UNIT I'ZLL 1,10, #z4- FIELD KEN^I GAS FIELD DATE ETD DETAILS OF OPERATIONS,, DESCRIPTIOriS & RESUI_TS 10/19/74 10/20/74 10/21/74 10/22/74 10/23/74 10/24/74 10/25/74 10/26/74 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD 5345'TD 5291'ETD (Footage 0') Completed installed dual tbg. head & x-over spool. Installed & tested BOPE to UOCO specs. Retrieved 7" RBP @ 1500 psi. Ran 4 1/8" bit & scraper to ETD @ 5291' Had 12' sd. fill on btm. Pooh. Laid dwn. 3 1/2" DP & collars. (Footage 0') Installed dual tbg. rams (2 7/8" X 2 7/8") RU to 2 7/8" X 2 3/8" dual tbg. string w/ BOT hyd. pkr. (Footage 0') Completed running dual string 2 7/8" & 2 3/8" tbg. LS - 141 its 2 3/8" 4.6 Armco-Sealock. SS - 138 its 2 7/8" 6.4 + 1 it. 2 3/8" 4.6# Sealock Buttress. Spaced out tbg. w/ 5" X 2 3/8" BOT. H-1 RSP pkr. @ 4763' & 7" X 2 3/8" X 2 3/8" BOT Husky H-2 pkr. @ 4390'. RU WL Otis unit & ran setting plug on LS tbg. Unable to get plug thru pkr. bore. Plug OD 1.875 pkr. bore 1.685'. RD Otis WL unit. Removed BOPE & installed dual 2 7/8" X 2 3/8" x-mas tree. RIG RELEASED TO STAND-BY @ 12:00 PM, 10/21/74. (Footage 0') Worked crews until noon 12/22/74. Drillers only from 12:00 noon, 10/22/74. RU Go-Int'l. Ran Magna-Range BP 1,468 OD in LS tbg. & set'@ 4733' tbg. measurement. Press. LS to 3500 psi & set BOT sgl. hyd. pkr. @ 4721'. Ran tbg. puncher & perf. tbg. tail belo~v.pkr, from 4731'-4733'-8-1/4" holes. RD Go-Int'l. RU Otis WE unit. (Footage 0') Displ. annulus w/ inhibited ~vtr. for pkr. fluid. (Footage 0') Production testing LS Beluga Sds. @ 5.7 mmcf/d w/ no cut. TP - 1160 p.si. (Footage 0') Production testing LS Beluga Sds. @ 7.81 mmcf/d w/ 18 BWDP - no sd. TP - 1125 psi. (Footage 0'). Released rig from Stand-by Rate to Turnkey R-ig Move @ 12:00 Noon, 10/26/74. [~AGE UNION OIL COttPA fF OF CALIFORNIA I, ELL I LCOt LE~SE KENAI UNIT l'~_ N0, #14-'6 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIOI'IS & RESULTS JTS. 137 141 TUBING DETAIL LONG STRING DESCRIPTION LENGTH BOTTOM TOP Otis 2 3/8" N-Nipple ID 1.875. 1.73 2 3/8" 4.6# SL Pup Sub 8.08 2 3/8" SLX 2 3/8" EUE X-over .62 BOT 5" X 2 3/8" H-1 RSP Hyd. pkr. ID 1.685' 4.47 2 3/8" SLX 2 3/8" EUE X-over .62 2 3/8" 4.6# N-80 SL Tbg. 63.24 2 3/8" SLX 2 3/8" EUE X-over 11 Blast Jts. 2 3/8" SLX 2 3/8" EUE X-over .62 2 3/8" 4.6# N-80 SL Tbg. 31.72 2 3/8" Otis X-O Sleeve 3.43 2 3/8" SLX 2 3/8" EUE X-over .68 BOT 7" X 2 3/8" X 2 3/8" Hyd. Husky H-2 2' 3/8" SLX 2 3/8" EUE X-over 2 3/8" 4.6# N-80 SL Tbg. 2 3/8" Otis X-O Sleeve 2 3/8" 4.6# N-80 SL Tbg. 2 3/8" 4.6# SL Pup Sub 2 3/8" 4.6# SL Pup Sub. 2 3/8" 4.6# SL Pup Sub. 2 3/8" 4.6# SL Pup Sub. 2 3/8" SLX 2 3/8" EUE X-over .88 Cameron 2 3/8" EUE Tbg. .Hanger .90 Elevation Tbg. Hgr. to RT. 15.82 .68 223.49 6.05 .62 31.42 3.55 4315.62 8.01 6.OO 6.00 2.00 4736.26 4734.53 4734.53 4726.45 4726.45 4725.83 4725.83 4721.36 4721.36 4720.74 4720.74 4657.50 4657.50 4656.82 4656.82 4433.33 4433.33 4432.71 4432.71 4400.99 4400.99 4397.56 4397.56 4396.88 4396.88 4390 83 4390 21 4358 79 4355 24 39 62 31 61 25 61 19 61 17.61 1.6.72 15.82 4390.83 4390.21 4358.79 4355.24 39.62 31.61 25.61 19.61 17.61 16.72 15.82 --0-- Total Jts. 2 3/8" 4.6# N-80 Armco Seal Lock w/ Sp-cl Collars. PAGE UN I Ol'l 01L CeIPANY OF CALI FORNIA lfELL I ECORD LF E KENAI UNIT I'~LL NO, # 14- 6 FIELD KENAI GAS FIELD DATE ETD JTS. 10 DETAILS OF OPERATIONS, DESCRIPTIOI.IS g RESUI_T$ TUBING DETAIL SHORT STRING DESCRIPTION BOTTOM TOP Otis 2 3/8" N-Nipple ID 1.875 1.73 2 3/8" 4.6# Seal Lock Pup Sub. 8.10 2 3/8" SLX 2 3/8" EUE X-over .68 BOT 7" X 2 3/8" X 2 3/8" Hyd. pkr. 6.45 2 3/8"'SL X 2 3/8" EUE X-over .62 2 3/8" SL 4.6# N-80 Tbg. 31.20 2 3/8'" SL 4.6# N-80 Pup Sub 4.03 2 3/8" SLX 2 7/8" Butt X-over .62 2 '7./8" 6.4# N-80 Butt. Tbg. 31.48 Otis 2 7/8" XO Sleeve IS 2.313 3.80 2 7/8" 6.4# N-80 Butt. Tbg. 297.26 2 7/8" 6.4# N-80 Butt. Pup SUb. 6. O5 2 7/8" 6.4# N-80 Butt. Tbg. 29.48 2 7/8" 6.4# N-80 Butt. Pup Sub. ' 6.16 2 7/8" 6.4# N-80 Butt. Tbg. 148.57 2 7/8" 6.4# N-80 Butt. Pup Sub. 10.19 2 7/8" 6.4# N-80 Butt. Tbg. 185.83 2 7/8" 6.4# N-80 Butt. Pup Sub. 10.24 2 7/8" 6.4# N-80 Butt. Tbg. 238.28 2 7/8" 6.4# N-80 Butt. Pup Sub. 6.10 2 7/8" 6.4# N-80.Butt. Tbg. 60.03 2 7/8" 6.4# N-80 Butt. Pup. Sub. 6.15 2 7/8" 6.4# N-80 Butt. Tbg. 118.87 4407.65 4405.92 4397.82 4397.14 4390.69 4390.07 4358.87 4354.84 4354.22 4322.74 4318.94 4021.68 4015.63 3986.15 3979.99 3831.42 3821.23 3635.40 3625.16 3386.88 3380.78 3320.75 3314.60 4405 92 4397 82 4397 14 4390 69 4390 07 4358.87 4353 84 4354 22 4322.74 4318.94 4021.68 4015.63 3986.15 3979.99 3831.42 3821.23 3635.40 3625.16 3386.88 3380.78 3320.75 3314.60 3195.73 Continued ..... UNION OIL COHPAIfF OF CALIFORNIA ,LLL I ECOID St I!:[..1 I; F"XGE Ilo, 10 LEASE KENAI UNIT I,~LL NO, #14-6 FIELD KENAI GAS FIELD DATE ETD Cont... JTS. 12 12 13 16 138 DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESUI_TS DESCRIPTION TUBING DETAIL SHORT STRING LENGTH BOTTOM TOP 2 7/8" 6.4# N-80 Butt. Pup' Sub. 14.78 2 7/8" 6.4# N-80 Butt. Tbg. 366.88 2 7/8" 6.4# N-80 Butt. Pup Sub. 6.10 2 7/8" 6.4# N-80 Butt. Tbg. 89.75 2 7/8" 6.4# N-80 Butt. Pup Sub. 8.10 2 7/8" 6.4# N-80 Butt. Tbg. 147.28 2 7/8" 6.4# N-80 Butt. Pup Sub. 10.12 2 7/8" 6.4# N280 Butt. Tbg. 61.14 2 7/8" 6.4# N-80 Butt. Pup, Sub. 8.10 2 7/8" 6.4# N-80 Butt.. Tbg. 119.16 2 7/8" 6.4# N-80 Butt. Pup Sub. 15.60 2 7/8" 6.4# N-80 Butt. Tbg. 354.12 2 7/8" 6.4# N-80 Butt.' Pup Sub. 15.05 2 7/8" 6.4# N-80 Butt. Tbg. 393.49 2 7/8" 6.4# N-80 Butt. Pup Sub. 15.09 2 7/8" 6.4# N-80 Butt. Tbg. 237.59 2 7/8" 6.4# N-80 Butt. Pup Sub. 14.98 2 7/8" 6.4# N-80 Butt. Tbg. 206.33 2 7/8" 6.4# N-80 Butt. Pup Sub 10.12 2 7/8" 6.4# N-80 Butt. Tbg. 243.81 2 7/8" 6.4# N-80 Butt. Pup Sub .. 14.75 2 7/8" 6.4# N-80 Butt. Tbg. 150.54 2 7/8" 6.4# N-80 Butt. Pup Sub 14.85 2 7/8" 6.4# N-80 Butt. Tbg. 479.21 2 7/8" 6.4# N-80 Butt. Pup Sub. 10.05 2.7/8" 6.4# N-80 Butt. Tbg. 147.68. 2 7/8" 6.4# N-80 Butt. Pup Sub. 14.95 2 7/8" 6.4# N-80 Butt. Pup Sub. 9.39 'Cameron 2 7/8" Butt. X 2 7/8" EUE' Tbg. Hgt. .90 Elevation RTto Tbg. Hgr. 15.82 TOtal Jts. 3195.73 3180.95 3180.95 2814.07 2814.07 2807.97 2807.97 2718.22 2718.22 2710.12 2710.12 2562.84 2562.84 2552.72 2552.72 2491.54 2491.54 2483.48 2483.48 2364.32 2364.32 2348.72 2348.72 1994.60 1994.60 1979.55 1979.55 1586.06 1586.06 1570.97 1570.97 1333.38 1333.38 1318.40 1318.40 1112.07 1112.07 1101.95 1101.95 858.14 858.14 843.39 843.39 692.85 692.85 678.00 678.00 198.79 198.79 188.74 188.74 41.06 41.06 26.11 26.11 16.72 16.72 15.82 137 jts. 2 7/8" 6.4# N-80 Buttress Sp-clI~IV:$1ON 1 jt. 2 3/8" 4.6,~ N-80 Seal Lock. 138 TOTAL JTS. SHORT STRING: A. 2 7/8" XO Sleeve D 4319' ID 2.31~ B. X'Over 2 7/8"-2 3/8" @ 4354'. C. Brown 7" Dual-Pkr. D 4390'. D. 2 3/8" N Nipple, Btm. @4408' ID 1. 875 LONG STRING: 1. 2 7/8" XO Sleeve 04355' ID 1.87~-.., 2. Brown 7" Dual pkr. @ 4390'. 3. 2 3/8" XO Sleeve @ 4398' ID 1.875 4. Blast Jts. @ 4433'-4657'. 5 Brown 5" H-1 Pkr. @4721'. ID 1 685 · . 6. 2 3/8" N Nipple, btm. @4736'~ ID 1.87 Tbg. Hgr. 15.82' 20" Csg. 0 60' 13 3/8" 61'#,54.5# Csg. (~3078'. A 7" X 2 3/8" X 2 3/8" Brown Pkr. (04390' 5,, 18~ Liner top ~a aSoq, 7" 26.4#csg. 046].8'. 5" X 2 3/8" Bornw H-] RSP Hyd. Pkr. @47I]' COMPLETED SCHEMATIC YU #1 Started 9/20/74 Deepening Completed 10/23~74. AFE NUMBER' TOTAL COST- TOTAL SPENT' 341112 $327,000 $414,495 10-30-74 WORKOVER-SUbI~L~RY KU 14-6 PURPOSE' Clean out cement plug, run liner and complete as a dual C-I, C-2 (new sand) and Beluga (new sand) gas producer. .SU~D'~RY OF RESULTS' The C--2 sand should .produce approximately 2.5 mmcf/d into the sales system based on the DST data.. No sand fill was encountered from the prior producing C-1 sand and the Pool 6 (C-1 and C-2 sands) was not treated for sand control. As of Oct. 29 the short string had not been returned to production. The Beluga completion was successful in establishing new zone production at the rate of 7.8 mmcf/d. Additional reserves of 26.5 BCF are estimated to be recoverab!e from the Beluga in KU 14-6 if it is developed on 320 acre spacing. Minimum total development of tke Beluga in the Kenai Gas Field will require nine new wells. SUb~L~RY OF WORKOVER' The completion of the Beluga between 4788'-5195' required drilling out the cement plug below the casing show at 4618'. A.cement plug was set from 5310'5404'. Centralizers were stripped off the 5" liner while attempting to run the liner in the old hole. After retrieving the liner the well was plug~edo back to 4721' without recovering the centralizers. After redrilling to 4919' the old hole was encountered and the redrilled hole was plugged back to 4710'. Redrilling to 5345' was' completed and the liner run with the liner top at 4593' (3' below the C-1 perforations and 25' ~bove the casing show). The cement was cleaned out of the liner to 5291' The liner was perforated from 4656' to 4658' and squeezed f~r isolation between the C-2 and Beluga sands. The Beluga was perforated from 5083'-5103' and 5175'-5195'. The DST of these sands produced 6.75 mmcf/d a~ainst a 1275 psi surface pressure. Additional sand. at 5139 %5149 was pe~orated but not te~ted. Beluga sands from 4788~4808', 4856'£4868' and 4960'74970' were perforated. A DST of these three sands produced 3.22 mmcf/d against a 10S0 psi surface pressure. The DST of the Upper Beluga interval included an excessive drawdown and 45' of sand entry occurred. Sand conso!idation of these sands was not performed. The sltut-~n pressures in these two DST's were 2282 psi and. 1.900 psi respectively. The pressure gradient to the lower the Upper Beluga sands was about 225 ps~ below Summayy of ~7orkove.r The estimated total delivery from the Beluga thru the 3-1/2" drill pipe and down hole choke into the sales system is 10 mmcf/d. the rate on October 2'7th was ?.8 mmcf/d when producing thru the 2-3/8" tubing. The C-2 sand'of Pool 6 was perforated from 4630'-46S0'. A DST of this interval produced 3.22 mmcf/d against a 940 psi surface pressure.- The indicated reservoir pressure in the C-2 sand, 1650 psi, is essentially the same as the C-1 reservoir pressure but 430 psi less than the original Pool 6 reservoir pressure. The calculated delivery from this interval against the sale system pressure is 2.6 mmcf/d. An additional 15' of the C-2 sand was perforated from 461S'-4630'; KU 14-6 was completed with 2-?/8" tubing string for C-l, C-2 production and a 2-3/8" tubing string for Beluga production. DI~.$1OI,t C,I: OIL AND GAS Atq~HORA~ PRODUCTION TEST AFTER WORKOVER KU 14-6 DATE . lO/2~ lO/2~ POOL 6 MMCF/D BWPD BELUGA I~4CF / D BWPD 5.7 7.81 PRODUCTION SUMMARY MONTH JANUARY FEBRUARY MARCH APRIL MAY JUNE JULY AUGUST SEPTEMBER WORKOVER POOL6 ~ICF/D 12.79 15.15 12.15 12.47 12.40 12.45 11.54 11.56 10.62 9-22-74 TO BELUGA M~CF/D 10-25-74 DEC DIVt$1¢,I'~ ,~.I: OIL AND (}AS ANCHORAGE KU #14-6 COMPLETIONS Converted KU #14-6 from a sgl. G-1 Zone gas producer to a dual C-l, C-2 & Beluga gas prodUcer. Commenced WO operations @ 3:00 pm, 9/22/74. 1. Rigged up over well & killed w/ 73#/cu. ft. salt wtr. 2. Removed x-mas tree. Installed & tested BOPE. 3. Pull. ed & laid dwn. sgl. 2 7/8" tbg. strings. 4. Milled over & retrieved sgl. perm. pkr. @ 4406'. 5. Drilled cmt. & csg. shoe from 4611'-4618'. 6. RIH FDC, CBL & GR Logs from 5404'-4200'. 7. TIH w/ OEDP to 5404'ETD. Laid cmt. 'plug w/ 100 sx. of Class "G" cmt. 8. Drilled out cmt. from 4949'-5310'. 9. Ran ].6 jts. of 5" 18# N-80 Hydril FJP Liner. Stopped @ 516]'. Pooh. Left 11 centralizers in hole. Unable to CO junk. 10. TIH w~ OEDP to 4903'. 11. Laid cmt. plug w/ 35 sx. of Class "G" cmt. 12. TIH w/ 6 1/8" bit. Tagged cmt. @ 4723'. CO to 4919'. Hit junk from centralizers. 13. Spotted 50 sx. of Class "G" cmt. from 4919' to 4694'. 14. Dressed off cmt. plug from 4694' to 4710'. 15. Sidetracked ho!c w/ DD from 47!0'-4~2'. 16. Drlg. from 4832'-5345~. 17. Ran 5" 18# liner on BOT 5" X ?" Liner hanger w/ screw dwn. & cmt'd, w/ 90 sx. Class "G" cmt. · 18. Perf. Beluga Sd. from 5083'-5103' & from 5175'-5195'. 19. Set DST tool & ran three pt. production test. 20. Perf. the C-2 Sd. from 4630'-4650'. 21. Set DST toot & production tested. 22. Perf. additional Beluga Intervals from 5139'-5149', 4960'-4970', 4850'-4868', & 4788'- 4808'. 23. DST Beluga Intervals from 4960'-4970', 4856'-4868', 4788'-4808'. 24. CO well to 5291' 25. Rigged up & ran dual 2 7/8" X 2 3/8" tbg. strings as programed. 26. Set 5" sgt. hydraulic pkr. @ 4721' & 7" dual h. yd. pkr. @ 4390'. 27. Installed & tested x-mas tree. 28. Set & tested pkrs. 29. Released KU #14-6 as a dual C-I, C-2 & Beluga gas producer. RELEASED RIG @ 12:00 NOON, ].0/26/74. ~ ~o. r~ STATE Or'ALASKA I~EV. B- I-?0 OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS 1. ~' [:LL w[:LL OTHER ~'. NAME OF OP]gR.ATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 4 LOCATION OF WELL SUBMIT lin ECtYPLICATE ~ APl NUAfERICAL CODE 99501 ~ LEASE DESIGNATION AND SEHIAL NO. A-028142 · ? IF INDIAI~'. ALOTTEE OR TRIBE NAME 8 L.~IT FAtal OR LEASE NAME Section 6: T4N, RllW, S. M. NOV 12 PF'~RMIT NO ~!v.,'~(.~,,, . ~- ~lL a~ t-.A! 68-5 SET A~ VOL~S USED. P~OF~TIONS. T~STS ~u ~-U~l%J,i~.~ ~D ~Y 0~ SIGNIFIC~ ~G~ ~ HO~ ~ITIO~S Kenai Unit 9 WELl, NO KU #14-6 f~ D 10 FIF~J.,D AND POOL. OR WI'LDCAT Kenai Gas Field oB.rgcTrvE) Section 6: T4N, R llW, S.M. RU Schlumberger. Ran FDC, CNL & GR Logs ·from 5404'-4200'. TIH w/ @EDP to 5404'ETD. Mixed & spotted 100 sx. of Class "G" cmt. w/ 0.5% D-19 & 10% Sd. Pooh. TIH w/ 6 1/8" bit. Drlg. hard cmt. from 4949'-5310'. Pooh. RU & ran 16 jts. of 5" 18# N-80 Hydril FJP csg. w/ BOT Hyd. Liner & screw set pkr. Liner stopped @ 5161'. Pooh w/ liner. Lost 11 centralizers in hole. TIH w/ 6 1/8" bit. Found top of centralizers @ 4916' Unable to move dwn. hole. Pooh. TIH w/ @EDP to 4903'. Mixed & laid 35 sx. of Class "G" cmt. w/ 0.5% D-1.9 & 10% nut plug. Pooh. Ran 6 1/8" bit on DP. Tagged top of cmt. @ 4721'. CO plug to 4919' Hit junk. Pooh. RIH w/ @EDP. Mixed & spotted 50 sx. of Class "G" cmt. w/ 10% sd. Pooh. RIH w/ 6 1/8" bit on DP. Tagged firm cmt. @ 4494' & dressed off cmt. plug to 4710'. Sidetracked well @ 4710'. DD 4710'-4832'. Pooh & laid dwn. DD. TIH w/ 6 1/8" bit. Drlg. from 4832'-5345'. Made wiper trip. Pooh. RU' & ran 5" 18# Hydril FJP Liner on 3 1/2" DP. Hung off liner @ 4593' w/ shoe @ 5337'. Cmt'd liner w/ 90 sx. Class "G" cmt. Pooh w/ setting tool. TIH w/ 6 1/8" bit to top of liner @ 4593'. Pooh. TIH w/ 4 1/8" bit. Tagged cmt. @ 5150'. CO cmt. from 5150' to LD collar @ 5291'WLM. Ran Neutron CBL-VD Log from ETD to top of 5" liner @ 4593'. Perf. 5" liner from 4656'-4658'. RIH w/ 5" sqz. tool & set @ 4698'. Tested 5" liner to 2000 psi. Re-set tool @ 4610' & sqz. 95 sx. Class "G" cmt. below tool to a final press, of 1500 psi. TIH w/ 4 1/8" bit & CO well to 5291'ETD. Reran CBL-VD Log. Perf. the Beluga Sd. from 5083'-5103' & from 5175'-5195'. TIH w/ DST tool & set @ 5043'. Opened tool. Cleaned up well & ran 3 pt. production test. 1/2" choke 1275 psi 6.8 mmcf/d no cut. 3/8" choke 1675 psi 4.8 mmcf/d no cut. 1/4" choke 1975 psi 2.2 mmcf/d no cut. ~'"'~ ~°' ~"-~ STATE O~-~J. ASKA REV. ~- I-?O OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 1. WKLL WELL 2. N'AMK OF OP~:LATOR SUBMIT IN DUPLICAT~ 3. ADDRE-~S OF O'~"~'OR '4. LOCATION OF W~ APl NU~EI~ICAL CODE 6 LF_~ASE DESIGI~A'I~ION A%'D SEHIAL NO. ? IF INDIALF. ALOTT~E OR TRIBE NAME 8, L.~IT FARM OR LEASE NAJ~E 9 WELL NO NOV ! 1 DIVISION ~F OIL AND OAS ,2 ~T~O ~3. R~ORT TOTAL D~ AT ~D OF MON~. C~N~~~, CASING A~ C~rZNG JOBS INCLUDING SET ~ VOL~ US~. P~O~TIONS, ~TS ~ ~SULrS F[SHI~TG JO~ J~K ~ HO~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ ~O~ ~ITIONS ].o F~J -,~.-~D ,ooL. OR Wm~JCAT i~ SEC. T.. R., ~t. (~m'roM HoL,E oaJ~-~ Final surface SI 2050 psi. Rev. out. Pooh. Perf. the C-2 Sd. from 4630'-4650'. Ran & set 5" RBP @ 4750'. RIH w/ DST tool & set @ 4615'. Opened test tool. Cleaned up well. Put well on production test. 1/2" choke 590 psi 2.7 mmcf/d no cut. 3/8" choke 940 psi 3.2 mmcf/d no cut. 1/4" choke 1375 psi 1.5 mmcf/d no cut. Rev. out. Pooh.. Retrieved 5" RBP. Perf. the Beluga Zone from 5139'-5149', 4960'-4970', 4856'-4868' & from 4788'-4808'. Perf. the C Zone (C-2 Sd.) from 4615'-4630'. Ran & set 5" RBP @ 5000'. RIH w/ DST tool & set @ 4715'. Prod. tested the Beluga perfs. 4788'-4808', 4856'-4868' & from 4788'-4808'. 1/2" choke 710 psi 3.85 mmcf/d no cut. 3/8" choke 1050 psi 3.22 mmcf/d no cut. 1/4" choke 1400 psi 1.80 mmcf/d no cut. Rev. out. Pooh. Retrieved. RBP @ 5000'. Set 7" RBP @ 1500'. Changed out tbg. head for dual tbg. head. Installed & tested BOPE. Made bit & scraper run to 5291'. RU & ran dual 2 7/8" X 2 3/8" tbg. strings as programed w/ 5" sgl. hyd. pkr. @ 4721' & 7" dual hyd. pkr. @ 4390'. Removed BOPE. Installed & tested x-mas tree. Set & tested pkrs. RELEASED RIG @ 12:00 NOON, 10/26/74. FINAL REPORT 14. i hereby that tl}e for;.~in~e~true.and correct ...... · - - ~ ~ [~'/~'~,-"~'-~-," Dist Drlg. Supt 11/10/74 NOTE--Report on this f~ is required for each calendar ~nth% regardless of Ihs Status of operations, and must ~'tiled in dupli~te with the oil and gas conservat{on commi~ee bythe IS~ of the euee~ding mon~, ~le~ otherwise dSrected. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~'~orm approve~. Budget Bureau No. 42-R356.5. ................ ...... ................ · , ,.:u. s. NI EE,S MONTHLY REPORT OF OPERATIONS Ai,,.C,4i© R,:--.~E The following is a correct report of operatior~s and prod~etior~ (ineludinff drillin6~ and produein~ wells) for th.e month of ......... .O_.c..t_.o..b..e__r.. ................. ,19...7..4_, ............................................................................ ,g~ e ~ t' s address .............. ........... Oo m p a y ....................................... .A~13~q~.9_r_..B_g_e_.t_.~.!.a..s.~..a_ ...... 9__5)_.5_.0..1_. Si ~ned .~..~,...~~.~~~ Phone ............................. 2.7_9=_7.6.8_l ..................................... et~e~t's title ...... D_i.s.L____D.r. lg .... 8x~_p._t ................. ' Wrza, ' D~r~ [ Co, F?, or GAs OALLON$ O~ BXitgZ~ O~ REMARKS ~EC. AND ~P, ~ANGE [. NO, BARRE~ OP O~ ~RAVITY OASOLINE WATER (If (If drilling, depth: if shut down, ca~ ; ~ O~ ~ P~ovvc=~ (In thou~nds) ds~ and result, of t~ for g~olim RECOVERED none, so state) content of .................... KU ~t4-6 RU ~chlun~.ber~er. .Rat FDC, CNL & G~ Logs from 5404~-4200~. TIH w/ OEDP to 5404~E2 . Mix~d & SpotteJ 10~) sx of Class "G" c~t. ~/ 0.5~ D-J9 & 10~ ;d_ Pooa. Till w/ 6 bi~. Drlg~.~ ha~-d cr~. fcom ~949~-5310~ roch. RU & a'an 16 jr:;.of 5" [8~ N-80 Hydr~l FJP csg. ~,/ B~T ~lyd. Line: & screw ;et p~r. Liner stopped ~ 5161~. Pooh w/ liner. Lost 1~ ce~.~traiizer: in hole. TIH w/ 6 1/8" bit. Four.d top of centrali:ers ~ 4916'. 50 sx. o[ g~s:~ "G~ cm~. w/J~0% sd. ])ooh. R]~ w/ ]/8" b~ on g~. ~D~ed..Ciera cmL. ~ ~9~~ ~ ,~as:;ed ()ff a~n~. p]aB ~o ~7Z0 . S:de~cked ~a]] Q ~2]0~. .DD ~2~0~--48~~. ~ooh ~ ]a~,~ d~n. [~D. ~]H ~v/ 6 ~/8" ~ D~B. ~om ~83~-5~5~. M~,'~e w~pe~ trap. Pooh. RU, k r. tn 5' 18~ Hyd:;il FJP Liner on 3 1/2" DP. Hung off liner ~ 4593~ w/ shoe ~ 5337'. ~%mt'l linsr w/ 90 sx. Class ~G" c~nt. Pooh v/ setting tool. TIH w/ 6 1/8" bit to top of li:aer } 45~3'. ]?ooh. TIH w/ ~ 1/8" bit. Tagged cmt. D ~150'. CO cmt. from 5150' to LD collar ~ 5291'WLl1. R~n Neutron CBL-VD Log fro:n ETD to top of 5" liner D 459!'. ]2erf. 5" liner from 4656'-~658'.. RIH w/ 5" sqz. tool & set D 4698'. Test, 2d 5" linea to !000 psi. ~ Re-set to~l ~ 4~10' & sqz. 95 sx. ~lass "Gt' cmt. below tool to a fJ.nal ores:;, ot 1500] psi. TIH w/ 4{ 1/8" bit & CO well to 5291'ETD. Reran Log. Per~-. thi~ Be].uga Sd. ~rom 5083'-5103' & from 5175'-5195'. TIH w/' DST tool & set 5043'. OF enec tool. C teanet up well k ran 3 pt.' proc.uction t~st. 1/2" chok~ ; 1275 psi 6.8 ~mcf/d no cut. 3/8" chok~} ' ~ 1675 psi 4.8 zamcf/d no cut. 1/4" chok¢~ 1975 psi 2.2 ~mcf/d no cut. __., . .... ,,, ....... Norz.--There were ...................................... runs or sales of oil; ............................................... M cu. ft. of gas so!d; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoTre--Report on this form is required for each calendar month, regardless of th~ status of operations, ~nd must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Forrrl 9-3~9 (Jemuary 19.,?~L1) 89 I~, 556 U.S. GOVERNMENT PR~NTI~IG OFFICE. 1964--O..72g,-794 KU #14-6 (cont...) -2- 11110/74 Final surface SI 2050 psi. Rev. out. Pooh. Perf. the C-2 Sd. from 4630'-4650'. Ran & set 5" RBP. @ 4750'. RIH w/ DST tool & set @ 4615'. Opened test tool. Cleaned up well. Put well on production test. 1/2" choke 590 psi 2.7 mmcf/d no cu..t. 3/8" ch6ke 940 psi 3.2 mmcf/d no cut. 1/4" choke 1375 psi 1.5 mmcf/d no cut. Rev. out. Pooh. Retrieved 5" RBP. Perf. the Beluga Zone from 5139'-5149', 4960'-4970', 4856'-4868' & from 4788'-4808'. Perf. the C Zone (C-2 Sd.) from 4615'-4630'. Ran & set 5" RBP @ 5000'. RI'H w/ 'DST tool & set @ 4715'. Prod. tested the Beluga perfs. 4788'-4808', 4856'-4868' & from 4788'-4808'. 1/2" choke 710 psi 3.85 mmcf/d no cut. 3/8" choke 1050 psi 3.22 mmcf/d no cut. 1/4" choke 1400 psi 1.80 mmcf/d no cut. Rev. out. Pooh. Retrieved.RBP @ 5000'. Set 7" RBP @ 1500'. Changed out tbg. head for dual tbg. head. Installed & tested BOPE. Made bit & scraper run to 5291'. RU & ran dual 2 7/8" X 2 3/8" th§. strings as programed w/ 5" sgl. hyd. pkr. @ 4736' & 7" dual hyd. pkr. @ 4390'. Removed BOPE. Installed & tested x-mas tree. Set & tested pkrs. RELEASED RIG @ 12:00 NOON, 10/26/74. FINAL REPORT AND OAS ANCHORAOE October 22, 1974 Re: Kenai Unit 14-6RD Union Oil Company of California Permit No. 74-50 ~.tr. Robert T. Anderson District Land Manager Union Oi1' Comgany of California 909 West 9th Aven~e Anchorage, Alaska 99501 Dear Sir: Enclosed is the approved application for permit to ~ill the above referenced well, on or about October 4, 1974, at a location in Section 6, Township 4N, Range 11W, Well samples, core chips, and a mud log are not required. A directional survey-is required. Many rivers in Alaska and their drainage systems ha~e been classified as impo~ant for the spawning or mi~Fration of a~ous fish. Operations in these a~as are s~jec~ to ~ 16.50.870 and-the tions promulga~ ~ere~er (Title 5, Alaska A~tn~strati~'C~). Prior ~ ~nci~ ~ratio~ you ~y ~ ~~C~ by ~ C~rdtnator's office, ~par~n~ of Fish ~d Pollution of any waters of the State is prohibited by AS' 46, Chapter 03, Article 7 and the regulations prom~lgate(l thereunder (Title 18, Alaska Adm~nistrative Code, Chapter 70) a.~ by the Federal Water Pollution Control Act, as amen~. Prior to commenci~ operations you may be contacted by a representative of tP~ Depar~aen% of Environmental Conservation. ~Vi7 truly, yours, Thomas R. ~.~arsha11, Jr. Executive Secretary Alaska Oil and Gas Conservation Ccn~mittee Enclosure CC: Department of Fish and Game, Habitat Section w/oencl. Department of Environmental Conserva~ion w/o eric1. Department of Labor, Supervisor, Labor~C~liance DiVision w/o encl. ~ - Form 10-- 401 .REV. I--I--71 la. TI'PM 0~' WOIK b. TYPE Or W~LL OIL ~'~ WmLL STATE O.F ALASKA OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL oR DEEPEN OTHBR DRILL GA8 WELL 2. NAME OF OPEI:~TOR SUBMIT IN TR[I: t'rlg (Other instruction., reverse side ) DEEPEN [] Sidetrack SINGLE r-I ZONE Union Oil Ccml0any of California 3. ADDRESS O~' OP~R-a-TOR q .--~. P. O. Box 6247, Anchorase, ~?'aska 99502 ZONE APl #50-135-10089-01 i. 6. LEASE D~IGNATION A2~-'D SERIAL NO. Anchorage 028142 IF INDIAN, ALLO'i-r.:-: OR TI~IBE NAM~ '8, UNIT FARM OR LEASE NAJVIE Kenai Unit 9. WELL NO. KU 14-6 RD 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. ~EC,, T., R., M., fBOTTOM HOLE OBJECTIVE) 4. LOCATION OF..~~ . _ .......... ; ,, At surface ~ 4.. 279'E, Frcrn ~ha NW ~~ .q~ ~ Td~ At pressed prod. zone 13. DISTANCE IN MILES AN~ DIRECTION ~OM REST TOWN OR POST OFFI~* ~ldoma, ~aska 14 ~les 14. BOND INFORMATION: ' ' Statewide Insurance Co. B-55372 TYPE Surety and/or No: United Pacific 15. DISTANCE FROM PROPOSED* i'8. NO. OF ACRES IN I'.EASE. LOCATION TO NEAREST . PROPERTY OR LEASE LINE, Fr. 4,000 ' 2,560.00 1 · (Also to nearest drig, unit, if any) , 18. DISTANCE FROM PROPOSED LOCATION* TO NEARESI' WELL DRILLING, COMPLETED. OR APPLI'ED FOR, 4, ~0' from 43-6 19. pROpOSED D~H 5,345 ' 21. ELEVATIONS (Show whether DF, RT. C-R, etc.) t~ 90' 23. PROPOSED CASING AND CEMENI'ING PROGRAM Sec. 6: T4N, RllW, S.M. , . . A,-o-,,, $100,000 17. NO. ACRES ASSIGNED TO THiS WELL 320 ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START* October 4, 1974 (prior verbal approval ) SIZE OF HOLE SIZE OFCASING" WEIGHT pER FOOT GRAI~E : S~'I"rlNG DEPTH quantity of cement 26" 20" ~ ~ ~. ~ 60' ~ :,?. ~ . pre~iously set (80 sx. ~.') _ 17-1/2" 13-3/8": { 54..,5~ '& 619 J~55 3018' " " (1720 sx. ~.) 7" 2~ &29~ -, ~ ' ~1~8 " " (775 sx. ~,) _ 6-~/8" 5" ~ ' ,, " 793._ N-80 5345' 100 ~ SI~ ~1~ ~ ~ (87 sx. ~. , ,, , This well Was preSently completed as a sgl. gas well in the Pool 6 C-1 Sd. with' perfS, frOm 4455' to 4590'. The original hole was cleaned out to 5404' but was subsequently sidetracked due to junk in the hole A set from junk @ 4903' to 4694' & dressed off to a KOP of i710', s drilled from 4710' to 5345'. OCT ! ,r.; 1974 DIVISION OF OIL AND OAS IN ABOV~ SPAC~ D~S~W. IBE PltOPO$~D PRIXIRAM: If ~--1 is to dee~n give ~. on present ~w preclusive ~ne. J~_~l ~ ~ ~rlll or ~n d~o~l~, ~ive ~rtm~nt ~' on's~su~a~ ~t~ ~d mca 'reCital dept. Give bio--u[ P~e~e~ter- 24. I hereby certify that th~q~Fore~g is True an~ Corr~ ~ S!GNE~~~DAT~, m ~to~r, . mll',,, 1974 (This space for S~te offi~ u~) CON~ONS OF ~V~, IF A~: SAMPL~ AND CORE CHIPS B~~ M,U'D LO'G Y~ ~ NO F District Land Manager SEE TRANSMITTAL LETTER A.P.I. ~CAL COD~ .5'o-/$.~- /oo~- o~ , October 22, 1974 Executive Secretary , ,, October 22, 1974 KU #14-6 (cont...) A 5" liner will be set from 4593' (below C-1 Sd. perfs, in 7" csg.) to + 5337'. The Beluga River Sds. (perfs. + 5175' to 5195' and from + 5083' to 5103-7) will be DST tested in the sidetrack hole for production. If test is commercially productive, a dual completion would be made. If non-productive, the Beluga would be abandoned and a single Pool 6 completion would be made with C-1 Sd. perfs, from 4455' to 4590' and the C-2 Sd. perfs added in the 5" liner (original wellbore) from 4615' to 4650'. DIV!SION OF OIL AND GAS Atx~HORAGI~ 33- 3O \ \ ~ 44- 30 21 x-32 \ 3~. ' 3 3-32 ~. ' · -- KDU-3 T 5N- RIIW T4N-RIIW N ¢43 -C KDU_4~ 43-12- 43 -'7 I ' ,KUH-I .5 K.DU. 2 union Alaska District KEN.Al GAS FIELD K.U, 14-6 RD DATE: OCT, 14, 1974 SCALE: I"= 2000' I I _ 0 '2000' UNITED STATES sw~i~ tother tnstructfi~,s on DEPARTI"~'NT OF THE INTERIOR ,,~,~.u~) c. OLOGICAL SURVEY SUNDRY NOTiC2S AND REPORTS ON WELLS (Do not use this form for propo~al~ to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT~" for such ~mpo~ls.) 1. WELL WBLL OT~ZR 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRES~ O~ OPERATOR 909 West 9th Avenue, Anchorage, Alaska LOCATION OF '.VSn[ (Report location clearly and tn accordance with an7 8tare requirements.' S~ also space 17 below,) At surface Section 7: 1-~. PERMIT 68-5 15. EU~VATZONS (Show whether hr, BT, Ga, et~) RT 90' Form aR,proved. Bud£et Bureau ~'o. t2-R1424. ~, LE&~E DE,qiGNATION AND MER!AL NO. 6. IF INDI&N. ALLOTTI:~ OK TRIBE NAME 7,,: UIqlT AGREE.',fgNT _ ,. '-7- ;Kenai Unit 8. FARM O~ L~A~E NAME 9. WELL NO.' __:,. 'KU ~14.-.~ ' 10, FIELD AND POOIo ~R ;VILD~AT ':; ': !<enai Gas Field -12. COUNTY OR PARISH{ 1~. STATE Kenai penri,i Alaska 16, Check App,'opriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE O]r- INTI~NTION TO : FRACTURE TREAT .Y[ULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS fOther) BUBSEqUENT REPORT 0~: FRACTURE TREATI~IENT ALTERING CA~ING SHOOTINQ OR ACIDIZING ~. ABANDONF1E.N52* (Other) (NOTE: Report results of multiple completion on YVeI1 Completion or Ytccomi)letion Report and Log farm.) 17. DESCRIBE PROPOSED OR COMPLETED OI~ERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated Cate of starting any ~ropos~ work. If well ia d/mctionMly d~H~ give subs~aee lo~ons and measured and true vertical depths for all markers and zone~ perti- nent ~ this work.) * .-:.-. . J, ':.. '~- ~' / :,- ' g ~. ;- -... . To Sidetrack ~ . .u .,. . :~ ',' . . . ::,.. ,,., Present Status: ~ ~-:. ~ .:{ ~, .:: The old wellbore in KU g14-6 was cleaned out to 5404~. Acmt. plug .'was laid on btm. ~ dressed off to 5310~, Sixteen its. of 5" 17.93~ N-80 csg'. was 'run. The csg. stopped ~ 5161~ when the lower liner hanger slips sheared,' The' liner was retrieved a 11 5" X 6 1/2" centralizers were left in the ho]e :' A clean out run was made w/ a 6 1/8" bit. The centralizers were. located (4 49].6'. Attempts to move the centralizers dmn. hole were unsucces?full." - ~ .- ,.- .... C' :, :, ::~ 1. TIH w/ OEDP. Lay cmt. plu~ from 4900' to 4750'., :~~i ~::l~:" 2. Dress off cmt. plug, Sidetrack well w/ DD ~ + 4800 . '4' ':' :' .' .,. ': .' I hereb cer~ h 1~. - ~C ~ t at the fore~lDg 1~ trle and correct · - ~"~'~ .... 7 .... f ~"~-' /' ./' ' ~~_~~~~r_ ~=~c~-~ - ................... (ThiS'space for Federal or State office use) APPROXJED BY CONDITIONS Oi7 APPP..OVAL, IF A~¥: TITLE *See Instructions on Reveme Side -2- PLAN OF PROCEDURE: (cont..) 4. Run 5" 17.93# N-80 Liner on BOT 5" X 7" liner hanger w/ screw dwn. pack-off to + 5300'. Set hyd. hgr. @ 4606'. 5. Cmt. 5" liner ~v/ + 250 sx. of Class "G" cmt. 6. RIH w/ 6 1/8". bit & CO to top of 5" liner. 7. Run 4 1/8" bit & CO 5" liner to + 5250'. 8. Run CBL Log from 5250' to 4300'. 9. Sq. 5" liner as determined necessary from CBL Log. 10. Perforate the Beluga from 5175' to 5195' & DST. 11. Depending upon the results of the DST, the following Beluga perforations may be added. 4776' - 4784' 4788' - 4808' 4856' - 4868' 4918' - 4928' 4956' - 4976' 5083' - 5103' 12. Completion dependent upon results of DST. Union Oil and Gas Division: Western Region Union Oil Company i)alifornia a- 909 W. 9th Avenue,/~,,chorage, Alaska .950 October 7, 1974 RE.: KU #14-6 ~ IT24AI E,'~S FIELD Dear ~'~. Smith: Enclosed for your approval are three copies of Fo~ 9-331, Change of Plus for k~ ~14-6, Kenai Gas Field. Telephone: (907) 279-7681 Regional Oil 6 Gas S~v. Conse~ation Division U. S. Geological Su~ey P. O. Box 259 Anchorage ~ Alaska 99501 Very truly yours, J~ R. Callender District Dr].g. Supt. sk -~lhncl. CC: Tom ,~rshall-Division of Oil .~ ~t~rathon Oil Co. Atlantic Rickfield Co, Standard Oil Co. of Calif. ~J - . ~Form 9-33! ( ~-", y 1963) (Other lnsl./"-;oos on re- DEPA~< ';~_NT OF I'HE INTi~RIOR EOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such Dropo~Is.) 1. WiLL ri'ELL OTHER IVAME OF OPERATOR LD4ION eli, C.C'~,FPaNY OF CAT.TFO~TA ~D~ O~ OP~TOR 909 West 9th Avenue, ~chorage, ~aska 99501 . LOCATION O? W£LL IReport location clearly and in accordance with any Sr. ar~e requirements.* See also sp.',co 17 below.) At surface 2~.'S & 4~7-~~,.'~he NIP corner. Sec. tibn-. 7: T4N,t--P4-i'~.~: M. 14. PERMIT NO. 68-5 15. ELEVA'flON-q (Show whether Dr, ~'r, RT 90~ Form approred. Bud=et llureau No. 4~-Rt42~ A-028142 6. IF INDIAN, ALLOT-fwE OR TIILB£ Kenai Unit ~. ~'AHM OB, LEA-~E NAME WiLL 1~0. KU #14-6 10. FIELD A.~D POOL, OR WILDCAT Kenai Cas Field 11. B~:C.. T., H,, ~., OR [ILK, AND Section 6' T4N, ?J.!'F, 'i2. coo.~ os v.u;,su; lS. s~ Kenai Pep.n. tMaska' 16. FRACTURE TEEAT 8HOOT OR ACLDIZ~ REPAII~ WELL (Other) Check ApprOpriate BOx To Indicate Nature al: Notice, Report, or Other Data - TE~T WATER ~HUT-OFF ~'~ PULL OR ALTER CA3I-N~ M ULTLPLE C0M PI,RTE ABAN~N~ C~ANGE p~N'~ .. · fJD*BSEQUENT RBPOET OF: ' . ':i' ' ~r,~A~..~o w~L,, WATER. S ~tlT~rg ~ACTU~ ' T~EATM ~Ny ~TERING CASING SHYING OR ACID~ING ABA~NM~NT' (Other) (NoT~: Report results of multiple comple~lon on WeAl .' Completion or Recompletlon Report and Lo~: form.) 17. DESCRtnE PIIOPOSED Oa COMPLETED OPERATIONS (Clearly state all pertinent details, and .."Ire pertinent dates, laeludin~ estimated date of starting pro~ ~'ork. If w~tl is ~o~y ~ give s~~ I~OnS and measur~ and true vertical depths for all m~ker~ and zonez To drlg. out csg. shoe, CO open hole ~ set a lher thru the Belu z' '-:::.-- .. .. -:. ~.~ .: ~ ..... .. PLaN OF PRO~DU~: = :, '=' - : ~- .-. ~ --.:- .. -, 1. Rig v~ over Well_ . Kill wellw/73~/cu., ft. salt ~,¢r. : T,..:f~:.. = ;'~ ..... -' -- Nippl ~. : .. 7 : · 2, Remove x-ms tree. e ~ 6 test gOPE. ~. - -- .7 ?'~ ~. .... 3. ~1 [ ~av &m. sgl 2 7/8" tbg. string fi accessories. ' '-. ~' ~ :. ~ ~ . . .~ ._ 5 -',' 4. b~ll over [ retrieve sgl. pem. pk~, ~ 4406', =.~/.: =, =. 5. CO 7" csg. to 4606~. ~'?'"' :' ~{ -'.' 6. ~lg. out ~r. fr~m 4~06~ to 4616~. ~!g. our 7" csg. s~oe ~ron 4616' to 4618~. ~lg. cut ~t. plug ~ediately below shoe. CO 9~' hole below plug to',5400 ~ '? ''" - ' ~ 7. ~GN~- -GR log :from 5400* to 4200~ r - ~ ~: 8. TIH w/ OEDP [ lay, ~t plug from +5400~ to 5050~ ~ ~ ' ' : ~ - . ' -- ' - ::'5 " :' ": 9. ~ess off ~t. plug ~o' +5500' .. ' 10. ~ 5" ~7.95~ N-80 L~,e~ on ~T S" X 7" liner hgt. w/ screw ~. 11. 12. 15. 14. to +5500'. Set hyd. her. @ 4606'. Cm,,tT 5" liner w/+250 sx. of Class "G" ~nt. RIH w/ 6 1/8" bi~ & CO to top of S" liner. R~m 4 1/8" bit & CO 5" liner to +S250'. Pc~-n CBL Log from 5250' to 4500', UNITED' STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and prod~otio~ (incl'~din~ drillin~ and produci~ wells) for' the montk of ...... .S..e. Rt.-e_.m--b-_e--r- .............. ,19---7.-4-, ........................................................................... d~ent's address _ ...... ......... ..... L, ............... Phone " 279-7681 Ext. 445 d~ent's titlet' ~__,~i..s_.t.....,~.r..l~.....~.u_.D.t.: .................... I GALLONS OJ' BA~.REL8 OF REMARKS W~J,,~ Dave BARR~I~ O~ O~ ORA~TY CU. FT. OF OAS ~EC. AND ~F. RANG~ NO. (~ thought) GASOLINE %VATER (~ (If drillinz, depth; if ehu~ down, ~ O~ ~ Paov~c~n R~COV~R~D ~oBe, so state) ~ ~d r~ult of %~t for - con,at of ;omme ~ced~ ~ O ope~atiom; ~ 3:00 ~m, ¢/ZZ/74. Killed ,vel! w/ 73g/cu. ft. ;alt wtr. :Msta[l~d BPV. ~x2ma~ tree~ Installed ~ tested BOPE to 3000 psi. ~icked up ,m 2 7/8" tbg Unable.t~> pull out of perm. pkr. 0 4406~. Cut. 2 7/8" bg. 0 4356~. ~]~ulle~ ~. hdd dwn. tt~g. ~['IH w/ OS ~ jars. Latched onto tbg. 'ish 0 ~356 ~ j:arrerl free Pooh. Rec. all of tbg. RIH w/ BO mill & pkr. retrieved pe::m, ekr. 0 4405 . TIH ~/ 6 1/8r bit. Drl~. )icker M~!lled ova & . ] , .. _ :mt. ~om ')611' to 616' Drlg csg shr.e from 4~16' to 4q!8'. Dr~ . ~ ...... ~" hole w/ 6 1/8" bit to ;404' w/ blt tri[s ~ 4649', 4775~, 4p04', 5003', 5218' ~ ;404'. Cir &con, l ho~e for logging. Pooh. I qow: Rigging ap E[chlunberger to log. .... ,,, NoT~..~There'were ....................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoTz.--Repor~ on this form is required for each calendar :nonth, regardless of the status of operat, ion~, aad must- be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by ~he supervisor. Form 9-329 (January 1950) S92-556 U.S. GOVERNMENT PRINTING OFFICE. !%4--{~--729-:g4 Fotm ~-331 (May 1963) UNITED STATES sv~m (Other lnstru~c~s on DE?AR~/"~NT OF THE INTERIOR ,e,~ . -OLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for prol~sats to drill or to daepen or plu~ back to a different reservoir. Us~ ",~,~PrJCATION FOR PERMIT~" for such proposals) 1. WELL WE r.L OT~t ER 2o NAME OF OPEa~T~)E 3. ADair. E88 O~ 0PF.2~0E 4. LOCATION OF W£LL (Report location clearly and in accordance with ~uy State requirements.* See also space 17 below.) At surface NO. 15. [IA]~IO.~-q (Show whether ?om approved. Budget Bureau No. 43-RI424. ~. LEA$I~ D~IGNATiON AND 5ZnL~.L .NO. 6; i~F INDIAN. ALLO'C]:EE OR TI1XBE NAME ,_ ~ . . .. 9. w~ NO. -, . .. 10. FIELD A~D ~, 0~ WiLDCA~ . . ~U~V~Y O~ ~A .... ~. ... 16. Chec{c Appropriate Box To Indicate Nature of Notice, Report, or Other FRACTURE TEEAT MUL~tlPLE COMPLETe: BHOOT OR &C~D~ZE ABA2/DON* ~EPAm WELL CH&NGm PLANS (Other) * (Other) (No~: Report result~ of multiple completion on wan Completion or Recompletton ~eport and Log f~rm.) 17. o~:scaln£ vnopos£o oR COMPLETED O?iRATIO.~8 (Clearly state all ~rtinent de,ils, and ~ive per,usnr dates, lnctudiny ~stlmat~ date of s~r~ing any ' P~ work. ~' W~ h ~on~y ~ give ~~ ~fiuns ~d meas~tr~ and true vertic~ dept~s for all markers-and zones ~rti. ~ ~ ~is wor~) * 2 .1 _. 15. 16. 17. 18. ~. 5" l~er as dete~ined necessa~' from ~L Log. Per.forate the Beluga from 5175' to 5195' & DST. ~pending ~on the results of the DST, the follo~ ~y ~ added.- 4776' - 4784' 4856' 4868' 4918' - 4928' 4956' - 4976' Co~letion dependent ~n results of D~*. 18. I hereby ce~.=~y ~hat the forezoin~ J~ true~aud correct ..Dist. Dr!g. CONDITIONS OF APPI{;~¢AL, IF A~N~/: (This space for Federal or Stare o~Sce use) STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: The motion of the Alaska Oil ) Conservation Order ~1o. 82 and Gas Conservation Committee to ) Kenai Field hear testimony 'fo establish pool ) Sterling Gas Pools 3, 4, 5.1, 5.2, 6 rules to govern the operation of ) Tyonek Gas Pool t the Kenai Gas Field. ) December 3, 1969 IT APPEAR ! NG THAT: 1. The Alaska Oil and Gas Conservation Committee moved to hear testimony by the operator to establish proper pool rules for the Kenai Field. 2. NOtice of the hearing was Published in the Ar:'~orage Daily News on October 7, 1969. 3. A public hearing was held in the Ben Crawford Memorial Building, Anchorage, Alaska, on October 30, 1969. Testimony was presented in response to the motion, and affected and interested parties were heard. The hearing was continued until November 6, 1969, in order that additional testimony could be presented. 4. Notice of continuance of public hearing was published in the Anchorage Daily News November 4, 1969. 5. The public hearing was resumed in the Ben Crawford Memorial Building, Anchorage, Alaska, on November 6, 1969. Additional testimony was presented. AND IT FURTHER APPEARING THAT: 1. Gas pools' Should be defined in this field. 2. To conform to currently accepted geological formation nomenclature published by the Alaska Geological Society, the pools designated in the testimony as various Upper Kenai Gas Pools and Middle Kenai Gas Pool should be named various Sterling Gas Pools and Tyonek Gas Pool respectively. 3. Existing 320-acre spacing should be continued in each pool, but exceptions must be granted for certain existing wells. COHSERVATION ORDER NO. 82 Page 2 December 3, !969 4. Testimony was insufficient to support a pool rule allowing any pay open to the well bore to be less than 3,000 feet from any pay in the same pool in any other well capable of producing therefrom. 5. Continued production and water encroachment may necessitate more than one key well bottom hole pressure survey in a calendar year. 6. This conservation order should set forth all current pool rules for the Kenai Field. NOW, THEREFORE, IT IS ORDERED that the area described as follows is affected by this order: T4N~ R11W, S.M._ Section 3: Lot 4, SW¼NW¼, W½SW¼ Sections 4, 5, 6, 7, 8: All I Section 9: N½, SW¼, W~SE~ ' ' SW NW¼ NW¼SW¼ Section 16: N~NW~, , Sections 17 and t8: All Section 19: Lot 1, NE¼NW¼, NE¼ Section 20: N½NW¼, SW¼NW¼ T4N, R12W, S~.M. Section 1: 'All SectiOn 2: E½E½ · 'Section 11! :E½NE¼ Sect i on 12: A I i Section 13: Lots 5 through 12, easterly 2.50 acres of Lots 13 through 16, E½NW¼NE¼, E½E½, E½W½SE¼NE¼, E½W½NW¼SE¼, E½SW¼NE¼, E½NW¼SE¼, AI'I of W½NE¼, E~NW¼ lying westerly of coastline !SN, Section 17: Lots 8 and 9, NW¼.SW¼, s½sW¼, All of Kenai River lying within SW¼, SW¼SE¼ Section 18: SE¼SE¼ Section 19: LOts 2, 6 through 13, SE¼, E½E½SE¼SW¼, NE¼, All SE¼NW¼, NE¼SW¼, S½SW¼ lying westerly of coastline Section 20: S½, NWA, SW¼NE¼, NW¼NE¼ Section 28: ~ NW¼NW¼, S½NW¼, SW¼, W½SE¼, SE¼SE¼ Sections 29 and 30: All Section 31: Lots 3 through 10, E½, All that portion lying westerly of cOastline Sections 32 and 33: All Section 34: NW¼NW¼, S½NW¼, SW¼, W½SE¼ T5N, R12W,.S.M.. Section 25: SE¼NE¼, E½SE¼ Sect i on 36: E½ CONSERVATION ORDER NO. 82 Page 3 December 3, 1969 . .. Rule 1. Definition of Pools.· , . . ~, . (a) The Kenai.Sterl.'Ing Gas Pool 3 is defined as the accumulation of gas common-to and--which correlates' with the accumulation found In the interval 4,175~' to-4,374' In the.KU 21,6 well. "~ . (b) 'The Kenai Star. ling Gas Pool,4 is'def, ined as the accumulatlon of gas common to and,which correlates with the accumulation.found in-the interval 4,412' to 4,558'· In .the ~ 21-6 well. (c) The Kenal Sterling Gas Pool 5.1 is defined as the accumulation of gas Common to and which correlates with the accumulation found in the interval 4,576' to 4,859' in the KU 21-6 well. (d) The Kenal Sterling Gas Pool 5.2 is defined'as 'the accumulation of gas common to and which correlates with the accumulatlon found in the interval--4,880'.-to 5'213' i-n the KU.21-6 well, ? ".; . . (e) The Kenai Sterling Gas pool 6' is defined.as-the accumulation of gas common to and WhiCh correlates-with the accumulation found in the Interval 5,250-;t: to 5,520~ .in .the KU '21-6 wel i-. .. , .. (f) The Kenai Tyonek Gas Pool 1 is defined as the accUmulation of gas common,.to, and whlch.correlateswi~th the accumulation found In.-the' interval 9-,155.'~.to.9,890~'.ln:.the. KDU No.~-I well.'. '- ~ -~... ] . ';;. - - .; = "; .. · · Rule 2. Well .spacing, ^ drilling unlt for each pool,shall consist.of any.~wo adjacent governmental' quarter sections within the same section. Not more than one completed well shall be all'oWed in any drilling unit, No pay open to the well bore will be less than 3,000' from the pay in the same pool in any. othec.well capable 'of prodUcing..therefrom,· ~ . .'" ~.. .~ ~:~' "> . .,' ..., -, , . ', ... .. ]...~ - , ;: , .. :., ::~.. - . . ,. '. RUle'3."Oasin~ and Cementing Requirements. . :...~.... .. : · - . . ,' . . . .i' ,'~ .' "' ' . · .' ~' ' '.. ;¢ ' · · ' · " · (a)-. sUrface casing'-shail be landed at not' less t~an'l,~OO',.Or'more th~n 2,000' and cement shall be.circulated to the surface'. ... -. - (b) Production casing shall be landed through the 'completion zone and cement shall cover and extend to at least .500' aboVe'each potential productive sand Int~Val.":?.?he use of multl-stage cementing procedures shall.::be'i~ermi~ed. .A:l-+ernatively a casing string shal. I .be adequately cemented'~f"~n~'~nt&rmediate point and a. liner landed through'the completion 'zOne~' I'f"a"i'iner-:l.S,run~ the'annular spa~e behind the liner shall be filled with cement to at.leastlO0, above·the caslng shoe or the top.of the liner shall be squeeZed with sufficient cement to provide'at least 100' of cement between the liner and casing annulus. Cement must cover all potentially productive Intervals behind the liner. Casing and well head equipment shall-be hydrostaf.ically.~esfed to not less than 2~000 pounds per square inch pressure...". ?.; ?,'"..-, ' - -. - CONSERVATION ORDER ht~. 82 Page 4 December 3, 1969 Rule 4. Computed Bottom Hole Pressure Surveys~. A key well bottom hole pressure survey shall be taken in 'each pool upon Committee request; however, such'surveys shall not be required more often than twice in any calendar year.· Bottom hole pressure may be computed from surface measurements taken with a dead weight tester provided, however, than an approved.bottom hole measuring device 'shall be run when the accuracy of the. computed bottom.hole pressure is questionable. The.time, length and kind of survey, number and location of'wells, datum and other details will be determined by the operator subject to Committee approVal. IT IS FURTHER ORDERED THAT: '· ~ Conservation, Order NO. 30. Is hereby revoked. A spacing exception is granted .for well KLI 21-6 ·which well is completed In the Kenai Sterllng Gas Pool 5.1 and 6 and'in the same drilling unit as well ~ 14-6 which is completed in Kenai Sterling Gas Pool 6. : . . Commingling of production from the Kenai, Sterling Gas Pool 4'and' the..Kenal Sterling Gas Pool 5.1 in well KU 33-32 is allowed. A spacing exception is granted to complete the wel'l ·KIJ'21X-32 in the, same pool or pools as the well KU 33-32 at a distance of not~ less than 2,000' from the pay open to the I<lJ 33-32 well bore in the same pool. · DONE at Anchorage, Alaska, and dated,December 3, 1969~ . Thomas R. Marshal I, Jr., Executive Secretary Alaska Ol I and Gas:Conservatlon Committee ., , Concurrence: Homer L.. Burrell, Chairman.' Alaska Oi-I and Gas Conservation Commlttee ] . · Alaska Oil and Gas Conservation Committee Company Lease'& ~-Jetl No. /F~z' //~;~ x~/~z~.y~ CHECK LIST FOR NEW WELL PERMITS Yes No Remarks , , 1. Is well to be located in a defined pool ................. _~. Do statewi de rul es apply ...... m .................. ~ -- Is a registered survey plat attached .................. __ ~_ ~ Is well located proper distance from property line ........... &EF~L~. ~/~ Is well located proper distance from other wells ............ ~ , z~:~ . 5. Is sufficient undedicated acreage available in this pool ........ ~_ l. Is well to be deviated ......................... ~ Is operator the only affected party ................... ~ ..... Can permit be approved before ten-day wait ............... ~F~y~ ~0. Does operator have a bond in force ................... . !s enough cement used to circulate on conductor and surface ...... ~3. Will cement tie in surface and intermediate or production strings . . . Wilt cement cover all possible productive horizons ........... 15. Will surface casing cover all fresh water zones ............ ]6. Will surface csg. internal burst equal .5 psi/ft, to next string .... l, Jill all casing give adequate safety in colla se an te sio . . . Does BOPE have sufficient pressure rating . .... ~ddi tional Requirements: HWK LCS
