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, , M MARATHON ') Marathon Oil Company ) Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 January 6, 2006 Steve McMains AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Ð) n ~Sõ . ... . \~ 11l~\J ~~~f) J ì; Ooq ¿/. . ,lo>' Dear Mr. McMains: Attached and submitted for your records is the Form 10-407 completion sundry to partially abandon the wellbore in the KU 43-6 well prior to sidetracking to the KU 43-6rd. Also attached for your records is the well schematic for the abandoned wellbore, Operational Summary Report, and Cementing Record. If you would like any other information, please contact me at 394-3060 or kdwalsh@marathonoil.com. Sincerely, ·~,-~.vJ~ Ken D. Walsh Senior Production Engineer Enclosures KECEIVED 1 a. Well Status: ) STATE OF ALASKA ') ALAS'" .-bIL AND GAS CONSERVATION COMMI~v{ON JAN 1 0 2006 WELL COMPLETION OR RECOMPLETION REPORT MliDILœ Cons. Commissio OilD GasD Plugged 0 Abandoned[2] SuspendedO WAGD 1b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 Developm ent [2] Exploratory D No. of Completions 2 Other Service D Stratigraphic Test D 5. Date Comp., Susp., or 12. Permit to Drill Number: Aband.: January 17, 2002 65-9 6. Date Spudded: 13. API Number: May 26, 1965 50-133-10091-00 7. Date TD Reached: 14. Well Name and Number: June 8, 1965 KU 43-6 8. KB Elevation (ft): 15. Field/Pool(s): 92' KB Kenai Gas Field, Pool 6 9. Plug Back Depth(MD+TVD): 4193' MD, 3609' TVD 10. Total Depth (MD + TVD): Zone- 4 5706' MD, 4780' TVD Zone- 4 11. Depth Where SSSV Set: Zone- 4 NI A 19. Water Depth, if Offshore: NIA feet MSL 16. Property Designation: Kenai Unit 17. Land Use Permit: A-028142 GINJD WINJD WDSPLD 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 4a. Location of Well (Governmental Section): Surface: 205' FNL, 1049' FEL,Sec 7, T4N, R11W, SM Top of Productive Horizon: 1985 FSL, 1139 FEL, Sec 6, T4N, R11W, SM Total Depth: 2593' FSL, 1066' FEL, Sec 6 T4N, R11W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 275133 y- 2361787 TPI: x- 275048 y- 2362956 Total Depth: x- 275119 y- 2364659 18. Directional Survey: Yes [2] No 0 20. Thickness of Permafrost: NIA 21. Logs Run: IES, Sonic, Microlog, GR, CBL 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 78.6# 0' 52' 0' 52' Driven None 10-3/4" 32.75# H-40 A' 1297' A' 1246' 17-1/2" 1450 sks None 7 -5/8" 26.4# J-55 A' 5601' A' 4697' 9-7/8" 700 sks None 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" (Longstring) 4296' - 5169' 5145' 2-7/8" (Shortstring) 4319' - 4452' 4452' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4187' - 5459' (calculated) 295 sks Class G cement 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): NIA Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Test Period ...... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Press. 24-Hour Rate ... Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS 8Ft .IAN 1 1 2D06 Form 10-407 Revised 12/2003 º RIG I NA~UED ON REVERSE G NAME GEOLOGIC MARKERS M. ) TVD 29. FORMATION TESTS Include and briefly sur. }ize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. 30. List of Attachments: Operations Summary Report, Wellbore Diagram, Cementing Report 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D. Walsh Signature: ((iN\. 'b, vJ ~ Title: Senior Production Engineer Phone: 907-394-3060 Date: 1/6/2006 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 well Name 8. Number: County or Parish: Perforations (MD) ; I Abandoned: @ BHT: I /17/2002 (TVD) Completion Fluid: Alaska I KU 43-6 Kenai Borough Lease: State/Prov, Kenai Unit (Sterling) I Country: USA 75/8", 26.4 ppf, J-55 cS9 @ 5601 at 5145' KB. Perf Interval: Isolated with Cement MD TVD B-3: 4593'-4615' 3926'-3944' 4624'-4646' 3951'-3968' B-4: 4680'-4702' 3996'-4013' 4708-4730' 4018'-4036' 4821'-4837' 4108'-4121' 4850'-4872' 4131'-4148' Perf Interval: Isolated with Cement MD TVD Upper C-1 5270'-5380' 4456'-4539' Lower C-1 5392'-5434' 4548'-4580' C-2 Sand 5450'-5455' 4592'-4596' C-2 Sand 5463'-5488' 4602'-4621' Brown 7-5/8" Dual Packer ITUbing: 2-7/8", 6.4ppf, N-80 8rd SS cut at 4319' KB and pulled LS cut at 4296' KB and pulled at 4452' KB. 17-5/8" EZSV Cement Retainer at 4187' KB. Squeezed below retainer with 295 sks (60 bbls) Class G cement 20" 78,6ppf @ 52' 3/4" 32.75ppf, H-40 csg @ 1297' 43-6 205' FNL, 1049' FEL, Sec. 7, T4N, R11W, SM API No. 50-133-10091-00 Abandonment Prior to Sidetrack -) --::¡:r.. i < ') Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 43-6 Common Well Name: KENAI UNIT 43-6 Event Name: RE-ENTRY Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 1/3/2002 08:00 - 08:15 0.25 RURD - WBPREP 08:15 - 08:35 0.33 SAFETY MTG - WBPREP 08:35 - 09:30 0.92 RURD - WBPREP 09:30 - 10:30 1.00 RURD - WBPREP 10:30 -11:15 0.75 WAlTON EQIP WBPREP 11: 15 - 11 :30 0.25 NULL WBPREP 11:30-12:15 0.75 GAUGE - WBPREP 12:15 -13:00 0.75 GAUGE - WBPREP 13:00 - 15:00 2.00 GAUGE - WBPREP 15:00 - 15:45 0.75 BAIL_ WBPREP 15:45 - 16:00 0.25 RURD - EQIP WBPREP 16:00 - 16:45 0.75 BAIL_ WBPREP 16:45 - 17:45 1.00 GAUGE - WBPREP 17:45 - 18:00 0.25 RURD - WBPREP 18:00 -19:15 1.25 GAUGE - WBPREP 1/9/2002 12:00 - 06:00 18.00 RURD_ RIG_ MIRU 1/10/2002 06:00 - 06:00 24.00 RURD_ RIG_ MIRU 1/11/2002 06:00 - 12:00 6.00 RURD_ RIG_ MIRU 12:00 - 00:00 12.00 RURD_ RIG_ MIRU 00:00 - 06:00 6.00 RURD - RIG_ MIRU 1/12/2002 06:00 - 12:00 6.00 RURD - RIG - MIRU 12:00 - 00:00 12.00 RURD - RIG - MIRU Page 1 of 4 Start: 1/3/2002 Rig Release: 1/30/2002 Rig Number: 1 Spud Date: 1/10/2002 End: 1/22/2002 Group: Description of Operations Departed shop. Safety meeting. Moved equipment to pad 41-7. Started rig-up. Wait on grating to be put on cellar. Did hydro. Long Sring: RIH with 2.30" gauge ring to 4419'. POOH. Long Sring ? - Unsure whether long or short side. RIH with 2.15" gauge ring to 4419'. POOH. Short Sring: Moved to other string. RIH with 2.30" gauge ring to 4386'. Worked tools 15 times down. Fell through to 4418'. Will not go any further. POOH. Hung up at 4386. Work tool through. POOH. Short Sring: RIH with 2.0 D. D. Bailer to 4327'. Worked tools. POOH. Bailer empty. Moved to long string. Long String: RIH with 2.0" D. D. Bailer to 4406'. Worked tools. POOH. Bailer empty. Long String: RIH with 1.80" gauge ring to 4420'. POOH. Rig to short string. Short String: RIH with 1.80" gauge ring to 4417'. POOH. Probably collapsed tubing. Rig down for night. Release rig from maintenance @ 12:00hrs 1/08/2001. Remove carrier tarps. derrick guide wires. Back wind walls. Pull electric wires to to rig floor and pits. Blow down service lines and brakes. Spot blocks and and scope down top derrick section. Rig down rig floor wind walls. Remove doghouse and choke house. Pump off 1480 gallons excess fuel. Remove fuel tank. Top all day tanks wlfuel. Level 43-6 location. Begin to set rig mats on 43-6. Finish set rig mats on 43-6. Lay derrick over on carrier. RID boiler and water tanks. Move rig components to 43-6. Clean ice from rig mats. Clean out boiler house. Replace bad steam valves. Set pump trailer and pits. RIU steam and water hoses. Pull electric lines. Lower sub base and move to 43-6. Unload trailers. Spot mud pits. RIU mud lines. Prep and raise sub. Pin and spot sub over well. Install mud boat. Attach ramp and RIU rig water lines. Fire up boiler. spot mechanic and parts trailer. Spot change house and RIU same. Set fuel tank. Spot carier. Fold down sub wings. Raise derrick and rear wind walls. Set carrier stairs spot second water tank and slop tank. RIU sub base outriggers. Set dog house and choke house. RIU floor plate, windwalls, stairs, catwalk, flowline, beaver slide. RIU mud pits. RIU drillers console. Repair PLC power, extend mast, tighten guide wires, and set rig floor exterior lighting. Cont. RIU guide wires. RIU degasser u-tube and choke lines. RIU steam to rig floor. Hang tarps for carrier and sub. MIU stand pipe lines. Install mud shock hose. Cont. to RIU electricallinean and Geolograph lines. Plumb water line to tanks flwell chagre pump manifold. RIU top drive unit on stand. Set link tilt extend, Set torque and max connection RPM. Trouble shoot mud saver on top drive. Install rotary table motor. Printed: 12/15/2005 4:32:44 PM ) --... ') Page 2 of 4 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 43-6 Common Well Name: KENAI UNIT 43-6 Event Name: RE-ENTRY Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 1/12/2002 12:00 - 00:00 12.00 RURD - RIG_ MIRU 00:00 - 06:00 6.00 RURD - RIG - MIRU 1/13/2002 06:00 - 12:00 6.00 RURD - RIG - MIRU 12:00 - 14:00 2.00 RURD - RIG_ MIRU 14:00 - 15:00 1.00 NUND TREE WBPREP 15:00 - 16:00 1.00 NUND BOPE WBPREP 16:00 - 17:30 1.50 PUMP - WTR_ WBPREP 17:30 - 19:30 2.00 PUMP - LCM - WBPREP 19:30 - 20:00 0.50 BLOWDNEQIP WBPREP 20:00 - 21 :30 1.50 PUMP - LCM - WBPREP 21 :30 - 00:30 3.00 MIX_ LCM - WBPREP 00:30 - 01 :30 1.00 PUMP - LCM - WBPREP 01 :30 - 03:00 1.50 PUMP - WTR_ WBPREP 03:00 - 06:00 3.00 RURD - OTHR WBPREP 1/14/2002 06:00 - 12:00 6.00 NUND BOPE WBPREP 12:00 - 16:30 4.50 NUND BOPE WBPREP 16:30 - 17:00 0.50 NUND BOPE WBPREP 17:00 - 18:00 1.00 TEST_ BOPE WBPREP 18:00 - 20:00 2.00 TEST_ BOPE WBPREP 20:00 - 21 :00 1.00 REPAIR RIG - WBPREP 21 :00 - 00:00 3.00 TEST_ BOPE WBPREP 00:00 - 03:30 3.50 TEST_ BOPE WBPREP 03:30 - 04:30 1.00 RURD - CMT - WBPREP 04:30 - 06:00 1.50 PUMP - WTR_ WBPREP 1/15/2002 06:00 - 09:00 3.00 RURD - ELEC CMPPUL 09:00 - 11 :00 2.00 WORK_ ELEC CMPPUL 11 :00 - 12:00 1.00 TRIP - TOOL CMPPUL Start: 1/3/2002 Rig Release: 1/30/2002 Rig Number: 1 Spud Date: 1/10/2002 End: 1/22/2002 Group: Description of Operations Block up ramps on carrier. Install choke hose. Cont. RlU stand pipe manifold. Install hydraulic cylinder socks. RIU windwalls on derrick board. RIU torque tube and hang T-bar. Install turnbuckles for torque tube. Cont. RIU TDS add 1/8" shim to slider on both sides. Pump up TDS compensator w/nitrogen. Prepare extended hoses to TD compensator. Repair hydraulic leaks. RIU panic line. RIU panic line. RIU drill floor drain hoses. RIU cellar cranes. RIU long bales. NIU valve on x-mas tree. Pull BPV's from LS and SS. RIU kill line to LS. RIU choke to annulus. Pump down long string. Pumped 16bbls pressure 450psi. Pressure fell back and bullheaded 42bbls fresh water @ .73bpm w/150psi. Observe well. Well losing 26BPH. Blow down lines. Mix LCM pill. Pump 130bbls into 2 7/8" Dual X 7 5/8" annulus. Hold 250psi/20min. Bleed off air and add 5bbls fresh water. Hold 250psi/15min. Bleed off annulus. Blow down lines. Complete mixing LCM pill. Pump 30bbls (20PPB CaC02 Med, 10PPB CaC02 Course, 3PPB Flovis 8.4PPG 74Vis). Well on vaccum. Observe well taking 26BPH. Blow down line. Mix LCM pill. Pump 33bbls(30PPB CaC02 Med, 20PPB CaC02 Course, 41/2PPB Flovis 9.0PPG 320Vis). Observed well to be on very slight vaccum. RIU on short string. Fill short string w/5bbls freash water and pressure up to 250psi. Bled off to 100psi in 3min. RID from short string. RID from TBG X CSG. Blow down lines. Set BPV's. NID tree. NIU 9" 3M X 11"3M DSA and 11 "3M X 13 5/8"5M adaptor spool. NID single gate BOP from stack. CIO upper rams to 2 7/8" duals. Function test stack. NIU 13 5/8" 5M A,Rd,S(w/dual 2 7/8" rams and blind rams) BOP Pull BPV's and install TWC's. Attempt BOP test. Tighten flange between mud cross and adaptor flange. Test choke valves 10,11,12,6,8,9, blind rams, outside and inside kill valves 250/3000psi 10min. Repair kill line check valve and test 250/3000psi 10min. Test choke valves 2,7,5,1,3,4 and manual choke 250/3000psi 10min. Test choke line HCR, manual choke line valve, 2 7/8" Dual rams, #1 floor valve, #2 floor valve, IBOP, upper and lower kelly cocks to 250/3000psi 10min. Pull TWC's(5bbls to fill well). MIU landing joint. RlU cement line to short string. Bullhead 30bbls fresh water down short string max pressure 850psi @ .8BPM. Shut off pumps and pressure bled off f/850psi to Opsi in 6.5 min. RlU electric line. PJSM prior to cutting tubing. RIH (LS) to 4367(had to work tool down last 150'). Shoot 2 1/8" jet cutter @ 4296'. Tool stuck immediatly after firing. Work stuck tool while circulating long string taking returns out the TBG X CSG valve. Tool came free after working 2hrs. POOH w/jet cutter. Printed: 12/15/2005 4:32:44 PM )) Marathon Oil Company Page 3 of 4 Operations Summary Report Legal Well Name: KENAI UNIT 43-6 Common Well Name: KENAI UNIT 43-6 Event Name: RE-ENTRY Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Sub Phase Code 1/15/2002 12:00 - 14:30 2.50 CUT_ TBG_ CMPPUL 14:30 - 15:30 1.00 CIRC_ CFLD CMPPUL 15:30 - 16:30 1.00 CIRC_ CFLD CMPPUL 16:30 - 19:00 2.50 RUNPUL TBG - CMPPUL 19:00 - 20:30 1.50 RUNPUL TBG - CMPPUL 20:30 - 05:00 8.50 RUNPUL TBG_ CMPPUL 05:00 - 06:00 1.00 RURD - OTHR CMPPUL 1/16/2002 06:00 - 10:00 4.00 CHANGE EQIP CMPPUL 10:00 - 12:00 2.00 TEST_ EQIP CMPPUL 12:00 - 15:00 3.00 PULD - DP - PLUGAB 15:00 - 17:00 2.00 PULD - BHA_ PLUGAB 17:00 - 00:00 7.00 PULD - DP - PLUGAB 00:00 - 01 :00 1.00 CIRC_ CFLD PLUGAB 01 :00 - 06:00 5.00 PULD - DP - PLUGAB 1/17/2002 06:00 - 06:30 0.50 CIRC_ MUD - PLUGAB 06:30 - 07:30 1.00 TRIP - PLUGAB 07:30 - 09:30 2.00 REPAIR RIG_ PLUGAB 09:30 - 11 :30 2.00 TRIP - PLUGAB 11 :30 - 12:30 1.00 RURD - ELEC PLUGAB 12:30 - 13:00 0.50 PULD EQIP PLUGAB 13:00 - 15:00 2.00 RUNPUL VLVE PLUGAB 15:00 - 16:00 1.00 TEST_ CSG - PLUGAB 16:00 - 18:00 2.00 TRIP - TOOL PLUGAB 18:00 - 20:00 2.00 RURD - CMT - PLUGAB 20:00 - 22:30 2.50 PUMP - CMT - PLUGAB 22:30 - 23:30 1.00 CIRC_ CFLD PLUGAB 23:30 - 01 :30 2.00 CHANGE EQIP PLUGAB 01 :30 - 03:30 2.00 RURD - CMT_ PLUGAB 03:30 - 04:00 0.50 TEST - CSG - PLUGAB 04:00 - 06:00 2.00 NUND BOPE PLUGAB 1/18/2002 06:00 - 07:00 1.00 NUND PLUGAB 07:00 - 10:00 3.00 NUND PLUGAB 10:00 - 17:00 7.00 NUND PLUGAB 17:00 - 18:00 1.00 NUND PLUGAB 18:00 - 20:30 2.50 TEST_ PLUGAB Start: 1/3/2002 Rig Release: 1/30/2002 Rig Number: 1 Spud Date: 1/10/2002 End: 1/22/2002 Group: Description of Operations RIH(SS) to 4390' and cut tubing @ 4319' w/2 1/8" tubing cutter. POOH. RID APRS. RlU to LS and circulate out w/4BPM 463psi. RID on LS and RIU to SS and circulate out w/4BPM 372psi. RID circulating hose. RIU Weatherford TBG pulling equipment. BIO lockdowns on tubing head. Work tubing free w/50K overn string wt. Pull hanger assy to floor. LID landing joints and hanger assy. Organize rig floor. MIU safety valves to 2 7/8" BUTT X/O's. PJSM prior to LID 2 7/8" tubing. POOH LID 2 7/8" tubing(total 273jnts). RID Weatherford tubing tools. CIO to short bales. CIO elevators. CIO moused holes. CIO upper rams to 4". Load pipe rack w/25-3 1/2" HWDP. Strap HWDP. PIU test joint and MIU test plug. Test upper 4" rams and annular 250/3000psi 10min. Perform accumulator test. Pull test plug. Could not get wear bushing through DSA. LID wear bushing. RIU floor to PIU DP. Adjust new tong counter weight system. PIU 6 3/4" bit and 75/8" csg scraper BHA. PIU 4.0" DP while RIH. Tag @ 4300'. Pump 20bbl hi-vis sweep and circulate out. Change out air boot for flowline. Circulate while PIU 4.0" DP and rack back. Circulate while PIU 4.0" DP. POOH. Repair derrick finger board. Perform koomey test for BLM. Cont. POOH wlbit and scraper. RlU Schlumberger. PJSM prior to electric line operations. Run 6.5" gauge ring to 4250'. POOH. Prepare setting tool. PJSM prior to using explosives. RIH and set 7 5/8" EZSV @ 4187'. POOH. RID Schlumberger. Test 7 5/8" CSG to 2000psi. MIU Halliburton cement stinger and RIH. Sting into 75/8" EZSV @ 4187'(4193DD). Space out DP. CIO to long bales. RIU cement line. PJSM prior to cementing operations. Test cement lines to 2500psi. Test CSG X DP to 2000psi. Establish injection 2BPM @ 1190psi, 3BPM @ 1260psi(total 21 bbls fresh water injected). Mix and pump 295sxs "G" cement w/0.3% CD-32 and 0.5% FL-33 to yield 60bbls 15.8ppg slurry. Displace w/46bbls fresh water. Shut in w/600psi. Sting out of retainer. Reverse out 2 X DP volume. Circulate long way one time. CIO to short bales. Blow down BJ lines. Fill trip tank. POOH. LID Halliburton stinger. Test 75/8" CSG 2000psi/10min. Blow down lines. N/D BOP. N/D 9" 3M tubing head. N/U 11" 3M TBG head. Test 1500psi/15min. N/U 135/8" 5M BOP. N/U kill and choke lines. Change bladder in #9 accumulator bottle. CIO 4" pipe rams to 2 7/8" X 5" variable rams. PIU 4" test joint and test plug. Test variable rams to 250/3000psi Printed: 12/15/2005 4:32:44 PM .. ) ) Page 4 of 4 Marathon Oil Company Operations Summary Report Legal Well Name: KENAI UNIT 43-6 Common Well Name: KENAI UNIT 43-6 Event Name: RE-ENTRY Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code 6'~dbe Phase 1/18/2002 1/19/2002 1/20/2002 1/21/2002 1/22/2002 1/23/2002 18:00 - 20:30 20:30 - 22:30 22:30 - 23:30 23:30 - 02:00 02:00 - 05:30 05:30 - 06:00 06:00 - 09:30 09:30 - 11 :30 11 :30 - 14:00 14:00 - 15:30 15:30 - 16:00 16:00 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 14:00 14:00 - 16:30 16:30 - 18:30 18:30 - 19:30 19:30 - 21 :30 21 :30 - 22:00 22:00 - 01 :30 01 :30 - 06:00 06:00 - 06:30 06:30 - 09:00 09:00 - 11 :00 11 :00 - 12:30 12:30 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 22:30 22:30 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 07:30 07:30 - 10:00 2.50 TEST_ PLUGAB 2.00 TRIP - SIDET 1.00 CIRC - MUD - SIDET 2.50 TRI P - SIDET 3.50 PULD - EQIP SIDET 0.50 TRIP - SIDET 3.50 TRIP - SIDET 2.00 CHANGE EQIP SIDET 2.50 SURVEY ORIT SIDET 1.50 SURVEY ORIT SIDET 0.50 SURVEY ORIT SIDET 1.50 SURVEY ORIT SIDET 1.00 CHANGE EQIP SIDET 1.50 RUN - WSTK SIDET 10.00 MILL_ WNDW SIDET 2.00 SIDET 1.00 CIRC_ MUD - SIDET 1.00 TEST_ LOT_ SIDET 1.00 CIRC - MUD SIDET 1.00 REPAIR RIG - SIDET 2.00 TRIP - BHA_ SIDET 2.50 REPAIR RIG - SIDET 2.00 TRIP - BHA_ SIDET 1.00 PULD - BHA_ SIDET 2.00 PULD - BHA_ PR1DRL 0.50 SERVIC RIG - PR1 DRL 3.50 TRIP - BHA_ PR1 DRL 4.50 DRILL_ ROT - PR1 DRL 0.50 CIRC - MUD - PR1DRL 2.50 TRIP - BHA_ PR1DRL 2.00 PULD - BHA_ PR1 DRL 1.50 TRIP - BHA_ PR1 DRL 17.50 DRILL_ ROT_ PR1DRL 1.00 DRILL_ ROT_ PR1DRL 1.00 CIRC_ MUD - PR 1 DRL 1.50 TRIP - WIPR PR1DRL 0.50 SERVIC RIG_ PR1DRL 0.50 TRIP - WIPR PR1 DRL 12.00 DRILL_ ROT_ PR1DRL 2.00 CIRC - MUD - PR1 DRL 2.50 TRIP - WIPR PR1DRL 1.00 CIRC - MUD - PR1 DRL 2.00 TRIP - PR1DRL Start: 1/3/2002 Rig Release: 1/30/2002 Rig Number: 1 Spud Date: 1/10/2002 End: 1/22/2002 Group: Description of Operations 10min. LID test joint and install wear bushing. PIU 63/4" bit and 7 5/8"scraper. RIH and tag 75/8" EZSV@4193'. CBU X 2. POOH. LID bit and scraper. PIU and scribe whipstock BHA. PIU 6-4 3/4" DC. RIH. Cont. RIH wlwhipstock assy. CIO to long bales. RIU TDS wireline guide. RIU Gyrodata wlAPRS wireline unit. Modify TDS wireline guide to accomodate new grabber box. Run gyro going in. Orient whipstock( 45deg left of high side). Run gyro pulling out. CIO bales and elevators. Set whipstock(tag retainer @ 4193'DD). Shear mills from whipstock. Displace hole to milling fluid. Mill F/4174' to 4208(window 4174' to 4187'). Mill formation F/4208' to 4219'. Circulate and work mills through window. Perform LOT 10.7ppg(8.6MW, 3592TVD, 409PSI). CIO mud. Adjust drawworks brake. POOH. Adjust drawworks brake. Cont. POOH. LID 6-4 3/4" DC and Mill assy BHA. PIU 6 3/4" PDC bit and 4 3/4" directional BHA. Test motor and MWD. Blow down lines. Service rig. RIH to 4219'. Dir. drill and survey FI 4219' to 4287'(Rot=1 hr, Slide=3.5hrs). Very difficult to hold tool face and motor stalling. CBU and pump dry job. POOH. BIO PDC bit. MIU TCI bit. RIH w/BHA. RIH w/4" DP. Dir drill and survey F/4287' to 5250'(AST=3.9hrs ART= 7.6hrs). Rotary drill F/5250' to 5291'. Circulate bottoms up. Wiper trip to casing shoe. Service rig & top drive. TIH to bottom @ 5291'. Rotary drill F/5291' to TD @ 5740' MD 14787' TVD. Ream I backream thru numerous tight spots while drilling. Circulate bottoms up FI samples. Wiper trip to casing shoe. Wash 70' to bottom. Circulate bottoms up. Slug pipe, TOOH SLM to run production liner. Add Fine & coarse calcium carbonate to system control losses. Lose +1- 150 BBLS 9.0 PPG mud to formation last 24 hours. 1.50 TRIP _ PR1 DRL Finish TOOH WI 4" drill pipe SLM. 2.50 PULD_ DP _ PR1 DRL Hold safety meeting. LID 25 JTS 3-1/2" HWDP and steerable drilling assembly. Printed: 12/15/2005 4:32:44 PM ) ) c CEMENT JOB REPORT ) !£j CUSTOMER Marathon Oil Co LEASE & WELL NAME KENAI UNIT 43-6RD DISTRICT Ken¡:¡i SI1F & TYPF OF PLUGS DATE 15-JAN-02 I F.R. # 1001100883 SERVo SUPV. Floyd Poage Jr COUNTY ·PARISH-BLOCK Kenai Alaska TYPE OF JOB SQueeze-Perfor,:¡tion pHYSICAL S~,URRY PROPFRTIES SLURRY SLURRY WATER PUMP Bbl WGT YLD GPS TIME SLURRY PPG FT3 HR:MIN Bbl MIX WATER LOCATION 6-4N-11W DRILLING CONTRACTOR RIG # Glacier No. 1 LIST .CSG.HARDWARE SACKS OF CEMENT MATERIALS FURNISHED BY BJ Fresh Water Class G Cement Water Available Mix Water 300 295 8.4 15.8 8.4 1.15 4.94 10 60.46 44 114.461 34.68 34.68 Bbl. Available Displ. Fluid 600 Bbl. TOTAL SI7F . % EXC¡::SS DEPTH SI7E WGT. TYPE DEP,TH GRADF 7.625 26.4 CSG 5488 J-55 4 14.69 DP 4195 I PKR·CMT RET·BR PL-LlNER I PERF. DEPTH TOP CONN WELL FLUID I DFPTH BRAND & TYPE I DEPTH TOP I BTM SI7E I THREAD TYPF 12971 1 4593 5488 4 1502 FRESHWATER bl$PL;FLÜID CÄL.. PSI CAL.MÄXPSI OP. MAX MAX TBG PSI MAX eSG PSI TYPE WGT. BUMP PLUG TO REV. SQ. PSI RATED Operator RATED Operator SHOE . FLOAT , STAGE LASTCÄSING SI7F I WGT I TYPF 10.75 35.75 CSG [)1$pL.VØL.I:.lNi.~ VOLUME UOM 46 SBLS Water WGT. 8.4 MIX WATER 8.4 1614 3312 4140 3312 rig EXPLANATION: TROUBLE SETTING TOOL, RUNNING CSG, ETC. PRIOR TO CEMENTING: 10:00 20:15 20:47 2 H2O 20:50 20:53 6 H2O 21:05 2000 2000 2.7 H2O 21:17 800 0 1 7 " 21:23 1190 0 2 12.4 " 21:29 1260 0 3 8.8 " 21:36 21:42 59 crvrr @ 15. 22:04 46 H2O 22:20 22:40 23:45 PSI TO TEST BBL.CMT TOTAL PSI BUMPED BUMP FLOAT RETURNSI BBL. LEFT ON PLUG PLUG EQUIP. REVERSED PUMPED CSG Y ~ Y [Nl 0 141.1 0 SAFETY MEETING: BJ TEST LINES 5000 PSI CIRCULATING WELL - RIG ~ BJ U 1-16-02 arrive KU43-6 -rig up @ wait on rig 1-16-02 safety meeting 2 bbls ahead test surface lines to 2500 break eire. down kiUline test annulas start injection test start cmt batch start cmt downhole cmt done / start H2O displacement stop - cmt in place -unsting and bleed off-600 psi isip wash up and rig down I go home SPOT TOP OUT CEMENT y ~ SERVICE SUPERVISOR SIGNATURE: Report PMnted on: JAN-OS.{)S 17:00:20 Page 1 Jra004 Abandonment KU 43-06 e e Subject: Abandonment KU 43-06 From: Stephen Mcmains <steve_mcmains@admin.state.ak.us> Date: Fri, 02 Dee 200515:22:17 -0900 To: I{enWalsh <Iq)Walsh@MarathonOilocom> Ken, Kenai 43-06, ~ J llP' 1 ~pi 50-133-10091-00-00, I think is plugged and abandoned. The well has been re-drilled and was completed March 2002 as a gas well. We have no 10~407 for the P&A of the original well. Could you provide the correct documentation for the P&A process, thanks. Steve &;ANNEÐ DEt f: 8 2D05 1 of! 12/2/20053:22 PM Marathon Oil Company Alaska, .~gion Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 19, 2001 Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVED 3EC 2 1 200i AJaska 011 & Ga; Cons. CommLsslon Anchoraoe Attached is a sundry application for changes to the abandonment, sidetrack, and completion of well KU 43-6 in the Kenai Gas Field as we discussed on December 18, 2001. The new sidetracked completion will be named KU 43-6rd, and operations are expected to begin in early January. The proposed changes are summarized below: · Because of the height of the existing tubing head, we cannot use the BOP configuration originally submitted. We must remove the single-gate pipe rams below the mud cross. A diagram of the proposed BOP configuration is attached. Even without the single-gate pipe rams the BOP configuration meets all requirements on 20 AAC 25. The existing abandonment sundry application calls for testing the 7%" casing to 2500 psi. Because of the casing's age and burst rating, we would like to test the 7%" casing to no greater than 2000 psi. This is 50% of the rated burst on this casing string. · Since submitting the original permit-to-drill and abandonment sundry application, Marathon has decided to proceed directly with a sidetrack and not attempt a workover of well KU 43-6. The cement retainer that was originally planned to be placed at 4325' will now be placed at approximately 4200'. A whipstock will be placed on top of the retainer to make the sidetrack. The cement volume will be increased to account for the extra 125' of 7%" casing that must be filled to abandon the existing completion. Attached is an updated abandonment and completion procedure for well KU 43-6rd along with a proposed wellbore schematic. This low-pressure (1.6 ppg EMW) Sterling Pool 6 completion is being configured without a packer to produce up the 4%" liner and 7%" .casing string, as well as up tubing. Conceptually it is the same completion style as other recent wells, such as KU 21-6rd and KU 24-5rd in the Kenai Gas Field. ~eE~l~io~duc tion Engineer A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Operation Shutdown Repair Well Plugging X Pull Tubing Variance Re-enter Suspended Well Time Extensior Stimulate Perforate Other 2. Name of Operator MARATHON OIL COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 205' FNL, 1049' FEL, Sec 7, T4N, R11W, SM At top of Productive Interval At Effective Depth 1985 FSL, 1139 FEL, Sec 6, T4N, R11W, SM At Total Depth 2593' FSL, 1066' FEL, Sec 6 T4N, R1 lW, SM 5. Type of Well: DevelopmentX Exploratow.__ Stratigraphic__ Service IModifications to Abandonment & Sidetrack Proposal 6. Datum Elevation (DF or KB) 14 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 43-6 9. Permit Number 65-9 10. APl Number 50- 133-10091-00 11. Field/Pool Kenai Ga~ 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measu red true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: 78.6# 32.75# 5706 feet Plugs (measured) 4780 feet 5556 feet Junk (measured) 4661 feet Length Size Cemented Measured Depth 52' 20" N/A 1297' 10-3/4" 1450 sks 1297' 26.4# 5601' 7-~8" 700 sks 5601' measured true vertical Tubing (size, grade, and measured depth) ,SEC 2 ] 2001 Alaska 011 & Gas Cons. CommJssio~ Anchora~ True Vertical Depth Packers and SSSV (type and measured depth) 1297' 4697' B-3: 4593' - 4615', 4624'-4646';B-4: 4680' - 4702', 4708'-4730" 4821'-4837'; 4850'-487~- C-1: 5270'-5380', 5392'-5434';C.2: 5450'-5455', 5463'-5488 B-3: 3926' - 3944', 3951 '-3968' ;B-4: 3996' - 4013', 4018'-4036', 4108'-4121 '; 4131 '-414; C-1: 4456'-4539', 4548'-4580';C-2: 4592'-4596', 4602'-4621 SS 2-7/8", 6.4#, N-80 tubing to 4460' MD LS 2-7/8", 6.4#, N-80 tubing to 5154' MD Brown dual hydraulic packer @ 4451' MD Baker model D permanent packer @ 5145' MD 13. Attachments Description Summary of Proposal X Detailed Operations Program X BOP Sketch X 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 1/7/2002 16. If Proposal was Verbally Approved Oil Gas X Name %Approver ~ Date Approved Service 17. I hereby~ the foreg°~lngt~'~e and correct to the best of my knowledge. Signed k,~ %~ ~ Title Production Engineer ~ ~ - FOR COMMISSION USE ONLY Conditions of Approval: Notify Co'~nmission so representative may witness BOP Test ~ Location Clearance Plug Integrit~ Mechanical Integrity Test Suspended Date 12/19/2001 Subsequent Form Required 10-'~/-.-/Z)7 IApproval No~_.~ Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Si~ Commissioner Date I/~;Trip~l[oate Original KB-GL: 14' 205' FNL, 4231' FWL Sec. 7, T4N, R11W, S.M. Tree cxn: 6.5" Otis Tubinq (tapered string) . 0' - 40-15', 3-1/2", 9.3 ppf, L-80, EUE 8rd 4015' - 5266', 2-7/8", 6.4 ppf, L-80, ST-L (flush) IOtis XN Nipple @ 5266' ID = 2.313", no-go ID = 2.205" Directional- Existinq Hole KOP - 250' 'Build- 3 deg/100' EOB - 2300', 39 deg hole angle Directional- Proposed KOP - 4195', 35 deg hole angle Build - 4 deg/100' EOB - 4647', 39 deg hole angle (hold) KU 43-6rd - P R O P O S E D,"~ IDrive Pipe: 20", 78.6 ppf @ 52' ISurface Casinq: 10-3/4", 32.75ppf, H-40, STC @ 1297' Cmt w/1450 sks Liner Top: 4-1/2", 12.6 ppf, L-80, BTC liner top @ 4046' Baker ZXP liner-top packer @ 4045' Production Casing: 7-5/8", 26.4 ppf, J-55, LTC @ 4195' (sidetrack window) Cmt w/700 sks (Originally run to 5601', June 1965) IPool 6 Perfs (proposed) 5284'- 5500' (gross) ' Guns are 2.5", OD, 6 spf, 60-deg phase TCP guns with 50% Stimgun coverage. IProduction Liner: ~1-~.6~, ~_-80, BTC @ 4045'- 5713' Cmt w/143 sks I PBTD: 5623' TD: 5713' Well Name & Number: KU 43-6rd (Proposed) Lease I Kenai Gas Field County or Parish: Kenai I State/Prov. Alaska I Country: I USA Perforations: (MD) Pool 6, 5284' - 5500' (proposed) (TVD) 4455' - 4621' TVD BHP: I 0 BHT: 01 Completion Fluid: FWHP:I FBHP: IFWHT: I FBHT: I Other: I Date Completed: RKB: Prepared By: Gary Eller I Last Revision Date: 11/16/011 Marathon Oil Well KU 43-6RD BOP Stack I FIow Nipple 13 5/8" 5M Annular Preventer I FIow Line 13 5/8" 5M Double Ram Preventer I Pipe Ram I 3 1/8" 5M Manually Operated Valves 113 5/8" 5M Cross JBlind RamI ~ 13 1/8" 5M Hydraulically (~ I Operated Valve I ~ 13 1/8" 5M Manually I i I Operated Valve Abandonment & Completion Procedure Following Sidetrack Well KU 43-6rd Kenai Gas Field AFE 9206301 lo Call out Vetco wellhead rep. Pressure test void on 11", 3M casing head to 1400 psi (50% of collapse rating on 7%" casing). Lubricate and loosen nuts on tubing head and casing head. Release wellhead hand. . MIRU slickline on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with a PN plug. for the 2.313" .N nipple. Set plug in the N nipple at 5166'. POOH. 3. PU shifting tool for 2.313" Otis XO sliding sleeve. RIH, shift open the XO sliding sleeve at 5110'. POOH, RDMO slickline. , MIRU electric line on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with jet cutter for 2~", 6.3 ppf tubing. Tie in with CCL, make longstring tubing cut at 4335'. POOH. RU on shortstring, test lubricator to 1000 psi. RIH with jet cutter for 2~", 6.3 ppf tubing. Tie in with CCL, make shortstring tubing cut at 4435'. POOH, RDMO electric line. o M1RU pump truck. Load casing and tubing with fresh water. Do not exceed 2000 psi on 7%" casing. Fill tree with methanol to prevent freezing. RDMO pump truck. 6. Call out Vetco wellhead rep. Set BPVs in both strings and bleed off surface pressure. Fill tree with methanol. . MIRU drilling rig. Prior to ND tree, confirm that no trapped pressure exists below BPVs. ND tree. Inspect lift threads on tubing hangers. NU BOPs. (Note: Will not be able to nipple up the single-gate rams due to height of the tubing head.) Pipe rams should be equipped ~ith dual ~7/,, ~/8 , 5M rams. Pull BPVs, set 2- way checks. Test BOPE to 250/3000 psi. Pull 2-way checks. 8. Load hole with fresh water and establish circulation. Apply LCM as needed. . RU elevators, spiders, and tongs for pulling dual tubing strings. Pull dual strings of 27/s'', 6.3 ppf, N-80, BTC tubing. Lay down all tubing, checking each joint for NORM. Haul off tubing as junk. 10. Install test plug in tubing spool. Replace dual 2~", 5M pipe rams with single 5M variable rams. Test BOPE as needed. Pull test plug. Well KU 43-6rd Completion Procedure Page 2 11. PU 6%" bit, 7%" scraper, 4%" drill collars, and 4" drill pipe (15.12 ppf, S-135, HT-38) and TIH to top of fish. All drill pipe should be drifted to 2.25". Circulate BU. TOH standing back drill pipe. 12. MIRU Schlumberger. PU and RIH with cement retainer for 7%", 26.4 ppf casing. Tie in with CCL, set retainer at approximately 4200' (Note: Want to position the retainer so that the whipstock can be set for a kickoff at 4195'. Avoid a setting depth that would require the window to be cut through a casing collar.) POOH, RDMO Schlumberger 13. RIH with drill pipe and sting into cement retainer. Test backside to 2000 psi (50% of burst of 7%" casing). Establish injection rate below cement retainer with fresh water. 14. MIRU cementing unit, pressure test lines. Bullhead 198 sx of class "G" cement (weight = 15.8 ppg, yield = 1.15 ft3/sack) below the cement retainer to abandon the perfs from 4593' - 4872'. The perfs from 5270' - 5488' are isolated by the PN plug (see step #2) and cement. Displace cement to the top of the retainer with contaminated fluid. Sting out of the retainer, reverse out any remaining cement. Do not exceed 2000 psi while reversing. Pressure test the 7%" casing and retainer to 2000 psi../RDMO cementing unit. TOH with drill pipe. 15. ND BOPE and the old 9", 3M tubing head. NU the new 11", 3M/tubing head. Test void to 1400 psi. NU BOPE. Set test plug and test BOPE.' Pull test plug, install wear bushing. 16. PU 6%" bit and TIH. Drill out cement to the top of the cement retainer at _+4200'. TOH. Note: The remainder of the procedure assumes that a whipstock is set on top of the cement retainer at _+4200'. The desired kickoff point is 4195' with a 6%" hole. The procedure assumes that a 6%" hole has been drilled to _+5713', and the decision has been made to complete the well. 17. Condition hole in preparation for running 4~" liner. Install long bales. 18. MU and RIH with 4V2", 12.6 ppf, L-80, IBT liner on 4" drill pipe. Liner will have a float shoe, one 4V2" shoe joint, float collar, one 4V2" joint, landing collar, and approximately 1700' of 4V2" liner, and a Baker model HMC liner hanger. A radioactive pip should be placed in one of the 4V2" casing collars at approximately 5100' MD. Place centralizers as per instructions of Drilling Engineer. RIH to TD and set hanger. Well KU 43-6rd Completion Procedure Page 3 19. Set HMC liner hanger. Cement liner in place as per separate cementing design. Displace cement with mud. Release hanger setting tool and TOH one stand. Reverse out contaminated cement to surface. TOH. 20. PU and TIH with ZXP liner-top packer. Set packer on top of liner hanger. Test liner-top packer to 19.0 ppg EMW. TOH. 21. PU and TIH with a 3~" bit, 4~" casing scraper, 2~" drill pipe (10.4 ppf, X-95 pipe with 2%" SLH90HT tool joints ) to the top of the liner, 7%" casing scraper, and 4" HT-38 drill pipe. Clean 4~" liner out to PBTD. 22. Swap hole over to fresh water by circulating a SafeKleen pill and fresh water at maximum rate. Circulate one full hole volume. Short-trip until the 7%" scraper is to surface, then TIH to bottom. Circulate one bottoms up volume with fresh water at maximum rate. 23. When returns are clean TOH laying down drill pipe. Pull wear bushing. 24. MIRU Schlumberger. RIH with RST log. Log as per instructions of Geologist, but the log should cover at least the entire length of the 4~" liner. POOH, RD Schlumberger. 25. PU and TIH with the completion string consisting of 100' of 3%", 6 spf TCP guns, 2%" gun drop assembly, drop-bar firing head, crossover to 2~" flush-joint tubing (6.3 ppf, L-80, Grant-Prideco ST-L connections), one joint of slotted 2~" tubing, XN nipple (minimum I]2) = 2.205"), 2~" flush joint tubing to 40' above the liner top, crossover, and 3~" tubing (9.3 ppf, L-80, EUE 8rd) to surface. All tubing should be rabbited prior to installation. 26. When guns are approximately on depth, hang off the tubing in the slips and RU Schlumberger. RIH with a GR/CCL. Tie in the RST log obtained in step #22. Determine correction needed to put guns on depth. POOH, RDMO wireline. 27. Space out tubing. MU mandrel tubing hanger and landing joint. Land tubing. Run in lock-down pins. Close annular BOP, test hanger seals to 1500 psi. Bleed off pressure, open annular BOP. LD landing joint. Pump 20 bbl of diesel into annulus while taking returns up the tubing. Install 2-way check in tubing hanger. 28. ND BOPE, NU tree. Orient tree as per instructions of Brent Senette (283-1301). Test tree to 2000 psi using methanol. Pull 2-way check, but do not install BPV. RDMO drilling rig. 29. Remove 7-1/16", 3M blind flange. Pull 6" BPV in tubing head side outlet. NU 7- 1/16" 3M valve and remainder of tree valves. Use a 6" 2-way check to test the first 7-1/16", 3M valve. Fabricate, install, and test spool pieces to towline. Well KU 43-6rd Completion Procedure Page 4 30. MIRU nitrogen pump onto the 7%" casing and flowback tank onto the tree top. Pressure test lines to 3000 psi. Reverse out completion fluid using nitrogen. Do not exceed 2000 psi casing pressure. Total estimated recovery = 194 bbl. After all expected fluid is recovered, shut-in returns and continue to pressure up casing with nitrogen to 1500 psi. RDMO nitrogen unit. 31. Prepare to drop bar to fire TCP guns. Hold safety meeting. Install SPIDR gauge on annulus. When ready, drop the bar to fire the guns. Monitor annulus pressure, tubing pressure, and noise for indications of guns firing. When guns have fired, produce well back to flowback tank. 32. When nitrogen has sufficiently purged and well is producing adequately, turn well over to sales. Produce as per instructions of Production Engineer. JGE - December 19, 2001 pl P Iil I IxOI A 1 ,xo--i I B-3 Sd: B-4 Sd. ~4 B-4 Sd. 10",.4 Lower C-1 Sd. C-2Sd. i_.,..~., ,.,, ® Upper C-1 Sd. I WELL KU 43-6 CASING & ABANDONMENT DETAIL I. Rotary Table al 0.0' II. Cameron Dual Tubing Hanger al 12.70' III. 20°. 78.6~, 0rive Pipe at 52' IV. 10-314°. 32.75H. H-40 Casing az 1.297' V. E.T.D, (Junk) at 5.556' VI. 7-518'. 26.4~, J-55 Casing at 5,601' ~,1~,~7 LONG TUBING DETAIL $'/'RING: 2- 7/8 ", 6.4 ~, N-80 TUBING 1. Otis"XO" Sleeve a! 4.416.62' 2. Brown Husky Dual Packer at 4,451.88' 3. Baker Blast Joints From 4.584.19' to 4.654.18' 4. Baker Blast Joints From 4,670.43' to 4.741.23' 5. Baker Blast Joints From 4,810.20' to 4.881.00' 6. Otis 'XO' Sleeve al 5.109.75' 7. Baker Locator Sub at 5.144.30' 8. Baker MoOel 'D° Perm. Packer W/Seal Asseml~ly at 5,145.30' 9. Otis 'N' Nioole at 5,165.85' 10. Bottom of Mule Shoe al 5,169.26' SHORT STRING: 2-7/8", 6.,4~., N-80 TUBING A. Otis 'XO' Sleeve at 4.382,78' B. 2-7/8' x 2-315' x-over at 4.448.88' C. Brown Husky Dual Packer at 4,451.88' O. X-over at 4,458.39' E. Otis 'N' NiDDIe al 4.463.34' PERFORATION RECORD DA TE 6/12/65 8/26/74 8/27/74 INTER VA L 4,593'-4.615' 4,624'-4.646' 4,680'-4.702' 4,708'-4.730' 4,821'-4.837' 4,850'-4,872' 5.270'-5,380' 5.392'-5,434' 5,450°-5,455. 5.463'-5,488' 5,392'-5,434' C ONDI TION B-3 Sd. ProauctJofl B-4 sd. Procluctiofl Uglier C-1 Sd. ProOuctJon Lower C-1 Sd. ProOuctJon C-2 Sd. Procluction Lower C-1 Sd. Procluct~on (M. arathon Od Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 December 5, 2001 Mr. Tom Maunder Alaska Oil & Gas COnservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KU 43-6 Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for Marathon well to abandon zones prior to sidetrack. If you need any additional information, I can be reached at 907-564-6317 or by e-mail at dmtitus@marathonoil.com. SincerelY, Denise M. Titus Production Engineer RECEIVED Na~ 0il & Gas C0~, Ca~issi0n ORIGINAL O:\EXCEL~OG CCsund. X LS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation Shutdown Re-enter Suspended Well . Alter Casing Repair Well Plugging~ Time Extensior Stimulate _ Change Approved Program __ Pull Tubing Variance Perforate__ Other 2. Name of Operator s. Type of Well: 6. Datum Elevation (DF or KB) MARATHON OIL COMPANY Development X 14 feet 3. Address Exploratory 7. Unit or Property Name P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic Kenai Unit 4. Location of Well at Surfacto ,~ ~ Service . 8. Well Number 205' FNL, 1049' FEL,Sec 7, T4N, R1 lW, SM KU 43-6 At top of Productive Interval 9. Permit I~mber Abandon Prior to Sidetrack 65-9 At Effective Depth 10. APl Number 1985 FSL, 1139 FEL, Sec 6, T4N, R11W, SM 50- 155-10091-00 At Total Depth 11. Field/Pool 2593' FSL, 1066' FEL, Sec 6 T4N, R1 lW, SM Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured 5706 feet~ Plugs (measured) true vertical 4780 feet Effective Depth: measured 5556 feet Junk (measured) true vertical 4661 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 78.6# 52' 20" N/A Surface 32.75# 1297' 10-3/4" 1450 sks 1297' 1297' Intermediate Production 26.4# 5601' 7-5/8" 700 sks 5601' 4697' Liner Perforation Depth: measured B-3: 4593' - 4615', 4624'-4646';B-4: 4680' - 4702', 4708'-4730" 4821 '-4837'; 4850'-487z- C-1: 5270'-5380', 5392'-5434';C-2: 5450'-5455', 5463'-5488 true vertical B-3: 3926'-3944', 3951'-3968';B-4: 3996'-4013', 4018'-4036', 4108'-4121'; 4131'~1~~'~,~;~ ~ ~l,~'~'n C-1: 4456'-4539', 4548'-4580';C-2: 4592'-4596', 4602'-4621 Tubing (size, grade, and measured depth) SS 2-7/8", 6.4#, N-80 tubing to 4460' MD LS 2-7/8", 6.4#, N-80 tubing to 5154' MD DEC 0 6 ~001 Packers and SSSV (type and measured depth) Brown dual hydraulic packer @ 4451' MD Baker model D permanent packer @ 5145' MD An~,hhn:v~ 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sket~ ...... "~" 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 11/12/2001 16. If Proposal was Verbally Approved Oil Gas X Suspended · Name of Approver Date Approved Service 17. I hereby c~tify that the foregoing is true and correct to the best of my knowledge. Signed l~J~ ~/~J~ Title Production Engineer Date 12/5/2001 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness I Approval No. Plug Integrity__ BOP Test__ Location Clearance_.._I ~ Mechanical Integrity Test Subsequent Form Required 10- Approved by Order of the Commission ~~1~)~" ~ -'"' ~ ~O1-~-~ Commissioner Date Form 10-403 Rev. 06/15/88 ORIGINAL Submit in Triplicate Marathon Oil Company Alaska Region Well KU 43-6 Kenai Gas Field, Pad 41-7 Abandonment Procedure AFE # 9206301 Objective: A sidetrack procedure is being prepared in the event that the dual packer cannot be pulled free. Before setting a whipstock to sidetrack, the both perforated intervals must be plugged and abandoned. Procedure: MIRU slickline on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with a PN plug for the 2.313" N nipple. Set plug in the N nipple at 5166'. POOH, RDMO slickline. 2. MIRU electric line on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with jet cutter for 2~', 6.3 ppftubing. Tie in with CCL, make longstring tubing cuts at 5130' and 4470', and 4335'. POOH. RU on shortstring, test lubricator to 1000 psi. RIH with jet cutter for 2~", 6.3 ppf tubing. Tie in with CCL, make shortstring tubing cut at 4435'. POOH, RDMO electric line. . Set BPVs in both strings and bleed off surface pressure. MIRU workover rig. ND tree, NU BOPs and test. Pull dual strings of 2~A'' tubing. Perform workover as per separate procedure. Note: The remainder of this procedure assumes that the Husky dual packer at 4452' could not be pulled, and the decision has been made to sidetrack the well. The following steps will plug and abandon the existing perfs and prep the well for sidetracking operations. . PU cement retainer for ~8,26.4 ppf casing and TIH on 4" drill pipe. Set retainer at 4325' (i.e. 10' above cut longstring tubing). Establish injection rate below cement retainer with fresh water. Test backside to 2500 psi. . MIRU cementing unit, pressure test lines. Bullhead 167 sx of class "G" cement (weight = 15.8 ppg, yield = 1. t5 fi3/sack) below the cement retainer to abandon the perfs from 4593' - 4872'~ The perfs from 5270' - 5488' are isolated by the PN plug (see step #1) and cement. Displace cement to the top of the retainer with contaminated fluid. Sting out of the retainer, reverse out any remaining cement. Pressure test the 7%" casing and retainer to 2500 psi. RDMO cementing unit. TOH with drill pipe. 6. Prepare to run whipstock and proceed w/sidetrack. Desired kick-off point is 4195'. Attachment Cement Volumes: Long string perfs (5270' - 5488'): Isolated with PN plug at 5166'. A cement cap, as per calculations below, will be placed on top of the PN plug. Short string perfs (4593' - 4872'): Minimum cement plug length (spans perfs by 100'): 4493' -4972' Designed cement plug length: 4470' - 5110' Casing volume factor in 7 5/8", 26.4 ppfless one 2-7/8" tbg string: 0.2523 ft3/Pt Calculated cement volume: 161 ft3 Density: 15.8 ppg, Yield: 1.15 ft3/sx Cement: 140 sx Cement below retainer: Cement retainer: 4325' Dual packer: 4452' Casing volume factor in 7 5/8", 26.4 ppfless two 2-7/8" tbg strings: 0.2397 ft3/ft Calculated cement volume: 30 ft3 Density: 15.8 ppg Yield: 1.15 fi3/sx Cement: 27 sx pi P WELL K U 43-6 II Iil B-3 Sd: B-4 Sd. B-4 Sd. Upper C-1 Sd. Lower IxO¢ A ~5 ! i CASING & ABANDONMENT DETA,IL I. Rotary Table at 0.0' II. Cameron Dual Tubing Hanger at 12.70' II!. 20°, 78.6~*, Drive Pipe at 52' IV. 10-3/4°, 32.75~', H-40 Casing at 1,297' V. E.T.D. (Junl~) at 5,556' VI. 7-5/8°, 26.4~,, J-55 Casing at 5,601' LONG TUBING DETAIL $TRING: 2- 7/8 °, 6.4 ~, N-8 0 TUBING 1. Otis "XO" Sleeve a% 4,416.62' 2. Brown HusKy Dual Pacl~r at 4,451.88' 2. Baker Blast Joints From 4,584.19' to 4,654.18' 4. Baker Blast Joints From 4,670.43' to 4,741.23' 5. BaiLer Blast Joints From 4,810.20' to 4,881.00' 6. Otis 'XO° Sleeve at 5,109.75' 7. Baker Locator Sub at 5,144.30' 8. Ba~er Moclel 'D° Perm. PacKer W/Seal AssemDly ~t 5,145.30° 9. Otis 'N' NiDDle at 5,165.85' 10. Bottom of Mule Shoe at 5,169.26' SHORT STRING: 2-7/8", 6.4.,-~, N-80 TUBING A. Otis 'XO' Sleeve at 4,382.78' B. 2-718' x 2-3/B' x-over at 4,448.88' C. Brown HusKy Dual PacKer a~ 4,451.88' D. X-over at 4,458.;39' E. Otis 'N' NioDle at 4,463.34' PERFORATION RECORD DA TE INTER VA L 6/12/65 4,593'-4,615' 4,624'-4,646' 4,680'-4,702' 4,708'-4,730' 4,821'-4,837' 4,850'-4,872' 5,270'-5,380' 5,392°-5,434' 8/26/74 5,450'-5,455' 5,463'-5,488' 8/27/74 5.392'-5,434' CONDITION B-3 Sd. Proauct~on B-4 Sd. ProOuction UDDer C-1 Sd. Procluclion Lower C-1 Sd. Proauction C-2 Sd. Procluction Lower C-1 Sd. Procluctlon ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 05~08/98 -+ PERMIT I API I WELL NUMBER NUMBER NAME .......................... 65-0009-0 1331009100 KENAI I/NIT 43-06 070 FEDA028142 05546 + IPER OPERJ%TOR )DE I NAME 1129000 MARATHON OIL CO FLDPOL FIELD AND POOL CODE I NAME ...... 448564 KENAI, STERLING 5.1 + ON-OFF NUM CODEI ...... I AREA ~HORE CMP 820 COOK INLET BASIN ON 0 MULTIPLE POOLS 448568 000000 000000.000000 000000 + UNIT UNIT CODE I NAME 51120 KENAI + ELEVAT IONS KB 92 00 DEPTHSi ILsE MD [ TVD COD ............. 5706 4780 20C -+ SURFACE LOCATION 0205 N 4231 W 07 04N 011W S BOTTOM HOLE LOCATION 2687 S 4214 W 06 04N 011W S + + ................................. 65 5706 + INITIAL FINAL CURRENT REQUIREMENTS FRM ACCTG CLASS STATUS CLASS STATUS CLASS STATUS SAMPL MUD SUR OTHER TST DEV 2 -GAS DEV 2 -GAS 000 00000 RCV 44001 + -+ PERMIT I PERMITI DATE I DATE I STATUS I RECORD 04/26/65 04/26/65 05/26/65 06/13/65 01/11/95 + + ALAS~ INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 WELL-NAME: KENAI UNIT 43-06 FIELD/POOL: KENAI, STERLING 5.1 1965 JAN FEB MAR METH DAYS OIL WTR GAS 1965 TOTALS OIL WATER · 1{ JAN FEB MAR ME~'H FLOWING FLOWING DAYS 4 3 OIL ~WTR GAS 36,104 32,506 1966 TOTALS OIL WATER 1967 JAlg FEB bL~.R MET}{ FLOWING FLOWING FLOWING DAYS 21 24 11 OIL WTR GAS 181,869 240,616 121,889 1967 TOTALS OIL WATER 1968 JAN FEB MAR METH FLOWING FLOWING FLOWING DAYS 30 20 25 OIL WTR 317,594 220,403 268,280 . TOTALS OIL WATER 1969 JAN FEB METH FLOWING FLOWING DAYS 19 27 OIL WTR GAS 175,231 286,289 1969 TOTALS OIL API: 133-10091-00 LEASE: FEDA028142 OPERATOR: MARAT}{ON OIL CO APR APR FLOWING 8 57,455 APR FLOWING 13 124,503 APR FLOWING 23 242,439 SALES CD - 44 ACCT GRP - 001 ** GAS PRODUCTION ** FINAL STATUS: DEV 2-GAS CURRENT STATUS: 000 00000 MAY JUN JUL AUG SEP OCT FLOWING FLOWING FLOWING 1 1 1 NOV DEC 400 GAS 6,456 CUM OIL 1,542 4,514 CUM WATER CUM GAS 6,456 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING' FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 20 30 30 23 3 30 28 15 188,867 309,663 314,970 259,332 GAS 1,957,713 CUM OIL 38,436 321,795 256,626 141,959 CUM WATER CUM GAS 1,964,169 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 29 29 29 30 26 29 30 305,403 294,444 287,080 295,046 GAS 3,003,104 CUM OIL MAY JUN JUL AUG FLOWING FLOWING FLOWING FLOWING 24 24 28 20 267,384 262,933 274,394 208,898 GAS 2,864,144 CUM OIL MAR APR MAY JUN FLOWING FLOWING FLOWING FLOWING 28 26 27 22 290,228 WATER 296,875 294,872 256,148 CUM WATER SEP OCT FLOWING FLOWING 26 14 .288,456 312,778 CUM GAS 4,967,273 NOV DEC FLOWING FLOWING 12 29 305,645 131,835 106,899 257,440 CUM WATER CUM GAS 7,831,417 OCT 'NOV DEC FLOWING FLOWING FLOWING 10 29 18 JUL AUG SEP 1970 JAN FEB MAR APR MET}{ FLOWING FLOWING FLOWING FLOWING DAYS 19 15 25 29 OIL WTR GAS 226,700 166,835 255,863 297,611 1970 TOTALS OIL WATER 305,241 219,816 GAS 2,088,116 CUM OIL CUM WATER 92,576 225,014 196,846 CUM GAS 9,919,533 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 25 30 31 31 30 29 29 29 256,034 355,142 347,660 347,048 357,124 322,465 299,905 293,739 GAS 3,526,126 CUM OIL CUM WATER CUM GAS 13,445,659 AIJ~S~ INDIVIDUltL WELL PRODUCTION AS OF 05/08/98 1971 JD/q FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 26 27 31 27 OIL WTR GAS 224,113 242,936 255,711 281,704 1971 TOTALS OIL WATER 1972 JAN FEB Fair APR METH FLOWING FLOWING FLOWING FLOWING DAYS 20 19 8 1 OIL WTR G~" 181,944 45,535 73,694 6,733 1 ._ TOTALS OIL WATER 1973 JAN FEB M3~R APR METH FLOWING FLOWING FLOWING FLOWING DAYS 20 26 22 20 OIL WTR GAS 202,244 238,749 212,337. 190,943 1973 TOTALS OIL WATER . 1974 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 26 25 3 2 OIL WTR GAS 208,091 281,936 35,822 20,843 1974 TOTALS OIL WATER 1975 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING Do~¥S 26 19 23 20 GAS 290,969 210,295 252,481 224,103 1975 TOTALS OIL WATER 1976 JAN FEB METH FLOWING FLOWING DAYS 25 22 OIL WTR GAS 249,307 210,052 1976 TOTALS OIL 1977 JAN FEB METH FLOWING FLOWING DAYS 30 28 OIL WTR GAS 248,487 228,521 1977 TOTALS OIL MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 10 31 31 29 29 27 22 100,208 317,140 322,213 GAS 2,682,255 CUM OIL 288,764 CUM WATER 274,303 175,334 CUM GAS 199,829 16,127,914 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 6 20 11 30 26 30 10 2 272,293 318,186 59,469 191,425 99,935 GAS 1,605,127 CUM OIL 93,947 CUM GAS 244,967 CUM WATER 16,999 17,733,041 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 17 16 6 20 25 28 28 15 241,961 CUM WATER 154,732 209,863 70,015 GAS 2,537,781 CUM OIL 326,384 CUM GAS 208,246 313,133 169,174 20,270,822 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 27 7 18 18 26 17 30 31 276,519 CUM WATER 336,961 CUM GAS 184,688 197,237 242,169 84,121 198,576 GAS 2,417,917 CUM OIL 350,954 22,688,739 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 10 16 26 26 21 28 .14 22 127,793 CUM GAS 283,430 212,081 CUM WATER 110,338 176,660 281,416 GAS 2,649,429 CUM OIL 274,675 205,188 25,338,168 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING FLOWING 8 19 68 22 29 27 31 29 30 246,459 CUM GAS 76,845 205,263 WATER 234,704 183,232 GAS 2,413,521 CUM OIL 229,844 CUM WATER 251,445 262,018 264,352 27,751,689 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 22 10 21 23 26 24 25 15 24 31 117,293 185,161 81,285 170,473 190,472 256,370 WATER GAS 2,457,450 CUM OIL 237,873 240,836 CUM GAS 192,769 CUM WATER 307,910 30,209,139 i~LASKA INDIVIDUAL WELL PRODUCTION AS OF 05108198 1978 JAN FEB METH FLOWING FLOWING DAYS 28 28 OIL WTR GAS 238,337 245,317 1978 TOTALS OIL 1979 JAN FEB METH FLOWING FLOWING DAYS 23 28 OIL i, 215,104 314,132 ~ TOTALS OIL 1980 JAN FEB METH FLOWING FLOWING DAYS 23 12 OIL WTR GAS 221,008 109,717 1980 TOTALS OIL 1981 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR GAS 300,432 289,558 1981 TOTALS OIL 1982 JAN FEB METH FLOWING FLOWING v$ 31 28 · ~ 32 28 GAS 306,076 296,672 1982 TOTALS OIL 1983 JAN FEB METH FLOWING FLOWING DAYS 31 27 OIL WTR 20 22 GAS 224,705 177,761 1983 TOTALS OIL 1984 JAN FEB METH FLOWING FLOWING DAYS 31 29 OIL WTR 8 8 GAS 178,625 176,827 1984 TOTALS OIL MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 30 28 29 16 26 18 26 31 14 20 237,452 208,450 236,783 105,727 248,778 WATER GAS 2,541,524 CUM OIL 172,886 242,501 CUM WATER 292,106 125,842 CUM GAS 187,345 32,750,663 MAR APR MAY J-JN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 15 30 24 17 29 3 27 26 183,375 31,593 276,916 265,988 159,432 305,538 234,440 WATER GAS 2,799,145 CUM OIL 266,813 CUM GAS 279,782 CUM WATER 266,032 35,549,808 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 2 15 14 23 9 16 5 16 30 31 41,877 CUM WATER 16,004 134,005 127,560 230,536 80,064 WATER 7,132 GAS 1,896,285 .CUM OIL 302,570 CUM GAS 155,882 147,210 7,132 7,132 329,852 37,446,093 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 29 28 20 27 28 28 29 31 30 31 293,004 CUM WATER 91 336,305 CUM GAS 31 338,318 7,341 275,528 282,991 289,723 201,928. 273,060 278,597 WATER 209 GAS 3,491,174 CUM OIL 87 331,730 40,937,267 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 10 25 29 30 31 29 29 23 22 29 22 169,690 CUM GAS 16 250,340 18 234,514 CUM WATER 30 29 8 14 15 107,500 229,147 271,375 279,422 282,304 WATER 264 GAS 2,840,468 CUM OIL 24 190,443 7,605 28 222,985 43,777,735 MAR APR MAY JI3-N JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING FLOWING 31 17 30 21 29 30 31 30 31 3 162,002 CUM WATER SEP FLOWING 30 20 11 14 18 177,845 98,272 193,492 129,459 WATER 125 GAS 1,881,681 CUM OIL 6 162,146 AUG FLOWING 31 159,466 180,218 CUM GAS NOV FLOWING 30 162,123 CUM GAS MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 31 30 31 13 10 13 9 9 169,728 168,836 134,805 163,546 170,783 WATER 70 GAS 1,975,202 CUM OIL 157,444 CUM WATER 3 185,304 7,730 OCT FLOWING 31 165,257 7,800 8 190,477 45,659,416 DEC FLOWING 31 167,762 47,634,618 ALASKA INDIVIDUDJ~ WELL PRODUCTION AS OF 05/08/98 1985 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR GAS 153,119 156,978 1985 TOTALS OIL 1986 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR 4 3 G ' 116,719 111,680 1~ TOTALS OIL 1987 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR 11 8 GAS 126,374 117,905 1987 TOTDJ~S OIL 1988 JAN FEB METH FLOWING FLOWING DAYS 31 29 OIL WTR 3 GAS 141,257 126,827 1988 TOTALS OIL 1989 JAN FEB METH FLOWING FLOWING DAWS 31 28 GAS 112,219 110,175 1989 TOTALS OIL 1990 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR 8 GAS 100,543 82,811 1990 TOTALS OIL 1991 JAN FEB METH SHUT-IN FLOWING DAYS 9 OIL WTR GAS 10,445 1991 TOTALS OIL MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 28 30 31 31 30 31 30 31 10 159,409 138,679 133,067 146,789 145,517 WATER 30 GAS 1,750,991 CUM OIL 3 147,375 7 147,688 CUM WATER 3 158,105 7,830 150,532 CUM GAS 7 113,733 49,385,609 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 26 27 30 31 30 31 30 31 6 5 16 2 2 104,775 92,803 103,370 91,341 98,447 .WATER 65 GAS 1,270,425 CUM OIL 1 106,218 CUM WATER SEP FLOWING 30 6 107,698 CUM WATER MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 31 30 31 9 7 126,944 98,650 111,845 95,011 115,526 WATER 70 GAS 1,449,792 CUM OIL 11 116,455 7,895 OCT FLOWING 31 137,775 7,965 95,972 3 120,169 CUM GAS NOV FLOWING 30 146,123 CUM GAS AUG FLOWING 28 9 112,036 12 112,476 .50,656,034 DEC FLOWING 31 2O 153,905 52,105,826 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 28 30 31 31 30 31 30 31 114,824 CUM GAS 86,514 92,491 CUM WATER 3 3 119,080 106,821 97,349 104,045 102,185 WATER 9 GAS 1,337,920 CUM OIL 125,975 7,974 120,552 53,443,746 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING 'FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 29 30 31 31 30 31 30 27 94,710 123,346 115,260 96,554 94,078 97,717 WATER GAS 1,221,643 CUM OIL 109,845 7,974 93,361 CUM WATER 104,459 CUM GAS 69,919 54,665,389 MAR APR MAY JUN JUL AUG SEP OCT' NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING ,FLOWING 29 21 21 14 7 4 7 7 9 1 9,657 7,990 51,130 4,662 2,300 3,073 349 WATER 16 GAS 264,122 CUM OIL 8 904 5,998 CUM GAS 1,877 CUM WATER MAR APR MAY JUN JUL AUG SEP OCT NOV SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM WATER CUM GAS WATER GAS 10,445 CUM OIL 7,990 818 54,929,511 DEC SHUT- IN 54,939,956 /ELASK3% INDIVIDUAL WELL pRODUCTION AS OF 05/08/98 1992 JAN METH SHUT- IN DAYS OIL WTR 1992 TOTALS OIL 1993 JAN METH SHUT-IN DAYS OIL 1~ TOTALS OIL 1994 JAN METH SHUT-IN DAYS OIL WTR GAS 1994 TOTALS OIL 1995 JAN METH SHUT-IN 'DAYS OIL WTR GAS 1995 TOTALS OIL 1996 JAN METH SHUT-IN W~vS GAS 1996 TOTALS OIL 1997 JAN METH SHUT-IN DAYS OIL WTR GAS 1997 TOTALS OIL 1998 JAN METH SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SRTJT-IN SHUT-IN SHUT-IN SHUT-IN SI47JT-IN FEB St{UT- IN FEB SHUT- IN FEB ' .SHUT- IN FEB SHUT- IN FEB SHUT-IN FEB SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SFHJT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN. SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL ~ APR MAY JD-N JUL SHUT-IN WATER GAS CUM OIL AUG SHUT- IN AUG SHUT-IN AUG SHUT-IN AUG SHUT-IN AUG SHUT-IN AUG CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP CUM WATER 7,990 OCT SHUT-IN 7,990 OCT SHUT- IN 7,990 OCT SHUT- IN 7,990 OCT SHUT- IN 7,990 OCT SHUT- IN 7,990 OCT 7,990 CUM GAS NOV SHUT- IN CUM GAS NOV SHUT-IN CUM GAS NOV SHUT-IN CUM GAS NOV SHUT-IN CUM GAS NOV SHUT-IN CUM GAS NOV CUM GAS 54,939,956 DEC SHUT-IN 54,939,956 DEC SHUT- IN 54,939,956 DEC SHUT- IN 54,939,956 DEC SHUT-IN 54,939,956 DEC SHUT-IN 54,939,956 DEC 54,939,956 ALASKA INDIVIDUAL WELL PRODUCTION AS OF os/o8/98 FIELD/POOL: KENAI, STERLING 6 1965 JAN MET}{ DAYS OIL WTR GAS 1965 TOTALS OIL FEB 1966 JAN FEB MET~ FLOWING WTR GAS 33,002 1966 TOTALS OIL WATER APR SALES CD - 44 ACCT GRP - 001 ** GAS PRODUCTION ** MAY JUN JUL FLOWING 1 500 GAS 500 CUM OIL MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 4 11 19 30 31 88,094 52,644 WATER 1967 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 30 28 1 13 OIL 'WTR GAS 288,568 275,814 12,500 134,216 1967 TOTALS OIL WATER 191,524 316,693 329,783 GAS 2,007,841 CUM OIL 1968 JAN FEB METH FLOWING FLOWING DAYS 29 25 OIL WTR GAS 347,336 254,330 311,698 254,567 1968 TOTALS OIL WATER .( JAN FEB MAR APR M~ H FLOWING FLOWING FLOWING FLOWING DAYS 21 25 30 14 OIL WTR GAS 229,953 286,505 332,228 156,253 1969 TOTALS OIL WATER 1970 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 22 25 25 28 OIL WTR GAS 222,695 248,041 234,101 265,169 1970 TOTALS OIL WATER MAY JUN JUL FLOWING FLOWING FLOWING 30 28 26 312,017 288,666 272,829 GAS 2,906,679 CUM OIL MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 27 27 25 20 26 284,399 164,376 208,304 GAS 3,026,302 CUM OIL MAY JUN FLOWING FLOWING 18 18 FINAL STATUS: DEV 2-GAS CURRENT STATUS: 000 00000 195,028 184,922 GAS 2,036,729 CUM OIL AUG SEP OCT NOV DEC CUM WATER CUM GAS 500 AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING 21 3 30 20 15 257,323 32,372 335,190 217,105 154,111 CUM WATER CUM GAS 2,008,341 AUG SEP OCT NOV DEC FLOWING FLOWING ' FLOWING FLOWING FLOWING 31 28 24 23 21 310,911 254,725 250,564 235,750 270,119 CUM WATER CUM GAS 4,915,020 AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING 21 25 14 21 30 256,048 285,273' 134,418 218,329 307,224 CUM WATER CUM GAS 7,941,322 JUL AUG SEP CUM WATER OCT NOV DEC FLOWING FLOWING FLOWING 9 25 28 95,979 269,950 285,911 CUM GAS 9,978,051 297,539 310,469 287,730 330,515 255,089 333,214 218,241 273,568 GAS 3,276,371 CUM OIL CUM WATER CUM GAS 13,254,422 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 28 27 24 31 25 31 23 30 ALASKA INDIVIDUAL WELL PRODUCTION AS OF os'/o8/98 1971 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR GAS 262,447 247,590 1971 TOTALS OIL 1972 JAN FEB METH FLOWING FLOWING DAYS 26 21 OIL WT~ G~,~ 296,086 242,404 1 z TOTALS OIL 1973 JAN FEB METH FLOWING FLOWING DAYS 29 14 OIL WTR GAS 303,601 125,640 1973 TOTALS OIL 1974 JAN FEB METH FLOWING FLOWING DAYS 6 4 OIL WTR GAS 87,188 34,228 1974.TOTALS OIL 1975 JAN FEB METH FLOWING FLOWING DW~q 29 24 GAS 265,088 222,697 1975 TOTALS OIL 1976 JAN FEB METH FLOWING FLOWING DAYS 19 25 OIL WTR GAS 161,466 205,959 1976 TOTALS OIL 1977 JAN FEB METH FLOWING FLOWING DAYS 18 28 OIL WTR GAS 137,740 214,085 1977 TOTALS OIL MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 29 21 11 31 31 22 6 9 31 240,049 212,385 109,317 320,445 WATER GAS 2,442,386 CUM OIL 304,312 231,088 CUM WATER 57,277 109,737 CUM GAS 347,739 15,696,808 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 11 6 15 20 16 31 20 5 5 26 321,610 46,971 121,295 74,086 184,489 220,348 230,417 WATER GAS 2,295,575 CUM OIL 55,719 CUM GAS 227,064 CUM WATER 275,086 17,992,383 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 13 23 31 22 6 12 25 4 13 5 277,386 CUM WATER 127,547 229,463 310,882 210,223 75,957 WATER GAS 2,017,714 CUM OIL 133,341 CUM GAS 127,186 41,143 55,345 20,010,097 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC SHUT-IN FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 11 12 28 31 17 25 26 27 30 219,217 CUM WATER 246,463 CUM GAS 235,090 177,143 131,203 134,765 309,903 312,235 WATER GAS 2,157,324 CUM OIL 269,889 22,167,421 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 29 16 23 24 23 11 17 31 30 30 252,310 CUM GAS 99,947 144,931 CUM WATER 271,926 154,624 208,558 225,972 211'526 WATER GAS 2,5'77,194 CUM OIL 264,359 255,256 24,744,615 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING FLOWING 26 27 27 21 28 17 31 26 12 233,114 214,407 220,694 233,256 156,270 WATER GAS 2,173,812 CUM OIL 257,881 142,326 CUM WATER 200,749 CUM GAS 147,690 26,918,427 F[AR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 29 12 3 13 19 17 30 25 27 24 180,479 216,327 66,090 23,423 112,467 170,293 WATER GAS 1,932,801 CUM OIL 152,985 224,215 CUM GAS 217,769 CUM WATER 216,928 28,851,228 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05~08/98 1978 JAN FEB METH FLOWING FLOWING DAYS 29 27 OIL WTR CxAS 228,742 207,118 1978 TOTALS OIL 1979 JAN FEB METI~ FLOWING FLOWING DAYS 31 28 OIL WT Gi~, 248,120 288,112 ~ TOTALS OIL 1980 JAN FEB METH FLOWING FLOWING DAYS 31 29 OIL WTR GAS 264,060 237,058 1980 TOTALS OIL 1981 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR GAS 269,509 246,277 1981 TOTALS OIL 1982 JAN FEB METH FLOWING FLOWING rq 31 28 ~ 11 9 GAS 267,143 253,678 1982 TOTALS OIL 1983 JAN FEB METH FLOWING FLOWING DAYS 29 16 OIL WTR 7 5 GAS 172,620 79,145 1983 TOTALS OIL 1984 JAN FEB METH FLOWING FLOWING DAYS 26 29 OIL WTR 8 8 GAS 121,670 151,490 1984 TOTALS OIL MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 26 23 28 26 26 28 22 29 30 26 227,619 163,775 223,452 185,321 211,752 WATER GAS 2,647,588 CUM OIL 248,848 195,280 CUM WATER 253,490 271,616 CUM GAS 230,575 31,498,816 MAR APR MAY JTJN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 30 27 9 13 31 21 20 25 11 29 239,442 214,156 81,460 108,431 274,691 WATER GAS 2,354,469 CUM OIL 171,534 174,287 CUM WATER SEP SHUT-IN CUM WATER MAR APR MAY JUN JUL AUG FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 21 21 23 12 2 209,140 OCT FLOWING 16 133,743 2,096 253,764 192,669 181,240 163,876 85,512 WATER 2,096 GAS 2,046,487 CUM OIL 94,183 CUM GAS NOV FLOWING 30 250,772 CUM GAS 10,354 250,913 33,853,285 DEC FLOWING 31 2,096 273,439 35,899,772 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 28 30 28 29 30 31 30 31 31 272,162 CUM GAS 267,020 255,204 229,366 268,510 234,946 WATER 61 GAS 3,077,761 CUM OIL 239,151 283,123 2,157 248,917 CUM WATER 30 263,576 38,977,533 APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 28 . 8 30 31 29 26 24 25 25 8 2 4 4 5 231,814 71,448 230,037 234,540 201,106 7 178,502 CUM WATER 9 151,738 2,243 MAR FLOWING 31 9 265,362 WATER 86 GAS 2,402,337 CUM OIL 8 155,723 CUM GAS 10 161,246 41,379,870 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 27 30 8 25 30 27 13 29 APR FLOWING 3O 2 153,367 67 10 124,629 CUM WATER MAR FLOWING 27 4 147,831 WATER MAR FLOWING 26 20 128,169 WATER 8 124,857 2,310 63,622 CUM GAS 2 5 10 6 131,376 155,480 32,232 105,577 GAS 1,450,709 CUM OIL 8 159,973 42,830,579 MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 26 28 31 31 30 31 30 31 20 4 4 146,877 120,748 134,841 GAS 1,613,753 CUM OIL APR FLOWING 27 15 133,530 130 126,820 143,237 2,440 17 137,444 CUM GAS 125,544 CUM WATER 34 143,383 44,444,332 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1985 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR 32 30 GAS 122,427 127,624 1985 TOTALS OIL MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 30 30 31 33 17 30 30 10 133,577 114,104 115,958 119,231 122,626 WATER 221 GAS 1,379,277 CUM OIL 1986 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 31 28 31 30 OIL 93 37 4 6 99,356 92,350 82,443 69,103 194o TOTALS OIL WATER 174 1987 JAN FEB MAR APR METH FLOWING FLOWING FLOWING FLOWING DAYS 31 28 31 30 OIL WTR 113 8 9 GAS 144,966 95,149 104,557 79,290 1987 TOTALS OIL WATER 174 1988 JAN FEB METH FLOWING FLOWING DAYS 31 29 OIL WTR 3 GAS 121,290 110,248 1988 TOTALS OIL 1989 JAN FEB METH FLOWING FLOWING vq 31 28 GAS 83,801 81,212 1989 TOTALS OIL 1990 JAN FEB METH FLOWING FLOWING DAYS 31 28 OIL WTR 16 GAS 78,200 72,681 1990 TOTALS OIL 1991 JAN METH SHUT-IN DAYS OIL WTR GAS 1991 TOTALS OIL FEB SHUT- IN MAY JUN JUL FLOWING FLOWING FLOWING 28 27 29 4 5 5 89,983 76,042 99,377 GAS 1,030,517 CUM OIL MAY JUN JUL FLOWING FLOWING FLOWING 31 30 31 15 12 84,992 77,514 94,729 GAS 1,221,055 CUM OIL · MAR APR MAY JUN JUL FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 24 30 31 3 101,927 91,533 WATER 15 3 6 63,741 85,416 84,518 GAS 1,050,576 CUM OIL AUG FLOWING 31 10 125,761 AUG FLOWING 31 6 78,657 AUG FLOWING 29 94,277 AUG FLOWING 31 65,733 SEP FLOWING 26 12 96,227 CUM WATER SEP FLOWING 3O 76,675 CUM WATER SEP FLOWING 30 87,692 CUM WATER SEP FLOWING 30 68,522 CUM WATER OCT FLOWING 26 10 91,788 2,661 OCT FLOWING 31 5 87,156 2,835 OCT FLOWING 31 10 112,280 3,009 OCT FLOWING 31 89,113 3,024 NOV FLOWING 30 121,389 CUM GAS NOV FLOWING 30 3 90,219 CUM GAS NOV FLOWING 30 121,756 CUM GAS NOV FLOWING 30 81,222 CUM GAS DEC FLOWING 29 7 88,565 45,823,609 DEC FLOWING 31 6 89,156 46,854,126 DEC FLOWING 31 7 123,853 48,075,181 DEC FLOWING 31 87,313 49,125,757 MAR APR MAY JUN JUL AUG SEP OCT NOV DEC FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING 31 30 30 30 31 31 30 31 30 30 93,065 89,437 WATER 11 79,421 79,331 83,187 79,549 GAS 985,360 CUM OIL 4 76,443 CUM WATER MAR APR MAY JUN JUL AUG SEP FLOWING SHUT-IN FLOWING SHUT-IN SHUT-IN FLOWING FLOWING 10 7 9 1 2,869 GAS 180,369 CUM OIL 8,102 WATER 16 MAR APR SHUT-IN SHUT-IN WATER 87,100 3,035 OCT SHUT-IN 3,051 OCT SHUT-IN 3,051 838 CUM WATER 10,077 84,344 CUM GAS NOV FLOWING 7 7,602 CUM GAS NOV SHUT-IN CUM GAS MAY JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN GAS CUM OIL CUM WATER 7 68,470 50,111,117 DEC SHUT-IN 50,291,486 DEC SHUT-IN 50,291,486 i~LASKA INDIVIDUAL WELL pRoDUCTION A~ OF 05108198 1992 JAN METH SHUT-IN DAYS OIL WTR GA~ 1992 TOTALS OIL 1993 JAN METH SHUT-IN DAYS OIL ~ TOTALS OIL 1994 JAN METH SHUT-IN DAYS OIL WTR GAS 1994 TOTALS OIL 1995 JAN METH SHUT-IN DAYS OIL WTR GAS 1995 TOTALS OIL 1996 JAN METH SHUT- IN 1996 TOTALS OIL 1997 JAN METH SHUT-IN DAYS OIL WTR GAS 1997 TOTALS OIL 1998 JAN METH SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN FEB SI{UT- IN FEB SHUT- IN FEB SHUT- IN FEB SHUT-IN FEB SHUT- IN FEB SHUT-IN WATER GAS CUM OIL MAR APR MAY J-ON JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN WATER GAS CUM OIL MAR APR MAY JUN JUL SHUT-IN WATER GAS CUM OIL AUG SHUT- IN AUG SHUT- IN AUG SHUT-IN AUG SHUT-IN AUG SHUT-IN AUG CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP SHUT-IN CUM WATER SEP CUM WATER 3,051 OCT SHUT-IN 3,051 OCT SHUT-IN 3,051 OCT SHUT-IN 3,051 OCT SHUT-IN 3,051 OCT SHUT-IN 3,051 OCT 3,051 CUM GAS NOV SHUT- IN CUM GAS NOV SHUT- IN CUM GAS NOV SHUT - IN CUM GAS NOV SHUT - IN CUM GAS NOV SHUT-IN CUM GAS NOV CUM GAS 50,291,486 DEC SHUT-IN 50,291,486 DEC SHUT-IN 50,291,486 DEC SHUT-IN 50,291,486 DEC SHUT-IN 50,291,486 DEC SHUT-IN 50,291,486 DEC 50,291,486 _ __ I(V ~o~Et9 STATE OF ALASKA AND GAS CONSERVATION CO/VV~ITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT ~ultl-POI.~T T'EST Test J U N ,...¢;~ 0 197'6 ' }'teid j iteservoir Kena| Gas Field .... Pool · Oper;~tor Union Oil Company of California JLease A-028142 ('ounty ,-o,-~,i,,. 277' S & 4279' E from NW Corner, Kenai S¢¢. 7, T4N, RI!W,'SH 11-2-70 ~'""d"c'n¢ Th"u' "'""'°'* j '""'~"'~'' cs~' s"' j 'Wt/Ft' 7. j' Z'D'"rUG.X I oso. ,' r,m~,-,,=,,93F, :r,,~:,:,,,',84.F 1,.7 .5/8 26.. 4/33. ' '6. ~.6~/6.76¢set~ 5288'. 2 7/8 6.4 2 7/8 2.441 4132' . 4132 2293 jTes: Date 7-14-75 tWell No. KU 43-6AS Total Depth J T,'Pay 4393' 60' 417~'-4370' Ratio 'I6F Per Bbl. j LNu:d0APi~* ,.-l~lpeline Connection Nikiski jType Taps Flange : ~ultlple Completion {Dual or Triple) , Dual -- _ jType production from each zone , , , OBSERVED DATA. Flow Data SI Time j (Prover) of Flow t (Line) Hours .J Size I ! 3.826 1 i 3 '826 1 i , 3-826 1 J 3.826, I (Choke) J Press. Diff. (Orifice) J h Size J psig w I 2.500 I I 3.24' 2. 500 ! i 8.41 2. 500 j ! 16.48 Tubing i Casing Press. Press. psig J psig 1373 1338 13o8 2.~;00 ! t 35.22 1178 F LO'C,' CALCULATIONS 1270 Flowin.~ Temp. 'F 87° 80° 76° ¢ient Hr.) , ,. ! 34:.14.7 I 66.210 2. J 34. 147 J 105. 482 ,,. J34.147 i ..14.~.52~ ~4. 34 147 204 982 P i Flow Temp. J Gravity J Compress, 1353 , , J ,, 0.~750 ~ 1.342] I 1.0883 1323 J 0.9786 I 1.3423 I 1.0895 1285 J 0.9813 i 1.3423 ! 1.0978 1193 J 0.9850 ! 1.3423 J 1.0867 Rate of Flow Q .MCF D 3221 5..155 7185 1oo57 PRESSURE CALCULATIONS , · xx' (psla) P= F Q (F Q)' (F Q): X 1-e-s p: p2 _ p: , Cal. 'p . :t c c c xx' C W P t · 1, . ' ~. ~ .................. J ", ......... Ah~,)lute l'o~ential '28.300 ~,cr'p .7218 :-:(~:RTIFI~TE: I. the undersigned, state that ! am th,, engineer o~ the Union 0i 1 Company -~-~eOmpanY). ~nd that I am ~,uthor~Zed by said eomp~ to make ~is report: ~nd ~al ~1~ reporl was pre. ,-}~t~d ~der my supervision and direcuon and ~at ~e fael~ ~late& there~ ~re Wue. eorreel ~d eumplele ~o · GAS'~LL OPEN FLOW POTEr]TIAL TEST RF~RT -- PRESSURE CALCULAT IONS .'-(Supplement to Alaska'O.& Gcc Form No. G-I) Field Kenai Gas Field Operator Union Oil Company of California Reservol. r ?T~17~ate Pool 3 - - Lease A-028142 ~';e I I :to. KU 4.3-6AS Test ( I ) (2) (3) (4) Ps pf (ps2_ pt2) 0 No. 1 1388 1353 9.59 3221 2 1388 1323 17.62 5155 3 1388 1285 27.53 7185 4 1388 1208 46.73 10057 .Sub-Surface Test Data Subsurface pressures measured. ]----J Subsurface pressures computed- Cullender-Smith ~,~ethoo of IOCC. (1 ) (2) (3) (4) Test Pws O (Pws2-pw ~ 2 ) .O No. ,nsia [,sia X 10 4 t..~r/~, .i. _ · , · ,, . ,~Nomenclature- 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 60OF and 14.65 psia -70 ./ Kenai Gas Field Back Pr~ure Tests Well: K ~3-6AS Pool: 3 ~ Survey Date:. 7-14-75 1.O l=]>i-]'-l:Ft'."-f: t~f :i!!;,~i".::i".'':! ;. !: I'::;;:'::. ;:".;. ::,: i:!:':: ::'.I~'1:':': :'i'":',', '7:":" F. ' [ : [ i '.i ,.[:::',...i · :; .... :.'~ ,~. ~ ~ - ; ,- ;; :.:,;' ::l.i ' . ..... i .......... ~., ,' ~.~ · ":.i::~ 'l ;.;;r; ; 'i: : ...... ~", ........ ~' ':; ...... : :.:':':'i 1~; .1: '; ~ ..... '" ~ ' ' ,, ..1 .. , ........ ,, , .................. . .I. ,, ............... , , ...... [.,. ,. . ., , UC s.~ $ i~., ................ i:.:1~1 ' ': - , . 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O2 · · O1 1..O 2 ~ 10 20 ~0 lO~ GAS FLOW RATE ?orm r~o. .. ,~'- · STATE OF ALASKA' ,.,."~ AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST'REPORT Multt-I'OIXT T~'ST Test Initial D Annuel ~ Special Field I Reservoir Kenai Gas Field Pool 6 Operator I Lease Union 0il Company of California A-028142 ¢'ount¥ t Location 205' S & 4'231' E from NW C~rner, Kenai ~ Sec. 7, T4N, Rl lW, S.M. ICompletlonDate I Total Depth 6-13-65 ' 5601 Test Date 7-11-75 V,'ell No. KU 43-6L T/Pay I rr~,,:,~ ~ lOOP 7 5/8 ~6.40 6.969 5601 ' 2 7/8 2.875 2.441 5169, ~. ~,,,~ t~ ~,,~o ,, Pipeline Connection I Type Taps Nikiski J Flange Multiple Completion (Dual or Triple) Type production from each zone Dual Gas _ I ] I I II I I I IL I I I II I III! II Flow Da~a Time (Prover) ~ J (Choke) Press. Diff. Tubing j Casing Flowin~ .~o. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size pstg w psig ! pslg °F s, 1.. ! I 1428 I i ,.=.__'_," " 1. J, S.826 '1 2.SO0 ! ...... '"i ,~.8~ .I ~e,ii,',.!'" i' 66°" ! ~. 1 . 3.826 2.5_00 ~ .. 9.61 ' 1306 i , .6.7° ~. 1 , 3.826 2.500 t 17.45 -1226 I 67° J._. 1 3. 826 2. 500 J 34.52 1126 ! 66° FLOW CALCULATIONS Coeffi- - ........ Flow Temp. J ' Gravity Compress. (24 Hr.) i' m psia Ft Fg Fp¥ !! Q 5ICF, D ,.. ~.]~ '!, I i' i-.~[~ ", '1'.106~ I ~OB8 .. ~. 134.147 i 112.671 1321 ' 0.99~3 I 1.3423 1.1031 , 5659 .~. J 34.147 J 147.158 1241 0.9933 i 1.3423 1.0981 7357 ~..j 34.1.47 j 198.462 1141 0.994~ ! . 1.~42~ . 1..,0905 . 9863 PRESSURE CALCULATIONS w Cal. W -p (psla) F'~:t I:'~Q CF c Q)* (Fo Q): X 1-e" P'*w P*e -- P*W * P w I - p- t I. Jill , , ,, , *, , ,, ,, , , , I III , · , , , ' Al,solute Potential j n 19,000., . .-.?c~.-,,r,I .6~ 16 C~R~FICATI~-: ], the ~ndersi~ed, state that ! am the 9ngine,er o~ me Union 0i I Company (company). and that I am authorized by said company to make this report: and that this report was pre. pared under my supervision and direction and that the facts stated therein are true, correct and complete to $,~ature davy E. Ca~l son GAS~LL OPEN FLOW POTENTIAL TEST R~"~RT PRESSURE CALCULAT IONS _ · , (Supplement to Alaska'O & GCC Form No. G-I) Field Reservol. r Test Date Kenai Gas Field Pool 6 7-11-75 Operator Lease Well ~o. Union Oil Company of Cal,!fornia ,,, A-028142 .... KU 43-,6L Test (i) (2) (3) (4) Ps pf (ps2_ pr2) 0 No. osia ~$i~ X I04 ~..~CF/D ._. 1 1442 ..... 1364 .. , 21.89 ,. 4098 2 1443 1321 33.72 5659 '3 1443 1241 54.22 7357 .,_ .... ' , .... Sub-Surface Test Data -. Subsurface pressures measured. [---]] S~bsurface pressures computed: 'Cullender-Smith ;.~ethod of 1.3CC. ' (I) " (2) (3) ..... (4") Test Pws 0 ' (Pws2-pw~2) Q No. osia psia X !0-4 ,,~/O...~, , Nomenc I ature: Ps = Static surface pressure 't~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 Kenai Ga~7.~Fi el d Back Pre hre Tests Well: KO 43-6L Pool: ' 6 Survey Date: 7-11-75 1.0 .02 · O1 1..0 2 5 10 20 50 100 GAS FLOW RATE ~CF/D STATE OF ALASKA AND GAS CONSERVATION COM/~II-I'EE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multt-POIXT T~-ST Test Initial 0 Annual O Special Field ~ Reservoir Test Date Kenal Gas Field J Pool 5.1 7-10-75 Oper;ttor J Lease !~%'ell .~o. Union Oil Company of California A-O28142 KU 43-6S county "oc~ti"n 205' S & 4231 ' E from NW Corner, j j Kenai Sec. 7, T4N, Rl lW~ St.D. 6-13-65 5145' ProducinK Thru ~,<~nolr [ w,JJ~,d i ~ ~l~I ,Vt/FL& I.D. JSet~ _ X ~7'~ 70'~ 7 S/8 32.75 26.4 1297' 5601' T~G. Size Wi/Ft. O.D. I.D. Set ~ Oas Cr.,lt~ A,'~. Prod. O~ ga~-Llq.id H)d:ccarbcn .2-,.7/8 6.4 2 · 875 " 2 .441 4465' 6Sep. LeIIjtb (~) ,ali0 ),(FO per Bbl. T/Pay J Pt..lo :.".Z t. lr.t~r~ai 126 )q593 -4872' Pipeline Connection Nikiski Pipeline Type Taps Flange Multiple Completion (Dual or Triple) Type production from each zone Dual Gas OBSERVED DAT.-k Flow Data Time (Prover) I (Choke) Press. Diff. Tubing Casing Flowin.~ .~o. of Flow (Line) (OrifiCe) h Press. Press. Temp. Hours Size Size psig w pslg psig I 'F ~,- - i 'J '" 138q I : ,~ 1 3' 826 ~ ' siO0 ..... ~ m~ m. ~' 0© ( ' I ~ 62 ~ 'mm i m.. ~ ~ 3.826 2 500 j ) 8.41 I 1337 i ' 69° 3.826 i 2.500 .... j j 24.50 j 1~00 t ' 70° ~.826 2. 500 J J 30 25 J 1227 J 6,9° _ FLOV~' CALCL'LATIONS Coeffi-cient · (24 Hr.) ~ 34.,) 47 J 34. 147 · ~. j 34.147 4. j 34.: 14.7. 74.216 106.632 179.492 193.831 Pressure psla 7377 . 1352 1315 1242 Flow Temp. J Gravity J Compress. Factor I Factor J Factor Rate of Flow F J 'F ! F Q .~ICF, D t , g pv ' 0.~,1,5 ,~ I 1.3423 J 1.1054 0.9915 ) 1.3423 t 1.10.33 0.9905 i 1.3423 ! 1.O999 0.9915 J 1.3423 J 1.0956 3728 5346 8963 .... 9651 PRI~:S$ t' RE CALCULATIONS Potential jII .... 2,3. 400 .~e~-.,n ; .6105 CERTIFICATE: I, the undersigned, state that I am th., engineer or the .Union Oi I Company (company). and that I am authorized by said company to make this report: and that this report was pre- pared under my supervision and direction and that the /acts s~ated therein are true. correct and complete to ,.,..to,.,_,.,,.. " signature ~a ry I~. Ca r 1 son GAS~ELL OPEN FLOW POTENTIAL TEST PRESSURE CALCULATIONS (Supplement to A laska'O & GCC Form No. G-I) Field Reservol. r Test Date Kenai, Gas Field Pool 5.1 7-10-75 _ Operator Lease ~';ell ;to. Union 0il Company of California A-028142 KU 43-6S (I) (2) (3) (4) Test Ps pf (ps2_ pt2) 0 No. 1 1404 1377 7.51 3728 2 1404 1352 14.33 5346 ., . 3 1404 1315 24,..20 8963 · 4 1404 1242 ' 42.87 9651 · Sub-Surface Test Data. Subsurface pressures measured. []]]]] S6bsurface pressures computed: 'Cullender-Smith :.~ethod of IvaC. (I ) (2) (3) (4) Test Pws 0 · (Pws2_pw ~ 2 ) Q No. p, sia psia X I0 4 ..~/~- ~ ..~,, ?~1 _ ,.. ~ ,, , , ,, . . ~ · Nomenclature: 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 Kenai Gas Field Back. Pre~sure Tests Well. ' '43-6S Pool: 5. I Survey Date:. 7-10-75 1.O ' l0 .05 .J Ox '_. O2 o O1 1..O 2 5 10 20 ~0 GAS FLOW RATE I'4MCF//D WORKOVER SU},DLARY KU 43-6 ~..,1 O- 29- 74 AFE NUMBER' 341114 TOTAL COST' $257,400 TOTAL SPENT' $187,932 PURPOSE' Clean out sand fill, perforate C-2 and treat C-1 and C-2 sands of Pool 6 for sand production control. SUbDIARY OF RESULTS.' The DST of the lower C-1 and C-2 sands was 4 to 5.67 mmcf/d with no sand or water entry against a 950 psi tubing pressure. The total production from the C-1 and C-'2 sands is now about 9 mmcf/d with no sand production. The hydroxy-aluminum treatment was successful in eliminating the sand production. The deliverability from the C-1 and C-2 increased from 8 mmcf/d on Sept. 11 to 9.27 mmcf/d on Oct. 2. These sands should produce 13 mmcf/d and continued rate improvement should occur. The C-1 rate prior to the workover was 11 mmcf/d. The B-3 and B-4 sands ~'ere not treated but were subjected to a 73 lb' KCL-Dril "S" workover fluid (550 psi differential). The producing rate both prior to and following the workover ~'as about 11 mmcf/d indicating no formation damage from the workover fluid. SU~,D[ARY OF WORKOVER Sand fill was cleaned out and the C-2 sand ~.:as perforated from 5450'-55' and 5463"-68'. This interval was then treated with hydroxy-aluminum for sand control, using 5% HCL in the preflush. The C-1 sand from 5392' to 5434' would not breakdown while attempting the hydroxy-aluminum treatment. This interval was reperforated and acidized with 1 BPF 15% HCL during the hydroxy-aluminum preflush. A DST of this lower C-1 interval and the C-2 produced 5.67.mmcf/d against a 950 psi surface pressure. No water or sand was produced. The Upper C-1 sand from 5270'-5380' was treated with hydroxy-aluminum for sand control. The preflush contained 15% HCL acid. DEC t Di~,q$10N (.,.F OIL AND AI,,~cHORAG~. DATE PRODUCTION TEST AFTER WORKOVER KU 43-6 POOL $. 1 MMCF/'D BWPD - ~DfCF/D 9/11 --- 8.00 9/26 11.97 .... 9.09 9/27 12.06 .... 9.10 10/2 11.80 9.27 10/27' 11.64 .... 9.27 POOL 6 BWPD PRODUCTION S Uis[MARY POOL 5.1 POOL 6 __ MONTH -bDIC F/D - MblC F / D JANUARY 8.00 14. $3 FEBRUARY 11.28 2,4,4 MARCH 11.94 .... APRIL 10.42 11.93 MAY 8.97 11.23 JUNE 12.10 11.14 , JULY 11.03 10.'07 AUGUST 10.96 10.42 woRKOVER 8 - 20- 74 SEPTEMBER 10.64 TO 9-2-74 10- 29-74 (GAG) o-,oo,-A UNION OIL CO. OF CALIFORNIA SHEET A REPAIR RECORD Page NO. KENAI UNIT · _WELL NO._~43-6 CONTRACTOR Kenai Drilling Co. Rig #3 LEASE FIELD .Kenai Gas Field TYPE UNIT__ Oi],~.~e]] 52T BEGAN: 8/22/74 COMPLETED: .. 9/2/74 ELEVATIONS: GROUND See PERMIT NO. /-~65,9 SERIAL NO.j~A-028142 - CASING HEAD Previous COMPANY E~C~NEER. ~.~t~,,~. 14m~ ~ TUBING HEAD Report APPROV%~~~ ' ~ ~d~~Z~~~~ ~ 4 ~ ~ ~ 4 ~O TARY DRIVE ............. BUSHING / Jim R. Callender~ I' CASING & TUBING RECORD i SIZE --DEPTHi WEIGHT , GRADE~ , ,, , [ ,~ II , I ~ : 20" 52' 78.6# ~ ' i~Driven to 52'. 10 3/4 1297' 32.75# ':· H-40 'Cmt'd.w/ 1450 si. ideal Construction Cmt. 7' 5/8" 5601' 26.4# . J-55 .Cmt'd w/.700 si. ideal Construction Cmt.-last 200 sx. w/2% ' , ~ : · CRC12. 2 7/8" ' 6.4# N-80 '.Dual Tbg. Strings· . i i , PERFORATING RECORD DATE INTER'vAL E.T.D. REASON PRESENT CONDITION ,. 6/12/65 4593'-4615' ' 5556' · Productior B-3 Sd. - Open for gas production· 6/12/6,~ 4624'-4646' ,. 5556' Productior B-3 Sd.-'Open for gas production. 6/12/6,~ 4680'-4702' 5556' · Productior. B-4 Sd. :i- Open for gas production 6/12/65 4708'-4730" 5556" Productior B-4 Sd. '- Open for gas production 6/12/65 4821'-4837' 5556' '~: -: Production B-4 Sd. - Open for gas production. 6/12/65 2850'-4872' i 5556'' ' ' Production B-4 Sd. - Open for gas production. 6/12/65 5270'-5380" . 5556' Production Upper C-1 Sd. - Open for gas production. 6/12/65 5392'-5434' 5556' Production, Lower C-1 Sd. - Open for gas production. 8 26/74 5450'-5455' 5556' - Production C-2 Sd - Open for gas production. 8/26/74 5463'-5488' 5556' Production C-2 Sd. - Open for gas production. 8/27/74 5392'-5434' 5556" ~ Production Lower C-1 Sd. - Open for gas production. INITIAL DATE I INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR [ REMARKS . . . . ' ' ' · DEC . . ' .. . : '. ..' . . · .- :. ' - WELL HISTORY PRIOR TO REPAIR LAST COMPLETION NO. Original COMPLETION DATE: 6/14/65 PRODUCING INTERVAL: B-3, B-4 & C-1 Sds. INITIAL PRODUCTION' LAST REGULAR PROD. & DATE: B-3 & B-4 Sds. C-1 & C-2 Sds. ll mmcf/d 8 mmcf/d August 74 CUMULATIVE PRODUCTION:. B-3 & B-4 Sds. 21,540,185 August 74 · C-1 & C-2 Sd.~. 2l :lqg_g~q Augt!st 74 REASON FOR REPAIR: To clean out sd. fill, treat the C-'i. Sd.. w/ Hydroxy-Aluminum for sc]. control & perforate the C-2 Sd. Fo~'m D-IOO1-B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NOi LEASE KENAI UNIT COMPLETION DATE: 9 / 2 / 74 DATE E.T.D. TYPE: Cameron WELL NO, 43-6 FIELD Kenai Gas Field APPROVED . .T~m R ~lle~der DETAILS"OF OPERATIONS, DESCRIPTI~)NS & RESULTS WELL I4RAD ASSEMBLY DIW$10N '~ ~ OIL ,'-.ND OAS CASING HEAD: Cameron 10" X 3M CASING HANGER: Cameron AW Slips CASING SPOOL: TUBING HEAD: Cameron 10" 3M X 8" 3M DCB TUBING HANGER' Cameron Dual 2 7/8" split hanger 8" w/ 8rd EUE up TUBING HEAD TOP' MASTER VALVES: Cameron 8" 900 series 2-2 9/16" Bore on 4" CC w/ Integal Tee. CHRISTMAS TREE TOP CONN.: Cameron 2 1/2" slim UNION 0IL CQt DAI'C OF CALIFOFC IA 'ZLL I<LCORD PAGE LEASE KENAI UNIT I'~LL NO, #43-6 FIEL~ KEN^I GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS 8/20/74 8/21/74 8/22/74 8/23/74 8/24/74 8/25/74 8/26/74 8/27/74 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD (Footage 0') Began Turnkey Rig Move from KDU #2 to KU #43-6 @ 6:01 pm, 8/20/74. (Footage 0') Continued Turnkey Rig Move from KDU #2 to KU #43-~ (Footage 0') Completed Turnkey Rig-up operations @ 10:00 am, 8/22/74. Drlg. rathole. Bullheaded 20 bbls Dril-S pill dwn. LS & spotted across C-1 perfs. Bullheaded 20 bbls Dril-S pill dwn. SS & spotted across B-3 & B-4 perfs. Opened psi sleeve in SS @ 4396'. Displ. annulus w/ 70# WO fluid. (Footage 0')~ Completed displ. 'annulus w/ 70#/cu. ft. WO fluid. Installed BPV. Removed x-mas tree. Installed BOPE. Rebuilt choke lines, mud lines & flow nipple. Circ. dwn. SS & out annulus. Tested BOPE rams to 3000 psi, kill & chOke lines to 3000 psi & hydril to 1500 psi. (Footage 0') Completed testing BOPE. Pulled & laid dwn. 2 7/8" SS. Picked up & released Baker Model "K" @ 4452'. Laid dwn. LS Picked up Tri-State pkr. picker. Picked up 3 1/2" DP. (Footage 0') Picked up 3 1/2" DP & RIH w/ BO mill & pkr. picker. Stabbed into Baker N-1 perm. pkr. @ 5145'.- Milled over & retrieved pkr. RIH w/ bit & scraper. Hit bridge @ 3759'-junk in hole from pkr. Had bridge @ 5377', sd. & junk. CO to 5556'ETD. Circ. & cond. mud. (Footage 0') Pooh. Rigged up Go-Int. Perf. C-2 Sd. from 5450'- 5455' & from 5463'-5488' w/ 4" csg. gun @ 4-1/2" hpf. Picked up Baker 7 5/8" fullbore pkr. & ret. Bp. RIH. Set BP @ 5500'. Set pkr. @ 5442'. Broke dwn. C-2 Sd. w/ 900 psi @ 3 cu. ft./min. 9.7 gradient). Moved. in Dowell 500 bbl tanks. Mixed 500 bbls 5% KCL, 500 bbls of Hydroxy-Aluminum. DiSpl. DP w/ 900 gal. HCL followed by 28 gal. 5% KCL. Rate of 6 cu. ft./min. 700 psi surface press. (Footage 0') Completed HydroXy-Aluminum treatment of C-2 perfs. from 5450' to 5455' &i from 5463' to 5488'. Pumped 900 gal. 15% HCL 2800 gals. 5% KCL, 6500 gals. Hydroxy-Aluminum followed by 3800 gals. of 5% KCL. Released pkr. & retrieved BP. Reset RBP @ 5442' & pkr. @'5386'. Unable to break dwn. I, ower C-] perfs. from 5392' to 5434' w/ 2800 psi (1.1 gradient). Pooh w/ pkr. & RBP. Reperf. Lower C-2 Sd. from 5392' to 5434' w/ 4" csg. gun @ 4 hpf. RIH w/ Baker fullbore pkr. & RBP. Backed off DP while setting RBP @ 5442'. RIH & screwed into fish. Pooh w/ pkr. & RBP. RIH w/ pkr. & RBP tightening DP. Set RBP @ 5442' & pkr. @ 5386'. Unable to break dwn. C-1 perfs, from 5392' to 5434' w/ 1100 psi. Spotted 210 gal. of 15% HCL across perfs. Broke dwn. perfs, w/ 1000 psi @ 3 cu. ft./min. & pumped in w/ 600 psi '@ 5 cu. ft./min. ~ ~ ~ ~ ~ E ~ DEC SI II:LI Il PA F_ Ih, UNION OIL CCI ANY OF CALIFOP 'tIA VELL I<LCOt [~P~E KENAI UNIT I'~LL NO, #43-6 FIELD KENAI GAS FIELD DATE 8/28/74 8/29/74 8/30/74 8/31/74 9/1/74 ETD 5706'TD 5556'ETD 5706'TD 5556'ETD 5706'TD: 5556'ETD 5706'TD 5556'ETD 5706'TD 5556'ETD DETAILS OF OPERATIONS, DESCRIPTIOIiS & RESULTS (Footage 0') Completed Hydroxy-Aluminum treatment on Lower C-1 Sd. perfs, from 5392'-5434'. Set RBP @ 5442', RTTS @ 5386'. Pumped 1350 gals. of 15% HCL & 299 gals. of 5% KCL. Closed tool. Pumped 3501 gals. of 5% KCL, 8800 gals. Hydroxy-Aluminum, 5300 gals. 5% KCL. Job completed-pumping @ 850 psi, 5 cfm. Reset RBP @ 5500' & RTTS @ 5442'. Tested for communication between Lower C'I perfs. & C-2 perfs. Communicated w/ 200 psi. Reset RTTS @ 5386'. Tested for communication between Upper C-1 perfso & 'Lower C-1 perfs. PI Lower C-1 perfs, w/ no communication to Upper C-1 perfs. Retrieved RBP. Pooh w/ RTTS & RBP. Rigged up test seperator to production test the C-2 & Upper C-1 Sds. (Footage 0') RU test seperator. RIH w/ DST tool for DST #1 on Lower C-1 & C-2 perfs. Set DST pkr. @ 5386' w/ tail @ 5408'. Charged DP w/ 1800 psi gas. Opened tool for initial flow @ 8:45 am IF - 30 mins. ISI - 1 hr. FF - 2 hrs. FSI - 4 hrs. Tested well @ 5,67 mmcf/d w/ 950 psi surface press. No wtr. no sd. Rev. out gas in DP. Released DST tool. Ran into 5556'ETD & rev. out gas cut mud. Pooh. IHH - 2238 psi IFP - 1248 psi FIFP - 1376 psi ISIP - 1615 psi IFFP - 1358 psi FFP - 1432 psi FSIP - 1615 psi FHH - 2201 psi. (Footage 0') RIH w/ Baker RBP & RTTS. Set RBP @ 5386' & RTTS @ 5250'. Tested pkr. & mixed KCL wtr. to 5% KCL. Displ. WO fluid in DP w/ 15% HCL. Closed tool & pumped 2750 gal. }ICL & 9000 gal. 5% KCL & 20,000 gal. Hydroxy-Aluminum. (Footage 0') Completed pumping 121000 gal. of 5% KCL to complete Hydroxy-Aluminum' treatment of Upper C-1 Sd. Pooh w/ RBP & RTTS. PU bit & scraper. RIH. Circ. btms. up. Pooh. Laid dwn. DP. Rigged up Schlumberger. RIH w/ gauge ring & junk catcher to 5200'. Pooh. RIH w/ Baker 7 5/8" Model "D" perm. pkr. Set @ 5145'. Rigged dwn. Schlumberger. Changed pipe rams Started running tbg. (Footage 0') Completed running dual 2 7/8" tbg. string w/ Baker Model "D" 7 5/8" X 2 7/8" perm. pkr. set @ 5145' & Brown 7 5/8" X 2 7/8" X 2 3/8" Husky Dual Hyd. pkr. set @ 4451'. Displ. WO fluid w/ 1.0% ~alco N-55C pkr. fluid. Spaced out tbg. w/ locator sub 1' above perm. pkr. & tbg. hanger 1.5' above tbg. head Set hyd. pkr. w/ 3000 psi. St II!LT D PAGE I'b, UNION OIL CC~qPANY OF CALIFOP~,IIA I,~iLL RECORD LEASE KENAI UNIT ~'~LL NO, #43-6 FIELD KENAI GAS FIELD DATE 9/2/74 ETD 5706'TD 5556'ETD DETAILS OF OPERATIONS, DESCRIPTIOI.IS & RESULTS (Footage 0') Attempted to land dual Cameron hanger after setting dual hyd. pkr. Landed LS & SS standing off 1.5'. Worked SS. SS unlatched. Removed 2.5' from SS. SS standing off .5'. Tested SS to 5000 psi. Removed BPV from LS. Tested annulus above pkr. w/ 1500 psi - ok. Installed BPV. Removed BOPE. Installed x-mas tree & tested to 3000 psi. RELEASED RIG FOR TURNKEY MOVE TO #43-7 @ 3:00 pm, 9/2/74. AI~'CH~' PA E UNION OIL COMPANY OF CALIFORNIA ¥ JLL tfCOI® LEASE KENAI UNIT l'~.LL. N0, #43-6 FIELD KENAI GAS FIELD DATE ETD JTS. 140 155 Jts. DETAILS OF OPERATIONS,' DESCRIPTIONS g RESULTS TUBING DETAIL LONG STRING t)ESCR IPTION LENGTH 2 7/8" Mule Shoe OD-3.25, ID-2,313 2 25 N Nipple OD-3.25,. ID-2.225 2 7/8" 6.4# N-80 Pup Sub Seal Assy. Baker Size 80-32 Locator Sub Baker Model "D" 80-32 2 7/8" 6.4# N-80 Tbg. XO Sleeve Otis ID-2,313, OD 3.65 2 7/8" 6.4# N-80 Tbg. 2 7/8" 6.4# N-80 Pup Sub 4 Blast jts. Baker ID-2.441, ID-3. 688 2 7/8" 6.4# N-80 Tbg. 2 7/8" 6.4# N-80 Pup Sub 4 Blast jts. Baker ID-2.441 OD-3.688 2-2 7/8" 6.4# N-80 Pup Sub's 4 Blast jts. Baker ID-2,441 OD-3.688 2 7/8" 6.4# N-80 Tbg.- X-over Brown Husky Dual 7 5/8" X X 2 7/8" X 2 3/8" X-over 2 7/8" 6.4# N-80 Tbg. XO Sleeve Otis ID-2.313, OD-3.75 2 7/8" 6.4# N-80 Tbg. 4-2 7/8" 6.4 N-80 Pup Sub 2-10's, 1-6'. Cameron Dual Hanger (top & btm. 2 7/8" 8rd) Landed below 0' 1 16 10 10 10 45 1 00 31 20 3 35 218 60 10 15 70.80 62.87 6.10 70.80 1.6.25 69.99 125.30 .50 6 51 63 31 28 3 35 4377 04 25 88 1.00 12.70 Total of 2 7/8" 6.4# N-80,Tbg. BOTTOM 5169 26 5167 01 5165 85 5155 75 5145 30 5144 30 5113 10 5109 75 4891 15 4881.00 4810.20 4747.33 4741.23 4670.43 4654.18 4584.19 4458.89 4458.39 4451.88 4451.25 4419.97 4416.62 39.58 13.70 12.70 TOP 5167.01 5165.85 5155.75 5145.30 5144.30 5113.10 5109.75 4891.15 4881.00 4810.20 4747.33 4741.23 4670.43 4654.18 4584.19 4458.89 4458.39 4451.88 4451.25 4419.97 4416.62 39.58 13.70 12.70 --0- SIIIJ-'I' l) DA6E I',b, UNIOil oIL'CCt"PANY OF CALIFOPJ" IA I'FLLL IIECOI -LEASE KENAI UNIT I, LL NO, FIELD KBNAI GAS FIELD DATE ETD JTS: 139 141 Jts DETAILS OF OPERATIONS, DESCRIPTIOr,IS. & RESULTS TUBING DETAIL SHORT STRING DESCRIPTION LENGTH N Nipple Otis 2 3/8" 4.6# Pup Sub X-over Brown Husky Dual 7 5/8" X 2 7/8" X 2 3/8" Brown~ Stab-in Stinger X-over 2 7/8" 6.4# N-80 Tbg. XO Sleeve Otis ID-2.313, OD-3.75 2 7/8" 6.4# N-80 Tbg. 5 Pup Sub 1-10', 1-8', 1-4', 2-3', 1-2' . Cameron Dual Hanger 2 7/8" X 2 7/8" 8rd. Landed below 0' 1.30 4.45 .50 6.51 2.36 .64 62.75 3.35 4338.59 30.49 1.00 12.70 Total of 2 7/8" 6.4 N-80 Tbg. BOTTOM 4464.64 4463.34 4458.89 4458 39 4451 88 4449 52 4448 88 4386 13 4382 78 44.19 13.70 12.70 DIVI$1CN ,,~ i~ (~:IL AND GAS ANCHORAGE TOP 4463.34 4458.89 4458.39 4451.88 4449.52 4448.88 4386.13 4382.78 44.19 13.70 12.70 -0- IRT 0' SHORT STRING: A. 2 7/8" XO Sleeve (a4383, ID 2.313 B. 2 7/8"-2 3/8" X-Over @ 4449~. C. Brown Dual pkr. (a 4452'. D. N Nipple @ 4465' ID 1.791 I,ONG STRING: , 2. 3 4 5 6 7 8 9 10. 2 7/8" XO Sleeve ~4416' ID 2 313 Brown DualPkr. @ 4452'. Baker Blast,lt. 4584'-4654' ID 2. Baker Blast Jr. 4670'-4741' ID 2.441 Baker Blast Jt. 4810'-4881' ID 2.44] 2 7/8" XO Sleeve @ 5]].0' ID 2. 313 2 7/8".Locator Sub @ 5144' 2 7/8" Seal Assy..@ 5145'. 2 7/8" N Nipple @ 5]66' ID 2.225 2 7/8" Mule Shoe 5167'-5169' ID 2.313 C TD 5706' ETD 5556' TbR. FIRr. 12.70' 20" 78.6#Csg. a 52' DEC t 1 DIV!SIGN ~,.1: OIL Al,ID ANCHORAGE 10 3/4" 32.75#Csg. @ 1297' 7 5/8" X 2 7/8" X 2 3/8"Brown pkr. @ 4452'. 7 5/8" Baker MDL NPerm. Pkr. a 5145' 7 5/8" 26.4#CsR. (a560]'. f ;77_ XEL:ETLZ7____75 I COMPLETION SCHEMATIC WO #1 KU ~43-6 ~ ----i ..................... ~ Began 8/22/74 Com¢leted 9/2/74 ......... ~ .................... ~ ....... l;, .~,.,,~""'"'" r' .... ~:: t' r~.,,,,.: ~-/,r.~ ~ '~" ' '* "~.~r~"' (.r,,.~, ' ' ' '~'"~'"" UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY XPorm approved, Budget Bureau No. 42-:R356.5. LA.D once .................................. LEASE NUMBER ..~'-.0~._8.~_~_~ .............. U.,T .Xenai..L~Lkt .................... LESSEE'S MONTHLY REPORT OF OPERATIONS State .... AlaM]f~ ................. County _~xlai.~.ellrt. ............ Field---Kenai..Cas._Y_ieict ................................ The followin~ is a correct report of operatior~s and prodz~ctioT~ (incl~dilr~ drillin~ and prod~c'in~ wells)/'or the mont]z of .... ~ttgtl$~/. ........................ ,19._7._4, ............................................................................ /l~e~t' s address ~_..9..O_.9_._}~e__s_.~_...9._t__h_...A_.v___~__.~._¢ ......................... Company ......................... Anchorage~ Alaska 99501 $i~ned~_~_~~~' .............. ::::::::::::::::::::::::::::::::::::::::::::::::::::: .... ........... AND CU. FT. OF o~ ~ BARgE~ Or On~ (In thousands) OALLONS OF GASOLINE RECOVERED on KU 6:01 pm, 70# Install, Removed res Pulled dwn. 2 7/ · Laid Picked ~p 3 I/2" Sta perm. .54'. Hilled over bit 5556'ETD. Rigged $~ Go-Int from S465 ' w/ 4"I OD csg. pkr. dwn ;i ~ 5 cu. Displ KCL by 3 ret @ S~42 . @ S$86' per 34' w/ 281 Pooh w/ 4" OD cs @ ~-1/2" RBP ile sett: @ 5442'. pkr ~ P~BP ing DP. C-1 5392' peris psi @ 5 1350 gal ~ 5800 ;% KCL. g 5500' 200 C-1 peris peris. per: '.ion to RU wi pkT tool for FSI tool pre set men~ .l Ptm~cd ~-d: :~2, O00 g, Ran /catc>~er set pkr. set N-SSC 5000 psi 9/2/74 ~/20174. :-mas ;" SS. w/' 900 0 ga!. c Unable )kr. ~ P~ ~pf. TIP TIH ~ sc ;et RBP @ o 5454'. cu. ft./ gal. of 5 RTrS @ ,set RTrs peris, tetrieved DST #1 ~n Lower 45 am, I~-30 rains Well tested 5.67 & RTTS @/52S0' fo 15% tlCL~ 9000 ga ~Poohtl~¢/ RBP' & 7 P~ du~! 2 7/8 Set Br~m dual Installed m ~ ~3:.7. BARRELS OF %VATER (If none, so state) Displ. e. Inst icked up DPw/D ~ retrie' ernation; ~m@4- 500' & p ~al. 15% c c o. ;:CT. to bred BP. Rep~ w/ Bake: rewed ~' 5442' Spotte~ ~ ~ p~ 5% KCL, 5442'. ~ 5386' ~P. P ISI-1 t:~cf/d I-Iydrox Is. 5% K R~S. ~4odel ' tbR. wd. pkr. Re~vei RE:MARKS (I! drilling, depth: if shut down, cause; date and result of te~t for gasoline content of romulus w/ tiled BOPE & & released Baker mill & pkr. picker. ed pkr. RI}I w/ ti. Perf. C-2 Sd. ./2" hpf. Tit! w/ er. @ 5442'. ~roke HCL, 2800 gal o ;d~. Lower C- i ~rf. ~wer C-1 Sd. ~ullSore pkr. ~ v fish. Pooh w/ pkr. 8 5586'. 210 gal of 15% ~d in w/ 600 ps~ ~800 gals. tiydroxy- Cogitation w/ PI Lower C-1 peris. Set DST. r; FF-2 hrs. 950 psi surface -Mt~aim~n treat- ;L 5 20,000 gal. ~iggcd ~ Schlamber~c 'D" pe~. pkr. & '~gs !oca~cd on ~ 4451' Disp!. ~Pr. installed NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas soM; ..... -f ...................................... runs or sales of gasolin~ri~[-~ t~l~-~t~. ~V~e[r~'' where applicable.) NoTr.--Report on this fomn is required for each caleb&/;/n~gt~glrc~i~r~cJ~of~els~,s of operations, and must be iilcd in duplicate with the supervisor by the 6th of thc succeedin~nth, unless otherwise dir~ by the supervisor. Form 9-329 SEP 1 6 i974 0IL AND 6A$ Form 9-331 · ~4NITED STATES- DEPART. :NT OF THE INTERIOR GEOLOGICAL SURVEY SUBMIT IN TRIPLICATE' (Other tnstru~s au verse side) - SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo,~als to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~] CAS [] WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPA,XPf OF CALIFORNIA 14. 16. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99S01 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.' See also space 17 below.) At surface 205'S & 4251'E from the Nw corner. Section 7: T4N, RllW, S. M. PERMIT NO. 65-9 Form approved. Budget Bureau No. 42-R1424. 5, LEASE VES~CN*TZON AND SERIAL NO. A-028142 {~. IF INDIAN, ALLOTTEE OR TRIBE NAME .. .. ~. UNIT AGREEMENT NAME 2_Kenai_I~1: 8. FAR~ OR LEASE NINE Kens! [,hit_.- g. WELL NO. mi .~45-6 · 10. FIELD A~D POOL, OR WILDCAT Kenai Gas Fiel. d* 11. SEC., T., R., M., 0g BLK. AND " SURVEY OR AREA Section 7: T4N, RllW, ~ 15. ELEVATIONS (Show whether OF, ST. a~, etc.) GR 78' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: 8UBSEQUItlN~ am, OaT 13. 8T*TE Alaska TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) 12..COUNTY OR PARISH} "Kenai, Penn.[' . OF: '*. WATER SHUT-OFF REPAIRIN~ WELL FRACTURE TREATMENT · ALTERING CASING SItOOTIN~ OR ACIDIZIN~ ~BANDONMENT* (Other) ...... -- (NOTE: Report results of multtvle comple~on on WeN Completion or Recompletion Report and Leg form.) 17. D~:ScgInE rnOeOSr. O OR CO.~IPLETE~ OPERATIONS (Clearly state all pertinent details, and give pertinent dates, iucluding estimated date of starting any proposed work. If well is directionslly drilled, give subsurface locations and measured and true vertical depths for all markers and 2,ones perti- nent to this work.) ' - ' ,- " :'- . '- *Pool. !; 5, 6. PlAN OF PROCEgIIRE: l. 2. 5. 4. S. 6. 7. 8. 9. Comenced WU operations on KU #45-6 @ 6:01 pm, 8/20/74, ., Killed well w/ 73#/cu..ft. hD fluid. ~_ '.. Pulled tbg. pkrs. & accessories. : 10. .. · -.. .: CO well to ETD @ 5556'. Perf. the Pool 6 C-2 Sand from 5450' to 5455' and from 5463' to 5488'. Treated the C-2 Sand & Lower C-1 Sand w/ Hydroxy-Alu~inum..and sand control. Drill Stem Tested the Lower C-1 and C-~2 Sands. .[.,'. ;, · '' Treated the Upper C-1 Sand perfs, from 5270' to 5380'. --' '-. :? :: . Cor:~pleted well w/ dual 2 7/8" tbg. strings. ~per completiOn-Poo! 5~ 1,~ B-3 & B-4 Sands. Lower completion-Pool 6 C-1 & C-2 Sands. -. '--. - Returned well to production @ $:00 pm, 9/2/74.~i2~ ~ ~, i:~,.. ;~ii~'' .' , .. · , . . · ~ .' ,. ;)., '~-. . , 18. I herebx c-,,~,7 ~at the folego~g Is true and correct .:.~ · ". (This space ior ~ederal or S~te offi~ use) ,. TITLE *See Instructions on Reverie Side APPROVED BY CONDITIONS OF APPROVAL, iF ANY: v ' . · DATE · , .... .. . :... -. ti" ., . ~'o.,,. 9~.~, /'~tlTED STATES s,m~~ ~E. Form (May 1963) Budget ~ur~au No. 42--R142~ . GEOLOGICAL SURVEY ............. ~~ F~ ~ / A-0~8142 ~/~ "~, l~ INDIAR, ALLOTT~ OR TRIB~ ~AMZ SUNDRY NOTICES AND REPORTS ON WE ~E~ J -" (Do not u~ this form for 'pro~sals to drill O, to d~pen or phlg back to a d]ffer~t~l~. ese "APPLICATION FOR PERMIT--" for such p~p~) [ 2 F~--I .....[ " ........ . ............. , ~ION OIL C~'~ 0F ~Ir0~ I , , ~. ADDRESS OF OPERATOR [ I ~ ~. WR~L NO. '.. ' 909 ~st 9th Avenue) ~chorage~ ~as~ 99501 4. ~IO~ ~'r~ ~~aflon clearly and' in'a~ordance with any S~ requt · ~'-' 10. ~IELD AXD POOL, 0R W1LOCA~ Seeals°spacelTbeiow.' ~a~T [ .... At surf,ce " "Kenai Gas Field,. * 205'S i 4231'E from the NM corner. . S~tion 7: T4N, ~.IW, S.H. FILE. .,,: -- ~Ction 7: T4N, ...Rl~tq~ . 65-9 ~ GR 78 ~., 16. Check Appropriate Box To Indicate Nature of Notice, Report,.or Other Data" . NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ [ PULL OR ALTER CASING FRACTURE TREAT [ [ MULTIPLE COMPLETE 8IIOOT OR ACIDI/E [__[ ABANDON* REPAIR WELL [ [ CHANGE PLANS (Other) 17. DESCRIBE PROPOSED OR CO:,IPLETED OPERATIONS (Clearly state all 18. I hereby ,icerltfy that the for~oinl~[s true and correct (This ~/a~e for Fede[~ ;5 ~ ~~[ ... SUESEOUS~T:Ri~ORT 0r::" ., · . ' WATER SHUT-OFF ':~ ;J REPAIRING .WELL .; FRACTURE TaEATM~NT A~TERIN0[ C~Sz~G SHOOTING OR ACIDIZING ABANDONMENTd .... ,t .'~[ :: .. , (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) )ertineut details, and give pertinent dates, Including estimated date of starting any proposed work. If well is direetionally drilled, give s~llrfa~e loc~tions and measure0 and true vertical depths, for all markers and zones perti- ..... nent to this work.) * .. .. :y. : ff,; ' . ~ t.. "-C ;. ~.?. :..- ~,.: ; ';' ~.IENDED PLAN OF PR~; .~ ;'~ ... ::- .. 1. Perf.th.e C-2 Sd. from 5450' to 5455' ~ from 5463' to 5488' .-:.::. .... :. :: ,.~:. 2, Treat the C-2 [ Lower C-1 Sd. from 5592' to 5454' w/ HTdroxy:Aluminm~ for sd. control. ~: . ~..':- '-~__'" 3, I)rill stem test the Lower C-1 [ C-2 Sd. (discussed verbalI¥:"W/: Bill'"'I~mniCke, USGS, Regional Oil [ Gas Division ~ John Miller, State of :,A~..,aska, Oil [ Gas Division). ii' ii' :: 'i..'.! :~ ':' .-... ... , 4, Treat the Upper C-1 perfs from 5270' to 5580' w/ HTdroxT-A!uminum for' sd'.' ccntrc!. C :: -J -:, ::[ ::: - : $, Complete the well w/ dual 2 7/8" tbg. strings and return well'.t0 prbdfiCti°n. ...... :il ...,.:..: ..... .. Note: The State Dept, of 'Environmental Conservation and the Cook-Inlet' Air Resources ~lan~. gement have been informed of our intent to DST and flare gas'.. rxg. s pt ,-:" ;i aN 0 r /74 ' ' DATE APPROVED BY CONDITIONS OF APPROVAL, LP AN~f: TITLE *See Instructions on Reverse Side ID rm 9--.331 (May 1963) DEPAR~ENT OF THE INTERIORver~e<Ot"er.~ue)'"str"cti°ns ~ - .EOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WEt "'~ " (Do not use this form for proposals to drill or to deepen or plug back to a daft ~ren~ res~vo~ WELL WELL , ~ION OIL CG~NT OF ~.!F0~]IA ]' 3 909 West 9th Ave~ ~chora~e~laska 99501 ~{"-~'i~b 4.S~t'~°;~r~also space 17 below.)~e~ location ~ ~ in accord;~th any State require ~I 205'S & 4231'E from the NM co~er. ' j"~ oEo~ . . Section 7- T4N, RllW, S. M. DRAFT J _ 65-9I 78'~, ~NFER: ~' Ch~ Appropriate Box To Indicate Nature o~ N~/.R-~: NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] [ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) See Below* Form approved. B u d g_e t_ _ _I3~ _r e__a .u_ ~. LE&3E DESIGNATION AND SERIAL NO, A-028142 {~. IF INDIAN, ALLOTTEE OR TRIBE NAME .. 9. WELL NO. 7. UNIT AGREEMENT NA-~IE Kenai Unit FARM OR LEASE NAME 10. FIELD AN~'-PO(~ OJ{ WILD~&T Kenai Cas Field 11. SEC., T., a., M., os BLK, AND 8URVE~ OR A~EA Section 7' T4N, RllI~!,.~ 12. COUNTY ua PARISH] 13. STATE i ~enai Penn[. Alaska her Data · BUBSEQUENT REPORT OF: WATER SHUT-OFt' R~PAIaINO WELL FRACTURE TREATMEN~ ' ALTERING CASINO 8HOOT1NO On ACIDIZlNO ASANDON~NT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recomple~ion Report and Log form.) 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 raeasured and true vertical depths for all markers and gones per[l- nen~ to this work.) * C-2 Sand. PL/hN OF PROCEDURE: ESTIiXt~TED RIG OPERATING TIb~' *To clean out sand fill, treat the C-1 Sand for sand control and perforate.the ': ::..7 ';- · :- '. . : * · ~ - T'.'. : '" ,. : 1. Rig 'up over well. Jill well w/ ?0#/ cu, ft. KCL salt wtr. 2. Remove x-mas tree. Install and test BOPE. :. ~, - ~. Release dual hydraulic pkr. @ 4452'. Pull & lay &m. dual 3 '?/8"'tbg. ing ..... str s and accessories. ,-*. - .. . 4. Mill over and retrieve single permanent pkv. @ 5145'. .-" $ CO sand fill in ? $/8" csg. to 5556'ETD · "-" ' · · - '.,. 6. TIt1 w~ 7 5/8" RTTS tool and set above the C-1 Sand perforations @ +S200'. Treat the C,1 Sand perforations for sand control with hydroxy-alumYnum, : 8. Complete the well w/ dual 2 7/8" tbg. strings and retu o Ten (10) Days. 18. I hereby ~ert%~ey that the.loreg¢~ is true and correct ., .JUN5-'I974 o v,s °N 0 :AN" GAS TITL~ DiRt: Dr!g, St~t, DATE 5/29/74 ... (This space for Federal~or ~tate o~l/ce use) APPROVED BY ~ITLE CONDITIONS OF APPROVAL, IF ANY: *See Instructions on Reverse Side ,, DATE Approved p~.u RetUrned _ -- C-1 C-t 110' 42' ]52' 5.i 5.i 5.1 5.! 5.1 5.i Poor. B-4 B-4 0_'1 C-1 C-I_ INTE~2.IA!; LO:'4.~ q,rp T I!'~TNEVA r: 5270' -5)S0' 5392:-'5,1 q ' ' 54,~8'-5/, .... ' ' 0.3 22' 22' 22' 22' 16' 22' 126' FOOTASE ]].0' 42' JUN 5 I974 ~I¥I$ION OF OIL/iNI] 'J'UB*';~ ~ 7/3" 6.4:~ Short ~:,,,u, ]k<tl . - , pkr 4x52' },,-.kef Sac~:-'' Jt (50 000,":) 5108' J. ~,, ~.?' , ~ Psi ?,!odel "L" Sliding Sleeve - 53.10' ...... : .%-. '..r--..i .... N-1 Baker p!:r. & ~,,..nd~l - 5145' j~ 52' 20" 78 6:,' -!297' !0 5/,i" 32 7', II-,,.0 c:' --4396' Psi '~--~"~ "if' i'.~,~ sliding sleeve. · -4409' Psi seating nipple. 4593' --4615"'~ ,l 3/8" ]~,pf. 4850' JUN 5. I974 DIVISIqN OF OIL Amn mo .... 5307'-53q7'~ 4 3/8" hpf 53,19' 5392 ' - 54 34 '~ '1708'-,1730' 4821, _,~.,' .,,37' ., . bPlpeline Connection'::: ;' '::'. ~::~Mu]tiple Completion (,Dual or Triple) -: ,--.,;,,, I,~t,;:~? f' , -- ""~ Flow,Data''' ............. ~,.. ~- ....... :. ,- OAS.,,~L OPEN ~FLO~.B~E~IAL :~,ES~ R~,~ RT~ ~ , .Operator~,,- ..~'; ,.~ '-. ....... .... . ',- ,,-,.~:, --- · ..- :. ', I - Lease ~F~:, ~a~:~,¥~.~;~,:,~ · ,~: ,~ ... Well Xo. -~ - r :~-,~?,?:??..,~nton 0tl-Co,.~ o~ .CMifO~ia,~-.,~-,~-.-,?];.,,,-A-02$142~-:.. :.., ~ ..... '," ~i~;.:.:-. ,.: ~ -' .' .. ,,, - ~: . ,--~,w ,~ e--~Y~i-, '~P.T~---:~f~.':~ ~f,~,*-~;~'.~ &~*~, ' .,,"., ' ' : .... ] Interval, ~: ~-~.-~nsi.. · [ cnr--Sec."~ 6~.T4N,.'RI-I~'-'~":~ ..... ..,-'-, ..... ,~'~,:,' ............. ~-13-6S a~sn'~n 148' ~.STS · -,- I.,2..44~ ..... ..l.S~s4 .... I o.s~$~.l SI~4 1 2860~''1- None ' I " ' Time ' ' (Prover).' '~ ~':'-(Choke)~ (;~,: --.',~'~i.l~ress. ~fi~, ..',:~z :~-,;Dlff~ ;_m,;,-,~ -wol'~ubl.nK~ ~i; .],mlt ~,Casin~i~.ujv ,._ Flowing :.- ~o. : "-' of Flow . ;; f (Line) ":. ~.' ~ :~?' (Orifice) -'.:~ ' · .-' : ~ ,".. '"~. h . " · -Press~ ' ] Press. Temp. .);' HoursJ ' '' Size · '-'-, .' ':,;/Size' ": , '": pslg '~-,' -.., w', .~?~Si~na afa,] i:~.,tl pslg'.r,',,~C)~ OF s~' .... ' '-' ' ' '- .... ' · ' ...... ' """ ';~ ' '"1 c"::: '": ~1~''' "': ~' '2'826':'.' '/'--:' ~L~~'~`''''/':~ '"~:1~~-''' "f'~"5;sO" '~'14'~''~ ""' ~"'"'? ~ ~'"" '"'7'~e '"'-"'~ '"~':" "~'~'"'"?;" ' /h~'" ' P'i:' -':.:~'. pressure ~-::',- ':f 'Factor. .... '" :' ' Factor Factor Rate'of Flow :;:~I0.', I~."-,.: clent~ ~ '~/'- 9' '~ ' '-'~' '.'/",';Y:' :'' ':'- ' :: "· F.." '"- .: F F .'-:...,:',.' :.[ .,;: .(~_~.~,.,.~., :?,V',:[w,~..,[';~ m~; ..::;-',~'.:'~,~p~l~-.:~:'., ' ~" :' ':t.'"" ."", : ' g . . . . ,,._Q A~/D .... ',.~'-'-.:::,'s~,'z~: ".-"-,z~,'~s.,,"'.'"/~"~s,8'''' '',,z~s'"':"',"~:~4~s,'~,~ ~.o,s~" ,.'::~:.-::~:-i-::'~,:~,14:~. ~' ~-l~';"Tg'-::;": '[,:~' ::1476 :~'~ "('t'::'-' ,;:;':"::'~';~850L:' :,'-'[. """': '1:~423 ",- i.0S47 .; " '-:' :,,;:;,{~" ":.i'!.:!'~' : Al.ska Oil and Ga.'~:Oonser~at/o. Commission · . :.~"..~:.O::.:,~Oas WeU ~ .Flow P0~U~ Test Repo~ (4.Po~t Test) . ','Form No~,"G:i'":'7"/':,,:'~ ... , ~:. ~' .. - ,. .~ . : :": Auto.ed by Order No. 1 - . ~, ~ ~.~ .- PRESSURE CALCULATIONS - .:. -;! -_ . . :. (Supplement t9 Alaska 0 [ GCC Form No. G-l) [ Reservoir Field [ Kenni ~as Field Module. 6 Operato'r Lease No. Union Oil Co. of California A-_028_1,42 ' Surface Test Data Test Date 6-7-68 Well No. · 43-61,, ~ Test I (1) (2) (3) (4) . Ps Pf (Pws2-pwf2)· Q · No. L Psia ..... Psis_ 'X lO'q ' MCF/D .. 1 164! ,,1605 ,_ ...... 1!.69 ..... _, _.4470 · 2 " 1645 1565 25.68 6530' ~ 1645 1SO0 ...... 45.60 .,."8560 7__._4 ... 1645 1452 - . 59.77 10,140 . Sub-Surface Test Data Subsurface pressures measured. ,,:ut,:.cd c,:F IOCC. Subsu'r~ace pz'essures computed' Ct~llendar-Sr..4tk '"" Test No. (1) Pws Psia t _ _!. ! 1835 2 J_ 1840 3 1840 a _ i 8_4_0- S -- (2) Q. MCF/D 4470 6530 8560 10,140 Ptf Psia 1605 1565 ,1500 1452 (4) Pwf Psia (S)~ (Pws2-pw:2) X' 10'4 7.66 18lA 18o8 I 11.67 17.,00 18.15 1791 · 17_J9 . Nomenclatur Ps = Static Flow String Pressure Pf = Flowing Flow String 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 R'E-C 'E I V ' ' '" 40. :50 :: ~o0 ? · FIGURE No. UNION OIL ~ I SiON A I~A 8 KA · KENAI GAS FIELD DELIVERABILITY AT THE WELL NO. MODULE ' Q, ,'nscF/D : ~TION BY JEC 20 30 40 ( Pws~ - Pw f" ). 70 8o 9o Joo ';7);~[ Fleld?';"_'i"L"-'-l;.:~-'' -'.,.';; '.:' ' :': :' "'" ' :" ''" '~/'"')tJ;Reserv°lr~?* !~Z,,'.'~;:)?.' ':'"',' ,' :" . ...... JTes~ Date ", H;?;:;:'..'-,~..;,.:,'-~':';:UnionfOil"'Co."o£. Calff, ";.' ,."< ":' ':' ?.:~J '~:(';'A;028142 ?.::'~:';¢;('ountY.,t:~" .... ' .<.' -LOcation,." : ; ,-'i,'::..:'-': ",l-"~f, :. ~"."<.? ...... ',:~%":'-?:<' :<'J-, ':' :"-~O~ Prod-Intvl:.'~.!gss-N:~d~,,41~i,~',. · -'::'.':' ?: Produci.~ Thru-,:"l ~,,,,olr [ Wellhe.d. ;I cs0..s~,, --;:,~_I · ' ..'.WBG.'I ' CS~. 'J '¢Temperalure [':~emperat~ .. J" '< ':. ' '~;.[ I ,';: :"</:~'.' '..l -':' . [': ~" · X.':I-"- -'?.:-'1".'96' .~ / 71 "~ 17'5~8":' I "26;"~'""' '1 ' · " .... ' '' ' '~/' ' ' '' ' ' . ". .-.' .-":2,7/8J"~'.~, [ 2.875 '[-2,441 [4460' "";:" ':.:'Pipeline Connection :',,' ' ".' . ;, .' "'...,:';.:'" :"' ."~ ::' "" '":. '.i"r--/:'J Type. Taps :- ' :'.. ': ' ' Tied' ~0 [e~al.Ntll:Ill P1DelI~e ~1 Multiple Completion (DUal or Triple) - --- , _ ., .',;J Type pr~duction"from ;each zone 'Flow Data "' Time' ' : (Prover)' " (Choke) (~t~ ') t'Apress.-}.~:d>I:t ~'.i/.t ..I,i'iDIfL; bot~o I vtot:~ubln~ ~s ../oil ~,Caslngt~m,b, ::: Flpwlng , ~o. :" of Flow . . (Line) ~,~ (Orifice) .-': '.h '" Press. ' Press. Temp, '. · Hours - Size ~ · : Size pslg ' w .5i'~i~~',~t~ ~.~I 'p~i~;t,',~?)'~ i OF , i . ' '" ' " ': "16~2 ~. .... i ". 3,826 '"'~"2,S"~'~' ~ .... '~'1S'~7~'':'"'¥'' ~'~'~"2"~~'~"''"''' ,. "'"'t~" ""~'"' ~'"~"'"~", "~'"~ .... ' :: i'a"_ ' ' 3.826'. ' ,. 1'.'.. .J 3;826 ,. ... FLOIV CALCULATIONS < ~O. - '~ clent ' ' ~h '"'. p :~.. ;~' Pressure '' ~ . :'~:Factor', ~.:))' ."'. , FaCtor . ' ."':' · Factor ' Rate of Flow ' ~ :' :~':(24 Hr,) W/ - "m'- psla · ~' ' "F',~',.: ':L;,'/ · .'. ,, F P : '' ,_Q M~F/D . .:. -:,t. ,(.. ..... : ... : :. - . g '..,. ~[aq ,~Vl~a~'rq .~o~9~ . , ~.'....34':i~63'~'~''' "92,'$6'' ' "' 151~ '~,' ': ':' ,9777;:`? :"":"' · "~: '1]'~4~[/< ''1:~ a c~" ~. ~ ~4'.~'148<~''~: "'~':...145;.61" 1.548 ... . .,.981t?.;::.::..,- <. ,,i~~,..~,,,.,~,~.~,~,~u~,,~em ,':=.'. 7.,.-4',.¢a~,,..: '...:,.,. 3. ~':~'154''~'''''' ':'177~'94'-''''<' ;'1496'- "" ' ;9831"':'""::;'""' · 1.:1421"'; -/ '" '"l,lnx~.. a I~n ' ~.' ~. ' ~"1~4': 208.$8" .... "1'4~8'~ '" :' ' ,gSS0'~:'-'';' '; 1,S42~ ""~° - - .,... ... p ,- · .!. :- ,~ . . --!. -':'. , '.' .b ,.. w p~". ...'P Q ':, (F q)' ';.. :~,,.~(F'q)= X l-e'~ -' ';! ::' P~ ' ' P' -- ps ' Cal. . . , ~, [. .' ........ , ,,'. , . . . - , . · ; , ; ,. . ,, , , ...., ~:. ~:..~.~ ,,, -, : · ~. ' ' , , ", . ,.' '.. -,:.~ ,.' · : ,'~ ,. , , , , , ~ , ,.,., · ,. , ..... k~ . ,, ,. ' ' : ' '" PRESSURE CALCUIJATIONS ' " . [/, ' "i,. '. C"--R?~F~CA~'~ ~,~tho u.de~s~ed, ~tate ~at (comply), ~d ~at I am au~or~ed by,s~d comp~y..to.,m~e ~ repo~; ,~d ~at t~ repo~ was' pre- p~ed ~der my supe~sion_ ~d ~ec~n ~d ~at. ~e-f~c~ s~t~d.~ere~ ar~.t~e, .~ect~d 9~mpl~e to best of my~.ow]edge.- .' .'... "' '.',..:~ ' ~,-',- '-, "' ," ' ' ' " "St~a~e. /~: _. ,' ' :', . ,. ' ' -" C !" .E C'L IV E D ":'-' :''::": ' "" ...... ::," 'R 0 C]-. g 1.: 1968 .~ . . .... ,~iVlSIO~..O~ MIN~ & ~iN~,' "' ~O~GE ' ' ...... ' '".'(las Well Open Flow Potential Test.. Report (4.Point Test) ; ' - Form',No.. G-1 "' % , :i,: '~'Authorized ,by~ Order. No. 1 ,, · ', , ..,, . ", .... : .;'. 'Effective October 1, 191i8 " : " G~S WELL OPEN FLOW pOTENTIAL TEST REPORT PRESSURE CALCULATIONS · (Supplement t,o Alaska 0 & GCC Form No. G-l) Field Kenai Gas Field Operator Union Oil Co. of California Reservoir Test Date Module S.I 43-65 Lease No. Well No. ArOZ8142 ~3-65_ Surface Test Data ' - '(1) Ts) - ..... (4) Test Ps Pl. (Pws 2- pwf2) · Q No. Psia : Psia 'X 10-~ ' MCF/D 1 1647 1605 %__. 13.66 4570 .... , 2 1647 1548 31.63 7240 3 , _ 1646 1503 45.03 8850 ,.4 .. , 1645 ' ]447 ' 61 . 2'2 1.0400 Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures cemputed· Cullendzr-Smith ~',!et',:cd ,..F IOCC. ....... (I)' '=- (2) ....... (3) ' (4) (5) -,.,-~ Test Pws Q . Ptf Pwf (pws2-pwf ~) .. ..... .N.o. , Ps.ia MCF/D Psia Psia .... X 1°-4,- .. _, 1 . 1812. 4570 1605 . 1795 .~. 6.13 2 1812 7240 1548 1783 10.42 · 3 -- 1811 ' ' 8850 1503 1777 19 20 _ 4 lg!O 10400 1447 176~ 1__4,67 -. Nomenclature' . . Ps = Static Flow String Pressure Pf = Flowing Flow String 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 FIGURE No. · AL~ASKA DISTRICT KENAI GAS FIELD DELIVERABILITY AT THE $~/VO .~'A¢~ WELL NO.: '~./~-~$ MODULE: ,,.~./ Q. mscF/D : (Pws~ -Pwf2) o.,w, a~ sCALE JEC DATE ~ 1.0 20 3O 50 60 70 8o9o[o0 FORM 369 I0-59 150M PRINTED IN U.S.A. UNION OIL COMPANY OF CALIFORNIA D ocume nt 'Tra nsm iff al '-,,'* ~o. Anchorage, Alaska 9-17-65 St_~te Div., of bl&M FROH ;. _ - . - :-_ . AT A~horage TRANSMITTING THE- FOLLOWING: ": ?/:/;'i . Form P-~7 ' ~ SUBMIT IN DUPLI~ !* ~ ~(~ structions ~n Lo6* . . la. TYPE OFf.ELL: ....... Qm__~ ~ ..... ~s. ~ UnionOil Company of California n,,,,~,~.: 8. A9DRESS OF OPERATOR ........ ~C~o~ 2805 D St... Anchorage, ~aska 99503 4. L0CA~ION O~ W~L~ (Report location clearly an5 t~ accordance with a~y ~tate requirements)* ~ ~.~aeo 205'S and 4231'E from the NW corner Se~.7,T4N Effective: July 1, 1964 · 5. LEASE -DESIGi~TI0'N AND SERIAL' NO. A-028142 6. IF INDIAN, ALLOTTEE OR ~RIEE NAME 7. UNIT-AOEEEMENT N~I~E Kenai Unit $, 'FARM OR. LEASE NAME At top prod. interval reported below __ 1985'N and 4141'E from the SW corner Sec.6,T4N,RllW, SM ~~l~P~nd 4214'E from the SW corner SeG.6_.T4N:RI!W, SM .~ .SeO,7~T4N,RllW;SM ] 14. PERMIT NO. DATE ISSUED 1-2 BOROUOH ' 5'26-65 I 6-8-65 [ 6-13~65 [ ' ~:2' R~ ' ' ' "'.{ 20[ ~AL D~H, ~ & ~ [ Il. PLU~, BA~ T.D., ~ & ~ I ~2. ~ MULTIPLE CO'PL., [ I 23. INTERVALS ' [ ' [~ HOW MANY$ ' I DRILLED BY ' 5706'(4780'TVD) I 5556' (4661'~D)~ ~ Two : . ~' ~' ~ ~ 0~5706'.~ 2~. ~ODU~IN~ IN~E~AL{8), OF ~HI~ cOM~LE~ZON ~OP, BO~OM, NAME (MD AND ~VD) ~ "- ~. WA~ DIVISIONAL Module 5.1 4592-4886 (3918-4150',TVD) ~:. Module 6 5267-5485 (4442'-4608',TVD) o Yes . ('; . 26. TYPE ELECTRIC ~ND OTHER LOGS RUN ' 9. 'WELL NO;' KU 43-6 i0: FIEVlD AND POOL, ca WILDCAT Kenia Gas Field OR. AREA . 1ES, Sonic, Microlog, Gamma Ray, Cement Bo~d i'i '~' . CASING SIZE 10-3/4" 7-s/s" CASING RECORD (Report alt ~tri~gS 'set t~ ~vell) WEIGHT, LR./rT. ] DEPTH SET (MD) 78.60~ ] .52' 32.75~ , 1297' 26.40~ 5601' LINER RECORD 29, SiZE TOP (MD) EOTTOM (MD) SACKS CEMENT* CEMENTING RE~ORD 31. i1! None 1450 sacks 700 sacks TUBING RECORD ~93-46151aFORATION RECOaD (I~t~diz%%~u~ber)_ 4624-4646 5270-5305) 4- 3/8" jet . 45'80'4702 530'7~ 5'3'47']~ h0i~'s Pe-r 41708-4730 5349-5380 ) foot , (';'~ i 4821-4837 ~ 5392-5434 ) SCRE[IN (M!)) ~?"~ [---- SIZE [C' 7/8 L/SI 27. WAS WELL UORED 446.0 t A MOUNT Pb.]~LED - , None . None · r~C.~ES -SET (~D) · 445'2 ~1~4 ,I 5145 . 82. ~/ '...ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC, , DEPTH *INTERVAL :(MD) AMOUNT AND Kil~D OF MATERIAl, USED 34. I)isPosITIO~ OF G~S (801d,. ~sed .}'or ~$t.e], ~en~eg, etc.) [:" .'., ] TEST WXTNESSI~D. aY 35. List OF ATTACHMENTS ff ' [ ' ! [hereby ce formation is complete and correct as' determined from all available records~ SIGNED .~/_(~f~ _~/~/'///~~~ ,) TITLE Dr{iling Engineer . DATE- August 5:, 1965 ~ *(See .Instructions and Spaces For Additi~r~al Dataon Reverse Side) ' I NS.TR UCTI, ON.S General: This form is desig~d for submitting a complete .and Correct well completion report ~nd log on alli'~ypes i~f landS:and l~ases to e~her a. Feder~l agency or or :bo~h, pursuant to applicable Federal and/or State laws:and regulations. Az~y'necessary special": instructions cSncerntzlg, the'use of this form and the number - o , . · . .~ · .· ... . . . . . , ~,. ... - . :.~ .. ~.. ~ ,,, , submitted, partmularly with. regard to local, area, or regional' p~o~ures and practices, either: are 'shown below or. ,wi11 be' issued by, or ma_v- b~ obtained from . , . . .... ' , , ., ..... ~ ,.~ ,. ..~,~ ,~ ~ , , ~. and/or State office. See instructions on items 22 and 24, and 33~Lbelow.':regardin~g sepa~atb relJorts :for'sepa.~ate completior~. '""~ . r~ -!: i : If.not~filed prior to the time this summary record is submitted~.'~opies~of all ,cur~en.tly a~ailabl~ lpgSl (d. rill6ks,' geolOgi~ts, gamPigdnd core'..~ly~is, all types~,~lect~i~, tion and pressure tests, and ~directtonal surveys, should be:: attached hereto, to~ th~ extent' req~flred' bY applicable Federal and]~r State ']~w's ~nd re,latin)ns. should.: be listed on this form, see item 35. :' ' : i'~. "~:' I~ '4: If. there are no applicable State.requirements, locations on Federal or Indian land should be described in accO~danc~ with Fedekal ~e~uirements~' orlFederal office for sp._eciflc instructions. ' ........ ';~ ~. ! . .~, ~ i.~ Iiem-.18: Indicate whid~ elevation..iS used as reference (where' .not.-otherwise shown) for depth measurements given in-~the'r" floaces on ~hi~ fO~?andi in a~i~tt~ I~ems'~ 22 a~d 24: If thi'~ well is completed :for separate p~(~duCt~on ~f{-Om m(~re than one interval 'z(~ne (multipl~ ~oi/iPletion)r,~ so', S~ate in i~em~:~2, an~' i~{~tem interval, or intervals, .top (s),, bottom (s). and name (s) (if, ar{~) · f6, r' onlyi';'~he interval reported in item 33. Submit a Separate~report (-Pa~) dnqhis., form,, a~dequ'~ for each additional interval to be Separately'prodUced, sh°wtn~"tl~e'additi0nal data pertinent to sUch interval:'~ .'. ,. ~:',' .'.: /,.: : .,' ';' ~.'. ' ir:.:: ii ~ ~ , I~¢m 29: "Sacks Cement": Attached supplemental records for this well sh6'hld show.the details of any multipib stage cementing:and the i0catto~ of tl~:~ cem~ehting'~:l I~em 33: Submi~ a separate completion report on this:form for each i~terval to be'separl/te, ly produced. (Se~.. 4ns.truction.for items 22 and 24 ~bove:)i , : ,., .... ~ ...... ::. i ~7.' SI~'MI~IARY OF 'POROUS ZONES ' , ,, ,,:, ~ -~', ,~ , , . . , .. . ~ .... .~ , :. ' ." s~0w ALL IMP0ST~NT ZONES 0r 'POROSITX AND CONTENTS THEREOF ~"; t...' DEPTH INTERVAL. TESTED, .CUSHION USED, TIME. TOOLOPEN; .,.FLOWING ~. .:;FORMATION .... ; TOP BOTTOM ..... ; . ~, ~ ' ~ES~RIPTI~N, CONTE~TS, ET~. . ~; i~, ' ~' -- ~ ' .~'~ ~. ~1': '" ' E nai G ' '"' 5486 I'. ~e~dded ' e as Zone 4.'176 ' . ' ~,. . : . ) · ~ ',:: , ,. .....~ r-: '"'.'~:" ' r' ~:. . : ......... ~. ' "" : "' ': : " ' ~"'~ ., ' ' . . ... . .,... : ~. -: : ....... _. ~. · . : .... - ' i . .';, i , ~ , (-- ,.' '~. .... .. '~' : : ~ ~ , · . ~. .. . ; .. ; . e o , . ~' ' ' '"' ' -' 'r. - : - ~ ...... . ~ ,-:. :J - . ..~;: ~.: : " ' ':": ' '' : ~'~ ..~ ., ........ ~.~ .,' , ~ , ~ ::. z - . . ,. , ~ ::~ ~..i~ .. .._.~ . .. . ~._ . ' DM-12 Date 7-13-67 _i __ i i ill _ State of Alaska Department of Natural Resources DIVISION OF MINES AND ~ Petroleum Branch INDIVIDUAL WELL RECORD Top 'Bottom 7 6 T. 4N 4N R. 1 lW 11W S Meridian Pemnit No. 65-9 Issued 4/26/65 Operator Union Oil Co. of Calif. Location (Surface)205" FNL & 4231 FWL, Sec. 7 Lease No, A-028142 or Owner ..... K~nai th%it Loc. (Bottom) 2655' FSL & 4231' FWL,. _Sec~.. 6 Well No. 43-6 Area Kenai 6/8/65 Suspended Abandoned Completed (F-GL-P) 6/13/65 IP B/D, Gray Total Depth 5706' Elevation78.05' Grd, 92'_..._~.B. 79"' Csg. Hd. API Cut % Gas MCF/D, Bean ;-/64 CP psi, TP Casing: Size Depth Sx Cmt Perf:4 3/8 hpf, 45931461~lugs~ 4624'-46"'; '/+6S0'-4702' - - 20" 52' None 4708'-30'; 4821.'-27' 4850'- 72 ' 1297' 1450 5270''5305 ' 10 3/4" 5307' -47'; ' 5349' -80' 7 5/8" 5601' 700 5392'-5434' - 2- 7/8'~'/S' 4460 Packer 4--------~52 2: 7_/8_t.~/S= _5156, ~cker_ 5145 GEOLOGIC FORMATIONS Surface Lowest Tested. Name psi PRODUCTIVE HORIZONS Depth Contents WELL STATUS Year Jan Feb M...ar _Apr .... ..May , June July Aug Sept Oct Nov Dec Remarks: REPORT and PLAN of RECEIVED SEP 20 1965 DIVISION OF MINES & MIN£RAL~ ANCHORAGE SUB-SURFACE SURVEY UNION OIL COMPANY KENAI UNIT Nn45' 6 KENAI. ALASKA JOB NO. DATE ..... ~JgNE 1965 DRILLING CONTROL CORPORATION 3327 LIME AVENUE LONG BEACH 7, CALIFORNIA DRILLING CONTROL CORP. SURVEY DATA SHEET SHEET NO- COMPANY .... _._U~_~ Oil ~~ DATE 1965 JOB NO ..... WELL FI ELD.. COUNTY ...... STATE Alaska TRUE RECTANGULAR COORDINATES MEASURED DRIFT DE VIATIOI~ DRIFT VERTICAL ~, , REMARKS DEPTH ANGLE COURSE DIRECTION · DEPTH NORTH SOUTH EAST WEST , I25 1 ° 30' 124 96 ~ 3 27 N29°~ 2 86 1 58 200 ~'~ 15' 199 94 I 64 N 38° g 4 15 57 250 3° 45' 249 ': 83 3 27 N 19° E 7 25 50 354 &o 00' 3.53' 25 : 10'87 N 17° i~ 17 64 3 67 ~7 7o 15' 445 52 ' 11 74 N 18° E 2800 7130 539 8o 00' 535 62 12 30 1~t5o E. 41 lb I0~62 :600 9o 30* 596 78 10 07 l~a'~ .51 23 , ,,I0i.62 695 I1o 00'. 690 03. 18 13 N 14° ti .68 83 '6;24 . 756 .... 12° 45* 749 53 13 46 1901fl~ 82 29 6 24 819 19° O0· 809 10 20 5I N 12`) E '102 35 ' 10 51 878 21:' 00' 864 10 21,14 N 18° E 122 45 .'i7 911 21° 15' 894 1I. 96 N 14° E 134!05 19.:93 943 22 o 45' 924 45 12 37 N ·06° E 146 35 · 2122 ~' 978 23° 15' 966 61 13 I12 N 01o ~ 150 17 :20 98 1040 ~.o 30' 1013 47 24 72 N 03~' W 184 186 19 11.33 24° .45., 1097 :9-3 38 94 'N 01° ~ 223 79 ,1~ :~ 123~ 27~ 00, 1184 36 44 04 N 12° 1/ 266 87 .9 I270 30'~ 30' 1218 83 20 30 N 15:'~ · 286'48 :4 58 13,30 32° 00, 1.269 71 31 30 N 12° ti 3:17 58 1402 31° 00' 1331 43 37 08 r,l 14° l~ 353 56 11 Ol 1499, 25° 00' 14/9 34 40 99 N 07° 1~ ~ 24 16 00 1576 24~', 45 '" 1469 27 32 24 N 06 o t/ 426 30 19 37 1637 26° 00~ 1544 10 26 74 N 05° ~ 45294 21 70 1698 27° O0* 1598 :46 27 /,9 N 06° ~ 480 48 24 59 1762 28° iX)* 1654 .83 30 29 N 06`0 ~ ' 510 ~ '2';76 , {DRILCON! DRILLING CONTROL CORP. SURVEY DATA SHEET COMPANY ...... []~LO,~3.. 0~. ~,~ ................... DATE .... ~e. ~ WELL K___U__. _ _'~""_ ._6 ....... FIELD ....... _~__e~. _~.! ............. COUNTY ..... SHEET NO, 2 JOB NO, TRUE RECTANGULAR COORDINATES MEASURED DRIFT VERTICAL DEVIATION DRIFT DEPTH ANGLE , COURSE DIRECTION REMARKS [~.. - .,, DEPTH NORTH SOUTH EAST WEST 1857 30~ 00-' 1737 .0 ,t750 N 07° t~ 557 76 33 55 ~' 1948 31!~' 00" 1814 ~7 48 22 N 07:' I~ 605 52 39 43 2041 33~' 45' 1881 ~0 51 67 N 08~ t~ 656 i'8 46 62 2134 35° 45' ~1967 18 54 35 N .08~ P/ 710 ,$9 5419 2226 37 '~ 45' 2039 ~2 56 32 N 08° ~/ 766 T/' 62 02 2320 39° 00' 2112 87 59 16 N 09° 1~ ~4 80 71 27 2416 40° 30' 21B5 87 62 35 N 10° t~ 886 20 82 I0 2542 39° 30' 22[13 09 80 15 N 13° t~ 964 30 10013 ,2634 39':' I5' 2354 ]3 5II 2I N lZl°~ 1~ 102C ~2'8 11421 2731 38':~ 45' 3429 913 (nO 71 N 13~ I~ 1079 93 12787 2825 38~' 30' 11503 55 58 52 N 14" W 1136.71 14203 28~1 .36,~ 45' ~ 42 33 51 N 07° t~ 11~: 97 146 1I 2912 37' 00' 2573 18 10 66 N 06:~ I~ 1188 53 148 06 30~ 38':~ 30' 2645 ~)6 57 /:)9 N 05:~ t~ 1114620 153 11 (' ": 3099 40'~ O0~ 2717 )7 60 42 N O5"' ~ 1'30639 158 38 3130 39° 00' .27,42 )6 19 51 NOll'llt 1325 90 158:38 3t82 39':' 15' 27~2 ~3 3290 :N 05° E 1358 68 155,51 3259 39'" 15' 2841 )6 40 72 N 04o E 140'7~8 152:11 3384 38° 45' 2939 15 78 24 N 09° E 1484 56 139 87 3510 37':' 45' 3039 )8 77 14 N 04° E 1561 51 134:49 3634 3~'~ 15' 3139 37 73 ~ N 04° E 1634 55 129i38 3759 36'~ 00' 3240 ~ 7347 N 04o E 1707 94 124:26 3074 35° 45' 3333 53 67 18 N 04'~ E 1774 96' 119 58 , 4(X)6 35° 30' 3440 98 76 65 N 04,, E 1851 ~2 114123 4153 35¢~ 15' 3561 02 04 84 H 04° E 1936 ii&. 108 31 ~ ,,, , .... ~ DRILLING CONTROL CORP. SHEET NO., SUI~VEY DATA SHEET CoMp^NY .... t~ionO~LCo~m~y . OAT~ ~_~_ l.~C~ ~os No. WELL E U ~a.~.~3___ FIELD_ ~R _t~3~_ COUNTY_ STATE TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATIOI~ DRIFT DEPTH ANGLE VERTICAL COURSE DIRECTION REMARKS DEPTH NORTH SOUTH EAST WEST ,~10 34:~ ,45' 3690 O1 ~) 49 N 0~> l~ 202~ 33 444,4 35o 45, 3814 99 89 97 N 04~ E 2115 o8 ~1~3 36" I;5* 3943 21 94 02 N ~ > E 2208 74 87 60 4778 37'30' ~ 18 9'436 NO4~E 2302 87 8101 5085 39' 45' 4~4 37 ~ 91 N 07~ i~ 2495 42 60 81 5~2 41:' 00' 4407 7(, 89 ~ N (:~,'~ E 2584 % 52 97 5366 40'~ 30' 4514 26 93 52 N 0T~E 2677 78 41 58 5706 38'~ 00' 4779 80 94 ~1 N 07~' g 2892 (~05~ 2892 41 NO© 21' .... ' ' ' X~ pep.~o:)e~ i Jo ~o ' ~o '.~ .~.' s~)'~8 .d~u~l.~u '~W J~ ' ~ ' '~J,~ ,,, 9 "Jo ~ Jo ffS~ ~.'0'r 'dmei"s~W'~ ' 0~ V~ I ~ aldm~oa~no~ ~I .,~ ~' 08~' '~S~A~ ~ , ~ :'l - ~ eloH u] pjnlj ~ ...... 16~ IO~OlUl 6ol -~ ,, ~60S - ~o6601--qlda ~0 ~S ~OllU~ldo~ '~ 3NO 'oN una .~ , . '" S~ 'l'O ~o~p~nsD~wSuUIHQ ~ '~'O mnloo '~aa aAoq~ 'l~';~l ' ~o~ pa~ns~w ~o1 .......... ~6 '8'N :'~el~ ,SL 'AOI~ ' ~9 :wnlo~ lU~UDW~ad i I i 14[['a6a N~ d~l 'L 3eSi. ~0 . . . ~~ · . . ~0 i :se~?aS JoqIO~ 3 , i~ff ? S ,S0a NOIIvDo1 Z O ' ..~ , , , ~ Z ..... . ~ ~ ~ . v~SV"~v]IVIS FIg~0~J~aC I~a3~ llNflOD ._-~ m m' m ~ Z Z- ..... : ~]NIW · S]NIW JO NOI~I~ ' I~N3~ al]la ~ -'- - J a 'JI;'dr:~l-'lVS. JO AIIVdH00 -ii0 HOINR AN~dWOD ~ ~'" J II I I I Ill II I I I I ,.,- . .liB. fj~.~) !~. . ~ '0 0 O' o o ~ · 0 0 0 :i . i l ' 0 0 0 0 .0 m m .:'. ! ! · ! . J l .) i O. 0 0 ' 0 0 ! 8L '1'3 " ~O 90Z.c; Ol BlltO R6g~ aa~ DSM$ , L 69 g DSM$ ~/~1S~"1~/ ']J.¥1S HgN0~N~, I V. N3~t ,U. 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