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Home My WebLink About168-051• • Marathon Oil Company Alaska Asset Team „~~ ~~- Ma~'at ~n P.O. Box 1949 ' MARATHON ~ ~~I Company Kenai, AK 99611 Telephone 907/283-1371 Fax 90712$3-1350 November 28, 2007 Mr. Tom Maunder ~'~ Alaska Oil & Gas Conservation Commission ~p~ ~ g 2pq~ 333 W 7th Ave Anchorage, Alaska 99501 Alaska Oil & Gas Cams. Commission ,Ancharage Reference: 10-404 Sundry Report Field: Kenai Gas Field ~ ` Well: Kenai Unit 43-6A ~~,. o Dear Mr. Maunder: Attached for your records is the 10-404 Sundry Report toying the work completed on KU 43-6A well under Sundry # 307-216. The initial plan was to install a concentric string to improve water displacement. Sand production increased after the instillation of the 2-3/8" tubing string causing erosion concerns. Marathon decided not to proceed with the instillation of the 1-3/4" coil tubing portion of this project to prevent sand erosion concerns on a second tubing string. Please contact me at (907) 283 -1371 if you have any questions ~or need additional information. Sincerely, ~ ~~~ ~ ~ ~~~ '~la~~~ ~~ ~vti~ ` Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS DMD ,.~~- ~~1~~~ • STATE OF ALASKA ~~1/ ~ $ Z(1O~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~1l01p~ ~~~ & Gas ~~~~• Cammissiofi Anchorage 1.Operations Abandon Repair Well Plug Pertorations Stimulate Other ~ Install 2-3/8" Performed: Alter Casing ^ Puli Tubing ^ Pertorate New Pool ^ Waiver^ Time Extension ^ Tubing Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re-enter Suspended Weli ^ 2.Operator Marathon Oil Company N 4. Well Glass Before Work: 5. Permit to Drill Number: ~ ame: Development Q Exploratory^ 168-051 3. Address: Stratigraphic ^ Service ^ 6. API Number. PO Box 1949, Kenai Alaska, 99611-1949 50-133-20123-00-00 T. KB Elevation (ft): 9. Weli Name and Number: 87' MSL Kenai Unit 43-6A 8. Property Designation: 10. FieldlPool(s}: ~ A - 028142 ~ Kenai Gas Field I Sterling Pool 11. Present Well Condition Summary: Total Depth measured 5,300'' feet Piugs (measured) 4,519' true vertical 4,565' ~ feet Junk (measured} NA Effective Depth measured 4,788' feet true vertical 4,139' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 0 0 0 0 0 0 Surtace 1,250' 10-314" 1,250' 7,195' 3,130 psi 1,580 psi Intermediate 0 0 0 0 0 0 Production 5,289' 7-5/8" 5,289' 4,555' 4,140 psi 2,890 psi Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 4,407' - 4,534' True Vertical depth: 3,813' - 3,922' Tubing: (size, grade, and measured depth) 2-3/8" 0.175" WT HS80 4,440' Packers and SSSV (type and measured depth) Weatherford SLPL Isolation Packer 4,010' - 4,388' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,250 15 8 Subsequent to operation: 0 3,000 135 25 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-216 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature Phone (907) 283-1371 Date November 28, 2007 Form 10-404 Revised 0412006 ~~a~ O ~ ~ ~ I (~ ~ ~ ( Submit Original Oniy r: Permit #: 168-051 API #: 50-133-20123-00-00 Prooertv Des: A - 028142 KB: 21' (87' above MSL) WBS #: Latitude: Longitude: KU 43-6A Pad 41-7 217' FNL, 4,279' FWL Sec. 7, T4N, R11 W, S.M. ~~ ).~ r;: r. Tbg Hanger prepped w/ -4' of 5-112", 14.0 ppf, K-55, STC pup jt No Re-entry guide on pump -5" Type "H" BPV profile -5-112" LTC lift threads rr Tree CXN: 3-112", 8b ~`, ~, r. ~, Isolated Perts 4106'-4107'(Sgzd) A - 8 4173'-4177' (Sgzd 4100) _~ A-1o a27o'-a2sa' (ivlno) A-11 4338'-4370' (11!1!70) Existing Perfs ~ ~ ~ ~ ~ i1= B-1 4407'-4457' (50') ~ ~ 1.~, ~ Isolated Perfs t, - B-2 4521'-4534' (13'j (8 spf, 511100) ~ sai C • ~A~nioN Surtace Casino 10-314° J-55 40.5 ppf Armco T~ Bo om Seal Lock ND 0' 1,250' TVD 0' 1,250' Cmt wl 1,575 sks of Class G Productio n Casino 7-SIB° J-55 20.4 ppf LTC J~ Bottom MD 0' 1,140' TVD 0' 1,140' 7-51a° N-80 33.7 ppf LTC Tip Bottom MD 1,14D' 5,289' TVD 1,140' 5,299' Cmt w/ 1,500 sks of Class G Isolation Assembly -Weathertord SLPU Isolation PKR @ 4010' -5-112", 15.5 ppf, K-55 LTC scab liner assemby 4010'-4388' -Weathertord SLPL Isolation PKR @ 4388' 2-3/8" Velocity String: BHA = 12.5' Hole at 4,436' XN at 4438' Entry guide at 4440' FIII: 4562' KB (5128104) 1: Halliburton EZSV @ 4703' (4100) is Baker "K" bridge plug @ 4786' Howco EZ CIBP @ 4800' capped wl 14' cmt 1: Howco EZ bridge plug @ 5217' ELM (1114197) mdoned Perfs: B-5 4930'956' TD @ 5300' Inflatable Bridge Plua 3-318" @ 4,519' KB (20 Dec 2004) Well Name & Number: Kenai Unit 43-6A Lease: Kenai Gas Field, Pad 41-7 County or Parish: Kenai Peninsula StatelProv: Alaska Count USA Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: Ground Level (above MSL): 66' RKB (above GL): 21' Prepared By: Kevin Skiba Lasl Revision Date: 11/27107 • Marathon ail Company Page 1 of 5 operations Summary Report Legal. Well Name: KENAI UNIT 43-6A Common Well Name: KENAI. UNIT 43-tiA Spud Date: '1/1/1968 Event Name: W~RKOVER Start: 7/5/2007 End: Contractor Name: Rig Releaser Group:: Rig Name:. Rig Number: Date Erom - To Hours Code Code. Phase. Description of Operations 7!5/2007 09:00 -10:00 1.00 SAFETY MTG_ CTBG Obtain permit. Held Pre-Jab safety meetingand Job specific tasks 10:00 - 18:00 ~ 8.00 ~ RURD_~ COIL ~ CTBG - 10:00 0:00 - 13:00 I 3.00 SAFETYIMTG_ CCTBG COIL I CTBG 17/18/2007 116 00 -16:30 ( 0 50 ~ SAFI ETYI MTGR I CTBG 16:30 - 20:30 ~ 4.00 ~ NUND ~ BOPE ~ CTBG - 21;01) ~ 0.50 ~ SECUR~ WELL ~ CTBG ~ 7/19(2007 ~ 07;00 - 08:00. ~ 1.00 ~ SAFETY ~ MTG_ ~ CTBG 00:00 - 14100 I 4.00 ~ RURD_I COIL (CTBG 14:00 - 15:30 ~ 1.50 ~ RURD_~ COIL 15.30 - 17:00 1.50 RURD_ COIL CTBG 17:00 - 17:30 0.50 SECUR WELL CTBG `7/21{2007 l 10:00 - 10:30 ` 0 50` SAFETY MTGL `CTBG 10:00 - 12:00 O.OO I PUMPUy N2O1L (CTBG 12:00 - 15:30 I 3.501 RUNPULI COIL I CTBG 15:30 - 16:00 ~ 0.50I TEST_ ~ BOPE ~ CTBG (JSA) on stabbing large coil tubing:. MIRU equipment, spotted tanks, coil unit and'. equipment around avell head.. Nipple up BOPS on #op of wellhead. Stab in 2.375" coil tubing. Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA) cn operating large coil tubing. Discussed BOP testing procedures. Finish hooking up hydraulic lines to injector head... Rigging up lines to BOP to pressure test. Forced to shut. down due to possible technical difficulties running VS under current rig up. Suspend operations until Monday. Arrive on location, sign. in, obtain work permit and hold pre-job safety meeting for Spotting and Rigging Up Coil Tubing Equipment, Installing; BOPS on Flowing. Well Tree. MIRU coil unit and equipment around well head. Nipple up BOPs on top of wellhead. LD liner to set Tanks. Set Tanks and Flow back Manifold. Contacted Jim Regg with AOGCG @ 15:00 hrs. 7/17/2007 about the BOPS Pressure Test on the KU 43-6A Thursday Morning July 19th @ 0800 hrs. Jim gave us a waver from the commission witnessing the. BOPS Test. Jim told me to go ahead. and test the BOPS when I was ready and write on the form I file with the commission that hegave me a waver:: Install night cap on BOP's. Safe out location and suspened operations for the. night. Arrive on location, sign in, obtain work permtand hold. pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations, 'Finish rigging up coil unit and equipment around well head. Function test BOPS. Pressure test BOPs. Low pressure = 300 psi. High pressure = 2500 psi. Good test. Prepair coil tubing to stab. into injector by installing bull nose on bottom.. of 2-3/8" Coil Tubing. Stab 2-3/8" Coil Tubing into injector. Remove bull. nose from Coll tubing. Nipple up injector head to wellhead. Start N2 equipment cool down. Purged coil free of water with N2. RD Coil Tubing Injector and Lubricator. Stand Back Lubricator and Set .Down Coil Tubing Infector. Install Night cap on Tree. Secured well for night. SDFN. Signed out for the night. Arrive on location, sign in, .obtain work permit and hold pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations. PU Ccit Tubing Injector and lubricator and install. Nipp[e up injector head to wellhead. Start N2 equipment cool. down. Purged coil free of water with N2. Remove Lubricator-and Injector from Well head. Install Coil Tubing BHA (12'-6" overaN) Consisting of Pump out Plug (2.23" O.D. & 1-3/4" Long), Centralizer (3-1/2" O.D. x 1.5" I.D. x 12" Long, NoGo/x-over (2/1/2" OD. x 1.135" I.D. x 7-1/4" Long), Straigh# Bar (2-1/2" O.D. x 2.44" LD. x 10' Long), Grapple Coil Connector (3.25" O.D. x 1.5" I.D: x 10" Long), and 2-3/8" Co! Tubing w/ 0.134" Wali thickness. Grapple Coil Connector Welded an to Bottom of 2-3/8" Coil Tubing with Straight bar, NoGo, Centralizer, and pump out plug screwed on bottom of Connector: Pull test CC to 1.5.,000#. Pull Test.. Held Good. Install Injector and Lubricator on Well head. Pressure test Lubricator to • . Marathon Oil Company Page 2 of 5 ®perations Summary Report Legal Well Name::. KENAI UNIT 43-6A Common Well Name: KENAI UNIT 43-6A Spud Date:- 1/1/1968 Event Name: WORKOVER Start: 7/5/2007 End: Contractor Name:. Rig Release: Group:. Rig Name: Rig Number: Phase Description of Operations Date From - To Hours Cade C d o e 7/21/2007 15:30. - 16:00 0.50 TEST_ BOPS CTBG Well Head Pressure. Held pressure Test. 16:00 - 1.8:00 2.00 RUNPU CO-L CTBG Well head open, RIH w! BHA and 2-3/8" Coil Tubing Velocity String.. Tag @ 4444' KB Coil Tubing MeaSUrement. Pull up hole 4' to 4440'. Set 2-318" Pipe Rams and Slips. Pull test and lock in slips. Bleed off Lubricator and Remove Lubricator and Injector.. 18:00 -.1830 0.50 RUNPU COIL CTBG Install Tubing Hanger Connection on Coil Tubing; Loatl Coil Tubing an Coil Tubing Unit with 6% KCL Water. Install GS Pulling Tool on Coil Tubing: on Coil Tubing Un#. 18:30 -19:00 0.50 RURD_ COIL CTBG Latch GS Pulling. tool on to Coil Tubing in Well. PU Coil Tubing Injector and lubricator and install on BOPS Stack. Pressure test Lubricator to Well Head Pressure. Held pressure Test. 19:00 - 20:00 1.00 RUNPU :COIL CTBG. Pull Test Connections to 20,000 # pull (10,000 # over Coii Tubing String Wt). Release BOPE Pipe: Rams and Stips. RIH 12' to set Coil Tubing fn Tubing Hanger. Lock in Tubing Hanger. Test Seal on Tubing Hanger. Seal .Held 3,000#. Set Coil Tubing @ GS Pulling Tool: in Neutral Tubing Wt. Pressure GS Pulling tool to 600 psi: Release GS Pulling Tool and Pull GS Pulling tool up hole 3'. RD Vetcogray. 20:00 - 21:00 1.00 SECUR - WELL CTBG Shut in All Valve on Flowing Christmas Tree. RD Coil Tubing lnjectar and Lubricator. Laydown Lubricator and Set Down Coil Tubing Injector.Close BOP Blind Rams. Secured well fior night. Asked .Number Qne Operator to Lock out/Tag out Bottom Master Value on Tree so it ~ could not be closed on Newly Installed 2-318" Coil Tubing.. 21:00.- 21:30 .0.50 'SECUR WELL CTBG SDFWE. Signed. out for the night. 7/23/2007 07:00 - 07:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre job safety ', :meeting. 07:30 -12:30' 5.00 RURD,_,_, COIL CTBG RD BOPE Stack. RDMO Coil Tubing and Crane. 12:30 - 13:00 0.50 SECUR WELL. CTBG Secured well. Leave Weil Shut in. 7/29/2007 07:00 - 08;00 1.00 SAFETY MTG_ CMPRUN Arrive on location, sign. in, fill out work permit and hold pre job. safety meeting. 08:00 -13:00 5.00 RURD COIL CMPRUN Wait on permit: Compressors shut dawn and no operators are available to issue permit. 13:00 - 1.4:00 1.00 SAFETY MTG_ CMPRUN. Issue work permit. Hold safety meeting again. 14:00 - 14:30 0.50 TEST_ ROPE CMPRUN Start pump and start pressure test. Reel swivel is leaking.. 14:30 - 17:00 2:50 WAITON ORDR CMPRUN' Discuss options.. 17:00 - 17:45 0.75 RURD COIL CMPRUN Load. reel on trailer and dispatch to yard. Will respool pipe onto different reel. 17:45 - 1..8:00 0.25 RURD_ COIL CMPRUN Secure location-and leave. 8/31/2007 07:00 - 07:01 0.02 Notifoed AOGCC by email and phone at 3 PM Aug 30. Recieved waiver from Jim Regg on witnessing BOP test. 07:01 - 07:45 0.73 SAFETY MTG_ CMPRUN Arrive on location, sign in, issue work permit and hold. pre-job safety meeting. 07x45 - 11;170 .3.25 RURD. COIL CMPRUN Spot reel and coiled tubing unit. RU iron. 11:00 -12:1.0 1.17 TEST_ BOPS CMPRUN Perform full BOP test, 250./ 2500 psi (3000 psi tree). 12:10 - 13::00 0.83 RURD_ COIL CMPRUN repave owe connector on . ; ' ve oaty stung. ssue hot work permit. 13:00 - 14:15 1.25 RURD .COIL CMPRUN Weld connector. 14:15 - 15:00 0.75 RURD. COIL CMPRUN Secure location and leave. 9!5/2007 08:00- 08:30 0.50 SAFETY MTG_ CMPRUN Arrive on location, sign fn, issue work permit and hold'pre-job safety meeting, 08:00 - 09:30 1.50. KURD ^ COIL CMPRUN Nipple up 7" lubricator. 09:30- 14:00 4.50 RURD COIL CMPRUN Wind. is increasing. measure gust abovew 25 MPH. Suspend operations dune to wind speed based on crane and manlift limits.. Secure location and leave. PM • • Marathon Oil Company Page 3 of 5 ®perafiions Sumrinary .Repast Lego[ Well Name: KENAI UNIT 43-6A Common`Well Name: KENAI UNiT 43-6A Spud Date: 1/1J1968 .,Event Name: WORKOVER Start.: 7/5/2007 End: Contractor Name: Rig Release; Group; Rig Name; Rig Number: Date 'From - To Hours Code Cade I Phase Description of Operations 9/6/2007 08:00 - 08;45 D.75 SAFETY MTG GMPRUN Arrive on location, sign in, issue work permit and hold pre-job safety meeting. 08:45 - 09:00 0.25 TEST BOPS GMPRUN Shell test BOP /lubricator 250 / 1500 psi. 09:00 - 11:00 2.00 RURD_ COIL. GMPRUN PU injector and MU 7-3/4" BHA. PU'7" Lubricator. 11:00 - 11:30 0.50 RURD COIL GMPRUN Unable to bleed pressure off of 2-3l8". 45 psi shut in and 22 psi flowing. 11:30 -12'30 1.00 RURD COIL GMPRUN Test hanger asst' to 2000psi. No leaks. Call for Pollard: slickfine unit and rig back BJ. 12:30 - 14130 2.00 WAITON EQIP GMPRUN Wait on slickfine. 14:30 -15:10 0.67 SAFETY MTG ! GMPRUN Hold safety meeting and discuss complete pollard JSA, 15:10 -17:10 2.00 RURD_ SLIK GMPRUN RU slickfine and stab on well. 97:10 -18:30 1.33 TEST_ EQIP GMPRUN Attempt to pressure test lubricator; Pollard pump cant catchy suction.. RD pump and send for repairs. 18:30 - 19:00 0.50 RURD_ SLIK GMPRUN Secure location and shut down for night. 9/7/2007 07:00 - 08:00 1.00 SAFETY MTG_ GMPRUN Arrive on location, sign in, issue work permit and hold pre-.job safety meeting. Discuss complete Pollard JSA. 08;00 - 08:30 0.50 RURD_ SLIK GMPRUN RU slickfine and stab on well. 08:30 - 08;45 0.25 TEST,_ EQIP GMPRUN Pressure test lubricator to 2000 psi.. 08:45 - 09:30 0.75 RUNPU SLIK GMPRUN RIH w/ 1..15" swedge to 4425' MD, tag and beat out pump out plug...: POH. 09:30 - 09:45 0.25 RURD_ SLIK GMPRUN PU 1.25" x-line. running tool and x-plug body. 09:45 - 10:00 0.25 TEST_ EQIP GMPRUN Test lubricator to 2000 psi. 10:00 - 10:30 0.50 RUNPU SLIK GMPRUN RIH x plug body and set at 4434' MD. POH. 10:30 - 10:45 0.25 RURD,,,_, .SLIK GMPRUN PU 1.25" JDC and X prong., Stab on to well.. 10:45 -11:00 0.25 TEST EQIP GMPRUN Test lubricator to 2000 psi. 11:00 - 1:1:30 0.50 RUNPU SLIK GMPRUN RIH and set prong in X-plug body> POH. 11:30.-12:00 0.50 RUNPU.. SLIK CMPRIJN Attempt to bleed down 2-3/8". Unable to bleed. 12:00--12:15 0.25 RURD_ SLIK GMPRUN PU 1.25" JDC and stab on, 12:15- 12:30 0.25 TEST_ EQIP GMPRUN Test lubricator to 2000 psi. 12:30 - 1.3:10 0.67 RUNPU SLIK GMPRUN RIH and latch prong ai 4431'. POH 13:1.0 - 13:20 0.17 KURD. SLIK GMPRUN OOH No prong. Stab batik on well.. 13:20 - 13:30 0.17 TEST_ EQIP GMPRUN Test lubricator ko 2D00 psi. 13:30 -14:00 0.50 RUNPU SLIK GMPRUN RIH and latch prong at 4431'. POH 14:00 - 14:15 0.25 RURD_ SLIK GMPRUN OOH. LD prong. PU 1.25" GS pulling took Stab back on well. 14:15 - 14;30 0.25 TEST_ EQIP GMPRUN Test lubricator to 2000 psi. 14:30 -15:00 0.50 .RUNPU SLIK GMPRUN RIH and latch plug body 45;00 -15:10 0.17 RURD_ SLIK GMPRUN. OOH. LD plug body. PU 1,25" x-line running tool and' vedressed plug body. Stab back on welh 15:10. - 15:20 0.17 TEST_ EQIP GMPRUN Test lubricator to 2000 psi. 15:20 - 15:50 0.50 RUNPU SLIK GMPRUN RIH with redressed plug body and set at 4434'. PQH 1.5:50 - 16:00 0.17 RURD_ SLIK GMPRUN OOH still have plug body with sand. Glean out and stab back on. :16;00 - 16:10 0.17 TEST, EQIP GMPRUN Test. lubricator to 2000 psi. 1.6:10 - 16:45 0.58 RUNPU SLIK GMPRUN RIH with plug body and work tools on bottom, POH. 1:6:45 - 18:00 1.25 RURD._ SLIK GMPRUN OOH. S811 have plug body. Secure location for night. 9/8/2007 06:30 - 07:30 1.00 SAFETY MTG_ GMPRUN Arrive on location,: sign in, issue work permit-and hold preyob safety meeting... Discuss complete Pollard JSA.. 07:30 - 08x20 0.83 RURD_ SLIK GMPRUN Redress plug and running knots. RU slickfine and. stab orrwell. 08:20 - 08:40 0.33 TEST EQIP GMPRUN Pressure test lubricator to 2000 psi.. 08:40 - 09:15 0.58 RUNPU SLIK GMPRUN RIH 1" DD bailer and bail from 4435' - 4437. FOH 09:15 - 09;30 0.25 RURD_ SLIK GMPRUN OQH. Empty bailer and stab back an well with same. 09:30 - 09:45 025 TEST_ EQIP GMPRUN Pressure test lubricator to 2000 psi. 09:45 - 10:15 0.50 RUNPU SLIK GMPRUN RIH 1" DD bailer and bail from 4437 -4490'. Fell through to 4450'. Work bailer down to 4451'. POH 10:15 - 10130 0.25 RURD SLIK. GMPRUN PU 1:25" braided line brush and stab on well. 11!27!2007 5:56'i08PM • • Marathon Oil Company Page ~ of ~ ®perations Summary Report Lega! Well Name: KENAI UNIT 43-6A Common Well Name: KENAI UNIT 43-6A Spud Date: 1/1/1968 Event Name: WORKOVEft Start: 7/5/2007 End: Contractor Name: Rig Release: Group: Rig Name:: Rig Number: d Phase Description of Operations Date ~`rom - To Hours Code C o 9/8/2007 10:30 -10:45 0.25 TEST_ EQIP CMPRUN Pressure test lubricator to 2000 psi. 10:45 -11:10 0.42 RUNPU SLIK CMPRUN RIH and brush nipple down to 4448'. POH 11:10 - 11:20 0.17 RURD_ SLIK CMPRUN PU 1.25" x-line running tool and XN plug body. Stab on well 11:20 -11:25 0.08 TEST_. EQIP CMPRUN Pressure test lubricator to 2000 psi. 11::25 - 11:45 0.33 RUNPU SLIK CMPRUN RIH plug body and set at 4434`, POH. 11:45 -11;55 0.17 RURD_ SLIK. CMPRUN PU 1.25"JDC and prong and stab on well.' 11:55 -12c05 0.17 TEST_ EQIP CMPRUN Pressure. test lubricator to 2000 psi. 12:05 - 12:30 0.42 RUNPU SLIK CMPRUN RIH prong and set at 4435'. POH 1.2:30 - 13:30 7.00 RUNPU. 5L1K CMPRUN Attempt to bleed 2-318" CT. No success. 13:30 - 14:30 1.00 RURD_ SLIK CMPRUN RD and release Slickline: 9/9/2007 06:30 - 08:00 1.50 SAFETY MTG_ CMPRUN Arrive on location, sign in, obtain work permit and Held PJSM.: Wait 45 minutes for crane operator to arrive. 08:00 - 09:30 1.50 RURD_ COIL CMPRUN PU Coil Tubing Injector, MU GS on bottom of BHA to pick up the 5" hanger with coil. Pull test connection to 19, 000 lbs. PT shell to 900 psig. Good shell test. Open swab. and run in hole. WHP = 43 psig. 09:30 -10:00 0.50 WORK COIL CMPRUN Tag top of fish @ 8' CTM. PU and RIH with coil to iateh fish., sat dawn 4000 Ibs, would not latch fish. POOH with coil. Shut swab, blow down pressure to 0 psig above swab. Break Bowen connection below injector. 10:00 - 1'1 :0p 1.00 RUNPU COIL. CMPRUN Lower injector to ground level. Check 2.3/8" GS and bend coil to change. memory in coil. Go to well with injector., 11:00- 17't30 0.50 RUNPU COIL CMPRUN Open swab valve. RIH with GS to latch top of hanger. Could not locate hanger. Close in swab valve with 2000 Ibs dawn on GS, located top of fish. PUH 40001bs Have fish. 11:30 - 12:00 0.50. RUNPU COIL CMPRUN PU 8000 Ibs, Vetco on location to upland hanger: `Total string weight 14, 000 Ibs. PU coil 8' with coil, close pipe rams. Blow down tubing, Tubing pressure at 43 psi.. Tubing. would. not blow down. Open pipe rams PU 13', set pipe rams, blew down tubing. Tubing pressure stayed at 43 psig. Checked all 2 X 2 valves above and below BOP to verify no leaking valves. 12:00 - 12:10 0.17 RUNPU COIL CMPRUN RIH with 2 3/8" tubing and. land tubing hanger. Vetco repined hanger: and PT hanger seals to 4000 psig. Good test. Coil pumped 12 bbls fluid to release GS. Note_ Appears thatwehave developed a hole in the 2 3/$" tubtnc below 12:10 - 12:25 0.25 RUNPU COIL CMPRUN Released GS, PU hole. Closed swab valve, blew clown tubing.. PU injector go to ground with injector and pulled GS off of BHA. Go back to well. Cooled down N2 to displace coil reel fluid to tank. Start pumping N2 at min rate. Fluid to tank.. 12:25 - 1.3:00 0.58 RUNPU COIL CMPRUN Displaced fuid off of coil reel. Shut down pumping. Blow down N2 unit to flow back tank.. 13:00 - 14:00 1.00 RURD_ COIL CMPRUN N2 blown down., flow lines down to 0 psig. Shut down N2 pumping. 14:00 - 14:40 0.67 RURD_ COIL CMPRUN Lay down injector, cuf welded connection on coil tubing off ofcoil. Secured well tree capon well Finish. rigging down coil unit and eQuipment: 15:10 - 17>30 2.33 RURD_ COIL CMPRUN Well secured, clean up around"well. BJ coil tech .left leases 9!1012007 08:00 - t)9:00 1.00 SAFETY MTG~ CMPRUN Arrive on location, sign in, obtain work permit and Held PJSM. 08:00 - 09:30 9.50 RURD SLIK CMPRUN MIRU wire line unit, pu lubricator. MU 1"tool sting with 1 1/4" JDC. PT lubricator to 1000 psig.: Good test. WHP = 43 psig. 09:30 - 10:00 0.50 WORK SLIK CMPRUN Open well, RIH to top of prong at 4453' KBD;. Wgrk tool string. POOH with tools. OOH. Recovered prong. Nrinrecr: ~vznluui 5:ob:uarM • Marathon Oil Company ~peration~ 5urnr~ary Report Legal. Well Name: KENAI UNIT 43-6A Common UVell Name: KENAI UNIT 43-6A Event Name: WORKOVER Contractor Name: Rig Name: Date From - To) Hours I Code ~ S 9/10/2007 ~ 10:00 - 10:20 ~ 0.33 ~ WORK~SLIK Start: 7/5!2007 Rig Release: Rig Number; Rage5of5 Spud Date: 1 /1 /1968 End: Group; Phase Description of Operations CMPRUN. MU 1.25" GS. PU tools and go to well. PT lubrcaior with fluid to 1000 psi. Good test. Open well RIH with GS to top of plug at 4453' KBD. Work tool string POOH. OOH no plug. 10:20 - 11;00 ~ 0.67 WORK~SLIK ~ CMPRUN ~ MU 1.25" GS with steel pin. PU tools and go to well.. PT lubricator with fluid to 1000 psi. Good test. Open. well RIH. with GS#o top of plug at 4453' KBD. Work,tool string POOH, OOH, retrieved plug. 11:OQ - 12:00 1.00 WORK SLIK. CMPRUN RD wire tine unit.. 12:00 - 12:30 0.50 RURD SLIK CMPRUN Well secured, clean up around well.. Move to CLU. 2/2007 07:30 - 08:15 0.75 SAFETY MTG_ CMPRUN Arrive on location, sign. in, obtain work permit and Held PJSM. 08:15- 12:30. 4.25 RURD_ SLIK CMPRUN MIRU wireline unit. 2 block device on crane is malfunctioning. Attempt to fix. Call Expro for crane. 12:30 -13:30 1.00 RURD. SLIK CMPRUN Continue RU. PU lubricator and 1"tool string with 1" bailer. Stab on weU. :1.3:30 -13:50 0.33 TEST_ EQIP CMPRUN PT lubricator to 500 prig. Good test. WHP = 43 psig. 93:50 - 15:00 1..17 RUNPU SLIK CMPRUN RIH Bailee Tag art 4443'. Bailer stuck. Work tools and jar free. POH. 15:00 - 15x20 0.33 RURD_ SLIK CMPRUN. LD Bailer and PU 1.25" X Plug body on running tool. 15:20 - 15:25 . 0.08 TEST_ EQIP CMPRUN Test lubricator. 15:25.-95:50 0.42 RUNPU SLIK CMPRUN RIH 1.25" Plug and setat4434' WLMD. POH. 1.5:50 - 16:00 0.17 RURD.. SLIK CMPRUN PU 1.25" X Plug equalizing prong on running tool. 1:6:00 -16:05 0.08 TEST_ . EQIP CMPRUN Test tubrirztoc 16:05 - 16:25 0.33 RUNPU SLIK CMPRUN RIH 1.25" Prong and set at 4434' WLMD. POH. 16:25>17:30 1.08 RURD^ SLIK CMPRUN RD slickline. Weil secured, clean up around'well. Leave location 3/2007 07:00 -:08:00 1.00 SAFETY MTG CMPRUN Arrive on location, sign in, obtain work permit and Hetd PJSM. 08:00 - 08:45 0.75 RURD_ ELEC CMPRUN MIRU ~xpro E-line unit. PU 1.25" PLT string. 08:45 - 08:55 0.17 TEST_ EQIP CMPRUN Test lubricator to 500 psi. 08:55 - 11`:30 2.58 LOG CSG_ CMPRUN Log down looking for hole in 2-318" CT. Tag at 4436' E-line correlated. with GR, Log with well leaking through packoff end locate hole: at 1-2' 1:1.30 - 12:20 0.83 RUNPU ELEC CMPRUN POH. 12:20 - 13:00 0.67 RURD ELEC CMPRUN RD and move to KBU 42-7. 07:00 - 07:30 0.50 SAFETY MTG_ IN'1 EVL over from KDU 4 RD, establish work permit and Held PJSM. 07:30 - 08;45 1.25 RURD_ SLIK IN1EVl_ MIRU Pollard wire line unit. MU 1.00" tool string wit pangs, oil. jars: and 1,5" GS to pull the prong. 08:45 - 10:20 1.58 WORK SLIK INIEVL Test lubricator to 500 psi. Good test. 10:20 - 11.:00 0.67 WORK SLIK INIEVL RIH with 1..25.." GS to 4459' KBD. Latch prong. 2 spang tacks. POOH:.. 11:00 -11;30 0.50 WORK SLIK INIEVL OOH, retrieved prong. MU 1.25" GS. 11:30 -12:00 0.50 WORK SLIK. IN1EVL PT lubricator to 500 psig, good test.. Open well. RIH to 4459' KBD. Latch. plug. POOH.: 12:00 - 12;20 0.33 RURD SLIK IN1 EVL OOH verified plug retrieved. RD wire line :unit. Move to nextwell Pdnted• `I t/77/~(1117 ~1f~1fŒ (ill~ ~~~~[K(~ AI,A.SIiA OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kevin Skiba Production Technician Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 Re: Kenai Gas Field, Sterling Pool 4, Kenai Unit 43-:-G.t\NNED AUG 1 41007 Sundry Number: 307-216 Sf..,; '" ~ , \\o~-oc> Dear Mr. Skiba: Enclosed is the Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Receipt of Marathon's response to the Commission's letter of July 26, 2007 is acknowledged. The issues identified in that letter have been satisfied, however the Commission still reserves the option to pursue enforcement actions. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd. rj~:y, foll?wing the date of this letter, or the next workin da~ if. the 4r~:f.(~1 Çf-'iý yrtllls 'éff). ~~, holIday or weekend. A Person may not appeal a 0 mISSIon Q:er·l¡>..lJ.1.l::i. (t" ;0.' "'\~:'"''d''' . Y(un 0 oUpet'l r Court unless rehearing has been reques d. Si ~~, ~ '{Q\'") o..~<:.o~c....~ \ ~~s~\oi ~CA~\è ~~ o.."'-S-~ ~b~\\~ ~~~~.. IS.~\.sc~( S~fè \J.. \\~~ù""<è..S~ ~~ ö.~\~'\~~ \ ~ ~~~ <-c""~"'.\-\'\.~ ~~ '" ~ O-~\'~-.;)~' Q' ~'^'~ ,-"vt\~ C- eo ""-'>^<i "..}.. 1;:"",,- ~ DATED this!l day of August, 2007 Enc!. cc: Kevin Skiba, MOC Kenai John Barnes, MaC Anchorage Alan Birnbaum, Alaska Department of Law . . Marathon Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 August7,2007 'T" "\ '? c..O\>ì S\..c-..J\"J bÇ: ~ú:\x~ O-~-\-~ \,~~(\ ()~~ f'G.\ "\ q-D ~~ ",it}, lj- " ". , ' iI.,.." <¡{I , Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 7 Z007 Reference: 10-403 Sundry Notice, Revised 08/07/2007 Field: Kenai Gas Field, Pad 41-7 Well: Kenai Unit 43-6A Dear Mr. Maunder: We propose to run a 2 3/8" by 1 :X" concentric coil tubing string in KBU #43-6A. We anticipate improving the condition of the well by pumping water off the formation and v increase production. Please find a 10-403, operations procedure, wellbore diagram, and proposed wellbore diagram attached. Please send any sundries or pertinent documentation to Kevin Skiba at the above address listed. If you have any questions or need further information please call me at (907) 398-1362. Si~. Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File DMD KJS F Type of Request: i rft .'07 STATE OF ALASKA ~l~ ALA _ OIL AND GAS CONSERVATION COM.IÕ~ APPLICATION FOR SUNDRY APPROV~þ~ 20 MC 25.280 . . .. ."j~, Abandon 0 Suspend 0' Operational shutdown 0 Perforate 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 C ¡Jimn!; ¡¡ion Other[]1 CCT String I I Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2, Operator Name: 4, Current Well Class: 5, Permit to Drill Number: Marathon Oil Company Development [] Exploratory 0 168-051 /' 3, Address: Stratigraphic 0 Service 0 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20123-00-00 ,- 7, If perforating, closest approach in pool(s) opened by this operation to nearest 8, Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No [] Kenai Unit 43-6A /' 9, Property Designation: ¡:¿¡:;; t.êA~ A. DZ~/~~;O, KB Elevation (ft): 11, Field/Pool(s): S-\-fëA~v-.~?w \ "" ./ 217'~ of NW CorMr ~. 7, T 4N, R11 $1',07 12' Kenai Gas Fiel , Pad 41-7 12, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5300' / 4565' /' 4786' 4139' 4519' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1250' 10-3/4" 1250' 1195' 3130 psi 1580 psi Intermediate Production 5289' 7-5/8" 5289' 4555' 4140 psi 2890 psi Liner . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4407'-4534' 3813'-3922' N/A N/A NIA Packers and SSSV Type: Weatherford SLPL Isolation Packer and Packers and SSSV MD (ft): 4388' and 4010' Weatherford SLPL Isolation Packer 13, Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: 0 0 D 0 , 0 Detailed Operations Program BOP Sketch Exploratory Development Service 15, Estimated Date for 16, Well Status after proposed work: Commencing Operations: 22-Jul-07 Oil D 0 /' Plugged 0 Abandoned D Gas 17, Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Com mission Representative: 18, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Kevin Skiba (907) 283-1371 Printed Name A ~ennis Donovan Title Production Engineer Signature j\WJ~ _on_ Phone (907) 283-1333 Date 18-Jun-07 . ~ ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3O-¡-~\v Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~ Ç><;', c.. '\ \S ~ X' ~.., ~ c,. <,. r;¿ \tj..,,-w..."J / RBDMS 8fl AUG 1 ð 2007 Subsequent Form Required: '--\CJ~ í1IA9J \ APPROVED BY I Approved by: ISSIONER THE COMMISSION -b f?,~.07 ~ ð'¡i;¡b-rsubmit in Duplicate Date: ~ -'i-ðr Form 10-403 Revised 06/2006 rID ~(£mAf . . (fl!) MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 43-6A 2007 CCT String Hangoff Procedure ,/ Notes: · This procedure covers work to install a 2-3/8" and 1.75" 00 coil tubing velocity strings to alleviate liquid loading using the Concentric Coil String Method. · Contact Vetco prior to MIRU to verify maximum hanger head 10 & mandrel 00 measurements, BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift 10 of individual connections, · G and G Machine will build a 2-3/8" X 1-3/4" BHA to Accept a Standing Valve that is replaceable via slickline through the 1-3/4" coil tubing, 1, Tag Fill and Bail Sand If Needed. MIRU Expro Wireline. Hold PJSM, Roundtrip a 3,75" 00 gauge ring with junk basket to tag top of fill in the 7-5/8" production liner (A Patch @ 4010' is 5-1/2"). RIH to tag fill (last tag on fill was with BJ Concentric Coil Tubing String @ 4509' CTD(approx 4519' KB)). Bail with Slickline if needed, Dump Bail Cement on 3-3/8" Inflatable Bridge Plug set at 4519' KB 2. Install Concentric Coil Tubing Head. Vetco to install 4" Cameron Type-H BPV and close primary master. Bleed off pressure and check for flow. Remove secondary master and install new Vetco CCT Multibowl Head with 2-1/16" 5M side outlets, Install 2-1/16" gate valve and SSV to side outlet on coil tubing head, Reinstall and test secondary master and swab valve, Make final measurements to install flowlines to CT Head inlet and outlet. Pull BPV, 3, Make flowline modifications for concentric coil tubing string. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline, Plumb in and test source gas flowline and 2-3/8" by 1-3/4" annulus flowline 4, MIRU MOC flow back equipment including open-top flowback tank, choke skid, gas buster, and flow back iron, MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank, Load fluid supply tank with 6% KCI and heat as necessary, Deliver diesel fuel manlift and two light plants, Remove well house and lock out electrical connections, Installation of 2-3/8" CT 5, MIRU BJ coiled tubing unit with 5519' of 2-3/8" coiled tubing (QTI #34209). Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6, Nipple up BJ CT wellhead assembly (WHA). WHA to include 4-1/8" - SM X 4-1/16" - 10M DSA, 4- 1/16" -10M X S' Flanged Riser, 4-1/16" -10M flow cross and 4-1/16" -10M Dual-Combi BOP (dressed for 2-3/8" CT), Function test BOP, Stab 2-3/8" CT into injector. Install G&G Concentric Coil Tubing BHA and pull test to 15,000 Ibs, Nipple up injector to WHA. . . Page 2 of3 7, Pressure test surface lines and CT equipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi), Pump fluid to load CT, Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi), Pressure test BOP rams (200/4500 psi), Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank, 8, MU CT BHA. Nipple injector off WHA. PU 10' of 4-1/16" CQ lubricator. MU velocity string BHA to end of CT. 9, Nipple UP iniector to WHA. Pressure test WHA using CT kill line (200/1500 psi), Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse, This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 10. RIH with 2-3/8" coil tubing velocitv string and BHA with well flowing to sales up annulus (if desired), 11. Cut coil tubing. PUH to span WHA for final landing depth of +/-4,475' Set CT in BOP tubing/slip rams. Lock tubing/slip rams, Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank, Nipple injector off of WHA. Walk injector up CT, Install C plate above BOP and 2-3/8"" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly, 12, MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger to hanging coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 2-3/8" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate, 13. Latch GS spear to Vetco mandrel after PU injector. Remove 2-3/8" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP, Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs, Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams, Open BOP tubing/slip rams, 14. RIH and land Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures_ Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15, Release GS Running Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. Installation of 1.75" CT 16. MIRU BJ coiled tubing unit with 5669' of 1,75" coiled tubing (QTI #34208). MU CT 1.75" CT BHA. Nipple injector off WHA. PU 10' of 4-1/16" CQ lubricator, MU velocity string BHA to end of CT. 17. RIH with 1.75" coil tubing velocitv string and BHA with well flowing to sales up Casing by 2-3/8" annulus (if desired), 18, Cut coil tubing. PUH to span WHA for final landing depth of +/-4,465' (10' above 2-3/8" CT Setting Depth), Use caution when nearing depth to avoid running in to the 2-3/8" BHA Watch weight indicator closely and stop immediately if pipe weight begins to drop off. Set CT in BOP tubing/slip rams, Lock tubing/slip rams, Slack off injector chain traction and roll chains to verify slips are set. Release KU 43-6A CCT String Hangoff Procedure DMD - 6/19/2007 10:19:27 AM . . Page 3 on WHP above tubing rams to the flowback tank, Nipple injector off of WHA. Walk injector up CT, Install C plate above BOP and 1,75" polish rod clamp on CT, Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly, 19, MU Vet co Coil TubinQ HanQer and Baker GS RunninQ Tool. Swing Injector and lubricator away from WH, Vetco to connect VGCT Coil Tubing Hanger (4" Nom C/W 3" Baker Fishneck with 2-3/8" 8rd Box and 2" BPV) to hang coil tubing with coil grapple, While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 1.75" CT connector. Pull test CT connector (25,000 Ibs,) using 1,125" 10SA box X 1-1/2" MT pin crossover and 1-1/2" MT box pull plate, Tool string will consist of 1-3/4" slim line dimple-on, 1-3/4" DF check valve, 1,125' 10SA box X 1- 1/2" MT pin X-over and 3" GS spear, PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger, 20, Latch GS spear to Vetco mandrel after PU injector. Remove 1,75" polish rod clamp and C-plate from top of BOP, Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs, Slack off weight to CT string weight. Equalize WHP across tubing rams, Unlock tubing/slip rams, Open BOP tubing/slip rams. 21, RIH and land Vet co CT hanQer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures, Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws, 22. Release 3" GS RunninQ Tool. Sit down weight on Hanger, Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear, Stop pumping when spear is unlatched and above mandrel. 23, PUrQe KCL water from CT remaininQ on reel trailer with nitroQen. Allow N2 to vent to flowback tank. 24. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors, 25, MIRU Slickline Unit and Pressure Test to 1.5 Times WH Pressure. RIH to nipple landing depth of 1- 3/4" CT string and Pull blanking plug, POOH. MU string to run out the end of the 1-3/4" CT and pull the blanking plug in the 2-3/8" CT (nipple landing depth of 2-3/8"), RIH and pull plug. MU tool string for standing valve and RIH to 2-3/8" landing depth and set standing valve. RDMO Slickline 26, Complete Wellhead Modifications for Concentric. Complete surface work for the completion of Concentric Coil Tubing Modification. CONTACTS Dennis Donovan: 907 -283-1333 (w) 907-398-1362 (cell) David Martens: 713-296-3302 (w) 832-472-6249(cell) Lyndon Ibele: 907 -565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 EmerQencv Dial 911 KU 43-6A CCT String Hangoff Procedure DMD - 6/19/2007 10:19:27 AM KB~Gl: 12,00' DF-Gl: Location 211' S & 4279' E of NW Corner SEC 7, T4N, R11W API#50-133-20123 4106'-4107' (Sqzd) A 8 4173'-4177' (Sqzd 4/(0) A-10 4270'-4294' (11/1/70) A-11 4338'-4370' (11/1/70) Existing Perfs B-1 4407'-4457' (50') B-2 4521'-4534' (13')(6 spf, 5/1/(0) Casing 7-5/8", 26.4#, J-55, LTC @ 0'-1140' 7-5/8", 33.7#, N-8(), LTC @ 1140'-5289' Cmt w/ 1500 sks of Class G 10-3/4",40.5#, J-SS, Armco Seal Lock Casing @ 1250' Cmt w/1575 sks of Class G -Wêatherford SLPU Isolation PKR @ 4010' -5-1/2", is,S ppf, K-55 LTC scab liner assemby 4010'-4388' -Weatherford SLPL Isolation PKR @ 4388' 3-3/8" @4519' KB. 20 Dee 2004 Tag Fill: 4562' KB Fish: Halliburton EZSV @ 4703' (4/00) Fish: Baker "K" bridge plug @ 4786' Fill: Howco EZ CIBP @ 48()()' capped wi 14' emt Fish: Howco EZ bridge plug Fill @ 5217' ELM Abandoned Perfs: 8-54930'-4956' location 211' S & 4279' E of NW Comer SEC 7, T4N, R11W API#5()-133-2()123 Isolated Perfs 4106'-410T A - 8 4173'-4171' (Sqzd 4100) A-10 4270'-4294' (11/1/70) A-11 4338'-4370' (11/1/70) B-1 4401'-4457' (50') B-2 4521'-4534' (13')(6 spf, 5/1/(0) Casinç¡ 7-5/8",26,4#, J-55, LTC @O'-1140' 7-5/8",33,7#, N-80, LTC @ 1140'-5289' Cmtwl prepped wi : of 5-1/2", 14,0 ppf, K-5S, STC guide on pump "W SPV profile l TC lift threads 10-3/4",40,5#, J-55, Armco Seal Lock Casing @ 1250' Cmt wI 1575 sks of Class G -Weatherford SLPU Isolation PKR @ 4010' -5-1/2", 15.5 ppf, K-55 LTC scab liner assemby 4010'-4388' -Weatherford SLPL Isolation PKR @ 4388' 3-3/8" @ 4519' KB, 20 Dee 2004 Tag Fill: 4562' KB Fish: Halliburton EZSV @ 4703' (4/00) Fish: Baker "K" bridge plug @ 4786' Fill: Howco EZ CIBP @ 4800' capped wi 14' cmt Howco EZ bridge plug Fill @ 5217' ELM (1 8-54930'·4956' . . Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 August 7, 2007 ~~~~r~~~orman ".I:.+'\~ '''''l ~SS<i. S.S~~\ \-\--.0.:, ~ro. \~~ AOGCC \-0..,-> <:CN\.ß\\~ ~ I .\-4_, ,çç..~,~~\f".;.~~ 333 West ¡th Ave r ,'" -.. y Suite 100 O<T-O~' "'I~"" \<.:t..~'\.l.+-o.~~~"'::.C:I"",ç Anchorage,AK 99501 ~~\c -c-..~ ~~<t ~~~~~~~~\-~ ~<::i\>J\I"\ Re: Kenai Gas Field, Beluga Gas Pool, Kenai Unit 43-6A .\~ '"'t(ë>c.. \ '<.. \\~:X \~~-\-~\--,~~~~ ~\\ \ 'oç Sundry Number: 307-216 <;~\\\t:0 '\.c--..~~ <:.~~~(L... '\~~ ~<t~ ~ Dear Mr. Norman: "O+\-.L,~~~,- '">~,>....;)I:::.,,,> ~ I \.~\.""> ~ f.. ~ ~ T~c:.c~~"~C>-.~Q~~~ \ o~ ~~~~J Marathon Oil Company has received your letter dated July 26,2007 which specifies reasons why the ""::.0')- ';)-\ 0 AOGCC denied our sundry request to install a concentric coiled tubing velocity string in the KU #43-6A well. The following addresses the concerns noted in your letter: 1r2-4^fv\. 1 ) Form 403 should not be used to transmit we" work reportinq. It is understood that Form 404 is <61 required for well work reporting. The operational summary that was attached to Sundry Number 1'\ 307-216 was information that should not have been submitted to the AOGCC. Further, it is our understanding of the Alaska statutes that the disclosed activity did not require a Form 10-403 and therefore no form 10-404 is required. The operational summary should simply be disregarded as supplemental information that was unnecessary. Please excuse any confusion that may have resulted from submitting more information than was required, 2) Please confirm that the Commission was notifed of the BOP test performed Mav 16. 2007...At your request, Marathon has attached copies of the emaH notification and documentation sent to Jim Regg for the coiled tubing BOP test performed on May 15, 2007 at this well. Please be aware that Marathon's daily well work reporting format standard encompasses the work conducted for the prior 24 hours up to 0600 hrs on the report date. Therefore, the BOP test date that you refer to as being performed on May 16, 2007 is actually for the previous day's work (i.e. 0600 hrs May 15 though 0600 hrs May 16). 3) Confidentialitv reauest: A statement appears in the header of the procedure attached to the sundry application stating that "All data relative to the testing of this well is confidential". This statement is not directed to the AOGCC, We understand the AOGCC statutes regarding confidentiality and we are not asking for any additional consideration. Rather, it has been our common practice to put a confidentiality statement on procedures because they are copied to our contractors who are performing the work. A copy of an emaH from Marathon's Kevin Skiba to Tom Maunder on July 17, 2007 attempting to clarify this issue has been attached to this document. Additionally, upon receipt of your July 26 letter, we discovered and voluntarily disclosed that work activities had commenced on this well prior to receiving sundry approval from the AOGCC, I called Tom Maunder and disclosed this immediately upon discovery on July 31, 2007. No work has been performed on this well since that date, With this letter, we have addressed the AOGCC's original concerns and we request approval of Sundry Number 307-216 so that work may proceed, It is understood that Marathon owes the AOGCC additional dialog relative to actions taken to ensure full compliance in the future. I have discussed many of these actions with Tom Maunder, and anticipate scheduling a meeting with Tom for additional discussion. Marathon respectfully requests that the AOGCC accept the re-submitted Sundry Number 307-216, and expedite its approval. Please send approvals to Marathon Oil Company, c/o Kevin Skiba, PO Box 1949, Kenai, AK, 99611-1949, If you would like any other information or have additional questions, please contact me at 907-565-3042. , ~ . . Sincerely, Lyndo Ibele, PE Production Coordinator Enclosures: 05/14/07 Email with BOP Test Notification (Wayne Cissell to James Regg) 5/23107 Email submittal for BOP Test Form (Wayne Cissell to James Regg), 5/15/07 BOP Test Form (as attached to the 5/23/07 email) 7/17/07Confidentiality Email (Kevin Skiba to Tom Maunder) Sundry Application, 8/07/07 revision, cc: Houston Well File Kenai Well File KDW . . . . . From: Cissell, Wayne E. Sent: Monday, May 14, 20072:34 PM To: James Regg Cc: Cissell, Wayne E.; Ibele, Lyndon; Walsh, Ken Subject: BOP test on well KU 436A Per phone conversation today: Marathon Oil will be testing the BOP on well KU 436A with BJ Coil Tech coil tubing unit tomorrow morning. We will send a copy of the completed paper work, You have Waved the witnessing and Marathon will continue to give notification 24 hours prior to the BOP test. After hour and weekend phone number is 907-659-2714. Thanks, Wayne Marathon Oil Company Northern Business Unit AAT Well Work Over Supervisor W ecissell@Marathonoil.com 907-283-1308. 394-1324 u.. . . . . . From: Sent: To: Cc: Subject: Cissell, Wayne E. Wednesday, May 23,20079:43 AM James Regg Cissell, Wayne E,; Sulley, Michael; Mullin, Mickey; Walsh, Ken BOP test form for BC-11 and KU 436a Attachments: BJ Coil Tech J195_BC_11_5-18-07.xls; BJ Coil Tech J195_ku436_11-10- 07.xls BJ Coil Tech BJ Coil Tech 19S_BC_ll-_S-18-.19S_ku436-_11-10.. Marathon Oil Company Northern Business Unit AA T Well Work Over Supervisor Wecis sell@Marathonoil.com 907-283-1308.394-1324 .' . , ' > . . 5/18/2007 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim reqq@admin,state.ak,us aogcc prudhoe bay@admin.state,ak.us bob fleckenstein@admin,state,ak,us Contractor: BJ Coil Tech Rig No.: J195 DATE: 5/15/07 Rig Rep.: Matt Summers Rig Phone: 283-1308 Rig Fax: Operator: Marathon Oil Company Op. Phone: 394-1324 Op. Fax: Rep.: Wayne Cissell E-Mail wecissell@marathonoil.com Well Name: KU43-6A PTD # 68-051-0 Meridian: NIA Location: Section: NIA Township: NIA Range: NIA Operation: Drlg: Workover: yes Explor.: Test: Initial: X Weekly: yes Other: Test Pressure: Rams: 3000 psi Annular: N/A Valves: 3000 psi MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen,: P Well Sign P Upper Kelly NA Housekeeping: P Dr!. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type NA Standing Order Posted P Inside BOP NA BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visual Alarm Stripper 1 41/16 TOT P Trip Tank P NA Annular Preventer NA Pit Level Indicators P NA #1 Rams blinds 41/16 TOT P Flow Indicator P NA #2 Rams cutters 41/16 TOT P Meth Gas Detector NA NA #3 Rams 2" slips 41/16 TOT P H2S Gas Detector NA NA #4 Rams NA #5 Rams NA Quantity Test Result Choke Ln, Valves NA Inside Reel valves 1 P HCR Valves 2X2 plug valve Manual P Kill Line Valves 1 P ACCUMULATOR SYSTEM: Check Valve 1 P TimelPressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2500 P Quantity Test Result 200 psi Attained 5 sec P No, Valves 2 P Full Pressure Attained 30 sec P Manual Chokes 2 P Blind Switch Covers: All stations Yes Hydraulic Chokes NA Nitgn, Bottles (avg): 2 @ 1500psi Test Results Number of Failures: º Test Time: 1 hr Hours Components tested Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: iim regq@admin,state,ak,us Remarks: BJ Coil Tech unit #J-158, Compensator valve was changed in November 2005, Upgraded system accumulatro system to 2800 psi for BOP. Accumulators, stripper was changed to a 9/16" TOT 10K, BOP is a 10K TOT combination. Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X NO c - Oper.lRig Waived By Jim Regg c - Database Date 5/14/07 Time 10:00 AM c - Trip Rpt File Witness Wayne Cissell c - Inspecto : Test start 10:30 Finish 1230 Coil Tubing BFL 5/15/2007 ,t, . . . 'I' ';' From: Skiba, Kevin J. Sent: Tuesday, July 17, 2007 II: 15 AM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Donovan Jr, Dennis M.; Walsh, Ken; Cissell, Wayne E.; Mullin, Mickey; Skiba, Kevin J. Subject: Well Infonnation Confidentiality Tom, Confidentiality statements are standard for many Marathon documents. Marathon is not requesting additional confidentiality above what is applicable. The statement just verbalizes Marathon's confidentiality expectations. Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 17, 2007 8:54 AM To: Donovan Jr, Dennis M,; Skiba, Kevin J. Subject: KBU 41-7X Dennis and Kevin, I am reviewing the sundry submitted to plug the Beluga perfs and move up to the Sterling. At the top of the procedure page it states that "All data relative to testing of this well is confidential", I have seen this statement on some other procedures as well. Confidentiality of well information generally applies for 25 months after the original completion of a well. There has lately been some statute changes that removes the 25 month period for wells in established fields, Is it indeed Marathon's intent to have this information confidential? Confidential information is covered in 20 MC 25.537. I look forward to your reply. Tom Maunder, PE AOGCC . ~ ~ ffi1 ~ Œ (ID ~ ffi1 ~ ffi1 ~ ~ ffi1 . AI.A.SIiA. OIL AlQ) GAS CONSERVA.TION COMltlISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED Dennis Donovan Production Engineer Marathon Oil Company PO Box 1949 Kenai, AI( 99611-1949 t)c;ANNED JUL 3 1 2007 Re: Kenai Gas Field, Sterling Pool 4, Kenai Unit 43-6A Sundty Number: 307-216 ~~'b~DS'1 Dear Mr. Donovan: Enclosed is the Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. No work will be approved for this well until the deficiencies noted below are corrected. Form. 403 (Application for Sundry Approvals) should not be used to transmit wen work reporting. Your attachment should be resubmitted using Form. 404 (Report of Sundry Well Operations). The reported well activity involved BOP installation and testing. Please contlrm that the Commission was notified of the BOP test peñormed May 16, 2007 as required by 20 AAC 25.286 (e)(7). On page 1 of your proposed well program, it is noted that all data relative to testing of this well is confidential. Information regarding this wen was released to the pubUc domain in October 1970. If confidential treatment of new information is desired, Marathon must make an appUcation according to 20 AAC 25.537 (b). Your response to the BOP test notification must be submitted not later than 15 days after receipt of this letter. The Commission reserves the right to pursue enforcement actions regarding these matters. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a . . DATED this ~ day of July, 2007 July 26, 2007 Sundry: 307-216 KU 43-ôA ission decision to Superior . Page 2 holiday or weekend. A person may not appeal a Court unless rehearing has been requested. . er Encl. cc: Kevin Skiba, MOC Kenai John Barnes, MOC Anchorage Alan Birnbaum, Alaska Department of Law . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 Marathon Oil Company June 18, 2007 RECEIVED Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 JUN 2 5 2007 ,Alaska Oil & Gas Cons. Cammission Anchorage Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Unit 43-6A Dear Mr. Maunder: We propose to run a 2 3/8" by 1 %" concentric coil tubing string in KBU #43-6A. We anticipate improving the condition of the well by pumping water off the formation and increase production. Please find a 10-403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. SinCereIY,~~ ~. Dennis ~ J Production Engineer Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic Operation Summary cc: AOGCC Houston Well File Kenai Well File DMD KJS · STATE OF ALASKA aP~? RECEIVED ALASKA OIL AND GAS CONSERVATION COM~ION JUN 2 5 2007 APPLICATION F~O~~~5~~RY APPROVAL~'aSka Oil & Ga Cons. Carn 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiv C orage Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extensi 0 CCT String Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspende ell 0 2. Operator Name: 4. Current Well Class: 5. Per . to Drill Number: Marathon Oil Com an Development 0 Exploratory 0 168-051 - 3. Address: Stratigraphic 0 Service 0 PO Box 1949, Kenai Alaska, 99611 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Yes 0 No 0 9. Property Designation: 22k1 ~ II....~? 10. KB Elevation (ft): 11. Field/Po 217'S & 4279' E of NW Corner Sec. 7, T 4N, R11 W 12' 12. PRESENT WELL CONDITION SU Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Dep 5300' 4565' ~ 4786' 139' 50-133-20123-00-00 ~ Kenai Unit 43-6A ~C-\\~, ?oo \ "'\ Kenai Gas Field, Pad 41-7 Plugs (measured): 4519' Junk (measured): N/A Collapse Casing Structural Conductor Surface Intermediate Production Liner Length Size MD Burst 1250' 10-3/4" 3130 psi 1580 psi 5289' 7-5/8" 4140 psi 2890 psi Perforation Depth MD (ft): 4407'-4534' Perforation Depth TVD (ft): 3813'-3922' N/A Tubing MD (ft): N/A 4388' and 4010' Packers and SSSV Type: Weatherford SLPL Isolatio Weatherford SLPL Isolation Packer 13. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 15. Estimated Date for o Service 0 Commencing Operations: 17. Verbal Approval: Com mission Representative: 18. I hereby certify that the foregoing is true an correct to the best of my knowledge. Printed Name Title Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact Kevin Skiba (907) 283-1371 Production Engineer 18-Jun-07 Signature Phone (907) 283-1333 Date COMMISSION USE ONLY Conditions of approval: mmission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 er-\SCJ\> \<:,\-c..o;. f\<:>......:J Location Clearance 0 Subsequen orm Required: l.\CJ~ RBDMS BFL JUL 3 02D07 Approved by: .COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 Revised 06/2006 0 RIG I N A L Submit in DUPli~ ~o/ . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KU 43-6A 2007 CCT String Hangoff Procedure ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: · This procedure covers work to install a 2-3/8" and 1.75" 00 coil tubing velocity strings to alleviate liquid loading using the Concentric Coil String Method. · Contact Vetco prior to MIRU to verify maximum hanger head 10 & mandrel 00 measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift 10 of individual connections. · G and G Machine will build a 2-3/8" X 1-3/4" BHA to Accept a Standing Valve that is replaceable via slickline through the 1-3/4" coil tubing. 1. Taa Fill and Bail Sand If Needed. MIRU Expro Wireline. Hold PJSM. Roundtrip a 3.75" 00 gauge ring with junk basket to tag top of fill in the 7-5/8" production liner (A Patch @ 4010' is 5-1/2"). RI H to tag fill (last tag on fill was with BJ Concentric Coil Tubing String @ 4509' CTD(approx 4519' KB». Bail with Slickline if needed. Dump Bail Cement on 3-3/8" Inflatable Bridge Plug set at 4519' KB 2. Install Concentric Coil Tubina Head. Vetco to install 4" Cameron Type-H BPV and close primary master. Bleed off pressure and check for flow. Remove secondary master and install new Vetco CCT Multibowl Head with 2-1/16" 5M side outlets. Install 2-1/16" gate valve and SSV to side outlet on coil tubing head. Reinstall and test secondary master and swab valve. Make final measurements to install flowlines to CT Head inlet and outlet. Pull BPV. 3. Make flowline modifications for concentric coil tubina strina. Plumb in and test annular flow line with a new 5K choke and ball valve to existing flowline. Plumb in and test source gas flowline and 2-3/8" by 1-3/4" annulus flowline 4. MIRU MOC flow back eauipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. Installation of 2-3/8" CT 5. MIRU BJ coiled tubina unit with 5519' of 2-3/8" coiled tubing (QTI #34209). Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple UP BJ CT wellhead assemblv (WHA). WHA to include 4-1/8" - 5M X 4-1/16" - 10M DSA, 4- 1/16" - 10M X 5' Flanged Riser, 4-1/16" - 10M flow cross and 4-1/16" - 10M Dual-Combi BOP (dressed for 2-3/8" CT). Function test BOP. Stab 2-3/8" CT into injector. Install G&G Concentric Coil Tubing BHA and pull test to 15,000 Ibs. Nipple up injector to WHA. . . Page 2 of3 7. Pressure test surface lines and CT eauipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. 8. MU CT BHA. Nipple injector off WHA. PU 10' of 4-1/16" CO lubricator. MU velocity string BHA to end of CT. 9. Nipple UP iniector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 10. RIH with 2-3/8" coil tubina velocitv strina and BHA with well flowing to sales up annulus (if desired). 11. Cut coil tubina. PUH to span WHA for final landing depth of +/-4,475' Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and 2-3/8"" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 12. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger to hanging coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 2-3/8" CT connector. Pull test CT connector (25,000 Ibs.) using a pull plate. 13. Latch GS spear to Vetco mandrel after PU injector. Remove 2-3/8" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 14. RIH and land Vetco CT hamler per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between a-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. Installation of 1.75" CT 16. MIRU BJ coiled tubina unit with 5669' of 1.75" coiled tubing (OTI #34208). MU CT 1.75" CT BHA. Nipple injector off WHA. PU 10' of 4-1/16" CO lubricator. MU velocity string BHA to end of CT. 17. RIH with 1.75" coil tubina velocitv strina and BHA with well flowing to sales up Casing by 2-3/8" annulus (if desired). 18. Cut coil tubina. PUH to span WHA for final landing depth of +/-4,465' (10' above 2-3/8" CT Setting Depth). Use caution when nearing depth to avoid running in to the 2-3/8" BHA. Watch weight indicator closely and stop immediately if pipe weight begins to drop off. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release KU 43-6A CCT String Hangoff Procedure DMD - 6/19/2007 10:19:27 AM . . Page 3 of3 WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and 1.75" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 19. MU Vetco Coil Tubina Hanaer and Baker GS Runnina Tool. Swing Injector and lubricator away from WHo Vetco to connect VGCT Coil Tubing Hanger (4" Nom CIW 3" Baker Fishneck with 2-3/8" 8rd Box and 2" BPV) to hang coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Dimple-on a 1.75" CT connector. Pull test CT connector (25,000 Ibs.) using 1.125" 10SA box X 1-1/2" MT pin crossover and 1-1/2" MT box pull plate. Tool string will consist of 1-3/4" slim line dim pie-on, 1-3/4" DF check valve, 1.125' 10SA box X 1- 1/2" MT pin X-over and 3" GS spear. PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger. 20. Latch GS spear to Vetco mandrel after PU injector. Remove 1.75" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 Ibs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 21. RIH and land Vetco CT hanaer per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 22. Release 3" GS Runnina Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 23. Purae KCL water from CT remainina on reel trailer with nitroaen. Allow N2 to vent to flowback tank. 24. RDMO and release eauipment. RD flowback iron. Release tanks and all rental equipment to vendors. 25. MIRU Slickline Unit and Pressure Test to 1.5 Times WH Pressure. RIH to nipple landing depth of 1- 3/4" CT string and Pull blanking plug. POOH. MU string to run out the end of the 1-3/4" CT and pull the blanking plug in the 2-3/8" CT (nipple landing depth of 2-3/8"), RIH and pull plug. MU toolstring for standing valve and RIH to 2-3/8" landing depth and set standing valve. RDMO Slickline 26. Complete Wellhead Modifications for Concentric. Complete surface work for the completion of Concentric Coil Tubing Modification. CONTACTS Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) David Martens: 713-296-3302 (w) 832-4 72-6249( cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emeraencv Dial 911 KU 43-6A eeT String Hangoff Procedure DMD - 6/19/2007 10:19:27 AM Pad 41 KU 43..6A , Kenai Gas Field KB-Gl: 12.00' DF-Gl: 21.6' (WO) ITree CXN: 3-1/2", 8rd Tbg Hanger prepped w/ : -4' of 5-1/2", 14.0 ppf, K-S5, STC pup jt No Re-entry guide on pump -5" Type "H" SPY profile -5-1/2" LTC lift threads Location 217' S & 4279' E of NW Corner SEC 7, T4N, R11W API#50-133-20123 10-3/4",40.5#, J-55, Armco Seal Lock Casing @ 1250' Cmt w/1575 sks of Class G Isolated Perfs 4106'-4107' (Sqzd) A - 8 4173'-4177' (Sqzd 4/00) A-10 4270'-4294' (11/1170) A-11 4338'-4370' (11/1/70) isolation Assemblv -Weatherford SLPU Isolation PKR @ 4010' -5-1/2",15.5 ppf, K-55 LTC scab liner assemby 4010'-4388' -Weatherford SLPL isolation PKR @ 4388' Existing Perfs B-1 4407'-4457' (50') Inflatable Bridge Plug 3-3/8" @ 4519' KB. 20 Dec 2004 8-2 4521'-4534' (13')(6 spf, 5/1/00) Fish/Fill Casing 7-5/8",26.4#, J-55, LTC @ 0'-1140' 7-5/8",33.7#, N-80, LTC @ 1140'-5289' Cmt w/1500 sks of Class G Tag Fill: 4562' (5/28/04) Fish: Halliburton EZSY @ 4703' (4/00) Fish: Saker "K" bridge plug @ 4786' Fill: Howco EZ CI8P @ 4800' capped w/14' cmt Fish: Howco EZ bridge plug Fill @ 5217' ELM (11/4/97) Abandoned Perfs: 8-54930'-4956' Well Name & Number: KU 43-6A Lease I KGF, Pad 41-7 County or Parish: Kenai Peninsula I State/Prov. AK I Country: I USA Prepared By: YLA Last Revision Date: I 07/18/051 KB-GL: 12.00' DF-GL: 21.6' (WO) Location 217' S 8. 4279' E of NW Corner SEC 7, T4N, R11W API#50-133-20123 Isolated Perfs 4106'-4107' (Sqzd) A - 8 4173'-4177' (Sqzd 4/00) A-10 4270'-4294' (11/1/70) A-11 4338'-4370' (11/1170) ExistinQ Perfs B-1 4407'-4457' (50') B-2 4521'-4534' (13')(6 spf, 5/1/00) CasinQ 7-5/5", 26.4#, J-55, LTC @ 0'-1140' 7-5/5",33.7#, N-SO, LTC @ 1140'-5259' Cmt wI 1500 sks of Class G ROPOSED KU 43..6Ä Pad 41-7, Kenai Gas Field Tbg Hanger prepped wI : -4' of 5-1/2", 14.0 ppf, K-5S, S'TC pup jt No Re-entry guide on pump -5" Type "H" BPV profile -5-1/2" LTC lift threads 10-3/4",40.5#, J-55, Armco Seal Lock Casing @ 1250' Cmt wI 1575 sks of Class G Isolation Assemblv -Weatherford SLPU Isolation PKR @ 4010' -5-1/2", 15.5 ppf, K-55 LTC scab liner assemby4010'-438S' -Weatherford SLPL Isolation PKR @ 4388' Inflatable Bridge Plug 3-3/5" @4519' KB. 20 Dec 2004 Tag Fill: 4562' KB (5/28/04) Fish: Halliburton EZSV @ 4703' (4/00) Fish: Baker "K" bridge plug @ 4786' Fill: Howco EZ CISP @ 4500' capped wI 14' cmt Fish: Howco EZ bridge plug Fill @ 5217' ELM (11/4/97) Abandoned Perfs: 8-5 4930'-4956' Well Name & Number: KU 43-6A Lease 1 KGF, Pad 41-7 County or Parish: Kenai Peninsula 1 State/Prov. AK I Country: I USA Prepared By: YLA Last Revision Date: I 07/18/051 ITO @ 5300' . . Mafathon Oil Com pal1Y Opera_ions Summary Report Legal Well Name: KENAI UNIT 43-6A Common Well Name: KENAI UNIT 43-6A Event Name: MAINTENANCE/REPAIR Contractor Name: Rig Name: Date From - To Hours Code Sub Phase Code 5/15/2007 10:00 - 18:00 8.00 RURD COIL CTBG 5/16/2007 07:00 - 08: 15 1.25 SAFETY MTG - CTBG 08:15 - 10:00 1.75 RURD - COIL CTBG 10:00 - 12:00 2.00 RURD_ CMT_ CTBG 12:00 - 15:20 3.33 WORK COIL CTBG 15:20 - 15:35 0.25 WASH FILL CTBG 15:35 - 16:45 1.17 WASH FILL CTBG 16:45 - 16:50 0.08 WASH FILL CTBG 16:50 - 17:15 0.42 WASH FILL CTBG 17:15 - 17:40 0.42 WASH FILL CTBG 17:40 - 18:35 0.92 WASH FILL CTBG 18:35 - 19:50 1.25 RUNPUL COIL CTBG 19:50 - 21 :15 1.42 RUNPUL COIL CTBG 21:15 - 21:30 0.25 SAFETY MTG - CTBG 21 :30 - 22:45 1.25 RURD_ SLlK CTBG 22:45 - 23:15 0.50 RURD_ SLlK CTBG 23:15 - 23:50 0.58 RUNPUL SLlK CTBG 23:50 - 23:58 0.13 RUNPUL SLlK CTBG 23:58 - 00:30 0.53 RUNPUL SLlK CTBG 00:30 - 00:45 0.25 RUNPUL SLlK CTBG 00:45 - 00:55 0.17 RUNPUL SLlK CTBG 00:55 - 01 :00 0.08 RUNPUL SLlK CTBG 01 :00 - 01 :20 0.33 RUNPUL SLlK CTBG 01 :20 - 01:30 0.17 RUNPUL SLlK CTBG 01 :30 - 01 :45 0.25 RUNPUL SLlK CTBG 01 :45 - 02:15 0.50 RUNPUL SLlK CTBG 02:15 - 03:15 1.00 RUNPUL SLlK CTBG 03:15 - 03:30 0.25 RUNPUL SLlK CTBG 03:30 - 03:40 0.17 RUNPUL SLlK CTBG 03:40 - 04:00 0.33 RUNPUL SLlK CTBG 04:00 - 04:30 0.50 RUNPUL SLlK CTBG 04:30 - 04:45 0.25 RUNPUL SLlK CTBG 04:45 - 05:00 0.25 RURD - SLlK CTBG 05:00 - 05:30 0.50 SAFETY MTG - CTBG 05:30 - 06:00 0.50 RURD_ COIL CTBG Start: 5/14/2007 Rig Release: Rig Number: of2 Spud Date: 1/1/1968 End: 5/16/2007 Group: p:~$cription of Operations MIRU equipment, spotted tanks, coil unit and equipment around well head. Held PJSM with Rig personnel, Udelhoven and BJ crew prior to starting up on location. Discussed activity level on pad and safety issues. MU concentric string to injector. Ran T bar down BOP to test. Tested BOP's at low pressure = 250 psig, high up to 6000 psig. Good test. Bled off. PU 2" X 1" coil and mu 2.25" sand vac nozzle to the end of coil. PT 1" to 3000 psig. 2" coil to 6500 psig. Good test. Finish making up the sand vac nozzles. Open well, RIH with coil to 4393' KBD. PIR at 0.3 BPM while running in well with concentric string. PIP= 941 PSIG, 2" pressure= 0 psig PU hole to check weight, SID pump to verify Sand vac working. Bring up pump verifed sand vac working. Continue in hole with coil. Coil at 4435.5' KBD, PIP= 4474 psig, CT weight while running in well at 11700 Ibs. 25 gal returns per minute, some sand in returns. Stacked out at 4443' KBD, PIP @ 5030 psig, 0.53 BPM with some sand in returns. No change, PUH with coil 10', SID pump, bring up pump. RIH tagged up at same depth. PUH with coil to 4430.1' KBD. RIH stacked up to 3200 Ib down on coil, same tagged depth. No change in depth, bucket test shows some sand in bucket. PU hole, RIH tagged same spot, returns have small amount of sand. Unable to make any hole. POOH. Stand back injector. Hold PJSM and review Safework Permit with BJ, and Pollard personnel. MIRU Pollard equipment. Open master valve (34 turns). Open swab valve (34 turns). RIH with 3.75" LIB. Tag 5-1/2" scab line @ 4000' KB on way in hole. PU and set down 4-5 times in order to get into liner. Tag @ 4405'KB. POOH. LIB had approx 1/2" of lead missing on small section of edge. With a sharp gash of undetermined origin on this same edge. PU 3.7" Centralizer, knuckle, and 3-1/2" LIB. RIH. No trouble running thru scab liner this time. Tagged @4419' KB. POOH. OOH. Edges of LIB intack-again shows gash on the edge that could be the very top of a fishing neck. Inconclussive. RIH with 3.7" centralizer, knuckle, and 3.7" LIB. Tag scab liner. POOH. Tagged @4016' KB. (scab liner top) LIB has rolled edge where it contacted the scab liner. PU 1" fishing neck with 2.1" skirt. RIH. Attempt to latch fishing neck. POOH. Fishing neck plugged with solids. Not sheared. PU 2-1/4" Drive down bailer. RIH. Tag @4418' KB. Continued to bail. OOH. Bailer plugged with dry solids. RIH with bailer. Tag @ 4422' KB. Continue bailing. POOH. Bailer full of dry solids. RD Pollard Held PJSM with ASRC crane operator and BJ crew prior to starting Sand Vac rig up.. Discussed over-head loads, crane safety, and safety issues. RU injector head to BOP's, Printed: 6/19/2007 10:11:05AM Marathon Oil Company Operations Summary Report . Legal Well Name: KENAI UNIT 43-6A Common Well Name: KENAI UNIT 43-6A Event Name: MAINTENANCE/REPAIR Contractor Name: Rig Name: Date From::' To Hours Code Sub Phase Code 5/17/2007 06:00 - 06:30 0.50 SAFETY MTG - CTBG 06:30 - 08:00 1.50 WASH FILL CTBG 08:00 - 10:35 2.58 WAlTON EQIP CTBG 10:35 -11:05 0.50 WASH FILL CTBG 11:05-11:21 0.27 WASH FILL CTBG 11 :21 - 11 :30 0.15 WASH FILL CTBG 11:30 -11:40 0.17 WASH FILL CTBG 11 :40 - 12:00 0.33 WASH FILL CTBG 12:00 - 12:40 0.67 WASH FILL CTBG 12:40 - 12:50 0.17 WASH FILL CTBG 12:50 - 14:05 1.25 WASH FILL CTBG 14:05 - 14:10 0.08 WASH FILL CTBG 14:10 - 14:20 0.17 WASH FILL CTBG 14:20 - 14:35 0.25 WASH FILL CTBG 14:35 - 16:07 1.53 WASH FILL CTBG 16:07 - 16:12 0.08 WASH FILL CTBG 16:12 - 17:00 0.80 WASH FILL CTBG 17:00 - 18:00 1.00 WASH FILL CTBG 18:00 - 18:20 0.33 RURD_ COIL CTBG 18:20 - 18:30 0.17 SAFETY MTG - CTBG 18:30 - 19:30 1.00 RURD_ COIL CTBG 19:30 - 02:30 7.00 RURD_ COIL CTBG . 20f2 Start: 5/14/2007 Rig Release: Rig Number: Spud Date: 1/1/1968 End: 5/16/2007 Group: Description of Operations On well with injector. Open well, RIH with concentric tool with modified sand vac nozzle. Nozzle has 2 ea. 0.065 down and 3 ea. up jets. Pump at 0.59 BPM while RIH. Coil at 4419' developed a small hydraulic leak on the hydralic fitting. PU coil to 4400', park coil and continue pumping. No fitting with correct size on location BJ bringing one out from office. Maintain status while waiting on part. Part replaced and coil back on line. Continue running in hole with sand vac. PIR= 0.59 BPM, PIP= 4560 psig, WHP= 45 psig. CT @ 4424' CKBD. Sand vac working down hole. Some sand in return fluid. Coil at 4442.1' KBD. WHP= 48 psig, 2" coil pressure = 11 psig. PIP (on 1" coil) = 4575 psig, PIR= 0.59 BPM. Returns at .5 BPM. Good returns some sand. Coil at 4454.2' KBD. WHP= 47 psig, 2" coil pressure = 11 psig. PIP= 4696 psig, PIR= 0.59 BPM, .. 0.25 cup sand in 5 gal returns. Coil at 4474' KBD. WHP= 48 psig, 2" coil pressure = 11 psig. PIP= 4710 psig, PIR= 0.59 BPM, coil tubing RIH weight at 9585 Ibs Sand vac down to 4509.7', sat down. Continue pumping at same rate, with no movement. PU hole 10' to 4499', RIH to same depth. Coil RIH to 4509.5' KBD, returns have 2 tea spoons per 5 gal bucket. PIR= 0.59 BPM. Circulate hole to surface and monitor returns for sand in returns. 40 bbls circulated with very little sand in returns. WHP= 48 psig, 0.60 BPM, CT @ 4507.4' KBD. PIP= 4527 psig. SID pump to shift from sand vac to well vac. Closed down hole valve and wait 10 minutes. Open valve, start pump. Pressure up to 5200 psig, and PIP @ 0.61 psig. Monitor rate and pressure. Appears that tool not shifted. SID pump to shift from sand vac to well vac. Closed down hole valve and wait 10 minutes. Open valve, start pump. Attempt to shift tool 6 additional times by shutting down pump and starting it up. SID pump, let pressure bled off and closed surface valves. Wait 10 minutes Pressure up to 6000 psig, instead of the 5300 psig. Sand vac shifted to Well vac. Check returns to flow back tank. Circulate 60 bbls prior to pulling out of hole. POOH with coil while pumping down the 1" and up the 2" coil. At surface with coil, SII master to unload fluid to flow back tank with N2. Well secured. Crew change. Held PJSM with ASRC crane operator and BJ crew prior to starting Sand Vac rig down and crew change. Discussed over-head loads, crane safety, and safety issues. Day crew left location, move coil injector to ground, pull the sand vac tool and place blank on end of coil to blow the reel down to the flow back tank with N2. Completed RD of concentrc unit and cleaned up around well head. BJ left crew at 0230 am. Printed: 6/19/2007 10:11:05AM . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Marathon Oil Company July 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 \~<lS--OS- \ .. ..... .....-..... ....-' Reference: Variance on 20 AC 25.286.g Field: Kenai Gas Field Well: KU 43-6a SCANNED JUL 0 9 2007 Dear Mr. Maunder: We have rigged up coiled tubing on well KU 43-6a Pool 3 producer to run the first part of the concentric completion. Near the end of our rigup we found out that the coiled tubing hanger is 5-7/16" 00 and the BOP is 4-1/16" 10. We request a variance on 20.AC.25.286g to utilize a 5000 psi annular preventer during the portion of our job while we are making up the hanger onto the 2-3/8" coiled tubing. The other parts of the job would still have the full coiled tubing combi BOP in place. The annular preventer is necessary to close in the well while rigging up the hanger, as the hanger must be rigged up below the BJ combi BOP. KU 43-6a has a flowing pressure under 10 psi and will remain flowing during the job. It has a shut in pressure capability of 125 psi and we will have kill lines and kill weight fluid ready to kill the well in the event of a leak. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, Michael A. Mullin Senior Production Engineer Enclosures: Current BOP diagram Planned BOP diagram KU 43-6a . . Page 1 of 1 Maunder, Thomas E (DOA) From: Mullin, Mickey [mmullin@marathonoil.com] Sent: Sunday, July 08,20077:04 AM To: Maunder, Thomas E (DOA) Subject: KU 43-6a \<P ~-a S- \ Tom, We found all the equipment to proceed with KU 43-6a but on review discovered that the total weight was greater than the capacity of the lifting equipment on the CT injector head. We are going to move to KBU 33-6 and have a 7" BOP leaving Oklahoma on Monday. We plan to return to KU 43-6a in about 10 days with the correct CT BOP. Thank you for your help. Mickey Mullin Senio~ P~oduction 2n9inee~ Ma~at:hon Oil Company (907) 283-1337 (907) 398-9954 7/9/2007 Valve BJ Flow Cross BJ Dual Combi BOP (Pipe/Slips) and Blind Cutters Future 2-3/8" and 1-3/4" Concentric Hanger BJ DUAL COMBI BOP (PIPE/SLIPS) AND BLIND CUTTERS FLOWLINE OUT TO FACILITY 2-3/8" AND 1-3/4" CONCENTRIC HANGER FLOWLINE OUT TO FACILITY Valve Flow Cross BJ Dual Combi BOP (Pipe/Slips) and Blind Cutters uture 2-3/8" and 1-3/4" Concentric Hanger " 5K Annular Preventer BJ DUAL COMBI BOP (PIPE/SLIPS) AND BLIND CUTTERS KILL LINE 1" FLOW CROSS FLOWLINE OUT TO FACILITY 2-3/8" AND 1-3/4" CONCENTRIC HANGER FLOWLINE OUT TO FACILITY -,. ! MEMORANDUM TO: THRU: FROM: Robert Christensont~'~ Chairman Blair Wondzell P.I. Supervisor Lou Grimaldi ~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2000 SUBJECT: Blowout Preventer Test ~'--Giacier rig #1~,) -- Marathon KU - Kenai Gas Field NON- CONFIDENTIAL Operator Rep.: Darrell Greene Contractor Rep.: Geor,qe Brewster Test Type Initial: X Test Pressures Rams: 250/5000 MISC. INSPECTIONS: P/F Location Gen.: P Sign: Housekeeping: P Rig cond: PTD On Location P Hazard: Standing Order: P Op. phone: 227-6837 Op. E-Mail: Rig phone: Rig E-Mail: Annular: 250/3500 Choke: 250/5000 TEST DATA FLOOR VALVES: MUD SYSTEM: P/F Quantity P/F Trip Tank P Upper Kelly 1 P Pit Level Indicators P Lower Kelly 1 P Flow Indicator P ' "' Ball Type 1 P Meth Gas Detector Inside BOP 1 P H2S Gas Detector BOP STACK: Quantity Size P/F Annular Preventer I 13 5/8 P Pipe Rams 1 13 5/8 P Lower Pipe Rams 1 3 1/2 dual P* Blind Rams 1 Blind P Choke Ln. Valves 1 4" P HCR Valves 1 4" P Kill Line Valves 2 3" F Check Valve 0 CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Man. Chokes 1 P Hyd. Chokes 1 P Visual Alarm P P P P P P P P P P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3050 P After Closure 1650 P 200 psi Attained :39 P Full Pressure 3:51 P Blind Covers (All Stations): P N2 Bottles (avg): 4~2450 P Test's Details This was the initial test and proof of worthiness Ibr this new rigs start-up. All piping pertinant to BOP functions was pressure tested. Two failures were observed, these being the swivel packing on the top drive which was replaced and retested "OK" and the shaft seal on the inside Kill valve which after being greased retested "OK". The accumulators recharge time was slightly long, the filters were pulled and cleaned. The check valve tbr the annular preventer leaked internally allowing the bag to open when system pressure. This was also cleaned and a piece of trash removed. On a whole,the rig tested out very well tbr a new start-up. This rig is very well laid out showing much/bre- thought in its design and should do quite well in Marathon's upcoming Drilling and workover program. Total Test Time: ~ Number of er2_~ failures: 2 Attatchments: None cc: Pete Ber.q'~arathon drillin,q supervis BOP Glacier 4/10/00 Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 19, 2000 Mr. Blair Wondzell, P.E. State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KU 43-6A Dear Mr. Wondzell' Enclosed is the completed Report of Sundry Well Operations for Well number KU 43-6A. A wellbore schematic and procedure is also attached. Please advise if additional information is required. I can be reached on 564-6303. Sincerely, Ralph J. Affinito Production Engineer Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. g:'cmn\drlg~kg~wells~ku43-6al~OGCC02.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate Pull Tubing Alter Casing Repair Well Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 277' FNL, 4279' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval At Effective Depth At Total Depth 2459' N and 181' E of surface location 5. Type of Well: Development_~_X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 15 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 43-6A 9. Permit Number 68-51 10. APl Number 50- 133-20121 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 5300 feet Plugs (measured) 4565 feet feet Junk (measured) feet ClBP capped w/14' cement @ 4800' ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 1250' 10-3/4" 1575 sks 52~89' 7-5/8" 1500 sks B-l: 4407' - 4457' MD, B-2: 4521' - 4534' MD true vertical B-l: 3813' - 3856' MD, B-2:3911' - 3922' MD Tubing (size, grade, and measured depth) NONE Packers and SSSV (type and measured depth) 5-1/2" ppf 1-80 Scab liner from 4010' to 4380" Weatherford SLPL packer @4010' MD Weatherford SLPU packer @4380' MD Measured Depth True Vertical Depth 1250' 1195' 5289' 4555' 13. Stimulation or Cement Squeeze Summary Squeeze the A-8 perfs from 4173-4177'to 500 psi surface pressure Isolated the A-8, A-10, and the A-11 perfs behind a straddle. Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure See attached Work Summary 14. OiI-Bbl Representative Daily Averaqe Production or Injection D~ta Gas-Mcf Water-Bbl Casing Pressure Prior to Well Operation 0 6362 0 Tubing Pressure 134 Subsequent to Operation 0 14719 0 0 162 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service Signed Ralph Affinito true and correct to the best of my knowledge. Tele 564-6303 Title Production Engineer Form 10-404 Rev. 06/15/88 Date 5/19/2000 ,~,, Submit in Duplicate",,,~ Kenai Gas Field Well KU 43-6a, Pad 41-7 Marathon Oil Co., Alaska Region Original KB-GL: 12.00' Workover DF-GL: 21.6' 217' S & 4279' E of NW Corner Sec. 7, T4N, Rl lW API #50-133-20121 Isolated Perforations 4106'- 4107' (Sqzd) A-8 4173' - 4177' (Sqzd 4/00) A-10 4270'- 4294' (11/1/70) A-11 4338'- 4370' (11/1/70) Existing Perfoations B-1 4407'- 4457' (6 spf, 5/1/00) B-2 4521'- 4534' (6 spf, 5/1/00) Abandoned Perforations B-5 4930'-4956' TD @ 5300' Tree Connection = 3-1/2", 8-rd Tubing Hanger prepped with: - 4' of 5-112", 14.0 ppf, K-55, STC pup joint No re-entry guide on pup - 5" Type "H" BPV profile - 5-1/2" LTC lift threads 10-3/4", 40.5#, J-55, Armco SealLock Casing @ 1250' Cmt w/1575 sks of Class G Weatherford SLPU Isolation Packer @ 4010' Isolation Assembly 5-1/2", 15.5 ppf, K-55, LTC scab liner assembly 4010' - 4388' Weatherford SLPL Isolation Packer @ 4388' Fill/Fish: Halliburton EZSV @ 4703' (4/00) Fish: Baker "K" bridge plug @ 4786' Howco EZ CIBP @ 4800' capped w/14' cement Fish: Howco EZ bridge plug Fill @ 5217' ELM (11/4/97) 7-5/8", 26.4#, J-55, LTC Casing @ O' - 1140' 7-5/8", 33.7#, N-80, LTC Casing @ 1140'- 5289' Cmt w/1500 sks of Class G Last Rev: JGE, 4/27/00 02-15-2000 MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field Well KU 43-6a Workover to 7-5/8" Tubingless Completion RU Slickline. RIH and pull PX plug from SS @ 4130'. RIH on SS and tag @ 4268'. RIH on LS and shift sliding sleeve @ 4084' CLOSED. 02-17-2000 MIRU SLB pumping service. Hold Safety meeting. PT lines to 2000 psig. Blend 11 bbl pill as follows: 3% KC1 5 lbm/bbl HEC 150 lbm SafeCarb-Coarse 450 lbm SafeCarb-Med Pump pill down long string, displacing w/20 bbls of 3% KC1 water. Installed BPV on LS. RU on SS and pump 34 bbls fresh water. Installed BPV on SS. RD Dowell. 04-05-2000 RU Slickline. RIH to 4096' and pull prong and PX plug body. Fluid level dropped from surface to 950'. RD Slickline. 04-07-2000 MI RU Glacier Drilling Rig gl. Unflange wellhead. PU on SS working 15-73K - not free. Pull 55K tension and RU APRS and chemical cut @ 4119' MD w/2-3/8" tool. Unable to work pipe free. Pull 60K tension and make jet cut @ 4120' MD w/2-3/8" tool. Unable to work free. Pull 60K tension and make chemical cut @ 4003' MD w/2-7/8" tool. Work SS tbg free w/47K Ibm weight. Circulate hole while losing 5.6 bbls/hr rate. TOH laying down SS. Tubing in very good condition w/no NORM. SS fish top left at 4013' MD. 04-08-2000 PU on LS unable to work free w/75K. Make chemical cut at 4145' below dual packer at 4123. Unable to work free. Make chemical cut above packer @ 4072'. TOH w/LS 2-7/8" tbg also in good condition. Install upper 4" and 2-7/8" rams. TIH w/fishing BHA on 4" DP. Latch onto SS fish @ 4013' fish and jar free. TOH laying down SS fish. TIH w/fishing BHA and engage LS fish. Unable to jar free. TOH and lay down 20' section of LS fish. TIH w/mill shoe and washpipe tagging fill @ 4107'. Wash to packer top at 4128' strap measurement. Mill to 4131' and TOH finding both LS and SS tubing stubs stuck in wash pipe. TIH w/new mill shoe and mill to 4134'. TOH and TIH w/overshot for packer. Latch onto dual packer fish and TOH w/same. New fish top now @ 4141' TIH w/wash pipe and wash over tbg fish to permanent pkr @ 4393'. TOH w/washpipe. TIH w/overshot and TOH w/tbg fish, seal assembly, and tail pipe. TIH w/packer plucker. Tag packer and mill 1.5' and packer came free. TOH w/packer fish. TIH w/mill tooth bit for 7-5/8" csg. Tag fill @ 4529'. Wash fill to 4700'. Hole standing full. TOH w/bit. 04-17-2000 TIH and set EZSV cmt retainer @ 4207' below A-8 perfs. Establish injection rate into A-8 perfs from 4173-4177'. Place a 20 bbl (100 sk) plug of cmt across perfs. Close annular BOP and Bradenhead sqz to 500 psig and WOC. Pressure bled to 400 psi after 7 hrs. TOH tbg. 04-19-2000 TIH w/bit and tag cmt @ 3892'. Drill out cmt from 3892-4200' and PT to 300 psig - held fine. Drill out retainer and run bit to 4700'. Circulate hole clean w/fresh water and TOH. TIH w/scraper for 7- 5/8" csg to 4400' and TOH. 04-20-2000 PU 370' of 5-1/2" 15.5 ppf L-80 liner w/Weatherford SLPL packer on bottom and SLPU packer on top. Run liner and set upper packer at 4010' (lower packer @ 4380') so that entire Pool #3 perfs (A-8, A-10, and A-ii) are isolated. TOH w/DP while laying down. RU 6" tree w/4' jt of 5.5" OD 14 ppf K-55 tbg below and backpressure valve profile. RD Glacier Drilling Rig #1. 04-28-2000 RU Slickline. Pressure test lubricator. RIH w/blind box attempting to find the fluid level to no avail. Unable to get into scab liner @ 4010' and extremely difficult to get back into 4' tbg sub below tree. RIH w/strain gauge making gradient stops. Determined pressure to be 1318 psig @ mid perf. RD Slickline. 04-29-2000 05-01-2000 05-04-2000 RU Coil Tubing service. Pressure test CT and all surface lines to 2500 psig. Fully function test and pressure test BOP to 2500 psig. Repaired O-rings in BOP and repressured to repair hydraulic leaks. Held safety meeting. RU 6' stinger with 2.25" OD bullet nosed jet with single 7/8" OD orifice on bottom. Unable to get into scab liner at 4010'. Unloaded 132 bbls of mud in working down to 4010'. Work several times at various nitrogen rates from 0 to 1000 SCFM. COH. No problem getting into 4'x5-1/2" landing joint below tree. Place bend in CT and re-run but unable to get into liner. Wellbore deviation at this depth is 32 degrees. Did not recover and additional fluid in getting down to 4010'. Hydrostatic on formation is estimated at 185 psig but still did not have any inflow. COH. Removed 6' stinger and ground down 1.75" side/bottom port nozzle. RIH while not pumping nitrogen and passing through scab liner. Work CT to 4650' and unload remaining fluid. Pull pass up through perfs and back down through perfs. Sitting on bottom for 30 minutes. Slowly come out of hole while jetting from 4650 to 1500 ft. Maintained 100 psi on annulus. No additional fluid was recovered. Total fluid volume recovered from entire CT operations was 135-140 bbls. RU WL. PT lubricator to 1500 psig. Reperforate the B-1 and B-2 w/3-3/8" 6 SPF as follows: B-1 4407-4457' 50' B-2 4521-4534' 13' No gas blow to surface. RU and run pressure/temperature log (PSP Tool). Determine fluid level @ 3208' and SBHP of 460 psig. RD WL service. RU of SLB CT equipment. Make up the same BHA which passed through the 5-1/2" liner on 04/30/00 consisting of a 1.75" OD multiport nozzel with dual check valves without stinger on 1.75" CT. Picked up injector head and RU vac truck containing FW to SLB filter pot. Hold safety and environmental awareness meeting noting job Commenced filling 1.75" OD CT with FW. CT volume = 32 bbls. Pressure tested top (gl) blind shears to 2500/250 psig by pumping down the kill line - held fine. Pressure tested (g2) blind shears to 2500/250 psig by pumping down the kill line - held fine. Pressure tested #4 pipe ram by closing #3 slips and pumping through CT to 2500/250 psig- held fine. Pressure tested BOP body to 2500/250 psig testing from pump truck to choke - held fine. Bled all liquid off through choke to tank. Displaced liquid fi.om CT to tank using nitrogen. Open swab and master valves and RIH. Commence pumping nitrogen at 750 SCFM while tubing is at 3000'. When nitrogen reached tbg end began running in the hole. Unable to get into liner packer @ 4010'. Work at various nitrogen rates from 0 to 1000 SCFM to no avail. COH and place bend in CT. RIH without pumping nitrogen and work aggressively to get into liner. Finally work into liner. Sit at 4180 and start pumping nitrogen at 1000 SCFM. Based upon SLB pressure log and a pressure of 460 psig there should be 61 bbls of fluid in the hole from 3216 ft to 4650 fi. RIH to 4650 ft. Continue jetting nitrogen at various rates from 500-1000 SCFM. Begin flowing back fluid. Pull uphole and set at 4100 and SD nitrogen for 45 minutes. Resume pumping nitrogen and continue back down to 4650' working from 4650 ft to 4100 ft 5 times while pumping at 750-1000 SCFM. Negligible fluid to surface and no gas indication on LEL monitor. Opened bypass on choke to maximize flow and reduce FTP. Pull out of the hole while pumping 1000 SCFM from 4650 to 100' with choke bypass open. A significant volume of fluid was recovered while pulling from 2000' to 100'. Total fluid recovered is 38 bbls. SD nitrogen at 100' and pull CT into BOP. Flow well to tank at 100 psig FTP. Open well to test separator going to atmosphere. Close choke and swab valve and RD injector head. Well flowing 2.486 MMCFGPD @ 100 # FTP through 2.5" orifice. SD for 10 min SITP built from 100# to 180 #. Test well at 14 MMCFGPD @ 162 psig FTP on 05-06-2000. 200.3 casing string to a pressure in excess of formation pressure, and will test the squee-.e ~,~, lo Lu greater than 2000 psi. Incidentally, when KU 43-6al was converted to annular flow in September 1998 the 7%" casing was tested to 660 psi with the fluid level in the casing at about 1000'. The last question you raised was how a tubingless completion of KU 43-6a stands to economically benefit the Stealing Pool 4 and the Kenai Gas Field. There are many benefits. It postpones the installation of additional compression at the Kenai Gas Field. It lowers the forecasted abandOnment pressure of Pool 4, increasing proven gas reserves and field life. On a dollar per MCFD basis, a w°rkover such as this stands to reduce Marathon's cost of developing deliverability by an order of magnitude compared to conventional alternatives. And success in the Stealing Pool 4 can be extended to Sterling Pool 6 with similar impacts as have already been stated. Please contact me if you need any further information. ~qincerelv. \ Marathon Oil Company October 15, 1999 Alaska R, ,.,on Domestic Production P.O. Box 196168 Anchorage. AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Reference: Workover of KU 43-6a, Kenai Gas Field Dear Mr. Wondzell: RECEIVED OCT 2 l 1999 1311& (las Cons. Commission Anchorage Our conversation of October 13 covered several aspects of Marathon's proposed tubingless completion of well KU 43-6a in the Kenai Gas Field. The text below summarizes our discussion. You asked several questions regarding erosion of tubulars, sand production expectations, sand or erosion monitoring, etc. Marathon does not expect erosion to be a significant factor in the life of well KU 43-6a following this workover. First, sand production has historically not been an issue with any of the Sterling Sands in the Kenai Gas Field unless a well also produced a significant volume of water.: The Sterling Pool 4 is a volumetric gas reservoir that produces minimal water. Second, as the table below shows, the expected peak flow rate of 30 MMCFD will be well below the calculated erosive threshold. ~l!f'~ ~-"*":""';: : ..... ~,'~-~.", 7%" Casing 6.765 150 none 73.1 7%" Casing 6.765 i 50 0.5 48.9 7%" Casing 6.765 150 1.0 34.6 6" Flowline 5.761 90 none 39.4 3" Flowline 2.900 90 none 10.0 If Marathon uses both of the existing 3" flowlines to produce the well initially, we'll be rate- restricted to no more than 8 MMCFD per flowline. So even in that example we'll stay well below the erosive threshold. A subsidiary of USX Corporation Environmentally aware for the long run. KU 43-6a Workover October 15, 1999 Page 2 At least initially, Marathon plans to monitor KU 43-6a in the same fashion as we do our annular completions. This includes annual ultrasonic inspection of pipe thickness at key areas of the flowline to verify that unacceptable wall loss is not occurring. We'll also periodically tag for fill in the well while conducting pressure surveys to verify that we're not accumulating solids in the wellbore. Finally, for the next several years Marathon plans that this well be used strictly for gas peaking operations. This means that well KU 43-6a will likely be produced at full rate for only a few days each year. Therefore, even though erosion is not expected, Marathon is taking adequate steps to make sure that any erosive tendency does not go unnoticed. Another question you asked was whether Marathon planned to install a tUbing hanger with a back-pressure valve (BPV) profile. It is Marathon's intention to install a hanger with a BPV profile and one joint of 51/2'' tubing in well KU 43-6a. At one point I had considered not running a tubing hanger because it would restrict the size of perforating gun that could be run in well KU 43-6a. This no longer is a concern, and running a hanger with a BPV profile seems the prudent thing to do. With regard to a casing pressure test, this will be accomplished during the workover when the Sterling "A' Sand perforations are squeezed. A test pressure of 500 psig will subject the entire casing string to a pressure in excess of formation pressure, and will test the squeeze perfs to greater than 2000 psi. Incidentally, when KU 43-6al was converted to annular flow in September 1998 the 7%" casing was tested to 660 psi with the fluid level in the casing at about 1000'. The last question you raised was how a tubingless completion of KU 43-6a stands to economically benefit the Stealing Pool 4 and the Kenai Gas Field. There are many benefits. It postpones the installation of additional compression at the Kenai Gas Field. It lowers the forecasted abandonment pressure of Pool 4, increasing proven gas reserves and field life. On a dollar per MCFD basis, a workover such as this stands to reduce Marathon's cost of developing deliverability by an order of magnitude compared to conventional alternatives. And success in the Stealing Pool 4 can be extended to Sterling Pool 6 with similar impacts as have already been stated. Please contact me if you need any further information. ions Engineer N:~DRLG~KGl~lArELLS~<u43 -6alLO204799~notb83 .wpd FROM FAX COVER LETTER PLEASE DELIVER THE FOLLOWING DOCUMENTS TO: Mr Blair Wondzell I1' ! ' Company AOGCC Department/Location Facsimile Number Number of pages (including th/s cover page) FROM: Name J. Gary Eller Department/Extension Facsimile Number Marathon Oil ]0-19-1999 2:~2P~ FRO~ ~.z Alaska Region Domestic Production Marathon Oil Company October 15, 1999 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr, Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 · Reference: Workover of KU 43-6a, Kenai Gas Field Dear Mr. Wondzell: . Our conversati°n of October 13 covered several aspects of Marathon's proposed tubingless completion of well KU 43-6a in the Kenai Gas Field. The text below summarizes our discussion. You asked several questions regarding erosion oftubulars, sand production expectations, sand or erosion monitoring, etc. Marathon does not expect erosion to be a significant factor in the life of well KU 43-6a following this workover. First, sand production has historically not been an issue . with any of the Stealing Sands in the Kenai Gas Field unless a well also produced a significant volume of water. ' The Sterling Pool 4 is a volumetric gas reservoir that produces minimal water. Second, as the table below shows, the expected peak flow rate of 30 MMCFD will be well below the calculated erosive threshold. . . 7%" Casing 7%" Casing 7%" Casing' 6" Flowline 3" Flowline' 6.765 6.765 6.765 5.761 2.900 150 [ none I 150 150 9O 9O 0.5 none none 73.1 48.9 34.6 39.4 10.0 If Marathon uses both of the existing 3" flowlines to produce the well initially, we'll be rate- restricted to no mOre than 8 MMCFD per flowline. So even in that example we'll stay well below the erosive threshold. A subsidiary of USX Corporation Environmentally aware for lhe long run. 10-19-1999 2: ~L3PM FROM KU 43-6a Workover October 15, 1999 Page 2 At least initially, Marathon plans to monitor KU 43-6a in the same fashion as we do our annular completions. This includes annual ultrasonic inspection of pipe thickness at key areas of the flowline to verify that unacceptable wall loss is not occurring. We'll also periodically tag for fill in the well while conducting pressure surveys to verify that we're not accumulating solids in the wellbore. Finally, for the next several years Marathon plans that this well be used strictly for gas peaking operations. This means that well KU 43-6a will likely be produced at full rate for only a few days each year. Therefore, even though erosion is not expected, Marathon is taking adequate steps to make sure that any erosive tendency does not go unnoticed. Another question you asked was whether Marathon planned to install a tubing hanger with a back-pressure valve (BPV) profile. It is Marathon's intention to install a hanger with a BPV profile and one joint of51/2' tubing in well KU 43-6a. At one point I had considered not running a tubing hanger because it would restrict the size of perforating gun that coUld be run in well KU 43-6a. This no longer is a concern, and running a hanger with a BPV profile seems.the prudent thing to do. With regard to a casing pressure test, this will be accomplished during the workover when the Sterling "A" Sand perforations are squeezed. A test pressure of 500 psig will subject the entire casing string to a pressure in excess of formation pressure, and will test the squeeze perfs to greater than 2000 psi. Incidentally, when KU 43-6al was converted to annular flow in September 1998 the 7%" casing was tested to 660 psi with the fluid level in the casing at about 1000'. The last question you raised was how a tubingless completion of KU 43-6a stands to economically benefit the Sterling Pool 4 and the Kenai Gas Field. There are many benefits. It postpones the installation of additional compression at the Kenai Gas Field. It lowers the forecasted abandonment pressure of Pool 4, increasing proven gas reserves and field'life. On a dollar per MCFD basis, a workover such as this stands to reduce Marathon's cost of developing deliverability ..by an order of magnitude compared to conventional alternatives. And success in the Sterling Pool 4 can be extended to Sterling Pool 6 with similar impacts as have already been stated. Please contact me if you need any further information. ~o~ ~ions F. ngineer N :~I)RLG~;GFVC/EL L$~KtCB-6~l\9204799~notbg3.wpd Alaska .~ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 October 12, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 t ECEIVED Reference: Workover of KU 43-6a, Kenai Gas Field Dear Mr. Wondzell: OCT 13 As per our conversation today, I am pleased to provide you with the following information with regard to Marathon's proposed tubingless completion of well KU 43-6a in the Kenai Gas Field. The additional information you requested pertained to the formation pressure trend, whether there is any history of tubing corrosion, and whether a kill string is warranted. Attached is a material balance plot of the Sterling Pool 4 in the Kenai Gas Field. The Sterling Pool 4 is a volumetric gas reservoir. Current bottomhole pressure is under 300 psig, which is about 14% of original reservoir pressure. Marathon's planned reservoir abandonment pressure is 100 psig. The Sterling Pool 4 is already more than 90% depleted. Kenai Gas Field as a whole has no particular history of tubing corrosion, and the Sterling Pool 4 is no exception. Well KU 43-6a has been worked over once in its lifetime. That workover in 1970 was done to abandon the Pool 5.2 completion and make a dual completion in Pools 3 and 4. Morning reports state that the 2-year old blast joints that were in contact with Pool 4 fluids "show no wear or evidence of sand production." Also, the original tubing was reused with no reports of any corroded joints. The best reason that a kill string is not needed in KU 43-6a is the Iow bottomhole pressure of the Sterling Pool 4. If there arises a need to kill the well, it can most easily be accomplished by simply bullheading water down the casing. The wellhead and tree are rated for 3,000 psi, and there are three separate places that a pump can be mounted to kill the well. The formation fluids are highly compressible so there will no difficulty pumping adequate volumes of kill weight fluid. A kill string would be reasonable if the formation pressure were so high that one could not bullhead kill fluid without exceeding the pressure rating of the wellhead. But that is simply not the case in this depleted Pool 4 completion. A subsidiary of USX Corporation Environmentally aware for the long run. Mr. BlairWondzell Octoberl 2, 1999 Page 2 of 2 There are numerous operational drawbacks associated with a production kill string. The most- likely kill string configuration would consist of 11/2' or 1 a/n' coil tubing hung from the tree. This configuration would not impede well deliverability, but it would render the vertical tree valves inoperable and severely restrict access to the wellbore. There are numerous other possible kill string configurations but they all suffer similar operational drawbacks. Please contact me if you need any further information. Sincerely, Corn ions Engineer MSBJNDOC S\Ops99\jge 1012 2,500 2,000 1,500 1,000 5OO 0 100 200 300 400 500 600 Gp, (BCF) . '. i~gr~sJon ] Ali ~i~a "~-' R~]i:~SJ~ ]-i,~i'~-7 data PL~. ;'-~aw DataI m :\excertkena~sterling~zster99, xls 6/24/99 ANALYSIS: REQUEST FOR CASING FLOW STERLING 4 GAS POOL WELL KU 43-06A October 1999, File: a-ku43-06a.doc Marathon Oil Company submitted a letter and 10-403 dated September 30, 1999 to remove the tubing strings (two) and packers (two) from their Kenai Gas Field Well KU 43-06A so that gas from the Sterling Pool 4 (SP4) can be flowed up the 7-5/8" casing. The purpose of this request is to increase recovery from a significantly depleted gas pool. The reconfiguration of the well is expected to increase the rate from 7 mmcf/d to an estimated 30 mmcf/d. The Proposal: From Marathon's letter: "Because the Sterling Pool 4 is depleted to roughly 300 psig bottom-hole pressure, the friction pressure drop in the small tubulars is enormous. When well KU 43-06A was converted to annular flow in the Sterling Pool 4 in September 1998, the reduction in friction increased gas deliverability from 3.0 to 7.0 MMCF/D. Similarly, removal of the remaining restrictions could improve deliverability of KU 43- 06a to as much as 30 MMCF/D." The Applicable Regulation: "20 AAC 25.200 (d) All wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced, unless otherwise specifically approved by the commission." Annulus Flow In KU 43-06a: In September 1998 the commission approved flowing the well up the annulus in addition to the 2-7/8" and 2-7/8" tubing strings. The approval was after a determination the gas was not corrosive and the flow stream would not erode the casing. Reservoir Depletion: The original reservoir pressure of the Sterling Pool 4 was 1919 psig. Production from this pool was started in 1965. Since that time KU 43-06A has produced 45 BCF from the SP4 and total production from the pool has been over 430 BCF. The current bottom hole pressure is estimated at approximately 300 psig. Marathon advises that abandonment pressure is approximately 100 psig; therefore they state that the pool is over 90 % depleted. Erosion and Corrosion Problems: The Kenai Gas Field does not have significant problems with either corrosion or erosion and KU 43-06a is no exception. The tubing was last pulled in 1970, at that time there were no indication of corrosion or erosion problems. Since then there have been no problems in KU 43-06a. Sand Production: Sand production in the Kenai Gas Field has been tied to water production and water production has been very Iow. At 300 psig bottom hole pressure and flow thru 7-5/8" casing, it is not reasonable to anticipate gas velocities capable of moving sand up the well bore. At 7 mmcf/d thru the 2-7/8" tubing, sand was not moved up the well bore. Marathon plans to enter the well annually for a pressure survey, this will also locate the top of fill. If sand were moved up the wellbore, erosion would be expected first in the surface lines, providing an opportunity to preclude sand erosion of the casing. Tubing Hanger: Marathon plans to run a tubing hanger and one joint of tubing. The reason for not running the hanger would be so a 5" gun could be run. With no tubing hanger, tree to BOPE swap would require setting a wireline bridge plug. The hanger will be run because the largest gun that SOS has in Alaska is only 4-1/2" and the hanger is cheaper than setting and pulling the bridge plug. Ultimate Recovery and The Economic Limit: A well is abandoned when the reserves are depleted, but this is an economic condition, not a physical one. Additional oil or gas can always be recovered from a "depleted" well, but not profitably and maybe not at "break-even". Therefore, any action that will improve the economics, extends the economic limit and thereby increases the ultimate recovery. For well KU 43-06a, increasing the production rate from 3 to 30 mmcf/d cuts the unit cost of production. Therefore the economic limit is extended and the ultimate recovery from the well (and also the pool) is increased. 1000 KENAI UNIT - STERLING 3 GAS POOL Well 43-06A 100 10 0.1 0.01 0.001 50 _~- ..................................... -1- ........ 30 -:~ ............. ~---,- ..... ~r 20 -~ 1970 71 72 73 7475 7677 78 79 ? ~--' ........ Cum Gas Prod (MMMcf) 8;. 85 '6 87 88 89 90 gl 9, 93'g4 95 ~6 97 g8 99 KENAI UNIT- STERLING 4 GAS POOL Well 43-06A 100 10 0.1 0.01 30 t i I ~-- . .... i ..... 20 q ~, ...... ; ........... ~ -- ' ' ~ ' : i 79 80 81 '1968 69 ' 70 ~ 71 ~ 72 ' 73 74 75 76 77 ~ 78~ Gas Rate (PD) ( MMcf/d ) ........ Water Rate (PD) ( bbl/d ) iIi i ....................................................................... ............... 83 84 8'5 86 87 -- F ....... i ....... ~ q- ....... .,r .......... Cum Gas Prod ( MMMcf ) 8'8 89 90 9'1 9'2 93 94 95 96 97 9'8 99 ARCO Subject File IBy Calculations Chart Sheet number of Date ARCO Calculations Chart Subject File IBy Sheet number of Date Alaska fion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 30, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Reference: Workover of KU 43-6a, Kenai Gas Field Dear Mr. Wondzell: Attached is an Application for Sundry Approval for a workover of Well KU 43-6a in the Kenai Gas Field. As part of this workover, Marathon is proposing that the well be equipped to flow up the 7%" production casing. Although we recognize that this is an extraordinary practice, Marathon believes that in Well KU 43-6a it is a respOnsible and optimal method for increasing gas deliverability. Purpose: The objective of this workover is to increase gas deliverability from the Sterling Pool 4 by removing tubulars and completion equipment that are restricting flow. Because the Sterling Pool 4 is depleted to roughly 300 psi bottom-hole pressure, the friction pressure drop in small tubulars is enormous. When Well KU 43-6al was converted to annular flow in the Sterling Pool 4 in September 1998, the reduction in friction increased gas deliverability from 3.0 to 7.0 MMCFD. Similarly, removal of the remaining restrictions could improve deliverability of KU 43-6a to as much as 30 MMCFD. The attached diagram shows the expected deliverability from Well KU 43-6a if flow occurs up 7%" casing or 5½" tubing. As the diagram shows, even 5½" tubing presents a significant restriction to flow in Well KU 43-6a. Use of 5½" tubing reduces deliverability by 45% compared to flow up the 7%" casing. There is also a cost savings associated with not having to purchase and install 5½" tubing, but cost savings is not Marathon's key reason for making this request. This workover is an attempt to increase well deliverability, and Marathon's primary reason for wanting to flow up the 7%" casing is to maximize deliverability. R [ C ~ [ V [ D A subsidiary of USX Corporation OCT 64 1999 Naska Oil & Gas Cons. Commissior, Anchorage Environmentally aware for the long run. Mr. Blair Wondzell Page 2 September 30, 1999 Concerns Addressed: The following information addresses concems that arise from producing a well up casing, such as corrosion potential and precedent. Corrosion Potential - A recent analysis of the produced gas from the Sterling Pool 4 in the Kenai Gas Field (attached) confirms that there is virtually no corrosion potential. This is consistent with field observation. The partial pressure of carbon dioxide is 0.4 psi which is substantially below the commonly-recognized corrosion threshold. Furthermore, there is no hydrogen sulfide gas produced in the Kenai Gas Field. Erosion Potential - The Sterling Pool 4 does not have a history of sand production. Erosion potential is minimal whether the well is produced up 7%" casing or 5½" tubing, and either is an improvement over the current annular flow status. Peak production up either 7~/~'' casing or 5½" tubing achieves only 40% of the calculated erosional velocity. Pressure Containment - The static bottom-hole pressure of the Sterling Pool 4 is approximately 300 psig (1.4 ppg EMW). The proposed wellhead and tree are rated for 3,000 psi. The well will be equipped with surface safety devices that shut in the well automatically in the event of production upset. Precedent - There is ample precedent in the state of Alaska for allowing flow up the casing as long as safety and engineering concerns are adequately addressed. There are eight wells in the Kenai Gas Field that already flow up the casing in the form of annular flow. The proposal to produce up 7%" casing in KU 43-6a is for all intents and purposes no different than annular flow. Well BC-9s in the Beaver Creek field is not equipped with tubing and packer, and is configured to flow strictly up the casing annulus. Arco operates several wells in the Beluga River Field that similarly flow strictly up the casing annulus. Finally, Well BC-10 in Beaver Creek was issued a Permit to Drill from the AOGCC in February 1998 (permit #98-26). Although never drilled, the approved configuration for Well BC-10 was for a 3½" tubingless completion, i.e. flow would occur up 3½" casing. Your prompt reply to Marathon's request is greatly appreciated. The AOGCC' s decision on casing flow in KU 43-6a impacts the ordering of materials needed to perform this workover. Please contact me if you need any further information. Sincerely, _~ J. 9.'XE!ler Co p~ons Engineer JOE:kgh -~RCO 0 Calculations Chart Sheet number t of Date ARCO Subject File Calculations Chart IBy ~ Sheet number ~. of Date QUALITY (g07~ 56,3-4743 ARCO Calculations Chart Subject File Sheet number of Date , , · ,; i:. . ,. · :. 'fype oi l:(equesL Abandon Suspend Operation Shutdown ~e-enter Suspended Well Alter Casing Repair Well Plugging X Time E~ension Stimulate Change Approved Program Pull Tubing X Variance Pedorate Other , , 2. Name of Operator MARATHON OIL COMPANY 3. Address P.- O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 277' FNL, 4279' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval At Effective Depth At Total Depth 2459' N and 181' E of surface location 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 15 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 43-6a 9. Permit Number 68-51 lO. APl Number 50- 133-20121 11. Field/Pool Kenai Gas Field, Pool 3 8, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5300 feet Plugs (measured) 4565 feet CIBP capped w/14' cement @ 4800' Effective Depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor Surface 1250' Intermediate Production 5289' Liner Perforation Depth: Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented 10-3/4" 1575 sks 7-5/8" 1500 sks ORIGINAL Measured Depth True Vertical Depth 1250' 1195' 5289' 4555' measured SS - A-8:4173' - 4177' MD, A-10: 4270' - 4294' MD, A-11: 4338' - 4370' MD LS - B-1: 4407' - 4457' MD, B-2: 4521' - 4534' MD true vertical SS - A-8: 3614' - 3618' MD, A-10: 3696' - 3717' MD, A-11: 3754' - 3781' MD LS - B-1: 3813' - 3856' TVD, B-2:3911' - 3922' TVD Shortstring: 2-7/8", 6.4~, N-80 tubing to 4130' MD Longstring: 2-7/8", 6.4¢¢, N-80 tubing to 4403' MD Guiberson RH2 dual packer @ 4123' MD Guiberson model A packer ~ 4393' MD Alaska Oit & Gas Cons. Anchorag(.; 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch X , ~ 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 11/20/99 16. If Proposal was Verbally Approved Oil Name of Approver Date Approved Service 17. I hereb~fy that the foregoiN is true and correct to the best of my knowledge. Gas X Suspended Title Production Engineer ~- -~ FOR COMMISSION USE ONLY Conditions of Approval: .~ommission so representative may witness Plug Integrity__ BOP Test ~ Location Clearance~ Mechanical Integrity Test~ Subsequent Form Required 10- ,~_~)~ Date 10/1/99 JApprova, No. ,.~ Cf... /¢~2 Approved by Order of the Commission ORIGINAL SIGNED. BY Robert N. Christenson Form 10-403 Rev. 06/15/88 Commissioner Submit in Triplicate Field: KENAI FIELD Bate: Oct t. t999 Well' KU 43-6a, Po01 4 File: KU43-6A Title: Casing Flow vensus Tub INPUT DATA 400 . 0 , , I I CORN I SH DARCY /~ \~.~ ~q.~j CASED HOLE - I ~'/~' ~g'~ Gas grav 0.5570 ' CO2 O. 05 N2 O. 63 H2S O. O0 ~ ~ Water grav 1.0300 '"~~ Cond-gas ratio 0.00 STB/MMCF r3 300.0 , Wtr-gas ratio 0.30 STB/MMCF' Neas depth 4534. feet ~ TVD 3923. feet ~. Abs Rough 0.00050 in D Pwh 150 psia 03 · 03 ~ Twh 72. Oeg F ~ .- ~ Tbh 93. Deg F L . Res Press 306. psia 0 Drain radius 1440. ft r- ~Net thickness 63, ft · ~ Eff perm 1520. md 4~ Skin 5.00 ~>'~ "~%1~' ~.~ Wellbore radius 4.8 in .. Shot density 12.00 SPF _ Tunnel length 7.0 in - Perf dim 0.33 in CZ k/Res k 0.400 Turb coef 1.057E+07 1/ft ~00.0 ~ O. ~0000. ~0000. 30000. 40000. 50000. Gas Rate, MCFD Tubing d~ameteP ~ A 4.B92 inches ~ C 6.765 inches t-~s/~--~..~ RT-GL: 12.0' 217' S & 4279' E of NW Comer See. 7, T4N, R 11 W Shortstring Tog: 2-7/8", 6.4//, N-80, Special clearance Butt. 0' - 4058' 2-3/8", 4.7//, N-80, Butt. 4058' - 4130' Crossover to 2-3/8" tbg (~ 4055' Otis "XO" Sliding Sleeve (~, 4056' ID = 1.875" (Sleeve opened 9/2/98)-' Hol6S'shot in 2-3/8" tubing (fi) 4089' (9111/98)' Guiberson RH-2 Dual Packer (~ 4123' Otis "N" Nipple (~ 4130' ID-- 1.791" PN.Plug set 9/9/98 : Shortstrino Perfs 4106'- 4107' (Sqzd) A-8 4173'- 4177' (1111/70) A-10 4270'- 4294' (1111/70) A-I 1 4338'- 4370' (11/1/70) .Lon~strin~ Perfs B-1 4407' - 4457' (4,spf, 9/5/68) B-2 4521'- 4534' (4 spf, 9/5/68) B-5 4930' - 4956' (isolated by CIBP) 10-3/4", 40.5//, J-55, Annco SealLock Casing ~ 1250' Cmt w/1575 sks of Class O Otis "XO" Sliding Sleeve ~4084' ID-' 2.313" i - Sleeve op~ ed for annular flOWg/30198; ~ .:..:: c' '.'< · . . -~. - ~ . :. Longstring Tubing: 2-7/8", 6.4#, N-80, Special clearance Butt. ' Blast Joints (3-3/4" OD) 4165'- 4185' 4261' - 4302' 4333' - 4373' Otis "XO" Sli,?ng SleeVe ®4374' ID= 2.313 Type "P" Landing Coupling ~ 4392' Ouiberson "A" Packer 1~ 4393' Otis "N" Nipple ~ 4401' ID -- 2.205" Muleshoe (~ 4403' TD (q) S300' Fill: 4531' MD (9/18/99) Fish: Baker "K" bridge plug (~ 4786' Howeo EZ CIBP ~ 4800' capped w/14' cement Fish: Howeo EZ bridge plug ._ 7-5/8", 26.4//, J-55, LTC Casing ~ 0' - 1140' 7-5/8", 33.7//, N-80, LTC Casing ~ 1140'- 5289' Cmt w/1500 sks of Class O Last Rev: JGE, 10/1/99 WELL KU 45-6A- AFE 9204499(?) KENAI GAS FIELD PULL TUBING, FLOW UP 7%" CASING Objective: Perform a workover on well KU 43-6a to allow the Sterling B-1 Sand to produce up the 7%" casing to increase deliverability. Procedure: 1. M1RU slickline on KU 43-6al. Test lubricator and BOPs to SITP. RIH with shitting tool for 2.313" Otis XO sliding sleeve. Shift the XO sleeve at 4084' into the closed position. POOH, RDMO slickline. 2. M]RU pump truck on KU 43-6al. Mix 500 bbl of 3% KCI. Bullhead a slurry with 3900 lbs of 20/40 sand down the longstring. Displace sand plug with 3% KCI. Load the iongstring tubing with 3% KCI. 3. RU pump truck on the casing of KU 43-6a. Load the casing with 3% KCI while taking returns onthe shortstring tubing. RDMO pump truck. 4.-MIRU electric line on KU 43-6al. Test BOPs and lubricator to SITP. RIH with chemical cutter for 2%" tubing. Tie in with CCL and make chemical cut at ~4150' MD. POOH. RU on shortstring, test lubricator to SITP. RIH with chemical cutter for 2%" tubing. Tie in with CCL and make chemical cut at --4113' MD. POOH, RDMO electric line. 5. Install BPVs in shortstring and iongstring tubing hangers. 6. MIRU workover rig. ND tree, NU and test BOPs. Pull BPVs. Establish circulation down SS tubing with 3% KCl. Be aware of probable lost returns in open Sterling Sands. 7. Pull and lay down SS tubing. Attempt to p~ull and lay down Guiberson model RH2 dual packer on LS tubing. If unable to pull packer, make tubing cuts to retrieve 27/d' tubing down to the dual packer. Lay down 2?/8" tubing. 8. Change pipe rams to accommodate 3 ~A" work string. Retest BOPs. Install wear bushing. PU string of 3 ½" work pipe (13.3 ppf, S- 135, IF, non-hardbanded). 9. If the dual packer is still in the hole, burn over and retrieve the dual packer along with 2~'/d' tubing down to the model A packer at 4393'. 10. TIH to top of model A packer at 4393'. Circulate hole clean. Lay in a cement plug from 4393' to 4073'. PU out of cement, close rams, and apply hesitation squeeze on Sterling A Sand perfs (4173! - 4370'). Circulate clean, TOH. Well KU 43-6a Puli Tubing, Flow Up 7%" Casing Page 2 11. PU 6~A'' bit and TIH. Drill cement down to top of the Guiberson model A packer at 4393'. Test squeeze to 400 psig at surface. TOH. If test fails, resqueeze as necessary. 12. PU burn shOe and TIH. Burn over model A packer at 4393' MD. TOH, LD packer. Be aware of possible lost returns in the Sterling "B" Sand perfs (4407'-4534'). Apply LCM as needed. 13. PU 6½" bit and TIH to bottom. Clean out sand plug and fill to 4700' applying LCM and gel sweeps as needed. TOH laying down work string. Pull wear bushing. 14. PU tubing hanger, land, and test. Install blanking plug, ND BOPs and NU 7-1/16", 3M tree. Test void. 15. RDMO workover rig. 16. MIRU coil tubing and nitrogen. Test lubricator and BOPs to 1500 psig. Pull blanking plug. RIH with coil tubing to 4600' CTM. Jet well dry using nitrogen. ' · ~-' 17. MIRU electric line. Test BOPs and lubricator to 1500 psig. RIH with 5", 12 spfHSD guns. Tie in with GR/CCL. Perforate the Sterling B-1 Sand from 4407'- 4457' with maximum. underbalance. POOH, RDMO electric line. ~'::' 18. Flow well KU 43-6a as per instructions of Production Foreman. JGE September 30, 1999 N:~DRLG'~KGFkWELL S~Ku43-6~lk9204499~big_t bg WPD Marathon Oil Well KU 43-6a Choke Manifold Gas Buster ITo Blooey Line IBleedoff Line to Shakers I 2 9/16" 10M Swaco Hydraulically Operated IFrom BOP Stack Choke 3 1/8" 5M Manually Adjustable Choke Marathon Oil Well KU 43-6a BOP Stack JFIow Nipple JFIow Line J J J135/8" 5M Annular Preventer J J135/8" 5M Double ?~ r Ram Preventer J. . J :~ 1/8- 5M Manually J J-'~ Operated Valves I~ s~-~= c~o~ ! JPipe Ram J J Blind Ram J J13 5/8" 5M~Single Ram Preventer JPipe Ram j anua,,,! Operated Valve '..j~ ,, ~ '. - .' .: g:~cmnldrlg~kgftwell$~ku43-Sal~AOGCCOl A.xJ$ STATE OF ALASKA ~-~ ALASK/~-OIL AND GAS CONSERVATION Cu,dMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulatem Pluggingm Perforate Pull Tubing Alter Casing m Repair Wellw Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well 'at Surface 277' FNL, 4279' FWL, Sec. 7, T4N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory, Stratigraphic Service At Effective Depth Convert to Annular Flow At Total Depth 2459' N and 181' E of surface location Datum Elevation (DF or KB) 15 feet 7. Unit or Property Name Kenai Unit 8. Well Number KU 43-6AI 9. Permit Number 68-51 10. APl Number 50- 133-2012~ 11. Field/Pool Kenai Gas Field, Pool 4 12. Present Well Condition Summary Total Depth: measured true vertical 5300 feet Plugs (measured) 4565 feet ClBP capped w! 14' cement {~ 4800' Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 1250' 10-3/4" 1575 sks 5289' 7-5/8" 1500 sks B-1: 4407' - 4457' MD, B-2: 4521' - 4534' MD Measured Depth True Vertical Depth 1250' 1195' 5289' 4555' true vertical B-1: 3813' - 3856' MD, B-2:3911' - 3922' MD Tubing (size, grade, and measured depth) 2-7/8", 6.48, N-80 tubing to 4403' MD Packers and SSSV (type and measured depth) Guiberson RH2 dual packer ~ 4123' MD Guiberson model A packer {~ 4393' MD 13. StimUlation or Cement Squeeze Summary RECEIVED OCT t,L; Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. RepresentAtive Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 2990 0 0 110 unknown, not yet tested 16. Status of Well Classification as: Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe ~ , J. Gary Eller Title Production Engineer Form 10-404 Rev. 06~ ~.~ Suspended __ Service Date 10/1/98 Submit in Duplicate Kenai Gas Field Well KU 43-6A, Pad 41-7 Marathon Oil Co., Alaska Region RT-GL: 12.0' 217' S & 4279' E of NW Comer Sec. 7, T4N, RI lW Shortstring Tbg: 2-7/8", 6.4#, N-80, Special clearance Butt. 0' - 4058' 2-3/8", 4.7#, N-80, Butt. 4058' - 4130' Crossover to 2-3/8" tbg @ 4055' Otis "XO" Sliding Sleeve @ 4056' ID = 1.875" (Sleeve opened 9/2/98) Holes shot in 2-3/8" tubing @ 4089' (9/11/98) Guiberson RH-2 Dual Packer 6 4123' Otis "N" Nipple 6 4130' ID = 1.791" PN plug set 9/9/98 Shortstring Perfs 4106' - 4107' (Sqzd) A-8 4173'- 4177' (11/1/70) A-10 4270'- 4294' (11/1/70) A-11 4338'-4370' (11/1/70) Longstring Perfs B-1 4407'- 4457' (4,spf, 9/5/68) B-2 4521' - 4534' (4 spf, 9/5/68) B-5 4930' - 4956' (isolated by CIBP) TD 6 5300' 10-3/4", 40.5//, J-55, Armco Sea[Lock Casing 6 1250' Cmt w/1575 sks of Class G Otis "XO" Sliding Sleeve 64084' ID= 2.313" Sleeve opened for annular flow 9/30/98 Longstring Tubing: 2-7/8", 6.4#, N-80, Special clearance Butt. Blast Joints (3-3/4" OD) 4165' - 4185' 4261' - 4302' 4333' - 4373' Otis "XO" Sliding Sleeve 64374' ID = 2.313" Type "P" Landing Coupling 6 4392' Guiberson "A" Packer 6 4393' Otis "N" Nipple ~ 4401' ID = 2.205" Muleshoe 6 4403' Fill: 4540' WLM (3/31/95) Fish: Baker "K" bridge plug 6 4786' Howco EZ CIBP ~ 4800' capped w/14' cement Fish: How¢o EZ bridge plug Fill @ 5217' ELM (11/4/97) 7-5/8", 26.4#, J-55, LTC Casing 6 0'- 1140' 7-5/8", 33.7#, N-80, LTC Casing @ 1140' - 5289' Cmt w/1500 sks of Class G Last Rev: JGE, 10/1/98 Alaska R~.=,on Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-6204 Fax 907/283-6175 August 12, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Lo .os'/ Reference: Annular Flow Conversion of KU 43-6A1, Kenai Gas Field RECEIVED 2 0 1998 Null 0il & Gas Cons. Anchorage Dear Mr. Wondzell: I am providing you with further information about the squeeze perforations at 4106' MD in well KU 43-6A1 in the Kenai Gas Field. These squeeze perforations are above the dual packer, and you have expressed concern about the integrity of these squeeze perfs and their potential to impact production from well KU 43-6A1 following its' annular conversion. I trust that the following information will alleviate your concerns. History_ The 7%" casing in well KU 43-6A was perforated at 4106' MD on October 28, 1970 in order to perform a block squeeze. The hole was full of 10.2 ppg mud at the time. The first squeeze attempt on October 29 using 90 sacks of cement was unsuccessful. A second squeeze job on October 31, 1970 using 38 sacks of cemem was successfully tested to 700 psig surface pressure (14.0 ppg EMW). There has been no indication of these squeeze perfs having broke down any time since. Annular Procedure The annular conversion procedure for KU 43-6A1 is written to minimize stress on the squeeze perfs and to minimize risk. Step #1 of the conversion procedure calls for the 7%" casing to be tested to 400 psig using nitrogen, which will test the squeeze perfs from 440 psig to 1950 psig (depending on the fluid level in the annulus). The static bottom hole pressure of the Sterling B- 1 and B-2 Sands in KU 43-6A is only 320 psig. Therefore the initial pressure test exceeds the pressure that the squeeze perfs will be exposed to following the annular conversion. A subsidiary of USX Corporation HUb 1," ' '~ 11; 1~ I~'IHKI"-I I HUrl KI~I- Oil Corr~pan'¥ ',4. ena] Gas Field P,O, Box 9,949 ~ana], AK 99611.-1949 TeJephone (907) 253-8205 Fax (907) 2~3-.6'J75 .Fax :~ova r.. heet TIME' TO: NAME: PHONE: PAGES SENT (Including Cover Sheet) ~-/21.Response Requested [ ] lmmedia[e REMARKS: [] Informa"dont[ttl~/1 2 1998 Oil & G~m C, on~. CommimWon I-IU~ J.r' ' 'JlJ 11 ; r'ld I'IHI~H I IJUI"I /~'"~'N~ Alaska R~ ,n Domestic J:-Voduc'5on P.O. Box 1949 Kenai, AK 99.811-1949 Tele,oho/'~e 907/283-.6204 .Fax 907/283..8175 A ug.us'[ 12, '] 998 'Mr. Blair Wondzcll Alaska Oit & (}as Coaservation Commission 3001 Porcupine Drive Anchorage, Air,,. 99513-7599 ReFerence: Annular l;low Conversion oI'KU 43-6A1, Kenai ""' Gas Field Dear Mr. Wondzell' 'I am providing you with further in:fbrmation about the squeeze pcrlbradoas at 4106' MD h-t well 'K.'U 43-6At ~'a d~e Kenai Oas f;ield. These squeeze berforations are aboYe 'd'~e dual packer, and yo'a have expressed concern about the integrity oF'd.;tese squeeT, e perfs and 'their potemial to A impact proc'luction 'f. rott:t well K'[.,r 4_3-6A1 }~>]lowhlg its' ~mnu]ar coavcrsion. I trust 'that the J:ollowizlg ]nl'orrQatiorJ will al]e¥iato your COllCerns, The 7%" casing in well Ki,r 43-6A 'was pertbrated a~: 4106' MD on Octol, er 28, 1970 in order pedbn'r~ a block squeeze. The hole wz',s :Etll o2' 10.2 ~pg mad at the dine. The firsl squeeze attempt on October 29 using 90 sacks of cement wa~ uns'uccessFal. A second squue7~ job on I , ,. tJ¢.~ace pressure October 31 3970 using 38 sacks of ceme'nt was suc~csslL1]y testect 're 700 psig s' ( 14.0 ppg EMW). There has been no indication of these, squeeze per:f;s havin8 broke down ti me since. I Ama elm' Procedure / .~ Thc annular conversion procedure t~r E(.I &~-6AI is'written, to minimize stress on the squeeze peris and lo minirMze risk. Step ¢1 of d'~e conv'crsqtin procedure calls lbr dae 7%" casing to bc tested 'm 400 psig using nitrogen., which will test th(~ squeeze perf']s ./:~om 440 psJg to 1950 psig (depending on 'the fluid level in '~o annulus). Thc s[auc bottom hole pressure of the Ste. rhn~ ~md B-2 Sands i'a KU 43-6A is only 320 psi$. Ther~lfore the initial pressure 'test exceeds pressure t'har 'the sq~'¢eeze perfs will be exposed to 'E'llowing the zmn'aI~ conversion. A subsidiary of USX Oorpora~ion AUG- ] ~lU~ J.C_ ' ~l:i J..L ~ r'-I~l I'IHt~H I I-lUl't I/,,bl- WcJl ~U 43-6A1 A'u§usi 12, 1998 P~ge 2 Most of tho process to remove '~hc packer fluid will ibc perFormed 'via ~he shortstring ~:ubing_ Th. is is done so '~l'~ftt il' ~he sq'tmoze perfs 'anexpec'tedly break down d'urJng conversion i~ wi ti no'~.joopm-dize '~he acI2v¢ longstdng completion. ()n]y a.ftet 'the paoker fl'ukts lmv¢ been rm-noved and tho inmgrky offhe squeeze ~pert.~s has boen ve, ri/'iod will ~he lm2gslring be opened (procedural step 10 c)l' '12), Please contact me iF'further inlbrma'/ion is needed. ~ hope to commence this wot. l<. on Monday, August i 7., st) your prc)mpt attention is ~ppreciated. AUG- 1 2 lgg8 Alaska r,~gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 5, 1998 Mr. Blair Wondze!! Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Kenai Gas Field - Annular Flow Conversion Dear Mr. Wondzell' As per your request, attached is a review of potential problems associated with converting Wells KU 11-8s, KU 24-5s, and KU 43-6AI at the Kenai Gas Field to annular flow. As the analyses show, Marathon does not anticipate that these conversions will cause undue stress, corrosion, or erosion on the production casing strings. Sincerely, A~d Pr0du~ion Engineer JGE:kgh Attachments RECEIVED AUG GG 1998 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. WELL KU 43-6A1, KENAI GAS FIELD ANNULAR FLOW CONVERSION POTENTIAL PROBLEMS ADDRESSED This conversion will allow gas from the Sterling B-1 and B-2 Sands (Pool 4) in well KU 43-6A1 to be produced up the 2%" tubing and 7%" casing simultaneously. This is expected to increase gas deliverability at a low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Erosional Velocity Corrosion Surface Safety Controls Burst/Collapse of Casing Solution The highest potential for erosive flow exists at the 2-1/16", 5M flanged outlets of the tubing head. Flow will be out both outlets of the tubing head to reduce velocity. Erosion could potentially occur if flow out the annulus exceeds 12 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Partial-pressure of COz is less than 1.0 psi. If the partial pressures of CO2 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Pressures imposed on the 7%" casing during this procedure will not compromise the integrity of the casing. Worst-case forces will not exceed 26% of the rated casing burst or collapse. The squeeze perfs above the dual packer (4106' MD) will be pressure tested to maximum anticipated shut-in pressure. The procedure is written so that the productive longstring completion will not be jeopardized if the squeeze perfs unintentionally break down. O:~EXCEL ~og¢cOI .xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Re-enter Suspended Well Alter Casing ~ Repair Well Plugging ~ Time Extension Stimulate Change Approved Program ~ Pull Tubing ~ Variance Perforate Other X 2. Name of Operator 5. Type of Well: 6. Datum Elevation (DF or KB) MARATHON OILCOMPANY Development X 15 feet 3,. Address Exploratory 7. Unit or Property Name P. O. Box 196! 68, Anch .orage., AK 99519.~6168 . , Stratigraphic Kenai Unit 4. Location of Well at Surface Service 8. Well Number 277' FNL, 4279' FWL, Sec. 7, T4N, R11W, S.M. KU 43-6al At top of Productive Interval 9. Permit Number 68-51 At Effective Depth Convert to Annular Flow ~0. APl Number 50- 133-20121 At Total Depth 11. Field/Pool 2459' N and 181' E of surface location Kenai Gas Field, Pool ,~ .- _ _ 12. Present Well Condition Summary V Total Depth: measured 5300 feet Plugs (measured) CIBP capped w/14' cement ~ 4800' ~ k L ~ I true vertical 4565 feet ,, Effective Depth: measured feet Junk (measured) true vertical feet Alaska 0il & Gas Cons, Anchorage Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface 1250' 10-3/4" 1575 sks 1250' 1195' Intermediate Production 5289' 7-5/8" 1500 sks 5289' 4555' Liner Perforation Depth: measured B-1: 4407' - 4457' MD, B-2: 4521' - 4534' MD true vertical B-l: 3813' - 3856' MD, B-2:3911' - 3922' MD Tubing (size, grade, and measured depth) 2-7/8", 6.4,9, N-80 tubing to 4403' MD Packers and SSSV (type and measured depth) Guiberson RH2 dual packer {~ 4123' MD Guiberson model A packer @ 4393' MD 13. Attachments Description Summary of Proposalm Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 8/5/98 16. If Proposal was Verbally Approved Oil Gas X Suspended ~ Name of Approver Date Approved Service i 7. I hereby c~rtify that the foregoing is. true and correct to the beast of my knowledge. Signed '~ ,~~~,~ ,.. Title Production Engineer Date 7/30/98 ~X ' - X~ - - FOR COMMISSION USEONLY ConditionsofApp'te~v~:'' Notify'Seml'nission so representative maywitnessL _ ,. iApproval N,,~~ '"*~// Plu!~"lntegrity --~..~._' BOP Test Location Clearance Mechanical~lntegrit, y Test Subsequent Form Required 10- ~trO~ 5 -- Approved by Order of the Commission original Signed BY ., ~,,ka~.nn Commissioner Date Form 10-403 Rev. 06115188 [)aVlkl ltv. ~u,,, ...... S~6m'it n Triplicate ED Approved Copy Ret ned Well KU 43-6A1 Kenai Gas Field August 12, 1998 Page 2 Most of the process to remove the packer fluid will be performed via the nonproductive shortstring tubing. This is done so that if the squeeze perfs unexpectedly break down during the conversion it will not jeopardize the active longstring completion. Only after the packer fluids have been removed and the integrity of the squeeze perfs has been verified will the longstring be opened (procedural step 10 of 12). Please contact me if further information is needed. I hope to commence this work on Monday, August 17, so your prompt attentio_n is appreciated. ~ ~x,?x~,Singerely, ~~ J.G{ El r Pro~n Engineer Alaska R, ,: Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 28, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Kenai Gas Field, Wells KU 11-8s, KU 24-5s, and KU 43-6al Dear Mr. Wondzell: Please find attached procedures for permitting annular flow in wells KU 11-Ss, KU 24-5s, and KU 43-6al in Kenai Gas Field. The increased flow area by producing up the production casing and tubing simultaneously is expected to double the well's gas deliverability. Flow up the production casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. This work is expected to commence early August 1998. Please contact me if further information is needed. J.~ G.'~Eiler P r"0d~ti o n Engineer M:~WI~OPNS98~JGE728, Enclosure A subsidiary of USX Corporatior', Environmentally aware for the long run. WELL KU 43-6al- AFE 0482398 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective: Allow floTM up the tubing-casing annulus in well KU 43-6al to increase gas deliverability. Procedure written to minimize pressure applied to squeeze perfs above the dual packer. Procedure: 1. MIRU nitrogen unit on KU 43-6a. Using nitrogen, pressure test 7%" casing to 400 psig. Monitor 10%" casing for potential communication. When test is complete, bleed all pressure off 7%" casing. 2. When casing is completely bled down, remove blind flange on tubing spool across from the existing 7%" casing valve. Have the existing casing valve open to atmosphere while performing this operation. If applicable, remove VR plug from the new outlet. Install a newly tested 2-1/16", 5M gate valve on the outlet. When that valve is completely installed, pull offthe old 2-1/16", 5M gate valve and replace it with one that is newly tested. Send old gate valve in for testing. Close both gate valves when complete. 3. Shut in both sides of well KU 43-6a. MIRU slickline on KU 43-6as. Test BOPs and lubricator to SITP. Set PN plug in N nipple (ID = 1.791") at 4,130' MD. RDMO slickline. 4. RU pump truck on KU 43-6as. Load tubing with fresh water and test PN plug to 500 psig. When complete, do not bleed pressure off of tubing. RDMO pump truck. 5. MIRU slickline on KU 43-6as. Test lubricator and BOPs to SITP. MU tool string with XO shifting tool, spang jars, & oil jars. RIH and locate XO sliding sleeve (ID = 1.875") at 4056' MD. Shift open sliding sleeve at 4056' MD while monitoring tubing and casing pressure. POOH. Note: If volume of nitrogen pumped in step #1 indicates fluid level in annulus is low, skip steps #6, #7, and #8. 6. RIH and pull PN plug at 4130' MD. POOH, RDMO slickline. 7. Allow several days for fluid in tubing and annulus to leak off into short string perfs. 8. MIRU slickline on KU 43-6as. Test lubricator and BOPs to SITP. Set PN plug in N nipple (ID = 1.791") at 4,130' MD. POOH, RDMO slickline. 9. RU nitrogen unit on 7%" casing of KU 43-6a. Pump nitrogen down casing, taking fluid returns on shortstring tubing to catch tank. Do not exceed casing test pressure. Continue until nitrogen is blowing around the tubing. RD nitrogen. Well KU 43-6al Convert to Annular Flow Page 2 10. MIRU slickline on KU 43-6al. Test BOPs and lubricator to SITP. MU tool string with XO shifting tool, spang jars, & oil jars. RIH and locate XO sliding sleeve (ID = 2.313") at 4084' MD. Shift open sliding sleeve at 4084' MD while monitoring tubing and casing pressure. POOH. 11. As soon as possible, produce well at maximum flow rate up tubing to clear any residual packer fluid from wellbore. Put well in test separator, and record flow rate and tubing pressure. 12. Shut in KU 43-6al. Install flowline to produce out both sides of the tubing head on KU 43- 6al. When complete, flow casing side and tubing side simultaneously to test separator and compare with previous test. When testing is complete, produce as per instructions of Production Foreman. JGE N:~DRLG~KGF~WELLS~u43-6aI'uMxINFLOW2.WPD Kenai Gas Field Well KU 43-6A, Pad 41-7 Marathon Oil Co., Ala.ska R egion RT-GL: 12.0' 217' S & 4279' E of NW Comer Sec. 7, T4N, R11W Shortstring Tbg: 2-7/8", 6.4#, N-80, Special elegance Butt. 0' - 4058' 2-3/8", 4.7#, N-80, Butt. 4058' - 4130' Crossover to 2-3/8" tbg @ 4055' Otis "XO" Sliding Sleeve ~ 4056' ID = 1.875" 10-3/4", 40.5#, J-55, Armco SealLock Casing @ 1250' Cmt w/1575 sks of Class G Otis "XO" Sliding Sleeve 84084' ID= 2.313" Guiberson RH-2 Dual Packer ~ 4123' Otis "N" Nipple @ 4130' ID = 1.791" Shortstring Perfs 4106' - 4107' (Sqzd) A-8 4173'- 4177' (11/1/70) A-10 4270'- 4294' (11/1/70) A-11 4338'-4370' (11/1/70) Longstring Tubing: 2-7/8", 6.4#, N-80, Special clearance Butt. BlastJoints(3-3/4" OD)4165'-4185' 4261'-4302' 4333'-4373' Otis"XO"Sliding Sleeve@4374' ID= 2.313" Longstring Perfs B-1 4407'- 4457' (4,spf, 9/5/68) B-2 4521'-4534' (4 spf, 9/5/68) B-5 4930' - 4956' (isolated by CIBP) 300' Type "P" Landing Coupling ~ 4392' Guiberson "A" Packer ~ 4393' Otis "N" Nipple ~ 4401' ID = 2.205" Muleshoe @ 4403' Fill: 4540' WLM (3/31/95) Fish: Baker "K" bridge plug @ 4786' Howco EZ CIBP @ 4800' capped w/14' cement Fish: Howco EZ bridge plug Fill @ 5217' ELM (11/4/97) 7-5/8", 26.4#, J-55, LTC Casing @ 0' - 1140' 7-5/8", 33.7#, N-80, LTC Casing ~ 1140'- 5289' Cmt w/1500 sks of Class G Last Rev: JGE, 7/30/98 Form P--3 ~ S~lbmft "Intentions" in ~pli~ ~ 9-~9 ~ "Su~q~ent Repo~s" STATE OF A~KA OIL AND GAS CONSERVATION COMMI~EE ~UN~Y NOTIC'E~ AND ~EPO~T5 ON W~ use "AP~biCA~[ON '~O~ peltrY" ~or ~uch NAM~ O~ OP~O~ U~on 0~ Conpnny o~ Cn~[ffor~[n [enn~ Unit .,, ] ~v ADDreSS O~ OP~A~O~ ~OCA~[ON O~ W~ ~0. ~ ~D ~OO~, O~ WI~ .~k~R: Ee~a$ Gas FSeZd FILE: .t~,-~ 277'S & 4279'E from ~-~r~eF- S~~ ~,~tT4N, ll. SEC.,T.,R.,M., (BO~OMHO~ " ' Sec. 6, T4N, RllW, SM. 13. ELEVATIONS ($ RT 14' 14. Check ~ppropriate Box To ],ndk~teNat'ure of N~ti'ce, Re NOTICE OF INTENTION TO: i TEET WATER EHUT-OFF PULL OR ALTER CA~ING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS /Other) 68-51 ~ort, or Other D~a rRACTrRE TRE*T"ENT.:.. ~-.--~-~-- ALTERZ~ CASX.~O ~X 8HOOTING OR ACIDIZINO ~ [ ABANDONMEKT* (Other) Recompze[zon , , (~o~=: Report reaulta of multiple completion oa Well ~ompletion or Reeompletton Report and Lo~ form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and gh'e pertinent dates, including estimated date of starting any proposed work, Kenai Unit 43-6Awas originally dually completed in Pool 4 (B-1 & B-2 sands) and Pool 5.2 (B-5 sand). The lower interval (Pool 5.2) was shut in due to sand production and could not be produced. It was proposed the well be recomp!eted as a dual in the Pool 3 & Pool 4 intervals. This work was completed as follows: 1. Santa Fe Drilling Co. move in& rig up 12:00 Noon 10/23/70. 2. Kesumed oper.~t%ons @ 12:00 Noon 10/24/70. Open sleeve in long string between pkrs @ 4857' & above top dual pkr @ 4342'. 3. Circ out gas with water down long string i out annulus & short string. Displace water w/80# per tn.ft, mud, killing well. 4. Remove tree & install 8" 3000# BOE. 5. Pull 2-7/8" short string. Attempted to pull pkrs & long strin$ free. No success. Worked tbg to 130,000#. 6. Ran Dia-Lo§ free point locator. Found tbg free to 1st joint above btm single pkr. While free-pointing/w/lO8,000# tension, top dual pkr parted 18" from the top. Pulled tbs & dual pkr stub. 7. Attempted to stab into pkr receptacle, no success. Ran jet cutter, no success working ~."into pkr. Ran Dia-Log bottom shot (2" x 6'), work into pkr. Fire shot in long string @ 4832' to blow tbg in two. Form tAE, V. 9-30~9 ,p Swbmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATIO.N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR PEiI~iT-2-~' 'for such 'pi~o~osalsJ . . . WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. Check Appropriate Box ~o In~i~ Nal~ ~ ~fice, Re~, or ~bsr ~ Page Two 5. AP1 N~CAL CODE i , 6.LEASE DESIGNATION AiND SERIA~ NO. ?. IF IN-DIA/~, ALLOTTEE OR TRIBE NA/VLE 8. UNIT, FAHA~ OR LEASE NAME 9.WELL NO. KU 43-6A W.0. 10. FIELD A~D POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERM. IT NO. NOTICE OF INTENTION ~0: · ~s~ ~ATER ~'RACTVBE TRE*T REPAIR WELL PULL OR ALTER CASING M ULTIPL~ COMPI,ETE ABANDON' CHANG~ PLAN~ Other) ' I WATER SItUT-OFF I [ REPAIRING 'ELL FRACTURE TRIATMINT ALTERING CASINO SHOOTING OR ACIDIZ~NG ~ ABANDONMENT$ (Other) (NOTE: Report results of multiple completion on Well Completion or Ret@repletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and gh'e pertinent dates, including estimated date of starting any proposed work. , , 10. 11. 12. 13. 14. 15. 16. 17. SIGNED I/I (/~. (This space f~l Ran spear & caught pkr. Pulled and recovered all fish including both dual & bottom single pkr. Shot had split tbg i knoa~ked lower pkr loose. Dresser-Atlas set Howco BP @ 4800', isolating B-5 sand, Pool 5.2. Placed 14' cml (3-1/2 si) on top of plug w/dump bailer. Top cml plug @ 4786' Set Baker model "K" BP on wAr.line @ 4150'. Perforate four 1/i" holes above "A" zone for block sqz @ 4106'. Ran RTTS tool & sqz cmtd perfs @ 4106' w/150 sx Class'"G" cml in two Jobs. Max press 1000#, held. OK. CIP @ 4:00~m 10/30/70. WOC 18 hrs. Drilled out cml 4035'-4120', BP @ 4150', & cleaned out to 4780'ETD. Layed down 3-1/2" drill pipe. Dresser-Atlas perforated Middle Kenai "A" zone, Pool 3, four 3/8" hpf from 4173'-4177', 4270'-4294', 4338'-4370'. Set Guiberson production pkr by wit,line @ 4393'. Ran dual 2-7/8" 6.4# N-80 buttress now-upset tbg, long string stabbed into production pkr @ 4393' w/Guiberson dual hydroset pkr @ 4123' & short string stabbed into dual pkr @ 4123'. Removed BOE & installed tree. Displaced mud w/wtr. Tested btm production pkr OK. Set top dual pkr & tstd OK. Flowed both long and short string to clean up. Long String SIP 1600# & Short String SIP 1500#. RIG RELEASED @ 4:00 PM %%.~2/?0~. Lon~ Strini flowing from B-1 & B-2 Sands, Pool 4. Short Strin~ flowing from A-8, A-10, A-II Sands, Pool 3. APPROVED BY CONDITION~ OF iPPROYA~,IF true and correct /~ TITLE Dist. Drlg. Supt. 11/5/~0 TITLE DATE See Instructions On Reverse Side Approved Copy Returned Form P~3. . ~."~ Submit "Intentions" in Triplicat~ ~, 9.-~7 * ~ & "Subseauent Repo~s" .' STATE O,F A~KA OIL AND GAS CONSERVATION; COMMI~EE SUN'~Y NOTICES AND REPORTS ON W~ (~ not ~ t~is ~o~ ~o~ p~oposa~ ~drH~ o~ to deepe~ o~ pl~ back to a di~fle~ent ~e~. ~ "~uc~o~ ~o~ ~T--" ~o~ ~h ~po~,~.) A-028142 0IL W~L~ ~ OTHER "'~. H~ OF OP~TOR 8. UNIT, F~ OR ~SE NAME Union Oil Compan~ of .Califor~ Kenai Unit ~ ~ss o~ O~rO~ : ~, Wm~ ~0. 909 W. 9th Ave.~ Anchorage, Ak. 99501 ~ KU 43-6A Atsurface 2~7'S & 4279'E from ~ cOrner Section 7, RllW, SM. (Drilling Island il) O~E~IVE) Sec. 6, T4N, RllW, 13. ELEvATIoNs (Show whether DF, RT, GR, etc. 12. P~T ~O. RT 14' 68-51 14. Check Appropriate BOx To i~ndi'cate NJature of N~ofiCe, Re ~ort, or :Other D~ta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~--~ PULL OR ALTER CASINO SUBSEQUENT REPORT OF: FRACTURE TREAT [__] MULTIPLE COMPI,ETE FRACTURE TREATMENT ALTERING CASING REPAIR WELL CHANOE PLANS (Other) (Other) Recomplete (NOTE: RePort results of multiple completion on Well' Completion or Recompletlon Report and Log form.) 15. D~:SCRIBE I'ROPOSEO OR CO.~fPLETED OP~,RATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting pro~sed work. Eenai gnat 43-6A is d~lly completed in Pool 4 (B-i and B-2 Sands) and poOl 5.2 (B-5 Sand). The lower interval is currently shut in.:due to sand production and cannot be produced. It is reco~ended that 43-6A be recompleted as a dual in the Pool 3 and Pool 4 Intervals. PLAN OF PROCEDURE: 1. 2. 3. 4. . . . 10. 11. ,J Move in Santa Fe Rig, kill well w/80#/ft3 mud. Install & test BOE. Pull dual tbg strings. Set. cast iron retainer @ 4650'+-. Top w/cmt for abandonment of the Pool #5 Interval. Set magnesium BP @ 4150'+-. Perf 4 holes @ 4106" for block sqz to eliminate top wtr entry into the Pool 3 Interval. Sqz. DO & test to 2000#/min' Perf Pool #3 Iaterval as follows with four 1/2'" hpf: 4173'-4177' 4270'-4294', 4338'-4370' 9 ' CO to abandonment plug @ 4650'. Re-run dual tbg strings w/dual pkr above Pool 3 Interval, and single pkr between the Pool 3 and Pool 4 Intervals. Set pkrs & flow well for clean up. Rig Down and Move Out. ESTIMATED STARTING DATE: CO~DITiOHS OF APPROVAL, IF October 15, 1970 true Rnd corre~ TITLE DIVISION OF OiL AHD GAS TITLE Dist. Drlg, Supt. DATE .. DATE See ~nstrucfions On Reverse Side 9115/70 Approved Copy Returned Form 4-330 (Rev. 5-63)* - uNITED STATES DEPARTMENT OF THE INTERi;OR (SeeotheriB-structionson ' reverse side) GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. T.YPE OF'WELL: ....... ~VELLOiL ..... ~r-'] .... WELLGA'S ~[~--' DRY [~] Other b. TYPE OF COMPLETION: NEW K-~ WORK BACK RESVR. WELL EN 2. NAME OF OPERATOR Un ion 0il Co. of California 3. ADDRESS OF "OPERATOR 507 Norfhern Lishgs Blvd. 4. LOCATION OF WELL (Report location clearly and in accordance with any ~tate requirements)* At surface Reference Form 9-1330 At top prod. interval reported below Previously Submi t:ted At total depth 15. DATE SPUDDED Form approved. Budget Bureau No, 42-R355.5. 5. LEASE DESIGNATION AND SERIAL NO. A 028142 6. IF INDIAN, ALLOTTEE' OR TRIBE NAME 7. UNIT AOREEMENT NAME $. ~ARM OR LEASE NAME K~n~I Un_it 9. WELL NO. · 4t-6A,~ 10. FIE'L~ A-~D ~'OOL, O~ ~X~O~ Kennt g~mrl'lnn Aaq P~oI Sec 6, T4N, RI!W SM I 16. DATE T.D. REACHED.I 17. DATE C0MPL. (Ready to prod.) 12..'COU_NTY OR 1~ 13.~/~.d~STATE 19. ELEV. CASINGHEAD 18. ELEVATIONS (DF, R~B, RT, O~r, ETC.)~* 20. T0~.. AL DEPTH, MD & TVD 21. PLUG, BAC~I{ T.D., MD & ~ I 22. IFHowMULTIPLEMANY. COM.PL., 24. PRODUCING INTERVAL(S) OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* :: , ; 26.:iTl[PR ELECTRIC AND OTHER LOGS RUN CASING SIZE WEIGHT, LB./FT. 23.INTERVALS DRILLED BY ROTARY TOOLS CABLE TOOLS I CASING RECORD (Report all strings set'in well) DEPTH SET (MD) HOLE SIZE CEMENTING RECORD 25. WAS DIRECTIONAL SURVEY MADE 27. was WELL CORED AMOUNT PULLED 29, LINER RECORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 31. PERFORATION RECORD (Interval, size and number) ' 30. TUBING R. ECORD SCREEN (MD)'--. SIZE DEPTHSE' (MD) I ~2. ~ ]:ACID, SHOT, FRACTURE, 0EMENT SQUEEZE, ETC, DEPTH ~INTERYAL (MD) AMOUNT AND KIND OF MATERIAL USED · PACKER SET (MD) 33.* PRODUCTION DATE Fl?ST PRODU. CTION~. - I pRODUCtION METHOD .~Ft. OW'!n~:,. g~8 l~.~, puf'd~ping--size ~n~' ty~e Of pu'~p) December. 1968I Flow DATE OF TEST' HOURS TESTED CHOKE SIZE PROD'N. FOR 0IL---BBL. GAS MCF. I TEST PERIOD l Dec, 1968 I . . WELL STATUS (Produotng or Produc I n.q WATER----BBL..GAS'OIL RATIO ,~,'z'?q ~.a ~, 34. DISPOSITION OF'OAS (~Old, used for fuel, ve~te5; 'et~.) ....... I TEST WITNESSED BY Sold I L B. WatJ~It/ISIONOFOILA:;;C'" 35. LI~ST OlV ATTACHMENTS ~CH0~,~. *See "Gas Well Open. FIo~ Po*enTial Test Report~" AK Form G-I 36. I hereby, certify that the fo~egoin~and attached information is complete and correct as determined from all available records ~. ~- Production Enq i ~- ~" -//~'~' *(See Instructions and Spaces for Additional Data On Reverse Side) ,. ' .. ? INSTRUCTIONS General: This~for'm is designed for submitting a complete and correct well completion report and~.iog on ali type's.of la'nors and leases to either a Federal agent o~ a or.both, pursuanlt~to applicable Federal:and/or State laws 'and regulations Any necessary Sr~oi~il instrUCtions ~n submitted attic arl with're ard , : . · . ,~ .. : : ~ ~,,,,:s ~.~ u~e-.v~ tins form aha, r~e numoer, of ~.~ -, ~.~,_.p ~.;.,~1 ~y . .. g!. to lo~_.al, ar~e~, or regionat,procedt~res and practmes, either are;shown. I~elow .or will be issued by, or/hay be obtained f~om the aha/or ~tar~ om~. ~ee m~tructxons on items zz and 24, and. 88, beloW.regarding separate reportS :for se[~rate eOmpl~ions. : - , ' .I.t not fi`led prior~t.~ the tim.~ this s _u!?mary record.is submitted, copieg'of all currently available lo~s (drillers, ge01ogists,..sample anti'core,analYsis, ali typ~-, elee~ic ~ -- ~onshouldanabePressure' ~es~s,.pnd. listed i~ this form,dire~tl6nal'su~veyS'se~':i~9'm 35. should: be.: attached:. .hereto,l : to. the extent required. .,.' by a}plicable. Fecleral.and/or 'State: ,lawsi~and, ....... rd~at~bns, r~l}.. , : .... ' . Item 4: Ii there-~re no avplicablerSta~e r~quirements, 10cafl~n~s. 0n'-F~de~al 'o~' Iii~iian-'iand shoed be de~rii~,d in a~cordance w~th FederalSrequiremen~ or' Federal office ~r si~'eifle instrucfJI-ons: ~ '~ '-~- ~ oJ ' - :' Item IS: ln(.li_ea.t~' which elevation .M used as reference (where not ~therwise shown):for depth :~neasurements ;;iven Items 12 ace z~: ~If this well is completed for separate production from more than one interval zone (multiple completion) interval, additional iiiterval t~ b~ separately produced, :sho{Cthg the idditional data pertine~t to stroh interval for each-or inter{als,, top(s), bottom(s) and name(s) .(if any):for .only 'the interval ;reported in item Item 2~: -"~ac/cs '(?emit": AttacHed supplemehtal records for this well Should show thet-del~ils of any multiple !Simge:eementing aud the IoeatJ~0n of ~he cementin~g Item ]~: [Submit a SeParate completion report ion ithis form .f~r each intgr~al to be sepa~ate!y produced. (See fhstru~tion'f0r item, S22 ~nd 2~t~bove. i) ~..i ., ' i)S H0.~ ALL IMPORTANT ZONI~S OF POR~),,SiTY AND CONT;RN,S~TI!]~j~-EE(~,; ' ,.:-i . . C~R~D XN~IRVALS; AND ' ~; DEP~ INTERVAL TESTED, CUSHION U~ED, TI~E ~OL oPEN :FLOWING AND': S~.UT*IN PREssuREs~ · . .... ~ - , ,( J ; . . ~' , ; f., ' . :" -+~oa~t~Io~ ~o~ ,.' ~o~to~ ~f ~ . ' ": ~sca~tlo~,;co~ti~s, ~c. .f~; L :L) " " : '" . ', ,~ , . x.: ",:'; '. : ' ,: : ..... --' .. . : -..~ ; ~ ' . :. '-': , : , ,..~::, . .,. , . ' ........ ~ ' ' ;"' , ' ': ' ,., ' ' , -- " ' ' '-' J l'-' , , .., . . . . .. · . . , . . ~ . ,' '~': ~ . -~ ! {..'; ~ .... , ,. ' ..! '~ · ,{ , , , , · ~_ " . .... ~y, t ';, . : ' · '2: ~' : : U~ ..- ' ' _..·, : :-: ,., ., . :.. [ ' ., o ,. ~. x ...; -., t.',. .tl ~..; .; : ".i ':" ,' ' ' :;: : ', , ~ '- ' }~i " ,.... ; :; :-~ ?', ,. U.S. GOVERNMENT PRINTING OFFICE Union Oil Compano California unlen 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 HLB ~ TR~ .I-..~-~r~--_ -- KLV RE[. -~ .___.-.-- No~ember 6, 1969 Mr. Homer Burrell, Director Department of Natural Resources 5001 Porcupine Drive Anchorage, Alaska Dear Hr. Burrell- This is to inform you that Hultipoint Flow Tests have not yet been conducted on the Kenai Unit 45-6A gas well. Mechanical conditions in the well have prevented prolonged production and as soon as these conditions can be coped with, Multipoint Tests will be run on each of the two completions. Should you have any further questions, please advise. R. C. Hartmann District Production Superintendent RCH-mgl FORM 401-ANC-W (8/67) KEITH H. MILLER, Governor DEPART~IENT OF. NATURAL RESOURCES DIVISION OF OIL AND GAS r~~~~ 3001 PORCUPINE DRIVE-ANCHORAGE 99504 October 29, 1969 Re: Kena I Unit ~43-6A Union 011 Co. of Callfornla Operator Union Oil Company of California 2805 Dena I i Anchorage, Alaska 99503 Gent lemen: The below-indicated reports and other information on subject well, as required by AS 31.05.030 and the applicable Oil and Gas Conservation Regulations, are: OVERDUE. Please submit. INCOMPLETE. We are enclosing." Please complete and return. APPARENTLY IN ERROR. We are enclosing. Please Correct and return. REQUIRED REPORTS AND OTHER INFORMATION ~ P-l, Application for Permit to Drill Or Deepen. ~ P-3, Sundry Notices and Reports.. ~ P-4, Monthly Report of Drilling'7'' and Workover Operations. ~ P-7, Well Completion or Rec0mpletion .Report. "---- ~ P-I3, Report of Injection Project. -. Remarks: 2 copies of Multi~int Flow Test Directional Survey Electric or Radioactivity Log. [~ Sepia ~ Blue line Mud or Lithology__~Log. ~ Sepia [~ Blue line Samples and Core Chips ~ Chrong'logical Well History NOV 719 Very~uly yours, Ho~er L. BU~'~'e 11" Director Union Oil Compar?'"~f California 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 unl®n iuly 15, 1969 OKG KLV HW',< !.~/-. - REL FILE Mr. Homer L. Burrell State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Re: Kenai Unit No. 43-6A Union Oil - Operator Multipoint flow test Dear Mr. Burrell: Due to mechanical conditions in the gas field, we have been unable to obtain the required test. As soon as these conditions have been corrected, the required tests will be run and results submitted. Very~truly yours.,._~ Robert C. Hartmann District Production Superintendent RCH/dp D~VI,~ONOF OILANDGAS ANCHO~GE FORM 401-ANC-W (8/67) ~orm P--7 . ~ SUBMIT IN DUPLICATE* : STATE OF ALASKA ' (Seeotherln- struct ions on ~ OIL AND GAS CONSERVATION COMMITTEE reYerse side) 5. AP! NTJ1V/;:~CA~ CODE 50--133--20121 ~ ,- T ~i:~ ~ II I ~ WELL COMPLETION OR RECOMPLETION R~bRT AND LOG* ~.~~~o~~~o. .................................................................................. · Anchorage 0281~2 b. ~Y~ O~ CO~O~: ~'~ ~ WELLNEW ~ OVER ~WOBK ENDEEP' ~ BAcKPLUG ~ . mFr.n~Svm ~ O~er " 8. UNIT,F~ OR ~SE N~E ~. ~,M~ or o~,~o~ ' ~ " KeBa~ U~t "~ ' 43-6A S ~, A~D~5~ O~ O~A~O~ ~ 507 ~. ~orthern L~ght~ Blvd., Anchorage~ ~la~ka ?9503 . ~0. ,m~~,oa w~ 4. LOCATION OF WELL (Report location olearl~ and in accordance with any ~tgte requirements)* Ke~ai Gas Field At ~.~ee n. S~., ~., ~., ~., (~~ .. At tod 9rod. lnter~i zegorte8 below : ; At total dep~ DEC 2 7 i96 DIVISION: 0F OIL AND GAS 68-51 'D~ ~W ~Y* ROTARY TOOLS ". CABLE TOOLS ~J PRODUCING ~V~(S), OF ~S ~M~I~, ~OM, N~E (~ ~ ~)* ~. W~ DI~ON~ ~ ~ SURV~ ~DE .:, .. , ~ ~ ~ , ~ .. r , .~' ~ -" - C~G ~ (Re~ all strings set ~ wall) ' CA~G SIZE WEIG~ LB/~. D~ ~T. (~) HO~ S~E ~~G ~CO~ c '1 28~ PE~O~TIONS OPEN TO PR (Inte~al, size ~d numar) ~. AC~, SHOT,'F~'~, ~ SQU~ZE, : , . . ~ i ii i i I ;~. ~ - ~ODU~ON D~TE FIRST P~ODUC~ON [ -~O.DUCTION METHOD (Flowh~g, gas Ii/t, pump~size and type of p~p) ' IWE~ ST~S (~oduc~ or ~ 12/5/68 '[:~ ,Flo. inE ~ '" ~ I ~""'"~)ProduCing 12/5 & 6'68 " 2' '' ;/ /, ! ~ - ' ivariable l ~I - I o, oo I- I - ' ~ow. ~. ~z~G179 4 ]~mG --: P~S~ . . j ~...[ . IC~~ ~-aOUR ~. -O~BBL. _ _ [°~~' i0,300 ] WA~B~. -- Jl°m GRAV~Y-~ -- (C~.) ,, i 1' ' ' ' - 3 . D~SPOS[~]ON Or O~S (~0i~, ~,~ ~0r/~], ~e~te~, etc.) TEST WITNESSED BY Sold - Kena~ Ni~sk~ P~pel~ne i ~' P' Kendall None ~~; ~ ~. I hereb~ cert~~~ information is complete and c0rre~t ~s determined from al~allable records ~ SIGNED - TITLE DiSt. Prod. Supt. DATE 12/26/68 ,- ' ~g. ; H rtmann~ ...... Sec. 6, T4N, RllW; SM. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report arid log on all types of lands and leases in Alaska. ' Item:,~i16: Indicate which elevation is used as reference (where not otherwise shown).for depth, measure- ments'given in c, ther spaces on this form and in any attachments. · .. Item$"~0, and 22:: If this well is completed for separatc- production from more than .one inte~'val .zone-'. (multiple completion), so state in item 20, and in item 2'2 show the p~c. Jucin.cj. inte~'val, or ,nte(..vals .... top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30.".'Submi:t a sep4fate reporf'7 (page) on this form, adequately identified, for each additional interval to be seperatel~, produced, ~.how::'. ing the ad~ditional data pertinent to such interval. It®m26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anct the location of the cementing tool. 1tern 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 36. CO~.E "D~TA, Aq~ACiI BRIEF D~CRIPI~ONS OF LITI~IOLOGY, POROSITY, FRAc~R~, APP~NT DIPS . . AND DE'PECk'El) SIIOWS OF OlD, GAS . Form No. P--4 REV. 9-30-67 STATE' OF ALASKA O~L AND GAS cONSERVATION COMMITTEE SUBMIT IN DEPLIC~.TE MONTHLY RE'PORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union 0il Company of California 3, ADDRESS OF OPEI~kTOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION oF WELL 277'S & 4279'E from NW corner Section 7, T4N, RllW, SM AP1 N~IERICA~ CODE 50-133-20121 6. LEASE DESIGNATION AND S~IAL NO. Anchorage 028142 7. IF INDIAN, ALOTTEE OR TRIBE NAME 8. LrNIT,FA2~M OR LEASE N.~ME Kenai Unit 9. WELL NO. 43-6A 10. FIEI.J) A. ND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M.. IBOTTOM HOLE OBJECTIVE) Sec. 6, T4N, RllW, S.M. 12. PEP. MIT NO, 68-51 13. REPORT TOTAL DEPTH AT END OF MONTH, CPLA/qGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~OI:LATIONS, TF. STS AN-D R2:SULTS. FISHING JOt?.S, JLrNK IN HOLE A24D SIDE-T1R~ACKED HOLE ~ND ANY OTHER SIGNIFICANT CHJkNGES IN HOLI~ CONDITIONS. KENAI UNIT 43-64, SEPTEMBER 1968 Drilled 9-7/8" hole to 5300'TD. Ran 126 its of 26.4# and 33.7#, N-80 & J-55, 8Rd, LT&C csg w/lhoe hung @ 5288' and.DY collar @ 2268'. Cemented through shoe w/800 sx Class "G" cmt, last 100 sx mixed w/10I mica. Cemented through DY collar W/700 sx Class "G" cmt mixed w/10I mica. Installed tubing head and BOE. Drilled out DV and circulated hole clean. Ran Schlumberger GR-CBL. Perforated with 2-1/16" scallop guns 4-3/8" hpf; 4407~4457; 4521-4534; 4930-4956. Ran dual tubing strings 2-7/8" 6.5# J-55 w/ special clearance couplings. Hung w/pkrs @ 4900' & 4356' for completion with B-1 & B-2 intervals through short string & B-5 through long string. Removed BOE, installed Xmas Tree. Changed from mud to water, set & pressure tested packers. Short string flowed, cleaned up. Surface shut in pressure 1800#. Opened sleeve in long string above top of packer. Depressed fluid out of tubing with short string gas. Long string flowed & cleaned up. Surface shut in pressure 1500#. Shut in well, filled annulus with water. RIG RELEASED 11:59 PM 9/6/69 DIVISION OF MIN~$ a MINERAL~ ANCHc).gAGt~ S~G~ . ~'~L/.Y~ =r= Dist. Drlg. Supt. DATt 10/11/68 NOTE--RePort on this~rm i5 requked for each calendar mo~th, reDard~ess of the status of operatio,s, and must ~ file~ in duplicate with the Divis~o~ of M~nes ~Minerals by the 15th of the succeed~n9 month, un~ess othe~ise directed. Form P--7 ., iii I ~1'~1 WELL COC~L°E~T~o~~B~PL~iON REPORT AND LOG* ,a. TYPEO~W~: o.. ~ .~ ~ . ~ WELL WELL - ~DRY Other b. TYPE OF ~OMPLE~ON: ~VELL (See other STATE OF ALASKA so-~-20~ NAME OF OPERATOR Union 0il Company:of_ California AI~DRESS OF OPERATOR · 507.',W_ Narth~rp. Li~ht.~ 'Blvd.. ~chOra~e. Alas~ 99503 ,, LOCATION .OF WELL-(Report lo~tion clearly: and. tin accordance ~i$h' any State requirements)* Atsu~ace 277'S & ~279~'E frbm:~ coraer Sec. 7, TdN, RllW, SB At top prod. interval reported, below 1980 ~65~N & 218.50E of Surface Loc. At total dep~ -.:2459'N & 180.86'E 0f SurfaCe Location ! 6. LEASIfl DI~...~N_&'IXON A/~ID SERIA~ NO. AnChorage 028142 7. IF INI>IA.N', ALLOTTEE OR TRIBE NAME 8. UNIT,FAI~IVI OR LEASE NAME Kenat Untt g. WELL NO. 43-6A 10. FIELA) A~rD lmOOL, OR WILgDOAT -Kenai Gas Field I1; S~-~., T., R., M., (BOTTOM HOL~ OBJECTIVE) · Sec, 6, T4N: R!IW, SM 12.PERMIT NO, I~T,GR, ETC) 117. ELEV. CASINGHEAD 13. D~TE ~.SI~UDD]~D1:4...~ ~..: ~c~t,:...~ ~o=~ ~.~. m .~.m. ll,. m.mv.~o~ (~,~, ~, .. 68-Sl 8J25/68 I 9/2/68 L i'. !; 9/6/68 :' ! RT 15' _ ] 2' 18. T~ ~, ~ & TVD.~. PLUG; ~CK ~ MD& ~D~; ~ ~L~m~ CO~L., ! m. I · -: I I oo. m. PRODUCING ~V~tS), OF~ ~S ~M~T~~, BOSOM, N~E (~ AND ~)*Mlddle Kena~ ' 'n. W~ DIRE~ON~ ~ 4407-4457 WD 38i2-3855 ~ Suzv~Y~D~ ~ 4521L4534~ TVD 3918-3929 ~- 4930-4956 TVD 4268-4291 Yes , ~ - CASING RECORD (RePOrt all .strings set in we 1) [wm~, ~,~. ~:"-~ ::'~- ~:i:1 -~ ~. ,,-, I ~o~ s~ ] c~m~ ~co~ ,' ~0-s~- / J,SS:'!~250'-'~ 1 ~7-~/2"! ~s0o ! ~;~' / ~'~°::i ~z~: I 9-718"1 lsd. stage 800 ,x L 27. TUB~G SC~ (MD) SIZE D~ SET (~) 2-7/8" '24. TYPE ET,RCTRIC 'AND OTHER I.,OGSI~UIq- :<} DIL, Sonic, Ga~a Ray and CBL ,~, C-~SLN G SIZE ~:.7-5/8" ?: 7-5/8" 20. LINER HECOI~]) SIZE '[ TOP (t%~D) None "" 28. PERFORATIONS OPF2N TO PRODUC 4-3/8" Holes per 'foot 4407-4457 4521-4534 4930-4956 iiiii t BoTToM (~iD) ! SACKS C~T* ~ION -(interva]. size and .nurnbe~) ,] .MVIOUN-T PULLED Ngn~ Md. i i ~. PP, ODUCTION ' 29. I PA. CICER SET (MD) 4350' 2-7/8" 4900 ' ACID, $~!OT, FR.~C'I'UIiE, CEATENT SQUEEZE, ETC. D]~I. i.!AVfISRyAL-(MD) -[ A,MOUAI'F AND I<tND O,F MA,TEH/AL USED ~o 'i! ,-' ' ,~ I Shut In ~' I 't:~-~°'~ ~ WA~BBL. I OIL GRAVITY-~I (CO~.) 31'. DISPOSITION OF ~AS (8ol'd, used )or tuel, vented, etc.) , ~TEST WITNESSED BY 32. LIST 0~' ATTACHMENTS 33. 1[ herebyl SIGNE~ cert~t,//,/~]~,E. 'T'].]~/L~L~~t~/~g°ing and attached information. "TITLEIs complete.,_ i. ~T.~_ ani'dii~':c°rrect.., Df"! I~'. ~tll'! "~d so_as determined, from alUavailableDATErecords *}~See Instructions and Spaces for ~dditional Data on Reverse Side) INSTRUCTIONS ".~ene.¢al: This form is designed fa~ submiiting a complete and correct well compietiOn report and log on '1811 types of lands and leases ih Alaskal . ' ; Jtem:'16: Ir~dicale which elevation is [~sed as~:reference (where not otherwise'shOWn).for depth measure- ments:'given in cther spaces on this for~'~nd in any attachments. .. ;:ltem;~20,i;nd 22:: If this well is ~:°mp'l'et~d for separate production from more than one interval zone !imuir. ip e completi, on), so state in item' 20, and in item..22' show the prc. Juci'r~g interval, or intervals, ' (!'tOp(s)., bot:tom(s).'.~nd name (s)' (if any):for-'only!':'the inte~r~,.,~l reported in item 30_. Submit a separate report :,(.page)!. on ;this form, adequately identif:jed, for..!each additional inte, val to be Seperately produced, show- . '""'ing i:be adtditiona:t data pertinent to ~,'.d,'cli;: inte'rgal. ,'item26: "Sacks Cement": Attached s0'~p!~men~al records for this welt should show the details of any mul- tiple :~tag~' cemen'ting and the ocatioRJ6f; the..,cementing: to01. ii.item 28: SubMit a separate'completion re. port':on this:form for each interval to be separately produced. :.., 'i'iSee instrUction for items 20.-and 22 aboge). .. · .. WA2'~I'~. AND MUD '~ NAME · ~ , _ ~- _ ~AS'.' O~_m ~i/~:'V~.-r. Omi , . -. . ', . · ,. H~ddle Kena~ 6~07 3812 , . .. , . DATA. AWACli BRIEF DESC'RI['VFIONS OF LITtlOLOGY, :POROSITY. FIIAC~IILg. Ar}FAiNT DIPS .. ... AND [)E'I'ICK-I'EI~ SIIOWS OF OIL"GAS O1l %VAT~. . , , ~,, ~, ,~,~. ,, ~ , ,,, , .,. , ,, ,, .. . .. .. .. .. 980930.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE .1 OF I DATE: 9/30198 FI ELD: FILL DEPTH/DATE: 4540' WLM - 3~95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day ~9 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-518", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS MIRU Pollard slickline on shortstring tubing. Test lubricator and BOPs to SITP. RIH with 2.1" impression block, looking to tag fluid level. Tag crossover to 2-3/8" tubing at 4055' MD, but did not tag fluid. Confirms that squeeze perfs are holding. POOH, RD slickline. RU slickline on Iongstring tubing. Test lubricator and BOPs to SITP. RIH with "BO" shifting tool. Located "XO" sliding sleeve at 4084' MD. Jarred down to shift sleeve open. After jarring several times, casing pressure increased from 85 psig to 235 psig. Shifting tool disengaged and would not relocate in sliding sleeve, indicating full travel of sleeve. POOH. "BO" shifting tool not sheared. RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC roUstabouts $0 $400 Dowell nitrogen pump & nitrogen $0 $12,200 Misc. $500 $4,000 Pollard slickline $815 $3,950 Schlumberger E-line $0 $6,000 Vetco Gray 2" gate valves $0 $1,600 DAILY COST: $1,315 CUM: $32,650 REPORTED BY: J.G. Eller 980912.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/12/98 FIELD: FILL DEPTH/DATE: 4540' WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #8 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS MIRU Dowell nitrogen unit on well KU 43-6A. SICP = 650 psig, SITP (shortstring) = 1600 psig. Blew down shortstring tubing to atmospheric pressure, and casing pressure dropped to 400 psig. Started pumping nitrogen down casing while taking fluid returns on shortstring tubing. After pumping 72,000 SCF of nitrogen (maximum casing pressure = 1370 psig) got nitrogen returns to surface. Stopped pumping nitrogen, then continued to blow nitrogen from the tubing to make sure all packer fluid is unloaded. Shut in well with SITP = SICP = 80 psig. RDMO nitrogen unit. Note: Plan to negative test squeeze perfs at 4106' MD all week. If squeeze perfs holding OK, will shift open the sliding sleeve on the Iongstring tubing next week. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen pump & nitrogen $3,800 $12,200 Misc. $500 $3,500 Pollard slickline $0 $3,135 Schlumberger E-line $0 $6,000 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $4,300 CUM: $31,335 REPORTED BY: J.G. Eller 980911 .xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/11/98 FI ELD: FILL DEPTH/DATE: 4540' WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #7 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS Prior to arrival of Schlumberger, Production Operator pressured up tubing on KU 43-6As to 1900 )sig using high pressure gas. ~IIRU Schlumberger electric line unit on well KU 43-6As (shortstring). Test lubricator and BOPE to 2100 psig. RIH with tubing punches. Tag PN plug at 4130' MD and correlate with wellbore diagram. Perforated 2-3/8" tubing with seven 0.25" holes from 4089' - 4090' ELM. Pressures changed as follows: Before Perforatinq After Perforatin.q SICP 300 psig 450 psig SITP (shortstring) 1900 psig 1500 psig SITP (Iongstring) 280 psig 280 psig POOH, RDMO electric line. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen pump & nitrogen $0 $8,400 Misc. $500 $3,000 Pollard slickli ne $0 $3,135 Schlumberger E-line $6,000 $6,000 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $6,500 CUM: $27,035 REPORTED BY: J.G. Eller 980910.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/10/98 FI ELD: FILL DEPTH/DATE: 4540' WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #6 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS MIRU Dowell nitrogen pump on 7-5/8" casing of well KU 43-6A. Line up to take returns off shortstring tubing. Held safety meeting and tested lines to 2500 psig. Opened valve to 10-3/4" casing to moniter for communication. SICP = 400 psig, SITP = 120 psig. Bled tubing to zero. Started pumping nitrogen down 7-5/8" casing. Not getting any fluid returns. Pressure up casing to 900 psig using only 5,600 SCF of nitrogen. Cease pumping nitrogen, bled casing to 300 psig. No communication with surface casing throughout job. SDFN. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen pump & nitrogen $4,000 $4,400 Misc. $500 $2,500 Pollard slickline $0 $3,135 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $4,500 CUM: $16,535 REPORTED BY: J.G. Eller 980909.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/9/98 FIELD: FILL DEPTH/DATE: 4540' WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #5 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF .OPERATIONS MIRU Pollard slickline on KU 43-6As (shortstring). Test lubricator and BOPE to SITP. RIH with PN plug to 4130' MD, set in "N" nipple. POOH, RDMO slickline. Shot fluid level on casing showing packer fluid at 695'. Note: Prior to this day, Production Operator had applied some gas pressure to the casing to try to force out the packer fluid into the shortstring perfs. Constant pressures indicated formation was not taking the fluid. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen $0 $4,400 Misc. $500 $2,500 Pollard slickline $685 $3,135 Vetco Gray 2" gate valves $0 $1,600 DALLY COST: $1,185 CUM: $12,035 REPORTED BY: J,G. Eller 980902.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE I OF 1 DATE: 9/2/98 FIELD: FILL DEPTH/DATE: 4540'WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day ~4 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS 8/29/98 Production Operator bled tubing on KU 43-6As to zero, then loaded tubing full of fresh water. Tubing holding steady. 9/2/98 MIRU Pollard slickline on KU 43-6As (shortstring). Test lubricator and BOPE to SITP. RIH with "B" shifting tool to XO sliding sleeve at 4094' WLM. Gained 100 psi on tubing when sleeve shifted open. POOH. RIH with "R" shifting tool, ran tool up and down across XO sleeve to verify that it is open. POOH. RIH with 1-3/8" JDC, latch equalizing prong of PN plug @ 4130' MD. Tubing on vacuum. RIH with 2" JDC, latched PN plug body. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitro~len $0 $4,400 Misc. $500 $2,000 Pollard slickline $1,140 $2,450 Vetco Gray 2" ~late valves $0 $1,600 DALLY COST: $1,640 CUM: $10,850 REPORTED BY: J.G. Eller 980827.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/27198 FIELD: FILL DEPTH/DATE: 4540' WLM - 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day#3 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-718", 6.4#, N-80 CASING: 7-518", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Steding B-1 & B-2 SUMMARY OF OPERATIONS MIRU Pollard slickline on KU 43-6as (shortstring completion). Test lubricator and BOPE to SITP. RIH with 1.87" gauge ring to 4130' MD. POOH. RIH with PN plug, set in "N" nipple at 4130' MD. POOH, RDMO slickline. Vendor Equipment Daily Cost Cumulative Cost APC roustabouts $0 $400 Dowell nitrogen $0 $4,400 Misc. $500 $1,500 Pollard ~ slickline $1,310 $1,310 Vetco Gray :2" gate valves $0 $1,600 DAILY COST: $1,810 CUM: $9,210 REPORTED BY: J.G. Eller 980817.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/17/98 FIELD: FILL DEPTH/DATE: 4540'WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #2 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS Hooked up a chart recorder on the 7-5/8" casing of KU 43-6A over the weekend. Casing pressure steady at 660 psig. Bled 7-5/8" casing to zero. Held operational and safety meeting. Removed blind flange from secondary casing outlet on tubing head. Installed a newly tested 2-1/16", 5M gate valve. Removed old casing valve, and installed another newly tested 2-1/16", 5M gate valve. Closed casing valves, release roustabout crew. Vendor Equipment Daily Cost Cumulative Cost Dowel l nitrogen $0 unknown Misc. $500 $1,000 Vetco Gray 2" gate valves $1,600 $1,600 APC roustabouts $400 $400 DALLY COST: $2,500 CUM: $3,000 REPORTED BY: J.G. Eller 980814.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/14/98 FI ELD: FILL DEPTH/DATE: 4540'WLM- 3/95 TUBING: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Convert to annular flow OTHER: Day #1 - AFE 0482398 Kenai Gas Field WELL #: KU 43-6AL 2-7/8", 6.4#, N-80 CASING: 7-5/8", 26.4#, J-55 TREE CONDITION: BENCHES OPEN: Sterling B-1 & B-2 SUMMARY OF OPERATIONS MIRU Dowell nitrogen pump on 7-5/8" casing of well KU 43-6A. Test lines to 3000 psig. Pressure test 7-5/8" casing to 660 psig using 7140 SCF of nitrogen. Volume of nitrogen used indicates fluid level is approximately at 1000', which is in agreement with workover records. The 10-3/4" surface casing had no pressure on it following the test of the 7-5/8" casing. RDMO nitrogen unit. Note: Over the weekend will put a chart on the casing to record the pressure test, then blow down the 7-5/8" casing to atmospheric pressure. Plan to install new casing valves on Monday. Vendor Equipment Daily Cost Cumulative Cost Dowel l nitrogen unknown unknown Misc. $500 $500 DALLY COST: $500 CUM: $500 REPORTED BY: J.G. Eller LEASE DATE 8/25/68 26 27 28 29 30 - 1 9/2/68 3. UNION OIL CO. OF CALIFORNIA DRILLING; RECORD SHEET D PAGE NO.. ~ KENAI UNIT WELL NO. 43-6A FIELD KENAI GAS FIELD E. T,. D. 728 1286 1286 1286 1700 5300 ' TD 5300 DETAILS OF OPERATIONS, DESCRIPTIONS ~:. RESULTS SPUDDED 8/25/68 @ 0115 hrs. 40' to 728'. Drilled 12-1/4" directional hole from Dynadrillgd and surveyed 12-i/4" directional hole to 1286'. RI with 17-1/2'.' hole-opener. Opened 12-1/4" hole to 17-I/2" from 267-1286' and conditioned hole for casing. Ran 31 Jts 10-3/4", J-55, 40.5# Armco Seal Lock casing with Baker Flexi/low shoe @ 1250'. Cemented thru shoe w/790 cuft class "G" cement with 42% Diacel, 6% gel amd 2% Cello/lake followed by 900 0 v ti 11 sX'~lass "G" cmt w/3% CaC12 added to last 200 sx Put ~0 s.. class C w/3% CaC12 on top of top plug, Displaced cemen; w/120 bbls mud - 200 sx cmt returns to surface. Float held OK. CIP @ 2015 hfs 8/27/68, WOC, cut Off casing. Installed 10-3/4" (10"-900) Sheller KD casing head. ~ested weld to 3500 psi for 10 mins. - OK. Installed 10" 1500 Series, 5000# BOPE. Test unsatisfactory. Changed BOPE ~,~-'~il,~,. and double hydraulic Shaffer). Tested all BOPE to lO00. psi for 15 mins - OK. Drilled out shoe. Found top of cement in casing @ 1140". Drilled directional 9-7/8" hole to 1700'. Dri~lled 9-7/8" directional hole to 5300'TD. Conditioned hole for logs. Rigged up Schlumberger and ran DIL and Sonic logs. Conditioned for casing. Ran 126 Jts 7-5/8", 33.7#, N-80 LT & C 8rd casing and 26.4# J-55 LT & C 8rd casing. Landed @ 5288.75' w/float co].lor @ 5240.22' and Howco DV @ 2268.07'. 7-5/8" CASING DETAIL Baker Model "G" shoe (7-5/8") 7-5/8'.' 33.7# N-80 LT&C c&sing Baker Model "G" Collar 7-5/8" 33.7# N-80 LT&C casing Howco DV Cementer 7-5/8" 3~,7# N-80 LT&C casing 7-5/8" 26.4# J-55 LT&C casing 7-5/8" 33.7# N-80 LT&C casing Landed below KB 1 JT 71 Jts 27 Jts 26 Jts 1 Jt 2.40 5288.75-5286.35 44.05 5286.35-5242.]0 2.08 5242.30-5240.22 2972.15 5240.22-2268.07 2.1.0 2268~07-2265.97 1126.17 2265,97-1].39.80 1099.02 1139.80- 40.78 28.78 40.78- .12.00 12.00 12.00- 00.00 Cemented first stage w/800 sx class "G" cement, last 100 sx w~2%.CaC12. Displaced w/247 'bbls mud. Bumped plug w/1500#. Cement returns to surface' 150 sx. Opened DV @ 2268' and circulated approximately 25 sx cement out.. Lost all returns. Pumped 700 sx class "G" mixed w/lO% mica. No returns. Displaced w/ilO bbls mud. Closed DV w/2000#. All floats OK. CIP @ 0200 hrs 9/3/68. All cement mixed w/fres.h wtr. Installed slips~ cut off 7-5/8" casing. Installed Shaffer packing. Rigged'up BOPE stack. UNION OIL CO. OF CALIFORNIA DRilliNG RECORD Sh EET d PAGE ~10. LEASE KENAI L~IT VV-ELL NO. t~-6A FIELD DA.TE 9/4/68 E. ~7. D. 5300 5235 ETD 5235 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Tested BOPE. Ran in hole to top of DV collar and conditioned mud. Drilled out DV.- Tested DV to 1850#. Cleaned out to float collar @ 5235'. Rigged'up Schlumberger. Ran CML and Gamma Ray logs. Perforated w/2-1/i6" scallop guns - 4HPF from 4407-4457'; 4521-4534'; 4930- 4956'. Ran bit and scraper, changed rams to run tubing. Ran dual 2-7/8" tubing string w/packers, 2-7/8" TUBING DETAIL LONG ~T~,ING Shear Sub Jts 2-7/8" No Go Guiberson RH 1 Packer 2-7/8" 6,40# N-80 Buttress Tbg, 1 2-7/8" Butt X 8rd EU X-Over Otis XO Sleeve 2-7/8" Butt X 8rd EU X Over 2-7/8" 6,40# N-80 Buttress Tubing 10 2-7/8" Butt, blast joint #! 2-7/8" Butt, blast Joint #2 2-7/8" Butt N-80 tubing 1 2-7/8'f Butt. blast Joint #3 2-7/8" Butt, blast Joint #4 2-7/8" Butt. blast Joint #5 2-7/8" Butt. blast Joint #6 2-7/8" 6.4# N-80 Butt. Tbg. i Guiberson RH2 Dual Packer 2' x 2-7/8" 8rd EU x Butt N-80 Pup Jt 2-7/8" Butt x 8rd EU X Over Otis XO Sleeve '2-7/8" Butt X 8rd EU X Over 2-7/8" 6,4# N-80 Buttress Tubing- 139 Cameron 8" tubing hanger - dual Landed below KB Otis "N" Nipple 2=3/8" Guiberson RH #2 Hyd Packer Seal Nipple w/2-3/8" Pup Jt 2-3/8" 8rd EU N-80 Tubing 6.4# Otis XO Sleeve 2-7/8 Butt. x 2-3/8" EUE 8rd XO 2-7~8" Butt. N-80 6.4# Tbg. 2-7/8" Buttress Tubing Pup N-80 2-7/8" Buttress Tubing Pup N-80 Cameron 8" Tubing Hanger Landed b~low KB 0,85 4901.95-4901,10 1,05 4901,10-4900.05 7,55 4900,05-4892.50 31,10 4892,50-4861.40 1,00 4861.,40-4860,40 2,55 4860,40-4857.85 1,00 4857,85-4856,85 314.51 4856.85-4542.3~ 20.30 4542.34-4522,04 20.00 4522.04-4502.04 31.33 4502.04-4470,71 20.05 4470.71-4450.66 20.20 4450,66-4430.46 20.10 4430.46-4410.36 20.25 4410,36-4390,1! 32.05 4390.11-4358.06 9.80 4358,06-4348.26 2.00 4348.26-4346.26 1.00 4346.26-4345,26 2.55 4345,26-4342,71 1.00 4342.71-434!..71 4330.86 4341.71- 10.85 0,85 i0,85 10,00 10,00 1~.0'0- 00.00 15'2 4901.95 DETAIL - SHORT STRING 0.60 4357.42-4356.82 7.90 4356.82-4348,92 5.30 4348.92-4343.62 1 31,38 4343.62-~312.24 2.20 4312.24'-43].0.04 0.80 4310.04-4309.24 137 ~ 4278.09 4309,24- 31..15 10.15 31;15- 21.00 ~ 10.15 21.00- !.0.85 0,85 10.85- 10.00 10.00 10.00- 00.00 138 4357.42 LEASE KENA! UNIT UNION OIL CO. OF CALIFORNia '' shEET D DRILLING RECORD PAGE 'NO . . VFELL NO 43-6A FIELD KENA! GAg FIELD DATE 9/6/68 E. T. D. 5300 TD 5235 ETD DETAILS OF OPERATIONS. DESCRIPTIONS &. RESULTS Landed tubing, Installed Xmas tree, Changed over from mud to water, Set-packers, Flowed short string until clean, Opened sleeve above top packer on long string, Depressed water down tubing and out casing thru sleeve on long string, Closed sleeve, Flowed· long string until clean. Cleaned mud pits, Shut in weIl.temporariiy~ Filled annulus with water, RIG RELEASED 11:59 PM 9/6/68 UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO.. 3 Kenai Unit LEASE WELL No.,KU43-6AW~IELD Kena.i Gas Field DATE io/22/7o 23 24 25 26 27 & 28 28 29 E. T. D, 4832' 4832' 4786'ETi 4150'BP 4786' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Rig,Released from KU 21-6 WO to KU 43-6A WO.,@, 12:00 M~dnight,,.10/22/70. Move to KU 43-6A Moved in & RU Santa Fe Drlg. Co's Rig #35. Otis opened X-O sleeves in long string @ 4857' & 4342'. .. Completed rigging up & winterizing Santa Fe Drilling Rig 35. Conditioned & increased mud weight from 74# to 80#. RESUMED OPERATIONS @ 12:00 Noon 10/24/70. Removed Cameron BPV's. Displaced gas w/wtr. Displaced wtr w/mud. Instld Cameron BPV's. Removed tree. Instld 8" 900 Double Shaffer & Hydril. Tested blind rams w/2200 psi OK. Pipe rams w/2400 psi OK, Hydril w/1800 psi OK., choke & kill lines w/2400 psi OK. Unable to test kelly cock & standpipe due ice plug. Thawed kelly & stand pipe. Removed plugged rotary hose. Thawed same. Pulled short string out of dual pkr. Annulus and short string "U"-tubed. Rigged to circulate. Mud lines would freeze almost as fast as they could be thawed. Circ hole. Mud free of gas but part'of system was cut to 76#. Pulled short tbg string. Pulled 130,000# on long string, but unable to unseat pkrs. RU Dia-Log. Found tbg free to joint of 2-7/8" tbg above btm pkr (Guiberson RH-1). Pulled 108,000# on tbg prior to firing back off shot in bottom pkr. String parted while in tension @ first break below top of Guiberson RH-2 dual pkr in the pkr body. Installed deadmen for rig guy lines due to high winds. Cut 45° taper on single of 2-3/8" EUE tbg, slightly kinked and pulled to 3-1/2" RIF dp. Attempted to stab into 2-7/8" entry port in dual pkr in order to shoot off above bottom pkr. Unable to orient Dia-Log thru tbg single into pkr entry holes. Laid down single. Stabbed into Dia-Log back off shot into 2-7/8" side of pkr. Fired shot in tbg @ 4882'. Ran spear to catch top pkr. Caught fish. Jarred fish up hole 30' where fish freed up. POH, Rec entire fish including both pkrs, tbg & jewelry. Dia-Log shot HRD split tbg, but did not sever tbg. Ran junk basket & gauge ring on da wireline to 4835'. Ran Howco EZ drill BP on wireline to 4800'. Due to a malfunction of the setting mechanism the plug was either lost going in the hole or released at time of firing and failed to set. Recovered top piece of tension sleeve. Ran another "EZ" drill and set plug @ 4800'. Dumped 3-1/2 sx cmt (14' plug) with wireline dump bailer on top of plug, top cmt plug @ 4786'ETD. Ran & set a Baker wireline set model "K" BP @ 4150'. Dresser-Aras perforated four 1/2" holes @ 4106-' for block squeeze above Middle Kenai "A" zone. Set RTTS tool @ 3930'. Broke down perfs w/1400 psi. Pumped at rate of 16 cu.ft. @ 1200 psi. Mixed & pumped 100 sx Class "G" cmt preceded w/50 cu.ft. wtr. Pumping at the rate of 4 cu.ft./min @ 1000 psi & prior to clearing dp of cmt (20 cu.ft, in dp), annulus pressure increased indicating communication. Displaced 90 sx into formation leaving 10 sx in csg. Theoretical top of cmt @ 4065'. Final standing pressure was 650 psi. CIP @ 3:30 am 10/29/70. Back scuttled, no indications of cm~ behind tool. Found small piece of shot wire in by-pass ports of RTTS tool. WOC 12 hrs. Found ' WOC 6 hrs more. top of cmt @ 4020 . Washed green cmt down to 4047'. Washed soft cmt down to 4065'. WOC. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. Kenai Unit LEASE . V~ELL NO 43-6A W~.iELD Kenai Gas Field DATE E.T.D. 10/ 4786' 31 4786' 11/i/70 4786' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS WOC total of 24 hrs. Drld firm cmt 4065' to 4090'. Unable to detect any cmt 4090' to 4112'. Firm cmt from'4112' to 4130'. (Top of BP @ 4146' by pipe measurements). Closed rams & pressure tested cmt job to 600 psi, no good. Bled off to 400 psi in 5 minutes. Set RTTS tool @ 3930'. Pressured perfs to 600 psi. Pressure. slowly decreased to 300 psi in 15 mins. Established pump rate of 7 cu.ft. @ 1450 psi. Mixed & pumped 50 sx cmt with 1/2 of 1% CFR-2 & 2% CaC12. Preceded cmt w/50 cu.ft. caustic wtr. Sqzd 38 sx thru perfs w/a final pressure (standing) of 1000 psi. C.IP..4:Q~ am .!0/30./70. WOC. i2 sx cmt left in csg. ~heoretical cmt top @ 4050'. RIH w/bit & scraper. WOC 18 hrs. Top of cmt @ 4030'. Drld soft cmt 4030' to 4085' & firm cmt from 4085' to 4120'. Pressure tested sqz w/800 psi. Pressure decreased to 700 psi in 15_ minutes. Held 700 psi. Drld BP @ 4150'. Pushed plug to btm. Circ hole clean..Laid down 3-1/2" dp. Changed rams to 2-7/8" D-A perfd the "A" zone pool 3 with four 3/8" hpf 4173'-77', 4270'-94', & 4338'-70'. Ran wireline junk bskt & gauge ring to 4600'~ Set Guiberson type "A" wire~ine set production pkr @ 4393'. RU & ran 135 its 2-7/8" 6.4# N-80 buttress tbg w/blast its across "A" zone perfs, and Guiberson RH-2 pkr @ 4123'. Stabbed LS into production pkr. Tstd pkr w/800 psi, no communication w/annulus, but fluid would pump into btm zone @ 800 psi. Lmnded LS w/10,000# compression. Installed BPV. Ran 129 its 2-7/8" & 2 its 2-3/8" tbg in short string. See. Attached tbg detail, Latched SS into dual pkr @ 4123'. Landed w/4000# compression. Instld BPV. Removed BOP's. Instld & tstd Cameron tree. Otis opened sleeve in LS @ 4374'. Disp mud w/wtr-. Set plug in SS "N" nipple @ 4130'. Set dual pkr by pressuring SS to 2500 psi. Retrieved "N" plug. Tested pkr w/1000 psi OK. Opened sleeve in LS @ 4084' (above RH-2).. Displaced top 1000' (30 bbls) of w~r in annulus w/gas from KDU #2. Closed sleeve @ 4084' trapping 500 psi gas blanket on annulus. Flowed LS '& SS to pit until clean. Closed sleeve in LS @ 4374'. Flowed LS to pit for draw down to check sleeve, OK. LS SIP 1600#. SS SIP 1525#, annulus SIP 500#. Installed BPV's for rig move. RIG RELEASED for. ~rig .do.wn & move @ .4.:00 ipm .!1/2/70. Well flowing Lon~ String - Middle Kenai B-1 & B-2 sands, Pool 4. Short Strin~ - Middle Kenai A-8 A-10 A-ii sands, Pool 3 UNION OIL cO. OF CALIFORNIA DRILLING RECORD LEASE . KENAI UNiT ~ . WELL NO. 43-6A FIELD Kenai Gas Field · LOCATION Kenai Peninsula Borough Drilling !sland #!. 217'S & 42791'E from NW Corner SeCtion 7, T4N~ RI. IW, SM , PERMIT N~. 68-51 SERIAL NO. Anc 028142 T.D. 5300 T.V.D. R.W. Rardin DEVIATION (B.H.L.) COMPANY ENGINEER SPUD DATE 8/25/68 .. COMP. DATE CONTRACTOR Coastal Drilling Co. TYPE UNIT i)iese]. - AS00 ' DRILL PIPE DESCRIPTION SHEET A PAGE NO. RIG NO. 3 ~ ELEVATIONS: WATER DEPTH R.T. TO OCEAN-FLOOR ~'~ ' ,.,gl, .- q2, B. T. -TO-M't:L-~V G r ou n'd - 12 ' Ii. T. TO DBI'LL DECK R.T. TO P~ APPROVED: BIT RECORD / YEL.~ DEPTH & DEVIATION BIT ' JET . DEPTH ' / VERTICAL [] DATE DEPTH NO. SIZE MAKE TYP~ SIZ~ OUT FEET ~OURS AN~ JET DIRECTIONAL ~ ,,. 8/25/68 40 iRR i2-I'/4' Reed STIAG 3-7'/I~ 267 227 6-1/2 6¢ - . . 25 267 '2Rt~ " Smith BHDJ 3-7/1( 728 461 11 65 . 26 728 3 ,,- HTC OSC3J 3-3/4 1088 360 8 65 - '27 1088 3RR " HTC' " 3-7/1~ 12.86 198 1-3/4 6.5 - 27 267 hO1 !7-1/2' Smith 6 Pt Open 1286 1019 13-1/Z 65 - 29 1286 4 9-7/8 Globe SST3 ~7;'?-/~ 2388 1102 !0-1/~ 1.~6 300 31 2388 5 9-7/8 Globe SST3 15/32 4038 1650 13-1/Z 156 300' 9/1/68. 4038 6 " Globe SS%3 " 4882 844 " " " 1 4882 7. " " "' " 5300 418 4-3/4 " " TD 4 8 6-5/8 HTC W7R 0oen .. . . . , . ,. , -- _ . ~ _ . . ... .. . . . .. . · , . _ __ , . . WELL RECORD PAG [': PlO 1 10/23/70 ,~ 11/2/70 [;EASE Kenai Unit WELl, iNTO 43=6A W0 SPUD DATE D.r~L~P. DATE }?IELD Kenai Gas Field COb~'"' LOCATIO~ 2~]_~S_~ 4279~E fm NW corner TYPE U~[T Hopper Double Drum Sec. 7_. T4N, R~!W,~ PERMIT NO, 68-51 T.D. DEVIATION (B.H.L.) _ COMPANY ENGINEER SERIAL NO. 02814-2 T.V.D. Ash, Rardin - · o D~_%_T__E _., H~TERYAL NET OIL CUT .., C.P_. T.P, · ENG-- ENO TYPE:~ -' I' DRAFT j SEC coNFeR:' FILE: CASING HEAD:. Sha'ffer KD 10-3/4" x 7'5/8",, w/2" side outlets (10" sg00)' CASING HANGER:~0%3/4" x 7-5/8" Shaffer sl{ps & packing, assembly, .' .. CASING SPOOL:, none TUBING HEAD:. Cameron - 10" S900"x 8" S900 fo~ dual split' ha~ger ~2 F ('': ~' ~ !,! [ !~' ' ':~ % , 'L ~ i ~ ,*' TUBING HANGER' Cameron 2-7/8" dual split ahnger CHRISTMAS TREE: XXL~~_ Cameron --2~7/8";dual run 8" x 3000# tree I¢ASTER VALVES' 2"3000# block valves · ' ', CHIiISTMAS IltI:.E TOP CONN.: 300011 flanged Cameron valves · .,..~AI U~'~ IT LEASE WELL RECORD .WELL NO: 4.,3-6A FIELD PA'GE NO. i KE'z~AI GAS FIELD ., · . CASING & TUBING RECORD SIZE WEIGH~ THREAD GRADE DEPTH ' , 'I~EMARKS t't-U~'-3/4 " 40.5# Seal Lock J-55 1.250 Cement_~d w/7qO e,, .~r "n"w/Dia ..... l & 900 ~x "G" 7_-5/8' 26.4# 8rd LT&C J-55' . & ............. 7-5/8 33.7# 8rd LT&C N-80 5288 Cemented 'wtlS0fl sx ( 2--7/8 6.40# Buttress N-80 ~357.42 gnec.~nl c]~nr~n.~ er,:,~!~,on -- short strino i . 2-7/8" 6.~0# Buttress N-80 ~901.q5 .. ,, ,, ---~.,-;--.o .... - long ,.. ...... PERFORATING RECORD DATE 'IN_TERVAL E.T.]~. REASON PRESENT' CONDITION '~9/15/68 '4407_4457 5235 Production Ope.n,, ...... 4521-4534 " " " 4930-4956 " " "' --i,~ .... I ' ' Top 'Fl0'lt, cl: ,, i · , , .... . . . · .. ...... .... .... , , , , , , , . · · , .... .... ,. INITIAL PRODUCTION ~TE "INTERVAL, NET OIL CUT GRAY. C.P. T.P. CI;IOKE g4CF .' (~0~1 I REMARK~ ' I 9/20/6. ,. , ........ , .... . , . - .......... ., ..... , _ , , .,, .... . . , _ . .. _ ,. . _ . WELL HEAD ASSEMBLY TYPE: CASING HEAD: Shaffer KD 10-3/4" ~ 7--i5/8'! w/2" side outlat~ (lO" · CASING HANGER' 10-3/4" x 7-5/8" Shaffer P].ips w/packing assembly CAS'IN~'SPOOL: 'Tubing Head ' ~ TUBING HEAD: Cameron - 10"-900 x 8" 900 for dual split hanger TUBING HANGER: Cameron dual split hanger TUBING HEAD TOP: Cameron dual tree MASTER VALVES:. 2" 3000# block valves CHRISTMAs TREE TOP CONN.: 2" 3000# flanged Cameron valves, 2 . . MUD RECORD PAGE NO LEASE_ Kenai Unit TYPE. _WELL NO. 43-6A WO FIELD_ Ke_._n_ai Gas Field DISTRIBUTOR ,, n~s 1 ~.~.~ w~m~[ v,~sc, w.L. ~ s~n~ om 10/26/7~ 4348' 80 48 5.8 10 w.o. fluid - PPI ' ' 27 -- 80 48 5.2 10 , , ' 28 'I i, ,1 ,, . '29 " 49 6.0 11.0 -- I 30 ' ' 47 6'4 " 31 " " " 10.0 11/1/70 " " " " -- 2 change to wa:er -- :lean up well. , ,,- , ,. , ,,, . ,,. .... ... -, ,.. %~ ~ ~', ~ , ... ...... i i I I .i ,i . ; UNIC,q OIL CO. OF CALIFO, ,N IA MUD RECORD SHEET B I~AGE NO.. LEASE KENAI UNIT TYPE Lignosulphonate WELL NO. 43-6A FIELD KENAi GAS FIEI,D DISTRIBUTOR Baroid · W VlSC. W.L. PH SALT OIL SAlaD SOI~IDS I~EMAI~KS 8/25/6J. 260 73 60 - -. .... Spud'in mud 26 1054 78 70. 5 9 400 - 4% 15% 27 1054 80 75 4.8 9 450 - 4% 16% · 28 1400 78 44 8 12 650 - 3% [2.5 'Drill out shoe and cmt. 29 2440 77 40 7 10 380 - - 4% 14% · 31 4110 79 46 5.1 9.5 480 - 4% 14% 9/1/68 4800 80 60 4,0 9,5'550 7% 4,% 16% 2 5300 83 49 4,0 9.5 560 6% A% 1.6% i 3 5300 83 49 4'0 9 ~5 560 6% A% 16% · . , · , , . · · - _ . . . . _ - · · · . · · , · · · .. .. _ · i , '" Prepared For .......... Company ...... Date ...... -~ ~ , ;~ ~'-' _ ~ ~- ~ _ _~ ~~. . _ l iZLZ._~JL_-_~-___ _ ~~~_=~_._~.__ · · , . [ ' ~,-m'~-~--m~~- __,._~___,~~___~ -~..x . · ,, ' ..... ........... Printed in U.S.A. · rain III _ -. GENERAL DATA: Total Depth Mud Wt. #/Gal. & Le'vel Max. Hole Deviaiion Date ' Compl.eti"on TU~ULA~ ~ATA: Depth/ Depth/Top Bottom Size ~igh.t Grade Thread and Liner Tubing ~1 String . ~~, ~'7/~ O. ~ " ""~~ ' /~~'~; ~2 String ~/ -- ~ /~ ~ ¢3 String .... WELL DATA: Bottom Zone II Zone III Zone IV Zone V *Type Well ¢ Perf. Depth ~'~ ~ ~I~- BHP BHT Inj. Press. *Type Well F: Flowing, SI: Shut-in, P: Pump, GL: Gas Lift, I: Injection, O: Oil, G -- Gas, W: Water PACKER DATA: Bottom Zone II Zone. III Zone IV Zone V , Serial No. ~~ /_~' ~~ ~ Size and Type ~ /'~" 7~ Stinger Type ~ New or Repaired ~~ Stinger Release Value ~ A~ ~ooo~ Shear Release Value ~~ Depth Set ~ ~~ ~ ,. SE~ING DATA: ' Bottom Zone II Zone III Zone IV ~one V Compression -- lbs. /~, ~O ~ ~~ ' ' Tension lbs. Test Pressure ~. ~ Diff. Setting ~~ ~ ~~~2, I Seating Sub: Type.. '~ ~/~~ Pump Out Value Relatch Stinger Shear Value Casing Scraped ~ Yes . ,.. WAS TUBING AND/OR WELL HEAD MOVED AFTER PACKER(S) SET? YES ~ NO ~ Completion Procedure (Include any unusual occurrence) .~. , , Copies: Prepared by Warehouse Telephone DT Number ~ Customer . ~ Distrid Office DIVISION OF DRESSER INDUSTRIES, INC. BOX 1106 · DALLAS, TEXAS 75221 Prepared For Company Date Lease Well No. Field Co. or Parish State J ~ New Completion Size 7 Weight Grade Thread Depth ~~ Zw/~ '" Si ze Weight Grade Thread Depth LINER TYPE OF TU~ FO~ ST~ ~0. ~0~ ~u~'~ l ~:Z~,.,~ ..... .......... ~:.....C ......... l ~/..~ ..... .............' '~-', :.~<..c~:~~~ ....... ................... ~ ...................................... ~~~' ~, L~ I-7~'~~.~,, ~ ~,r~ ~~ , ~ ,q""~:.,., ~ (~ I0. 7~'-.zf~z .~/z~/~-~.w~~'-'~ 9:~:/ ~/zz~¢ ~r/.:/, ~;~ " d, Oq ~'~:~' /. . ,. ., " ~o,/ Y ~ ~¢1. '"' ~ ~:"" -- ~ 4 ~..(.,'/,~ ~" ~ . :~, , ._ /, ,, , ,, ,. 1(/. ~-q 4~,:~,,~:~~.~:__ ~?': ,, :~""' O'WS,ON OF ORESSE~ ~NOUSTRmS. ,NC. BOX 1106 · DALLAS, TEXAS 75221 Prepared For Co r~ i~Y Date ~.. 11. ~' Lease Well No. I Field Co. or Parish State I [] New Completion I [] Workover Size Weight Grade. Thread Depth CASING Size Weight Grade Thread Depth LINER ., TYPE OF TUBING. FOR STRING NO.,~_.~,,~..~..~'//C,~/.r.-- I ................................................. ~~::'~: .......................................... ~?0': .......................................... ~_,~~~'~/~ /0, t~ ::~~~ . . . , . . . . .... , , .... I"iIIVlSION Or IDRESSER INDUSTRIES, INC. BOX 1106 · DALLAS, TEXAS 75221 , , r Prepared For Company Date ~. ll-Z. ?o Lease Well No. J Field Co. or Parish State J []j~, NeWworkoverCOmpletion Si ze Weight Grade Thread Depth CASING Si ze Weight Grade Thread Depth LINER TYPE OF TUBING FOR STRING N 0 .,_~/_~/~Z? '~r" ,.,~,~/,j'b/~-- I s~, . I w~i~, I G,~a~ I T~,~a Depth ' ,, ,. ,, ,. z.o~ ~d~ 4o. . . . : · . . . ~x:/~. _~~/:~/:o~/~ :/-~: ) "'""' ~ ":'"' '~ .i~-~ z ., ,.',..-.':.,. ', ..:..:., , , , Form No. REVISED : JAN. I, 1969 STATE OF ALAS: KA suB.n* ~ vU'~LtCA'r~ OIL AND GAS CONSERVATION COMMITTEE Field Initial Kenai_ Gas Field GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4-.POINT TEST Test Annu,, El ReServoir .... . Kenai Sterlin~l Gas P~ool 4 Test Date 12-24-69 IWell No. 43-6AS 9~6-68 I 5300 MD 163' M 14~?~ ~280 ~D JGravity of Llq~ Ap() · Operator : ................... - .................. I- Lease Union 0il Co. of California I A 028142 ('ount~ I Lo~ati''~' SurfaCe': ........ 277r's' &"~279'E' f~om Kenai~ NW Corner Sec, 7, T4N~ RI IW, SH TemperatUre empe ~ ..... · .o. 96.' 7-5/e ~6.4/33.7 TriG. Size ~Vt/Ft. -' O:b.' ...................... i'[D[ s;t ;~ ~as a~avlty Avs. Prod. 2-7/8 6.4 2,7t8~ 2.441 4~56 6s:~g~ u~g~ 2418 Nikiski I Flange MuItiPl; Completion (Dual or Tripl;) ........................ ' ..... I '~p* P;°auct!°a f~0~ e~o~ S~' Dual~ ' I ' Gas OBSERVED DATA Flow Data Time -I~ (Prover) (Choke) LP/~s s. Diff. ~ublng Casing Flowing .~o. of Flow (Line) (Orifice) h Pre~s. Press, Temp. Hours Size SiZe psig w p~lg Pslg 'F s~ 24+ ....................... I~78 .0. ~ I}78 ...... Packer . ~ meter ,. I 3.826 2,500 .. 1.485 4 1555 .... Packer.. 102 ~. I'~ ' -3,826 ~ 2.500 1464 .. '9 ...... !533 ...... PacCor .. 96 s~ ' I, 3.82~ ' 2.500' 1430 16.40 1495 Packer' 88 - ' I ~" 826 2.500 ..... 1363 26 52 j432 Packer 88 * I soch rona I FLO%V CALCULATIONS Gravity Compress, Coeffi ...... Flow Temp. 1%1o. cient W-hw "~p Pressure Factor F~otor iFs,¢to~· Rate of Flow (24 Hr.) m psfa F F Q MCF/D t g pv ,-" ........... 34. 146I~ ..... 77,-456© ......... 1500 ..... 0':'961. 9 ............................... . 1.3423 ,.0699 ' 3'654 3423 I. 073 I ~. .34, t468 115,3780 1479 . 0.9671 I. ' .......... ' ......... 5488 ~. 34,..14.68 i53,9490 -1445''' 0.974.1 . 1.3423 ......... · J']'~9 '" 7402 ,.. 34,.1~,68 191. 1560 ' '1378 ' '0'9741 I"'342;~ ....... 1';'07'4i .........9167 PRESSURE CALCULATIONS Absolute Potential 1 n / MCF/D CERTIFICATE: I, the undersigned, state that I am tb~ Prod. £ngrot the Union Co. of (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 ther~e~ ~ ~1~15~ ~ compl~,~.t~S'i] the best of my knowledge. ........ ' Sig~'~ J.E. Church GAS WELL OPEN FLOW POTENTIAL TEST REPORT PRESSURE CALCULATIONS (Supplement to Alaska 0 & GCC Form No. G-I) Field Reservoir Test Date Kenai Gas Field Kenai Sterling G~5 P991 4 12-24-69 Operator Lease Well No. Union Oil Co. of California A 028142 43-6AS Surface Test Data (I) (2) (3')" (4) Test ps Pf' (Ps2- pf2) Q No. ,Ds, i..a _p$ia X '1~4 MCF/D ! 1593 1570 .... 7.27 3654 2 1593 1548 ' 14.13 5488 ~ 1593 151~ 25.75 7402 4 1593 1447 44.38 9167 Sub-Surface Test Data I--] Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith Method of IOCC. (I ) (2) I (3) (4) Test Pws Pw fI (Pws2-pwf2) Q No. psia p. sia X 10-4 MCF/O I 1746 1742 I . 39 3654 = 2 1746 1739 2.44 54,,8,,8 ., 3 1746 1734 4.17 7~n~ 4 1746 1719 9,35 9167 _ Nomenc I ature: Ps = Static surface pressure PT· = 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 ! -70 ! 2 .3 4 5 7 '8 9.10 30 40 50 60 7o 8o 90 200 2 3 8910 FLOW RATE, Q, mmscF/Day UNION OIL COMPANY OF CALIFORNIA WESTERN REGION ANCHORAGE DISTRICT KEN. Al. GAS. FIELD DELIVERABILITY AT THE $'d~O~¢~' Q, mscF/O = (Pws"-Pwf") INTERPRETATION BY DRAWN BY 20 30 40 50 60 70 ~- DATE STATE OF ALASKA AND GAS CONSERVATION CO/V~II~EE GAS WELL OPEN FLOW POTENTIAL TEST REPORT .:MultI-POIXT T~.ST Test Initial D Annual D Special J'iJ N ,~ 0 1976 Field j Reservoir Kenai Gas Field Pool 4 Oi)er;ttor I Lease ' Union 0il Company of California J A-028142 T~O. Size 2 718 coun,y iL°~"'i''n 277' N & 42?9' E from NW Corner, c=,~,a0nv,,, t to,.iD,,,h Kenai J Sec. 7, T~N~ Rl1~, S.H.. 11-2-70J ~00' ~ 95'~, 7 5/8 26.~-3~.7 6.~62 6.76 5280' ~D j ,,',,F,. J o.= j ,.D.6.42 7/8 2.441 s'~ ~ j ~'~'""" I *""~'°d' j GL j ~""~'~"""~'°"'~4403' 0.'s'~""'°'555 ~'~'~ ' 2444 ,.,,o ,,St ,., B~,. Test Date 7-14-75 %%'ell No. KU 43-6AL 63' 14407'-4534' MI}-: ,Pipeline Connection j Type Taps Nikiski PipelineJ Flange .~ultlple Completion (Dual or Triple) Dual jType production from each zone OBSERVED D,LTA Flow Data SI Time JJ (Prover) j (Choke) of Flow I (Line) (Orifice) Hours Size Size 1 t ~.826 J 2.500 1 J 3.826 I 2.500 1 ! 3. 826 i 2. 500 1 J 3.826 J 2.500 cient P (24 Hr.) m i ~4.147 I 66.115 34. 147 J 10_B.919 34. 147 I 142.322 34. 147 t 1~6.746 Press. j hDiff' psig ! w ~.20 8.41 15.80 32.86 Tubing [ Casing t Flowin.~ Press. Press. I Temp. psis' I psig I 13Fl J 1163 I 87° 82° 78° 75° Pressure psla FLOW CALCULATIONS Flow Temp. Factor F -t 0.~750 o. ~79_~ 0.9831 0.~8~ 1366 1_~4 1282 1~78 PRE~;SI.' RE CALCULATIONS Gravity ! Compress. Factor Factor F F g pv Rate of Flow ~ MCF,. D 1.3423 I 1.0886 ! 3216 1.~423 I 1.0908 ! 5187 1.3423 J 1.0909 ) 6996 1.~42~ j 1.0864 i 9659_ P w ~ Cal. .... (psla) ~ F Q (F q): iF Q)= X 1-e-~ P: P~ -- P~ P p .t c c c ~v e w w t ' ! 1. I Potential j n 18,3oo .,,c>-,pI .~057 :~~I~t~: L t~ ~.~e~si~. st~e m.: I .m ~- engineer ~t m~ Union 0i J Company Jeomp~), ~ ~t J ~m ~ot~ed b)' sai~ eomp~ ~o ~a~e ~is ~epo~t: ~.~ ~l Dis report was pared ~der my supervision and direc~on and ~at ~e facts slated thereto are true, correct ~d complete to ' :~me best of my ~owl~ge. /~/~ · ~m~ ' Gar~ E. CarJso~ GAS m"'q__ L OPEN FLOW POTENTIAL TEST RE;'~T_ _ PRESSURE CALCULAT I O:~S · '~(Supplement to Alaska'O & GCC Form No. G-I) Field Reservel. r Tesl Date Kenai Gas Field Pool 4 7-14-75 Operator Lease ~','ett 'Jo. Union Oil,,Company of California A-028142 KU 43-6AL Test ( I ) (2) (3) (~) Ps pf (ps2_ pr2) 0 No. os ~a ..... ~$ i e X 1 04 t..:CF/D.. 1 1388 1366 6.06 3216 ,, , 2 1388 1334 14.70 5187 3 1388 1282 28.30 6996 4 1388 1178 53.89 9659 Sub-Surface Test Data Subsurface pressures measured. 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' . , . ,t ~ ' ' I I ,' ' , /-- ',- ' / ' · , 1..o 2 5 l0 2o 5o lO6 GAS FLOW RATE }~CF/D GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi-POiNT T~.ST Test Inlti-',l O Annual J"-J Special JUN 0 1976 Field j Ite~ervolr Tea: Date Kenai Gas Field J Pool 3 7-14-75 Opcr;ttor Union 0|1 Company of California JLe~e x,X'~ll No. A-028142 KU 43-6AS coun~x j Co,.~ti,,, 277' S & 4279' E from NW Corner, Kenai J Sgc,.. 7, T4N, R1..[W, SM 11-2-70 Prs,ducin~ ThrUrlJG,Il CSO. ?,-,,,,,',-~'"~°'~ j ,,'.,h,. j =. s,.. ,,'t/Ft. ' J I.D. 6~ sec r~ X ~)3~ 84'~ 75/8 26.4/3]-.7 6.~6~/6.7 TUG.2 7/8Size ~Vt/Ft.6.4 2 o.D.7/82.I'D'441 4Set132' ~ O.(SvPar~t°rlGaS GriviJY555 Lell/[~AvJ'~ 1327'°~'{~1 2293G= Ga~.Liq,,dRilio MiFO Ii) Jr:earccap~r Bbl. Jl LJ'4~:d 0APi~ · Pipeline Connection i Nikiski J Flange ~Itlltlple L'ompletion (Dual or Tripl~) . J Type production from each zone Dual J Gas OBSERVED DATA Flow Data .... ·ime {Prover) (Choke) Pre~. Diff. ~ubing Casing Flowin~ ~o. o~ Flow I ~Line) {Orifice> h Press. Press. ~ Temp. Hours J Size Size pslg w pslg J psig I 'F 5288' I 4393' 60' 4173'7437¢ 4. 1. 1 t 3.826 1 ~ 3 .'82g 1 ' 3.826 1 J 3.820 ,i 2.500 2.5OO 2.500 3.24 ' 8'41" 16.48 1373 1338 I ~ 87© , 1308 i 83° ....... 1270 I ' 80o 35.22 1178 cient (24 1tr.) 34.147 I ..24. 147 i 34.147 J 34'.'1'47 'j p Pressure m psla 66.210 1353 ~ . 105.482 .1323 145.523 1285,.. 204.982 ,. 1193 FLOW CALCULATIONS Flow Temp. J Gravity J Compress. }'actor J Factor t Factor Rate of Flow -t g p¥ ' . '0.9750 ! 1.3423 J 1.0883 I 3221 ' 0.9786 ~ 1.~423 I 1.0895 i 5155 .. 0..9813. ! 1.3423 ! 1.0978 0.9850 I 1.3423 J 1.0867 7185 10057 CALCULATIONS w p: p, -- p~ , Cal. - (1)sla) P'-' ~ O (F O)' (P Q): x l-e-' P p t c c c w ¢ w w t . 28,300 .~,cr'p .7218 CERTIFICATE: I, the undersigned, state that I am th~,' eng i neer of the Un ion 0i1 Company (company), and that I am authortzed by said company to make th~s report; and that this report was pre. pared under my supervision and dtrect~on and that the facts stated, thereta are true. correct and complete to Ga~:Y . Carl son ENTIAL TEST PRESSURE CALCULAT I O~S (Supplemen~ to Ala~ka'O.& GCC Form No. G-I) Field Reservel. r Kenai Gas Field Pool 3 7~27~ate ........ " rotor Lease Well ~,~, ~ Union Oil Compa,~y of California A-028142 KU 43-6A5 ,,, Test ( I.) (2) (3) (4 Ps pf (ps2_ pt2) 0 No. I 13'88 1353 9.59 3221 2 1388 1323 17.62 5155 3 , 1388, 1285 27.53 7185 4 _ 1388.. 12Q,8 46.73 .... 10057 ,, i Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed' Cullender-Smith :.~el'hod of I~C. Nomenc I a tu re' Ps = Static surface pressure "Pf___= Flowing' surface pressure Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowin9 bottom-hole pressure (mid-point of perforations) Q = Flow rate, Mcr per day at 60°F and 14.65 psia I-?0 Back PrIure Tests Well :~~3-6AS Pool' Survey Date: 7-~4-75 1.O ~' '. 02 ''[Ll'tl'"~f'~'lf ;: ~*i "';"l"l ,' ;.. f i: '.';; :':. ~',' ':. :t:: /1'.'.1', ............ :,:.1, ..... :..::.,:.:,- II1,,t,,-- '+' ",l". . ,l,,:[' ...... ,.- ,,.., .:., ...... [ ..... ~: .......... '" l,,"" / :, , · . , ,,.,I ,,., .,::.. :,".!*" ....... " :,. ~ ' 'l'~' ' i ~ ' ' I .;,I .........i ............ I' ' ' ' ' ! ''''' ~ ' ' 1' ' ?t-~. 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I ............... · ~,[~","I," ',.,.! ' '. :". ~. ~' , ' r;.,:.. , ,..:.:..';.~ ..... I,~.~..~,; ::,:,;'.',,; ........ ',,~,:~; ;i! .~ ......I ............. ~'~"' -t"F~-'' ,-T';, .... ;,;'::-~-~;..:'t;'l'":": ........ : ":; ......... :* ' ' : ~' ..o -: .l .'.::-.. i:;,~',': .... l . ,.l ;; .... i .... , ........... -~:-': ; ~':::"[' ':;!'[:: .......~ i' ~ ..... ;~ .' .... ::;' "? '"' :;,' '/'; . :.i; ,.. .' ' -...~ i , '. ; .... - ........... .01 T;~I:;~'. ~,~::~':'"'~'~ ..... : i-~'" '~ ~:'~'"": ...... ;"::'t ...... ~', ...... ;'..":;;!...:.: ...... :..~.. J ........ 1..0 2 .5 l0 20 ~0 :lC OAS FLOW RATE . _ STATE OF ALASKA ~![ AND GAS CONSERVATION CO~1.'4 GAS WELL OPEN FLOW POTENTIAL TEST REPORT :Muitt-POIXT T~ST Test ]nllSal O A nnua! U Specla! 197o }'ltld Kenai Gas Field JiJe~erx'oir Pool 5.1 Test Date 7-10-75 Oper-'ttor J Lease Union Oil Company of California A-O28142 ¢'uunty Locati.n 205I S & 4231' E from NW Corner, Kenai Sec. 7, T4N, Rl lW, S.D. 6-13-65 To:Il Depth 5145.' ~Vtll NO. KD 43-6S J 126 !4593'-487;~ Ttmperature 70'F , 7 5/8 32.75 26.4 O.D. J I.D. J Set ~ 2.875 ' 2.441 4465' I.D. Set @ 1297' ~601' GL Ga~.LIq,.d H) J::c~r~cn Ratio )I(F per Bbl. 0 j Gri.r ,' o: I Li'4u'd0.'P')' Pipeline Connection Type Taps Nikiski Pipeline Flange ~lultlple Completion (Dual or Triple) J Type production from each zone Dual J Gas SI Time JJ (Prover) i (Choke) of Flow I (Line) (Orifice) Hours Size Size · OBSERVED DATA Flow Data I t Press. psig Diff. h Tubing Press. pslg 13~9 1362 Casing J Flowing Press. j Temp. psig 69° 3. 826 2. 500 4.00 3.826 J 2.500 8.41 ' 1337 69° 3.826 2.500 3.826 t 2.500 1300 1227 24.50 30.25 700 69° FLOW CALCULA. TIONS cient ~ h p (24 Hr.) , w m 34.147 ! 74.216 34, 147 { 106.632 34. 147 J .179.492 ~)4.147 J 193.831 Pressure psla 1377 1352 1315 1242 Flow Temp. Factor F t o.9~15 <).99]5. 0.9905 O.9915 Gravity Factor 'F g 1.3423 1.3423 1.3423 1.3423 Compress. Factor pv Rate of Flow Q Mcr D 1. 1054 i 3728 1. 1033 ; 5346 1.0999 i 8963 .... 1.0956 : 9651 PIII-:SSL' IrE CALCULATION.~ w , Cal. w 'p (psla) P:t F¢.q (F c q)~ (FC q): X 1° e-~ P:v.' P'C -- TMw P w } P ! , · .~J)~,'l U i e Potent l;.iJ I! 2-3- 400 Mc~"I> .6105 OERTI¥ICATE: I. the undersized. State ma~ I am lhe enqineer ot me Union 0il Company {~mpany). ~nd mat I' am au~or=ed by said comply to make ~ts report: and lhat ~I~ report was pre. ~ared under my supervismn and d~reenon and mat me tae~ staled thereto are Irue. correct ~d complete to ~e best Of my ~owlcdge. ~ s~n~ture ~ary E'. Carlson (Supplement to Alaska'O & GCC Form No. G-I) Field Kenai Gas Field Operator Union Oil.,.Company of California Reservol. r Pool ~.1 Lease A-O28142 Tesl Date ,,7,:,!0-75 ~',.~ I I '.~. KU 43-6S , , ,, (2) (3) (4) Test (I) Ps pf (ps2_ pr2) 0 No. nsi? 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. Subsurface pressures computed· 'Cullender-Smith :.iethoo of ' (I) (2) (3)" (4') Test Pws 0 ' (Pws2_pw~ 2) 0 No. psia psia ;,,' I0- 4. . ,-,,- .~?/.,.~, ..... · , .... · ] , Nomenc I ature · 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 1-70 Well: 3-6S Pool: Survey ~te: 7-10-75 1.0 .10 .05 .. 02 · O1 ~.0 2 5 10 20 50 100 GAS FLO¥! RATE Form No. G.1 REVISED : JAN. I, 196g STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE SUBMIT IN DUPLICAT~ GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4-POINT 'TEST Test Initial. [~ Annual D Speela! ~ Recompletion Field Kenai Gas Field Oper~at°r I Lease Union Oil Co. of California Kenai Unit (A-028142) County iLOcatiOn ~ surface: 277' S & 4279' E from NW [ C0mpletl0. D,t, Kenai Borouph[ corner Sec, 7, y4N,. RI.IW,r SM[ 11-2~70 Pr°ducin~ Thru JResets°ir I wellheadTBo.X J CSG. Tempera, ur. I' Temperature I C86' $h'i ,,'t/F~. "[ ' I'.D. ~ Set~ . 93'~ 148-51~ 7-5/8 26.4/33,7 6.969/6.76 IReservoir Kenai Sterling Gas Pool 3 5280 ' MI] TBG. Size I %Vt/Ft. ...2-7/8I, .6..4 Pipeline Connection Nikiski O.D. I 2r7/8 Multiple Completion (Dual or Triple) ..... D, ual , , ....... Test Date I 1-21-70 %Veil No. 43-6A$ 5300' M 60'M 4173- 4370 MD (Separator) Length (b) Ratio M('F per Bbl. Liquid (Apl) . 2.44l 4132 M .555 4132 2293 - - Type Taps FI anqe Type production from each zone Gas i , ,i i r i 111 11 il i1 ill i , i , , ill, , , , , O]BS~R¥~D ~ATA. Flow Data Stat i c , , , , Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing .~o. of Flow (Line) (Orifice) ~J..OOJ ~/V C-I- h Press. Press. Temp. Hours ~ Size Size psig w psig pslg S-~ " ' 24 ' 3. 826 ' 2.500 l~60' '- "' 1548 Packer ~. '"'i 3.826 2,500'" 1520 ..... 2.'89 1548 " Packer 66 '~.'" I ' 3.826 2.500 ' ! 485 5.76 1548 ' ~ Packer ' 6'6 ~.. .... I , , 3.826 2.'500' 1457 12..25 154.8 . "Packer. . 67. . .~.... I I. 3.826 2.500 1310 37..45 1548 Packer 65 *lsochronal test procedure fol lowed FLO%¥ CALCULATIONS Coeffi- , , Flow Temp. Gravity Compress. No. cient ~ --~/hw p Pressure Factor Factor Factor Rate of Flow (24 Hr.) m psia F F F Q MCF/D t g pv ,.] 45.835 66.59] 1535 . .9943 , 1.3423" ' . i,.09,49 . '33.23 ~... 45.835 92.93 1500 .9943 I .3423 1.'.0932 . 4630 ... a:.. 45.835 134.29 1472 .. 9933 . I. 3423 I. 09.12 . .6678 % .45.835 22,2.80 132.5 ... .9952 . 1.3423 . . I...0,847 .1!~024 ** ncl udes Fg: mcr/day PRESSURE CALCULATiONI ' P P Cal. w w p.a F Q (F Q)-~ (F Q)i X 1-e-~ p~ ps -- ps p · p · (psia) :t c c c w c w w P t e 1. ~.." see A';tached ''' ., , 3. 4. Absolute Potential { n 68,000 ~ZCF/D[ 0. 723 CERTIFICATE: I, the undersigned, state that I am tbs' Prod. Enur ct the Union 0{ { ..C,o. of Cai if. (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 sta ted the_~complete to the best of my knowledge, gn~a'~e si J.E. Church GAS WELL OPEN FLOW POTENTIAL TEST RETORT PRESSURE CALCULATIONS (Supplement to Alaska 0 & GCC Form No. G-I) f FieldK ,o · . Operator Union Oil Co. of California Reservo.~.,r Kenai - --., :.'.'.;- : -. . Lease Kena i ~ Surface Test Data (I) (2) (3) (4) Test ps Pf~ (ps~2~- pf2) Q No. ~sia .p$ia ~ I]~4 MCF/D 332~ I 1563 1535 8.68 ~.~ 2 1563 1500 19.30 4630 3 i563 1472 27.62 6678 _ 4 1563 1325 68.74 11,024 · ~tatic reservoir pressure at datum. 1710 . psia .. Sub-Surface Test Data [---] Subsurface pressures measured. ~ Subsurface pressures computed: Cullender-Smith Method of IOCC. (I) ('2)" (3) _ (4) Test Pws P~f (Pws2-Pwf2) Q - . No. : ~Psia ~sla X 10-4 MCF/O ~ . I 1701 I~ _ 4,41 332~ 2 1701 1665 12.12 46~0 3 1701 1668 11.12 667~ ,4 1701 1631 23.32 11-074 . , Nomenclature: : , ps = Static surface pressure ~ · p~'- = Flowing surface pressure Pws ="Static bottom-hole pressure Pwf = Flowing bottom-hole pressure · . Q = Flow rate, MCF per day at 60°F and 14.65 psia 1-70 5 6 7 8 9.10 ii). 2O 4 5 § 7 8910 · ,,( '.; i~:.~ :~.-~ FLOW RATE, G, mmscF/D~y - :. ........*.~!-:~!'._-~::~'*'* ': "' "' -- "-- FtG'u RE ................. N O. L_:.~::::_~-IUNION OIL COMPANY OF CALIFORNIA ' WESTERN REGION ANCHORAGE 015 TRIGT · ..... ' KENAI GAS FIELD '_- :-..--:. I DELIVERABILITY AT THE WELL NO.' ~"o/4~ POOL: K 5~-,r 'IP'O~I -~ Q, mscF/D = INTERPRETATION BY ZO 30 40 ll~? DRAWN BY $CAkE DATE 50 60 80 9o ~3o-, 2oo Form No. G-1 REVISED : JAN I, 1969 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT I~N DUPLICA'I~ GAS WELL OPEN FLOW POTENTIAL TEST REPORT 4-POINT TEST Test Initial. [~ Annual [~ Special k--1 Recompletion TBG. Size 2-7/8 Field ] Reservoir t Test Date Kenai Gas Field , ,K,enai,,, Ste, rl in9 (Gas. Pool .4) I 1-25-70 Operator t Lease ! %Veil Xo. Union Oil Co. of California Kenai Unit (A-028142) 43-6AL County / Location Surface: 277,N & 4279, E fromi ! .o.,.- i ,Kenai ,Borough , ,NW Corner,,S,e,c. 1,~,,,T4N, R,IIW~, S,M, ...... 11-2-70 5300'MD 153'M / 96 °F Ig'7/¢Z'F 7-5/,8,, ,.26.4/33.7...6.969/6.7 5. 5280' MD '"t/Ft. [' O.D. I I.D. [ Set @ I GasGra'lty ]Avg. Pr°d. i GL I Ga'~'Llq"ldltydr°e'rb°" Gra"ity°' (Separator) Length (L) Rallo MCF per Bbl. Liquid (Apl) 6.4 2-7/8 2.441 4403~ 0.55~ 4403 2444 - - ° Pipeline Connection I Type Taps Nikiski I Flange Multiple Completion (Dual or Triple) ] Type production from each zone Dual [ Gas .... · , , , h , 'r '1 , , ..... m -11.11= 11,11 111 , i1 , 3 , , - 1111 , i,ill,I I II I[ Il rr i Il II I11 I Il I Il I Ill I I , OBSERVED DATA Fiery ~ata Static , ,, Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing .~0. Of Flow (Line) (Orifice) F I.o~ i n9 h Press. Press. Temp. Hours ~ Size Size si 24 -, - , , - , , Packer ,, ,~, I 3,826' 2.500 1523 ~;. ~2 1555, Pac ke r 59 2. ...... I, ,3.826 2.500 1495_ 9. or) I ~ p~,-~or- ,, 60 3. I ' , 3.826 2.~00 1447 15.6R !~55 P~ 74 Producing Interval 4407- 4534 ~D *i soohrona I test procedure FLONV CALCULATIONS Coeffl-** Flow Temp. Gravity Compress. No. (24 cient Hr.) -~/hw Pm Pressure psia Factor Ft Factor Fg Factor Fpv Rate Q MCF/D of Flow '. 45-R=;5 77:~56 1538 1.0010 1.3423 I. 10"~6, 3928 2. n 116,585 1510 I .0000 1.3423.., I -IOO~ 5880 ~: i '' .... 151.413 I462 0.986,8, I .3.423 I - 0.8.~.,O, I , 7437 ,.. , , ., ,., 203.655, 1371, 0.9905. , I,,..34,2..3 ..... I,.,08,54 ....... 10,0,35 ** Includes F : mcf/cl~ly Prmsst:~E CALCULATIONS P P CaL w . .w (psi'-,) 1~ F q (F q)~ (P Q)~ X 1-~-s pi p~ _ ps p . p :t e c c w c w w P t 2. See Attached 4. , , r , , 1-i ,ITl , , ,] ~ , i i ,, , fr , ,, , ,r I ~ ,r , ,,,1 i hr, Absolute Potential [ n . 62 ~ 000 MCF/D[ O, 659 i " i i , 11 ~1 ,, ' ,,HI 15 ~r , , i ~ , i i ~ , , i , , 11 , 1111 11,1 , , , , CERTIFICATE: I, the undersigned, state that I am th., Prod.. Engro~ the Union O| I Cm, mi Cai ii. (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, c ect and complete to Signa~ j. E. Church GAS-WELL OPEN FLOW POTENTIAL TEST RE,--ORT PRESSURE CALCULATIONS (Supplement to Alaska 0 & GCC Form No. G-I) ,., F i e I d Reservo,~.r Test Date Kenai Gas Field Kenai Sterling G~ Pool 4 11-25-70 ' Operator Lease We l I No. Union Oil Co. of 'California~ Kenai Unit (A-028142) ,, 43-6AL ,,, ... Surface Test Data (I) (2) (3) " (4) Test ps ~pl. (Ps2- pr2) Q No. . bsia _~sia X '1~4 MCF/D, I 1570 1538,. 9,9~ 397R 2 1570 1,510 18.48 5RRn 3 I 1570 1462 32.75 7437 4 1570 1371 58,5~ , 10035 _.Static reservoir pressure at datum, 1727 psia Sub-Surface Test Data Subsurface pressures measured. Subsurface pressures computed: Cullender-Smith Method of IOCC. .- (.I) ('2) (3) (4) Test Pws .P~f (Pws2-pwf2) Q No. ~ psia,, ]]Psla._ X I0 _4 MCF/O I 1719 1705 - 4.80 3928 . 2 1719 ,,1703 5.48 ~RRn ~ 1719 1685 .... 11.58 7437 4 1719 1664 18.61 10.035 . , Nomenclature: PS = Static surface pressure P~' = Flowing surface pressure PWs =-"Static bottom-hole pressure Pwf = Flowing bottom-hole pressure Q = Flow rate, MCF per day at 60°F and 14.65 psia 1-70 . -. 3 4 5 6 3 4 5 6 78910- ~._::::::.:_'~' UNION OIL COMPANY OF CALIFORNIA ~ ' -" WE$'~'RN REGION ANCHORAGE DIS TRICT · --", 'KENAI GAS FIELD' . ? · , DELIVERABILITY AT THE "~:: ;: , FLOW RATE, O, mmscF/Doy · , , . · T**: 2 ..... WELL NO.' O, mscF/D = INTERPRETATION BY )~./~<:) (Pws~-Pwf=) DRAWN BY ! ! 20 30 40 50 ?0 8o 9o DATE } . KU 43-681 Pressure SurVey Well: KU 43-681 Field: Kenai Gas Field Borough: Kenai Slickline Company: Pollard Wireline Bomb Type: McAIlister quartz Gauge Number: Gauge #1 Date: 11-Jun-99 Perfs: Pool 4 MPP: 4,472' 3,885' KB-THF: 26.0' MD Depth Depth (MD) (TVD) Pressure Pressure Temperature Gradient (psia) (deg F) (psi/fi) Temperature Gradient (Deg/100 ft) 0' 0' 283.40 72.4 3,000' 2,643' 297.48 68.3 0.005 - 0.154 4,000' 3,485' 302.40 79.2 0.006 1.292 4,272' 3,714' 305.07 90.9 0.012 5.100 MPP: 4,472' 3,885' 304.74 84.3 0.006 1.292 Datum: 4,778' 4,146' 306,26 87.7 0.006 1.292 Annular Flow Only 4,272' 3,885' Surface Measured Meter Depth Depth FBHP Pressure Delta-P Gas Rate, Building, (MD) (TVD) (psia) (psia) (psi) ,(,,,M .cfpd) (p~,ia). 283.80 243.10 21 3,398 231.2 Tubing Flow Only 4,272' 3,885' 297.78 233.40 7 1,922 227.8 Figure 2 o:~saphir~kenai~sterling~3-6as~06-99~sbhp99.xls i . [ [[ LABORATORY TESTS RESULTS 08/02/99 GLIEMT l.D ......... ~ 14-X6L-Steriing CompLetion DATE SAmPLeD ....... TIHE 9ANPLED ....... : 00;00 ~ORK DESCRIPTION...: Natural Gas SampLe Extended NaturAL Gas Anatya'le Oxygen ~itrogen Carbon Dioxide Methane Ethane Propane laobutane n-~utene n-Pantene Hexanet Piu~ Tote[ Relative Der~|ty ¢~m~aressibitity F~ctor Gros~ Heating Va~ue (Dry/ReaL) Ne: Heating VaLue COry) 2,g-DimethyLbu~ane A-MethyL Penta~ S-NethyL Pen[one n-Nexane Hethy~cyclop~tene B~zene gyc[ohexene 2-Methyl Hexane 3-NethyLhexane OJmethyLcy~Lo~ntene~ n-Heptane MethyLcyeLehexane Tr~thyLcy~Lepentane~ ToIue~ 2-Mm~hyihep~ane 3-Me~hyLheptane D{~thy[cyc[oh~anec n-o~tane E:hyt Benzene C9 Puraff{n~ n-Nonane ~' Decanes PLus Hexanea PLu~ NoL WT Hexane~ PLus ReLative Defla~:y flexanes PLus Heat{rig VaLue ~exanes PLus Vapor equivalent 0.01 0.03 0.12 ~.70 0.10 <0.01 <0.01 <0.01 <0.01 <0.01 100.00 0,5~81Z 0.99B02 1013.4 912.6 <0.001 <0.001 <0.001 <0.001 ~0.001 0.001 ,<0.001 <0.001 <0,001 <0.001 <0.001 0.001 <0.001 0.002 0.002 <0.001 0.002 <0.001 0.001 O.OO& O.OOZ O.OOZ 0.021 127.4 0.7825 6656.1 19.45Y LABORATORY I.D...: 993289-0003 DATE RECEIVED .... : 07/28/99 TIME RECEZVEO .... : REHARES .......... : '1 0.01 0,01 0.01 0,01 0.01 0.01 0.01 0,01 0.01 0,01 0.01 0.01 o o 0 o.o01 0.001 O,OD1 0.001 0,001 0.001 0,001 0.001 0.001 0.001 0.o01 0.001 0.001 O.O0~ O. 001 0.001 0,001 0.001 O. 001 O. 001 0.001 0.001 o. o01 o. o001 0.1 o. OOl Not g Hot ~ Mol ~ Mot · MoL 2 MoL · MoL V. HoL MoL X Hot ~ 4oL ~ ITU/CF 14.696 BTU/CF (Real) MoL % Hot ~, Hot ~ Mol Y, Hot ~ Hot ~ Hot ~ HoL ~ HoL ~ MoL ~ HoL ~ MoL · Hot ~ MoL ~ MoL ~ MoL ~ ~L ~ MoL ~ ~oL ~ JMot X MoL ~ Mol ~ W~-mo L iB~/CF (IdeaL) CF/gaL GPA 2261-95 GPA 2261-05 GPA Z261-95 GPA 2261-95 GPA 27.~1-95 GPA 2261-95 GPA 27,61-95 [GPA 27-61-95 OPA ZZ61'9~ GPA Z261'95 GPA 2Z61'95 GPA 2172-96 GPA ~172-96 GPA 2286-95 ~A 2286-95 GPA 2286-95 GPA 22~-95 GPA 2286-95 GPA 2286-95 ~PA 2286-95 naA 2286-95 GPA 2286-95 GPA 2286-95 GPA 228&-9~ GPA a286-gS GPA 2206-95 OPA 2286-95 GPA 22B6-95 GPA ~.8~-~ O~A GPA Z256-95 GPA 2286-95 GPA GPA GPA GPA 2286-95 GPA 2286-95 GPA 2286-95 O8102199 TS~ P 0 BOX 3~,766 HOUSTON, TX (713) 9~3-9776 iiii i i i PAGE:2 7723&-~282 RECEIVED 'l$1Obl OF MH',!~5 ~ ANCHOf~ REPORT and PLAN of SUB-SURFACE SURVEY UN ION OIL COMPANY KENAI UNIT 45-6A KALIFONSKY BEACH, ALASKA JOB NO SEPTEMBER 1968 DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA MEASURED DEPTH 2712 2922 3103 3300 3515 3794 4038 4342 4716 4882 5300 DRILLING CONTROL CORP. 8UItVEY DATA SHEET 8H EET NO._ COMPANY WELL 43 - 6 A DRIFT ANGLE 35° Q0~ 34° 00' 33o,,,30' 33° 00' 32° 30 ' 32~ 00~ 32° Q0 ~ 32° 15' 30° 45 ' 30° 00 ' 35° 00' Union O~ ] Cc~y TRUE VERTICAL DEPTH DATE_ September 196 ~8_ FIELD~liforn~ Be:~_ch__ . COUNTY~ IDE~qAT~ON COURSE DRIFT DIRECTION JOB NO. 2385 N 01° E 2559 N 03° E 2710 N 02° W 2875 N 03° W 3056 N 07° W 3293 N 03° W 3500 N 04° W 3757 N 03° W 4078 N 03° W 4222 N 03° W 4564 N 06° W N 040 12" E BTATE -~--~ BECTANGULAR COORDINATES SOUTH i. EAST 262 268 265 259 245 737 228 220 210 205 108 17 74 7] 2: 2-,' 8.' WEST NORTH 1069 99 1187 26 1287 10 1394 24 150@j, 90 1656, 54 15@5 i3 2138 ~9 2221 ~8 2459 REMARKS DRILLING CONTROL CORP. SHEET NO. flUI~,VEY DATA flHEET GOMPAN¥ bhion Oil .CC~..v DATE Sepk~m~b~_r._lR6~ joe No._ WELL. 43 --' 6 A _._ FIELD~_ P~aC.~. ___ COUNTY__ 8TATE~q~a ,,, TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEV]AT]ON DR/FT DEPTH ANGLE VERTICAL COURSE D]REC~ON - REMA~ DEPTH NORTH SOUTH EAST WEST · , ,,,, ..... 207 1° 15' 206 9~ 4 51 North 4 51 267 0" 45' 266 95 79 N 23° E 5 24 31 327· 4° 00' 326 80 4 19 N 300 E 8 86 2 40 390 4° 30' 389 61 4 94 N 42° E 12 53 5 71 450 4° 00' 449 46 4 19 N 35° E 15 97 8 11 575 4° 45' 574 03 !0 35 N 40° E 23 90 14 76 635 7° 00: 633 58 7 31 N 32° E 30 !0 18' 63 728 7o 00' 725 '89 11 33 N 35° E 39 38 25 13 745 8° 15' 742 71 2 44 N 35° E 41 38 26 53 833 15° 45' 827 41 23 89 N 29° E 62 28 35 11 927 22' 45' 914 10 36 35 N 27° E 94 67 54 61 987 23° 45' 969 02 24 16 N 20° E 117 37 62 87 1024 28° 15' 1001 51 17 51 N 17° F., 134 12 67 99 f.- 1054 20° 30, 1027 46 15 ~3 N 17° E 148 6'8 72 45 1286 31° 00' 1226 33 119 ~8 N 17° E 262 94 107 39 1434 31° 30' 1352 52 77 33 N 21° E 334 14 135 10 1742 33° 00' 1610 84 167 74 N 17° E 494 [55 184 15 1865 34° 45~ 1711 90 70 L1 N 15° E 562 27 202 30 2051 36° 45' 1860 94 .111 !9 N 13° E 671 71 227 34 2209 38* 30' 1984 59 98 36 N 13° E 767 55 249 47 · 2270 40° 00' 2031 32 39 !1 N 13° E 805 75 258 29 2300 41° 30' 2053 79 19 38 N 10° E 825 33 261 74 2330 39° 45~ 2076 36 19 L. 8 N 07° E 844 37 264 05 ' 2465 37° 30' 2183 '~7 82 [9 N 01° W 926 55 262 65 , 2550 36° 30' 2252 30 50 ~6 N 02° W 977 08 260 89 · ..... . i i i i ii i iii ,~ ~ --- i . i ............ DEPTH- 5300' ............ i~, .................................. i :' ........................... ..* .................... ........ ~':. ~. . ' ' - -~ :~ : : NORTH;- EAST - 180.83' 2.459.83' - ; · I" = 200' i ¢ ' ' " i i 3515' · -- ~ 2550' .; 2209' · ' .. 1286' _ _ . i 835' ' ' i i i i i ii i] i ~o~ ~o. ~-~ STATE O'F ALASKA O~L AND GAS~CONSERVATIO'N CO~I~EE SUBMIT IN DEPLICATE ~NIONTHLY REPORT OF DRILLING AND WORKOYER OPERATIONS O~L L_~ ~s ,~ ELL W ELL OTHER 2.N;i%IE OF OPI~%ATOR U4i0n 0il Comoanv of California 3.ADDRESS OF oPEP~ATOK 507 W. Northarn Lights Blvd.. Anchorage, Alaska 4.LOCATION O,F WEI2L 277'S & 4279'E from lqW corner Section 7, T4N, RllW, SM 99503 5. APl NUACERICAL CODE ~0-1~3-20121 6. LEASE DESIGNATION AND SEtRIAL NO. Anchorage 028142 IF INDIAN, ALOT1EE OR TRIBE NA.AIE 8, UNIT,F,ki~M OR LEASE N.A.ME Kenai Unit g. WELL NO. 43-6A 10. FIELD A_ND POOL, OR WILDCAT Kenai Gas Field 11. SEC,, T., R., 5{., (BOTTOM HOI2E OBJECTIVE ) Sec. 6, T4N, RllW, SM 12. PER1VIIT NO. 68-51 13. REPORT TOTAL DEPTH AT END OF MONTH, CILkNGES IN I4OLE SI~E, CASING AND CE1ViENTING JOBS INCLUDING DEPTH SET ANI) VOLU1VIF~ USED, PF~R~ORATIONS, TESTS AND I~SULTS, FISHING JOt~, JLrNK IN HOI~ A_ND SIDE-T~LACKED HOLE AND A_NY OTHER SIGNIFICANT CI~klX[~ IN HOI~ CONrDITIONS. KENAI UNIT 43-6A, AUGUST 1968 SPUDDED 1:15 AM 8/25/68 Drilled 12-1/4" directional hole to 1286'. " Opened 12-1/4" hole to 17-1/2" hole to 1286'. Ran 31 Jts 10-3/4", J-55, 40.5#, Armco Seal Lock casing. Hung with shoe @ 1250'. Cemented with 790 cuft class "G" cmt w/42% Diacel, 6% gel and 2% celloflak, followed by 900 sx class "G" cmt w/3% CaC12. Good returns to surface. Drilled 9-7/8" directional hole to 4038'. Now drilling. 14. I hereby s~G~ ~.r .'.~z~4~ ~T~ p~S~. ~. SUPra. ~','~ 9/~0/68 , " U - ~ - NOTE--Report on thi~form is required for each calendar month, regardless of the status of operations, an~ must file~ in duplicate with the Division of Mines/--& Minerals by the 15th of the succeeding month, unless othe~ise directed. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY -- Form approved. Budget Bureau Bio. 42-R356.5~ LAND OFFICE .: L~s~ .u~a~. Auc, 028142 Ken~t LESSEE'S MONTHLY REPORT OF OPERATIONS The /ollowin~ is a correct report of operations and p'rod~ctio~ (includinv, drillin~ and producin~ wells) for the month of.. ....... ~gg~g .... ~ .................. 19_~_, ............................................................................ ~ent's address 507 W. Northern L~hts Blvd, _ Comnan, Union 0i~_..~.9.~.~.9~...9.~_..~.~.~ . .. ..... ........ .......... phone 279-4511 8~ent's tit~e ..... ~a~_... SEC. &ND TWP. !RAI~GE WELL D~rs CU. FT. OF GAS OA~LONS OF ' BARRSLS 0~; REMARKS ~ O~ ~ [ NO.' Paooucg~ BARRE~ OF OIL' ORAVITY (~ thousands) GASOLINE SVATSR (I1 (I~ drilling, de~th; if shut down. RECOVERED BO~O, so state) date and r~ult of tes~ for . ' . .... con,eat o~ .... . ........... . ............ . KENAI [~NIT . . . SPUDDED i:15 ~1 8]25/68 - Drilled L2-11'4" 'directional. aole :o 1286'. Opened 1~-1/,?~ho]e to 17-1/2" ho..o to 1286',. Ran 31 J.s ~}-~/~'~, J-55, 40~.5~I A:'mco Seal Iock casing. ~un~ ~t~ sh~e ~ ]250~. Ce~ente.~ ~th 790 cu f~ cl~s "G" cmt ~th 62g D~ace] ~.6g gei a~d 2; cel2 oflak followed ~y 900 ~x {las~ "G": cmt ~t~ gg C~Cl2. Good ret[ms :o s~[rfac~ . Drilled ~-7/ ;" d~ect~onal hole t~> ~Og8~. Now ~ril Ling . , , . . . - , , .../ ~. ....... .. ,~ ............... NoT~..--There were .............. ._ri_Q~ ................... runs 'or sales of oil; ................ D_Q ......................... M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~.--Report on'this form is required for each ca.lendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of ~he succeeding mc. nth, unless otherwise directed by ~he Supervisoc. Form 9-329 ' (January 1950) u.s. GOVERNMENT PRINTING OFFICE: 1964--0-729-.794 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALA~A OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do noi use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEH~IT--" for such proposals.) 0IL ~. OAS ~-~ WELL WELL OTHER 2. NAME OF OPERATOR Union 0il CompAny of California 3. ADDRESS OF OPE~LkTOR 507,, W, Northern Lights Blvd., Anchorase, Alaska 4. LOCATION. O,F WELL At surface 277'S & 4279']/ from NW corner Section 7, T4N, RllW, SM 13. ELEVATIONS (Show whether DF, 3~T, GR, etc. Il. ~ ' Check ApprOPriate Box To I,ndkate N~ature of NOtice, Re §. AP1 NUM]~'{ICAL CODE 50-133-20121 6. LEA~E DE~/GNA'I'ION A.ND SERIA~ NO. Anchorage 028142 7. IF INDIA~, AJ.~O'I-I's:s: OR TRIBE NAME UNIT, Fa OR LEASE NAME Kenai Unit 9. ~VELL NO. 43-6A 10. FIELD AND FOOL, OR WILDCAT Kenai Cas Field 11. SEC.; T., R., M., (BOTTOM HOLE OBJECTIVE) Sec.' ~ T4N~ RllW; SM 12. PEP.MIT . 68-51 NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I ] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDONs REPAIR WELL ] [ CHANGE PLANS (Other) Change of Surface Location SUBSEQUENT REPORT OF: FRACTUR~ TRIATMENT ALTERING CASING SHOOTING OR ACIDI-ZING ABANDONMEN'Te (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletton Report and LoS form.) 15. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an? proposed work. RECEIVEO DIVISION OF MINES & MINERALS - ANCHORAGE CONDITIONS OF APPROVAL, IF ANY: TITLE ~; ~ C. DATE See Instructions On Reverse Side FORM SA - I B 125~5M 8/67 TO: J-- jll~~ State of Alaska DATE SUBJECT= FORM SA-lB 125.5M 8/67 MEMORANDUM TO: F~~~ State of Alaska FROM: ~ ~ J~ ~Jll~J, DATE : SUBJECT: ~ SUBMIT IN TRIP~ rE Form P--1 (Other instructions reverse side) REV. 9~30-67 STATE O,F ALASKA OIL AND GAS CONSERVATIO'N ,COMMITTEE , APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 11~. TYPE OF WORK DRILL [] WELL WELL OTHER ZONE 2. NA~E OF OP~TOR Union 0il Company of California 3. ADD~S ~ OPhiR 2805 Denal5 Street, Anchorage, Alaska DEEPEN [-1 PLUG BACK 1--] MULTIPLE ~ ZONE 4. LOCATION O'F WELL ~%tsurface Approx. 205'S & 4581'E from NW corner Sec. 7, T4N, RllW, S.M. (Drilling Island #1) At pro~osed prod. zone Top "B" Interval' 1875!N & 5007W from SE corner Sec. 6, T4N, RllW, S.M. ~ : ~, 13. DISTANCE IN MILES AND DIRECTION FJ~OM NEAREST TOWN OR'POST OFFICE* 6.5 from miles "- l(enal API 50-133-20123 5. 6. LF~SE DESIGNATION AND SIgRIAL NO. Anchorage 028142 7. IF II~DIAN, ALX~ OR TRIBE NAIVE 8. UNIT~FARM OR LEASE NA1ViE Kenai Unit 9. WELL NO. 43-6A 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., (BOTTO1V[ HOLE OBJECTIVE) Sec. 6, T4N, R11W, S.M. lg. 14. BOND INFORMATION: Statewide United Pacific Insurance Company B-55572 TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* :- - ' "' ~ : -.- 'i16~ .NO. OF ACRES IN LEASE LOCATION TO NEAREST ~ . . PROPERTY OR LEASE LINE~ FT. - (AL~o to nearest drig, unit, if any) . "{~. DISTANCE FROM PROPOSED LOCATION* - : " ' 119. pRoPOSE~D DE~P~rI TO NEAREST WELL DRILLING, COMpLET .~l), - ' ' /' ' ' , OR APPLIED FOR, FT. ' -450:, ~*- [5182 MD & 4459 VD · ,..~o-,,t $100,000.00 17. NO, ACRES ASSIGNED TO THiS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) ~.9., APPROX. DATE WORK WILL START* RT 90' 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF C/K~IN : WEIGH~tPER rO~' GRAD~ [' S,rI"rlNG' DEPTH ' qUANTIT, OF CEMEN~ 15~" ~ 10-3/4" 40.5~ 'J-SS 1200' 1000 sacks 9-7/8" 7-5~8" 3~. 7~ N-80 5250' 500 " - ~. . . . ~ . ~ - ,. Cement 10-5/4" casing in 15½" hele at 1200'. Install 10" 300.0# BOPB. Drill 9-7/8" directional hole to 5250'. Run electric logs. Cement 7-5/8" casing. Complete for production. * 43-6/is productive in~ ~{odUle 5 1 (B-3 & B-4 sands)and Module 6 (C-1 and C-2 sands). 43-6A objective is Module 4 (b-1 and B-2 sands) and Module 5.2 (B-5 sand). Bottom Hole Location: Approximately 2200'N & 500'W from SE corner Sec. 6, T4N, RllW, S.M. IN ABOVE SPAC-~ DESCRIBE PROPOSKD PROGRkM: If proposal is to deepen or plug back, give data on present productive zone and propased new productive zo~e. If Pr(~posal i~ to drill or deepen direct:onally, give pertinent data on m~bsur~ace l~cation~ and measu~d a~xd true vertical depths. Give blow, ut preventer program. ~g41 ~I hereby certify that~F~oing is True and J~orrect (This sp~ce ~or State office use) C~DI~ONS OF ~PI~DV~, IF ANY: S~%iPLES AND CORE CHIPS REQUll~ / (yrI~ I~U~TS: District Land Manager [ DI/~CTIONAL SURVEY REQUn::LgD YES [] NO A.P.I. NU1ViERIC~ CODE f J~ · Inmu~i°ns On ~~t~~'~ June 3~ 1968 33- 30 N I ._32 K D.U I 43-6 (~ 43-6A ¢7o'1 I . I I _ I ~ I - 43 -7 -t- ,33 T 5N- RIIW T4N-RIIW PBHL TMD 5250' TVD 4450' TOP"B" TMD 4450' TVD 3800' UNION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION PLAT KENAI GAS FIELD 43-6A OAT E: APRIL, 1968. 0 ZOO0 ' ' 1 SCALE I" = 2000' I