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199-024
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2, Cement Packer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 4215, 4260, 4395, Total Depth measured 8,110 feet 4500, 4915 feet true vertical 7,565 feet N/A feet Effective Depth measured 4,190 feet N/A feet true vertical 3,838 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 4,392' MD 4,015' TVD Packers and SSSV (type, measured and true vertical depth)N/A; N/A N/A N/A N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi126' 1,502' 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi Casing Structural 20" 13-3/8" 9-5/8" Length 126' 1,525' 5,810' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-038 23 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-024 50-133-20487-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Kenai Beluga Unit (KBU) 33-06 N/A FEDA028142 5,810' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Sterling Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5,329' WINJ WAG 0 Water-Bbl MD 126' 1,525' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:45 pm, Apr 09, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.09 11:23:32 -08'00' Taylor Wellman (2143) SFD 4/15/2021DSR-4/12/21 Sterling 5.2, 5.1, 4, and 3 Gas Pools SFD 4/15/2021 BJM 7/16/21 RBDMS HEW 4/13/2021 Rig Start Date End Date 2/3/21 3/18/21 02/17/2021 - Wednesday PTSM, prepped pad, serviced rig. Laid out felt & liner, spotted base beam, rig carrier & aux eq, r/u circulating lines, installed berming. Checked well, 1,081 psi on tubing, 38 psi on annulus. R/U lines to circulate. Bleed pressure off, pump @ 3.5 bpm, took 36 bbls to catch pressure, cont pumping 66 bbls before getting returns, cont pumping @ 3.5 bpm losing 120 BPM while pumping @ 102 bbls away pressure started dropping, & lost returns, cont. pumping another 20 bbls with no returns, shut down both tubing & annulus on vac, secured well & blew down lines. SDFN. Night watch rig. 02/18/2021 - Thursday 02/19/2021 - Friday PTSM, check well on vac, blow through surface lines good. Set BPV, N/D tree. Prep wellhead, cap injection line, install test dart. N/U BOPE Tq. flanges, install rig floor & stairs, r/u accumulator lines, build test joints, function test BOPE from remote good, spot pipe skate, install floor hand rails. R/U gas system, calibrate & test good. Modify hand rails as needed for r/u, night watch rig. PTSM, blow through lines, r/u test eq. Fill surface eq. shell test 250/2,500, had bleed off issue, troubleshoot, found bad needle valve, c/o same & cont. test good. Test BOPE as per Hilcorp & AOGCC requirements, test witness was waived by AOGCC inspector Jim Regg & BLM inspector Allie Schoessler, tested w/2-7/8" & 3-1/2" TJ's, 250/2,500. R/D test eq., blow down lines, pull test dart, pump 2 tubing volumes, m/u landing joint. Back out L/D pins, pull hanger off seat 19k, put 1-1/2 turns in pipe while working pipe up t/ 35k, dn t/20k, packer came free on up stroke @ 27k when turn reached packer. Let elements relax 10 min. pull hanger t/ floor & l/d. Cont. POOH f/ 4,505', t/ 4,011', l/d 2-7/8" completion, spooling chem injection line f/483', l/d chem. mandrel, pump 5 bbls down annulus every 20 min. Blow down surface lines, secure well. Night watch rig. 02/20/2021 - Saturday PTSM, check well on slight vac, blow through surface lines good. Cont. POOH f/4,011' l/d 2-7/8" completion, had full recovery, l/d total of 141 jts, 1-chem inj mandrel, 1- sliding sleeve, x-nipple & 9-5/8" AS1-x packer. R/U e-line, rih w/8.5" GR/junk basket, tag at 4,509' WLM, was sticky off bottom, POOH. P/U 9-5/8" CIBP, RIH tag @ 4,509', p/u placing top of plug @ 4,500', set plug, POOH, drop back down & tag top of plug @ 4,500' good, POOH r/d w/l. Attempt to fill hole, pump 389bbls with no returns, consult with ops engineer for options, blow down, secure well for night. Night watch rig. 02/03/2021 - Wednesday PTW/JSA with Cruz vac truck operator and HAK wellsite supervisor and production operator. RU hot oil truck to IA. Initial pressures. Tubing 1,100 psi, IA 500 psi, OA 0 psi. Pressure test lines to 250/3,500 psi. Open IA valve. Online with 60/40 Pressure up well and shut down. Double block pump. Start 30 min test at 1770 psi. Ending at 1,762 psi. Good test. 4.2 bbls used to pressure up for IA MIT. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06 50-133-20487-00-00 199-024 P/U 9-5/8" CIBP, Start 30 min test at 1770 psi. Ending at 1,762 psi. Good test. 4.2 bbls used to pressure up for IA MIT. Attempt to fill hole, pump 389bbls with no returns placing top of plug @ 4,500', set plug, Rig Start Date End Date 2/3/21 3/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06 50-133-20487-00-00 199-024 03/02/2021 - Tuesday Sign in. Mobe to location. PTW and JSA. Spot and rig up lubricator. MU perf gun. PT lubricator to 250 psi low and 2,500 psi high. TP - 1,020 psi. RIH w/ 2-1/8" x 10', 6 spf, 60 deg phase Strip gun and tie into OHL. Run correlation log and send to town. Bleed pressure to 728 psi. Got ok to perf from 4,265' to 4,275' with 728 psi on tubing. Spot and fire gun. Good indication it fired. After 5 min - 730.2 psi, 10 min - 732 psi and 15 min - 733 psi. POOH/All shots fired could not tell if wet. Rig down lubricator off tree. Put night cap on and turn well over to field. Rig rest of equipment down. 02/24/2021 - Wednesday MIRU slickline and READ cased hole equipment. Run Memory CBL from 4347' to surface. Download data looks good, TOC @ 2770'. RDMO 02/22/2021 - Monday PTSM, Break down subs, clear rig floor, suck out pits, r/d gas detection system, n/d BOPE. Prep wellhead, get with production & welder for tree orientation, n/u tree, test void t/5,000 good, clean pits. Pull BPV, install TWC, test tree, t/5,000 good. Pull TWC, displace water from tree & freeze protect with diesel. Prep to l/d mast, cont. pack up circulating & accumulator lines, take down berming, load eq. on trailers. Scope down mast & lay over, clear liner of eq. & roll up liner & felt, SDFN. 02/21/2021 - Sunday PTSM, check well on vac, blow down lines, fill 30 bbls no returns. R/u E-l. ine, rih w/ 9-5/8" CIBP, pull up into set depth @ 4,395' top of plug, set same, good indication set, pull up 50', rih tag plug @ 4,395', POOH r/d e-line. Fill hole, 56bbls, test 1,500 psi f/30 min good, blow down lines. P/U 2-7/8" shoe track, & 1 joint 3-1/2" check floats good. Cont. RIH t/ 4,376' P/U 3-1/2" 9.2# L-80 IBT liner w/ centralizers every other joint for first 40 joints, filling every 5 joints. Cont. in hole f/4,376' to tag CIBP @ 4,396', up wt 30k, dn wt 25k, POOH l/d joint & p/u space out pups & joint. M/u hanger & landing joint, land same, RILD pins, placing shoe @ 4,392', landing collar @ 4,357'. R/U break circulation with rig, good, r/u cementers, PJSM with all involved. Halliburton Cement unit pump 5 bbls flood lines, shut in & PT lines 1,000/4,000 good, pump 20 bbl fresh water spacer, batch up 15.3ppg cement & pump 104 bbls @ 4BPM 100psi, shut down, drop dart, displace with 38bbls fresh water, FCP 750 psi @ 2.5 bpm, bump plug pressure up to 2,300psi, check floats good, Cement in place @ 21:20 shut in annulus. Blow down lines & cleanup cementers. l/d landing jt. set BPV. Night watch rig. Run Memory CBL from 4347' to surface. batch up 15.3ppg cement & pump 104 bbls @ 4 Got ok to perf from 4,265' to 4,275' h w/ 9-5/8" CIBP, pull up into set depth @ 4,395' top of plug, set same, Spot and fire gun. MIT-IA and MIT-T passed to 1500 psi on 2/23/21 - BJM @ 4,392', /U 2-7/8" shoe track, & 1 joint 3-1/2" check floats good. Cont. RIH t/ 4,376' P/U 3-1/2" 9.2# L-80 IBT liner w/ centralizers every other joint for first 40 joints, Fill hole, 56bbls, test 1,500 psi f/30 min good, See attached files.TOC @ 2770'. RILD pins, placing shoe @ Rig Start Date End Date 2/3/21 3/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06 50-133-20487-00-00 199-024 03/17/2021 - Wednesday Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi. RIH W/ 2.75" OWEN CIBP. PULLED CORRELATION PASS. SEND PASS TO TOWN. TOWN WANTS TO SHIFT PASS UP 4 FEET. SUBTRACT 4' FROM PASS. RECONFIRM ON DEPTH AND PULL INTO POSTION. *******SET 2.75" OWEN CIBP @ 4,215'*********** RETAGGED PLUG AND CONFIRMED SET. POOH. OOH BLEED OFF AND SET UP BAILER AND MIX CEMENT. LOAD CMT FOR 1ST BAILER RUN. RIH W/ 30' x 2.5" BAILER FILLED WITH CEMENT. DUMPED CMT ON TOP OF PLUG @ 4,215'. GOOD INDICATION OF DUMP. POOH. OOH, BLEED OFF AND CONFIRMED CMT DUMPED. LOAD BAILER WITH 2ND RUN OF CMT. RIH W/ 2ND BAILER OF CMT AND DUMPED ON TOP OF PLUG. GOOD INDICATION OF DUMPING. POOH. ******DUMPED TOTAL 9.5 GALLONS OF CEMENT ON TOP OF CIBP PUTTING THE EST TOC @ 4,190'********. OOH, BLEED OFF AND CONFIRMED CMT DUMPED. LAY EQUIPMENT DOWN ON LOCATION , DEPART LOCATION AND HEAD BACK TO SHOP. CONTINUE JOB IN AM. 03/08/2021 - Monday AKE-line called and had a fuel issue with crane. The were running an hour late. Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi. RIH w/GPT, 2.75" CIBP and tie into perf log. Ran GPT/Plug correlation log and send to town. Could not see any fluid level. Told to add1'. Added 1', spotted plug at 4,260' and set plug with 1,036 psi on tubing. Lost 120 lbs of line tension. PU 30' and went back down and tagged plug. POOH. everything looked good. Good set. RIH w/ 2-1/2" x2 0' bailer of 17 ppg cement (10') and tag plug at 4,260'. PU 8' and dump 10' of cement on top of plug. Est TOC 4,250' and CIP at 1350 hrs. POOH. Good Dump.. RIH w/ 2-1/8" x 10', 6 spf, 60 deg Strip Gun and tie into GPT/Plug log. Run correlation log and send to town. Get ok to perforate from 4,234' to 4,244' with 200 psi surface pressure. Spot and fire gun. Lost 250 lb line tension. Got blown up hole approx 10'. We worked tools, set jars off a couple.times Worked tools from 4,180' to 4,169' (Rope Socket) up 100 lb increments from 2,000 lb to 2,800 llb and pull out of rope socket. POOH. Line showed pulled out of rope socket. AKE-Line is taking tool drawing to Pollard slickline for fishing. Rig down E-line equipmentand turn well over to field. Est TOC 4,250' o perforate from 4,234' to 4,244' with 200 psi surface pressure. Spot and fire gun. f 17 ppg cement (10') and tag plug at 4,260'. PU 8' and dump 10' of cement on top of plug. E spotted plug at 4,260' and set plug w DUMPED CMT ON TOP OF PLUG @ 4,215' EST TOC @ 4,190' *SET 2.75" OWEN CIBP @ 4,215' Rig Start Date End Date 2/3/21 3/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 33-06 50-133-20487-00-00 199-024 Arrive on location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi. Rih w/ 20' x 2- 1/8" strip gun. Logged correlation pass. Send to town for approval. Depths on log per town. Pull into position and fired. Good indication of firing. POOH. **********PERFORATED INTERVAL @ 3,883' - 3,903'************* (CCL top shot = 19.3' / CCL stop depth = 3,863.7'). Initial psi @ 960# (fired @ 10:20.) 5 min. = 922#. 10 min = 887#. 15 min = 847#. OOH. Bleed off and confirmed all charges shot. Rig down. Depart location and head back to shop with equipment. ***Job complete*** 03/18/2021 - Thursday *PERFORATED INTERVAL @ 3,883' - 3,903' _____________________________________________________________________________________ Updated by DMA 03-26-21 SCHEMATIC Kenai Gas Field Well: KBU 33-06 Last Completed: 7/6/2000 PTD: 199-024 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A Surf 126' 13-3/8' Surface 68 / L-80 / BTC 12.415 Surf 1,525' 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 5,022' TUBING DETAIL 3-1/2" Production 9.3 / L-80 / IBT 2.992 Surf 4,392’ JEWELRY DETAIL No Depth ID Item 1 4,215’ Owen 2.75” CIBP w/ 25’ cement – TOC @ 4,190’ 3/17/21 2 4,260’ 2.75” CIBP w/ 10’ cement – TOC @ 4,250’ 3/8/21 3 4,357’ Landing Collar – w/ Shoe Track @ 4,392’ 2/21/21 4 4,395’ 9-5/8” CIBP 2/21/21 5 4,500’ 9-5/8” CIBP 2/20/21 6 4,915' 9-5/8” CIBP 7 5,180' Baker Model D Packer 8 5,231' WLEG 9 5,460' 2.441” Cement Retainer PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling P3_A8 3,883' 3,903' 3,572' 3,589' 20' 3/19/2021 Open Sterling P4_B2 4,234' 4,244' 3,877’ 3,885’ 10’ 3/8/2021 Isolated Sterling P5.1_B3 4,265' 4,275' 3,904' 3,912’ 10' 3/8/2021 Isolated Sterling P5.2_B5B 4,654’ 4,659’ 4,247’ 4,252’ 5’ 6/22/2013 Isolated Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' 5/12/2013 Isolated Beluga - U5 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8" 17-1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. 9-5/8” 12-1/4" hole cmt w/ 570 sks of Class G, 12 ppg. Full returns throughout job. TOC @ 1700’ (CBL dated 22-MAR-2004) 3-1/2” 9-5/8” casing cemented with 104 bbls 15.3 ppg cement. TOC @ 2770’ (CBL ran 2-24-21) Sterling P3_A8 3,883'3,903'3,572'3,589'20' 3/19/2021 Open Sterling P4_B2 4,234'4,244'3,877’3,885’10’3/8/2021 Isolated Sterling P5.1 B3 4,265'4,275'3,904'3,912’10'3/8/2021 Isolatedg_,,,//, Data Collection Report Chassis Left Scale Right Scale Serial Number 823373 567620 Datatype Upper Units PSI G Upper 0.0 200.0 400.0 600.0 800.0 1000.0 1200.0 1400.0 1600.0 1800.0 PSI G33-6 IA -23-Feb-21, 18:57:41, 1034 Points PSI G Chassis Lower Module Upper Module BARO Module Left Scale Right Scale Serial Number 823373 567620 567620 Model NV 3KPSI Message Store Kenai Gas Field Userspan 1.00032 Offset Datatype Upper Units PSI G PSI G Tare Average User Factor User Offset User Resolution Firmware Version R080016 R090009 Calibration Due 30-Sep-21 Run Index 10 Run Start Time Run Duration Run Tag Logging Interval 2.0 Point #Time Right - PSI G 1 02-23-21 18:57:41 1686.3 2 02-23-21 18:57:43 1686.2 3 02-23-21 18:57:45 1686.1 4 02-23-21 18:57:47 1686.0 5 02-23-21 18:57:49 1685.9 6 02-23-21 18:57:51 1685.9 7 02-23-21 18:57:53 1685.8 8 02-23-21 18:57:55 1685.7 9 02-23-21 18:57:57 1685.6 10 02-23-21 18:57:59 1685.6 34 minutes 26 seconds 33-6 IA 23-Feb-21/18:57:41 Data Points 11 02-23-21 18:58:01 1685.8 12 02-23-21 18:58:03 1685.6 13 02-23-21 18:58:05 1685.6 14 02-23-21 18:58:07 1685.5 15 02-23-21 18:58:09 1685.5 16 02-23-21 18:58:11 1685.3 17 02-23-21 18:58:13 1685.3 18 02-23-21 18:58:15 1685.3 19 02-23-21 18:58:17 1685.2 20 02-23-21 18:58:19 1685.1 21 02-23-21 18:58:21 1684.9 22 02-23-21 18:58:23 1684.9 23 02-23-21 18:58:25 1684.8 24 02-23-21 18:58:27 1684.7 25 02-23-21 18:58:29 1684.6 26 02-23-21 18:58:31 1684.6 27 02-23-21 18:58:33 1684.6 28 02-23-21 18:58:35 1684.5 29 02-23-21 18:58:37 1684.4 30 02-23-21 18:58:39 1684.3 31 02-23-21 18:58:41 1684.2 32 02-23-21 18:58:43 1684.2 33 02-23-21 18:58:45 1684.1 34 02-23-21 18:58:47 1684.0 35 02-23-21 18:58:49 1683.9 36 02-23-21 18:58:51 1683.8 37 02-23-21 18:58:53 1683.8 38 02-23-21 18:58:55 1683.7 39 02-23-21 18:58:57 1683.7 40 02-23-21 18:58:59 1683.5 41 02-23-21 18:59:01 1683.5 42 02-23-21 18:59:03 1683.4 43 02-23-21 18:59:05 1683.4 44 02-23-21 18:59:07 1683.3 45 02-23-21 18:59:09 1683.3 46 02-23-21 18:59:11 1683.2 47 02-23-21 18:59:13 1683.1 48 02-23-21 18:59:15 1682.9 49 02-23-21 18:59:17 1682.9 50 02-23-21 18:59:19 1682.9 51 02-23-21 18:59:21 1682.8 52 02-23-21 18:59:23 1682.7 53 02-23-21 18:59:25 1682.7 54 02-23-21 18:59:27 1682.6 55 02-23-21 18:59:29 1682.5 56 02-23-21 18:59:31 1682.4 57 02-23-21 18:59:33 1682.4 58 02-23-21 18:59:35 1682.3 59 02-23-21 18:59:37 1682.3 60 02-23-21 18:59:39 1682.2 61 02-23-21 18:59:41 1682.2 62 02-23-21 18:59:43 1682.0 63 02-23-21 18:59:45 1682.0 64 02-23-21 18:59:47 1681.9 65 02-23-21 18:59:49 1681.9 66 02-23-21 18:59:51 1681.8 67 02-23-21 18:59:53 1681.6 68 02-23-21 18:59:55 1681.5 69 02-23-21 18:59:57 1681.5 70 02-23-21 18:59:59 1681.5 71 02-23-21 19:00:01 1681.4 72 02-23-21 19:00:03 1681.4 73 02-23-21 19:00:05 1681.3 74 02-23-21 19:00:07 1681.2 75 02-23-21 19:00:09 1681.1 76 02-23-21 19:00:11 1681.0 77 02-23-21 19:00:13 1680.9 78 02-23-21 19:00:15 1680.9 79 02-23-21 19:00:17 1680.8 80 02-23-21 19:00:19 1680.7 81 02-23-21 19:00:21 1680.6 82 02-23-21 19:00:23 1680.7 83 02-23-21 19:00:25 1680.5 84 02-23-21 19:00:27 1680.5 85 02-23-21 19:00:29 1680.4 86 02-23-21 19:00:31 1680.3 87 02-23-21 19:00:33 1680.3 88 02-23-21 19:00:35 1680.2 89 02-23-21 19:00:37 1680.1 90 02-23-21 19:00:39 1680.1 91 02-23-21 19:00:41 1680.0 92 02-23-21 19:00:43 1679.9 93 02-23-21 19:00:45 1679.9 94 02-23-21 19:00:47 1679.9 95 02-23-21 19:00:49 1679.8 96 02-23-21 19:00:51 1679.7 97 02-23-21 19:00:53 1679.6 98 02-23-21 19:00:55 1679.6 99 02-23-21 19:00:57 1679.5 100 02-23-21 19:00:59 1679.4 101 02-23-21 19:01:01 1679.3 102 02-23-21 19:01:03 1679.2 103 02-23-21 19:01:05 1679.2 104 02-23-21 19:01:07 1679.1 105 02-23-21 19:01:09 1679.1 106 02-23-21 19:01:11 1679.0 107 02-23-21 19:01:13 1678.9 108 02-23-21 19:01:15 1678.9 109 02-23-21 19:01:17 1678.8 110 02-23-21 19:01:19 1678.7 111 02-23-21 19:01:21 1678.7 112 02-23-21 19:01:23 1678.6 113 02-23-21 19:01:25 1678.6 114 02-23-21 19:01:27 1678.5 115 02-23-21 19:01:29 1678.5 116 02-23-21 19:01:31 1678.3 117 02-23-21 19:01:33 1678.3 118 02-23-21 19:01:35 1678.2 119 02-23-21 19:01:37 1678.2 120 02-23-21 19:01:39 1678.0 121 02-23-21 19:01:41 1678.1 122 02-23-21 19:01:43 1677.9 123 02-23-21 19:01:45 1677.9 124 02-23-21 19:01:47 1677.9 125 02-23-21 19:01:49 1677.7 126 02-23-21 19:01:51 1677.7 127 02-23-21 19:01:53 1677.6 128 02-23-21 19:01:55 1677.6 129 02-23-21 19:01:57 1677.5 130 02-23-21 19:01:59 1677.4 131 02-23-21 19:02:01 1677.3 132 02-23-21 19:02:03 1677.3 133 02-23-21 19:02:05 1677.2 134 02-23-21 19:02:07 1677.2 135 02-23-21 19:02:09 1677.1 136 02-23-21 19:02:11 1677.0 137 02-23-21 19:02:13 1677.0 138 02-23-21 19:02:15 1676.9 139 02-23-21 19:02:17 1676.9 140 02-23-21 19:02:19 1676.8 141 02-23-21 19:02:21 1676.7 142 02-23-21 19:02:23 1676.6 143 02-23-21 19:02:25 1676.6 144 02-23-21 19:02:27 1676.5 145 02-23-21 19:02:29 1676.4 146 02-23-21 19:02:31 1676.4 147 02-23-21 19:02:33 1676.3 148 02-23-21 19:02:35 1676.2 149 02-23-21 19:02:37 1676.2 150 02-23-21 19:02:39 1676.1 151 02-23-21 19:02:41 1676.0 152 02-23-21 19:02:43 1676.0 153 02-23-21 19:02:45 1676.0 154 02-23-21 19:02:47 1675.9 155 02-23-21 19:02:49 1675.7 156 02-23-21 19:02:51 1675.7 157 02-23-21 19:02:53 1675.8 158 02-23-21 19:02:55 1675.6 159 02-23-21 19:02:57 1675.5 160 02-23-21 19:02:59 1675.5 161 02-23-21 19:03:01 1675.4 162 02-23-21 19:03:03 1675.3 163 02-23-21 19:03:05 1675.3 164 02-23-21 19:03:07 1675.2 165 02-23-21 19:03:09 1675.2 166 02-23-21 19:03:11 1675.0 167 02-23-21 19:03:13 1675.0 168 02-23-21 19:03:15 1675.0 169 02-23-21 19:03:17 1674.9 170 02-23-21 19:03:19 1674.9 171 02-23-21 19:03:21 1674.7 172 02-23-21 19:03:23 1674.7 173 02-23-21 19:03:25 1674.7 174 02-23-21 19:03:27 1674.5 175 02-23-21 19:03:29 1674.5 176 02-23-21 19:03:31 1674.5 177 02-23-21 19:03:33 1674.4 178 02-23-21 19:03:35 1674.4 179 02-23-21 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19:20:47 1643.8 695 02-23-21 19:20:49 1643.7 696 02-23-21 19:20:51 1643.6 697 02-23-21 19:20:53 1643.5 698 02-23-21 19:20:55 1643.5 699 02-23-21 19:20:57 1643.4 700 02-23-21 19:20:59 1643.3 701 02-23-21 19:21:01 1643.3 702 02-23-21 19:21:03 1643.3 703 02-23-21 19:21:05 1643.2 704 02-23-21 19:21:07 1643.1 705 02-23-21 19:21:09 1643.0 706 02-23-21 19:21:11 1643.0 707 02-23-21 19:21:13 1643.0 708 02-23-21 19:21:15 1642.9 709 02-23-21 19:21:17 1642.9 710 02-23-21 19:21:19 1642.7 711 02-23-21 19:21:21 1642.7 712 02-23-21 19:21:23 1642.6 713 02-23-21 19:21:25 1642.6 714 02-23-21 19:21:27 1642.6 715 02-23-21 19:21:29 1642.6 716 02-23-21 19:21:31 1642.5 717 02-23-21 19:21:33 1642.4 718 02-23-21 19:21:35 1642.3 719 02-23-21 19:21:37 1642.3 720 02-23-21 19:21:39 1642.2 721 02-23-21 19:21:41 1642.1 722 02-23-21 19:21:43 1642.1 723 02-23-21 19:21:45 1642.0 724 02-23-21 19:21:47 1642.0 725 02-23-21 19:21:49 1642.0 726 02-23-21 19:21:51 1641.9 727 02-23-21 19:21:53 1641.8 728 02-23-21 19:21:55 1641.7 729 02-23-21 19:21:57 1641.7 730 02-23-21 19:21:59 1641.6 731 02-23-21 19:22:01 1641.6 732 02-23-21 19:22:03 1641.6 733 02-23-21 19:22:05 1641.5 734 02-23-21 19:22:07 1641.5 735 02-23-21 19:22:09 1641.4 736 02-23-21 19:22:11 1641.3 737 02-23-21 19:22:13 1641.3 738 02-23-21 19:22:15 1641.3 739 02-23-21 19:22:17 1641.1 740 02-23-21 19:22:19 1641.1 741 02-23-21 19:22:21 1641.1 742 02-23-21 19:22:23 1641.0 743 02-23-21 19:22:25 1640.9 744 02-23-21 19:22:27 1640.9 745 02-23-21 19:22:29 1640.8 746 02-23-21 19:22:31 1640.7 747 02-23-21 19:22:33 1640.7 748 02-23-21 19:22:35 1640.6 749 02-23-21 19:22:37 1640.6 750 02-23-21 19:22:39 1640.5 751 02-23-21 19:22:41 1640.5 752 02-23-21 19:22:43 1640.4 753 02-23-21 19:22:45 1640.4 754 02-23-21 19:22:47 1640.3 755 02-23-21 19:22:49 1640.3 756 02-23-21 19:22:51 1640.2 757 02-23-21 19:22:53 1640.2 758 02-23-21 19:22:55 1640.1 759 02-23-21 19:22:57 1640.0 760 02-23-21 19:22:59 1640.0 761 02-23-21 19:23:01 1639.8 762 02-23-21 19:23:03 1639.9 763 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19:24:13 1637.9 798 02-23-21 19:24:15 1637.9 799 02-23-21 19:24:17 1637.8 800 02-23-21 19:24:19 1637.7 801 02-23-21 19:24:21 1637.6 802 02-23-21 19:24:23 1637.6 803 02-23-21 19:24:25 1637.6 804 02-23-21 19:24:27 1637.5 805 02-23-21 19:24:29 1637.4 806 02-23-21 19:24:31 1637.3 807 02-23-21 19:24:33 1637.2 808 02-23-21 19:24:35 1637.3 809 02-23-21 19:24:37 1637.3 810 02-23-21 19:24:39 1637.2 811 02-23-21 19:24:41 1637.1 812 02-23-21 19:24:43 1637.1 813 02-23-21 19:24:45 1637.0 814 02-23-21 19:24:47 1636.9 815 02-23-21 19:24:49 1636.9 816 02-23-21 19:24:51 1636.8 817 02-23-21 19:24:53 1636.8 818 02-23-21 19:24:55 1636.7 819 02-23-21 19:24:57 1636.7 820 02-23-21 19:24:59 1636.6 821 02-23-21 19:25:01 1636.6 822 02-23-21 19:25:03 1636.4 823 02-23-21 19:25:05 1636.4 824 02-23-21 19:25:07 1636.4 825 02-23-21 19:25:09 1636.3 826 02-23-21 19:25:11 1636.4 827 02-23-21 19:25:13 1636.2 828 02-23-21 19:25:15 1636.1 829 02-23-21 19:25:17 1636.1 830 02-23-21 19:25:19 1636.0 831 02-23-21 19:25:21 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19:27:39 1632.2 901 02-23-21 19:27:41 1632.2 902 02-23-21 19:27:43 1632.1 903 02-23-21 19:27:45 1632.0 904 02-23-21 19:27:47 1631.9 905 02-23-21 19:27:49 1631.9 906 02-23-21 19:27:51 1631.9 907 02-23-21 19:27:53 1631.8 908 02-23-21 19:27:55 1631.8 909 02-23-21 19:27:57 1631.7 910 02-23-21 19:27:59 1631.6 911 02-23-21 19:28:01 1631.6 912 02-23-21 19:28:03 1631.6 913 02-23-21 19:28:05 1631.5 914 02-23-21 19:28:07 1631.5 915 02-23-21 19:28:09 1631.4 916 02-23-21 19:28:11 1631.4 917 02-23-21 19:28:13 1631.3 918 02-23-21 19:28:15 1631.2 919 02-23-21 19:28:17 1631.2 920 02-23-21 19:28:19 1631.1 921 02-23-21 19:28:21 1631.0 922 02-23-21 19:28:23 1631.1 923 02-23-21 19:28:25 1630.9 924 02-23-21 19:28:27 1630.9 925 02-23-21 19:28:29 1630.8 926 02-23-21 19:28:31 1630.9 927 02-23-21 19:28:33 1630.7 928 02-23-21 19:28:35 1630.7 929 02-23-21 19:28:37 1630.6 930 02-23-21 19:28:39 1630.6 931 02-23-21 19:28:41 1630.5 932 02-23-21 19:28:43 1630.5 933 02-23-21 19:28:45 1630.4 934 02-23-21 19:28:47 1630.4 935 02-23-21 19:28:49 1630.3 936 02-23-21 19:28:51 1630.3 937 02-23-21 19:28:53 1630.2 938 02-23-21 19:28:55 1630.2 939 02-23-21 19:28:57 1630.2 940 02-23-21 19:28:59 1630.0 941 02-23-21 19:29:01 1630.0 942 02-23-21 19:29:03 1629.9 943 02-23-21 19:29:05 1629.9 944 02-23-21 19:29:07 1629.9 945 02-23-21 19:29:09 1629.8 946 02-23-21 19:29:11 1629.8 947 02-23-21 19:29:13 1629.7 948 02-23-21 19:29:15 1629.6 949 02-23-21 19:29:17 1629.5 950 02-23-21 19:29:19 1629.5 951 02-23-21 19:29:21 1629.4 952 02-23-21 19:29:23 1629.4 953 02-23-21 19:29:25 1629.3 954 02-23-21 19:29:27 1629.3 955 02-23-21 19:29:29 1629.3 956 02-23-21 19:29:31 1629.2 957 02-23-21 19:29:33 1629.1 958 02-23-21 19:29:35 1629.1 959 02-23-21 19:29:37 1629.0 960 02-23-21 19:29:39 1628.9 961 02-23-21 19:29:41 1629.0 962 02-23-21 19:29:43 1628.9 963 02-23-21 19:29:45 1628.8 964 02-23-21 19:29:47 1628.7 965 02-23-21 19:29:49 1628.7 966 02-23-21 19:29:51 1628.6 967 02-23-21 19:29:53 1628.6 968 02-23-21 19:29:55 1628.5 969 02-23-21 19:29:57 1628.4 970 02-23-21 19:29:59 1628.4 971 02-23-21 19:30:01 1628.4 972 02-23-21 19:30:03 1628.3 973 02-23-21 19:30:05 1628.2 974 02-23-21 19:30:07 1628.1 975 02-23-21 19:30:09 1628.1 976 02-23-21 19:30:11 1628.0 977 02-23-21 19:30:13 1628.1 978 02-23-21 19:30:15 1628.0 979 02-23-21 19:30:17 1627.9 980 02-23-21 19:30:19 1627.9 981 02-23-21 19:30:21 1627.8 982 02-23-21 19:30:23 1627.7 983 02-23-21 19:30:25 1627.7 984 02-23-21 19:30:27 1627.7 985 02-23-21 19:30:29 1627.6 986 02-23-21 19:30:31 1627.6 987 02-23-21 19:30:33 1627.5 988 02-23-21 19:30:35 1627.4 989 02-23-21 19:30:37 1627.5 990 02-23-21 19:30:39 1627.3 991 02-23-21 19:30:41 1627.2 992 02-23-21 19:30:43 1627.2 993 02-23-21 19:30:45 1627.1 994 02-23-21 19:30:47 1627.1 995 02-23-21 19:30:49 1627.0 996 02-23-21 19:30:51 1627.0 997 02-23-21 19:30:53 1627.0 998 02-23-21 19:30:55 1626.9 999 02-23-21 19:30:57 1626.8 1000 02-23-21 19:30:59 1626.8 1001 02-23-21 19:31:01 1626.8 1002 02-23-21 19:31:03 1626.7 1003 02-23-21 19:31:05 1626.6 1004 02-23-21 19:31:07 1626.6 1005 02-23-21 19:31:09 1626.5 1006 02-23-21 19:31:11 1626.5 1007 02-23-21 19:31:13 1626.4 1008 02-23-21 19:31:15 1626.4 1009 02-23-21 19:31:17 1626.2 1010 02-23-21 19:31:19 1626.3 1011 02-23-21 19:31:21 1626.2 1012 02-23-21 19:31:23 1626.2 1013 02-23-21 19:31:25 1626.1 1014 02-23-21 19:31:27 1626.1 1015 02-23-21 19:31:29 1626.0 1016 02-23-21 19:31:31 1625.9 1017 02-23-21 19:31:33 1625.9 1018 02-23-21 19:31:35 1625.9 1019 02-23-21 19:31:37 1625.8 1020 02-23-21 19:31:39 1625.7 1021 02-23-21 19:31:41 1625.6 1022 02-23-21 19:31:43 1625.6 1023 02-23-21 19:31:45 1625.6 1024 02-23-21 19:31:47 1625.5 1025 02-23-21 19:31:49 1625.5 1026 02-23-21 19:31:51 1625.4 1027 02-23-21 19:31:53 1625.4 1028 02-23-21 19:31:55 1625.3 1029 02-23-21 19:31:57 1625.2 1030 02-23-21 19:31:59 1625.2 1031 02-23-21 19:32:01 1625.1 1032 02-23-21 19:32:03 1625.1 1033 02-23-21 19:32:05 1625.1 1034 02-23-21 19:32:07 1625.0 Data Collection Report Chassis Left Scale Right Scale Serial Number 823373 822132 Datatype Lower Units PSI G Lower 0 200 400 600 800 1000 1200 1400 1600 1800 PSI G 33-6 Tubing Pressure MIT -23-Feb-21, PSI G Chassis Lower Module Upper Module BARO Module Left Scale Right Scale Serial Number 823373 822132 822132 Model NV 10KPSI Message Store Kenai Gas Field Userspan 1.00000 Offset Datatype Lower Units PSI G PSI G Tare Average User Factor User Offset User Resolution Firmware Version R080016 R090009 Calibration Due 30-Sep-21 Run Index 8 Run Start Time Run Duration Run Tag Logging Interval 2.0 Point #Time Left - PSI G 1 02-23-21 14:41:43 1551 2 02-23-21 14:41:45 1551 3 02-23-21 14:41:47 1551 4 02-23-21 14:41:49 1551 5 02-23-21 14:41:51 1551 6 02-23-21 14:41:53 1551 7 02-23-21 14:41:55 1551 8 02-23-21 14:41:57 1551 9 02-23-21 14:41:59 1551 10 02-23-21 14:42:01 1551 19 minutes 58 seconds 33-6tb 23-Feb-21/14:41:43 Data Points 11 02-23-21 14:42:03 1551 12 02-23-21 14:42:05 1551 13 02-23-21 14:42:07 1551 14 02-23-21 14:42:09 1551 15 02-23-21 14:42:11 1551 16 02-23-21 14:42:13 1551 17 02-23-21 14:42:15 1551 18 02-23-21 14:42:17 1551 19 02-23-21 14:42:19 1551 20 02-23-21 14:42:21 1551 21 02-23-21 14:42:23 1551 22 02-23-21 14:42:25 1551 23 02-23-21 14:42:27 1551 24 02-23-21 14:42:29 1551 25 02-23-21 14:42:31 1551 26 02-23-21 14:42:33 1551 27 02-23-21 14:42:35 1551 28 02-23-21 14:42:37 1551 29 02-23-21 14:42:39 1551 30 02-23-21 14:42:41 1551 31 02-23-21 14:42:43 1551 32 02-23-21 14:42:45 1551 33 02-23-21 14:42:47 1551 34 02-23-21 14:42:49 1551 35 02-23-21 14:42:51 1551 36 02-23-21 14:42:53 1551 37 02-23-21 14:42:55 1551 38 02-23-21 14:42:57 1551 39 02-23-21 14:42:59 1551 40 02-23-21 14:43:01 1551 41 02-23-21 14:43:03 1551 42 02-23-21 14:43:05 1551 43 02-23-21 14:43:07 1551 44 02-23-21 14:43:09 1551 45 02-23-21 14:43:11 1551 46 02-23-21 14:43:13 1551 47 02-23-21 14:43:15 1551 48 02-23-21 14:43:17 1551 49 02-23-21 14:43:19 1551 50 02-23-21 14:43:21 1551 51 02-23-21 14:43:23 1551 52 02-23-21 14:43:25 1551 53 02-23-21 14:43:27 1551 54 02-23-21 14:43:29 1551 55 02-23-21 14:43:31 1551 56 02-23-21 14:43:33 1551 57 02-23-21 14:43:35 1551 58 02-23-21 14:43:37 1551 59 02-23-21 14:43:39 1551 60 02-23-21 14:43:41 1551 61 02-23-21 14:43:43 1551 62 02-23-21 14:43:45 1551 63 02-23-21 14:43:47 1551 64 02-23-21 14:43:49 1551 65 02-23-21 14:43:51 1551 66 02-23-21 14:43:53 1551 67 02-23-21 14:43:55 1551 68 02-23-21 14:43:57 1551 69 02-23-21 14:43:59 1551 70 02-23-21 14:44:01 1551 71 02-23-21 14:44:03 1551 72 02-23-21 14:44:05 1551 73 02-23-21 14:44:07 1551 74 02-23-21 14:44:09 1551 75 02-23-21 14:44:11 1551 76 02-23-21 14:44:13 1551 77 02-23-21 14:44:15 1551 78 02-23-21 14:44:17 1551 79 02-23-21 14:44:19 1551 80 02-23-21 14:44:21 1551 81 02-23-21 14:44:23 1551 82 02-23-21 14:44:25 1551 83 02-23-21 14:44:27 1551 84 02-23-21 14:44:29 1551 85 02-23-21 14:44:31 1551 86 02-23-21 14:44:33 1550 87 02-23-21 14:44:35 1551 88 02-23-21 14:44:37 1550 89 02-23-21 14:44:39 1550 90 02-23-21 14:44:41 1550 91 02-23-21 14:44:43 1550 92 02-23-21 14:44:45 1550 93 02-23-21 14:44:47 1550 94 02-23-21 14:44:49 1550 95 02-23-21 14:44:51 1550 96 02-23-21 14:44:53 1550 97 02-23-21 14:44:55 1550 98 02-23-21 14:44:57 1550 99 02-23-21 14:44:59 1550 100 02-23-21 14:45:01 1550 101 02-23-21 14:45:03 1550 102 02-23-21 14:45:05 1550 103 02-23-21 14:45:07 1550 104 02-23-21 14:45:09 1550 105 02-23-21 14:45:11 1550 106 02-23-21 14:45:13 1550 107 02-23-21 14:45:15 1550 108 02-23-21 14:45:17 1550 109 02-23-21 14:45:19 1550 110 02-23-21 14:45:21 1550 111 02-23-21 14:45:23 1550 112 02-23-21 14:45:25 1550 113 02-23-21 14:45:27 1550 114 02-23-21 14:45:29 1550 115 02-23-21 14:45:31 1550 116 02-23-21 14:45:33 1550 117 02-23-21 14:45:35 1550 118 02-23-21 14:45:37 1550 119 02-23-21 14:45:39 1550 120 02-23-21 14:45:41 1550 121 02-23-21 14:45:43 1550 122 02-23-21 14:45:45 1550 123 02-23-21 14:45:47 1550 124 02-23-21 14:45:49 1550 125 02-23-21 14:45:51 1550 126 02-23-21 14:45:53 1550 127 02-23-21 14:45:55 1550 128 02-23-21 14:45:57 1550 129 02-23-21 14:45:59 1550 130 02-23-21 14:46:01 1550 131 02-23-21 14:46:03 1550 132 02-23-21 14:46:05 1550 133 02-23-21 14:46:07 1550 134 02-23-21 14:46:09 1550 135 02-23-21 14:46:11 1550 136 02-23-21 14:46:13 1550 137 02-23-21 14:46:15 1550 138 02-23-21 14:46:17 1550 139 02-23-21 14:46:19 1550 140 02-23-21 14:46:21 1550 141 02-23-21 14:46:23 1550 142 02-23-21 14:46:25 1550 143 02-23-21 14:46:27 1550 144 02-23-21 14:46:29 1550 145 02-23-21 14:46:31 1550 146 02-23-21 14:46:33 1550 147 02-23-21 14:46:35 1550 148 02-23-21 14:46:37 1550 149 02-23-21 14:46:39 1550 150 02-23-21 14:46:41 1550 151 02-23-21 14:46:43 1550 152 02-23-21 14:46:45 1550 153 02-23-21 14:46:47 1550 154 02-23-21 14:46:49 1550 155 02-23-21 14:46:51 1550 156 02-23-21 14:46:53 1550 157 02-23-21 14:46:55 1550 158 02-23-21 14:46:57 1550 159 02-23-21 14:46:59 1550 160 02-23-21 14:47:01 1550 161 02-23-21 14:47:03 1550 162 02-23-21 14:47:05 1550 163 02-23-21 14:47:07 1550 164 02-23-21 14:47:09 1550 165 02-23-21 14:47:11 1550 166 02-23-21 14:47:13 1550 167 02-23-21 14:47:15 1550 168 02-23-21 14:47:17 1550 169 02-23-21 14:47:19 1550 170 02-23-21 14:47:21 1550 171 02-23-21 14:47:23 1550 172 02-23-21 14:47:25 1550 173 02-23-21 14:47:27 1550 174 02-23-21 14:47:29 1550 175 02-23-21 14:47:31 1550 176 02-23-21 14:47:33 1550 177 02-23-21 14:47:35 1550 178 02-23-21 14:47:37 1550 179 02-23-21 14:47:39 1550 180 02-23-21 14:47:41 1550 181 02-23-21 14:47:43 1550 182 02-23-21 14:47:45 1550 183 02-23-21 14:47:47 1550 184 02-23-21 14:47:49 1550 185 02-23-21 14:47:51 1550 186 02-23-21 14:47:53 1550 187 02-23-21 14:47:55 1550 188 02-23-21 14:47:57 1550 189 02-23-21 14:47:59 1550 190 02-23-21 14:48:01 1550 191 02-23-21 14:48:03 1550 192 02-23-21 14:48:05 1550 193 02-23-21 14:48:07 1550 194 02-23-21 14:48:09 1550 195 02-23-21 14:48:11 1550 196 02-23-21 14:48:13 1550 197 02-23-21 14:48:15 1550 198 02-23-21 14:48:17 1550 199 02-23-21 14:48:19 1550 200 02-23-21 14:48:21 1550 201 02-23-21 14:48:23 1550 202 02-23-21 14:48:25 1550 203 02-23-21 14:48:27 1550 204 02-23-21 14:48:29 1550 205 02-23-21 14:48:31 1550 206 02-23-21 14:48:33 1550 207 02-23-21 14:48:35 1550 208 02-23-21 14:48:37 1550 209 02-23-21 14:48:39 1550 210 02-23-21 14:48:41 1550 211 02-23-21 14:48:43 1550 212 02-23-21 14:48:45 1550 213 02-23-21 14:48:47 1550 214 02-23-21 14:48:49 1550 215 02-23-21 14:48:51 1550 216 02-23-21 14:48:53 1550 217 02-23-21 14:48:55 1550 218 02-23-21 14:48:57 1550 219 02-23-21 14:48:59 1550 220 02-23-21 14:49:01 1550 221 02-23-21 14:49:03 1550 222 02-23-21 14:49:05 1550 223 02-23-21 14:49:07 1550 224 02-23-21 14:49:09 1550 225 02-23-21 14:49:11 1550 226 02-23-21 14:49:13 1550 227 02-23-21 14:49:15 1550 228 02-23-21 14:49:17 1550 229 02-23-21 14:49:19 1550 230 02-23-21 14:49:21 1550 231 02-23-21 14:49:23 1550 232 02-23-21 14:49:25 1550 233 02-23-21 14:49:27 1550 234 02-23-21 14:49:29 1550 235 02-23-21 14:49:31 1550 236 02-23-21 14:49:33 1550 237 02-23-21 14:49:35 1550 238 02-23-21 14:49:37 1550 239 02-23-21 14:49:39 1550 240 02-23-21 14:49:41 1550 241 02-23-21 14:49:43 1550 242 02-23-21 14:49:45 1550 243 02-23-21 14:49:47 1550 244 02-23-21 14:49:49 1550 245 02-23-21 14:49:51 1549 246 02-23-21 14:49:53 1550 247 02-23-21 14:49:55 1550 248 02-23-21 14:49:57 1550 249 02-23-21 14:49:59 1549 250 02-23-21 14:50:01 1550 251 02-23-21 14:50:03 1550 252 02-23-21 14:50:05 1550 253 02-23-21 14:50:07 1549 254 02-23-21 14:50:09 1550 255 02-23-21 14:50:11 1550 256 02-23-21 14:50:13 1550 257 02-23-21 14:50:15 1549 258 02-23-21 14:50:17 1549 259 02-23-21 14:50:19 1549 260 02-23-21 14:50:21 1549 261 02-23-21 14:50:23 1550 262 02-23-21 14:50:25 1549 263 02-23-21 14:50:27 1550 264 02-23-21 14:50:29 1550 265 02-23-21 14:50:31 1550 266 02-23-21 14:50:33 1549 267 02-23-21 14:50:35 1550 268 02-23-21 14:50:37 1550 269 02-23-21 14:50:39 1550 270 02-23-21 14:50:41 1549 271 02-23-21 14:50:43 1549 272 02-23-21 14:50:45 1549 273 02-23-21 14:50:47 1549 274 02-23-21 14:50:49 1549 275 02-23-21 14:50:51 1550 276 02-23-21 14:50:53 1550 277 02-23-21 14:50:55 1549 278 02-23-21 14:50:57 1550 279 02-23-21 14:50:59 1549 280 02-23-21 14:51:01 1549 281 02-23-21 14:51:03 1550 282 02-23-21 14:51:05 1550 283 02-23-21 14:51:07 1549 284 02-23-21 14:51:09 1549 285 02-23-21 14:51:11 1549 286 02-23-21 14:51:13 1549 287 02-23-21 14:51:15 1550 288 02-23-21 14:51:17 1549 289 02-23-21 14:51:19 1549 290 02-23-21 14:51:21 1549 291 02-23-21 14:51:23 1549 292 02-23-21 14:51:25 1549 293 02-23-21 14:51:27 1549 294 02-23-21 14:51:29 1549 295 02-23-21 14:51:31 1549 296 02-23-21 14:51:33 1549 297 02-23-21 14:51:35 1549 298 02-23-21 14:51:37 1549 299 02-23-21 14:51:39 1549 300 02-23-21 14:51:41 1549 301 02-23-21 14:51:43 1549 302 02-23-21 14:51:45 1549 303 02-23-21 14:51:47 1549 304 02-23-21 14:51:49 1549 305 02-23-21 14:51:51 1549 306 02-23-21 14:51:53 1549 307 02-23-21 14:51:55 1549 308 02-23-21 14:51:57 1549 309 02-23-21 14:51:59 1549 310 02-23-21 14:52:01 1549 311 02-23-21 14:52:03 1549 312 02-23-21 14:52:05 1549 313 02-23-21 14:52:07 1549 314 02-23-21 14:52:09 1549 315 02-23-21 14:52:11 1549 316 02-23-21 14:52:13 1549 317 02-23-21 14:52:15 1549 318 02-23-21 14:52:17 1549 319 02-23-21 14:52:19 1549 320 02-23-21 14:52:21 1549 321 02-23-21 14:52:23 1549 322 02-23-21 14:52:25 1549 323 02-23-21 14:52:27 1549 324 02-23-21 14:52:29 1549 325 02-23-21 14:52:31 1549 326 02-23-21 14:52:33 1549 327 02-23-21 14:52:35 1549 328 02-23-21 14:52:37 1549 329 02-23-21 14:52:39 1549 330 02-23-21 14:52:41 1549 331 02-23-21 14:52:43 1549 332 02-23-21 14:52:45 1549 333 02-23-21 14:52:47 1549 334 02-23-21 14:52:49 1549 335 02-23-21 14:52:51 1549 336 02-23-21 14:52:53 1549 337 02-23-21 14:52:55 1549 338 02-23-21 14:52:57 1549 339 02-23-21 14:52:59 1549 340 02-23-21 14:53:01 1549 341 02-23-21 14:53:03 1549 342 02-23-21 14:53:05 1549 343 02-23-21 14:53:07 1549 344 02-23-21 14:53:09 1549 345 02-23-21 14:53:11 1549 346 02-23-21 14:53:13 1549 347 02-23-21 14:53:15 1549 348 02-23-21 14:53:17 1549 349 02-23-21 14:53:19 1549 350 02-23-21 14:53:21 1549 351 02-23-21 14:53:23 1549 352 02-23-21 14:53:25 1549 353 02-23-21 14:53:27 1549 354 02-23-21 14:53:29 1549 355 02-23-21 14:53:31 1549 356 02-23-21 14:53:33 1549 357 02-23-21 14:53:35 1549 358 02-23-21 14:53:37 1549 359 02-23-21 14:53:39 1549 360 02-23-21 14:53:41 1549 361 02-23-21 14:53:43 1549 362 02-23-21 14:53:45 1549 363 02-23-21 14:53:47 1549 364 02-23-21 14:53:49 1549 365 02-23-21 14:53:51 1549 366 02-23-21 14:53:53 1549 367 02-23-21 14:53:55 1549 368 02-23-21 14:53:57 1549 369 02-23-21 14:53:59 1549 370 02-23-21 14:54:01 1549 371 02-23-21 14:54:03 1549 372 02-23-21 14:54:05 1549 373 02-23-21 14:54:07 1549 374 02-23-21 14:54:09 1549 375 02-23-21 14:54:11 1549 376 02-23-21 14:54:13 1549 377 02-23-21 14:54:15 1549 378 02-23-21 14:54:17 1549 379 02-23-21 14:54:19 1549 380 02-23-21 14:54:21 1549 381 02-23-21 14:54:23 1549 382 02-23-21 14:54:25 1549 383 02-23-21 14:54:27 1549 384 02-23-21 14:54:29 1549 385 02-23-21 14:54:31 1549 386 02-23-21 14:54:33 1549 387 02-23-21 14:54:35 1549 388 02-23-21 14:54:37 1549 389 02-23-21 14:54:39 1549 390 02-23-21 14:54:41 1549 391 02-23-21 14:54:43 1549 392 02-23-21 14:54:45 1549 393 02-23-21 14:54:47 1549 394 02-23-21 14:54:49 1549 395 02-23-21 14:54:51 1549 396 02-23-21 14:54:53 1549 397 02-23-21 14:54:55 1549 398 02-23-21 14:54:57 1549 399 02-23-21 14:54:59 1549 400 02-23-21 14:55:01 1549 401 02-23-21 14:55:03 1549 402 02-23-21 14:55:05 1549 403 02-23-21 14:55:07 1549 404 02-23-21 14:55:09 1549 405 02-23-21 14:55:11 1549 406 02-23-21 14:55:13 1549 407 02-23-21 14:55:15 1549 408 02-23-21 14:55:17 1549 409 02-23-21 14:55:19 1549 410 02-23-21 14:55:21 1549 411 02-23-21 14:55:23 1549 412 02-23-21 14:55:25 1549 413 02-23-21 14:55:27 1549 414 02-23-21 14:55:29 1549 415 02-23-21 14:55:31 1549 416 02-23-21 14:55:33 1549 417 02-23-21 14:55:35 1549 418 02-23-21 14:55:37 1549 419 02-23-21 14:55:39 1549 420 02-23-21 14:55:41 1549 421 02-23-21 14:55:43 1549 422 02-23-21 14:55:45 1549 423 02-23-21 14:55:47 1549 424 02-23-21 14:55:49 1549 425 02-23-21 14:55:51 1549 426 02-23-21 14:55:53 1549 427 02-23-21 14:55:55 1549 428 02-23-21 14:55:57 1549 429 02-23-21 14:55:59 1549 430 02-23-21 14:56:01 1549 431 02-23-21 14:56:03 1549 432 02-23-21 14:56:05 1549 433 02-23-21 14:56:07 1549 434 02-23-21 14:56:09 1549 435 02-23-21 14:56:11 1549 436 02-23-21 14:56:13 1549 437 02-23-21 14:56:15 1549 438 02-23-21 14:56:17 1549 439 02-23-21 14:56:19 1549 440 02-23-21 14:56:21 1549 441 02-23-21 14:56:23 1549 442 02-23-21 14:56:25 1549 443 02-23-21 14:56:27 1549 444 02-23-21 14:56:29 1549 445 02-23-21 14:56:31 1549 446 02-23-21 14:56:33 1549 447 02-23-21 14:56:35 1549 448 02-23-21 14:56:37 1549 449 02-23-21 14:56:39 1549 450 02-23-21 14:56:41 1549 451 02-23-21 14:56:43 1549 452 02-23-21 14:56:45 1549 453 02-23-21 14:56:47 1549 454 02-23-21 14:56:49 1549 455 02-23-21 14:56:51 1549 456 02-23-21 14:56:53 1549 457 02-23-21 14:56:55 1548 458 02-23-21 14:56:57 1549 459 02-23-21 14:56:59 1548 460 02-23-21 14:57:01 1549 461 02-23-21 14:57:03 1549 462 02-23-21 14:57:05 1548 463 02-23-21 14:57:07 1548 464 02-23-21 14:57:09 1549 465 02-23-21 14:57:11 1548 466 02-23-21 14:57:13 1548 467 02-23-21 14:57:15 1548 468 02-23-21 14:57:17 1549 469 02-23-21 14:57:19 1548 470 02-23-21 14:57:21 1548 471 02-23-21 14:57:23 1548 472 02-23-21 14:57:25 1549 473 02-23-21 14:57:27 1548 474 02-23-21 14:57:29 1548 475 02-23-21 14:57:31 1548 476 02-23-21 14:57:33 1548 477 02-23-21 14:57:35 1548 478 02-23-21 14:57:37 1548 479 02-23-21 14:57:39 1548 480 02-23-21 14:57:41 1548 481 02-23-21 14:57:43 1548 482 02-23-21 14:57:45 1548 483 02-23-21 14:57:47 1548 484 02-23-21 14:57:49 1548 485 02-23-21 14:57:51 1548 486 02-23-21 14:57:53 1548 487 02-23-21 14:57:55 1548 488 02-23-21 14:57:57 1548 489 02-23-21 14:57:59 1548 490 02-23-21 14:58:01 1548 491 02-23-21 14:58:03 1548 492 02-23-21 14:58:05 1548 493 02-23-21 14:58:07 1548 494 02-23-21 14:58:09 1548 495 02-23-21 14:58:11 1548 496 02-23-21 14:58:13 1548 497 02-23-21 14:58:15 1548 498 02-23-21 14:58:17 1548 499 02-23-21 14:58:19 1548 500 02-23-21 14:58:21 1548 501 02-23-21 14:58:23 1548 502 02-23-21 14:58:25 1548 503 02-23-21 14:58:27 1548 504 02-23-21 14:58:29 1548 505 02-23-21 14:58:31 1548 506 02-23-21 14:58:33 1548 507 02-23-21 14:58:35 1548 508 02-23-21 14:58:37 1548 509 02-23-21 14:58:39 1548 510 02-23-21 14:58:41 1548 511 02-23-21 14:58:43 1548 512 02-23-21 14:58:45 1548 513 02-23-21 14:58:47 1548 514 02-23-21 14:58:49 1548 515 02-23-21 14:58:51 1548 516 02-23-21 14:58:53 1548 517 02-23-21 14:58:55 1548 518 02-23-21 14:58:57 1548 519 02-23-21 14:58:59 1548 520 02-23-21 14:59:01 1548 521 02-23-21 14:59:03 1548 522 02-23-21 14:59:05 1548 523 02-23-21 14:59:07 1548 524 02-23-21 14:59:09 1548 525 02-23-21 14:59:11 1548 526 02-23-21 14:59:13 1548 527 02-23-21 14:59:15 1548 528 02-23-21 14:59:17 1548 529 02-23-21 14:59:19 1548 530 02-23-21 14:59:21 1548 531 02-23-21 14:59:23 1548 532 02-23-21 14:59:25 1548 533 02-23-21 14:59:27 1548 534 02-23-21 14:59:29 1548 535 02-23-21 14:59:31 1548 536 02-23-21 14:59:33 1548 537 02-23-21 14:59:35 1548 538 02-23-21 14:59:37 1548 539 02-23-21 14:59:39 1548 540 02-23-21 14:59:41 1548 541 02-23-21 14:59:43 1548 542 02-23-21 14:59:45 1548 543 02-23-21 14:59:47 1548 544 02-23-21 14:59:49 1548 545 02-23-21 14:59:51 1548 546 02-23-21 14:59:53 1548 547 02-23-21 14:59:55 1548 548 02-23-21 14:59:57 1548 549 02-23-21 14:59:59 1548 550 02-23-21 15:00:01 1548 551 02-23-21 15:00:03 1548 552 02-23-21 15:00:05 1548 553 02-23-21 15:00:07 1548 554 02-23-21 15:00:09 1548 555 02-23-21 15:00:11 1548 556 02-23-21 15:00:13 1548 557 02-23-21 15:00:15 1548 558 02-23-21 15:00:17 1548 559 02-23-21 15:00:19 1548 560 02-23-21 15:00:21 1548 561 02-23-21 15:00:23 1548 562 02-23-21 15:00:25 1548 563 02-23-21 15:00:27 1548 564 02-23-21 15:00:29 1548 565 02-23-21 15:00:31 1548 566 02-23-21 15:00:33 1548 567 02-23-21 15:00:35 1549 568 02-23-21 15:00:37 1549 569 02-23-21 15:00:39 1549 570 02-23-21 15:00:41 1548 571 02-23-21 15:00:43 1549 572 02-23-21 15:00:45 1548 573 02-23-21 15:00:47 1548 574 02-23-21 15:00:49 1549 575 02-23-21 15:00:51 1548 576 02-23-21 15:00:53 1548 577 02-23-21 15:00:55 1548 578 02-23-21 15:00:57 1548 579 02-23-21 15:00:59 1549 580 02-23-21 15:01:01 1548 581 02-23-21 15:01:03 1548 582 02-23-21 15:01:05 1548 583 02-23-21 15:01:07 1549 584 02-23-21 15:01:09 1548 585 02-23-21 15:01:11 1548 586 02-23-21 15:01:13 1548 587 02-23-21 15:01:15 1548 588 02-23-21 15:01:17 1548 589 02-23-21 15:01:19 1548 590 02-23-21 15:01:21 1548 591 02-23-21 15:01:23 1548 592 02-23-21 15:01:25 1548 593 02-23-21 15:01:27 1548 594 02-23-21 15:01:29 1548 595 02-23-21 15:01:31 1548 596 02-23-21 15:01:33 1548 597 02-23-21 15:01:35 1548 598 02-23-21 15:01:37 1548 599 02-23-21 15:01:39 1548 600 02-23-21 15:01:41 1548 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/31/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06 (PTD 199-024) CIBP Cement PERF 03/18/2021 Please include current contact information if different from above. PTD: 1990240 E-Set: 34863 Received by the AOGCC 03/31/2021 03/31/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/31/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06 (PTD 199-024) CIBP Cement PERF 03/08/2021 Please include current contact information if different from above. PTD: 1990240 E-Set: 34862 Received by the AOGCC 03/31/2021 03/31/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06 (PTD 199-024) PERFORATING RECORD 03/02/2021 Please include current contact information if different from above. PTD: 1990240 E-Set: 34794 Received by the AOGCC 03/19/2021 03/22/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06 (PTD 199-024) JB-GR, CIBP 03/20/2021 Please include current contact information if different from above. PTD: 1990240 E-Set: 34793 Received by the AOGCC 03/19/2021 03/22/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/08/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 33-06 (PTD 199-024) Memory Radial Cement Bond Log 02/24/2021 Please include current contact information if different from above. PTD: 1990240 E-Set: 34757 Received by the AOGCC 03/08/2021 03/09/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2, Cement Packer 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,110'N/A Casing Collapse Structural Conductor Surface 1,950psi Intermediate 3,090psi Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: February 1, 2021 2-7/8" Perforation Depth MD (ft): 5,810' See Attached Schematic 20" 13-3/8" 94' 9-5/8"5,810' 1,547'3,450psi 115' 1,502' 5,329' 115' 1,525' 4.7# / L-80 TVD Burst 4,506' MD 5,750psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028142 199-024 50-133-20487-00-00 Kenai Beluga Unit (KBU) 33-06 Kenai Gas Field / Sterling Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 7,564'4,886'4,458'906 4,886' AS1-X 9-5/8" Retrievable ; N/A 4411' MD / 4032' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:08 am, Jan 19, 2021 321-038 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.19 09:49:23 -09'00' Taylor Wellman * CBL required over 3 1/2" for TOC 10-404 N2, Cement Packer rig 401 XX DSR-1/19/21 Plug Perforations SFD 1/20/2021 Perforate * 2500 psi BOPE test gls 1/27/21Comm q Yes 1/27/21 dts 1/27/2021 JLC 1/27/2021 RBDMS HEW 1/29/2021 Well Prognosis Well: KBU 33-06 Date: 1/06/2021 Well Name: KBU 33-06 API Number: 50-133-20487-00-00 Current Status: Gas Well Leg: N/A Estimated Start Date: 1/30/2020 Rig: 401 Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 199-024 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) AFE Number Maximum Expected BHP: ~ 1315 psi @ 4090’ TVD Based on RFT Data Max. Potential Surface Pressure: ~ 906 psi Based on BHP minus 0.1 psi/ft gas Gradient Brief Well Summary: KBU 33-06 drilled and completed in 2000 targeting the Beluga formation. The well was the first to complete with a dual monobore completion. The well came online making about 0.5 MMCFD in the Tyonek 73-1 Sand (long string) and did not sustain flow in the Middle Beluga sands (short string). They fracture stimulated the short string, Middle Beluga sands (M14 and M15) in Nov. 2000, which appears to have added about 1 MMCFD to the well. The long string sanded up (as well as the short string a few months later) and a coil clean out was attempted in May of 2001 with a short string cleanout following. It declined out and eventually the well died (both strings by mid- 2002). However due to both strings being “kinked” @ 6410’ MD, Intervention became an issue and the well was recomplete uphole in 2003 to the MB sands in the LS. The middle Beluga turned out to quite the sand producer, never really able to sustain flow. In 2004, 33-06 was recompleted to the Upper Beluga, UB 5 and UB 6. The dual strings were cut and pulled, RIH with single 4-1/2” tbg/pkr completion. The well could not sustain flow because of excess water. A poor boy gas lift string was installed in 2004 (packerless V-string and hp gas source). This however did not work. The well was recompleted to Pool 6 Storage well which never would sustain flow, even after a v-string installation. The well was recompleted uphole the Sterling B5B sand in June 2013, came online making 5.5 MMCFD and eventually watering out after making just under 0.7 BCF of gas in July 2014. The initial targets will be the Sterling Pool 5.1 sands, which have not been produced and/or online since 2006. Objective: The purpose of this Sundry is to pull the 2-7/8” completion from ~4506’, plug back the existing wellbore, and run a 3-1/2” cemented completion to provide a monitorable annulus and monobore for perforating up-hole Sterling pays. Well Condition: - Max deviation: 32 degrees at 2227’ MD. - Last Tag: RIH w/ 2.25 DD bailer to 4644’ RKB – tagged fill, ¼ full of course sand. 11/13/2018 - Minimum ID: 2.31”, Sliding Sleeve profile in 2-7/8” tbg @ 4366’ MD. Pre Rig Work 1. MIT-IA to 1500 psi. 2. RU slickline & pressure test lubricator to 250 psi low / 2500 psi high. a. RIH and drift to PBTD with DD bailer. Notify OE if unable to work past 4620’. b. Open sliding sleeve @ 4366’ MD to allow the rig to circulate a kill. c. RDMO slickline Planned TOC is 3000 ft for future Sterling perforations. gls 1/22/21 6.18 ppg EMW Kill well (test 7" casing) The initial targets will be the Sterling Pool 5.1 sands, which have not been produced and/or online since 2006. BHP = 6.18 ppg EMW Well Prognosis Well: KBU 33-06 Date: 1/06/2021 Rig 401 Procedure 1. MIRU 401 workover rig. 2. Load and circulate well with 8.4 ppg lease water & monitor fluid level for stability. 3. Set BPV, ND Tree, NU 11” BOPE. 4. Perform BOP Test 250 psi low & 2500 psi high, annular to 250 psi low & 2500 psi high. a. Provide 24hr notice to AOGCC of BOP Test. b. Test with 2-7/8” and 3-1/2” test joints. c. Record with chart & submit to AOGCC within 5 days of test. 5. Pull BPV. 6. Pull and lay down 2-7/8” completion. a. Tripoint will send a hand if help is required releasing AS1-X packer. b. Spool up chemical injection line while pulling tubing until mandrel is laid down 7. RU e-line & test lubricator to 250 psi low / 2500 psi high. a. RIH with junk basket / gauge ring and drift for CIBP to PBTD. b. RIH and set 9-5/8” CIBP at ~4650’. c. RDMO e-line 8. Pressure test casing and CIBP to 1500 psi for 15 minutes. 9. Run 3-1/2” 9.3# L-80 tubing to ~4615’ with float shoe, 20’ shoe track and float collar. New PBTD estimated at ~4595’. 10. RU cement head, mix and pump 104 bbls 15.3# cement down tubing with returns up IA. Drop wiper plug, displace with 40 bbls to bump plug. 11. Hold pressure and WOC. 12. Set BPV, ND BOP. 13. NU production tree & test to 5000 psi. 14. Pull BPV. 15. RDMO. Fullbore Procedure 1. Perform MIT-IA to 1500 psi for 30 minutes and chart results. Send a copy to OE who will QC and forward to AOGCC. Slickline Procedure 1. MIRU Slickline. PT lubricator to 250 psi low / 2500 psi high. 2. RIH with gauge ring and drift to PBTD. 3. RIH with memory CBL and log from PBTD to surface and send to OE. 4. Swab well down. 5. RDMO. E-line Procedure 1. MIRU E-line. PT lubricator to 250 psi low / 2500 psi high. 2. Perforate the following Sand intervals with 2-1/2” Shogun Spiral guns: AOGCC CBL review required before perforating well. CIBP @ 4650 ft .0639 BPF 1600 ft x .0639 = 103 bbls NOTE: (forward PDF of CBL to AOGCC) run 3.5" tubing with shoe track CBL 3 1/2" x 9 5/8" = Note: MIT-T ... test 3.5 tubing to 1500 for 15 min. 2500 psi BOPE test Well Prognosis Well: KBU 33-06 Date: 1/06/2021 Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom P3_A8 ±3,883' ±3,903' 20' ±3,572' ±3,592' P3_A10 ±3,944' ±3,972' 28' ±3,625' ±3,653' P3_A11 ±4,050' ±4,079' 29' ±3,716' ±3,745' P4_B1A ±4,113' ±4,151' 38' ±3,769' ±3,807' P4_B2 ±4,225' ±4,247' 22' ±3,868' ±3,890' P5.1_B3 ±4,265' ±4,316' 51' ±3,904' ±3,955' P5.1_B4A ±4,368' ±4,421' 53' ±3,996' ±4,049' P5.1_B4B ±4,476' ±4,539' 63' ±4,090' ±4,153' a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e. The listed Sands are governed by Conservation Order 510A. f. Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, nitrogen depression followed by a plug or an isolation patch may be set prior to moving up to the next sand interval. 1. RDMO. 2. Turn well over to production. Contingent Coiled Tubing: If slickline tags cement high and is unable to remediate. 1. MIRU Coiled Tubing Unit. 2. PT BOP equipment to 250 psi Low / 2,500 psi High. a. Provide 24hr notice to AOGCC of BOP Test. b. Record with chart & submit to AOGCC within 5 days of test. 3. MU motor and mill, RIH and clean out to PBTD. 4. POOH w/ coil. RDMO CTU. Contingent Coiled Tubing: If slickline is unable to swab all water off well. 5. MIRU Coiled Tubing Unit. 6. PT BOP equipment to 250 psi Low / 4,000 psi High. a. Provide 24hr notice to AOGCC of BOP Test. b. Record with chart & submit to AOGCC within 5 days of test. 7. MU nozzle, and RIH to PBTD. 8. RU N2 pumping unit. 9. Blow well dry with N2 taking returns to tanks. 10. Once well is dry, leave N2 pressure on well per OE for the first perforation interval. 11. POOH w/ coil. RDMO CTU. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Rig 401 BOP Schematic not required if SLB CTU . Review Nitrogen SOP with all personnel on location before starting any displacement operations. Well Prognosis Well: KBU 33-06 Date: 1/06/2021 4. Coil BOP Schematic 5. Standard Nitrogen Procedure 6. RWO Change Form _____________________________________________________________________________________ Revised By: TCS 1/13/2021 SCHEMATIC Kenai Gas Field Well: KBU 33-06 Last Completed: 7/6/2000 PTD: 199-024 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A Surf 126' 13-3/8' Surface 68 / L-80 / BTC 12.415 Surf 1,525' 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 5,810' TUBING DETAIL 2-7/8" Production 4.7 / L-80 2.441 Surf 4,506' JEWELRY DETAIL No Depth ID Item 1 484’ N/A Chemical Injection Mandrel 2 4,366’ 2.31 Sliding Sleeve 2.31 Profile 3 4,409’ 4.73 T-2 Overshot with 2-7/8” EUE Box 4 4,410.5’ 4 T-2 Body 4-1/2” EUE Pin 5 4,411' 4 9-5/8” AS1-X Packer 40 to 53.5# 6 4,453' N/A X-Nipple 7 4,506' N/A WLRG 8 4,915' N/A CIBP 9 5,180' N/A Baker Model D Packer 10 5,231' N/A WLEG 11 5,460' 2.441 Cement Retainer PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling 5.2 Sands 4,654’ 4,659’ 4,247’ 4,252’ 5’ 6/22/13 Open Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' 5/12/2013 Isolated Beluga - U5 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8" 17-1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. 9-5/8” 12-1/4" hole cmt w/ 570 sks of Class G, 12 ppg. Full returns throughout job. TOC @ 1700’ (CBL dated 22-MAR-2004) Top of fill @ 4,644’ 11-12-18 _____________________________________________________________________________________ Revised By: TRH 01/06/2021 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 33-06 Last Completed: 7/6/2000 PTD: 199-024 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / N/A Surf 126' 13-3/8' Surface 68 / L-80 / BTC 12.415 Surf 1,525' 9-5/8" Intermediate 40 / L-80 / BTC 8.835 Surf 5,022' TUBING DETAIL 3-1/2" Production 9.3 / L-80 / IBT 2.992 Surf ±4,615' JEWELRY DETAIL No Depth ID Item 6 ±4,595’ N/A Float Collar 5 ±4,650’ N/A CIBP 4 4,915' N/A CIBP 3 5,180' N/A Baker Model D Packer 2 5,231' N/A WLEG 1 5,460' 2.441 Cement Retainer PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status P3_A8 ±3,883' ±3,903' ±3,572' ±3,592' 20' TBD Proposed P3_A10 ±3,944' ±3,972' ±3,625' ±3,653' 28' TBD Proposed P3_A11 ±4,050' ±4,079' ±3,716' ±3,745' 29' TBD Proposed P4_B1A ±4,113' ±4,151' ±3,769' ±3,807' 38' TBD Proposed P4_B2 ±4,225' ±4,247' ±3,868' ±3,890' 22' TBD Proposed P5.1_B3 ±4,265' ±4,316' ±3,904' ±3,955' 51' TBD Proposed P5.1_B4A ±4,368' ±4,421' ±3,996' ±4,049' 53' TBD Proposed P5.1_B4B ±4,476' ±4,539' ±4,090' ±4,153' 63' TBD Proposed Sterling 5.2 Sands 4,654’ 4,659’ 4,247’ 4,252’ 5’ 6/22/13 Open Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' 5/12/2013 Isolated Beluga - U5 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed OPEN HOLE / CEMENT DETAIL 13-3/8" 17-1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. 9-5/8” 12-1/4" hole cmt w/ 570 sks of Class G, 12 ppg. Full returns throughout job. TOC @ 1700’ (CBL dated 22-MAR-2004) CBL required to verify TOC in 3 1/2" x 9 5/8" annulus 3883 ft - 4539ft (approx range of Sterling) MIT-IA 1500 psi Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 34A-33 10/20/2020 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well KBU 33-06 (PTD 199-024) Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. in this file. the first page History File # Please insure that it remains as Æ ~ Well Added to LaserFiche File No Yes Data Digital #- #- #- s CD No No Yes Yes DVD's - Diskettes Added to LaserFiche File No Yes Oversized Material - # Maps No No Yes # Mud Logs Yes If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC _ Librarian@admin.state.ak.us # General Notes or Comments about this file. Other II 0 Landon Ellison Geo Tech II Hilcorp Alaska, LL 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Ifile-m-p Alaska. 1,1C Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATE 07/01/2013 To: Alaska Oil & Gas Conservation Commission Howard Okland 333 W 7th Ave Ste 100 Anchorage, AK 99501 saws) JUL 0 8 Z0 DATA TRANSMITTAL KBU 33 CD: Name Date modified Type Size KBU 33-06 AIT GR CAL PEX 5/24/2013 2:42 PM TIF File 156,733 KB jj KBU 33-06 DENSITY NEUT GR CAL PEX 5/24/2013 2:51 PM TIF File 72,106 KB KBU 33-06 DIPHOLE SONIC IMAGER 5/24/2013 2:26 PM TIF File 114,906 KB KBU 33-06 DIPOLE SONIC QC-PLOT 5/24/2013 3:13 PM TIF File 211076 KB .iki KBU 33-06 MUDLOG L..., 5/24/2013 1:59 PM TIF File 13,887 KB : KBU 33-06 PHOTO DENSITY NEUTRON 5/24/2013 2:11 PM TIF File 23,475 KB : kbu_33-6_61 1/24/2013 11:42 AM LAS File 454 KB L7,7'; kbu_33-6_cmr_las 1/24/2013 11:42 AM LAS File 743 KB ; kbu_33-6_cmrsplas 1/24/2013 11:42 AM LAS File 677 KB 7' kbu_33-6_mudlog 1/24/2013 11:41 AM LAS File 6,018 KB 1; kbu_33-6_pexait_las 1/24/2013 11:41 AM LAS File 1,073 KB .._ .`° kbu 33-6 raw dsi ',--1 _ _ _ 1/24/2013 11:41 AM LAS File 1,834 KB Li kbu_33-5_raw_lasfiles 1/24/2013 11:42 AM LAS File 5,662 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 7/ erv,,r 2L Q I , L 4,. Date: ) j uk) • j Davies, Stephen F (DOA) From: Jeremy Mardambek [jardambek ©hilcorp.com] Sent: Wednesday, June 19, 2013 2:47 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: KBU 33 -06 perforation adds Steve, We have reinterpreted the cased hole log of the KBU 33 -06 and have picked 2 zones to perforate in Pool 5.2. These will be the only active perforations in Pool 5.2 at Kenai Gas Field since 1981 when the zone was abandoned. Depths listed below are in MD. 4520 — 4529 4654 — 4664 Regards, Jeremy Mardambek NEQ JuL JUL 0 8 2013 Reservoir Engineer Hilcorp Alaska Office - (907) 777 -8388 Cell — (561) 512 -8690 1 • i �P� of // T,r THE STATE ikilaska Gilt °fALA K1"i ci_ianservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue oF ALASY'' Anchorage, Alaska 99501 -3572 �� Main: 907.279.1433 1 9 q 11 Fax: 907.276.7542 Shane Bennett Operations Engineer SCANNED !AY 0 2 2013 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Kenai Field, Upper Tyonek Beluga Gas, Sterling 6 Gas & Storage Pools, KBU 33 -06 Sundry Number: 313 -201 Dear Mr. Bennett: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner S DATED this / day of May, 2013. Encl. • • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 6 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGG 1 Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ t!3 Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El • Pull Tubing , . Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Complete , 2. Operator Name: ✓ 4. Current Well Class: ✓ 5. Permit to Drill Number:, Hi :corp Alaska, LLC Exploratory ❑ Development la • 199 -024 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, Anchorage AK, 99503 50- 133 - 20487 -00 -00 • 7. If perforating: /2 /, �f�� 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? ! ��T /Pr 24 l / 3 Will planned perforations require a spacing exception? Yes ❑ No ❑ Kenai Beluga Unit 33 -06 . 9. Property Designation (Lease Number): ✓ 10. Field /Pool(s): ✓ FEDA028142 Kenai Field / Up Tyonek Beluga Gas, Sterling 6 Gas & Storage Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft)y, Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): � 8,110 • 7` q / q , r n � 5,188 4,739 5,251' 5,188' Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 115' 115' 3,060psi 1,500psi Surface 1,547' 13 -3/8" 1,568' 1,540' 3,450psi 1,950psi Intermediate 5,303 9 -5/8" 5,810' 5,324' 5,750psi 3,090psi • Production Liner i f Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • Reference Schematic Reference Schematic 4 -1/2" 12.6 / L -80 4,850' f P ckers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 111111 ' Baker Model D Permanent Packer and N/A 5,180'(MD) / 4,732'(TVD) and N/A • 2. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: v' Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development E Service ❑ 14. Estimated Date for • 15. Well Status after proposed work: v Commencing Operations: 5/3/2013 Oil ❑ Gas Q • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ , Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true end correct to the best of my knowledge. Contact Shane Bennett Email sbennettahilcorp.com Printed Name h • ne Bennett Title Operations Engineer Signature _ � i L /L/ Phone 777 -8425 Date 4/26/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 2t1 Flug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RSDMS MAY — 2 2O 14 Other: ( Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / O Y b I APPROVED BY J Approved by: COMMISSIONER THE COMMISSION Dater / / ) 3 • Submit Form and 1 / Form 10 40 ' Revised 10/20 (� ? A , ppr d 1 gn for 12 months from the ate of approval. Attachment i Duplicate • • Well Prognosis Well: KBU 33 -06 Bacon) Alaska, Lb Date: 4/26/2013 Well Name: KBU 33 -06 API Number: 50- 133 - 204 - 8700 -00 Current Status: Online Leg: Estimated Start Date: May 5, 2013 Rig: Cloverleaf Rig # 4 Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts (907) 777 - 8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: AFE Current Bottom Hole Pressure: —125 psi Based on current Pool 6 pressure Maximum Expected BHP: —125 psi Based on current Pool 6 pressure Max. Anticipated Surface Pressure: —90 psi Based on 0.02 psi /ft gas gradient) Brief Well Summary KBU 33 -06 was drilled in 4/2000 as a Beluga and Tyonek dual string completion with no production casing but just two 3.5" cemented strings. The concept behind cementing two strings without a production liner was to save money and retain the ability to access and stimulate "higher" quality Beluga sands but also able to stimulate the lower quality sands which require different stimulations. The first four months of production were done with no stimulation but production tripled after stimulation in 11/2000. In early 2003 both strings were found to be kinked at 6170' MD and after a third party study on the mechanism of this kink it was concluded this was due to compaction at some interval above the productive zones due to depletion. Because the well had no casing to support the shear forces, the cement failed inward and the tubing was kinked. In 2/2003 a plug was set in both the LS and the SS to isolate the tubing below the kink and the seemingly watery Tyonek perfs. Both strings were perforated higher in the middle Beluga. After the Beluga was perforated, fill became an increasing problem and multiple fill clean outs were attempted. In 2/2004 a RWO was performed to make the well a single upper Beluga producer and perforated based on RFT data in nearby wells. The upper Beluga flowed gas with excess water production and the well loaded up with sand and water. In 10/2006 the Upper Beluga was plugged and the well was and recompleted to Pool 6. This completion was originally a 4 1/2" tubing string but did not flow above unloading rates so a 2 3/8" coiled tubing string was installed with a 1 3/4" concentric coiled tubing string inside to provide for concentric gas lift. The two inner strings were found to be plugged with sand in 9/2008 the inner string was pulled. The current completion is a 2 3/8" coiled tubing velocity string inside of 4 1/2" tubing. OBJECTIVE OF WORKOVER Pull the current packerless completion, both the 2 3/8" coiled tubing velocity string and 4 tubing. Run the HES TMD3D cased hole log as deep as possible. Install a plug over the current Pool 6 perforations. Run in a new packerless 2 3/8" tubing with the tail at 4500' MD. This will leave enough rat hole to cut the tubing string so as to test the Sterling Gas Pools above the 5.2 if necessary. Conduct JSA on rig up operations. Pre Work over Rig Procedure • • Well Prognosis Well: KBU 33-06 Hikora Alaska, LU Date: 4/26/2013 1. Pre pulling unit activities. 2. Close and tag (lock out/ tag out /bleed) pressure sources to wellhead from flow lines and gas lift supply lines. 3. Shoot fluid levels on casing and tubing. Record pressures on tubing and casing. Coiled Tubing Procedure 4. RU Coiled tubing and test Quad BOPE, test low 300 psi /4500 psi high. a. Notify AOGCC 24hrs in advance to witness b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. 5. Latch onto 2 -3/8" coiled tubing velocity string and pull on to coil reel. 6. RDMO Work -over Ri: • ocedure � / � 7. MIRU verleaf pulling unit. Set two way ch k and test from below. � n p ` \ 22 ` 8. ND tree, N b :OPE and test to 250 psi to ,000 psi high, annular to 250 psi low /2,500 psi high. w a. Notify OGCC 24hrs in adv ce to witness / t)" b. BOPE tes esults mus .e reported in daily operations report AND MUST BE PROVIDED TO C? `o n THE AOGCC' ■ ITH ', 5 DAYS. h � c. Notify BLM 4: ` • urs in advance of BOP test. 9. Pull 4 Tubing 10. Rig up SL and with dummy drift L9" and 40' long 11. Run Hallib on TMD3D log to S ag 12. RIH wit 3/8" tubing with the tail -t at 4500' MD Ift. 13. ND : • P and NU tree. Test wellhead to , 000 psi. 14. RI 0 15. Turn well over to production. Eline Procedure 16. RU Eline and test lubricator to low 250 and high 2500 psi 17. RIH and perforate Pool 5.2 between the depths of 4520' MD and 4620' MD. Exact perforation ` depths will be determined based on the Halliburton TMD3D log run in step #11. 5 Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic • • KBU 33 -6 Permit #: 199-024 API PI #: 50- 133 - 2043-204 87 -00 -00 Pad 41 -7 Property Des: A- 028142 37' FNL, 4,068' FWL KB Elevation: 87' (21.6' AGL) x= 274,976.7 Sec. 7, T4N, R11 W, S.M. MARATNOM Y = 2,361,976.2 Spud Date: 4/28/2000 TD Date: 5/20/2000 Rig Released: 5/27/2000 21:00 hrs [.[ Conductor 20" K -55 133 ppf Top Bottom MD 0' 115' TVD 0' 115' Production Tubing Surface Casing 4 -1/2" L -80 12.6 ppf 13 -3/8" L -80 68 ppf BTC Top Bottom Al I Top Bottom MD Surf 4,850' MD 0' 1,568' TVD Surf 4,419' TVD 0' 1,540' 17 -1/2" hole cmt w/ 600 sks of Class 0, X Nipple @ 4,801' RKB 12 ppg. 100 sks to surface. W EG @ 4,850' RKB ): Velocity String Tubing Intermediate Casing 2 -3/8" 9 -5/8" L -80 40 ppf BTC Top Bottom j Top Bottom MD Surf 5,178' MD 0' 5,810' TVD Surf 4,725' III 2 -318" BHA Description TVD 0' 5,324' 2 -3/8 ": (Assy Bottoms Up, Tested to 15,0004) li 12 - 1/4" hole cmt w1570 sks of Class G, - Centralizer (3.50" OD X 2.375" ID X 12.00" Long) 12 ppg. - NoGo /Xover (2.50" OD X 1.135" ID X 8.75" Long) - Straight Bar (2.50" OD X 2.375" ID X 10' Long) 11= - Grapple CT Connector (3.00" OD X 2.375" ID X - 10" Long) 1 t Tag fill 9/10/09 1.25" DD bailer @ 5,183' Tag top of fill / junk @5,188'CTMI (7/12/07) Baker Model D Permanent Packer @5,180'MD NI - - Sealbore Extension Top of Cement -10' sub @ 5,251' ELM -3.812 X Nipple -10' sub I - Wireline Re -entry Guide @ 5,231' I= ( ' t 1 .. Y ___ Sterling Pool -6 Perforations: MD ft TVD Gun Type Date Cl 4,940' - 4,990' 50' 4,502' - 4,549' 3.3/8 ", 60°, 6 (11/17/06) = a SPF 9 -518" Cement Retainer at 5460' MD, Unable ■ Isolated Beluga Perforations: to establish injection at 3000psi. = MD ff 1 V I Date U5 5,350' - 5,370' 2 4,899' - 4,906' Gun Type (6/21/04) ]) (Squeezed) 2 -3/8" (10 /8 /06) ® I U6 5,380'- 5,400' 20' 4,925'- 4,940' (6/21/04) (Squeezed) 3 -3/8" (10 /8 /06) i1 ill n 1' f'' _ii ` IL TD PBTD 8,110' MD 5,251' MD 7,559' TVD 4,793' TVD Well Name & Number: Kenai Beluga Unit 33 -6 Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 4,940' - 4,990' Perf (TVD): 4,502' - 4,549' Angle @ KOP & Depth: -2° / 100 ft @ 550' Angle @ Perfs: 22 Date Completed: 2/22/03 Ground Level: 66' (AMSL) RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 9/10/2009 • • . Ili Kenai Gas Field KBU 33 -06 04/15/2013 lia orp Ala*las, ids: Tubing hanger, ICC-CXS, 11 X Kenai Gas Field 4''/ EUE lift and susp, w/ 4" KBU 33 -06 type H BPV profile, 6 Y," 20X133/8X95/8X4%X23/8 hanger neck, Alloy material Coiled tubing hanger, VG- CTM, 3" nominal X2 3/8 EUE 8rd susp X 3" GS Baker Fish Neck lift, w/ 2" Type H BPV and grapple for 2" coil BHTA Otis, 4 1/16 5M X 6.5" Qtis Quick Union 1 i �C p, -, O Valve, swab, WKM -M, e c `j, �> 4 1/16 5M FE, HWO, \fi ���. � � c ��a� AA c o' 4,' "33 , ai cats o.,f III � rs � O Valve, upper master, WKM -M, /t 41/165M FE, HWO, AA ..i e ,Rtcg'„ PA V a xv M N Coiled Tubing head, Vetco ,� ■ 2 11163 FE, Gray, 4 1/16 5M FE X 41/16 5M stdd, w/ 1- e ' ' Valve, wing, WKM -M, 2 1/16 5M SSO 41°0111 1 2 1/16 5 3" Safeco operator NO COIL HUNG OFF IN HEAD ,. .« VG 100. �. vaNerW1n, NWO,�' Coiled Tubing head, Vetco 111! 165MF Gray, 4 1/16 5M FE X r 21� 4 1/16 5M stdd, w/ 1- ■ s �' Valve, wing, WKM -M, 2 1/16 5M SSO - 1 1 2 1/16 5M FE, w/ 13" Safeco 2 3/8 Coil in head Agin ' \ / = operator Valve, lower master, WKM -M, a Q 4 1/16 5M FE, HWO, AAt n o. �,,, Adapter, ICC, 11 5M FE X t[1 '• _ 12t 41/165M, w /6''A "seal 1 pocket Tubing head, ICC -CD-2, r. 1 135/83M X 115M,w/2- «..... 21/16 SM SSO, X -bottom 1 � � prep, 3 Y: VR profile, :r' WKM -M, 21/16 5M locator pins for dual FE, HWO, AA hangers . I�+� ' ll��[` >��i ti......... Casing head, t 'r"rgp7 McEvoy SL, 13 5/8 3M X 1!1 - 'ti tE Valve, WKM -M,2" 3M LP, ' 1 0 133/8 SOW, w/ 2 -2" �?' HWO AA LPO, ■a L—»— 1 911 -I.. ■ 1p .., .. .,:__ MEMMEMMEM • • Kenai Gas Field 11 Well: KBU 33 -06 PROPOSED Last Completed: 7/6/2000 Ililcarp Alaska, LLC PTD: 199 -024 CASING DETAIL RFC: MSL = 8T 121.6 AGL Size Type Wt/ Grade/ Conn ID Top Btm C 20" Conductor 133 / K -55 / N/A Surf 126' i 1 j 6 13 -3/8' Surface 68 / L -80 / BTC 12.415 Surf 1,525' E 9 5/8" Intermediate 40 / L -80 / BTC 8.835 Surf 5,022' TUBING DETAIL .. 1 2 -3/8 Production 4.7 / L -80 1.995 Surf I 4,500' t 13 -3/8" 4 ; s JEWELRY DETAIL y:, No Depth Item 1 ±4,420' Arrowset Packer 2 ±4,450' X- Nipple 3 ±4,500' WEG 4 ±4,915' CIBP 5 5,180' Baker Model D Packer " 6 5,231' WLEG .0 ;, 7 5,460' Cement Retainer , k PERFORATION DETAIL , o3,17 0,14 , 1 Zone To (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling 5.2 Sands ±4,520' ±4,640' ±4,128' ±4,235 ±120' Future Future i i Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' Future Isolated Beluga - U5 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed ' toy 5.2 Sands r , OPEN HOLE / CEMENT DETAIL 13 - 3/8" 17 - 1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. i " 9 - 5/8" 12 - 1/4" hole cmt w/ 570 sks of Class G, 12 ppg. TOC @ ±4,890' P. � 4 r l r ' C PA i TOF @5,188' E. 7/12/2007 TOC @5,251' �'! 6 °a , 9-5/8' , t o 7, - ■ I et 51/2 ! TD 4,110' PBTD = 5,251' Revised By: TDF 4/24/2013 • • Kenai Gas Field KBU 33 -06 Proposed HHskorp Un a, t.rx: 04/16/2013 Kenai Gas Field Tubing hanger, ICC-CXS, 11 X KBU 33 -06 4''/ EUE lift and susp, w/ 4" 20X133/8X95/8X23/8 type H BPV profile, 6 X" hanger neck, Alloy material Hanger will be bushed back to 2 3/8 &d EUE BHTA, Otis, 4 1/16 5M X 6.5" Otis Quick Union c 5 s Valve, swab, WKM -M, c �\c��'r �S ��'\ o c 41 /165M�FE,HWO, ! o a ° � a� -V ,i46 a \ 5 Q 3 IIII Valve, upper master, WKM -M, `� 4 1/16 5M FE, HWO, AA (r;l -a mp Valve, lower master, WKM -M, °'e, '" 4 1/16 5M FE, HWO, AA ear � ' IV tlt "' fit Adapter, ICC, 11 5M FE X 4 1/16 5M, w/ 6 '/." seal pocket Tubing head, ICC -CD-2, , � , , ' ,,_ 13 5/8 3M X11 5M, w/ 2- 2 1/16 5M SSO, X- bottom 11' Elm [UJ Valve, WKM -M, 2 1/16 5M prep, 1'/: VR profile, ^ FE, HWO, AA locator pins for dual ® I 1 o : hangers 1� It I I i i k 1∎i� l j' • aim . Casing head, — `- ? �= McEvoy SL 135/83MX !ii I I Valve, WKM- M, 2 "3M LP, 13 3/8 SOW, w /2- 2" ? HWO, AA A Ilf M-. s e : off, .., • • .. ini Kenai Gas Field KBU 33 -06 BOP 04/15/2013 Nitrorpr Ua *ka, t,t,t: Kenai Gas Field Tubing hanger, ICC -CXS, 11 X KBU 33 -06 4 Y. EUE lift and susp, w/ 4" 20 X 13 3/8 X 9 5/8 X 4 Y2 type H BPV profile, 6 Y." hanger neck, Alloy material 3.98' ' Hydril ' GK 11" -5000 111 111 111 111111 11IIIIt111I111 _ ► U m 2 7/8 5 variables 4.54' _ • 1 _� 11" 50 + _ = Blind 44, 111 Ill alt ail Ill I 0 a . IIP Iii I1t 1 1. 1 IN l 1[1`° 1 1 O I Tubing ead, ICC -CD-2, rat ® ® rat g Valve, WKM-M,2 1/1 5 M 13 5/8 3M X 11 5M, w/ 2- „ FE, HWO, AA 2 1/16 5M SSO, X- bottom t prep, 1 Y VR profile, 1 11114 ` T' M oc , . . , locator pins for dual •- v hangers Y!t Casing head, - yt�- McEvoy SL, ' ` 135/83MX 11i tIt Valve, WKM- M, 2 "3M LP, 133/BSOW,w/2 -2" ∎ ■ 'e HWO, AA LPO, M IiMa 40` WORM ' 0 0 RECEIVED STATE OF ALASKA APR 3 0 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS (7.0 20 AAC 25.280 i i . Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ •' Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing 111 Time Extension Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Complete Q 2 Operator Name: 4. Current Well Class: 5. Permit to Drill Number: L , i Alaska, LLC Exploratory ❑ Development el . 199 -024 ;:i. Address: Stratigraphic ❑ Service ❑ 6. API Number. ✓900 Centerpoint Drive, Anchorage AK, 99503 50- 133 - 20487 -01 . '0 • 7. If perforating: 8. Well Name and N - What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes ❑ No ❑ : Beluga Unit 33 -06 9. Property Designation (Lease Number): FEDA028142 • 11. Total Depth MD (ft): - 10. Field /Pool(s): Kenai Fiel / Up Tyonek Belu•a G. ,� terling 6 Gas & Storage Pool PRESENT WELL COND ITION SUMMARY Total Depth TVD (ft):?Ilh d Effective Depth MD (ft): Effective Depth TVD (ft): •I a measured): Junk (measured): � 4 ° SCSI' e� • 8,110 .7 -6,1-et . NI ' 4,739 �� 5,251' • 5,188' Casing Length Size MD Burst Collapse Structural PT' Conductor 94' 20" 115' 115' 3,060psi 1,500psi Surface 1,547' 13 -3/8" 1,568' ` .� 1,540' 3,450psi 1,950psi Intermediate 5,303 9 -5/8" 5,810' _`,` 5,324' 5,750psi 3,090psi Production r -4 1/4 I 1411 Liner R rforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Schematic Reference Schematic 4 -1 " 12.6 / L -80 4,850' r.'=ackers and SSSV Type: & A • ack= - d SSSV MD (ft) and TVD (ft): Baker Model D Permanent Packer and N/A N ■A • 5,180'(MD) / 4,732'(TVD) and N/A 12. Attachments: Description Summary of Proposal •V` , 13. Well • ass after proposed work: Q� Detailed Operations Program ❑ BOP Sketch ,' xp ra •ry ❑ Stratigraphic ❑ Development Q • Service ❑ 14. Estimated Date for \ 5. W-Il Status after proposed work: Commencing Operations: 5/3/201 oil ❑ Gas le • WDSPL ❑ Suspended ❑ 13. Verbal Approval: Date: ' WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 1 I hereby certify that the foregoing is true and correct t• he best of my knowledge. Contact Shane Bennett Email sbennettahilcori .com Printed Name j' -ne :- - •ett Title Operations Engineer i Signature /� Phone 777-8425 Date 4/29/2013 COMMISSION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number: . � 313 -2� Plug Integrity ❑ BOP est L; Mechanical Integrity Test ❑ Location Clearance ❑ Other: • SCANNED MAY 0 6 2 °13 Spacing Exception Required? Yes ❑ No / Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and \ 1 3 Form 10 -403 (Revised 10/2012) Ap o li a o fjIiforl2 months from the date of approval. Attachments in upii t '1� , ki i.... V 6\ • Well Prognosis Well: KBU 33 -06 Hiker!) Alaska, LI) Date: 4/14/2013 Well Name: KBU 33 -06 API Number: 50- 133 - 204 - 8700 -00 Current Status: Online Leg: Estimated Start Date: May 5, 2013 Rig: Cloverleaf Rig # 4 Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts (907) 777 - 8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: AFE Current Bottom Hole Pressure: —125 psi Based on current Pool 6 pressure Maximum Expected BHP: —125 psi Based on current Pool 6 pressure Max. Anticipated Surface Pressure: —90 psi Based on 0.02 psi /ft gas gradient) Brief Well Summary KBU 33 -06 was drilled in 4/2000 as a Beluga and Tyonek dual string completion with no production casing but just two 3.5" cemented strings. The concept behind cementing two strings without a production liner was to save money and retain the ability to access and stimulate "higher" quality Beluga sands but also able to stimulate the lower quality sands which require different stimulations. The first four months of production were done with no stimulation but production tripled after stimulation in 11/2000. In early 2003 both strings were found to be kinked at 6170' MD and after a third party study on the mechanism of this kink it was concluded this was due to compaction at some interval above the productive zones due to depletion. Because the well had no casing to support the shear forces, the cement failed inward and the tubing was kinked. In 2/2003 a plug was set in both the LS and the SS to isolate the tubing below the kink and the seemingly watery Tyonek perfs. Both strings were perforated higher in the middle Beluga. After the Beluga was perforated, fill became an increasing problem and multiple fill clean outs were attempted. In 2/2004 a RWO was performed to make the well a single upper Beluga producer and perforated based on RFT data in nearby wells. The upper Beluga flowed gas with excess water production and the well loaded up with sand and water. In 10/2006 the Upper Beluga was plugged and the well was and recompleted to Pool 6. This completion was originally a 4 1/2" tubing string but did not flow above unloading rates so a 2 3/8" coiled tubing string was installed with a 1 3/4" concentric coiled tubing string inside to provide for concentric gas lift. The two inner strings were found to be plugged with sand in 9/2008 the inner string was pulled. The current completion is a 2 3/8" coiled tubing velocity string inside of 4 1/2" tubing. OBJECTIVE OF WORKOVER Pull the current packerless completion, both the 2 3/8" coiled tubing velocity string and 4 tubing. Run the HES TMD3D cased hole log as deep as possible. Install a plug over the current Pool 6 perforations. Run in a new 2 3/8" tubing tail, packer and new 2 3/8" production tubing, depths for tail and packer will be set once HES TMD3D has been identified. This will leave enough rat hole to cut the tubing string so as to test the Sterling Gas Pools above the 5.2 if necessary. Conduct JSA on rig up operations. • Well Prognosis Well: KBU 33 -06 H'lcwv Alaska, LI) Date: 4/14/2013 Pre Work over Rig Procedure 1. Pre pulling unit activities. 2. Close and tag (lock out/ tag out /bleed) pressure sources to wellhead from flow lines and gas lift supply lines. 3. Shoot fluid levels on casing and tubing. Record pressures on tubing and casing. Coiled Tubing Procedure 4. RU Coiled tubing and test Quad BOPE, test low 300 psi /4500 psi high. a. Notify AOGCC 24hrs in advance to witness b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. 5. Latch onto 2 -3/8" coiled tubing velocity string and pull on to coil reel. 6. RDMO Work -over Rig Procedure 7. MIRU Cloverleaf pulling unit. Set two way check and test from below. 8. ND tree, NU BOPE and test to 250 psi low /3,000 psi high, annular to 250 psi low /2,500 psi high. a. Notify AOGCC 24hrs in advance to witness b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. c. Notify BLM 48 hours in advance of BOP test. 9. Pull 4 Tubing 10. Rig up SL and tag with dummy drift 1.9" and 40' long 11. Run Halliburton TMD3D log to SL tag 12. RU E -line and test lubricator to 250psi low /2,500psi 13. RIH and set bridge plug at +/- 4,915' to isolate the open Sterling Pool 6 — C1 perfs (4,940' MD top of perfs). Dump bail 25' of cement on top of plug and pressure test to 1,500 psi. 14. RIH and tag TOC at +/- 4,890'. 15. RD Eline. 16. RIH with 2 3/8" tubing tail, packer and new 2 3/8" production tubing with the packer and tubing tail set depth to be determined after HES TMD3D log. 17. ND BOP and NU tree. Test wellhead to 5,000 psi. 18. RDMO 19. Turn well over to production. Eline perforations will be identified at a later date. Eline Procedure 20. RU Eline and test lubricator to low 250 and high 2500 psi 21. RIH and perforate Pool 5.2 between the depths of 4520' MD and 4620' MD. Exact perforation depths will be determined based on the Halliburton TMD3D log run in step #11. Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic • • KBU 33 -6 A #: #: 199-024 50- 13 API 3-204 PI #: 50-133-20487-00-00 Pad 41 -7 Property Des: A - 028142 37' FN L, 4,068' FWL KB Elevation: 87' (21.6' AGL) X = 274,976.7 Sec. 7, T4N, R11 W, S.M. MARATHON Y = 2,361,976.2 Spud Date: 4/28/2000 TD Date: 5/20/2000 Rig Released: 5/27/2000 21:00 hrs Conductor i ", 20" K -55 133 ppf Top Bottom MD 0' 115' TVD 0' 115' Production Tubing Surface Casing 4 -1/2" L -80 12.6 ppf / 13 -3/8" L -80 68 ppf BTC Top Bottom Top Bottom MD Surf 4,850' MD 0' 1,568' TVD Surf 4,419' TVD 0' 1,540' 17 -1/2" hole cmt w/ 600 sks of Class G, X Nipple @ 4,801' RKB 12 100 sks to surface. WEG @ 4,850' RKB ppg Velocity String Tubing Intermediate Casing 2 -3 / 8 " 9 -5/8" L -80 40 ppf BTC Top Bottom Top Bottom MD Surf 5,178' TVD Surf 4,725' all MD 0' 5,810' 2 -3/8" BHA Description TVD 0' 5,324' 2 -3/8 ": (Assy Bottoms Up, Tested to 15,000 #) I 12 - 1/4" hole cmt w/ 570 sks of Class G, - Centralizer (3.50" OD X 2.375" ID X 12.00" Long) 12 ppg. - NoGo /Xover (2.50" OD X 1.135" ID X 8.75" Long) =at __ - Straight Bar (2.50" OD X 2.375" ID X 10' Long) - Grapple CT Connector (3.00" OD X 2.375" ID X 10" Long) r Tag fill 9/10/09 , i 1.25" DD bailer @ 5,183' Tag top of fill / junk @ 5,188' CTM Baker Model D Permanent Packer I l i.. � (7/12/07) @5,180'MD ' - Sealbore Extension i a _ .. Top of Cement -10' sub . ` i @ 5,251' ELM -3.812 X Nipple , -10' sub - Wireline Re -entry Guide © 5,231' Sterling Pool -6 Perforations: MD ft TVD Gun Type Date C1 4,940'- 4,990' 50' 4,502' - 4,549' 3 -3/8 ", 60°, 6 (11/17/06) SPF 9 -5/8" Cement Retainer at 5460' MD, Unable --■ to establish injection at 3000psi. Isolated Beluga Perforations: MD ft TVD Date U5 5,350'- 5,370' 20' 4,899' - 4,906' Gun Type (6/21/04) ^ ' (Squeezed) 2 -3/8" (10/8/06) i „ U 6 5,380' - 5,400' 20' 4,925'- 4,940' (6/21/04) � ' (Squ 3 -3/8" (10/8/06) • ii . h -1) IL TD PBTD 8,110' MD 5,251' MD 7,559' TVD 4,793' TVD . Well Name & Number: Kenai Beluga Unit 33 -6 Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 4,940' - 4,990' Perf (TVD): 4,502' - 4,549' Angle @ KOP & Depth: -2° / 100 ft @ 550' Angle @ Perfs: 22° Date Completed: 2/22/03 Ground Level: 66' (AMSL) RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 9/10/2009 • • Kenai Gas Field Well: KBU 33 -06 PROPOSED Last Completed: 7/6/2000 ililcorp Alaska, LLC PTD: 199 -024 CASING DETAIL RJB:MSL= 87 /21.6AGL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K -55 / N/A Surf 126' 13 -3/8' Surface 68 / L -80 / BTC 12.415 Surf 1,525' 0 d 9 - 5/8" Intermediate 40 / L -80 / BTC 8.835 Surf 5,022' ;, M TUBING DETAIL • '4 `4 ■ 2 -3/8" Production 4.7 / L -80 1.995 Surf 4,500' 13 -3/8" 4 A JEWELRY DETAIL i No Depth Item 1 ±4,420' Arrowset Packer 2 ±4,450' X- Nipple 3 ±4,500' WEG , 4 ±4,915' CIBP :4' , 5 5,180' Baker Model D Packer 41 6 5,231' WLEG 64 ' 7 5,460' Cement Retainer as I .1 1 Pi PERFORATION DETAIL 7'4 , Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status , Sterling 5.2 Sands ±4,520' ±4,640' ±4,128' ±4,235 ±120' Future Future Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' Future Isolated Beluga US 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed v r 5.2 Sands 4 OPEN HOLE / CEMENT DETAIL 13 -3/8" 17 -1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. 4 9 -5/8" 12 -1/4" hole cmt w/ 570 sks of Class G, 12 ppg. i. i TOC @ ±4,898 ' - , ` '.. 4 t g 1 t TOF @5,188' ' ` q 7/12/2007 TOC @5,251' ' 6 - At '' 9-5/8" € .r Ai re k 1 5-1/2" TD 4,110' PBTD = 5,251' Revised By: TDF 4/24/2013 • • Kenai Gas Field KBU 33 -06 BOP Hilrorp .1In.ka. I.1.: 04/15/2013 Kenai Gas Field Tubing hanger, ICC -CXS, 11 X KBU 33 -06 4 Y: EUE lift and susp, w/ 4" 20 X 13 3/8 X 9 5/8 X 4'A type H BPV profile, 6'/." hanger neck, Alloy material 3.98' Hydril • GK 11" -5000 111 lit lit ll#II1 ill III III 111 111 4.54' g � 0'... 1 - 2 7/8 -5 variables I 11 "- 5000 �: Blind 1111 IiI Ill ti _t !t9 1 1 IIt 111 �i 2.00 i N t4 Iii Ilt Ill til `Ill" 1 . Tubing head, ICC -CD-2, li! iii 13 5/8 3M X 11 5M, w/ 2- Va lve, W KM -M, 2 1/16 5M 2 1/16 5M 550, X -bottom s. FE , H WO, AA prep, 1 % VR profile, ! i� 1 II1 u 1 ;11 �.1 locator pins for dual hangers 1 1114 Casing head, »...i I a lve, WKMM2 "3M LP 13 3/8 SOWw/ 2- 2" ,r M2 LPO, M imolo » -I- ►i • • • • Kenai Gas Field • KBU 33 -06 }Til ,*+I r.4a. ILIA; 04/15/2013 Tubing hanger, ICC-CXS, 11 X Kenai Gas Field 4 % EUE lift and susp, w/ 4" KBU 33 -06 type H BPV profile, 6'/," 20 X 13 3/8 X 9 5/8 X 4''/ X 2 3/8 hanger neck, Alloy material Coiled tubing hanger, VG- CTM, 3" nominal X 2 3/8 EUE 8rd susp X 3" GS Baker Fish Neck Lift, w/ 2" Type H BPV and grapple for 2" coil BHTA, Otis, 4 1/16 5M X 6.5" Qtis Quick Union 4,') Valve, Valve, swab, WKM -M, •c / �, �\ 4 1/16 5M FE, HWO, � \�e, .1` ¢ 44' ff.,, '1 ' <14s0QO 4MMM: 1 :411 11 1 (9) Valve, upper master, WKM -M, 4 1/16 5M FE, HWO, AA 0 vale w�Fg Hv AP rd� e, O, Coiled Tubing head, Vetco - 21 � 1 6 5M Gray, 4 1/16 5M FE X - 41/16 5M stdd, w/ 1- s Valve, wing, WKM -M, 2 1/16 5M SSO !I!u 2 1/16 SM FE, w/ 13" Safeco NO COIL HUNG OFF IN HEAD operator e u. ve,`N�nBVGwo, PA Coiled Tubing head, Vetco ® va \165Myt,H Gray, 4 1/16 5M FE X 21� 41/165M stdd, w/ 1- L' iN Valve, wing, WKM -M, 2 1/16 5M SSO MR ! fit1 I O P 2 1/16 5M FE, w/ 13" Safeco 2 3/8 Coil in head - ` f° - operator a rt, Valve, lower master, WKM -M, P ti' 4 1/16 5M FE, HWO, AA Adapter, ICC, 11 5M FE X 1171 4 1/16 5M, w/ 6'/." seal pocket Tubing head, ICC -CD-2, 13 5/8 3M X 11 5M, w/ 2- 21/165MSSO,X -bottom Jwri prep, 1 VR profile, p ins for dual Valve, WKM -M, 2 1/16 5M p .. 1 • � FE, HWQ AA locator hangers NW. gAil II� 'AJl�41. it , Iii T Casing head, McEvoy SL, rf III 111 13 5/8 3M X Valve, WKM -M, 2" 3M LP, 133 /8 SOW,w /2 -2" � 2 HWO AA LPO, Il11 1 1I 1 4�' ,11. yE I I • • 1 Kenai Gas Field K131.133-06 Proposed 04/16/2013 if&arp AIA.ka. LL(: Kenai Gas Field Tubing hanger, ICC-CXS, 11 X KBU 33 -06 4''A EUE lift and susp, w/ 4" 20 X 13 3/8 X 9 5/8 X 2 3/8 type H BPV profile, 6'''A" hanger neck, Alloy material Hanger will be bushed back to 2 3/8 8rd EUE BHTA, Otis, 4 1/16 5M X 6.5" Qtis Quick Union n) .k. Amu- 4 Valve, swab, WKM -M, \ . < ' � � ?%\ o c 4 1/16 5M FE, HWO, K+ " Ja�J¢ \'''4)4\ `� esa� AA 4,11) . ---.12' kg, O Q 4, „,,,,q 1 k. i , 1 Iii[ s �i f o Valve, upper master, WKM -M, 4 1/16 5M FE, HWO, AA i. A t ' oilMo '• �. Valve, lower master, WKM -M, n .� 41/165M FE,HWO,AA a� n AI?) 131 ";,fit ' la a Adapter, ICC, 11 5M FE X 4 1/16 5M, w/ 6''A" seal '.. pocket Tubing head, ICC -CD-2, g, m;� ,_ 13 5/8 3M X11 5M, w/ 2- €� `r 2 1/16 5M SSO, X -bottom a i l ! ill Valve, WKM -M, 2 1/16 5M prep, 1''A VR profile, In air, FE, HWO, AA locator pins for dual _ <? e ' hangers .I ■! � IC All 1 I ioiitk IIJ1I i I11-I• 44 at e" T Casing head, x - II McEvoy SL 13 5/8 3M X ll Ili Valve, WKM- M, 2 "3M LP, 133 /8 SOW, w /2 -2" g 0 HWO, AA LPO, N � . �o� 1 �7 / . - k 41 • • Schwartz, Guy L (DOA) From: Shane Bennett - (C) <sbennett@hilcorp.com> Sent: Thursday, May 02, 2013 10:44 AM To: Schwartz, Guy L (DOA) Cc: Keith Elliott; Chris Myers; Tom Fouts; Jeremy Mardambek Subject: RE: KBU 33 -06 (PTD 199 -024) Guy by email I am asking to withdraw, Sundry no. 312 -207, submitted on April 30th. Shane Hilcorp Alaska, LLC Shane A. Bennett Operation Engineer 0 (907) 777 -8425 C (325) 203 -7487 H (325) 643 -2401 From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Thursday, May 02, 2013 1:30 PM To: Shane Bennett - (C) Subject: RE: KBU 33 -06 (PTD 199 -024) Shane, Will you send me an email requesting that you withdraw the last sundry submitted on April 30th. Sundry no. 312 -207 Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Schwartz, Guy L (DOA) Sent: Thursday, May 02, 2013 10:28 AM To: Shane Bennett - (C) Subject: KBU 33-06 (PTD 199 -024) 1 + • • Shane, I have gotten three sundry applications for this well. From what I can tell the first one 312 -187 will cover all well work up until perforating. The second one 312 -201 will cover just the perforations. The third one you submitted on April 30th ( 312 -207 ) is not needed. I am sending it back to you as not needed. It is a duplicate sundry ... Please use a combination of the first two sundries to complete the work on this well. Call me if you have any questions. Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907- 793 -1226 office 2 V OF 7'j • • . y w \� ����j, _ s� THE STATE Alaska Oil and Gas 0,114IN 0f LAsKA Conservation Co ission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 A Main: 907.279.1 433 Fax: 907.276.7542 Jeremy Mardambek Reservoir Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Kenai Field, Tyonek Beluga & Sterling 6 Gas & Storage Pool, Kenai Beluga Unit 33 -06 Sundry Number: 313 -187 Dear Mr. Mardambek: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. - Seamount, Jr. Commissioner DATED this Z day of April, 2013. Encl. SCANS APR 2 5 Z013 1 1. • 1 RECEIVED • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .APR 16 2013 APPLICATION FOR SUNDRY APPROVALS _ 20 AAC 25.280 AOGCC 1 Type of Request: Abandon ❑ Plug for Redrill ❑ 0 Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations [V{ 744 Perforate ❑ Pull Tubing 5 ' Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Name: 4. Current Well Class: 5. Permit to Drill Number: lii;corp Alaska, LLC Exploratory ❑ Development 0 199 -024 - Address: Stratigraphic ❑ Service ❑ 6. API Number. 300 Centerpoint Drive, Anchorage AK, 99503 50-133-20487-00-00 i If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A No Beluga Unit 33 -06 require spacing exception? Ye ❑ K e nai Belu Will planned perforations squire a p g ❑ g p p 9. Property Designation (Lease Number): 10. Field /Pool(s): • FEDA028142 Kenai Field / Up Tyonek Beluga Gas, Sterling 6 Gas & Storage Pool i 1. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth VD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,110 7 J.14 11 . 2 ' 13 5,188 4,739 5,251' 5,188' Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 115' 115' 3,060psi 1,500psi Surface 1,547' 13 -3/8" 1,568' 1,540' 3,450psi 1,950psi Intermediate 5,303 9 -5/8" 5,810' 5,324' 5,750psi 3,090psi 1 . • Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Schematic Reference Schematic 4 -1/2" 12.6 / L -80 4,850' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Model D Permanent Packer and N/A 5,180'(MD) / 4,732'(TVD) and N/A 1 12. Attachments: Description Summary of Proposal Is 13. Well Class after proposed work: tailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ i 4. Estimated Date for 15. Well Status after proposed work: i F(L� ammencing Operations: 5/9/2013 Oil El Gas 5 w WDSPL ❑ Suspended !1 Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 'Commission Representative: N/A GSTOR ❑ SPLUG ❑ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Bennett Email sbennett hilcorp.com P''inted Name Jeremy Mardambek • • Title Reservoir Engineer Signature Phone 777 -8388 Date 4/16/2013 COMMISSION USE ONLY F Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i',ug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: - X 3Q°° S:, 130 e �-- / 1 ) �cpa.�c_Cs, , .E1.4....,....--a-t -D Pr 6 W 'L r Lt t,N� / RBDMS APR 2 5 2O1i S acin Exception Required? Yes IIII No ❑ i.. Subsequent Form Required: / 0 — Y Oil %Ai. I � APPROVED Y 472,..57/3 ��;pproved by: ,,/ COMMISSIONER THE COMMISSION Date: On Submit Form ane \� - 444A A p roved application is valid for 12 months from th date of approval. Attach u ! 5 e 6 i c ut 10 ants in D plicate 2 4 1' Atie O • Well Prognosis Well: KBU 33 -06 Hileorp Alaska, LL Date: 4/14/2013 Well Name: KBU 33 -06 API Number: 50- 133 -204- 8700 -00 Current Status: Online Leg: Estimated Start Date: May 5, 2013 Rig: Cloverleaf Rig # 4 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts (907) 777 -8398 Permit to Drill Number: First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) AFE Number: AFE Current Bottom Hole Pressure: —125 psi Based on current Pool 6 pressure Maximum Expected BHP: —125 psi Based on current Pool 6 pressure Max. Anticipated Surface Pressure: —90 psi Based on 0.02 psi /ft gas gradient) Brief Well Summary KBU 33 -06 was drilled in 4/2000 as a Beluga and Tyonek dual string completion with no production casing but just two 3.5" cemented strings. The concept behind cementing two strings without a production liner was to save money and retain the ability to access and stimulate "higher" quality Beluga sands but also able to stimulate the lower quality sands which require different stimulations. The first four months of production were done with no stimulation but production tripled after stimulation in 11/2000. In early 2003 both strings were found to be kinked at 6170' MD and after a third party study on the mechanism of this kink it was concluded this was due to compaction at some interval above the productive zones due to depletion. Because the well had no casing to support the shear forces, the cement failed inward and the tubing was kinked. In 2/2003 a plug was set in both the LS and the SS to isolate the tubing below the kink and the seemingly watery Tyonek perfs. Both strings were perforated higher in the middle Beluga. After the Beluga was perforated, fill became an increasing problem and multiple fill clean outs were attempted. In 2/2004 a RWO was performed to make the well a single upper Beluga producer and perforated based on RFT data in nearby wells. The upper Beluga flowed gas with excess water production and the well loaded up with sand and water. In 10/2006 the Upper Beluga was plugged and the well was and recompleted to Pool 6. This completion was originally a 4 -1/2" tubing string but did not flow above unloading rates so a 2 -3/8" coiled tubing string was installed with a 1 -3/4" concentric coiled tubing string inside to provide for concentric gas lift. The two inner strings were found to be plugged with sand in 9/2008 the inner string was pulled. The current completion is a 2 -3/8" coiled tubing velocity string inside of 4 -1/2" tubing. OBJECTIVE OF WORKOVER Pull the current packerless completion, both the 2 -3/8" coiled tubing velocity string and 4 -W' tubing. Run the HES TMD3D cased hole log as deep as possible. Install a plug over the current Pool 6 perforations. Run in a new 2 -3/8" tubing tail, packer and new 2 -3/8" production tubing, depths for tail and packer will be set once HES TMD3D has been kWh This will leave enough rat hole to cut the tubing string so as to test the Sterling Gas Pools above the 5.2 if necessary. Conduct JSA on rig up operations. II __ i ,. • • Well Prognosis Well: KBU 33 -06 HiIcoru Alaska, Lb, Date: 4/14/2013 Pre Work over Rig Procedure 1. Pre pulling unit activities. 2. Close and tag (lock out/ tag out /bleed) pressure sources to wellhead from flow lines and gas lift supply lines. 3. Shoot fluid levels on casing and tubing. Record pressures on tubing and casing. Coiled Tubing Procedure 4. RU Coiled tubing and test Quad BOPE, test low 300 psi /4500 psi high. a. Notify AOGCC 24hrs in advance to witness 1 b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. 5. Latch onto 2 -3/8" coiled tubing velocity string and pull on to coil reel. 6. RDMO Work -over Rig Procedure 7. MIRU Cloverleaf pulling unit. Set two way check and test from below. 8. ND tree, NU BOPE and test to 250 psi low /3,000 psi high, annular to 250 psi low /2,500 psi high. a. Notify AOGCC 24hrs in advance to witness b. BOPE test results must be reported in daily operations report AND MUST BE PROVIDED TO THE AOGCC WITHIN 5 DAYS. c. Notify BLM 48 hours in advance of BOP test. 9. Pull 43/2" Tubing 10. Rig up SL and tag with dummy drift 1.9" and 40' long 11. Run Halliburton TMD3D log to SL tag 12. RU E -line and test lubricator to 250psi low /2,500psi 13. RIH and set bridge plug at +/- 4,915' to isolate the open Sterling Pool 6 — C1 perfs (4,940' MD top of perfs). Dump bail 25' of cement on top of plug and pressure test to 1,500 psi. C k,„,4 14. RIH and tag TOC at +/- 4,890'. 15. RD Eline. 16. RIH with 2 -3/8" tubing tail, packer and new 2 -3/8" production tubing with the packer and tubing tail set depth to be determined after HES TMD3D log. 17. Land tubing, set packer at ±4,420' and pressure test casing to 1,500psi. 18. ND BOP and NU tree. Test wellhead to 5,000 psi. 19. RDMO 20. Turn well over to production. Eline perforations will be identified at a later date. Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic • • KBU 33 -6 Permit #: #: 199-024 50- 13 API 3-204 PI #: 50-133-20487-00-00 Pad 41 -7 Property Des: A - 028142 3T F N L, 4,068' FWL KB Elevation: 87' (21.6' AGL) x= 274,976.7 Sec. 7, T4N, R11 W, S.M. MARATISON Y= 2,361,976.2 Spud Date: 4/28/2000 TD Date: 5/20/2000 Riq Released: 5/27/2000 21:00 hrs Conductor 1 20" K -55 133 ppf Top Bottom MD 0' 115' i , TVD 0' 115' Production Tubing r Surface Casing 4 -1/2" L -80 12.6 ppf - 13 -3/8" L -80 68 ppf BTC Top Bottom - Top Bottom MD Surf 4,850' MD 0' 1,568' TVD Surf 4,419' TVD 0' 1,540' 17 -1/2" hole cmt w/ 600 sks of Class G, X Nipple @ 4,801' RKB 12 ppg. 100 sks to surface. WEG @ 4,850' RKB Velocity String Tubing . 1 Intermediate Casing 2 -3/8" 9 -5/8" L -80 40 ppf BTC Top Bottom Top Bottom Surf 5,178' TVD Surf 4,725' MD 0' 5,810' 2 -3/8" BHA Description TVD 0' 5,324' 2 -3/8 (Assy Bottoms Up, Tested to 15,000 #) 1 12 - 1/4" hole cmt w/ 570 sks of Class G, - Centralizer (3.50" OD X 2.375" ID X 12.00" Long) ■ 12 NoGo /Xover (2.50" OD X 1.135" ID X 8.75" Long) 111= PP9• - Straight Bar (2.50" OD X 2.375" ID X 10' Long) --,,r - Grapple CT Connector (3.00" OD X 2.375" ID X 10" Long) Tag fill 9110/09 1.25" DD bailer @ 5,183' Tag top of fill /junk @ 5,188' CTM Baker Model D Permanent Packer II 4" (7112107) Id @5,180'MD - Sealbore Extension Top of Cement -10 sub @ 5,251' ELM -3.812 X Nipple tio _10' sub -Wireline Re -entry Guide @ 5,231' { e s= ' ■ I Sterling Pool -6 Perforations: I MD ft TVD Gun Type Date C1 4,940'-4,990' 50' 4,502' - 4,549' 3 -3/8", 60 °, 6 (11/17/06) , SPF 9 -5/8" Cement Retainer at 5460' MD, Unable ■ to establish injection at 3000psi. ,,, I Isolated Beluga Perforations: I Date M TVD U5 5,350' - 5,370' 20' 4,899'- 4,906' Gun Type (6/21/04) (Squeezed) 2 -318" (10/8/06) „� U6 5,380'- 5,400' 20' 4,925'- 4,940' (6/21/04) (Squeezed) 3 -3/8" (10/8/06) it I i� °; , ' 11 ii - TD PBTD 8,110' MD 5,251' MD 7,559' TVD 4,793' TVD Well Name & Number: Kenai Beluga Unit 33 -6 Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 4,940' - 4,990' Perf (TVD): 4,502' - 4,549' Angle @ KOP & Depth: -2° / 100 ft @ 550' Angle © Perfs: 22° Date Completed: 2/22/03 Ground Level: 66' (AMSL) RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 9/10/2009 Kenai Gas Field • • • Well: KBU 33-06 PROPOSED Last Completed: 7/6/2000 }Licari) Alaska. 1.1.f. PTD: 199 -024 nw51 = CASING DETAIL Type Wt/ Grade/ Conn Top tob 20" Conductor 133 / K -55 / N/A Surf 126' 13 3/8' Surface 68 / L -80 / BTC 12.415 Surf 1,525' 9 -5/8" Intermediate 40/ L -80/ BTC 8.835 Surf 5,022' TUBING DETAIL 2 - 3/8" 1 Production I 4.7/L - 80 � 1.995 1 Surf 4,500' 13 -3/8" JEWELRY DETAIL No Depth Item 1 ±4,420' Arrowset Packer 2 ±4,450' X- Nipple 3 ±4,500' WEr 4 4,915' CI I' 5 5,180' Baker Model D Packer 6 5,231' WLEG 7 5,460' Cement Retainer PERFORATION DETAIL 1 ne 'MD) Btm (MD) Top i D) Btm Date Status 3 2 Sterling Pool 6 - C1 4,940' 4,990' 4,502' 4,549' 50' Future solated Beluga - U5 5,350' 5,370' 4,899' 4,906' 20' 10/8/2006 Squeezed Beluga - U6 5,380' 5,400' 4,925' 4,940' 20' 10/8/2006 Squeezed 3 OPEN HOLE / CEMENT DETAIL. 13 - 3/8" 17 -1/2" hole cmt w/ 600 sks of Class G, 12 ppg. 100 sks to surface. 9 -5/8" 12 -1/4" hole cmt w/ 570 sks of Class G, 12 ppg. roc @ ±a,89a m 4 TOF @ 5,188' 7/12/2007 5 TOC @ s,x1' 6 7 9-5/8 • 5-1/2 TD 43.110' PBTD = 5.251' Revised By: TDF 4/15/2013 f • • 0 • Kenai Gas Field KBU 33 -06 nip A t rx. 04/15/2013 }� W Tubing hanger, ICC-CXS, 11 X Kenai Gas Field `,' � 1 WWWW 4Y EUE lift and susp, w /4" KBU 33 -06 W \ type H BPV profile, 61.." 20 X13 3/8 X 9 5/8 X 4% X2 3/8 hanger neck, Alloy material Coiled tubing hanger, VG- CTM, 3" nominal X 2 3/8 EUE 8rd susp X 3" GS Baker Fish Neck Lift, w/ 2" Type H BPV and grapple for2" coil BHTA, Otis, 4 1/16 5M X 6.5" Qtis Quick Union se .■ ,� V- is , Valve, swab, WKM -M, '�Q'y c QO ` Z ' % 44\ 4 1/16 5M FE, HWO, S , Ni v �� a �� S'< , a o & M ., . 43:5 . Ja 0 a� < 'q ft II. .., 'S� J d i g o r a I l Valve, upper master, WKM -M, o 41/16 5M FE, HWO, AA lio o eo G-M. \sl ..0,, WO PP Coiled Tubing head, Vetco -.��= 2 t1 1- 65Mp E,N Gray, 41 /165M FE 4 1/16 5M stdd, w/ 1- I o`O�% o � Valve, wing, WKM -M, 2 1/16 5M SSO �1� �0li 2 1/16 SM FE, w/ 13" Safeco r ^_ NO COIL HUNG OFF IN HEAD t; operator .fi f r e , 1 0 PP Coiled Tubing head, Vetco -. 1 . Vi1165MFE MN Gray, 41/16 5M FE X 2 41/165M stdd, w/ 1- ri d/ i' Valve, wing, WKM -M, 21/16 5M SS ead idyl r � 2 1/16 5M FE, w/ 13" Safeco 2 3/8 Coil in head LIVINsorl: operator Valve, lower master, WKM -M, 41/16 5M FE, HWO, AA le `7101' , , Adapter, ICC, 11 5M FE X ini •�k 1 4 1/16 5M, w/ 6'/." seal pocket Tubing head, ICC -CD-2, la 13 5/8 3M X 11 5M, w/ 2- 1111 1 2 1/16 5M SSO, X -bottom w ® i 1 prep, 1' /: VR profile, Valve, WKM -M, 21/16 5M locator pins for dual V` - { . , FE, HWO, AA hangers `I-li �I�l �I � • .�I1et 1,13 1i 11 .." 111 Casing head, • i . •- McEvoy SL, E f t - ^2 11 13 5/8 3M X ii $ Valve, WKM -M, 2" 3M LP, 133/8SOW,w/2 -2" �g > HM, AA LPO, la. 3 400i,...00, 4�i " -L w • • • • Kenai Gas Field K 3 3 -06 Proposed 04/16/2 Harm? mrp %titan. 13A. Kenai Gas Field Tubing hanger, ICC-CXS, 11 X KBU 33 -06 4'/: EUE lift and susp, w/ 4" 20 X 13 3/8 X 9 5/8 X 2 3/8 type H BPV profile, 6''A" hanger neck, Alloy material Hanger will be bushed back to 23 /88rdEUE �rof 054 9 BHTA, Otis, 4 1/16 5M X 6.5" Qtis Quick Union ti � ate !, y �'� \0� �4 O Valve, swab, WKM -M, • �� �\p� <c`T �$' < :a os 4 1/16 5M FE, HWO, ti" ¢' Ja i ° ,fie' S 'z ' Ja % O o Q mow I Ili � I Valve, upper master, WKM -M, 4 1/16 5M FE, HWO, AA it ° o! , 0 AM Valve, lower master, WKM -M, 41/16 5M FE, HWO, AA t.1 t 1'l"i - g Ifil Adapter, ICC, 11 5M FE X � 4 1/16 5M, w/ 6'/." seal _ pocket Tubing head, ICC -CD-2, r�� v: . 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X -bottom lii II . " Valve, WKM -M, 2 1/16 5M prep, 1'/ VR profile, FE, HWO, AA locator pins for dual ' 2 hangers �[ n � It ■llll i ' ; - tip Casing head, r McEvoy SL, 13 5/8 3M X III Valve, WKM -M, 2" 3M LP, 133/8SOW,w/2 -2" HWO, AA LPO, l 1 ,j� 111!-l' re v IA 7' , : lik, v P 7 . ..•, . . • . iii Kenai Gas Field KBU 33 -06 BOP 1likory :ua•ka, 11,1, . 04/15/2013 Kenai Gas Field Tubing hanger, ICC -CXS, 11 X KBU 33 -06 4 Y EUE lift and susp, w/ 4" 20 X 13 3/8 X 9 5/8 X 4 Y: type H BPV profile, 6'/." hanger neck, Alloy material 1 3.98' • Hydril • GK 11" -5000 Iii 111 111 111111 I11 III III I11 Iii 11 = 2 7/8 5 variables 4.54' 1111 11 "- 5000 11 ®: Blind 1i1 111 III 111 III FR ip , III III III III 111 1 s 2.00' ® liii , � s N Ey,� � ,4J; � Q ; � � i : 111 ail Iii fit ill ® a .. J Lam Tubing head, ICC -CD-2, 1al . ®. ,ti 13 5/8 3M X11 5M, w/ 2- ^ Velve,WKM- M,21/165M 2 1/16 SM 550, X -bottom S , FE, HWO, AA prep, 1 Y: vR profile, 11�f 14e 11 �- 00114:01111. -i locator pins for dual C� �% hangers a 111 al r` Casing head, McEvoy SL, g,� Ir i!1 135/83MX Itl _ alve,WKM M,2 "3M LP, 133/8 SOW, w/2 -2" , „? HWO, AA LPO, w 7 _ i III I I .dIN C �f A - : -A ,, lit -.' • • Schwartz, Guy L (DOA) From: Shane Bennett - (C) <sbennett@hilcorp.com> Sent: Monday, April 22, 2013 3:58 PM To: Schwartz, Guy L (DOA) Subject: Re: KBU 33-06 Pull Tubing and Complete PTD: 199-024 No a packer should be ran, I didn't right it up, but I will fix it, sorry. Shane A. Bennett TPC RESOURCES, LLC (325) 325 -7487 On Apr 22, 2013, at 6:55 PM, "Schwartz, Guy L (DOA)" < saysc! , zvartz calaska Lov< rnailto:guy.sclwartz(?alaska.gcav>> wrote: The casing should be tested too after plug is set. Is there any reason a packer cannot be run? Guy Schwartz Senior Petroleum Engineer AOGCC 907 -444 -3433 cell 907 - 793 -1226 office From: Schwartz, Guy L (DOA) Sent: Monday, April 22, 2013 3:39 PM To: 'Tom Fouts' Cc: Bettis, Patricia K (DOA); Shane Bennett - (C) Subject: RE: KBU 33 -06 Pull Tubing and Complete PTD: 199 -024 I have the sundry in hand. It is missing some basic steps like setting the plug to isolate zone 6 . ( should be at step 11 ? ?) can you send a revised procedure? Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Tom Fouts (maiito hilcorp.coril Sent: Monday, April 22, 2013 11:39 AM To: Schwartz, Guy L (DOA) Subject: KBU 33 -06 Pull Tubing and Complete PTD: 199 -024 Guy, I was hoping to get a status update for KBU 33 -06 which was submitted on 4 -16 -2013. Any information would be appreciated. 1 • Thanks, Tom Fouts 1 Ops/Reg Tech Hilcorp Alaska, LLC tfouts&micoquonl<mailte:tfouts@hi1cp_r_p.corn> Direct: (907) 777-8398 Mobile: (907) 351-5749 2 M Marathon MARATHON Oil Company October 22, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 E C~CT 2 ~ 20C8 Ala~lia Qil ~ G~ ~ ~`~~~. C.c~' A;~ul ticrags Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6 ~.; ~;~, ~ ~ ~? ~ '~ 200 ~~ p'- 6 Dear Mr. Maunder: Attached for your records is the10-404 Report of Sundry Well Operations fior KBU 33-6 well. This report covers the attempted concentric string repairs approved under Sundry #308-174. Marathon recently removed the inner 1-3/4" concentric string tubing during the attempt to return KBU 33-6 to production. The 1-3/4" coil tubing string was removed to allow for the installation of a wire-wrap screen below the 2-3/8" standing valve. It became apparent that solids had built up in the wellbore, to the bottom of the concentric string, once the 2-3/8" standing valve was removed. The well is currently shut-in waiting on further evaluation to determine future options. Please contact me at (907)283 -1371 if you have any questions or need additional information. Please return any correspondences to me utilizing the address in the letterhead above. Sincerely, ~,~ . s l Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS .~ STATE OF ALASKA • ~~~ ALAS OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing 0 Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Marathon Oil Company Na 4. Well Class Before Work: 5. Permit to Drill Number. me; Development Q Exploratory^ 199-024 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number. Kenai Alaska, 99611-1949 50-133-20487-00-00 7. KB Elevation (ft): 9. Well Name and Number. 87' 21' AGL Kenai Belu a Unit 33-6 8. Property Designation: 10. Feid/Pool(s): A - 028142 Kenai Gas Field /Sterling Pool-6 11. Present Well Condition Summary: Total Depth measured 8,110' feet Plugs (measured) 5,251' true vertical 7,410' feet Junk (measured) 5,188' Effective Depth measured 5,460' feet true vertical 5,046• feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 115' 115' 3,060 psi 1,500 psi Surface 1,547' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,303' 9-5/8" 5,810' 5,324' 5,750 psi 3,090 psi Production Liner Perforation depth: Measured depth: 4,940' - 4,990' True Vertical depth: 4,502' - 4,549' Production Tubing 4-1/2" L-80 4,850' Tubing: (size, grade, & MD) Outer Concentric Tubing 2-318" H070FF 5,166' Model D Permanent Packers and SSSV (type and measured depth) Packer 5,230` Sealbore Extension 12. Stimulation or cement squeeze summary: Intervals treated (measured): Revised 10-404 documenting the presence of the 41/2" Production Tubing and identifying the 2-3/8" string as the Outer Concentric Treatment descriptions including volumes used and final pressure: Tubing. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 64 Subsequent to operation: 0 0 0 D 54 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 ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-174 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature , Phone (907) 283-1371 Date November 11, 2008 Form 10-404 Revised 04/2 O6 ~ ~ ~, ; ~~~~~ Submit Original Only ~ ~~ ~ "~ it~t 1 STATE OF ALASKA •~ AL/~ OIL AND GAS CONSERVATION COM~ION ~~~~ ~~ EPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pult Tubing Q Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Oper Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon OII Comp ~/ N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory^ 199-024 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20487-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 87' (21' A ) Kenai Belu a Unit 33-6 8. Property Designation: 10. Field/Pool(s): A - 028142 Kenai Gas Field /Sterling Pool-6 11. Present Well Condition Summary: Total Depth measured 8,110' ~ feet Plugs (measured) 5,251' true vertical 7,410' feet Junk (measured) 5,188' Effective Depth measured 5,460' feet true vertical 5,046' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 115' 115' 3,060 psi 1,500 psi Surface 1,547' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,303' 9-5/8" 5,810' 5,324' 5,750 psi 3,090 psi Production Liner ~~~~~~~`' Pertoration depth: Measured depth: 4,940' - 4,990' ~ r' ~ / - ! ~ ~ True Vertical depth: 4,502' - 4,549 f '+',~ ~i ~~ ~ ~-y,~s~ 1~-- Tubing: (size, grade, and measured depth) w~`,~y S~tt, ~2.3/8" H FF 5,166' Model DPermanent Packers and SSSV (type and measured depth) Packer 5,230' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13'. Representative Daily Average Production Injection Data Oil-Bbl Gas-Mcf Water-Bbl asing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 64 Subsequent to operation: 0 0 0 0 54 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ ~ ervice ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WI ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or /A if C.O. Exempt: 08-174 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ Phone (907) 283-1371 Date tober 22, 2008 Form 10-404 Revised 04/200 ~ R ~ ~ ~ ~ A ~ Submit Ori~al Only ~^ ~~~~ • `~ I~perations Summary Report ,~,,,!, zpj~ Cornper~y Vhlell Name: KENAI BELUGA UNIT 33~ Daily Operations Report Date: 5!24!2008 Job Category: WELL INTERVENTION 2l HrS~mmary MIRU Pollard. Set ?{ plug and prong in V-string ~ 5173' KB. SL3rtTtne ErtlTtne Dir 0 Core ACLI Catle opE SfadE TroebkCOtle Canmeet 06:00 06:30 0.50 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA. Obtain Safe Work Permit. Discuss muster area, emergency response, and adjacent operations. 06:30 07:36 1 .10 RURD SLIK AF PU lubricator. MU tools string- RS, 5' stem, kj, 10' stem, kj, oj, 5' stem, kj, sj. MU 1 .30" GR. V!MP 100 si. Carr lubricator to WN. 07:36 07:48 0.20 TEST EQIP AF Test lubricator to 500 psi. Test good. 07:48 08:42 0.90 RUNPUL SLIK AF RIH (1) wJ 1 .30" GR. Tag @ 5176' KB. POOH. 08:42 09:12 0.50 RUNPUL SLIK AF RIH (2) wJ braided line brush to 5176' KB. Brush X nipple. POOH. 09:12 09:57 0.75 RUNPUL SLIK AF RIH (3) wJ 1 .25 " }(-line running tool and }{ plug. Set ~ 5176' KB. POOH. 09:57 10:27 0.50 RUNPUL SLIK AF RIH (4) wJ 1 .25" SB running tool and prong. Set prona in plua Coo 5174' KB. POOH. Bleed down V-strip to 0 si. Plu holdin . 10:27 11:12 0.75 RURD SLIK AF RD slick line unit. 11:12 11:27 0.25 SECURE LL AF Secure well. Close all valves. Turn in Permit. Tell operator on duty we are finished. Leave loc. Report Date: 9~'20.r2008 Job Category: WELL INTERVEN TION 2l H r Seminary tv11RU BJ Coil to pull 1-3J4" V-string. MIRU flow back tanklgas buster. Test BOP's. S13rtTlne E~tlTtne Der 0 Cak ACtll Corte opE St1trE TrofbkCafe Canmeet 07:00 08:00 1 .DO SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ and ASRC JSA's. Make specific job assignments. Discuss equipment layout for RU. Discuss our scope of operations wJ near by construction crew. 08:00 12:30 4.50 RURD COIL AF Lay liner and spill pans. Spot equipment. RU equipment. RU 2" hard lines. Spot flowback tank. Prep coil end. 12:30 14:18 1 .80 RURD COIL AF Carry BOP's to WH. Hammer up flange. RU 2" hard line to gas buster. 14:18 16:03 1 .75 TEST ROPE AF Test BOP's. Functions test pipe/slips, shears+blinds. Test good. PTest pipes./slips-25014500 psi. Test good. PTest shears+blinds-250!4500 psi. Test ood. 16:03 17:03 1 .00 SECURE LL AF Install night cap. Secure wellhead and location for the night. Turn in permit and sign out. Report Date: 9!21!2008 Job Category: WELL INTERVENTION °! H r Seminary PU iniectar, connect stinger to GS. RIH PU 1 3J4" coil. POOH and rig back coil. opf St3rtTlne E~tlT1ne Der o Code AGM Cafe StabE TrolbkCOtle Canmeet 07:00 08:00 1 .00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ and Vetco JSA's. Make specific job assignments. Discuss e ui inept la out far RU. Discuss sco a of task for toda . 08:00 10:00 2.00 RURD COIL AF PU injector, MU addttionnal lubricator, Coil connector. Pull test connecdtian 0 15 K. Good pull test. MU 3.8" centralizer with 2.5" GS take injector to well head. PT shell to 1000 psig. 10:00 11:00 1 .00 RURD COIL AF 0 en well to latch into GS. RIH 9.5' sat down, PU 16 K, RIH, PU to 11 K, Vetco loosen bolts to release hanger. Hanger released. WHP= 37 psig. PUH to -5', set pipe slips, bled pressure, run in pipe handles to secure pipe. PU lubricator with crane 3' above GS. Cut 1 3J4" pipe below mandrel asst'. Move injector to ground, cut off BHA and made up flexable dimple on coil connector. PU injector and go to well with coil connector. Work to get he coil connector into fish. 11:00 13:00 2.00 RURD COIL AF Coil connector hard to attached to velocity string. Found coil 0.134" wall not 0.125" wall, ground off internal seam. PU injector grind velocity string coil. MU coil connector to velocity string. PU coif to 16 K, open pipe rams. PUH with coil. Coil connector cleared the goose neck to reel. 13:00 15:00 2.00 `Y'ORK CGIL .~;F POOH with call. '!"aNP= 0 siq. CT !rA 3100' CThA. Pullinq caSV out of well. www.peloton.com Report Prirrted: 10!22!2008 ~~~~ '0i1 COr~P~nY Uperations Summary Report Well Name: KENAI BELUGA UNIT 33~ SgrtTme E~tlTlne oir 0 Cotle Actli Ctltle otx 51a0ra TroiDkCOtle Canme~t 17:48 18:03 0.25 SECURE LL AF Install tree cap and secure well far the night. Turn in permit and sign out. 18:03 18:03 www.peloton.com Report Printed: 10C12C1008 • f/:: 199-024 50-133-20487-00-00 v Des: A - 028142 cation: 87' (21.6' AGL) 274,976.7 2,361,976.2 ate: 4/28/2000 eased: 5/27/2000 21:00 hrs (7/19/2007) -2-3/8" H070FF Grade, 0.134 WT w/ BHA @ 5178' KB (TD) OTI#34209 STR#25913 Mill Date 11-3-2006 Tagged Top of BHA in 2-3/8" @ 5151' KB SLM (7119/2007) Top of 2-3/8" NoGo tagged @ 5,166' KB CTM (8/1812007) Model D Permanent Packer Sealbore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' ling Pool 6 Interval MD TVD 4,940' - 4,990' 4,502' - 4,549' of Cement at 5,251 ELMD' Beluga MD TVD KBU 33-6 Pad 41-7 37' FNL, 4,068' FWL Sec. 7, T4N, R11W, S.M. ~ ~~ CC Drive Pipe 20" K-55 133 ppf T~ Bottom MD 0' 115' TVD 0' 115' Production Tubing 4-1/2" L-80 X Nipple @ 4,801' RKB WEG @ 4,850' RKB Surface Casing 13-3/8" L-80 68 ppf BTC TOE Bottom MD 0' 1,568' TVD 0' 1,540' Cmt w/ 600 sacks of Class G Intermediate Casing 9-5/8" L-80 40 ppf BTC T~ Bottom MD 0' 5,810' TVD 0' 5,324' Cmt w/ 570 sacks of Class G 2-3/8" BHA Description 2-3/8": (Assy Bottoms Up, Tested to 15,000#) - Centralizer (3.50" OD X 2.375" ID X 12.00" Long) - NoGo/Xover (2.50" OD X 1.135" ID X 8.75" Long) - (None) - Straight Bar (2.50" OD X 2.375" ID X 10 Ft Long) -Grapple CT Connector (3.00" OD X 2.375" ID X 10.00" Long) 9 5/8" Cast Iron Cement Retainer at 5460' MD, Unable to establish injection at 3000psi. Well Name & Number: KBU 33-6 Lease: Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Angle/Perfs: KOP TVD: Angle @ KOP and Depth: Completion Fluid: Date Completed: 02/24/03 Ground Level: 66' RKB: 21.6' Prepared By: Kevin Skiba Last Revision Date: 10/22/08 TD = 8,110' MD Page 1 of 2 Maunder, Thomas E (DOA) From: Skiba, Kevin J. [kskiba@marathonoil.com] Sent: Tuesday, November 11, 2008 7:44 AM To: Maunder, Thomas E (DOA) Subject: RE: KBU 33-6 (199-024) Attachments: KBU 33-6 10-404 Revised CT Removal 111108.pdf Tom, I have attached a revised 10-404 Sundry for this well. The revised sundry documents both of the tubing strings in this well. Before work began, KBU 33-6 had been fitted with a 4-1/2" Production String and a 2-3/8" / 1-3/4" Concentric String. No work was conducted on the 4-1/2" Production Tubing, so it remains the same. The inner 1- 3/4" Concentric String tubing was removed to install the wire wrap screen below the 2-3/8" tubing. It was determined that solids had migrated into the wellbore, to the bottom of the Concentric String tubing. The solids accumulation would eliminate any chance of success for this project. So further work on this well was put on-hold pending additional evaluation to determine future well work options. The well is currently configured with 2 tubing strings: "4-1/2" Production String * 2-3/8" Remaining Outer Concentric String portion I apologize for the 4-1/2" tubing information omission. Please let me know if you also need to have the revised sundry submitted in paper form. Sincerely, Kevin Slaba Engineering 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: Monday, November 10, 2008 8:25 AM To: Skiba, Kevin J. Subject: KBU 33-6 (199-024) Kevin, I have reviewed the 404 submitted for the recent work on this well and have a couple of questions. 1. From the operations summary, it does not appear that the velocity string was redeployed although the drawing shows such a string in the well. Is there a velocity string in the well? 2. On the 404, in the tubing line, the specifications of the velocity string are given however nothing is listed for the 4-1/2n tubing originally set in the well. Thanks in advance. Call or message with any questions. 11/11/2008 ~ • Marathon Oil Company Alaska Asset Team Marathon ~ ~.-~;~~ ~~~~~~~ ~ KeOnag AK 99611 MARATHON Oil Company ~k~ "~'~ "~"" Telephone 907/283-1371 ~AY ~ ~ 200$ Fax 907/283-1350 Oil & Gas C~r~s. C~~~~`i~i~~ ~ May 15, 2008 '~'I~~~ ~Chor~9~ (,~ r ~ ~~ Mr. Tom Maunder Alaska 4il & Gas Conservation Commission -~h~SE ~`-~'~'`~~~ S~~ 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List Dear Mr. Maunder: ~ ~ ~ ~c `~ e~C..VC~~ ~ ~'C~ UC~ ~ .~- ~ ~~ ~ ~~~~ G.~~. ~~~~t~C~OS~G,\Ov.-S~ ~o ~..p °~- ~ a~-Se~ ~ ~ `~- a- U`~.~ ~c,~ ~ ~o ~"~ Marathon and the AOGCC have had discussions on the follow-up reporting needed to close out 10-403 Sundry approved well work activities. Work has been ongoing to identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, '~~ ~P~~1'wv Kevin J. Skiba Engineering Technician ~~~,~~~~~~'~ Fa~~~°~ ;~ R:k: ?C~~~ C~.CCO ~'°~~ ~ ~~ ~"~~ ~~ ~ ~~ ~ ~ Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS . M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 33- 6 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~ V ~~ ~~~' ~ ~ LUUS ~ilaska qii ~ Gas Conso Commissiar Anchorage Attached is a Sundry Report 10-404 for work performed on well KBU 33-6. Marathon set a plug a velocity string at 5375' to lift water off of the U5 & U6 formations. Gas was metered and used to lift water from the well but no positive gas resulted from this hang off. This work was authorized under sundry #30~ 333. ~ Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, ~ Wayne E. Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operations Summary Kenai Well File KJS .~ STATE OF ALASKA s~~~~~ MAY i~ ~6~~L~, ALAS~OIL AND GAS CONSERVATION COMM~O ka ~ . REPORT OF SUNDRY WELL OPERATIO~~ ~'f & Gas Cons. Cornm,ss~~~ Anchorage 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ Install veloctiy~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ^ Waiver~ Time Extension ^ String Change Approved Program ~ Operat. Shutdown ^ Perforate ^ Re-enter Suspended W ell ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: rvame: Marathon Oil Company Development ~^ Exploratory^ 199-024 J 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20487-00-00 7. KB Elevation (ft): 9. Well Name and Number: 187' ~ Kenai Belu a Unit 33-6 8. Property Designation: 10. Field/Pool(s): FE~ A- 028142 . Kenai Gas Field / Beluga Pool 11. Present Well Condition Summary: Add 1 3/4" velocity string Total Depth measured 8,110'. feet Plugs (measured) 5230 true vertical 7,410' feet Junk (measured) p Effective Depth measured 5,460' feet true vertical 5,046' feet Casing Length Size MD ND Burst Collapse Structural 0 0 0 0 0 0 Conductor 115' 20" 115' 115' 3,060 psi 1,500 psi Surface 1,568' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,810' 9-5/8" 5,810' S,324' 5,750 psi 3,090 psi Production 0 0 0 0 0 0 Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 5350 - 5400' True Vertical depth: 4899 - 4940' Tubing: (size, grade, and measured depth) 4 1/5" L-80 5229 Packers and SSSV (type and measured depth) Model D Permanent Packer 5,230' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 75 Subsequent to operation: 0 0 0 0 75 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ 304- 333 / Contact Kevin Skiba (907) 283-1371 Printed Name W E Ci ll Title W ll W k O S i /~ '~~ j DS ayne . sse e or ver uperv sor a ` Signature Phone (907) 283-1308 Date January 24, 2008 Form 10-404 Revised 04/2006 ~~c~ ~(~ ~~~ 2€ Zppg Submit Original Only ~~~~'!~ ~?'°~ ~ • Marathon Oil Company Page 1 of 2 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 9/8/2004 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/8/2004 11:30 - 19:30 8.00 RURD COIL CMPRUN Rigged up BJ CT w/ 1-3/4" hangoff spool and MOC flowback iron. 9/9/2004 07:15 - 08:00 0.75 SAFETY MTG CMPRUN Obtain work permit, hold safety meeting 08:00 - 09:20 1.33 RURD COIL CMPRUN Pick up injector head and finish rigging in auxiliary equipment. 09:20 - 10:00 0.67 BLOWD COIL CMPRUN Purge CT with N2 10:00 - 10:45 0.75 PULD BHA_ CMPRUN Make up hangoff BHA inGuding CT oonnector (pull tested to 10,000 Ibs), 10.8' straight bar, nipple for a KEP-1.188 Equalizing Plug profile, and pump off plug/re-entry guide. 10:45 - 12:00 1.25 RUNPU COIL CMPRUN RIH w/ 1-3/4" velociry string to 5405' to ensure perfs are clear. PU 30' to get on depth. Measure space out and pick up additional 14' in prep. to cut CT. 12:00 - 12:30 0.50 SAFETY MTG CMPRUN Hold safety meeting to discuss steps involved in cutting CT 12:30 - 12:40 0.17 CUT COIL CMPRUN Close tubing rams/slips. Lock in. Bleed off WHP above rams. Shut in well and observe to ensure no building pressure past rams. 12:40 - 14:00 1.33 NUND WLHD CMPRUN Walk injector head up pipe. Install o-plate and polish rod clamp backup. Cut weephole in CT with a hacksaw to ensure no pressure, then cut entirely. MU GS spear to CT and Vetco hanger mandrel to CT stub. 14:00 - 15:15 1.25 NUND WLHD CMPRUN Engage GS spear into Vetco hanger. MU lubricator and pull test connection. Equalize BOPs on either side of tubing rams. Mark tubing behind counter head for spaceout. Pull test connection to 18,000 Ibs 15:15 - 15:45 0.50 NUND WLHD CMPRUN Open pipe rams once all pressure is equalized. Turn lockscres to engage load shoulder. RIH -14' to load shoulder watching wt indicator and mark on pipe. 15:45 - 16:00 0.25 TEST WLHD CMPRUN Run in lock screws and pressure test wellhead to 2500psi. Test good, string successfully landed. 16:00 - 17:00 1.00 PUMP WTR CMPRUN Pump off of hanger PUH w/ CT. Close swab valve and bleed down CT. Begin cooling off N2 unit. 17:00 - 17:30 0.50 PUMP N2 CMPRUN Pump N2 to blow off CT pump off plug. 17:30 - 21:30 4.00 RURD COIL CMPRUN Rig down CTU. 11/6/2004 12:00 - 13:00 1.00 RURD OTHR CMPFLW Rigged up N2 unit to CTxtubing annulus. 13:00 - 13:15 0.25 SAFETY MTG_ CMPFLW Hold brief safety meeting regarding hi P and hearing protection 13:15 - 14:45 1.50 PUMP_ N2_ CMPFLW Begin pumping N2. Pump at 1000 scfm. Pressure increased to 1700psi. See returns to tank after about 10 minutes. See N2 returns after additional 20 minutes. Well lifting water steadily. Prepare field gas line to flow to lift flange while still lifting with N2. Pump pressure up to 1800psi. Expected pressure to drop with N2 around end of CT. Pinch back N2 rate in attempt to lower lift pressure. Lift pressure remains at 1800 psi with 150 scfm. 14:45 - 16:00 1.25 FLOW TEST CMPFLW Cut N2 and observe retums. Returns dwindling. Rig N2 unit off of well as it is needed elsewhere. Continue to monitor to open tank with field gas used to lift. Chart indicates that 800psi FTP from 24-6h is not adequate to lift 33-6. Tum 33-6 to production to monitor. Well did not continue to lift water. 4/16/2005 07:30 - 08:30 1.00 SAFETY MTG CMPFLW Sign in obtain permit, hold safety meeting. 08:30 - 11:30 3.00 RURD PIPE CMPFLW RU from tree top to flowback tank. 11:30 - 12:30 1.00 RURD OTHR CMPFLW RU BJ N2 pump. Tree has 1600psi. Bleed pressure down in 5 minutes to open top tank. Cool down N2 unit. 12:30 - 12:45 0.25 TEST EQIP CMPFLW Test pumping lines to 4500psi. 12:45 - 13:30 0.75 PUMP N2_ CMPFLW Begin pumping down annulus. Pressure jumped from 900 to 1700psi. Shut down pump to avoid collapsing CT velociry string. Wait for pressure to bleed down and make additional attempts to pump. Pressure continued to climb. Decide to cancel lift to come up with second plan. Printed: 1/26/2008 9:57:11 AM ~ ~ Marathon Oil Company Page 2 of 2 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENA! BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 9/8/2004 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Co e Phase Description of Operations 4/16/2005 13:30 - 14:00 0.50 RURD EQIP CMPFLW RD N2 equipment. Move flowback line from tree top to permit slickline if needed. Printed: 1/26/2008 9:57:11 AM • M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 33- 6 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~ MA~' ~. 6 2008 ~~laska ~~i ~ Gas Cons. Commission Anchorage , o ~,u ~~~ ~~;~;~~~~~~ ~ Ai~t~ ~~t ~ ZD~~ Dear Mr. Maunder: Attached is a Sundry Report 10-404 for work perFormed on well KBU 33-6. Marathon set a plug above the lower Beluga on the Short side of KBU 33-6. The plug was set at 6250'. We also added perforations from 6088' - 6094'. There was no response. This work was authorized under sundry #303-050. Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, ~ r Wayne E. Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operations Sumrnary Kenai Well File KJS ~~. ~~~~ov~e , STATE OF ALASKA `sa~o~ , ~ ALAS~OIL AND GAS CONSERVATION COMM~ON ~~~Y ~~.LLO~ REPORT OF SUNDRY WELL OPERAT~~~~4~ &~as Cons. Commissi~n Anr.h~~eQe 1. Operations Abandon Repair Well Plug PerForations ~ Stimulate Other Add plug - PerFormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool Q Waiver~ Time Extension ^ in short side Change Approved Program ~ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ~& perforate ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ~^ Exploratory^ 199-024 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: , PO Box 1949, Kenai Alaska, 99611-1949 50-133-20487-00-00 7. KB Elevation (ft): 9. Well Name and Number. 87' Kenai Belu a Unit 33-6S 8. Property Designation: 10. Field/Pool(s): ,~"E",D A- 028142 Kenai Gas Field / Beluga 11. Present Well Condition Summary: Set plug above lower Beluga & perforate Middle Beluga @ 6088 - 6104' Total Depth measured 8110 , feet Plugs (measured) 6250.00 true vertical 7585 feet Junk (measured) p Effective Depth measured 7594 feet true vertical 7057 feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 115' 20" 115' 115' 3,060 psi 1,500 psi Surface 1,568' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,810' 9-5/8" 5,810' S,324' 5,750 psi 3,090 psi Production 0 0 0 0 0 0 Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 6387 - 6490 True Vertical depth: 5883 - 5983 3 1 /2" 9.2 5617 Tubing: (size, grade, and measured depth) 2 7/8" 6.5 2439 2 7/8" L-80 970 Packers and SSSV (type and measured depth) n/a 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-Bbi Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 400 Subsequent to operation: 0 0 0 0 400 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~^ Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ~^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exem t: ~ 303-050 Contact Kevin Skiba (907) 283-1371 e ~h~~~ Print d Name Wayne E. Cissell Title Well Work Over Supervisor U Signature Phone (907) 283-1308 Date January 24, 2008 Form 10-404 Revised 04/2006 ~p~~ ~f p Submit Original Only ~~J1Ml~ {~~[~ .;i.ll: ~ ~ L~d~g • • MARATHON OIL COMPANY Page 1 of.1. Daily Recompletion Report ' Re-complete to New Zone ` WELL NAME KENAI BELUGA UNIT 33-6 KB 21.0 GL 66.00 24 HR PROG TMD TVD DFS 0 DOL 0 RPT A 6-S DATE 24-Feb-2003 SUPERVISOR Denise Titus RIG NAME & NO. AUTH MD WBS TA0308288EXP SAPANBS COST FIELD NAME KENAI RIG PHONE MOC WI 100.0000 NRI DAILY WELL COST 55,784 USD CUM WELL COST 130,805 USD STATEIPROV ALASKA COUNTY/OTHER KENAI LAST CASING 0 NEXT CASING in 0 ft LEAKOFF CURRENT STATUS ~ 6AM Ri in down electric line 24 HR FORECAST Attem t to flow OPERATION COMMENTS Perforated M6 {6088'-6104') in short string from with 2in, 2006 PowerJet, HMX, 4spf, Odeg phase. Pwh=400psi S SU MANHRS WORKED 0.00 ACCIDENT TYPE None LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP9 N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM= TO HRS FROM TO OPERATIONS SU SUB' PHASE OP`! SUBOP TRBL-' ~.. MMARY, DESCRIPTION . 17:00 19:15 2.25 Begin RU on SS. Repair crane. 19:15 19:30 025 Arm plug set device with GR/CCL. 19:30 19:50 0.33 Pressure test w/ Haskel pump to 300/2500psi. Test good. 19:50 21:15 1.42 Corelate on depth with AIT gamma ray. Flag line at 6000'. Set plug at 6250'. Tag plug and POOH. 21:15 22:00 0.75 At surFace. Call production to bleed N2 pressure cap off of well. 22:00 00:20 2.33 Blow well down to 400psi via test separator 00:20 01:15 0.92 Correlate on depth 01:15 01:30 0.25 Orientate gun and perforate 6094'-6104'. No immediate pressure response. 01:30 02:20 0.83 POOH 02:20 02:45 0.42 At surface MU gun #2. 02:45 04:00 1.25 RIH, Correlate and orientate. PerForate 6088'-6094'. 04:00 04:30 0.50 POOH. Pwh=400psi. No visible pressure gain. 04:30 06:30 2.00 RDMO Schlumberger CASING SU LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE ID 'SHOETEST . 'MAXSICP MD ' 7Ub . ` .=:VYT °° GRADE BURST.. ~ Printed: 1/26l2008 9:50:02AM ~ M Marathon MARATHON Oil Company January 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 9071283-1371 Fax 907/283-1350 F ~.~~~~~~g~~~ :411C y - 2D0~ ~~ ~~ ~ ~I~ \~ ~ 0 ~-~ , ~~~ ~ ~ MAY ~ ~ ~'' ~~ Reference: 10-404 Sundry Report Field: Kenai Gas Field ~,~a~ka ~?+1 &~a~ C°~S' ~'°~m~~s~~n Well: Kenai Beluga Unit 33- 6 Anct~ora9e Dear Mr. Maunder: Attached is a Sundry Report 10-404 for work perFormed on well KBU 33-6. Marathon set a plug above the lower Beluga on the Long side of KBU 33-6. The plug was set at 6378'. We also added perforations M12 @ 6252 - 6269' and the M13 @ 6296 - 6331'. There was no response. This work was authorized under sundry #303-035. Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, ~ Wayne E. Cissell Well Work Over Supervisor Enclosures: 90-404 Sundry Report cc: Houston Well File Operations Summary Kenai Well File KJS __ ~ p.ve~' ~~V~~ Y ~L~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMM oN MAY 1~ 20Q8 REPORT OF SUNDRY WELL OPERATIONS Als~ska ~ii ~ Gas Cor~s. Cammission 1. Operations Abandon Repair Weli Plug Perforations ~ Stimulate pG Add plug Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool Q Waiver ~ Time Extension ^ in long side Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 8~ perforate ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: rvame: Marathon Oil Company Development ~ Exploratory^ 199-024 ' 3. Address: Stratigraphic ^ Service ~ 6. API Number: ~ PO Box 1949, Kenai Alaska, 99611-1949 50-133-20487-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87' Kenai Belu a Unit 33-6L ' 8. Property Designation: 10. Field/Pool(s): ~ A- 028142 Kenai Gas Field / Beluga ~ 11. Present Well Condition Summary: Set plug above lower Beluga & perforate Middle Beluga @ 6252 - 6269' Total Depth measured 8110 feet Plugs (measured) 6250.00 true verticai 75g5 feet Junk (measured) p Effective Depth measured 7594 feet true vertical 7p57 feet Casing Length Size MD ND Burst Collapse Structural 0 0 0 0 0 0 Conductor 115' 20" 115' 115' 3,060 psi 1,500 psi Surface 1,568' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,810' 9-5/8" 5,810' 5,324' 5,750 psi 3,090 psi Production 0 0 0 0 0 0 Liner 0 0 0 0 0 0 Perforation depth: Measured depth: 6387 - 6490 True Vertical depth: 5883 - 5983 3 1 /2" 9.2 5617 Tubing: (size, grade, and measured depth) 2 7/8" 6.5 2439 2 7/8" L-80 970 Packers and SSSV (type and measured depth) n/a 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 900 Subsequent to operation: 0 0 0 0 900 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ~ Development ^~ Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. 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: 303-035 `~ Contact Kevin Skiba (907) 283-1371 Printed Nam W E Ci ll Titl W ll W k O S i ~~l ~ e ayne . sse e ver or uperv sor e Signature Phone (907) 283-1308 Date January 24, 2008 ~ ~~.~ ar~ ~~~~ 2€~ 2009 Form 10-404 Revised 04/2006 Submit Original Only ~ • MARATHON OIL COMPANY Page 1 of 2 Daily Recompletion Report Re-complete to New Zone WELL NAME KENAI BELUGA UNIT 33-6 KB 21.0 GL 66.00 24 HR PROG TMD TVD DFS 0 DOL 0 RPT # 5-L DATE 23-Feb-2003 SUPERVISOR Denise Titus RIG NAME & NO. AUTH MD WBS TA0308288EXP SAP/W8S COS7 FIELD NAME KENAI RIG PHONE MOC WI 100.0000 NRI DAILY WELL COST 2,165 USD CUM WELL COST 75,021 USD STATEIPROV ALASKA COUNTYIOTHER KENA~ LAST CASING 0 NEXT CASING in 0 ft LEAKOFF CURRENT STATUS ~ 6AM Lon strin erfs com lete. Pwh=900 si SDFN 24 HR FORECAST Move to short strin and add M6 erforations OPERATION COMMENTS Set bridge piug at 6378'. Perforated phase. Pwh=900psi M12 (6252'-6269') and M13 (6296'-6331') in long string from with 2in, 2006 PowerJet, HMX, 4spf, Odeg SAFETY SU MMARY MANHRS WORKED 0.00 ACCIDENT TYPE None LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP7 N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: OPERATIONS SU MMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 09:30 11:30 2.00 RU on long string. Pressure test to 300/2500psi. Pwh=2500psi (from N2 cap) 11:30 13:00 1.50 RIH w/ CCL and Baker 035 N2 CIBP. 13:00 13:20 0.33 Correlate to pup jt. Tag bottom at 6410' WLM. PUH and set plug at 6378'. 13:20 14:30 1.17 POOH 14:30 15:00 0.50 At surface. Bleed down lubricator and MU POT-C orientated perforating head. 15:00 15:30 0.50 Bleed tubing pressure down to Pwh=100psi. Arm 5' gun. 15:30 16:45 1.25 RIH 16:45 17:30 0.75 Correlate on depth. Attempt to orientate tool. Tool will not rotate 17:30 18:30 1.00 POOH w/ gun. Swap out POT-C firing head. 18:30 19:45 1.25 RIH and correlate gun on depth. Orientate tool and fire. No immediate pressure response. Perforate 6326'-6331'. 19:45 20:15 0.50 POOH 20:15 20:30 0.25 MU 10' gun section 20:30 21:20 0.83 RIH. Correlate gun on depth. Orientate tool and fire. Perforate 6316'-6326'. Pwh=O. 21:20 21:50 0.50 POOH. 21:50 23:00 1.17 MU 10' Gun. RIH. Correlate on depth and orientate. Good indications of shots. No visible pressure response. Perforate 6306'-6316'. POOH 23:00 00:00 1.00 MU 10' gun. RIH. Correlate and orientate. Gun did not fire. POOH. 00:00 00:15 0.25 Swap out firing head. 00:15 01:00 0.75 RIH w/ 10' gun. Correlate and oreintate. Shoot on depth. No pressure response. Pwh=Opsi. Perforate 6296'-6306'. POOH M13 perForating complete 01:00 01:45 0.75 Check out POT-C orientating device at surface. Proper functioning. MU 7' gun. 01:45 02:15 0.50 Correlate and orientate gun on depth. Perforate 6262'-6269'. Pwh=Opsi. POOH. Printed: 1/26/2008 10:00:15 AM . • • MARATHON OIL COMPANY Page 2 of 2 Daily Recompletion Report Re-complete to New Zone WELL NAME KENAI BELUGA UNIT 33-6 KB 21.0 GL 66.00 24 HR PROG TMD TVD DFS 0 DOL 0 RPT # 5-L DATE 23-Feb-2003 OPERATIONS SU MMARY FROM TO HRS FROM TO SUB PHASE OP SUBOP TRBL DESCRIPTION 02:15 02:45 0.50 MU final 10' gun. Pwh=800psi. 02:45 03:15 0.50 Correlate and orientate. Fire gun. Poor indication of shots at surFace. POOH. 03:15 03:45 0.50 At surFace. Guns did fire. Perforated 6252'-6262'. Pwh=900psi. 03:45 04:30 0.75 RD lubricator and BOPs. SDFN A M Y LAST BOP TE ST: LAST CASING TEST: NEXT BOP TEST: SIZE ID SHOE TEST MAX SICP MD TVD WT GRADE BURST Printed: 1/26/2008 10:00:15 AM ~ M Marathon MARATHON Oil Company January 24, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 33- 6 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~~~ ~1AY ~ ~ L0~8 Alaska Qil ~ Gas Co~s. ~p~m~ssion Anc~aorage ~ o~- b ~ 1°~ ~ '~~~.~i~~°'i.,~ !~.~~i ~"~ ~~' ~'~ ~1~~~1 . !~~v~,~ .. e~° Attached is a Sundry Report 10-404 for work perFormed on well KBU 33-6. Marathon used coil tubing to clean out fill in well and establish well back to production. The work was conducted on permit #301-264. Please return any correspondences to me utilizing the address in the letterhead. You can contact Kevin Skiba at (907)283 -1371 if you have any questions or need additional information. Sincerely, . Wayne Cissell Well Work Over Supervisor Enclosures: 10-404 Sundry Report cc: Houston Well File Operations Summary Kenai Well File DMD KJS ~~ ~~ S-o2o~v1~ STATE OF ALASKA ~~~~ ~G ALAS~IL AND GAS CONSERVATION C ~I'[OOd REPORT OF SUNDRY WELL OPE~TIONS ~missio~ ~ ° C as Cons. Co 1. Operations Abandon Repair Well Plug Perforations Stimulat ~rag Other ~ Coil tubing Clean Performed: Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver Time E~ension ~ OUt Of ShOPt _ Change Approved Program ~ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ~ Strin 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development /^ Exploratory~ 199-024 ' 3. Address: p0 Box 1949 Stratigraphic ^ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20487-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42' Kenai Belu a Unit 33-6 8. Property Designation: 10. Field/Pool(s): ~'D A- 028142 Kenai Gas Field / Beluga Pool 11. Present Well Condition Summary: Total Depth measured $,110' ' feet Plugs (measured) 7,594' (Cement) true vertical 7,666' - feet Junk (measured) NA Effective Depth measured 7,594' feet true vertical 7,057' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 115' 115' 3,060 psi 1,500 psi Surface 7,547' 13-3/8" 1,568' 7,540' 3,450 psi 1,950 psi Intermediate 5,789' 9-5/8" 5,810' 5,324' S,750 psi 3,090 psi Production Liner Perforation depth: Measured depth: 6,387'-6,490' True Vertical depth: 5,883'-5,983' Tubing: (size, grade, and MD) (SS) 3-1/2"/2-7/8" &(LS) 3-1/2" L-80 (SS) 8,087' &(LS) 8,088' Packers and SSSV (type and measured depth) NA NA 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 Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to weil operation: 0 0 0 0 75 Subsequent to operation: 0 2,300 22 0 650 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 301-260 'f Contact Kevin Skiba (907) 283-1371 ~~ Printed Name ennis M. Donovan Title Production Engineer ~~~ Signature ' ~ Phone (907) 283-1333 Date January 24, 2008 ~~..~ -_. ~~~ ~r~ ~~~ ~ ~ ~D~~ Submit Ori Form 10-404 Revised 04/2006 ginal Only i s A V ~ MAR~ITHON~OIL COMPANY DAILY WELL OPERATIONS REFt ~ PAGE 1 OF 1~ DATE: 9/11/2001 FIELD: Kenai Gas Field WELL #: KBU 33-6S FILL DEPTH/DATE: 7371' TUBING: CASING: N/A DATE LAST WL WORK: TREE CONDITION: Good WORK DONE: BENCHES OPEN: PRESENT OPERATION: CT CLEANOUT OTHER: TIME: SUMMARY nG npFRaT~nNS 0700 1300 1440 2100 RU CT unit. Held safety and environmental meeting. Discussed procedure with crew. PT BOP to 5000 psig. PT flow back iron with 3% KCL to 3000 psig. B/D PT water to flow back tank prior to RIH with CT. RIH with 1.75" CT, 2" noule. Opened up FB iron to flow back tank while running in well with CT. Had fluid returns while running in hole. WHP= 1035 PSIG, CT weight while running in the well, was @ 6500 Ib. PU weight 14200 Ibs. Tagged fill at 6438' KBD, WHP= 1060 psig. Start N2 at 500 SCFM. Work CT down to 6453' tagged fill, work CT up 20' then back down again. Repeat several sweeps. Work the CT down to 6600' . Sat @ 6600' pumping N2 for 30 minutes, water to tank during N2 pumping . WHP=650 psig, PIP=1150 psig CTP. Start OOH while pumping N2. @ 3600 ft. No liquid to tank, SD N2 POOH. IRD CT unit. Note: Well placed on production at 2.3 MMCFPD rate. Total of 22 BBLs H20 to tank during CT clean out. VBJ services Veco vac truck Veco crane operator DAILY COST: CUM: REPORTED BY: Wayne Cissell • ~- ~ ~-~~ ALASSA OIL AKD GAS C01~TSERQATI011i COl-iMISSIOIQ Ken Walsh Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai AK 996 1 1-1 949 ~~~~ MAY ~ ~ 200$ • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE,ALtCSKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field, Beluga Gas Pool, Kenai Beluga Unit 33-6 Sundry Number: 308-174 . ~ ~'~ ~~~~ l./ Dear Mr. Walsh: hcation for Sundry Approval relating to the Enclosed is the approved App ' above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further tune as the Commission grants for goo hcat~on shown, a person affected by it may ~ is considered timely if itais rePived by for rehearing. A request for rehearing 4:30 PM on the 23rd day following the date kends lAteerson may not appeal day if the 23rd day falls on a holiday or wee p has been a Commission decision to Superior Court unless rehearing requested. Sincerely, ~~~~ Daniel T. Seamount, Jr. Chair 2~ DATED thi.s~ / day of May, 2008 Encl. M Marathon MARATHON Oil Company May 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Well: Kenai Gas Field Kenai Beluga Unit 33-6 Dear Mr. Maunder: r~ U Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~(~~';~ Alaska Orl ~ Gas ions. Anc~orase C°mm~ssior~ ~`~ v ~i Enclosed please find the 10-403 Application for Sundry Approvals for KBU 33-6. Marathon proposes to pull the inner concentric string 1-3/4" coil tubing, to replace the standing valve located in the 2-3/8" outer tubing. The replacement standing valve will be equipped with a 4' wire wrap screen, to prevent sand infiltration. The 1-3/4" inner coil tubing will then be reinstalled 10' above the 2-3/8" setting depth. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~' ,~.~ ~V , ,~ Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice cc: AOGCC Work Procedure Houston Well File Well Schematic Kenai Well File KJS KDW ~"CCGC1 ~/ ~ p, ~`~•3~ STATE OF ALASKA ~~~- Ov ALA OIL AND GAS CONSERVATION COM SIGN 5" MAY 4 8 r's~ °?: ~ ,~-- \~ APPLICATION FOR SUNDRY APPRO~I~if & Gas t~~~n;`. ,_~.v .~~`'~' 20 AAC 25.280 A. t;t;r`..~~,:.~= 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Replace standing Change approved program ^ Pull Tubing Q , Perforate New Pool ^ Re-enter Suspended Well ^ valve 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: `' Development ^ , Exploratory ^ 199-024 3. Address: PO BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20487-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership oriandownership changes; R S i E i ~ ? ^ Kenai Beluga Unit 33-6 pac ng xception red equ Yes No 9. Property Designation: 10. KB Elevation (ft); 11, Field/Pool(s): ~-~ A - 028142 8T ~ Kenai Gas Field I Sterling Pool 6 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): 8,110' - 7,410' 5,460' 5,046' 5,251' 5,188' Casing Length Size MD TVD Burst Collapse Structural Conductor g4' 20" 115' 115' 3,080 psi 1,500 psi Surface 1,547' 13-3/8" 1,568' 1,540' 3,450 psi 1,950 psi Intermediate 5,303' 9-5/8" 5,810' 5,324' 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,940' - 4,990' 4,502' - 4,549' 2-3/8" H070FF 5,166' Packers and SSSV Type: Packers and SSSV MD (ft): Model D Permanent Packer 5,230' 13. Attachments: Description Summary of Proposal [] 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: May 13, 20 ~ 9 ~~1 1 Oil ^ Gas Q Plugged ^ Abandoned ^ CC L ,` ~ 4 17. Verbal Approval: Date: Jrf~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission 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 Ken D. Walsh Title Senior Production Engineer Signature ~ Phone Date (907) 283-1311 May 6, 2008 ~- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q ~ ! 17 Plug Integrity ^ BOP Test `~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~-,,~V~ Ps.~ +JV~ ~Li~ Subsequent Form Required: 1 t 0 APPROVED BY ~ /~ Approved b : COMMI SIO R THE CO MISSION Date: y Form 10-403 Revised 06/2006 ~ ~ ~~/~ '~~ 1~'~~ ~bmit in Duplicate ORIGINAL • ~ M MARATHON MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 33-6 2008 CT String Hang-off Procedure (4-28-2008) WBS # W0.07.15714.CAP.001 ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Notes: • This procedure covers work to pull the 1.75" OD coil tubing velocity string and to retrieve the 1- 1/4" Standing Valve which is unseated and "sanded in" the 2-3/8" Concentric Coil String. • Previous efforts to bail sand and fish the 1-1/4" Standing Valve have proven unsuccessful. • Concentric Coil Tubing Head installed. • Flow line modifications for concentric coil tubing string have been installed. Procedure: Pulling 1-3/4" CT 1. MIRU Pollard Wire line Services. Hold PJSM and obtain Safe Work Permit. Install wire line valve with pump in sub to Otis tree cap connection. Pressure test wire line valve and lubricator with pump to 2500 psig. 2. RIH tag top of profile with 1.25" GR. Verify the tubing is open. RIH to profile with 1.25" brush. 3. RIH w/ 1-1/4" tool string with 1.25" eaualizina X plug. Set in profile @ 5156'CTM. RIH with prong. RD Pollard. 4. MIRU MOC flow back eauipment. Including open-top flow back tank, choke skid, gas buster, and flow back iron. MIRU 500 bbls. Rain-for-Rent fluid supply tank. Lay liner and berm area around tank and wellhead. Load supply tank with 6% KCL. Deliver diesel fuel man-lift and two light towers. Lock out electrical connections and remove well house. 5. MIRU BJ 1~/+" coil tubing and nitrogen. Conduct pre-job safety meeting. Spot CTU with 1$/+" CT work reel, and pumping equipment. Nipple up and test BOP's. .Test flow back iron 250/4500 psi. Stab CT work string in injector. Make up CT connector. Pull test CT connector to 15,000 lbs. *** Notify the AOGCC James Reag t'a? 9071276-7542 (24 or longer) prior to testing the BOP's 6. Make up tool string with BHA to latch into the velocity string hanger. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 lbs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. Page 2 of 3 • • 7. Back off lock-down screws on the hanger. PU coil head above BOP's, set tubing rams. B/D velocity string. PU injector by walking up coil. Install 1-3/4" polish rod clamp and C-plate from top of BOP. Cut coil above and below the GS. MU Roll-on coil connector. Reel coil onto working string. 8. Rig back coil tubing. 9. MIRU Pollard W/L. .Hold PJSM and fill out Safe Work Permit. Install QTS and wire line valve with pump in sub to Otis tree cap connection. Pressure test QTS, wire line valve, and lubricator with pump to 2500 psig. 10. RIH wl 1-1/2" tool string with 1.80" GR. RIH w/ 1.60" LIB. Bail if necessary. 11. RIH w/ 1" GS to null 1.25" Standing Valve. Once valve is pulled, bail as necessary to assure 2-3/8" CT is open. 12. RIH w/ 1" Drive-down Bailer. Clean out 10' below 2-3/8" CT. 13. RIH w/ 4' of 1.1"wire wrapped screen on 1.25" Standing Valve. Hang off in 1.25" XN Profile. Installation of 1.75" CT 1. MIRU BJ coiled tubing unit with 6200' of 1-3/4" coiled tubing. 2. PU CT 1.75" CT WHA. Nipple up BOP's. Test BOP's to 250/4500 psi. PU 10' of 4-1/16" CQ lubricator. MU velocity string BHA to end of CT. *** Notifv the AOGCC James Regg Cad 907/276-7542 (24 or longer) prior to testing the BOP's 3. RIH with 1.75" CT velocity string and BHA w/ 1.25" blanking plug. 4. Cut coil tubing. PUH to span WHA for final landing depth of +/- 5166' (10' above 2-3/8" CT Setting Depth). Use caution when nearing depth to avoid running into 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 WHP above tubing rams to the flow back 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. 5. MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger (4" Nom C/W 3" Baker Fishing neck 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 Weatherford GS tool string assembly to coil on reel trailer. Dimple-on a 1.75" CT connector. Pull test CT connector (25,000 lbs.) 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 KBU 33-6 CT Velocity String Hangoff Procedure MBS - 5/6/2008 3:53:25 PM Page 3 of 3 • • 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. 6. 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 lbs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 7. 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. 8. Release 3" GS Running Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release Weatherford GS spear. Watch for weight change to verify release and pickup to unlatch spear. POOH. 9. Purge KCL water from CT remaining on reel trailer with nitros~en. Allow N2 to vent to flowback tank. 10. RDMO and release equipment. RD flow-back iron. Release tanks and all rental equipment to vendors. 11. MIRU Slickline Unit and Pressure Test to 1.5 Times WH Pressure. RIH to nipple landing depth of 1- 3/4" CT string with 1.25" GR. RIH w/ 1" GS to pull blanking plug. POOH. MU tool string for standing valve and RIH to 2-3/8" landing depth and set standing valve. RDMO Slickline. CONTACTS Dennis Donovan: 907-283-1333 (w) David Martens: 713-296-3302 (w) 907-398-1362 (cell) 832-472-6249(cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emerpency: Dial 911 KBU 33-6 CT Velocity String Hangoff Procedure MBS - 5/6/2008 3:53:25 PM #: 50-133-20487-00-00 ~erty Des: A - 028142 21.6' AGL (87' KB Elevation) d Date: 4/28/2000 Released: 21:00 hrs 5/2712000 274,976.7 KBU 33-6 Pad 41-7 37' FNL, 4,068' FWL Sec. 7, T4N, R11W, S.M. TD=8,110'MD Well Name & Number: KBU 33-6 Lease: Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Angle/Perfs: KOP TVD: Angle @ KOP and Depth: Completion Fluid: Date Completed: 02/24/03 Ground Level: 66' RKB: 21.6' Prepared By: Kevin Skiba Last Revision Date: 1/20/2008 MAM . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Marathon Oil Company September 7, 2007 RECEiVED SEP 1 0 2007 Alaska Oil & Gas Cons. Cl}mmission . Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 "q q - 0 ~Lt Reference: 10-404 Sundry Report Field: Kenai Gas Field Well: Kenai Beluga Unit 33- 6 Dear Mr. Maunder: Attached is a Sundry Report 10-404 for work performed on well KBU 33-6. Marathon recently installed a 2-3/8" by 1-3/4" concentric string in an attempt to improve well performance by enhancing the well's water removal capability. Please return any correspondences to me utilizing the address in the letterhead. You can contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, K~j·0htv '"",'\~~~\-\.-1J~> .~ \- - '-~~Ccwt'\c;.~~) ">~ \ \ \ -S t..\) · k9.-11j '''''~':'\ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Well Schematic Operations Summary cc: Houston Well File Kenai Well File DMD KJS . STATE OF ALASKA ..~ RECEIVED ALASKA Oil AND GAS CONSERVATION COMr210N SEP 1 0 2007 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Co:mmissiQn 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: RepairWell U Pull Tubing D Operat. Shutdown D Plug Perforations U Perforate New Pool D Perforate D 4. Well Class Before Work: Development 0 Stratigraphic D . Stimulate U Other AJíthdmgêll Concentric WaiverD Time Extension D String Re-enter Suspended Well D 5. Permit to Drill Number: Marathon Oil Company Exploratory D 199-024 Service D 6. API Number: 50-133-20487 -00-00 ~ PO Box 1949, Kenai Alaska, 99611-1949 7. KB Elevation (ft): 8. Property Designation: 9. Well Name and Number: Kenai Beluaa Unit 33-6 - 21.6' ( 10. Field/Pool(s): Kenai Gas Field I Sterling Pool 6 . A - 028142 ( 11. Present Well Condition Summary: Tubing: (size, grade, and measured depth) Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 8,110' / feet 7,410' feet 5,188' Plugs (measured) Junk (measured) 5,251' / measured true vertical feet feet 5,460' 5,046' Length o 115' 1,568' 5,810' o o Size o TVD Burst Collapse 0 0 0 115' 3,060 psi 1,500 psi 1,540' 3,450 psi 1,950 psi 5,324' 5,750 psi 3,090 psi 0 0 0 0 0 0 20" 13-3/8" 9-5/8" o o MD o 115' 1,568' 5,810' o o Measured depth: 4,940' - 4,990' True Vertical depth: 4,502' - 4,549' 1-3/4" 2-3/8" 4-1/2" Model D Permanent Packer Sealbore Extension H070FF H070FF L·80 5,156" 5,166' 4,850' 5,230' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after work: Exploratory D 16. Well Status after work: oilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 13. Contact Printed Name Signature Oil-Bbl o o Tubing Pressure 75 75 Development 0 Service D GINJ D WINJ D WDSPL ISundry Number or N/A if C.O. Exempt: I 307- 212 o Kevin Skiba (907) 283-1371 , Dennis Dpnovan '''" \itA i'-::n . Title Production Engineer Phone (907) 283-1333 Date September 7, 2007 Form 10-404 Revised 04/2006 ORIGINAL RBDMS BFl SEP 2 4 Z0071K 1,\ #ri~;ø7 KBU 33...6 Pad 41-7 37' 4,068' FWL Sec. 7, T4N, R11W, S.M. (7/19/2007) -2-3/8" H070FF Grade, 0.134 WT wi BHA @ 5178' KB (10) QTI#34209 STR#25913 Mill Oate 11-3-2006 -1-3/4" BHA bottom @ 5,156' KB CTM (10' above 2-3/8" CT bottom) Model 0 Permanent Packer Sealbore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' þo 95/8" Cast Iron Cement Retainer at 5460' MO, Unable to establish injection at 3000psl. I TD:: 8,110' MD 20" K-55 133 ppf Top Bottom MD 0' 115' TVD 0' 115' Surface Casina 13-3/8" L-80 58 ppf BTC Top Bottom MD 0' 1,568' TVD 0' 1,540' Cmt w/500 sacks of Class G 4-1/2" L-80 X Nipple @ 4,801' RKB WEG @ 4,850' RKB 9-5/8" L-BO 40 BTC Bottom MD O' 5,810' TVD 0' 5,324' Cmt wI 570 sacks of Class G Concentric BHA Description 2-3/8": (Assy Bottoms Up, Tested to 15,000#) - Centralizer (3.50" 00 X 2.375" 10 X 12.00"l.ong) - NoGo/Xover (2.50" OD X 1.135" 10 X 8.75" Long) - Standing Valve (1-3/4" in X Nipple) - Straight Bar (2.50" OD X 2.375" ID X 10 Ft Long) - Grapple CT Connector (3.00" 00 X 2.375" ID X 10.00" Long) 1.75": (Assy Bottoms Up, Tested to 16,000#) - Coil connector (2" OD X 4.25" Long) - Barrel (1.90" 00 X 1.25" 10 X 33.25" Long) - Coil connector welded on to bottom of 1-3/4" coil tubing with BHA barrel screwed on bottom of connector. Well Name & Number: KBU 33-6 Lease: Kenai Gas Field County or Parish: Kenai Peninsula Borough State: Alaska I Country: ¡ USA Angle/Perfs: KOP TVD: Angle @ KOP and Depth: I Completion Fluid: Date Completed: 02/24/03 I Ground Level: 66' I RKB: 21.6' Prepared By: Kevin Skiba Last Revision Date: I 09106/07 . . Marathon Oil Company Page 1 of 6 Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 7/9/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 1 0/17/2006 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase Descriptio~of Operations Code 7/9/2007 07:30 - 08:30 1.00 SAFETY MTG_ CTBG Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA) on stabbing large coil tubing. 08:30 - 18:00 9.50 RURD - COIL CTBG RD equipment from KU 43-6A and move to this location. spot coil unit and equipment around well head. Nipple up BOPs on top of wellhead. Stab in 2.375" coil tubing in injector head. LD liner to set tanks. 7/10/2007 08:00 - 09:30 1.50 SAFETY MTG_ CTBG Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA) on stabbing large coil tubing. 09:30 - 11 :00 1.50 RURD - COIL CTBG Finish rigging up coil unit and equipment around well head. 11 :00 - 12:30 1.50 TEST_ BOPE CTBG Function test BOPs. Pressure test BOPs. High 3780psig. Low 350 psig. Pressure low pressure on slips = 560 with no bleed off. High pressure = 4160 psig. Good test. 12:30 - 15:00 2.50 WAlTON EQIP CTBG Shut down coil operations and wait on personnel to finish berming the liner. 15:00 - 17:30 2.50 TEST_ TBG_ CTBG Fill coil with KCI water and pressure test tbg and bull plugged BHA to 1060 psig. OK Took 24 bbls to load. No loss on test. Nipple up injector head to wellhead. Start N2 equipment cool down. Purged coil free of water with N2. Rigged back injector into cradle for night. Secured and cleaned location. 7/11/2007 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Obtain permit. Held Pre-Job safety meeting and job specific tasks (JSA) on stabbing large coil tubing. 08:00 - 11 :00 3.00 SAFETY DRIL CTBG Shut down coil operations after alarms Sounded. Move to Muster Area because of Gas release. Wait on situation to be resolved. Resume Work. 11 :00 - 15:00 4.00 NUND BOPE CTBG Start to open Well Master Valve and discovered Back Pressure Valve was still installed in hanger below Well flowing Tree. Call Vetco gray to remove back pressure valve. RD Coil Tubing Injector, Lubricator, and BOPE Stack. Vetco gray arrived rigged up lubricator and removed Back pressure valve from Well flowing tree hanger. RD Vetco gray. 15:00 - 16:30 1.50 NUND BOPE CTBG Rig up cross, BOP Equipment, and Steel Lines on Wellhead Flowing Christmas Tree. 16:30 - 17:00 0.50 TEST_ BOPE CTBG Function test BOPs. Pressure test BOPs. High 2000psig. Low 600 IWELL psig. Good test. 17:00 - 17:30 0.50 SECURE CTBG Secured Well and cleaned location. SDFN. 7/12/2007 07:00 - 08:00 1.00 SAFETY MTG - CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations. 08:00 - 10:00 2.00 RURD - COIL CTBG PU Coil Tubing Injector and lubricator and install. 10:00 - 11 :00 1.00 TEST_ EQIP CTBG Install Coil Tubing BHA Consisting of Pump out Plug (2.23" O.D. & 1-1/4" Long), Centralizer (3-1/2" O.D. x 2.375" I.D. x 12" Long, No Go/x-over (2/1/2" OD. x 1.135" I.D. x 8-3/4" Long), Straight Bar (2-1/2" O.D. x 2-3/8" 1.0. x 10' Long), Grapple Coil Connector (3" O.D. x 2-3/8" I.D. x 10" Long), and 2-3/8" Coil Tubing. Grapple Coil Connector Welded on 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 15,000#. 11 :00 - 11 :30 0.50 TEST_ TBG_ CTBG Pressure test Lubricator to 2000 psi and 600 psi. Held both low pressure and high pressure Test. 11 :30 - 13:00 1.50 RUNPUL COIL CTBG Well head open, RIH w/ BHA and 2-3/8" Coil Tubing Velocity String. Found Coil Tubing Counter to be off -300'. 13:00 - 14:30 1.50 RUNPUL COIL CTBG POOH w/ 2-3/8" Coil Tubing and BHA. Close All Flowing Well Christmas Tree Valves. 14:30 - 16:00 1.50 RUNPUL COIL CTBG Wait on Replacement Coil Tubing Counter parts to Repair Coil Tubing Counter. Parts Arrived but were wrong size and We could not repair Coil Tubing Counter. Printed: 9/5/2007 3:53:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - 7/12/2007 16:00 - 17:00 . . MarathonOH Company Operations Summary Réport KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING C Sub , ,.......... '" ode Code Phase 1.00 SECURE WELL CTBG 17:00 - 17:30 0.50 SECURE WELL CTBG 7/13/2007 07:00 - 08:00 1.00 SAFETY MTG - CTBG 08:00 - 09:00 1.00 RURD - COIL CTBG 09:00 - 10:00 1.00 TEST_ EQIP CTBG 10:00 - 10:30 10:30 - 12:00 12:00 - 16:30 16:30 - 17:30 7/14/2007 17:30 - 18:00 07:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 19:00 0.50 TEST _ TBG_ CTBG 1.50 RUNPUl COIL CTBG 4.50 RUNPUl COIL CTBG 1.00 SECURE WELL CTBG 0.50 SECURE WELL CTBG 1.00 SAFETY MTG_ CTBG 3.00 RUNPUL COIL CTBG 1.00 RURD_ COIL CTBG 1.00 TEST_ TBG_ CTBG 6.00 RUNPUL COIL CTBG 2of6 Start: Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: 7/9/2007 10/17/2006 1 Description of Operations RD Coil Tubing Injector and Lubricator. Remove Coil Tubing BHA from 2-3/8" Coil Tubing. Stand Back Lubricator and Set Down Coil Tubing Injector. 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 Coil Tubing Injector and lubricator and install. Install Coil Tubing BHA Consisting of Pump out Plug (2.23" 0.0. & 1-1/4" Long), Centralizer (3-1/2" O.D. x 2.375" I.D. x 12" Long, NoGo/x-over (2/1/2" OD. x 1.135" I.D. x 8-3/4" Long), Straight Bar (2-1/2" O.D. x 2-3/8" I.D. x 10' Long), Grapple Coil Connector (3" O.D. x 2-3/8" I.D. x 10" Long), and 2-3/8" Coil Tubing. Grapple Coil Connector Welded on 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 15,000#. Pressure test Lubricator to 2000 psi and 600 psi. Held both low pressure and high pressure Test. Well head open, RIH w/ BHA and 2-3/8" Coil Tubing Velocity String. Tag @ 5188' KB Coil Tubing Measurement on top of Junk in Hole (Model D Permanent Packer w/ Sealbore Extension, 10' sub, 3.812 x Nipple, 10' sub, and Wireline Re-entry Guide @ 5230'). Pick up Coil 1 0' Putting Bottom of Coil BHA @ 5178' KB Coil Tubing Measurement. Held Safety Meeting JSA for Cutting 2-3/8" Coil Tubing and Landing in Tubing Hanger. Shutin Pipe Rams on BOP. Bleed off Lubricator Pressure. Remove Lubricator from BOP Stack. Clamp and Cut off 2-3/8" Coil Tubing above BOP Stack. Prepair to land 2-3/8" Coil Tubing in Tubing Hanger. Found 2-3/8" Coil Tubing Flattened by Injector Chains on Coil Tubing Unit. Standby for Orders. Will get swedge for I.D. of 2-3/8" Coil Tubing Built at Machine Shop overnight to swedge out 2-3/8" Coil Tubing Tomorrow so Rubber 0 Rings on Tubing Hanger will properly seal. Make sure BOPE Pipe Rams are closed Tight so pipe ram slips will hold 2-3/8" Coil Tubing Hanging in Well. Install Night Cap on Tree. RD Coil Tubing Injector and Lubricator. Stand Back Lubricator and Set Down Coil Tubing Injector. 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. Swedge out 2-3/8" Coil Tubing Hanging in Well. Install Tubing Hanger Connection on Coil Tubing. Load Coil Tubing on Coil Tubing Unit with 6% KCL Water. Install GS Pulling Tool on Coil Tubing on Coil Tubing Unit. PU Coil Tubing Injector and lubricator and install on BOPE Stack. Latch GS Pulling tool on to Coil Tubing in Well. Pressure test Lubricator to 2000 psi and 600 psi. Held both low pressure and high pressure Test. Pull Test Connections to 25,000 # pull (11,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. RIH 13' to set Coil Tubing in Tubing Hanger. Stack out wt on Hanger. Latch Coil Tubing in Tubing Hanger. 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'. Test Seal on Tubing Hanger. Tubing Hanger would not seal. RIH and Latch GS Pulling tool on to Coil Tubing. Printed: 9/5/2007 3:53:04 PM . . Marathon Oil Company Page 3 '6 Operªtions Summary Report , ,. Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 7/9/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 10/17/2006 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From- To Hours Code Sub Phase Description of Operation$ Code 7/14/2007 13:00 - 19:00 6.00 RUNPUL COIL CTBG Release Tubing Hanger Rams. PUH w/ Coil Tubing. Close BOPE Pipe Rams and Set Slips. Bleed off Pressure. Remove Lubricator. Reinstall New 0 Rings on Tubing Hanger Seal Assembly. Latch GS Pulling Tool. Install Lubricator. Pull Test Connections to 25,000 # pull (11,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. RIH 13' to set Coil Tubing in Tubing Hanger. Stack out wt on Hanger. Latch Coil Tubing in Tubing Hanger. 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'. Test Seal on Tubing Hanger. Seal Held 5,000#. RD Vetcogray. 19:00 - 20:30 1.50 SECURE WELL CTBG Shut in All Valve on Flowing Christmas Tree. RD Coil Tubing Surface Iron. RD Coil Tubing Injector and Lubricator. Stand Back Lubricator and Set Down Coil Tubing Injector. Install Night Cap on Well. Secured well for night. Asked Number One Operator to Lock out/Tag out Bottom Master Valve on Tree so it could not be closed on Newly Installed 2-3/8" Coil Tubing. 20:30 - 21 :00 0.50 SECURE WELL CTBG SDFN. Signed out for the night. 7/15/2007 09:00 - 09:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 09:30 - 13:00 3.50 RURD - COIL CTBG RD BOPE Stack. Remove Gas Buster from Flow back Tank. RDMO Coil Tubing and Crane. 13:00 - 13:30 0.50 SECURE WELL CTBG Install Night cap on Tree. Secured well. Leave Well Shut in. 13:30 - 14:00 0.50 SECURE WELL CTBG Signed out for the night. 7/19/2007 08:00 - 09:00 1.00 SAFETY MTG_ SLICK Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 09:00 - 10:00 1.00 RURD - SLlK SLICK MIRU slick line equipment. PU lubricator. MU standard tool string w/ 1.90" OD swage, 3' of 1.5" OD weight bar, and knuckle. 10:00-11:10 1.17 RUNPUL SLlK SLICK PTest lubricator to 500 psi. Well dead with 100 psi. Test good. RIH Tight spot @ 5151' KB, drop thru to 5147' W/I (5168' KB). POOH. OOH. 11:10 -11:45 0.58 RURD - SLlK SLICK Add 1.84"OB fluted centralizer to end of weight bar. (! .90 " OD swage, 3' of 1.50" OD weicht bar and 1 84" on fh ItF!rlI'1"IIIar.PTest lubricator to 500 psi. Test good. 11 :45 - 12:30 0.75 RUNPUL SLlK SLICK RIH Still tight spot @5151'KB. Tap thru. Work sqage thru tight spot 6-8 times. Continue in hole to 5148' w/I (5169' KB.) POOH. 12:30 - 12:45 0.25 RURD_ SLlK SLICK OOH. PU 1.90" OD drift 2' Lonq, 3' of 1 75" on h::lr ~' long 1 ¡:;n" nrt weight bar, 1.84" OD fluted centr::l1i7F!r (p. 5' o\l"r::lll) PTest lubricator to 500 psi. Test good. 12:45 - 14:15 1.50 RUNPUL SLlK SLICK RIH to 5151' KB Set down- work tools- can not fall thru. Call office to discuss anticipated setting depth of the 1.75" V-string. Decide that this depth is sufficient. POOH. 14:15 - 14:30 0.25 RURD - SLlK SLICK Hold rig down JSA. 14:30 - 15:30 1.00 RURD - SLlK SLICK RD. CHeck location for spills. OK. Sign off Permit. Turn in Permit and sign out. 8/7/2007 - NotifyJim REgg AOGCC Friday afternoon about BOP test for Monday 6 August. He said Lou Gremaldi would call. Monday morning had not heard from Mr. Gremaldi so I called Jim Regg again. He said he had forgotten to call Lou. Lou called me 11 :30 , but left no phone number. I called Jim Regg. Lou called and gave me his phone # - ~ Lou asked that we call him Tuesday morning when the coil was ngged up. <\/,' Lou will also witness MIT on 31-7X. Would prefer to do in before Friday. He is on days off. 10:00 - 10:30 0.50 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety Printed: 9/5/2007 3:53:04 PM . . Page 40f 6 Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING From - To Hours Code î~dbe Phase 8/7/2007 10:00 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 18:30 18:30 - 19:00 08:00 - 09:00 0.50 SAFETY MTG_ 1.50 RURD_ COIL 2.00 RURD_ COIL 4.50 RURD_ COIL 0.50 1.00 SAFETY MTG_ CTBG CTBG CTBG CTBG CTBG MIRU 8/8/2007 09:00 - 10:30 1.50 RURD_ COIL MIRU 10:30 - 12:00 1.50 SAFETY MTG_ CTBG 12:00 - 15:00 3.00 RURD - COIL CTBG 15:00 - 17:00 2.00 RURD - COIL CTBG 8/9/2007 07:00 - 09:00 2.00 SAFETY MTG_ MIRU 09:00 - 13:00 4.00 RURD - COIL MIRU 13:00 - 15:30 2.50 RURD_ COIL CTBG 15:30 - 16:00 0.50 RURD_ COIL CTBG 16:00 - 17:00 1.00 RURD - COIL CTBG 8/10/2007 07:00 - 09:00 2.00 SAFETY MTG_ MIRU 09:00 - 11 :00 2.00 RURD_ COIL MIRU 11 :00 - 13:30 2.50 RURD - COIL CTBG 13:30 - 17:00 3.50 RURD - COIL CTBG 17:00 - 18:00 1.00 RURD COIL CTBG 8/18/2007 08:30 - 09:00 0.50 SAFETY MTG_ MIRU 09:00 - 12:00 12:00 - 13:30 3.00 REPAIR RIG_ MIRU 1.50 TEST _ BOPE CTBG 0.50 SECURE WELL CTBG 13:30 - 14:00 , Start: Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: 7/9/2007 10/17/2006 1 Description of Operations meeting. Unload reel spools from trailers. Layout liners and spot equipment. Rig up coil equipment. Set 7" SOP on well head. Suspend operations. Secure well for the night. Leave location. BJ Coil tech crew on location. Uptained work permit, discussed procedure with crew and held PJSM with all crew members. Continue rigging up coil to tree. Hydraulic hose blew apart underneath the operation cab. Caused hydraulic fluid to blow beyond secondary containment causing a spill. Cleaned up notified HES department. Coil shut down for a few hours. Notified Mr. Gremaldi with the AOGCC about witnessing the BOP test on the coil unit. Jim Reggs has waived the witness of the SOP test. Paper work will be e-mailed after completed. His phone # M.~ ~( (;. Welder on location, welded up the BHA connector on coil. vvela IIIi:lJe. , Hydraulic hose repaired continue with rig up. Finished RU on flow back iron to tank. Ready to do BOP test, wrong test bar for SOP's. Decide to lay down for night. Secured coil, SJ left lease. SJ Coil tech crew on location. Uptained work permit, discussed procedure with crew and held PJSM with all crew members. Continue rigging up coil to tree. Went to stump test the BOP's and found that the 7 1/16" BOP had been rebuilt with 2" slips. S rought parts out from shop, rebuilt BOP's to 1 3/4" slips. Continue with BOP test, 0 ring seal leaking under tubing rams. Had to repair prior to test. Repaired back to testing BOP's. Tested low pressure at 380 psi! high pressure to 3300 psi on tubing rams, tested same on blinds. Good test. Clean up around well. Secured coil, BJ left lease. SJ Coil tech crew on location. Uptained work permit, discussed procedure with crew and held PJSM with all crew members. Swapped out pumping unit with new pump. Pump seized up from running the pump with closed Hydraulic lines. PU lubricator extension and MU to well head. Displace coil with N2 to flow back tank prior to running in well with coil. Slobber hose underneath the injector leaking fluid, Could not pack off stripper. Set down injector to try and repair. Main problem is with the side door stripper packer door. Pack off would not seal. BJ Crew dismantling and take to shop to try and rebuild. Clean up around well. Secured coil, BJ left lease. BJ Coil tech crew on location. Uptained work permit, discussed procedure with crew and held PJSM with all crew members. Contated By phone and left message yesterday evening @ 8:00 pm (as soon as I found out CT unit parts were ready) Friday, August 17, 2007 to test BOPE today August 18, 2007 @ 12:00 noon with Jim Regg w/ AOGCC. Did not hear anything from Jim. Called back again but to Slope number. Got return call from Chuck Scheve with the AOGCC called back today Saturday 09:30 am August 18, 2007 and waived Witnessing BOP Test today @ 12 noon on the KBU 33-6. Repaired and installed Seal for coil tubing injector. Test BOP's. 250 psi/3500 psi. Both Blind Rams and Pipe Rams Test good. Perform Test on Accumulator. Tested Ok. Install night cap on BOP's. Safe out location and suspendd operations Printed: 9/5/2007 3:53:04 PM . . Marathon Oil Company page 5 of 6 OpCirations Summary Report .... Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 7/9/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 10/17/2006 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase pescriptioryof Oper~tions Code 8/18/2007 13:30 - 14:00 0.50 SECURE WELL CTBG for the night. 8/19/2007 07:00 - 08:00 1.00 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting for Installing and Testing Lubricator, and coil tubing operations. 08:00 - 11 :00 3.00 TEST_ EQIP CTBG PU Coil Tubing Injector. Install Coil Tubing BHA (Overall Length of BHA = 36") Barrel (1.90" O.D. x 1.25" I.D. x 33.25" Long), Weld on Coil Connector (2" 0.0. x 4.25" Long), and 2-3/8" Coil Tubing. Coil Connector Welded on to Bottom of 1-3/4" Coil Tubing with BHA Barrel screwed on bottom of Connector. Install Injector onto Lubricator and BOP Stack. 11 :00 - 13:00 2.00 TEST_ TBG - CTBG Load Coil Tubing w/ 25 bbls 6% KCL Water. Circulate to Flowback Tank. Shut in 2x2 Valve on Choke. Pressure test Lubricator to 1000 psi. Held pressure Test. Open Valves to Flowback tank. Blow Water out of Coil Tubing w/ Nitrogen. Let all pressures fall to Zero. Wait to make sure both barriers in 2-3/8" Coil Tubing BHA still Holding. Well Still Dead. 13:00 - 16:00 3.00 RUNPUL COIL CTBG Open Well Head. Worked to Stab 1-3/4" Coil Tubing BHA into 2-3/8" Coil Tubing Hanger. Had to Remove Lubricator and Bend Coil Tubing and Stab Coil Tubing By Hand because of lack of taper on both 1-3/4" BHA and Especially Lack of Taper Tubing Hanger for 1-3/4" Coil Tubing. 16:00 - 18:00 2.00 RUNPUL COIL CTBG RIH w/ BHA and 1-3/4" Coil Tubing Velocity String. Tag @ 5166' KB Coil Tubing Measurement on top of NoGo in 2-3/8" Coil Tubing BHA. Pick up Coil 10' Putting Bottom of Coil BHA @ 5156' KB Coil Tubing Measurement. 18:00 - 20:00 2.00 RUNPUL COIL CTBG Held Safety Meeting JSA for Cutting 1-3/4" Coil Tubing and Landing in Tubing Hanger. Measure and pick up Coil Tubing 12' to 5144' to get tubing cut above BOP. Shutin Pipe Rams on BOP. Bleed off Lubricator Pressure. Remove Lubricator from BOP Stack. Clamp and Cut off 1-3/4'''' Coil Tubing above BOP Stack. Prepairto land 1-3/4" Coil Tubing in Tubing Hanger. Install Tubing Hanger Connection on Coil Tubing. Install GS Pulling Tool on Coil Tubing on Coil Tubing Unit. 20:00 - 20:30 0.50 TEST_ TBG_ CTBG PU Injector and Latch GS Pulling tool on to Coil Tubing in Well. Lower RUNPUL and Flange up Lubricator. 20:30 - 21 :30 1.00 COIL CTBG Pull Test Connections to 16,000 # pull (8,000 # over Coil Tubing String Wt). Release BOPE Pipe Rams and Slips. RIH 12' to set Coil Tubing in Tubing Hanger. Stack out wt on Hanger. Latch Coil Tubing in Tubing Hanger. Landed Bottom of 1-3/4" BHA @ 5166' (10' above NoGo in 2-3/8" Coil Tubing BHA). Load Coil Tubing on Coil Tubing Unit with 6% KCL Water. Set Coil Tubing @ GS Pulling Tool in -2000# Tubing Wt. Pressure GS Pulling tool to 600 psi. Release GS Pulling Tool and Pull GS Pulling tool up hole 13'. Test Seal on Tubing Hanger. Seal Held 5,000#. RD Vetcogray. 21 :30 - 22:00 0.50 SECURE WELL CTBG Shut in All Valve on Flowing Christmas Tree. RD Coil Tubing Injector. Set Down Coil Tubing Injector. Install Night Cap on Well. Secured well SECURE for night. 22:00 - 22:30 0.50 WELL CTBG SDFN. Signed out for the night. 8/20/2007 08:00 - 09:00 1.00 SAFETY MTG_ CTBG Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. 09:00 - 12:30 3.50 JET_ N2 - CTBG Start Pumping Nitrogen to Pressure Coil and Pump out 2 pump out Barrier Plugs in 2-3/8" Coil Tubing. Nitrogen pump not working correctly. Shutdown operations. Repaired Nitrogen Pump. Continue to Pump out pump out Barrier Plugs with Nitrogen. Pumped pressure up to 1200 psi in coil tubing. Ruptured Both Pump out plugs, Pressure Printed: 9/5/2007 3:53:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/20/2007 8/25/2007 Date 09:00 - 12:30 12:30 - 15:00 15:00 - 15:30 15:30 - 16:00 14:00 - 14:30 14:30 - 14:50 14:50 - 15:05 15:05 - 15:15 15:15 - 15:30 15:30 - 15:35 15:35 - 15:40 15:40 - 15:45 15:45 - 16:05 16:05 - 16:10 16:10 - 16:25 16:25 - 17:00 - . . Marathon Oil Company Operations Summary Report 3.50 JET_ N2 - CTBG 2.50 RURD - COIL CTBG 0.50 SECURE WELL CTBG 0.50 SECURE WELL CTBG 0.50 SAFETY MTG_ SLICK 0.33 RURD - SLlK WRLN 0.25 TEST BOPE WRLN 0.17 RUNPUL SLlK WRLN 0.25 SECURE WELL CTBG 0.08 TEST_ BOPE WRLN 0.08 RURD - SLlK WRLN 0.08 TEST - BOPE WRLN 0.33 WRLN 0.08 WRLN 0.25 WRLN 0.58 WRLN WRLN Page 6 of 6 Start: 7/9/2007 Rig Release: 10/17/2006 Rig Number: 1 Spud Date: 4/28/2000 End: Group: KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING ·Fr~01- T 0 HoursCØd~ ~~Je Phase ;. of Operations . started to fall, shutdown pumping nitrogen. Pressure fell to 230 psi. Shutin Master Valve and Swab Valve on Well. Bled pressure off BOP, Lubricator, and Surface Piping. RD Lubricator and BOPE Stack. RD Surface Equipment. RDMO Coil Tubing and Crane. Install Night cap on Tree. Secured well. Leave Well Shut in. Signed out for the night. Arrive on location, sign in, obtain work permit and hold pre-job safety meeting. PU lubricator. PU 1" tool string w/ G spear and standing valve. PTest lubricator to 750 psi. Test good. RIH w/ 1" G spear and 1-1/4" standing valve. Have trouble droping into velocity string hanger. Tag out @ 8' wi md. POOH. OOH. PU 1.30" fluted centralizer and 1.18" swage. PTest lubricator to 750 psi. Test good. RIH. Swage thru 8'. POOH. PTest lubricator to 750 psi. Test good. RIH w/ 1" G spear and 1-1/4" standing valve to 5167' TD wi md. Tap down to set standing valve in X Nipple. POOH. OOH w/ G spear. RD. Secure well for the night. Printed: 9/5/2007 3:53:04 PM . ~v~væ LID~ ~~~~æ~ . AI4A.SIiA. ORAND GAS CONSBRVATlON COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mickey Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 SCANNED JUL 0 5 2007 Re: Kenai Gas Field, Sterling Pool 6, Kenai Beluga Unit 33-6 Sundry Number: 307 -212 Dear Mr. Mullin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisll day of June, 2007 Encl. 1<4C\ _Of)L( ,. . . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 (M) Marathon MARATHON Oil Company RECEIVED June 18, 2007 ,JUN 2 5 7007 Alaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Kenai Gas Field, Pad 41-7 Well: Kenai Beluga Unit 33-6 Dear Mr. Maunder: We propose to run a 2 3/8" by 1 %" concentric coil tubing string in KBU #33-6. 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) 283-1337. Sincerely, ~~~ ¡ðTu,u OT Senior 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 ! ..I- _ . - ~ ~J~"o1 STATE OF ALASKA a¿-.Â?;P;1 JUN 2 5 2007 Ãi.~ Oil AND GAS CONSERVATION COM ION Æt<--\'>6 . , APPLICATION FOR SUNDRY APPROVALS .Älaska Oil & Gas Cons. Commission 20 MC 25 280 Anchorage Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 .AJNo 0 9. Property Designation· _ ' - ¿7¡¿,?~ 10. KB Elevation (ft): 37' FNl, 4068' FWl Sec. 6, T4N, R11W, S.M. 21.6'" 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 8110' - 7410' 5460' 5046' Length Size MD TVD 115' 20" 115' 115' 1568' 13-3/8 " 1568' 1540' 5810' 9-5/8" 5810' 5324' Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Com panv 1. Type of Request: Suspend 0 Repair well 0 Pull Tubing 0 3. Address: PO Box 1949, Kenai Alaska, 99611 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 4940'-4990' Packers and SSSV Type: Perforation Depth TVD (ft): 4502'-4549' Tubing Size: 4-1/2" Model D Permanent Packer Seal bore Extension Packers and SSSV MD (ft): 5230' 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Perforate 0 Waiver 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 199-024 ~ Other 0 CCT String Exploratory 0 Service 0 6. API Number: 50-133-20487-00-00/ 8. Well Name and Number: Kenai Beluga Unit 33-6 / 11. Field/Pool(s): ~~ t"\~ "'~ \/ed Co ~S!.1y.A.<. ( Kenai Gas Field, Pad 41-7 / >B- Plugs (measured): 5251' Junk (measured): N/A Collapse Burst 3060 psi 3450 psi 5750 psi 1500 psi 1950 psi 3090 psi Tubing Grade: Tubing MD (ft): 4850' L-80 14. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commencing Operations: 17. Verbal Approval: Commission Representative 14-Jul-07 Date: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mickey Mullin Title Signature ~ A~~hone (" / (907) 283-1337 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ::~"~~..\ B~~~~? ~::::~~:,,~~ S"b"","~t Fo~ Roo"""" 4C)L\ ~I ;1 Approv"" by' WI / ~_'ONER Form 10-403 Revised 06/2006 0'" R r 3tN At Contact Kevin Skiba (907) 283-1371 Senior Production Engineer Date 18-Jun-07 Sundry Number: :30'7- ó2..1 ~ Location Clearance 0 APPROVED BY THE COMMISSION Date: t·18-~ ~9?i3/âJmit in Duplicate . . MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 33-6 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" OD 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 OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift ID of individual connections. · G and G Machine will build a 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" OD gauge ring with junk basket to tag top of fill/cement in the 9-5/8" production liner (Model D Permanent Packer @ 5230'). Last tag on fill was with Expro @ 5251' ELMD. Bail with Slickline if needed. 2. Concentric Coil Tubina Head. Is installed 3. Flowline modifications for concentric coil tubina strina. Is installed 4. MIRU MOC flow back eauipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. Installation of 2-3/8" CT 5. MIRU BJ coiled tubina unit with 5285' of 2-3/8" coiled tubing pulled from KU 14-32. 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. 7. Pressure test suñace 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 wI N2 to flowback tank and vent N2 pressure to flowback tank. 8. MU CT BHA. Nipple injector offWHA. PU 10' of 4-1/16" CQ lubricator. MU velocity string BHA to end of CT. . . Page 20£3 9. Nipple UP injector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would seNe 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 +/-5,200' 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 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. 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 6200' of 1.75" coiled tubing (Old KDU 4rd String). 17. MU CT 1.75" CT BHA. Nipple injector offWHA. PU 10' of 4-1/16" CQ lubricator. MU velocity string BHA to end of CT. 18. RIH with 1.75" coil tubina velocitv strina and BHA with well flowing to sales up Casing by 2-3/8" annulus (if desired). 19. Cut coil tubina. PUH to span WHA for final landing depth of +/- 5190' (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 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. 20. 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 GO#3 CT Velocity String Hangoff Procedure DMD per KDW - 6/19/2007 10:19:19 AM . . Page 3 of3 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. 21. 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. 22. RIH and land Vetco 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. 23. 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. 24. Purae KCL water from CT remaininQ on reel trailer with nitroaen. Allow N2 to vent to flowback tank. 25. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. 26. 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 CONTACTS Dennis Donovan: 907-283-1333 (w) 907-398-1362 (cell) David Martens: 713-296-3302 (w) 832-4 72-6249( cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emeraencv Dial 911 GO#3 CT Velocity String Hangoff Procedure DMD per KDW - 6/19/2007 10:19:19 AM API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37'FNL, 4068' FVVL See 6, T4N, R11VV, S.M. Perforations: Sterling Pool 6 Interval C1: 4940' - 4990' MD (4502' - 4549' TVD) Top of Cement at 5251 ELMD' Cement Squeezed Perforations Upper Beluga US 5350' 5370' MD (4899-4906 TVD) U6 5380' 5400' MD (4925-4940 TVD) 9-5/8",40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G KBU 33-6 Pad 41 2006 120",133#, K-55 Drive Pipe @ 115' I 13-3/8",68#, L-80 BTC Casing @ 1568' Cmt wI 600 sx of Class G 4-1/2" Production Tubing X Nipple @ 4801' RKB VVEG @ 4850' RKB Model D Permanent Packer Sealbore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' 95/8" Cast Iron Cement Retainer at 5460' MD, Unable to establish injection at 3000psí. TD=8110' Well Name & NumberBu Plug/Cplg KBU 33-6 I Lease I County or Parish: Kenai Pen Bourough State/Prov. ¡ AK Country: I USA Angle/Perfs Angle @KOP and Depth KOP TVD I BHP: BHT: Completion Fluid: I FWHP: FBHP: I FWHT: I I FBHT: I Other: I Date Completed: RKB: I Prepared By: MAM I Last Revision Date: 08/11/061 MAM API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec 6, T4N, R11W, S.M. Perforations: Sterling Pool 6 Interval C1: 4940' - 4990' MD (4502' - 4549' TVD) Top of Cement at 5251 ELMD' Cement Squeezed Perforations Upper Beluga U5 5350' 5370' MD (4899-4906 TVD) U6 5380' 5400' MD (4925-4940 TVD) 9-5/8", 40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G Well Name & NumberBu County or Parish: Angle/Perfs BHP: BHT: FWHP: FBHP: Date Completed: Prepared By: PROPOSED KBU 33-6 Pad 41 2006 120",133#, K-55 Drive Pipe@ 115'1 13-3/8",68#, L-80 BTC Casing @ 1568' Cmt wI 600 sx of Class G 4-1/2" Production Tubing X Nipple @ 4801' RKB WEG @ 4850' RKB Model 0 Permanent Packer Sealbore Extension, 10' sub. 3.812 X Nipple. 10' sub and Wireline Re-entry Guide @ 5230' 9 5/8" Cast Iron Cement Retainer at 5460' MD. Unable to establish injection at 3000psi. TD=8110' KBU 33-6 MAM State/Prav, USA P and Depth MAM Last Revision Date: . . Marathon Oil COOlpc:::n IY Page 1 of1 Operations Summary Rep·Qrt :i j Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: MAINTENANCE/REPAIR Start: 4/10/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From -To Hours Code Sub Phase Description of Operatiol"S Code 4/11/2007 13:00 - 14:00 1.00 RURD_ SLlK WRLN MIRU Pollard Slickline. Held PJSM to review JSA and Safe Work Permit conditions. 14:00 - 14:30 0.50 RURD - SLlK WRLN MU tool string and lubricator. 14:30 - 15:00 0.50 RUNPUL SLlK WRLN RIH to 5121' KB with 1.83" OD gauge ring. POOH without tagging fill. 15:00 - 17:30 2.50 RUNPUL SLlK WRLN RIH with tandem 1-11/16" Memory Pressure-Temperature gauges to mid-perf depth of 4965' KB. Took static benches at surface, midway to the perfs, and at the mid-perf interval. POOH with gauges. Checked data-Good. 17:30 - 19:00 1.50 RURD_ SLlK WRLN RDMO Pollard Wireline. Printed: 6/1912007 10:18:11 AM MarathonOil Company Ope~ªtions Summary Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING Co ··.··Sub . .q~ Code Phase Date From - 1 0/6/2006 07:00 - 07:40 . Page 1 of 6 Start: 10/5/2006 Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: of Operations> . 0.67 SAFETY MTG_ PLUGAB Objective of Recompletion: Kenai gas Pool 6 was converted to a gas storage pool in 2006. Pool 6 can store up to 10 bcf of excess gas at 45 MMCFD injection capacities during low gas market demand. However, the pool can only deliver about 43 MMCFD during peak gas demand due to low reservoir pressures, number and size of the existing production wells. Additional production wells are needed to capture potential gas sales opportunity during the peak seasons. 07:40 - 13:00 5.33 RURD - COIL PLUGAB 13:00 - 13:45 0.75 SAFETY MTG - PLUGAB 13:45 - 15:00 1.25 RURD_ SLlK PLUGAB 15:00 - 15:45 0.75 TEST_ PBU - PLUGAB 15:45 - 16:20 0.58 WAlTON EQIP PLUGAB 16:20 - 16:45 0.42 RUNPUL SLlK PLUGAB 16:45 - 16:50 0.08 RUNPUL SLlK PLUGAB 16:50 - 17:00 0.17 RUNPUL SLlK PLUGAB 17:00 - 17:15 0.25 RUNPUL SLlK PLUGAB 17:15 - 17:30 0.25 BLOWD TBG - PLUGAB 17:30 - 18:00 0.50 RURD - SLlK PLUGAB 18:00 - 18:30 0.50 RURD - SLlK PLUGAB 10/7/2006 08:00 - 10:00 2.00 SAFETY MTG - PLUGAB 10:00 - 11 :50 1.83 RURD_ COIL PLUGAB 11 :50 - 13:45 1.92 WORK COIL PLUGAB 13:45 -19:10 5.42 WORK COIL PLUGAB 19:10 - 20:30 1.33 RURD COIL PLUGAB 20:30 - 21 :00 0.50 SAFETY MTG - PLUGAB 21 :00 - 21 :30 0.50 RURD_ SLlK PLUGAB 10/8/2006 08:00 - 10:00 2.00 SAFETY MTG - PLUGAB 10:00 - 12:00 2.00 RURD_ COIL PLUGAB 12:00 - 12:20 0.33 RUNPUL COIL PLUGAB The workover is planned to increase peak deliverability from Pool 6 by approximately 10 MMCFD. KBU 33-6 well is currently completed in Upper Beluga. The well is shut in and it is not able to flow through a velocity string due to high water and solids production problems. KBU 33-6 will be re-completed from a Beluga producer to a Pool 6 (C1 sand) producer. Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety MIRU BJ Services Coil Tubing Unit Held Safety Meeting with Expro Americas Slickline, Discussed Expro JSA, Safety checklist, slips trips falls, Crane RU, manbasket safety MIRU Expro Slickline Services, RU slickline equipment to set 1.188" KEP plug in velocity string Shut down to pressure test BJ Services Manifolds and well stack Alternator pulley came loose, repaired at office and replaced Start in hole w/ jars and KEP plug, 1775 psig on V-string. Set down and beat down plug in profile @ 5372' SLM Picked up to check over pull and sheared down and off plug, POOH OOH Bleed down well to 1250 psig to check integrity of plug (15 min) Plug held. RDMO equipment Leave location and sign out Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety MU 1 3/4" Coil with coil connector, dual checks, 3" hydraulic GS. Conduct shell test, low pressure = 400 psig, high= 2250 psig. Open well to RIH with coil to latch top of velocity string at 16.2'. WHP= 1300 psig. Tried to latch top of velocity string, PU hole, RIH set down over 15 times to try and latch. Tried pumping while setting above tag, unable to latch. POOH OOH with coil, bled down coil, lay down for night. MIRU sick line unit. Held PJSM and discussed procedure. Used WHP to test lubricator. PU lubricator, open up well RIH set down at 16'. work tool string by hand jaring. Set GS, sheared off POOH with wire. OOH RD unit. Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Remove night cap, stab injector unit, prepare for pressure test (400 psig low shell, 2250 psig high shell), bleed off pressure to 1300 psig, open wellhead. RIH to latch, tag coil hanger, PUH to 4.5 feet, no latch, POOH Printed: 6/19/2007 10:19:50AM . . MçU'athon Oil Com pany Operª'tions Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Event Name: RECOMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From- To Hours Code Sub Phase Code 10/8/2006 12:20 - 12:45 0.42 PUMP_ WTR_ PLUGAB 12:45 - 13:26 0.68 RUNPUL COIL PLUGAB 13:26 - 14:22 0.93 RUNPUL COIL PLUGAB 14:22 - 15:45 1.38 RUNPUL COIL PLUGAB 15:45-16:15 0.50 RUNPUL COIL PLUGAB 16:15 - 16:20 0.08 RUNPUL COIL PLUGAB 16:20 - 16:50 0.50 PUMP_ WTR_ PLUGAB 16:50 - 17:30 0.67 RUNPUL COIL PLUGAB 17:30 - 18:43 1.22 RUNPUL COIL PLUGAB 18:43 -19:10 0.45 RUNPUL COIL PLUGAB 19:10 - 20:10 1.00 RUNPUL COIL PLUGAB 20:10 - 21 :30 1.33 RURD - COIL PLUGAB 21 :30 - 21 :55 0.42 RURD - ELEC PLUGAB 21 :55 - 22:45 0.83 RUNPUL ELEC PLUGAB 22:45 - 23: 15 0.50 RUNPUL ELEC MIRU 23:15 - 23:30 0.25 RURD - ELEC MIRU 23:30 - 00:00 0.50 RURD - ELEC MIRU 10/9/2006 08:00 - 08:45 0.75 SAFETY MTG - PLUGAB 08:45 - 09:55 1.17 RURD_ COIL PLUGAB 09:55 - 10:30 0.58 PUMP_ N2 - PLUGAB 10:30 - 11 :50 1.33 RURD_ COIL PLUGAB 11:50 -12:20 0.50 SAFETY MTG - PLUGAB 12:20 - 13:10 0.83 RUNPUL COIL PLUGAB 13:10 - 13:28 0.30 PUMP_ WTR_ PLUGAB 13:28 - 13:40 0.20 TEST_ LOT_ PLUGAB 13:40 - 15:00 1.33 RUNPUL COIL PLUGAB 15:00 - 16:23 1.38 PUMP_ CMT_ PLUGAB 16:23 - 17:15 0.87 RUNPUL COIL PLUGAB 17:15 - 18:34 1.32 RUNPUL COIL PLUGAB 18:34 - 18:50 0.27 RUNPUL COIL PLUGAB Page Start: 10/5/2006 Rig Release: Rig Number: 1 Spud Date: 4/28/2000 End: Group: Description of Operations Pump off bait sub from 3" GS pulling tool stab onto well, shell test to 2000, bleed off WHP to 1300 psig. open wellhead and RIH, Attempt to latch 4 times, no latch, POOH. injector removed off wellhead, and retool stab injector to wellhead, tag bottom, attempt to latch 4 times, no latch, POOH. pump off GS to 1000 psig and retool Stab onto wellhead, PT to 2000 Ibs, open WH and RIH, latch up to CT hanger and pull 15,000 Ibs Slack off pull weight to allow for Vetco Gray to unlock CT hanger bolts. Begin pumping to 1500 psig on tubing, coil is free, backout the remaining pins and PUH Close slips/rams and bleed off BOP's, Pull up injector off wellhead while having CT docked in BOP's Cut velocity string and remove injector head, remove baiting tools. Connect CT work string to velocity string, place injector head on WHo equalize pressure above and below the rams, pull test to 12000 Ibs, open slip rams. POOH w/1. 75" CT Velocity string, and spool onto work reel. Pipe at surface, shutin well Bleed wellhead pressure, remove BHA, secure injector, BJ leave location (Expro Americas arrive onsite at 20:30 and hold PJSM and JSA with Marathon) Rig up 1-11/16" sinker bars w/2" CCL RIH w/1250 psig surface pressure Tagged bottom at 5386' ELM, Pulled log to 5080' ELM (Tubing tail at 5212' ELM) OOH, Rig down Leave location and turn in work permit Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Start Equip, Remove night cap, stab injector unit, begin cool down for N2 pumping unit, Prime N2 unit, ready to pump. Start pumping N2, 11000 scf of N2 away, Blowdown Wellhead Put injector on ground, unstab CT pipe from injector, place injector in cradle, stab work string into injector. hold safety meeting PU injector, begin making up tools, stab inj. onto wellhead Begin loading coil, coil loaded with water Shell Pressure test to 4000 psig, bled down to 1000 psig, open wellhead RIH, Up test@ 5230' CTM 11,500 Ibs, Mixing Cement, Tag @ 5361' soft bottom, PUH @ 13,000 Ibs, RIH to tag @ 5336' CTM, sat at 5432' CTM, PUH @ 13,000 Ibs, RIH to 5410' CTM, tag bottom @ 5447' CTM, PUH 10 feet to 5437' CTM and correct depth from 5435' to 5375' CTM. Begin pumping to load coil, start pumping cement, CT plugged off Pressure up to 5000 psig on CT, 0 psig WH pressure. 1.9 bbl of cement in CT, POOH fast 180-200 ftImin At surface, inject. off wellhead, remove nozzle, close blinds, clear blockage in CT (heavy clean sand pack) Stab injector to wellhead, pump reel volume with 2300 psig on CT, bleed pressure to 1200 psig, open well, RIH @ 5350' CTM, Do PU test 25 fpm s/o wt 10,500 Ibs, RIH to tag TDS, no pump, tagged @ 5446' CTM and set down 1000 Ibs. PU 10 feet, then Printed: 6/19/2007 10:19:50 AM . . Maratho.n Oil C0rr\pany OperationsSumma.r'YR.pørt Page 3 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING 10/9/2006 Phase 18:34 - 18:50 18:50 - 20:45 0.27 RUNPUL COIL PLUGAB 1.92 PUMP _ CMT_ PLUGAB 20:45 - 21:30 0.75 RURD - COIL PLUGAB 10/10/2006 09:00 - 10:00 1.00 SAFETY MTG - PLUGAB 10:00 - 10:30 0.50 RURD_ COIL PLUGAB 10:30 - 12:00 1.50 TEST_ LOT_ PLUGAB 12:00 - 12:25 0.42 RURD ELEC PLUGAB 12:25 - 13:15 0.83 RUNPUL ELEC PLUGAB 13:15 - 13:40 0.42 RUNPUL ELEC PLUGAB 13:40-14:15 0.58 SAFETY MTG - PLUGAB 14:15 -14:45 0.50 RURD_ ELEC PLUGAB 14:45 - 15:10 0.42 RUNPUL ELEC PLUGAB 15:10 - 15:25 0.25 RUNPUL ELEC PLUGAB 15:25 - 15:50 0.42 RUNPUL ELEC PLUGAB 15:50 - 16:30 0.67 PERF_ TBG - PLUGAB 16:30 - 16:40 0.17 RURD - ELEC PLUGAB 16:40 - 16:55 0.25 PUMP - WTR_ PLUGAB 16:55 - 17:15 0.33 PUMP - N2 - PLUGAB 17:15 - 17:30 0.25 PUMP _ N2 - PLUGAB 17:30 - 18:00 0.50 RURD - COIL PLUGAB 18:00 - 20:00 2.00 RURD_ COIL PLUGAB 20:00 - 22:50 2.83 RURD - OTHR PLUGAB 22:50 - 00:30 1.67 RURD_ OTHR PLUGAB 10/11/2006 06:00 - 06:00 24.00 RURD_ RIG - MIRU 10/12/2006 06:00 - 06:00 24.00 RURD_ RIG_ MIRU Start: 10/5/2006 Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: Description of correct depth to wireline 5375' WLM Start pumping cement, 1000 Pump Press and 30 WHP. Pump 15 bbl of cement Pressure to 2900 PP and 15 WHP. Pump 13 bbl of water. Cement is to nozzle (1000 PP and 26 WHP), proceed to lay in cement plug. Pump 17 Þbl H20 and park pipe (28bbl of H20 total vol of CT) for 15 min. POOH circulating bottoms up, OOH Secure injector to cradle and replace night cap, secure location and leave site Arrive on Location, Held Safety Meeting with BJ Services and Expro, Discussed JSA's, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Start Equip, Prime Pumps, Line out ground iron for Press Test, Open Wellhead (24 turns) Pressure Wellhead to 100 psig. Increase well pressure to 2500 psig., shut blinds, Pump is down and hold for 30 min per AOGCC P&A Test. (1200 hrs to 1600 hrs BJ Services on standby) Begin rigging up CCL and weightbars for depth check on Eline. Start in hole, 500 psig surface pressure Tagged to of cement at 5251' KB POOH (Depth Correlated with Logs) Min 100' Plug accepted by AOGCC, this was a viable abandonment of the perforations. OOH. Hold explosives safety meeting Pick up circulating gun 1-11/16" 6 holes RIH, get on depth, attempted to shoot gun, didn't fire. POOH to find problem. OOH, observed safety rules, cleared area shut down generator, Fixed Problem Replaced PX-1 friring sub and RIH Shot gun @ 5150'-5152' (6 holes), POOH (Expro RDMO 1630 to 1700) OOH, rig down. Expro left location, signed out (BJ Services brought Unit back online) Circulate well thru Circ holes, Pump 4 bbl to establish returns, shut down pump. Pump 30 bbls to the return tanks Stab injector to wellhead, Begin purging reel with N2 Shut down N2 pump, 15,000 scf of N2 pumped WH bled off, injector secure on trailer. RDMO CT Unit, Flow back Iron, Flowback tanks, Flowlines Wait for Well to U-tube and die out so the Back Pressure Valve can be set. Continue removing flowlines. Vac Truck standing by for Vetco and also taking U-tube fluids out of 2 bbl tote. Wells annular and tubular balanced, no flow from well. Vetco Set Back Pressure Valve. Remove Tree and Make smaller. RDMO vetco and light plants PJSM; RID Camp. Pump Water ( Vac Truck) Grade Pad, Set Liner & Matting Boards. Move And RlU Camp. Set Sub,Mud Boat, Pump/ Pit Units. Set Boiler House. Set Carrier. Run Electrical and Service Lines. Prep Mast To Raise. Rig 100 % Moved To 33-6 50% Rigged Up RlU Pump Room To Pits. Level And Secure Carrier. Run Electrical Lines To Carrier. RlU Out Riggers. Set Choke House. Fuel Tank. Set Trip Tank. Set Dog House. RlU Beaver Slide Cat Walk. Install Stairs To Rig Floor. Run Service Lines. Spot BOP Stack. Run Choke Lines. Note Wind 20-35kts Delayed Crane Work. Set Wind Walls Printed: 6/19/2007 10:19:50 AM . . Marathon Oil Company Page4of'$ ()per~tions Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 10/5/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Sub Phase DéSenptfó!'tof.Operations .< .·i... Code ... 10/12/2006 06:00 - 06:00 24.00 RURD_ RIG - MIRU Suspend Crane Work Due To Hi Winds. Set Back Wind Walls Rig Floor. Rig Accepted 0600hrs 10-12 06 10/13/2006 06:00 - 12:00 6.00 RURD_ RIG - MIRU PJSM; Complete Torque Tube RlU. RlU Top Drive 12:00 - 13:00 1.00 SAFETY MTG - MIRU 1 Hr. Safety Meeting Two Crews. 13:00 - 14:30 1.50 NUND TREE MIRU PJSM; N/D Tree. 14:30 - 20:30 6.00 NUND BOPE MIRU PJSM; N/U BOPE And All Related Components 20:30 - 04:30 8.00 TEST_ BOPE MIRU Remove Back Pressure Valve-Install Two Way Check Rig Up Test Equipment Body Test BOP 250 PSI/2000 PSI F-10 Min. Leak at grey lock on Choke Line-Install New Ring Check Valve Failed- Clean and Reinstall-Test Annular Kill CMV'S #10 #11 #12 250 PSI/2000 PSI 04:30 - 05:00 0.50 RURD - CSG - CMPPUL Rig Up Weatherford Tongs 05:00 - 05:30 0.50 RUNPUL TBG - CMPPUL Pull Hanger Up Wt. To Pull hanger Lose 80K Pull Seals out of seal Bore String Wt.75K-20 Bbls. to Fill Backside 05:30 - 06:00 0.50 CIRC_ CFLD CMPPUL Circulate Hole Volume 9 bbls. Min.-250 PSI.. No Gas On B/U. Monitor Well ( Static) 10/14/2006 06:00 - 15:30 9.50 RUNPUL TBG - CMPPUL PJSM. UD Landing Jt. And Tubing Hanger, POOH UD 4 1/2 Tubing And Injection Line. UD Seal Assy. Total Of 128 jts UD Pull 70k To Unseat Seal Assy F- Packer 15:30 - 02:00 10.50 RUNPUL TBG - CMPRUN PjsM; RlU Pipe Racks. Install Seal Rings Strap P/U & Drift 115jts 4 1/2 Tubing, XN Nipple, WLEG And Pups To 4848.19 XN At 4801.62W LEG Set At 4850.39 M/U Hanger Land Out W 65K On Well Head 02:00 - 02:30 0.50 TEST_ WLHD CMPRUN Install TWC. Test Hanger To 3000psi Test passed 02:30 - 06:00 3.50 NUND BOPE CMPRUN Nipple Down BOPE 10/15/2006 06:00 - 06:30 0.50 NUND BOPE CMPRUN PJSM N/D BOPE, 06:30 - 08:00 1.50 NUND TREE CMPRUN PJSM; N/U Tree, Test To 5000psi /10 Min. Test Pased. 08:00 - 09:00 1.00 TEST_ CSG - CMPRUN Test Csg. To 2000psi F- 30 Min/ Test Passed Pull TWC Install Back Pressure Valve. 09:00 - 18:00 9.00 RURD_ RIG - RDMO PJSM; RlU G/D-1 Prep For Move To West Side 41-7 Pad. Flush Out All Mud Lines Clean Pits Flush Out KCL Brine. RID Top Drive And Torque Tube. Scope Down Mast. RID Service Lines. RID Pit&Pumps. RID Wind Walls, Dog And Choke Houses. Remove Beaver Slide Catwalk. Break Down BOP Stack. RID Water Tank, Boiler House Generator. Move Carrier. RID Mud Boat. 10/16/2006 06:00 - 06:00 24.00 RURD - RIG - RDMO PJSM; Lay Mast Down, Move Out Cuttings Tank, Water Tank, Boiler And Generator House. Move Pit And Pump Units. Move Sub. Move Matting Boards And Liner To West Side Of 41-7 Pad. Set Sub&.Carrrier Mud Boat, Pit Pumps, Water Tank, Boiler. Generator. Run Electrical And Service Lines. Set Out Riggers. Raise Mast To Floor. Set Dog House. Stairs Wind Walls. 10/17/2006 06:00 - 12:00 6.00 RURD_ RIG - MIRU PJSM ; Set # 3 Pump, Complete RlU Service Lines Berm Rig Release Rig To Maintenance 1200hrs 10-16-06 11/9/2006 08:00 - 08:30 0.50 SAFETY MTG - CMPFLW Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety 08:30 - 15:00 6.50 RURD_ COIL CMPFLW Move well house. MIRU BJ Services Coil Tubing Unit. (Tanks and choke were rigged up yesterday, time included on this report). 15:00 - 15:30 0.50 RURD_ COIL CMPFLW Fill CT with SO/50. Printed: 6/19/2007 10:19:50 AM . . Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING Hours Code Sub Phase Code 11/9/2006 15:30 - 16:00 0.50 TEST_ BOPE CMPFLW 16:00 - 17:00 1.00 RURD_ COIL CMPFLW 08:00 - 08:30 0.50 SAFETY MTG - CMPFLW 08:30 - 10:20 1.83 RURD_ COIL CMPFLW 10:20 - 10:25 0.08 TEST_ BOPE CMPFLW 10:25 - 10:45 0.33 PUMP_ N2 CMPFLW 10:45 -11:15 0.50 RUNPUL COIL CMPFLW 11:15-13:15 2.00 PUMP_ N2 - CMPFLW 13:15 - 13:35 0.33 PUMP_ N2 - CMPFLW 13:35 - 14:45 1.17 PUMP_ N2 - CMPFLW 14:45 - 16:45 2.00 PUMP_ N2 - CMPFLW 16:45 - 18:45 2.00 PUMP_ N2 - CMPFLW 18:45 - 21 :30 2.75 PUMP_ N2 - CMPFLW 21 :30 - 23:30 2.00 PUMP_ N2 - CMPFLW 23:30 - 01 :10 1.67 PUMP_ N2_ CMPFLW 01:10 - 01:45 0.58 PUMP N2 - CMPFLW 01 :45 - 02:40 0.92 RUNPUL COIL CMPFLW 02:40 - 03:45 1.08 RURD_ COIL CMPFLW 16:00 - 16:30 0.50 SAFETY MTG - CMPFLW 16:30 - 20:00 3.50 RURD - COIL CMPFLW 08:15 - 09:30 1.25 RURD_ ELEC CMPPRF 09:30 - 10:30 1.00 RURD - ELEC CMPPRF 11/10/2006 11/11/2006 11/17/2006 10:30 - 10:45 0.25 SAFETY MTG - CMPPRF 10:45 - 12:05 1.33 RURD - ELEC CMPPRF 12:05 - 12:10 0.08 TEST_ BOPE CMPPRF 12:10 -12:35 0.42 TEST_ BOPE CMPPRF 12:35 - 13:38 1.05 RUNPUL ELEC CMPPRF 13:38 - 14:00 0.37 RUNPUL ELEC CMPPRF 14:00 - 14:20 0.33 RUNPUL ELEC CMPPRF 14:20 - 14:50 0.50 SAFETY MTG - CMPPRF 14:50 - 15:20 0.50 SAFETY MTG - CMPPRF 15:20 - 16:00 0.67 SECURE WELL CMPPRF 11/18/2006 07:30 - 08:00 0.50 RURD - ELEC CMPPRF 09:30 - 10:30 1.00 RURD - ELEC CMPPRF 08:45 - 09:15 0.50 SAFETY MTG - CMPPRF 09:15 - 09:35 0.33 RURD_ ELEC CMPPRF 50f6 Start: Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: 10/5/2006 t)escription of Operations Test lines, valves, blind rams, pipe rams, and shell 250 1 4500 psi. Secure equipment for night and leave location. Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, working in cold temperatures. Start equipment. Stab on to well. Test shell 250 /4500 psi. Purge 50/50 back to MeOH tank. RIH CT. Start N2 at 300' RIH to 5150' pumping n2 in reverse. Water returns. Increase N2 to 1000 SCF/min. 70 Bbls returned. N2 at 750 SCF/min. Pump pressure at 2250 psi. 150 Bbls returned. N2 at 700 SCF/min. Pump pressure at 2460 psi. 195 Bbls returned. N2 at 1000 SCF/min. Pump pressure at 2100 psi. 255 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2380 psi. 335 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2450 psi. 365 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2350 psi. SD N2. 375 Bbls returned. POH CT. N2 pressure = 2300 psi. POH CT. OOH. Rig back CT and secure well for night. Leave location Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, danger during rig down. Rig down coiled tubing. Leave location Arrive @ KGF, sign in, obtain work permit and go over job procedure. Spot Equipment and do job site inspection. Concurrent operations include BJ CT Unit on well 41-6 jetting it clean. Glacier Rig mobilized on pad close to CT Unit and E-line Unit. Big G electric wiring 33-6 well house next to well head. Hold PJSM with Expro JSA. Discussed Crane safety, slips, trips, falls. make sure to shut down the job due to if the gas buster starts blowing off from 41-6 Start rigging up equipment Start pressure testing to 1500 psig. O-ring leaked at low pressure on lubricator. Changed out o-ring and completed pressure test to 1500 psig. Open well and start in hole (135 psig) Start PL T up pass @ 5200' KB, fluid level is at 5142' KB End up pass @ 4700' KB OOH, Lay down PL T tools and prepare for explosive safety meeting. Glacier Rig, Big G, Expro, BJ and MOC personnel attended explosive safety meeting. The Decision was made to shut down the perforation due to BJ coil on 41-6. BJ was at a critical spot where the well was attempting to kick and radio's were needed. It was more safe to lay down. Lay down Lub, night cap well, leave location and turn in work permit and sign out. Arrive @ KGF, sign in, obtain work permit and go over job procedure. Start all equipment and gather BJ, rig crew, and electricians for safety meeting. Hold PJSM with Expro, BJ and Glacier crew. Discuss complete perforating safety checklist, Expro JSA, and complete BJ safety checklist. Arm 3-3/8" X 30' gun#1. 6 SPF 1 60 Deg phasing. Reduce THP to 105 psig to have 130 psi at perf interval. Printed: 6/1912007 10:19:50 AM . . ,., Page 6 of 6 Marathon Oil Company Operations Summarý Rêport KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING C d .$.µþ Ph o.·.~/.·ç()q~ . ·.ase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Spud Date: 4/28/2000 End: Group: Start: 10/5/2006 Rig Release: Rig Number: 11118/2006 09:35 - 10:18 10:18 - 10:45 10:45 - 11 :26 0.72 TEST BOPE CMPPRF 0.45 RUNPUL ELEC CMPPRF 0.68 PERF _ CSG_ CMPPRF Pressure test lubricator to 1500 psig. Open well and run in hole (105 psig) Tie in to CBL and pull into position. S phasing with 3-3/8" carrier gun. Log off and POH gun #1 LD spent gun. All shots fire . Confirm radio silence a arm Gun #2, 3-3/8" X 20' carrier. Pressure test lubrica r to 1500 psig. Tie in to CBL an ull into position. Shoot 4940' - 4960' at 6 SPF, 60 deg phasing with 18" carrier gun. LD spent . All shots fired. Rig do Expro and release them to move to CLU 7. Hav afety meeting, JSA and Tag water level with Echometer. Ive at KGF office and sign in and obtain permit Arrive on Pad 41-7 and Hold PJSM wI Expro JSA Spot Equip and Rig up Stab Lub and Pressure test to 500 psi Start in hole wI PL T string SITP=138 psig Tagged Fluid @ 4948' (perforations @ 4940'-4990') Pressuring up well to push water back into perfs. (PIP=142 psig, temp 102 F) Fluid Went down l' wait 15 min Start down hole from 4840' down after 15 min wait (PIP 164 psig, temp 100 F) Stopped bull heading well. (PIP= 164 psig, temp 97 F) Well stabilized to 149 psig and 98 deg. F, logging down to check fluid level Fluid level at 4950' same as before, pull up to 4870' to flow well. (SIBHP=148 psig, temp 101 F) Start Flowing Well Pull up to 4910, waitforfluid to come up (FBHP=141, temp 101 F) Checked fluid level, no change 4059', Flowing .4 MMCFD (FBHP=140 psig, temp 101 F) Open choke 100% (full open) Flowing at 2MM RIH wI fluid at 9446' RIH wI fluid at 9442' Pressure stabilized @ 98.5 psig. Saw indication of fluid @ 4905' Pure Fluid @ 4948' Flowing at 1.6MM POOH OOH, RD Leave location and si n out MIRU wire line unit. Held PJSM and discussed procedure for well work. Discussed safety issues around well. MU lubricator to well, PU tamden pressure gauges and go to well with gauges. PT lubricator to 500 psig. Good test. Open well, WHP= 20 psig. RIH with gauges at 100 fpm. Down to mid point perfs, stop for 10 minutes. POOH with gagues. OOH with gauges. Check data, RD unit. Pollard rig down and left lease. 0.40 RUNPUL ELEC 0.33 RURD_ ELEC 0.33 RURD_ ELEC 0.45 TEST _ BOPE 0.63 PERF _ CSG_ CMPPRF CMPPRF CMPPRF CMPPRF CMPPRF 11 :26 - 11 :50 11 :50 - 12:10 12:10 - 12:30 12:30 - 12:57 12:57 - 13:35 0.33 RUNPUL ELEC 2.08 RURD_ ELEC 1.00 TAG_ BOTM 0.50 RURD_ ELEC 0.25 RURD_ ELEC 1.17 RURD_ ELEC 0.25 TEST _ BOPE 1.08 RUNPUL ELEC 0.17 RUNPUL ELE 0.67 FLOW_ B K CMPPRF CMPPRF OTHER WRLN WRLN WRL W RLN WRLN WRLN 13:35 - 13:55 13:55 - 16:00 1/11/2007 14:30-15:30 1/19/2007 08:00 - 08:30 08:30 - 08:45 08:45 - 09:55 09:55 - 10:10 o 10:10-11:15 ~ 11 : 15 - 11 :25 ? :25 - 12:05 4\~ 12:05-12:20 ~ 12:20 - 12:40 WRLN WRLN WRLN WRLN WRLN 0.33 RUNPUL ELEC WRLN 0.67 RUNPUL ELEC WRLN 1.25 RUNPUL ELEC WRLN 0.25 RUNPUL ELEC WRLN 0.42 RUNPUL ELEC WRLN 0.67 RUNPUL ELEC WRLN 0.25 RUNPUL ELEC WRLN 15:40 - 15:55 15:55 - 16:20 16:20 - 17:00 17:00-17:15 0.42 RUNPUL ELEC 0.83 RURD_ ELEC 0.50 RURD ELEC 0.50 SAFETY MTG_ 17:15 - 17:40 17:40 - 18:30 18:30 - 1 :00 15:30 - 16:00 WRLN WRLN WRLN SLICK 2/7/2007 16:00 - 16:30 0.50 RURD_ SLlK SLICK 1.00 WORK SLlK SLICK 16:30 - 17:30 1.00 WORK SLlK RURD_ SLlK SLICK SLICK 17:30 - 18:30 18:30 - Printed: 6/19/2007 10:19:50 AM . . Alaska Region Domestic Production Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1371 Fax 907/283-1350 . ..' -......, ,. ~-... February 1, 2007 Tom Maunder AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 SCANNED FES 1 4 Z007 REC;E'VED (1 {j 2007 Reference: 10-407 Sundry Report Field: Kenai Beluga Unit Well: KBU #33-6 ", .. ~"'. '." . '..... :!Uaska (~ f' ... "ammlsSlOn Dear Mr. Maunder: Iqq-o~4 Attached and submitted for your records is the Form 10-407 completion sundry for the KBU #33-6 well. Under AOGCC sundry approval number 306-330, the Beluga perforations in this well were abandoned with cement and the well was completed in the Sterling Pool 6 interval. '. ~ ~ \"'''''''' <4",,'o~ c..c~,c,..~~,~ Ç'>o..t""\ o~ .-\~ O\-,,\'::)\~\~\\~,\..~~t \0 \\~~Q.J ~\"C~t:.\\ef' Initial sales from this well have been sporadic and unsustainable due to liquid loading of M?J1.1' produced water attributable to the current tubular configuration. The well is currently shut JIt~ in waiting on the installation of a concentric velocity string. As we discussed and agreed on the telephone on January 27,2007, the AOGCC will not require that Marathon submit a 10-403 sundry to install the velocity string but will require that a 10-404 be submitted after the installation, with details of the installation. Also attached for your records is the current well schematic, directional survey, and completion history. If you would like any other information, please contact Kevin Skiba at 283-1371 or kskiba@marathonoil.com. Sincerely, I~b.~ Ken D. Walsh Senior Production Engineer Enclosures: 10-407 Sundry Report Well Schematic Operations Summary cc: Houston Well File Kenai Well File Ken Walsh Kevin Skiba /C¡1-ò ~'f ~ r't::t;1=:'/VED . STATE OF ALASKA _ ,.,,?-/';~~ ALASKA Oil AND GAS CONSERVATION COMMIS~ () 5 2007 WELL COMPLETION OR RECOMPLETION REPORT ANÐ 1il9Gs [' "on~ f'~ 1a. Well Status: OilD GasE] Plugged D Abandoned U Suspended U WAGU 1 b. Well Class: Ai;;Þm1Jl.g 1/1 20AAC 25.105 20AAC25.110 ~ Development [] Expló~~r 0 GINO WINJD WDSPL 0 No. of Completions Other ;¿~D1 Service 0 Stratigraphic TpstD 2. Operator Name: 5. Date Comp., ~ /;:;~~r;1 ~ 1fi,þ1 Marathon Oil Company Aband.: ~ - - 3. Address: 6. Date Spudded: 13. API Number: PO Box 1949, Kenai Alaska, 99611-1949 4/28/2000 50-133-20487 I 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 37' FNL & 4,068' FWL, Sec. 7, T4N, R11W, S.M. 5/20/2000 KBU 33- 6 I Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 1,925' FSL & 3,410' FWL, Sec. 6, T4N, R11W, S.M. 87' KB above MSL l Kenai Gas Field { Total Depth: 9. Plug Back Depth(MD+TVD): Sterling Pool 6 2,243' FSL & 2,911' FWL, Sec. 6, T4N, R11W, S.M. 5,251' MD, 4,793' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: j Surface: x- 274976.7 y- 2361976.18 Zone- 4 8,110' MD, 7,564' TVD A - 028142 TPI: x- 2744440.281 y- 2363666.25 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 273838.16 y- 2364222.50 Zone- 4 NA 18. Directional Survey: Yes ~No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NA feet MSL NA 21. Logs Run: CMR, CNL, PEX, AlT, 051, GPIT, NGT, & RFT 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CEMENTING RECORD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE PULLED 20" 133 K-55 0' 155' 0' 115' Driven Driven NA 13-3/8" 68 L-80 0' 1,568' 0' 1,540' 17-1/2" 600 sacks NA 9-5/8" 40 L-80 0' 5,810' 0' 5,324' 12-1/4" 570 sacks NA 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4,940' - 4,990' MD, 3.375" 00, 6 SPF 4-1/2" 4,850' 5,230' 4,502' - 4,549' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5,251' - 5,460' 73 sacks, class "G" 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-Oil Ratio: Test Period -+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate -+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None. {~Rî1IVi:Q 8Ft 1 5 2007 mission Form 10-407 Revised 12/2003 o RIG I N~NrUED ON REVERSE k:).( \ ...., () NAME GEOLOGIC MARKERS MD 29. RMATION TESTS 28. TVD Include and briefly sum e test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sterling A8 Sterling B1 Sterling B3 Sterling B5 Sterling C1 Sterling C2 3867 4101 4265 4584 4894 5080 3558 3760 3903 4184 4465 4638 None. 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba Signature: .vJ~ Title: Senior Production Engineer Printed Name: Ken D. Walsh Phone: 907-283-1371 Date: 2/1/2007 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL See 6, T4N, R11W, S.M. Perforations: Sterling Pool 6 Interval C1: 4940' - 4990' MD (4502' - 4549' TVD) Top of Cement at CementSCllJeezed Perforations Upper Beluga U5 5350' 5370' MD (4899-4906 TVD) U6 5380' 5400' MD (4925-4940 TVD) 9-5/8", 40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G 33..6 Pad 41-7 2006 13-3/8",68#, Cmt wI 600 sx of 4-112" Production Tubing X Nipple @ 4801' RKB WEG @ 4850' RKB MQdel 0 PermanentPacker Sealbore Extension,>10'sub, 10' sub and Wireline Re-entry Guide@ 5230' 95/8" Castiron Cement Retainerat54ßQ'MO, Unable to establish injection at 30QOpsi. TO::;:8110' Well Name 8. NumberBu Plug/Cplg KBU 33-6 County or Parish: Kenai Pen Bourough State/Provo Angle/Perfs Angle @KOP and Depth BHP: BHT: FWHP: FBHP: Date Completed: Prepared By: MAM Last RevisionDate: . . , Marathon QilComþany Pa,ge 1 of 6 Operations Summary Report legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPlETION Start: 1 0/5/2006 End: Contractor Name: GLACIER DRilLING Rig Release: Group: Rig Name: GLACIER DRilLING Rig Number: 1 Date From - To HOUf$ Code Sub Phase Description of Operations Code 10/6/2006 07:00 - 07:40 0.67 SAFETY MTG_ PLUGAB Objective of Recompletion: Kenai gas Pool 6 was converted to a gas storage pool in 2006. Pool 6 ( can store up to 10 bcf of excess gas at 45 MMCFD injection capacities during low gas market demand. However, the pool can only deliver about 43 MMCFD during peak gas demand due to low reservoir pressures, number and size of the existing production wells. Additional production wells are needed to capture potential gas sales opportunity during the peak seasons. The workover is planned to increase peak deliverability from Pool 6 by ( approximately 10 MMCFD. KBU 33-6 well is currently completed in Upper Beluga. The well is shut in and it is not able to flow through a velocity string due to high water and solids production problems. KBU 33-6 will be re-completed from a Beluga producer to a Pool 6 (C1 sand) producer. Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety 07:40 - 13:00 5.33 RURD - COIL PLUGAB MIRU BJ Services Coil Tubing Unit 13:00 - 13:45 0.75 SAFETY MTG_ PLUGAB Held Safety Meeting with Expro Americas Slickline, Discussed Expro JSA, Safety checklist, slips trips falls, Crane RU, manbasket safety 13:45 - 15:00 1.25 RURD - SLlK PLUGAB MIRU Expro Slickline Services, RU slickline equipment to set 1.188" KEP plug in velocity string 15:00 - 15:45 0.75 TEST_ PBU - PLUGAB Shut down to pressure test BJ Services Manifolds and well stack 15:45 - 16:20 0.58 WAlTON EQIP PLUGAB Alternator pulley came loose, repaired at office and replaced 16:20 - 16:45 0.42 RUNPUL SLlK PLUGAB Start in hole wI jars and KEP plug, 1775 psig on V-string. 16:45 - 16:50 0.08 RUNPUL SLlK PLUGAB Set down and beat down plug in profile @ 5372' SLM 16:50 - 17:00 0.17 RUNPUL SLlK PLUGAB Picked up to check over pull and sheared down and off plug, POOH 17:00 - 17:15 0.25 RUNPUL SLlK PLUGAB OOH 17:15-17:30 0.25 BLOWD ITBG_ PLUGAB Bleed down well to 1250 psig to check integrity of plug (15 min) 17:30 - 18:00 0.50 RURD - SLlK PLUGAB Plug held. RDMO equipment 18:00 - 18:30 0.50 RURD - SLlK PLUGAB Leave location and sign out 10/7/2006 08:00 - 10:00 2.00 SAFETY MTG_ PLUGAB Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, man basket safety 10:00 - 11 :50 1.83 RURD - COIL PLUGAB MU 1 3/4" Coil with coil connector, dual checks, 3" hydraulic GS. Conduct shell test, low pressure = 400 psig, high= 2250 psig. 11 :50 - 13:45 1.92 WORK_ COIL PLUGAB Open well to RIH with coil to latch top of velocity string at 16.2'. WHP= 1300 psig. - 13:45 - 19:10 5.42 WORK_ COIL PLUGAB Tried to latch top of velocity string, PU hole, RIH set down over 15 times to try and latch. Tried pumping while setting above tag, unable to latch. POOH 19:10 - 20:30 1.33 RURD - COIL PLUGAB OOH with coil, bled down coil, lay down for night. 20:30 - 21 :00 0.50 SAFETY MTG - PLUGAB MIRU sick line unit. Held PJSM and discussed procedure. Used WHP to test lubricator. PU lubricator, open up well 21 :00 - 21 :30 0.50 RURD - SLlK PLUGAB RIH set down at 16'. work tool string by hand jaring. Set GS, sheared off POOH with wire. OOH RD unit. 10/8/2006 08:00 - 10:00 2.00 SAFETY MTG_ PLUGAB Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, man basket safety 10:00 - 12:00 2.00 RURD - COIL PLUGAB Remove night cap, stab injector unit, prepare for pressure test (400 psig low shell, 2250 psig high shell), bleed off pressure to 1300 psig, open Printed: 1/31/2007 7:50:56 AM . . Page 2 of 6 Marathon OilCompany Operations Summary Report Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Event Name: RECOMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From -To Hours Code Sub Phase Code 10/8/2006 10:00 - 12:00 2.00 RURD - COIL PLUGAB 12:00 - 12:20 0.33 RUNPU COIL PLUGAB 12:20 - 12:45 0.42 PUMP - WTR_ PLUGAB 12:45 - 13:26 0.68 RUNPU COIL PLUGAB 13:26 - 14:22 0.93 RUNPU PLUGAB 14:22 - 15:45 1.38 RUNPU PLUGAB 15:45 - 16:15 0.50 RUNPU PLUGAB 16:15 - 16:20 0.08 RUNPU PLUGAB 16:20 - 16:50 0.50 PUMP - PLUGAB 16:50 - 17:30 0.67 RUNPU PLUGAB 17:30 - 18:43 1.22 RUNPU PLUGAB 18:43 - 19:10 0.45 RUNPU PLUGAB 19:10 - 20:10 1.00 RUNPU PLUGAB 20:10 - 21:30 1.33 RURD - COIL PLUGAB 21:30 - 21:55 0.42 RURD - ELEC PLUGAB 21 :55 - 22:45 0.83 RUNPU ELEC PLUGAB 22:45 - 23:15 0.50 RUNPU ELEC MIRU 23:15 - 23:30 0.25 RURD - ELEC MIRU 23:30 - 00:00 0.50 RURD ELEC MIRU 10/9/2006 08:00 - 08:45 0.75 SAFETY MTG_ PLUGAB 08:45 - 09:55 1.17 RURD - COIL PLUGAB 09:55 - 10:30 0.58 PUMP_ N2 - PLUGAB 10:30 -11:50 1.33 RURD - COIL PLUGAB 11:50-12:20 0.50 SAFETY MTG_ PLUGAB 12:20 - 13:10 0.83 RUNPU COIL PLUGAB 13:10 - 13:28 0.30 PUMP - WTR_ PLUGAB 13:28 - 13:40 0.20 TEST_ LOT_ PLUGAB 13:40 - 15:00 1.33 RUNPU COIL PLUGAB 15:00 - 16:23 1.38 PUMP_ CMT_ PLUGAB 16:23-17:15 0.87 RUNPU COIL PLUGAB 17:15-18:34 1.32 RUNPU COIL PLUGAB Start: 10/5/2006 Rig Release: Rig Number: 1 Spud Date: 4/28/2000 End: Group: Description of Operations wellhead. RIH to latch, tag coil hanger, PUH to 4.5 feet, no latch, POOH Pump off bait sub from 3" GS pulling tool stab onto well, shell test to 2000, bleed off WHP to 1300 psig. open wellhead and RIH, Attempt to latch 4 times, no latch, POOH. injector removed off wellhead, and retool stab injector to wellhead, tag bottom, attempt to latch 4 times, no latch, POOH. pump off GS to 1000 psig and retool Stab onto wellhead, PT to 2000 Ibs, open WH and RIH, latch up to CT hanger and pull 15,000 Ibs Slack off pull weight to allow for Vetco Gray to unlock CT hanger bolts. Begin pumping to 1500 psig on tubing, coil is free, backout the remaining pins and PUH Close slips/rams and bleed off BOP's, Pull up injector off wellhead while having CT docked in BOP's Cut velocity string and remove injector head, remove baiting tools. Connect CT work string to velocity string, place injector head on WHo equalize pressure above and below the rams, pull test to 12000 Ibs, open slip rams. POOH wI 1.75" CT Velocity string, and spool onto work reel. Pipe at surface, shutin well Bleed wellhead pressure, remove BHA, securè injector, BJ leave location (Expro Americas arrive onsite at 20:30 and hold PJSM and JSA with Marathon) Rig up 1-11/16" sinker bars wI 2" CCL J RIH w/1250 psig surface pressure Tagged bottom at 5386' ELM, Pulled log to 5080' ELM (Tubing tail at 5212' ELM) OOH, Rig down Leave location and turn in work permit Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Start Equip, Remove night cap, stab injector unit, begin cool down for N2 pumping unit, Prime N2 unit, ready to pump. Start pumping N2, 11000 scf of N2 away, Blowdown Wellhead Put injector on ground, unstab CT pipe from injector, place injector in cradle, stab work string into injector. hold safety meeting PU injector, begin making up tools, stab inj. onto wellhead Begin loading coil, coil loaded with water Shell Pressure test to 4000 psig, bled down to 1000 psig, open wellhead RIH, Up test @ 5230' CTM 11,500 Ibs , Mixing Cement, Tag @ 5361' soft bottom, PUH @ 13,000 Ibs, RIH to tag @ 5336' CTM, sat at 5432' CTM, PUH @ 13,000 Ibs, RIH to 5410' CTM, tag bottom @ 5447' CTM, PUH 10 feet to 5437' CTM and correct depth from 5435' to 5375' CTM. ~ Begin pumping to load coil, start pumping cement, CT plugged off ~ ~ Pressure up to 5000 psig on CT, 0 psig WH pressure. 1.9 bbl of v Y cement in CT, POOH fast 180-200 ft/min At surface, inject. off wellhead, remove nozzle, close blinds, clear blockage in CT (heavy clean sand pack) Stab injector to wellhead, pump reel volume with 2300 psig on CT, Printed: 1/31/2007 7:50:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/9/2006 10/10/2006 10/11/2006 10/12/2006 . . Page Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING Sub From - To Hours Code Code Phase 17:15 - 18:34 18:34 - 18:50 18:50 - 20:45 20:45 - 21 :30 09:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 12:25 12:25 - 13:15 13:15 - 13:40 13:40 - 14:15 14:15 - 14:45 14:45 - 15:10 15:10 - 15:25 15:25 - 15:50 15:50 - 16:30 16:30 - 16:40 16:40 - 16:55 16:55 - 17:15 17:15 - 17:30 17:30 - 18:00 18:00 - 20:00 20:00 - 22:50 22:50 - 00:30 06:00 - 06:00 06:00 - 06:00 1.32 RUNPU COIL PLUGAB 0.27 RUNPU COIL PLUGAB 1.92 PUMP _ CMT _ PLUGAB 0.75 RURD_ COIL PLUGAB 1.00 SAFETY MTG_ PLUGAB 0.50 RURD_ COIL PLUGAB 1.50 TEST_LOT _ PLUGAB 0.42 0.83 0.42 ELEC PLUGAB PLUGAB PLUGAB 0.58 SAFETY MTG_ PLUGAB 0.50 RURD_ ELEC PLUGAB 0.42 RUNPU ELEC PLUGAB 0.25 RUNPU PLUGAB 0.42 RUNPU ELEC PLUGAB 0.67 PERF _ TBG_ PLUGAB 0.17 RURD_ ELEC PLUGAB 0.25 PUMP _ WTR_ PLUGAB 0.33 PUMP 0.25 PUMP_ 0.50 RURD_ 2.00 RURD_ 2.83 RURD_ N2_ N2_ COIL COIL OTHR PLUGAB PLUGAB PLUGAB PLUGAB PLUGAB 1.67 RURD_ OTHR PLUGAB 24.00 RURD_ RIG_ MIRU 24.00 RURD_ RIG_ MIRU Start: 10/5/2006 Rig Release: Rig Number: 1 Spud Date: 4/28/2000 End: Group: Description of Operations bleed pressure to 1200 psig, open well, RIH @ 5350' CTM, Do PU test 25 fpm s/o wt 10,500 Ibs, RIH to tag TDS, no pump, tagged @ 5446' CTM and set down 1000 Ibs. PU 10 feet, then correct depth to wireline 5375' WLM ~ Start pumping cement, 1000 Pump Press and 30 WHP. Pump 15 bbl of cement Pressure to 2900 PP and 15 WHP. Pump 13 bbl of water. Cement is to nozzle (1000 PP and 26 WHP), proceed to lay in cement plug. Pump 17 bbl H20 and park pipe (28bbl of H20 total vol of CT) for N 15 min. POOH circulating bottoms up, OOH 0 Secure injector to cradle and replace night cap, secure location and ~p~ leave site Arrive on Location, Held Safety Meeting with BJ Services and Expro, Discussed JSA's, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Start Equip, Prime Pumps, Line out ground iron for Press Test, Open Wellhead (24 turns) Pressure Wellhead to 100 psig. Increase well pressure to 2500 psig., shut blinds, Pump is down and hold for 30 min per AOGCC P&A Test. (1200 hrs to 1600 hrs BJ Services on standby) Begin rigging up CCL and weightbars for depth check on Eline. Start in hole, 500 psig surface pressure Tagged to of cement at 5251' KB POOH (Depth Correlated with Logs) ,(¡ " Min 100' Plug accepted by AOGCC, this was a viable abandonment ~~'} the perforations. ~~r OOH. Hold explosives safety meeting Pick up circulating gun 1-11/16" 6 holes RIH, get on depth, attempted to shoot gun, didn't fire. POOH to find problem. OOH, observed safety rules, cleared area shut down generator, Fixed Problem Replaced PX-1 friring sub and RIH Shot gun @ 5150'-5152' (6 holes), POOH (Expro RDMO 1630 to 1700) OOH, rig down. Expro left location, signed out (BJ Services brought Unit back online) Circulate well thru Circ holes, Pump 4 bbl to establish returns, shut down pump. Pump 30 bbls to the return tanks Stab injector to wellhead, Begin purging reel with N2 Shut down N2 pump, 15,000 scf of N2 pumped WH bled off, injector secure on trailer. RDMO CT Unit, Flow back Iron, Flowback tanks, Flowlines Wait for Well to U-tube and die out so the Back Pressure Valve can be set. Continue removing flowlines. Vac Truck standing by for Vetco and also taking U-tube fluids out of 2 bbl tote. Wells annular and tubular balanced, no flow from well. Vetco Set Back Pressure Valve. Remove Tree and Make smaller. RDMO vetco and light plants PJSM; RID Camp. Pump Water ( Vac Truck) Grade Pad, Set Liner & Matting Boards. Move And RlU Camp. Set Sub, Mud Boat, Pump/ Pit Units. Set Boiler House. Set Carrier. Run Electrical and Service Lines. Prep Mast To Raise. Rig 100 % Moved To 33-6 50% Rigged Up RlU Pump Room To Pits. Level And Secure Carrier. Run Electrical Lines To Carrier. RlU Out Riggers. Set Choke House. Fuel Tank. Printed: 1/31/2007 7:50:56 AM . . Marathon Oil Company Page 4 '.~.. Operations Summary Report .... Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Spud Date: 4/28/2000 Event Name: RECOMPLETION Start: 1 0/5/2006 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRilLING Rig Number: 1 Date From": To Hours Code Sub Phase Descripti<;>nofOperåtîons Code 10/12/2006 06:00 - 06:00 24.00 RURD - RIG_ MIRU Set Trip Tank. Set Dog House. RlU Beaver Slide Cat Walk. Install Stairs To Rig Floor. Run Service Lines. Spot BOP Stack. Run Choke Lines. Note Wind 20-35kts Delayed Crane Work. Set Wind Walls Suspend Crane Work Due To Hi Winds. Set Back Wind Walls Rig Floor. Rig Accepted 0600hrs 10-1206 10/13/2006 06:00 - 12:00 6.00 RURD - RIG_ MIRU PJSM; Complete Torque Tube RlU. RlU Top Drive 12:00 - 13:00 1.00 SAFETY MTG_ MIRU 1 Hr. Safety Meeting Two Crews. 13:00 - 14:30 1.50 NUND TREE MIRU PJSM; N/D Tree. 14:30 - 20:30 6.00 NUND BOPE MIRU PJSM; N/U BOPE And All Related Components 20:30 - 04:30 8.00 TEST_ BOPE MIRU Remove Back Pressure Valve-Install Two Way Check Rig Up Test Equipment Body Test BOP 250 PSI/2000 PSI F-10 Min. Leak at grey lock on Choke Line-Install New Ring Check Valve Failed- Clean and Reinstall-Test Annular Kill CMV'S #10 #11 #12 250 PSI/2000 PSI 04:30 - 05:00 0.50 RURD_ CSG_ CMPPUL Rig Up Weatherford Tongs 05:00 - 05:30 0.50 RUNPUL TBG_ CMPPUL Pull Hanger Up Wt. To Pull hanger Lose 80K Pull Seals out of seal Bore String Wt. 75K-20 Bbls. to Fill Backside 05:30 - 06:00 0.50 CIRC_ CFLD CMPPUL Circulate Hole Volume 9 bbls. Min.-250 PSI.. No Gas On B/U. Monitor Well ( Static) 10/14/2006 06:00 - 15:30 9.50 RUNPUL TBG - CMPPUL PJSM. UD Landing Jt. And Tubing Hanger, POOH UD 4 1/2 Tubing And Injection Line. UD Seal Assy. Total Of 128 jts UD Pull 70k To Unseat Seal Assy F- Packer 15:30 - 02:00 10.50 RUNPUL TBG_ CMPRUN PjsM; RlU Pipe Racks. Install Seal Rings Strap P/U & Drift 115jts 4 1/2 Tubing, XN Nipple, WLEG And Pups To 4848.19 XN At 4801.62W LEG Set At 4850.39 M/U Hanger Land Out W 65K On Well Head 02:00 - 02:30 0.50 TEST_ WLHD CMPRUN Install TWC. Test Hanger To 3000psi Test passed 02:30 - 06:00 3.50 NUND BOPE CMPRUN Nipple Down BOPE 10/15/2006 06:00 - 06:30 0.50 NUND BOPE CMPRUN PJSM N/D BOPE, 06:30 - 08:00 1.50 NUND TREE CMPRUN PJSM; N/U Tree, Test To 5000psi /10 Min. Test Pased. 08:00 - 09:00 1.00 TEST_ CSG_ CMPRUN Test Csg. To 2000psi F- 30 Min/ Test Passed Pull TWC Install Back Pressure Valve. 09:00 - 18:00 9.00 RURD - RIG_ RDMO PJSM; RlU G/D-1 Prep For Move To West Side 41-7 Pad. Flush Out All Mud Lines Clean Pits Flush Out KCL Brine. RID Top Drive And Torque Tube. Scope Down Mast. RID Service Lines. RID Pit&Pumps. RID Wind Walls, Dog And Choke Houses. Remove Beaver Slide Catwalk. Break Down BOP Stack. RID Water Tank, Boiler House Generator. Move Carrier. RID Mud Boat. 10/16/2006 06:00 - 06:00 24.00 RURD - RIG - RDMO PJSM; Lay Mast Down, Move Out Cuttings Tank, Water Tank, Boiler And Generator House. Move Pit And Pump Units. Move Sub. Move Matting Boards And Liner To West Side Of 41-7 Pad. Set Sub&.Carrrier Mud Boat, Pit Pumps, Water Tank, Boiler. Generator. Run Electrical And Service Lines. Set Out Riggers. Raise Mast To Floor. Set Dog House. Stairs Wind Walls. 10/17/2006 06:00 - 12:00 6.00 RURD - RIG - MIRU PJSM ; Set # 3 Pump, Complete RlU Service Lines Berm Rig Release Rig To Maintenance 1200hrs 10-16-06 11/9/2006 08:00 - 08:30 0.50 SAFETY MTG_ CMPFLW Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, Crane Safety while rigging up, manbasket safety Printed: 1/31/2007 7:50:56 AM . . Marathon Oil Company ºp~rations $.ummary Report Pagè5 of6 Legal Well Name: KENAI BELUGA UNIT 33-6 Common Well Name: KENAI BELUGA UNIT 33-6 Event Name: RECOMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From- To Hours Code Sub Phase Code 11/9/2006 08:30 - 15:60 6.50 RURD_ COIL CMPFLW 15:00 - 15:30 0.50 RURD_ COIL CMPFLW 15:30 - 16:00 0.50 TEST_ BOPE CMPFLW 16:00 - 17:00 1.00 RURD - COIL CMPFLW 11/10/2006 08:00 - 08:30 0.50 SAFETY MTG_ CMPFLW 08:30 - 10:20 1.83 RURD_ COIL CMPFLW 10:20 - 10:25 0.08 TEST_ BOPE CMPFLW 10:25 - 10:45 0.33 PUMP N2 CMPFLW 10:45-11:15 0.50 RUNPUL COIL CMPFLW 11:15-13:15 2.00 PUMP_ N2_ CMPFLW 13:15 - 13:35 0.33 PUMP - N2 - CMPFLW 13:35 - 14:45 1.17 PUMP_ N2_ CMPFLW 14:45 - 16:45 2.00 PUMP - N2 - CMPFLW 16:45 - 18:45 2.00 PUMP - N2 - CMPFLW 18:45 - 21:30 2.75 PUMP_ N2_ CMPFLW 21 :30 - 23:30 2.00 PUMP - N2 - CMPFLW 23:30 - 01:10 1.67 PUMP - N2 - CMPFLW 01 :10 - 01 :45 0.58 PUMP N2 CMPFLW 01 :45 - 02:40 0.92 RUNPUL COIL CMPFLW 02:40 - 03:45 1.08 RURD - COIL CMPFLW 11/11/2006 16:00 - 16:30 0.50 SAFETY MTG_ CMPFLW 16:30 - 20:00 3.50 RURD_ COIL CMPFLW 11/17/2006 08:15 - 09:30 1.25 RURD - ELEC CMPPRF 09:30 - 10:30 1.00 RURD - ELEC CMPPRF 10:30 - 10:45 0.25 SAFETY MTG_ CMPPRF 10:45 - 12:05 1.33 RURD - ELEC CMPPRF 12:05 - 12:10 0.08 TEST_ BOPE CMPPRF 12:10 - 12:35 0.42 TEST_ BOPE CMPPRF 12:35 - 13:38 1.05 RUNPUL ELEC CMPPRF 13:38 - 14:00 0.37 RUNPUL ELEC CMPPRF 14:00 - 14:20 0.33 RUNPUL ELEC CMPPRF 14:20 - 14:50 0.50 SAFETY MTG_ CMPPRF 14:50 - 15:20 0.50 SAFETY MTG - CMPPRF 15:20 - 16:00 0.67 SECURE WELL CMPPRF 11/18/2006 07:30 - 08:00 0.50 RURD - ELEC CMPPRF 09:30 - 10:30 1.00 RURD - ELEC CMPPRF 08:45 - 09:15 0.50 SAFETY MTG_ CMPPRF Start: 10/5/2006 Rig Release: Rig Number: 1 Spud Date: 4/28/2000 End: Group: Description of Operatiqns ..,« <.. Move well house. MIRU BJ Services Coil Tubing Unit. (Tanks and choke were rigged up yesterday, time included on this report). Fill CT with 50/50. Test lines, valves, blind rams, pipe rams, and shell 250/4500 psi. Secure equipment for night and leave location. Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, working in cold temperatures. Start equipment. Stab on to well. Test shell 250 / 4500 psi. Purge 50/50 back to MeOH tank. RIH CT. Start N2 at 300' RIH to 5150' pumping n2 in reverse. Water returns. Increase N2 to 1000 SCF/min. 70 Bbls returned. N2 at 750 SCF/min. Pump pressure at 2250 psi. 150 Bbls returned. N2 at 700 SCF/min. Pump pressure at 2460 psi. 195 Bbls returned. N2 at 1000 SCF/min. Pump pressure at 2100 psi. 255 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2380 psi. 335 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2450 psi. 365 Bbls returned. N2 at 800 SCF/min. Pump pressure at 2350 psi. SD N2. 375 Bbls returned. POH CT. N2 pressure = 2300 psi. POH CT. OOH. Rig back CT and secure well for night. Leave location Held Safety Meeting with BJ Services, Discussed BJ JSA, Safety checklist, Slips Trips Falls, danger during rig down. Rig down coiled tubing. Leave location Arrive @ KGF, sign in, obtain work permit and go over job procedure. Spot Equipment and do job site inspection. Concurrent operations include BJ CT Unit on well 41-6 jetting it clean. Glacier Rig mobilized on pad close to CT Unit and E-line Unit. Big G electric wiring 33-6 well house next to well head. Hold PJSM with Expro JSA, Discussed Crane safety, slips, trips, falls. make sure to shut down the job due to if the gas buster starts blowing off from 41-6 Start rigging up equipment Start pressure testing to 1500 psig. O-ring leaked at low pressure on lubricator. Changed out o-ring and completed pressure test to 1500 psig. Open well and start in hole (135 psig) Start PL T up pass @ 5200' KB, fluid level is at 5142' KB End up pass @ 4700' KB OOH, Lay down PL T tools and prepare for explosive safety meeting. Glacier Rig, Big G, Expro, BJ and MOC personnel attended explosive safety meeting. The Decision was made to shut down the perforation due to BJ coil on 41-6. BJ was at a critical spot where the well was attempting to kick and radio's were needed. It was more safe to lay down. Lay down Lub, night cap well, leave location and turn in work permit and sign out. Arrive @ KGF, sign in, obtain work permit and go over job procedure. Start all equipment and gather BJ, rig crew, and electricians for safety meeting. Hold PJSM with Expro, BJ and Glacier crew. Discuss complete , Printed: 1/31/2007 7:50:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 11/18/2006 1/11/2007 1/19/2007 08:45 - 09:15 09:15 - 09:35 09:35 - 10:18 10:18 - 10:45 10:45 - 11 :26 11 :26 - 11 :50 11:50-12:10 12:10 - 12:30 12:30 - 12:57 12:57 - 13:35 13:35 - 13:55 13:55 - 16:00 14:30 - 15:30 08:00 - 08:30 08:30 - 08:45 08:45 - 09:55 09:55 - 10:10 10:10 -11:15 11 : 15 - 11 :25 11 :25 - 12:05 12:05 - 12:20 12:20 - 12:40 12:40 - 13:05 13:05 - 13:12 13:12 - 13:25 13:25 - 13:45 13:45 - 14:25 14:25 - 15:40 15:40 - 15:55 15:55 - 16:20 16:20 - 17:00 17:00 - 17:15 17:15 - 17:40 17:40 - 18:30 18:30 - 19:00 . . 60f6 Marathon Oil Company Operations Summary Report KENAI BELUGA UNIT 33-6 KENAI BELUGA UNIT 33-6 RECOMPLETION GLACIER DRILLING GLACIER DRILLING C $µb Hours ode. 'C~de Phase 0.50 SAFETY MTG_ CMPPRF 0.33 RURD - ELEC CMPPRF 0.72 TEST BOPE CMPPRF 0.45 RUNPU ELEC CMPPRF 0.68 PERF - CSG - CMPPRF 0.40 RUNPU ELEC CMPPRF 0.33 RURD - ELEC CMPPRF 0.33 RURD - ELEC CMPPRF 0.45 TEST_ BOPE CMPPRF 0.63 PERF - CSG_ CMPPRF 0.33 RUNPU ELEC CMPPRF 2.08 RURD_ ELEC CMPPRF 1.00 TAG_ BOTM OTHER 0.50 RURD_ ELEC WRLN 0.25 RURD_ ELEC WRLN 1.17 RURD_ ELEC WRLN 0.25 TEST _ BOPE WRLN 1.08 RUNPU ELEC WRLN 0.17 RUNPU ELEC WRLN 0.67 FLOW_ BACK WRLN 0.25 RUNPU WRLN 0.33 RUNPU WRLN 0.42 RUNPU WRLN 0.12 RUNPU WRLN 0.22 RUNPU WRLN 0.33 RUNPU WRLN 0.67 RUNPU WRLN 1.25 RUNPU WRLN 0.25 RUNPU WRLN 0.42 RUNPU WRLN 0.67 RUNPU WRLN 0.25 RUNPU WRLN 0.42 RUNPU ELEC WRLN 0.83 RURD ELEC WRLN 0.50 RURD_ ELEC WRLN Start: Rig Release: Rig Number: Spud Date: 4/28/2000 End: Group: 10/5/2006 Description of Operations perforating safety checklist, Expro JSA, and complete BJ safety checklist. Arm 3-3/8" X 30' gun#1. 6 SPF / 60 Deg phasing. Reduce THP to 105 psig to have 130 psi at perf interval. Pressure test lubricator to 1500 psig. Open well and run in hole (105 psig) Tie in to CBL and pull into position. Shoot 4960' - 4990' at 6 SPF, 60 Æ deg phasing with 3-3/8" carrier gun. ~f' Log off and POH gun #1 LD spent gun. All shots fired. Confirm radio silence and arm Gun #2, 3-3/8" X 20' carrier. Pressure test lubricator to 1500 psig. Tie in to CBL and pull into position. Shoot 4940' - 4960' at 6 SPF, 60 ~ deg phasing with 3-3/8" carrier gun. ffY LD spent gun. All shots fired. Rig down Expro and release them to move to CLU 7. Have safety meeting, JSA and Tag water level with Echometer. Arrive at KGF office and sign in and obtain permit Arrive on Pad 41-7 and Hold PJSM w/ Expro JSA Spot Equip and Rig up Stab Lub and Pressure test to 500 psi Start in hole w/ PL T string SITP=138 psig Tagged Fluid @ 4948' (perforations @ 4940'-4990') Pressuring up well to push water back into perfs. (PIP=142 psig, temp 102 F) Fluid Went down l' wait 15 min Start down hole from 4840' down after 15 min wait (PIP 164 psig, temp 100 F) Stopped bull heading well. (PIP= 164 psig, temp 97 F) Well stabilized to 149 psig and 98 deg. F, logging down to check fluid level Fluid level at 4950' same as before, pull up to 4870' to flow well. (SIBHP=148 psig, temp 101 F) Start Flowing Well Pull up to 4910, wait for fluid to come up (FBHP=141, temp 101 F) Checked fluid level, no change 4059', Flowing .4 MMCFD (FBHP=140 psig, temp 101 F) Open choke 100% (full open) Flowing at 2MM RIH w/ fluid at 9446' RIH w/ fluid at 9442' Pressure stabilized @ 98.5 psig. Saw indication of fluid @ 4905' Pure Fluid @ 4948' Flowing at 1.6MM POOH OOH, RD Leave location and sign out Printed: 1/31/2007 7:50:56 AM ~ oun y..., "',......~.,."...ru n."., ""'11 w n........w n unngr...1ii . Job No. 0480-00008 Bldetfllak No. Page...L of..:.L Company MARATHON OIL COMPANY Rig Contractor & No, Glacier CrUllng -Rig #1 Field KENAI GAS FIELD Well Name" No. PAD At-7/KBU 88-8 su.wý Section Name BHI MWD BHI Rap, ~ ~~M~ øt1VD . f'1) Tatge' Coord, NIB SlotCoord,fII/S -17.35 GrId Correction 0.000 Dopthe Meeaured frorn: RKBf!I MBlD SS[j etDe$criptlon TergelCoord. EIW SlotOoord.EJW 4068,17 Magn.Decllnlllion 21.220 CalGtJledonMelhod MINIMUM CURVATURE ,et DlreotJon f]D _ Bulld\Walk\Dl per: 100018 JJOmO 1DmD Vert. Seo. AzIrn. 341.41 Magn. to Map eorr, 21.220 Map North Co: OTHER SURVEY DATA Survev survey J~lnal, '.~~~'~;"~; Ç9uree Vertical':' f,' tqta¡ Coordln8le BuIld Attte Walk Rate ~. Tool Dènth ·Än9r~.., ,Direction' " Len~ ,'''fVI) SectIon . ~(..) I p(-) E(+) /WH' ¡f!iDL Suld (+) , RIght (+) Comment Type -iFn-' ïiù" ,'tDlYI ,1 ,Fñ' . o:n ".\ ,'f'1);' ~:.. IPar lDOF'11 Drop (-) , Left (-) , . . :i.~át 0.00 0.00 ~. : 0.90 " O.qt)· 0.00 ~.OO ' ~, ,::i~, 0.00 ',. TIE IN pólNT " . )II ~,.....,M.WD. 166.00 O.60.\-226~7Ö16~.;'íét¡ :.tRS.qo ,~.29 ':~9.47 .0.46 "'0.82 o.ai., .."(. ~,~. '" .<." t .1,,' .,,"., ~ .' ',' "., ',~:,".m"."",_..~~ ,..,._. ." ..... \PR:oo' MWti 34ë.OO 0.76 ~ 223.40 198.00 ~7.99 -U8 .:2.01 ·1,8Ð 0.15 0.1& ' ' , \PI\OO MWD 527.00 1.18 286.90 179.00 -Øæ ~.8' .s.91 ' -4.31 0.2$ 0.22' \PR.oD MWD 5,85,00 1.85263.30 66.00 '584.94 '-1.96 -4.02 -6.7B 2.32 '-16; \PR-OO, MWD 615.00 2.20 : 2A56.fiO 30:.00 16'4.92 -1.38 -3.74 .a.SI 1.23 1.11 " \PR..oo~ -'"MWD, 648.00 2.50 ,:293.80 SMO: J!46.90 ;-o.~8 -3.31 ....001.32 0111 ~ ~:. \PR:OO'MWI)' 708.00 3.10 a06:.ao SD.ÐO 705.82 un ·1,84 -10.51 1.42 1,OQ \fA-DO MWO 766.00 4.10 320.80 69.OÓ 764,11 4.87 9:12, -'3.16 2~ 1.89 , . " ' ,p~,: ~:'MWD 7U6.oo '[, 4,70 ':,:'3.22iaO ,3Q.00 \ :1~.~2:7.04· , 2.51 -14.69' '2.01i . 2.00: ,.. ,."., " ..... ... , ,. ~ ".' " ". .' I ,. ", '.. '. ' .. . " .. ,¡ ¡", i·' ,p~! i'MwD¡ 8211.00:. 5.02' .i..!U7i,&O :30.00. -824.51 ".f". ,'" ..60 -16.04 1.6& 1.(11 i 18.33 . .. ,pß.(fO MwD 8158.00' 5.70 ; :883.00 ~;.OO'" èl3Ø.38" '1Í!.Í¡; , 7.36 -n,60 2.48 2.00," 15.29' > ! ,,' >.'," 'PR-OO MWD 890.00 7.16 33M'" 31.00 ee9,~1 18.DA 10.61 -19,05 4.94 4.71 13,36 I .-00 MWD 919.00 8,00 841.80 29,00 917.91 19,8B 14,(JØ -2DAO 3.46 2.90 14.34 1. .. lJÄ.oo MWD 950.00 8.64 344,00 81.00 948,&9 24.3' 18.35 ·21.73 2.15 1.74 8.71 ': , U'R-OO MWD 983,00 ø.eo 345.so 33.00 881.17 29.69 23,45 -23,09 4.22 4.12 &.76 \PR-OO MWD 1014.00 11,10 ' 846.80 81.00 1011.65 35.22 28,94 -24,43 3.89 8.87 2.. \PR-OO MYVD 1078.00 12.60 347Ji5 69,00 1089.40 47.22 40,70 -21.13 2.A1O 2m 1.81 'PR-QO MWO 1134,00 13.61 849.20 Gum 1128.'3 eo.86 54.16 -a,8& 1,76 1.66 2.10 M~OO MWD 1198.00 14,85 348.80 62.00 1169.01 76.64 6UD -32.74 l.ae 1.85 ..0.65 f¡AV-OO MWD 1256,00 16.78 347.60 60.00 1246,94 91.13 &4,06 -æ.9S us 2.88 -2.17 ffAV.œ MWD 1816.00 17.00 148.20 60,00 1304,6' 107,95 100,61 -39,5' 2.06 2.oa "'7 AAV-OO MWD 1371.00 18.90 .347.10 55.00 1366.83 124.79 117.18 -48.05 8.47 3.4B .0.91 AAY.ao MWO '449.00 19,80 348.80 78.00 1430.46 160.12 142.38 -48.2B 1.01 0.90 1.41 s ' UIY.~ ate Toot ~: _ Type , J\Y.oo MWD! ~ , :MWDi AV.oo --- AV.oo - AV..oo "MWQ - : MWD 1187,00 24.00' - MWD 1862.00 25.80 - AY.fJO MWD 192ð.Do 28.30 . - AY.oo; .tRlD: '.;00;' 27.80 . ! '. AY.oo MWD 2054.00 2B.70 AY.oo MWJ), 2118,00 ' 80.18 Ayœ t· MWD; 22!\8\ö'Q:· 2&,41 . " ,,; AY..œ- ; MWD~ 231i1Oo·. ~.'4 AY.oo MWO' 24eø:~" 29.68 AV.oo MWD 2608,00 29.. :.00 MWD 2599.00 2I,UO AY.oo MWD 269Ø.00 80.07 AY.oo MWD 2'1Ø0.00 80,_ AY-OO MWD I285B,oo 29,. AY-OO MWD 2925.00 29,40 AY-oO MWD 8D17.oo 29.80 -- AY.oo MWD 8148.00 1i!B.39 - AY.oo MWD 8D,80 - AV-OO MWD 29. - - AY-OO MWD 28,46 - - AY,OO MWD 29.65 a302.00 -...,--. _:t.DD - 3451,00 - a522.00 Æ!l - ,:'\. ," t', . 1514,00· , 20.82 naa.op :' ~1,OC) 1688¡00- t.22,eo 342.40 341,80 840.70 - 840.00 ---- 341.00 343AD ~42;80 84S~70' - ,842;50 &43.60 343.40 342.70 Hol,. Dlreolòn \ODI a,1J1r80 --..;.- .f~~ 34ã~ 345.00 342.60 34ioo 1341;10' , a41t70 844.30 - 843.30 842.80 - 342.10 00\1'.. f,.ength "t.f].... .. 65.00 - ·82.00 80:00 101.00 75.00 84.00 - , Ø(t.oo 82.00 1:14..00 /:lae);OO , .63.00 '128.00 - 84.00 96.00 87.00 64.00 9s.oo 89.00 ,12.00 128.00 168.00 - 11.00 64.00 65.00 ¡ ; , lVO : ..1E!L- 149fliD ~ 1677.isb -.-.-- 1661,78 1744.64 .e12.61 le70.o7 'S2ð.~ 198~M8 2039.20 215t~ 22Q6.9t 2318.47 2874. It - 24157.84 264t.B7 2587.20 2680.86 2740.36 2820~ 2ØS2.1S5 - 8D67,88 31<46,5& 8202.20 3268,71 814.114 662.13 710.28 742.88 790.81 824.31 86&.74 --!- æ3,Jm 1011.07 1056.70 1088.38 , 120,38 274'.61 3Dø.t6 ....---,- 3S4,2ß 884.27 893.81 ,425.oS ,I '*,e9~t 52ó;1Io ~ 688.. ¡ 1010,18 1040.œ 1010.19 320.18 : 34~~68 316,58 ~'87 ':4êá- ~ :~.D8 ~ 568.10 sa42 BII3.. 619.61 7'0,48 19a.Q3 ~ 224.64 263.oe - 293,39 756.62 789.00 882.39 893.07 966.96 " ~~2,~.22 ~ ·'42.86 ~ ·:-15~..82 --'--- -170,18 -1711.17 -192.91 - -aJ7.%1 -218.41 -229.79 -289.70 - ·253.41 -272.88 -298.63 ·311.28 -52, .91 ..æIt60 SURVEY DATA '., ,.:;,.<' V.d" i;:~' ¡! ., Totat Coordinate .' eluca. - ~;SeCÚon t. N(+) / S(-} E(+lI W{-) . , .. ,,', "Lr:!l- . IF!) " 172.61' " 184.24 "-62.8.2 -...::- ' ~r 234.72 .' -80.40 -88.38 -79.20 -38,06 .s8.83 -106,'3 -1I1S.07 0.88 0.71 0.81 0.&4 ~ 2.28 2.88 D.. - 1.o~ 0.61 0.15 DAS 2.78 0. 0.67 0.84 0.60 0.80 0.68 1.80 1.39 2.40 0.78 e.27 ; 1.46 2.81 ~ , -0"5' ¡ ~ .Q.62·"~ . .. .. ¡ --; 0.84'1 0.13 -0.27 0.. 0.33 -o.æ - -0,41 0.43 .o.ali! - 0.&8 .0,45 .o.Øi9 0.16 t¡ .. . , -' j~ .. '(: - . 0.00 - 2,60 -1.04 .0,72 .0,18 0.23 - .0.32 -1.82 -1,00 1.54 .0,18 ..0.78 -0.94 0:69 .:......;..;.,.; -ÜJ() 0,78 ..3.38 .0.78 -1.s6 3.11 , : '. " , , , " " , t. _rIA "ò' ~' . BUild RafØ.~ DL ". Si.tlld fT. .). "1 \DD , Drap ~ 1.66 ': 1.57 \oj '0,41:, - - 2:19 2.00 un Wâlk Rate Rf;nt(+) ;'Left(-} ,i':: "1". '/~: . .~ ',"¡~: .:., '\~' ·2.6' i/.', .,,: .' .. -2.37 ',49 12 Il~ - ~I:tOLE \.. CQmment , : ~ " ~ "( It 1VD .t DeeoripØon þt DIrectlan (F1) TD,get Coord. N/S Target Ooowd. EJW Bulld\Welk\OL per.1000(H 30m[} SUlVey 98otlo" Name BHI MWO - WEU. DATA Slot Coord, N/S Slot Coord. 'êJW 10mD Vorl Sec. Azfm. -17.86 .!!!.17 841.41 Grid eorrecllon Magn. DeoSlnatlorl Magn. to Map Coif. . 0,000 2~ 21.220 Depth. Me.suted From: RKB f!I MSLo SSD Celcutllllon MeUlod MINIMUM CURVATURE Map Nor\h to: OTHER I ~ Ø'&Q. <iõJ"'" y ... ...-,..".....-w......... OompQ rJlAAATHON Oil COMPANY Well Name SINo. pAD 41·7/KBU 33·8 . ....-.. ,..1.... . ........., ¥f wn,,",, , ... , Job No. Rig Ccntfactor lit No, GlacIer OriUlng . Rill *1 O4SD-OOOOS Slde'raok No. Page -L of-1- Fletd KENAI GAS FIELD ElHI Rep. 00 MWD 4422.00 2&,28 340,10 65.00 4041.34 Dlr .~ 'MWpi, ' 46S0:Q6iaØIf' , .,., 'à41:60' J21ÜJO ¡' 4ìß4Ji'5 . ,'.,:,~_,,' :':'. 4_.. . ~'... ,...H'·· ~ 1 ,., ",~..' _ ....:~' It,. .....,..¡. ... 00: ;~~¡ 46i8.Øb ',26.45 "'34a.90 ;... ~~2Eí.' : ,',I' r...-''';' .... .;;;..)...,-,. ..... .. ..., ..." .. " .~.! . 4~~FO oot "f,iMWD; ,4T41·,Ob·~2t$;.e' <), ·~2.to :' 'j3¡ÓOj. 4'~;~1: , ... <t.:,>. _ _...~ - - - œ't;I WO' 4834,00 23,90 843.80 Ba.OO <i41Ô;Q1 - - - MWO' 4æ7,OO 22,88 841.10 Ø3,00 44e5AS - - - 45t!2.SS MWD 6021.00 21.54 336.17 94,00 - - - .00 MWD SU 2.00 20,22 _.40 91.00 <4667.58 - - - ·DD MWD BZ86.oo liMe 827 .2Ø 128,00 4183,_ - - - .00 MWO 6858,00 18.85 821.70 123.00 4898.46 - - - .00 MWD 6453.00 18.50 820,20 95.00 4989.~ - - - - .00 MWD 8542.00 ~8.17 31MO 89.00 6078.. - - , .00 MWD 888&.00 17,82 314.80 123.00 6~9O.a5 - - - - :.00 MWD 6756.00 17.31 31UO 91.00 6277,8& - - - - :.00 MWD 5887.00 18.&2 314.60 11 1.00 5383.74 - - - - :.00 MWD 6988,00 16,55 3tO.&O 129.00 6507.28 - - - - - ~ MWD 6124,00 16,126 S08AO 128.00 5B3O.D1 . X) 3D DO 419D~ 428&.00 . ...,....- _: ". 4351;00: \ ,. Survey ,Inol. 1 Hole _ pepth ~&Ie: , ,:f?lrvctlon --'E!L. .'" .,,¡;::'.lDD! ' ~.oo . ; æ.åo' ~ ~'11:~~-; 29ja ~: ~~.4~ -- 3844.00 80.61 -- 4038.00 29.81 2~;~6 29,10 28.78 342,90 341.80 - 841.70 - 841.80 ~ '84.:.50 192.00 '. 64.~ -'-- 15,00 ~ :Ú:ø;óìJ " . 3704,32 3759"". '.. 3880.93 ';s:¡~ - 1376.62 18.4.05 - - , ..1408.41 1844.20 ,. '476.70 1409.0e "533.7.5 ! (:v t4s3:riAi 1564,77 1492,81 , 1624.E$O i ,.:. 1549.16 ",. '_._~., ' 1'- ,¡ .-'~ - .... ." 1682.41 '::':"'1603.97", .. -.. . .. :1709.~ ,::.16~~ 114$.015 1668.87 1786.18 1701.90 1820.47 1784.94 1852.66 1764.28 1.,52 1800.82 1932.19 1883.22 1960:rø 1858.so 19863.3.. 1 fS18.tJl., - - 202t-OS 1SD5.46 - - 20415.61 '924,87 - - 2014,90 1948.03 - - 2f07 AO 1973.12 - - 2138.23 I sse.. , -6152.24 2.18 ·1.16 - - -666,08 2.30 ·1.45 - - .ea7.01 1.68 .0.62 - - -610,48 1.53 .0.41 - -629,68 0,68 .0.47 ~.28 ,I·~l : -0,'6 ..f74,.5& oæ .; -0.81 - -693.77 0,47 -0.84 - -718.8D 0.49 -o.as - -744.16 0.94 ..0.28 - - - ·771.88 0,84 -0.23 _..~!'9,90 ,o!~;~ '~Ii~ -628.7' - -B89,77 0.76 ,- ::~:-:_":' þ:tli ....:.;11... ~.; :~1~. '1;;48' 1.64 ~, \ ~ -0.70' : - . . . ~. ,I, ,_.e~J -1.38 ·1.87 .; ~ -4.93 - -5,02 ·4023 ....47 -1,88 -S.I6 -2.11 1.10 LASTSURVEV IN 12 1/4 -1.17 FIRST SVY IN 81/2 HOLE - -3.10 - -o,se .~;DA7 4- ,~.47 t:- é',2.08 "- 1.16 -1.88 , ~, - ,< f\,,~i' ,~t I ¡ :? ":a~ ~~i;f1~ ~ ~: :1'~ :::"9 ~ : .' , I ! I , ! r~'TIé, . Vo· '!.f . i l -411.32 0.65 - - -421.41 0.88 .."·l~ '-442.74' . 0.47 . - " , .. _ '~~:66, :'0;35 - - -470.65 0.82 .0.13 0.63 .' .'-:......., - -0.47 I 0.14 :.o.àc:; : "":":;;0.34 t. '. - - .0.69 -0.92 TRIP FOR BfT. MOTOR - - ~~~ .. - I i:¡ . COUl8~ 'f': L'tngtl1. U ; (FI)"." c· , . I ".~~:. >: "Moo ; . - 129.00 - :.T, r: '''.,;'''' l' lV!}. . " F.1j."¡ '. .:~.~9·1~~, M2ijJ;l2 ': ~'". 3538.33 SURVEVDATA .., .. ;,.Y;;rtlóaI ,~~BP1 ~n .:...I!!.~~ ,::;·~2!:6,~1 1280.14 ToteI Coordln8l1l ..:., ....- N(+)/S(-) E(+)/W(-f;' ..., IFTJ:I.· ': - (F1) .::::." ,;!,¡. H29,81 _,~~~f , . .... :::":-...,.,;, )- ':,·.~~~,60 -381,68 1Í60.62 1222.28 .. - . . '1'."DL.' tper,odFl) ,~~~·t " "."',.'~ . '0.71'; ,.._~....'J¡¡;....;,,~ 0,930' Blind RaIe ~uUd (+) , I?(ÖP ,C:}:;" . ;'. O,2Q' ........~.~._. ". >,J :' ;. ,'.:ø.""It .::·,~;.i'''''~'' '. 0,9' -0..a5 Walk Rete Right (+) Left H : , " : i:':'.O~1Ð ..!.,.. !.T~.61 ' '- 0.88 .0.88 f!:~ ! :. ~~ ¡'.".. Ii} 'ÓÔr'n~erit ¡ r-;.;~. ..··f·'· ~.~;'.;r.fj~~ --- ;,:::1': , '1"1 !.:; I>. .l, ¡Oh. ~}J i , /' .. o t$O,lpllon reaUon tDD) WELL DATA Target Coord. NIB Slot CQOfd. NIB ·17.95 Target Coord. E/W 810t Coord. E/W <W68.17 Bulld\Welk\DL po,; 100ft1!t somD 10mD Vert. 8eo, Azlm, 341.41 Grid COI,ectlo" Megn, Decllnalion Magn. to Map Coif, o~ 21.220 21.220 , DeptheMeeflu,ed From: RKB~ MSLO ss[ Calculation Method ~INIMUM CURVATURE Mop NOftb tol OTtlEA ~ œ;Q F1) SURVEY CALCULATION AND FlEW WOHK5Ht:1:.1 Job No. 0450.00008 Compeny MARATHON OL ~PANV Rig Conlrector 6. No. 01_81 Drftlfng . AIg #. Well Name &.No. PAD 41-7/KBU aM Surve)' SeotIon Name BHI MWD Sldetreck No. psge 2- of -L Reid ~NAI BAS AELD BHI Rep, r. ! I . I J . 1'1 Ii , .' j ,;:j;..¡ ( 00 MWO 6638,00 '4.41 3UT.40 - - - - - 00 MWD 6164.00 14.18 3D~,.80 - - - DO MWD 6891.00 1.1.88 304.30 . .;,."., '''d'''"" ,_...' . 13;41':;¡¢ 'ãoâ.øo oò' ;"'MWD 701S.òo DO MWD 7142.00 13,10 ø.1JO pó; )~WQ 7?ß5'~ '~2,62' ¡.' 89t.~ . ~ ~ ... 1 ()(): :\ MwD '7385.00 '2.07::'· ~~30 otJ' ; 'MWD ttii1.oo 11'.10 ¡ ,,~ ,: 8IX!~8Q: .00 MWD 768S,00 '1.19 800.&0 - MWO 7817,00 10.44 30' .60 - MWD 7921.00 9.10 902.20 - - - .00 MWD 8D81.oo 9.66 308.40 - - - .00 MWO 8110.00 9.50 303.90 123.00 8S15,04 2349.02 - - ,.~:';;1·~;,~ 6734.96 "2370.14 ~ {.:~~iÖµ ,.,,'''',....'/'', , ,0052, ~e, ,,' 2389.62 r'JÌ2.ÖO ,6991.t4 241'1.75 - - i06.00 7095,œ 2427.71 - - 184.00 ms.76 2464.01 - - 104.00 7378,16 2468.0S - - 130,00 7506.81 2486.10 - - 69.00 7564,49 2492.85 - - . - 126,00 128,00 121.00 ,'.,., ., - ;:':128:00 - - 00 MWD - . . ..' ...'" ~-;- !"~ Hö"" ' 'CQurì. Dlreót!.OÞ:, ";'L8njhr i, .. ,:.. ',,'.. ,. ",,',)' 6253.00 16~79 " '.~.80" 1~,òØf " _"",.. ,. ""_.,.. ."-._,, ,( .J Ò380.00 16~'.'" ¡;:~. ~';:1:2.!~ 6510.00 14,90 007,90 1àó:bo ,15:110 ::1!t ,,51õ4,dø """'1" '. . \~iý~,~t 6001.84 8125.66 6241,~4 - 8870,98 ~ 6495.34 2225.87 2252.37 m7 ,98 2302.76 2328.81 2202.15 22aJ.55 22SO.14 WI'.m 2241.41 : '2168.97 , , ,'t"" . . ·2'77.JI 2191.99 ioeo.Tl -878.8' OM - 2009.88 -903,oe 0.39 2117.0B -9.28,m 0.39 ~ , 21s!1;Ó2: :'-9~,01 ':o';~f - - - 2149.60 -877.65 0.40 ." , 0,48 - 0,42 - 0.72 - 0.18 - - -1137.74 0..29 . : /', 'D Isorlptlon roøtåon .m.. Target Coord, N/S Target Coord EIW I3UiId\Wslk\DL per: 100tt~ sOmO ,amO .f!l. WELL DATA Stet Coord, NIB 8101 Coord. EIW Verl See, Azlm. SURVEVDATA ., ,.,-, " , - - Ok ........ Total Coordinate, '/", yO..,,,,,, " , ~e:o.ø0" N(t) (s(.) i E(+)IW(.): ~",,f_, . t, t' , ", , 2168.29 : ,. 20j~..1;i: ': ',', -1S9,~.¡ _. ....~~.'., ,...., .. 2t96~ 2039.91.'~6..~! " - _...~ 2060.94 -ð53:ió" ~ .tbL ¡piIllOÌIf1 .; " '1..40 ¡,¿:~~ 0.42 Build Rato Build (+) D'~p,H " .. "~;3ø -o.~ -0.42 -0.32 -0.28 -0.24 , -o.:Jò:~ --.-.. -0,30 - -0.89· - .0.46 , -0.28: -0.48 .0.41 -0,71 -0.04 -0.25 0.61 ~::.- .,.,... .-' 0.92 LAST SURVEY 0.86 PROJECTED TO BOTTOM OF 61/2 -0.39 - -1.19 - -1.28 :O.~1.' -1,14 ;:pM. : '·~.iis· 'OA2,', . - -0.28 - 0.48 ., 'I"'{f ....~ ~.' j " ; ; ''¡ " '! Walk R. RIght (+) I.efl(-) I '.0.62 , !;.ø.3 t t.'e. .02.1 \ , ". , ,., " 9ó~ment', ~ " J~" I ~~;l.':J¡ u~ , : ";\:',;:¡.;,.;;',;",:";'; -.:';~.: ~ .. "'., ,,,..: .. . ; .11:!! ~.'7 341,41 Grid Correotlon .Æ!! Dep\he Me88l1Ted From: RKB fg MBLD saD Meøn. Deollflldlon _ 2~ Caloutatlon Metf10d MINIMUM CURVATURE Magn. to Map Corr. 21.220 Mop North to: OlHEA . " - ~ rE'CiI SURVEY CALCULA Company MAAA11-fON OIL OOMPANV Well N8me" No, PAD 41-7/KBtJ sa.e I IUN ANU I-It:LU VVU"I\.~nCI: I JóbNo, Rl9 Col1trector " No. Glaoler· Drilling - RIg " Swvey Saotlen Name 8HI MYtID 0450œ003 Sidetrack No, Field ~GA.9 BHI Rep. Pege -L oI-L- FIELD f ~~ , . . · , t' c c: ... · i · ¡ : , . j~ £~! .....'.... . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Petroleum Engineer DATE: October 9,2006 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: Plug Verification Marathon KBU 33-6 P.T.D. #99-24 Mondav. October 9. 2006. I witnessed the verification by tag and pressure test of the Beluga perforations in Marathon Oil company's KBU 33-6 in the Kenai Gas Field. I arrived to find BJ services rigging up to pump on the well. The Tubing had less than 10 psi on it with the IA at 100 psi and the OA at 0 psi. The tubing was lined up to the pumps with 3/10 bbl pumped to attain 100 psi and less than 2 bbl's to pressure up to 2385 psi. The following times/pressures were observed; 0- 2385 psi +15- 2340 psi +30- 2310 psi +45- 2290 psi The pressures were stabilized at this point and the tubing pressure was bled to 1000 psi. Expro wireline was rigged up and a tag with E-line was made using a CCl for correlation. The top of cement was found at 5251' (RKB). The upper perforation was documented at 5350' (RKB). The plan was for 100' feet of cement, I allowed for 99' to be sufficient. Glacier one will be rigging up to pull tubing and recomplete an up-per Sterling formation. £E Winton Aubert (A.O.G.C.C.) Tim lawlor (BlM) NON-CONFIDENTIAL 2006-1009 _P&A_ KBU _ 33-6_plug-verify _Ig.doc lof2 33·6 Plug Verification 2006-1009 _P&A_KBU _ 33-6 _pi ug-verify _19.doc 20f2 Wire line and Pumping Equipment for Plug Verification; Isolation of Beluga Perforations . . FRANK H. MURKOWSKI, GOVERNOR AI..ASKA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Peter Lewis Completion Engineer Marathon Oil Company PO Box 196168 Anchorage, AK 99519-6168 (.} fA.. t> '}.. Lt \CJÇ\ Re: Kenai Field, Upper Tyonek Beluga Gas Pool, Kenai Beluga Unit 33-6 Sundry Number: 306-330 Dear Mr. Lewis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this.a day of September, 2006 Encl. . . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Marathon Oil Company September 25, 2006 RECE.\VE.D SE? 2 7 lGGb Comffi\$siol'l 01 &. Gas Gons. . . ~'aska \ ~nt"o{a\\e Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Application for Sundry Report 10-403 for permit 99-24 Field: Kenai Gas Field Well: Kenai Beluga Unit 33-6 Pad: 41-7 Dear Mr. Aubert, Enclosed please find an Application for Sundry Approvals form 10-403 for Kenai Beluga Unit Well #33-6 and associated attachments. Marathon is proposing a recompletion to the Sterling Pool 6 horizon. Request for approval is being made to abandon the existing Upper Beluga perforations, mobilize a rig to round-trip the production tubing, and recomplete the KBU #33-6 to the Sterling Pool 6. Should you require further information, I can be reached at 713-296-2200 or bye-mail at PALewis@MarathonOil.com. Sincerely, Enclosures: AOGCC Form 10-403 Well bore Diagram (Existing & proposed) Description Summary of proposal 9/25/2006 3:36:32 PM øß a/~· c{; 1ft 9'/2.7/cG /. ) STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM.ON APPLICATION FOR SUNDRY APPROVALS H.~Vt;:gl}oo(, SEP 2 7 2006 .. Alaska Oil & Gas Cons. Commission 20 AAC 25.280 . 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development 0 / Exploratory 0 99-24 ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196168, Anchorage, AK 99519-6168 50-133-20487 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: / Spacing Exception Required? Yes 0 No 0 Kenai Beluga Unit 33-6 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL - 028142 87' KB above MSL Kenai Gas Field, TyoneklBeluQa and SterlinQ Pool 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): 8110' 7410' TVD 5460' 5046' Casing Length Size MD / TVD Burst Collapse Structural Conductor 115 20" 115 115 NA Surface 1568 13 3/8" 1568 1540 3450 2270 Intermediate 5810 95/8" 5810 5324 5750 3090 Production Liner Perforation Depth MD (I Perforation Depth TVD (ft): Tubing Size: / Tubing Grade: Tubing MD (ft): 5350 - 5400' 4899 - 4940' 4.5" L-80 5229 Packers and SSSV Type: Packer: Model D Permanent Packers and SSSV MD (ft): / 5230 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 /ì Exploratory 0 Development 0 Service 0 15. Estimated Date for ~ct-06 16. Well Status after proposed worle / Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Peter A. Lewis P'oled ~ ~ A. Lew;, Title Completion Engineer Signature Ä1.;f 'l'~$'-tJ~ Phone 713-296-2200 Date 9/25/2006 '7/¡ (/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5DlJ ' 330 Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: , ,~ , RBDMS BFt SEP 2 9 2006 Subsequent Form Required: \~ 0. APPROVED BY 9- zf ,.¡;h T -) V. ~ ~MISSIONER Approved by: THE COMMISSION Date: ,l)fl t1'"'-tNA - Form 10-403 Revised 06/2006 r, ~, - Submit in Duplicate ~ . . KENAI BELUGA UNIT 33-6 (pad 41-7): OBJECTIVE 1. Isolate and abandon the existing Upper Beluga (U5 and U6) perforations with cement. 2. Recomplete the KBU 33-6 to the Sterling Pool 6 (Cl) interval. Surface Casing: SIZE weight Grade Conn Footage Setting ID Pb (@80%) Pc (@80%) #/ft depth 13 -3/8" 68.0 L-80 BTC 1568' 1568' 12.415" 4020 1800 Production Casing: SIZE Weight Grade Conn Footage Setting ID Pb (@80%) Pc (@80%) #/ft depth 9-5/8" 40.0 L-80 BTC 5810' 5810' 8.835" 4600 2475 Casing Head: Cameron, 13-3/8", 3M Tubing Head: valves) Vetco, 13-3/8", 3M XII", 5M (with (2) 2-1/16", 5M Production String: 4-1/2", 12.6 ppf, L-80, IBT (currently landed -1' above the BOT Model D packer at 5192') with 12' seal assembly. To be re-installed as part of the recompletion. Coiled Tubing Gas lift String: 1.75", 0.125" WT velocity string (at 5375' MD) Existing Perforations: Upper Beluga (to be abandoned) : U5 5350' - 5370' (4899' - 4906' TVD) U6 5380' - 5400' (4925' - 4940' TVD) Proposed Perforations: Sterling Pool 6 (C-l) : Cl 4905' - 5025' (4475' - 4586' TVD) Existing Annular Fluid: 6%- KCl brine (-8.8 ppg, Sg = -1.05) / GENERAL PROCEDURE 1. Contact Kenai Gas Field Office daily for work permit, discuss safety and environmental concerns. 2. RU 1-3/4" CTU. NU BOP stack on 4-1/8", 5K swab valve. RU flowback line and ~ fill CT with fluid. Pressure/function test BOPE with 250/2500 psi. 3. MU CTU BRA with spear assembly. RlH with BRA to Vetco mandrel hanger and latch into the top of the 1-3/4" velocity string. Reconnect coil to velocity string per separate procedure and POOH. Spool velocity string for inspection and possible re-use. 4. MU CTU BRA with cementing nozzle. RlH with BRA and tag PBTD (IOcat~t the 9-5/8" ClBP at 5460'). Abandon the Upper Beluga perforations with 16 bls of cement. Note: The 16 bbls (assumes there is no fill) will fill up the 9-5/8" production casing up to 5250' (100' above the current Beluga U5 and U6 perforations). 5. POOH with CT BRA. RDMO CTU and equipment. . (M) KENAI BELUGA UNIT 33.{i (pad 41-7): . 6. WOC. MIRU slickline unit. MU and RIH with wireline BHA to make a tag run ensuring that the TOC is at 5250'. RDMO slickline unit. Notes: · May need to make a depth correlation run to locate either the EaT on the tailpipe assembly or X-profile. · If the TOC does not cover the Upper Beluga perforations by 100', RU eline unit and dump-bail cement to required height. 7. Bleed off wellhead pressure and set BPV in the tubing hanger. 8. MIRU Glacier Drilling Rig #1. 9. Check for pressure below the BPV. Remove the BPV and install 2-way check. Note: May opt to set blanking plug in the BPV or run a 2-way check. ~ 10.ND 4-1/8", 5M production tree. ¡\ItA sP ./V , t(POO fYL . 11. NU 11", 5M BOP stack equipped with 4-1/2" pipe rams. Shell-test the BOP ~ stack to 75/2000 psi. Pressure-test the ram preventers, lines and manifold to 75/2000 psi. Test pipe rams on 4-1/2" tubing. Pull 2-way check. Notes: · May NU 13-3/8", 5M BOP stack with DSA back to 11", 5M tubing spool. · The estimated static bottomhole pressure for the Sterling Pool C-1 is -180 psi. The corresponding MASP (per Chevron Equation) is -100 psi. 12. Install 4-1/2" landing down pins. Unseat the packer at 5230'. CBU. joints into the tubing hanger. Back out hanger hold tubing hanger and pull the seals from the Model D Shell-test the casing to 2000 psi. 13. (if necessary) If the seals do not pull free, RU electric line unit equipped with tubing cutter. RIH with cutter BHA and cut the production tubing above the seal assembly. 14. RU handling tools and power tongs. POOH and LD the 4-1/2", 12.6 #/ft IBT production tubing. PU production BHA with 4-1/2" wireline re-entry guide and XN profile. TIH with production tubing. 15. (Optional) Run the depth) and install injection mandrel. line connection. production string to -1500' (chemical injection mandrel the control line (1/4" x 0.049") and the chemical Function-test the injection mandrel and test the control 16. Run the production string to -4850' MD. Obtain PU and SO weights. PU landing joint and install tubing hanger. Land production tubing placing the EOT at -4850' . Note: Plan to set the EaT -50' above the top perforation. The Sterling Pool C-1 interval is located from 4905'-5025' MD (4776' - 4896' TVD). Actual perforation have yet to be determined. 17. Set BPV and nipple down BOPE. 18.NU bonnet and 4-1/8", 5M production tree with dual master valves. 19. Pull BPV and install two-way check. Shell test tree to 2000 psi. Remove 2- way check. 20. RDMO Glacier Rig #1. 21. RU BJ CTU with N2. RU with 4-1/16", 10M BOPE stack and 1-3/4" CT. 22. Pressure-test CT BOPE stack tO~PSi. . (M) KENAI BELUGA UNIT 33-6 (pad 41-7): . 23. RIH with CT and displace the 9-5/8" casing string with N2 to create minimal underbalance. Note: May want re-install CT hanger spool on the tree assembly to allow for reverse circulation with N2. 24. RD BJ CTU. 25. RU E-line, crane, and 5M lubricator with grease injection. Check wellhead for stray current and voltage. Pressure-test the BOPE. MU perforation BRA. RIH with BRA and perforate the Sterling Pool C-1 interval. Anticipated interval is 4905'- 5025' (4475' - 4568' TVD). RD Eline unit. 26. Open KBU 33-6 to flowback tank to blow off N2. Roll the production stream to production unit when appropriate. PAL: KBU 33 6 AOGCC.doc Pete Lewis (09/25/06) 713.296.2200 - office 713.203.4115 - cell KBU 33-6 Pad 41 PROPOSED Proposed Perforations: Sterling Pool 6 Interval C1: 490S' - S025' MD (4475' - 4586' TVD) 20", 133#, K-55 Drive Pipe @ 115 APi: 50-133-20487 RT~GL: 21.6' RT-THF: 17.6' 37' FNl, 4068' FWl See 6. T4N, R11W, S.M. 13-3/8",68#, l-80 BTC Casing @1568' Cmt wI 600 sx of Class G 14-1/2" Production Tubing I Specific perforation depths to be determined. Proposed Top of Cement at 5250' Model D Permanent Packer Sealbore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' ExistinQ Perforations Upper Beluga U5 5350'-5370' MD (4899-4906 TVD) U6 5380'-5400' MD (4925-4940 TVD) 95/8" Cast Iron Cement Retainer at 5460'MD, Unable to establish injection at 3000psi. 9-5/8",40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G TD=8110' Well Name & NumberB County or Parish: Angle/Perfs BHP: FWHP: Date Completed: Prepared By: Kenai Pen Bourough Angle @KOP and Depth BHT: FBHP: FBHT: RKB: MAM Last Revision Date: 25/9/2006 LewisP " ~f API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37'FNL,4068'FVVL See 6, T4N, R11VV, S.M. Tree cxns: 3-1/2" 8rd Tubing Detail 4-1/2",12.6 ppf, L-80, IBT @ 5229' Upper Beluga U5 5350'-5370' MD, (4899-4906 TVD) US 5380'·5400' MD, (4925-4940 TVD) 9-5/8",40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G Well Name & NumberBul PluglCplg KBU County or Parish: Kenai Pen Angle/Perfs Angle @KQP and BHP: BHT: FWHP: FBHP: Date Completed: Prepared By: DMT KBU 33..6 Pad 41 Existing 18", 68#, L-80 BTC Casing @ 1568' t wI 600 sx of Class G Chemical injection Mandrel Model D Permanent Packer Sealbore Extension. 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' 1-3/4" 0.125VVT TD=8110' State/Provo Last Revision Date: Velocity String@5375' 9 5/8" Cast Iron Cement Retainer at 5460' MD. Unable to establish injection at 3000psi. USA KJ3' A!, ~ 1YQ\JS{8E!.JJGI\ GðS KJ3' A!JE..UGA._UNlT 10 æœ - Wlter R:ite (CD¡ (1\ItIbI/d ) 5 OJm Gas Prod 0.5 0.1 005 001 0.005 0001 06 2000 01 02 03 04 05 l::J€te ~,........... ~...., ¡;:--- ,.- Ifuïrf'.\ ¡["it'"" '~ II Lß\ II ¡ ~. ...... ! rïlU II I. L J U ~ [Tn! !¡'þ.- f^\ II U ,'U.\ Ii ,I).I,.! ;r-\\.IL ~,~ ~'-"; ,---, n fj 'A' I f' /.11\\ it \ I Ù U \~¡ Lrù FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 31, 2004 ¡ (11 ~()~Lf Denise Titus Operations Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 Re: Kenai KBU 33-6 Sundry: 304-333 Dear Ms. Titus: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. 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 ifit is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure ¿ ItA. ') Marathon MARATHON Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August27,2004 RECEIVED AUG 3 02004 Alaska Oil & Gas Cons. Commission Anchorage Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: KBU 33-6 Dear Mr. Aubert: Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KBU 33-6. The proposed work is to install a 1-3/4" coiled tubing lift string at the U5 & U6 ~ perforations. Gas from a nearby higher pressure Tyonek well will be metered and used as lift gas. A similar installation was placed in another well which also targeted the U5 & U6 zones. While the installation successfully lifted water, no incremental gas production was ever /' detected. The inability to flow gas from the previous well was contributed to behind pipe cement issues. A cement bond log on this well showed effective zone isolation. Work is expected to begin around September 8th. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at DMTitus@MarathonOil.com. Sincerely, f\ ~w;Þ ì~.iL71.,!...,f. ,.';:> ~ ¡,JO\...,. . / ;' t Denise Titus Production Engineer Enclosures Sundry Application Detailed Procedure Proposed well bore diagram Tree diagram Meter diagram -- - ..--..-.. CJ~!GINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: AbandonD Suspend weliD Operation ShutdownD Alter Casing D Repair weliD Plug perforationsD Pull TUbingD Perforate New Pool D Change Approved Program D 2. Operator Name: Marathon Oil Company 3. Address: PO Box 196168, Anchorage, AK 99519-6168 7. KB Elevation (ft): 87' KB above MSL 8. Property Designation: A-028142 \Nú 't- PrL-j '3' I ';,O{ z..O°4- ?(Jo /1- RECEIVED AUG 3 0 variancA~ Oi~~~I~&$b~ . Anchorage StimulateD Time ExtensionD Other\KJ Run Lift String ../ Perforate D ssion Re-enter Suspended Well D 4. Current Well Class: DevelopmentE] ExploratoryD stratigraPhicD serviceD 5. Permit to Drill Number: 99-24/' 6. API Number: 50- 133-20487 /' 9. Well name and number: KBU 33-6 / 10. Field/Pools(s): Kenai Gas Field, Tyonek Beluga Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 5460' I 5046 Size MD TVD 11. Total Depth MD (ft.) 8110 MD Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): See attached Diagram Packers and SSSV Type: Packer: Model D Permanent 12. Attachments: Description Summary of proposal~ Detailed Operations Program E] BOP Sketch -0 ITotal Depth TVD (ft): I 7410 TVD Length 115 1568 5810 115 1568 5810 20' 133/8" 9 5/8" 115 1540 5324 Perforation Depth TVD (ft): I See attached Diagram Tubing Grade: I L-80 Packers and SSSV MD (ft): 5230 Tubing Size: 4.5" 13. Well Class after proposed work: Exploratory D Development Plug (measured): Junk (measured): Burst Collapse NIA 3450 5750 2270 3090 Tubing MD (ft.): I 5229 / E] Service D 14. Estimated Date for Commencing Operations: 8-Sep-2004 15. Well Status after proposed work: Oil D GasE] /PluggedD Abandoned D 16. Verbal Approval Date: WAG D Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name --¡tl1M1' Phone Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D ::,eo, F~v:l4 0 4 Approved by: ~ Form 1~ Rev~ 2I200~ C0MMISSIObiER GINJD Contact Title Operations Engineer 283-1333 SUndry Number: Location Clearance D R8DMS Bf L BY ORDER OF THE COMMISSION .'!GINAL WINJD D WDSPL Date August27,2004 .:£X-I-333 SEP 02 1M Date g--hð /ðcf V I sutmit in duplicate Marathon Oil Company Alaska Region KBU 33-6 Kenai Gas Field, Pad 41-7 Lift String Procedure History: Excess water has kept KEU 33-6 from flowing gas as indicated from a recent SBRP ---- survey. An artificial lift mechanism will be installed to encourage initial production from the U5-U6. Consistent with other Beluga sand completions in the Kenai Gas Field, KBU 33-6 is expected to show a trend of dewatering and increased gas production once production is established. This lift installation was used on KEU 41-7x in an attempt to produce gas. The string successfully gas lifted the water for several months. The US & U6 zones never did /' contribute gas, likely due to poor cement. Objective: Install a temporary gas lift string in an attempt to dewater Upper Beluga intervals. The mechanism used will include a packerless velocity string and a high pressure gas source to lift water out of the wellbore. PJr'ocedUJre: 1. MIRU BJ CT unit with 5600' of 1.75" x 0.125" 70 grade tubing. NU BOPs on 41;8" 5M flanged tree valve. RU flowback line from side outlet on CT hanger spool (2-1/16" 5M flange). ./ 2. Fill CT with 6% KCl and pressure/function test BOPs to 25012500psi against the closed master valve. '" .). Assemble CT BRA per procedure. BRA includes 10' straight bar to permit wireline exit and re-entry at the tubing tail. Break lubricator and install BRA including profile nipple and pump-off plug. MU lubricator and line up kill line to BOPs for body test 250/1000psi 4. Rill slowly w/ 1.75" velocity string watching weight indicator. Open annular returns from pipe displacement to the tank via CT hanger outlet. Run string to depth of 5375' -- / confirm depth based on 21' RT-GL measurement. Mark pipe on reel end at hangoff depth. l:: J. Measure distance from CT hanger lock screws on tree to above BOPs. Pick up measured distance. Close BOP slips and rams. Bleed off any pressure from above pipe rams. Then, monitor well pressure on annulus for a few minutes to make certain pressure remains at 0 psi. 6. Break the connection above the BOPs and raise injector head (as per BJ CT Operating procedure) as needed to clear the hanger to cut CT and install CT hanger seal assembly. 7. Install C-Plate and dog collar slips on pipe. Cut tubing and install CT connector, dual flapper valve, and Hydraulic GS. Pull test CT connector to 25,000 lbs. 8. Dress pipe stub above BOPs and install CT hanger seal assembly. 9. Engage running tool in top of hanger. Remove dog collar and C-plate. Lower injector and make up riser to BOP. Pull test connectors and hanger against slips to + /-25000 lbs. 10, Engage load shoulder using lock scre\vs on Vetco CT hanger. Slovvly lower pìpei:û hangoff depth using mark on pipe as reference, watch for drop off in weight to verify hanger location. Check measurements, and land hanger on load shoulder. / 11. Run in lock screws and torque per hanger specifications. Verify seal integrity via pressure test ports in tubing head. 12, Pump down CT 1.5 bpm to 2 bpm to release running tool and retract. PUR and pump N2 down kill line to eject pump off plug, 13. RDMO BJ CT. 14, RU BJ N2 truck to CT annulus flange. Rig up flowback to open top tank: through tree wing flange or tree cap, Pump N2 to void annulus and tubing taking returns to tank. Tubing Wæ'll b pnsidered clear once water returns slow or tubing load volume (CT + annulus) 0 ~bbl is recovered. Expected max pressure = 2500 psi. Shut in flowback and over- Isplace with nitrogento 1500psi. Leave N2 cap on well to prevent wellbore influx. RDMO BJ Services. ./ 15. Complete surface tie-ins (see attached tree schematic). Configure so that metered gas line from KTU 24-6h ties into the CT hanger annulus. The wing above the second master will tie in to the low pressure system as before. 16. Line up lift gas to CT annulus with 2-pen chart recorder on tubing and gas lift injection line. With injection gas on, open velocity string to MOC flowback equipment. Maintain / lift gas at or above 0.8MMscfd. Watch returns for solids production. Once flowrate appears stable and clean and returns are gas and water (not nitrogen), turn well to low pressure system via test separator. Monitor annulus gas rate and pressures at stable well flowrates and well gas and water production rates. ~ KBU 33-6 Pad 41-7 API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37'FNL,4068'FVVL Sec 6, T4N, R11VV, S.M. Tree cxns: 3-1/2" 8rd Tubing Detail 4-1/2", 12.6 ppf, L-80, IBT @ 5229' Proposed Completion: Upper Beluga U5 5350'.5370' MD, (4899-4906 TVD) U6 5380'.5400' MD, (4925-4940 TVD) 9-5/8",40#, L-80, BTC casing @5810' Cmt wI 570 sx of Class G TD=8110' 120",133#, K-55 Drive Pipe @ 115' I 13-3/8",68#, L-80 BTC Casing @ 1568' Cmt wI 600 sx of Class G Chemical injection Mandrel at +1- 1500' Model 0 Permanent Packer Sealbore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide @ 5230' 1-3/4" 0.125VVT CT Velocity String @ 5375' ,/' 95/8" Cast Iron Cement Retainer at 5460' MD, / Unable to establish injection at 3000psi. Well Name & NumberBul Plug/Cplg KBU 33-6 I Lease I County or Parish: Kenai Pen Bourough State/Provo I AK Country: I USA Angle/Perfs Angle @KOP and Depth KOP TVD I BHP: BHT: Completion Fluid: I FWHP: FBHP: I FWHT: I I FBHT: I Other: I Date Completed: RKB: I Prepared By: DMT I Last Revision Date: 06/04/03r I Gas lift meter 2:as I Gas Lift Gas Flow To low pressure production header Diagram For KBU 33-6 Return gas meter From Meter KBU 33-6 ~J Portion of gas stream produced from KTU 24-6h ""'-. .. :::~:","-c' I Well KBU 33-6 I ~. - I '\ 4- I ~ Water and Gas KBU 33-6 Gas Lift 4-1/2" Tubing 1-3/4",0.125" wall Velocity String -----I>' To Production Lift Gas In ~ ( ~ ( M Marathon MARATHON Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 June 24,2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 qc¡-ó~ L{ Reference: KBU 33-6 Dear Mr. Aubert: Enclosed is the 10-404 REPORT OF SUNDRY WELL OPERATIONS for Marathon well KBU 33-6. Work was completed to target Upper Beluga pay by cutting and pulling the dual monobores at the cement top in the intermediate casing string. The Beluga U5 & U6 zones were then perforated through tubing. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at DMTitus@MarathonOil.com . Sincerely, ~~ Denise Titus Production Engineer Enclosures Sundry Report Daily Perforating Report Current wellbore diagram '''I/¡;" JÚ;tt .2 8.') <"'Ots1 ORIG\NAL ._~ '.",,-~ -~~,-:-_---- ~ - - \ STATE OF ALASKA All -~ Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Marathon Oil Company Name: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other U Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 99-24 Service 0 6. API Number: 50-133-20487 -00-00 9. Well Name and Number: Kenai Beluga Unit 33-6 10. Field/Pool(s): Beluga 3. Address: PO Box 196168 Anchorage, AK 99519-6168 7. KB Elevation (ft): 87' KB above MSL 8. Property Designation: A-028142 11. Present Well Condition Summary: Total Depth measured 8110 true vertical 741 0 feet feet Plugs (measured) 5460 Junk (measured) NA Effective Depth measured 5460 true vertical 4991 feet feet Casing Structural Conductor 115 Surface 1568 Intermediate 5810 Production Liner Length Size MD TVD Burst Collapse 20' 13-3/8" 9-5/8" 115 1568 5810 115 1540 5324 NA 3450 5750 2270 3090 Perforation depth: Measured depth: 5350'-5370'; 5380'-5400' , , ~ ,~\\\I True Vertical depth: 4887'-4906'; 4915'-4934' JUN 2 8 2004 Tubing: (size, grade, and measured depth) 4~ 1/2" L-80 l\:¡,;,........i!..,7' 5231""",'1"": Packers and SSSV (type and measured depth) Baker Mode! D Perm. 5210' 12. Stimulation or cement squeeze summary: .Interva!s treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA Subsequent to operation: NA 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 0 0 0 0 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 0 0 1200 Service 0 x Contact Denise Titus GINJ 0 WINJ 0 WDSPL 0 SUndry Number or N/A if C.O. Exempt: 304-064 Printed Name Deni;'Ií~s ti'~ Signature ~ ~ Title Production Engineer Phone 907-283-1333 Date 6/24/2004 Form 1 0~404 Revised 04/2004 ORIGINAL Submit Original Only M .AIATIIO. API: 50-133-20487 1~'. ,1\0 , I~,',," .' ,~ -I, RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec 6, T4N, R11W, S.M. Tree cxns: 3-1/2" 8rd Tubina Detail 4-1/2", 12.6 ppf, L-80, IBT @ 5229' Proposed Completion: Upper Beluga .a:. U5 5350'-5370' MD, (4899-4906 TVD) :=II :cDI II U6 5380'-5400' MD, (4925-4940 TVD) :ell :cDI 9-5/8",40#, L-80, BTC casing @5810' Cmt w/ 570 sx of Class G Well Name & NumberBul Plug/Cplg KBU 33-6 County or Parish: Kenai Pen Bourough Angle/Perfs Angle @KOP and Depth BHP: BHT: FWHP: FBHP: Date Completed: Prepared By: { , \, .11 !t-~ ~,. KBU 33-6 Pad 41-7 H ~. 120",133#, K-55 Drive Pipe @ 115 i~,., 'i,t ~. Ji~~~;'6~~#~;~~Oc~a:~ ~aSing @1568' ~ 'I ", Chemical injection Mandrel at +/- 1500' I " !II , ~' ~ ~ :,' Model D Permanent Packer II +- Sealbore Extension, 10' sub, 3.812 X Nipple, "~ 1 0' sub and Wireline Re-entry Guide @ 5230' " . l' 1~~ ,~ " ':0 lt Ü'"'"',,,,.,',', I ; ¡, .,: ~ a: lei: ;;r " ~ ¡'t ,j ;~ ~~ '1 EX EX -;¡ 9 5/8" Cast Iron Cement Retainer at 5460' MD, Unable to establish injection at 3000psi. :; ....--- '" 1~'~ r\~ ').:'1 'I!,I ~,Fi /I,' ,'" {! l' ','; e \~; ¡.JIfi :~', ;" }"'. Ii, 'I, ", $:' 'II '''(,. 'I .. , ~ . I TD=8110' Lease I AK USA I Country: I KOP TVD State/Prov. DMT Completion Fluid: FWHT: I I Last Revision Date: I Other: RKB: 06/04/031 FBHT: Page 1 of 1 MARATHON OIL COMPANY Daily Drilling Report Re-complete to New Zone I DFS I DOL I RPT # DATE 0 0 1 22-Jun-2004 SAPIWBS COST \24 HR PROG TMD TVD AUTH MD WBS jGL 66.00 KB WELL NAME KENAI BELUGA UNIT 33-6 SUPERVISOR Denise Titus FIELD NAME KENAI STATElPROV Alaska CURRENT STATUS @ 6AM Perforating complete OPERATION COMMENTS RU Expro. Perforated Upper Beluga U5 & U6: 21.0 RIG NAME & NO. WO.04.10247.CAP I DAILY WELL COST I 10,030 0 I NEXT CASING (in) Cã2 0 (ft) CUM WELL COST 10,030 0 I LEAKOFF NRI MOCWI 100.0000 RIG PHONE I LAST CASING Cã2 0 \ 24 HR FORECAST Turn well to production COUNTY/OTHER Kenai Borough 5350'-5370' & 5380'-5400' wi 3-3/8" 60 deg, RDX, 25 gram perf guns. SAFETY SUMMARY ~~NOHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: I LAST RIG INSPECTION OPERATIONS SUMMARY SUB PHASE OP SUBOP TRBL DESCRIPTION CMPPRFSAFETY MTG- Arrive on location, sign in, obtain permit, meet to discuss procedure, spot equipment, PJSM. Rig up 5-1/2" lubricator and BOPs. Pwh=900psi (N2 pressure) Wait on Veco to assemble and certify scaffolding Continue rigging up BOP and lubricator Arm gun using PX-1 safe firing system. Stab lubricator on well. RU methanol skid and pressure test to 2500psi. Open well and RIH wi gamma gun and 3-3/8" perf gun Log interval to be perforated. Pull additional strips. Correlation difficult due to difficult gamma and only 3 original casing collars. Get guns on depth. Set guns on depth and fire with questionable response. POOH. Guns at surface. Did not fire. Inspect firing head and rig up second PX-1 dropping gamma gun from tool string. Send man to shop for conventional firing head. RIH again wi gun #1 and 2nd PX-1 firing head. Get on depth, attempt to fire gun, firing panel in truck shorting aout. Assess and fix problem and reattempt to fire gun. Indications good. POOH wi spent casing. All shots fired. PU gun #2 with conventional firing system and CCL. RIH to logging depth. Log interval to be perforated. Fire guns on depth. POOH with 2nd gun carrier. Pwh=1200psii Tools at surface, LD equipment and rig down truck. Sign out and turn in work permit. Leave location. FROM TO HRS FROM TO 12:00 12:45 0.75 CMPPRFRURD- ELEC CMPPRFW AITON EQI P CMPPRFRURD- ELEC CMPPRF PULD- PGUN CMPPRF TEST - BOPE CMPPRF~UNPULELEC CMPPRF LOG- CSG- 0.33 0.75 1.50 0.58 0.58 0.83 5,430 1.50 5,430 5,050 12:45 13:05 13:05 13:50 13:50 15:20 15:20 15:55 15:55 16:30 16:30 17:20 17:20 18:50 CMPPRF~UNPULELEC CMPPRF PULD- PGUN 18:50 19:45 0.92 5,050 19:45 20:30 0.75 CMPPRF~UNPUL ELEC CMPPRF PERF - TBG- 20:30 21 :45 1.25 5,430 21 :45 22:00 0.25 5,430 5,050 CMPPRF~UNPUL ELEC CMPPRF PULD- PGUN CMPPRF~UNPULELEC CMPPRF LOG- CSG- CMPPRF~UNPULELEC CMPPRFRURD- ELEC 0.58 5,050 0.42 0.83 5,430 0.25 5,430 5,050 1.33 5,050 1.08 22:00 22:35 22:35 23:00 23:00 23:50 23:50 00:05 00:05 01 :25 01 :25 02:30 CASING SUMMARY LAST CASING TEST: MAX SICP I MD I TVD NEXT BOP TEST: WT I GRADE LAST BOP TEST: SIZE I ID I SHOE TEST BURST Printed: 6/24/2004 4:26:04 PM If ( Alaska Business Unit Domestic Production M Marathon MARATHON Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561.5311 Fax 907/564-6489 May 21,2004 q~-D~ I Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Kenai Beluga Unit 33-6 Report of Sundry Well Operations (10-404) Dear Mr. Aubert: Enclosed is the referenced report for the Kenai Gas Field well KBU 33-6 with attachments (including digital log data). Should you require further information, I can be reached at 907-283-1333, or bye-mail at d mtitus@MarathonOil.com. Sincerely, tT51/? Denise M. Titus Production Engineer Enclosures ('" r-" \"""," \I~"';o JUN J 4~ 7GG4. l~h1,:s,t1;a I STATE OF ALASKA (' ALt""r<Ä OIL AND GAS CONSERVATION COMIVIISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Marathon Oil Company Name: 3. Address: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other U Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 99-24 Service 0 6. API Number: 50-133-20487 -00-00 9. Well Name and Number: Kenai Beluga Unit 33-6 10. Field/Pool(s): Beluga I Tyonek PO Box 196168 Anchorage, AK 99519-6168 7. KB Elevation (ft): 87' KB above MSL 8. Property Designation: A-028142 11. Present Well Condition Summary: Total Depth measured 8110 true vertical 741 0 feet feet Plugs (measured) 6378' Junk (measured) NA Casing Structural Conductor 115 Surface 1568 Intermediate 5810 Production Liner Length Size feet feet MD c.~~~ 115 ~~~\"v Burst 1568 ~ 5810 NA ~ 5324 3450 " 5750 Collapse Effective Depth measured 6321 true vertical 5614 20' 13-3/8" 9-518" 2270 3090 Perforation depth: Measured depth: Not yet perforated fi "'~ ~f"'~; "''i ~.."" \\~" r- ~ \\/E.. "\D t:, ~ " ~:\:' t JUN I 4 2004 True Vertical depth: Not yet perforated Tubing: (size, grade, and measured depth) 3.5" tubing L-80 ¡~~*a Oil 8~ Cml1mission ¡.\nehoiage Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. J. 1 'U 1 ,4 ?~'ftltt Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA Subsequent to operation: NA 14. Attachments: Copies of Logs and Surveys Run X Daily Report of Well Operations 0 0 0 0 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 0 0 0 Service 0 x GINJ 0 WINJ 0 WDSPL 0 SUndry Number or N/A if C.O. Exempt: 304-064 Contact Denise Titus Printed Name DeniAT~~ AÁ¡~ Signature ~ VJllfI'" Title Completions Engineer Phone 907-283-1333 Date 5/21/2004 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only " -r ~ ~~ ~TI: ~ ~ ~~ q,, I \If ~!O\ ,r ' ~.~ ,I "ill! ¡ ~' ~ ~' ==,",! ï,:n i1.!: ñ" TI!,", ,,',:,1: ~" î ~. ~ ~ ~ ~ þ;~ TD=8110' Well Name & NumberBul PluglCplg KBU 33-6 I County or Parish: Kenai Pen Bourough State/Prov. AnglelPerfs Angle @KOP and Depth BHP: BHT: FWHP: FBHP: Date Completed: Prepared By: ., , Nt .AUTlO. ~- i 1 API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec 6, T4N, R11W, S.M. Tree cxn: 4 1/8 5M valves by 6.5" Otis Tree Cap Tubina Detail 4-1/2",12.6 ppf, L-80, 1ST +/- 5300' Proposed Completion: Upper Beluga U5 5350'-5370' MD, (4887-4906 TVD) lJ6 5~Rn'-54nn' MO. (4q1 fi-4q~4 TVn) 9-5/8",40#, L-80, STC casing @581 0' Cmt w/ 570 sx of Class G TubinQ Detail Longstrinq: 3-1/2",9.3 ppf, L-80, EUE 8rd-M w/ SCC @ 8088' CIBP @ 6210 3/3/2004 Current Completion: Longstring-Beluga M12 & M13 6252'-6269' (4spf, 00, 2/23/03) 6296'-6331' (4spf, 00, 2/23/03) CIBP @ 6378' Note: Tubing is kinked in both strings @ 6410' Historic Info: Longstring Perfs- Tyonek 73-1 7,941 '-7,951' 7,960'-7,970' . '~~I'-'-,I"'" X~' 13-3/8",68#, L-80 STC Casing@1568' . ~ Cmt w/ 600 sx of Class G ", to... ~ Chemical injection Mandrel at 1466' I ~ +- Model D Permanent Packer with floating seals ~' Seal bore Extension, 10' sub, 3.812 X-Nipple, 10' ..;t sub and Wireline Re-entry Guide at 5,230'. l' ~ ~. J; ~ , ~ to f ~ l -. -::r: 11 a a ,. 95/8" Cast Iron Cement Retainer at 5460' MO, ¡,' .. ---- unable to establish injection at 3000 psi. I;j..- ~ TubinQ Detail Shortstring: 3-1/2" x 2-7/8" tapered 0'-5617': 3-1/2", 9.3ppf, L-80 EUE 8rd-M w/ sec 5617'-8087': 2-7/8", 6.5ppf, L-80, EUE 8rd-M w/ SCC KBU 33-6 Pad 41-7 ;"" ~ ~ . é ~ ~ JI ~ .. J; ., ~ ~ r ~ -I ~ - CIa iI - .. x . 'Jì" 1':"a.'~" r"",';' 'i ¡ " "m~,', ~\ i!,' ..n j ~ : I,'~ i I! f 120", 133#, K-55 Drive Pipe @ 115' I Shortstrinq-Beluqa M6 6088'-6104' (4spf, 0°, 2/24/03) CIBP @ 6250' Historic Info: Shortstring Perfs-Beluga M14, M15 6387'-6410' (4 spf, Odeg, 7/00) 6426'-6442' (4 spf, Odeg, 7/00) 6446'-6460' (4 spf, Odeg, 7/00) 6464'-6471' (4 spf, Odeg, 7/00) 6476'-6482' (4 spf, Odeg, 7/00) 6486'-6490' (4 spf, Odeg, 7/00) PBTD (LS)=8055' PBTD (SS)=8056' Lease I AK USA I Country: I KOP TVD Completion Fluid: FWHT: I I Last Revision Date: DMT I Other: RKB: 06/04/031 FBHT: ~. Daily Summary for Well: KENAI BELUGA UNIT 33.6 Report Date Report Number MD TVD Summary ".............',,,........................................,".....,...........,,."',...",,,,,,,,,,,,,,,,,,,,,,,,,,,"'''''''''''''''-''''''''''00''''''''''''''''''''''''''"'''''''''''''00'''''''''''''''''''''''''''''''''''''00''''''''''''''-''''''''''''''''''''",,,,,,,,,,,,,,,,,,,,,,-,,,,,,,,,,-,,,,,,,,"""''''''''''-''-''''__'''00''''''''........."'...................................................................................." 2004 Recompletion 04-Mar-04 RU Expro W/L. Make 2.8" OD GR run in short string to 5,614' WLM. Make 2.3" OD GR run in short string to 6,140' WLM. Make 2.8" OD GR run in long string to 6,240' WLM. Set 2.75" CIBP in Long string @ 6,210'. Secure well and SDFN. 05-Mar-04 2 RU Expro W/L. Attempt to set 2.25" CIBP in Short String. CIBP pre-set @ 4,540'. RD ElL and convert truck to slickline operations. RIH with 2.6" OD LIB and tag fish at 4,540' WLM. Indication of clean rope socket. RD Expro. 06-Mar-04 3 RU BJ Coiltech. 07 -Mar-04 4 RU BJ C/T/N2/FB equip on 33-6 SS. Make up Weatherford fishing assembly. RIH and tag fish at 4541. Pull to 14000 Ib and broke free with normal PU wt. Re-tag fish and PU with normal wt. POOH to inspect BHA. Laying down fish as of report time. 09-Mar-04 5 KBU 33-6 Short String. Prep for CT milling job. PU milling BHA and RIH. Tag CIBP fish @ 4576' CTM. Jar down on CIBP fish and push to 5600' CTM. POOH. Perform injection test. RD CT and prep location for upcoming rig move. 11-Mar-04 6 MOB and R/U Glacier Driling Rig #1 to well KBU 33- 6 workover. 12-Mar-04 7 Finish R/U of rig. Test casing, N/D tree and N/U BOPs. Test BOP's 13-Mar-04 8 Test BOPE. Pull 2 way checks. Fill and monitor well. R/U E-line, Cut LS @ 5470' - not free. Cut SS @ 5430', not free. Ran freepoint on LS -free at - 5,100'. 14-Mar-04 9 Cut both LS and SS tubings and CBU on annulus. R/U and POOH wi dual tubing strings. Printed - 5/20/2004 Dailv Summary for Well: Report Date 15-Mar-04 16-Mar-04 17 -Mar -04 18-Mar-04 19-Mar-04 20-Mar-04 21-Mar-04 22-Mar-04 23-Mar-04 24-Mar-04 25-Mar-04 26-Mar-04 ......---.................... Report Number MD 10 11 12 13 14 15 16 17 18 19 20 21 TVD .""-"""""""""'''''''''''''''''''''''''''''-- KENAI BELUGA UNIT 33-6 Summary .....--.......-.......-.......,,-- ... .0. .". POOH wI dual 3-1/2" dual tubing strings. Test BOP's 250 I 3000 psi. M/U and TIH wI overshot fishing BHA. Engaged fish 5,101'. Jar on fish, CBU. Ran freepoint and string shot. Backed off fish and POOH. Recovered 186' of tubing. Latch LS fish at 5118'. Jar, freepoint and string shot. Back off and recover 15' cut jt. TIH latch LS fish and blind backoff, recovered (2) jts. TIH wI fishing BHA. Latch LS fish 5197'. Jet cut at 5,373'. Unable to pull, blind backoff. POOH wI 31.47' LS fish. TIH latch and jar fish at 5,229'. POOH wI 159.67' LS fish. RIH wI fishing BHA for SS. Latch SS fish 5,287' and TOOH w/SS fish. TIH, S& C drill line, TIH. Ream fill 5,320-85'. CBU. Latch LS fish and pull free. CBU. TOOH wI LS fish. Redress overshot and TIH. RIH. Washover LS fish. POOH. M/U overshot assy. RIH. Engage fish. Jar fish free. POOH. Recovered 2.9' of 3.5" TBG. Rig repair. RIH w/8 1/2" Wash shoe. RIH. Wash over LS fish. POOH. RIH latch LS fish. Jar on fish. POOH. Recover 9.5' of 3.5"TBG. M/U mill assy. RIH. Mill TBG F/5444' to 5461'. Mill 3 1/2" dual string F/5461, to 5474'. POOH. LID mill assy. Test BOPE. Rig repair. Test BOPE. RIH wlbit and scraper assy. RIH w/bit and scraper. Circ. and work junk baskets. TOOH w/bit and scraper. Run Logs. P/U and RIH cement retainer. Set retainer and attempt to get injectivity. No injectivity. Trobleshoot electrical problem with mud pumps. Trouble shoot pumps while wait on logs to be analyzed. Clean pits build 6% KCL brine. Displace hole. POOH LID DP and collars. RIH wireline pkr, POH pkr for gamma log, run GR correlation, RIH wireline pkr, set pkr, run 4 1/20 comp assy Run tbg, space out, circ, land tbg, test, nipple dn, nipple up tree, test, set BPV, rig dn, prepare move. Printed - 5/20/2004 RE: KBU33-6 Recompletion lCfQ..o2.cf Subject:RE: KBU3~-6R.eçompletión From: "Eynon, Don" <DEEynon@MarathonOil.com> Date:Fri, 05 Mar 2004 11 :06:55-0900 To: Winton Aubert <winton_aubert@admin.state.ak.us> cc: James B Regg <jim_regg@admin.state.ak.us> Winton, We have started the KBU 33-6 plug back in preparation for the drilling rig. Wednesday March 3rd we ran the gauge ring and set a CIBP in the long sting at 6210' KB. While running the 2.875" CIBP (2.16" 00) on the short string the CIBP prematurely set at 4540' KB inside the 3.5" casing. While pulling on the wire to see if the CIPB was set the wire pulled out of the rope socket and left the setting assembly with the BP. A subsequent run with a lead impression block indicates a clean fishing neck. We are rigging up CT today to fish out the setting assembly and then will attempt to push the remainder of the CIBP to the casing swedge at 5617'. We would then like to set a plug on top of the fish and dump bail 25' of cement on top. With all the current and proposed zones in the same unit is a variance necessary to set the plug greater than 50' from the perfs? We may be ready to set a plug prior to Monday so a response today is appreciated. . Thanks, Don Eynon 907 -283-1337 Office 907 -398-9954 Cell -----Original Message----- From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] . Sent: Friday, February 20, 2004 7:55 AM To: Eynon, Don Cc: James B Regg Subject: Re: KBU33-6 Recompletion Don, To satisfy abandonment regulations, you should set a CIBP in the 3-1/2" long string @ ::!: 62103 COt'tll 253 o~ XE~EV't ßatÂE8 ov 't01t, av8 a XIBII tv 'tllE 2-7/8\:1 crlloP't cr'tptvy ==:i:: 6040' with 25' of bailed cement. The subsequent Upper Beluga completion should include tubing and packer. Winton Aubert AOGCC 793-1231 Eynon, Don wrote: Winton, We are planning on moving KBU 33-6 in approximately three weeks for a workover. We will be abandoning the current intervals and moving to the Upper Beluga U5 (5352'-5370' MD) and U6 (5390'-5406' MD) zones in the 9 5/8" casing. We would accomplish this by setting CIBP's with 25' of cement on top at approximately 5,560' in the short and long string and then cutting off and pulling the dual mono-bores at the cement top around 5,420 MD. Would this satisfy the regulations for abandoning the intervals in the Beluga and Tyonek previously on production in SC¡~~NEO MA~ 1 5 2004 3/5/2004 12:03 PM Marathon Oil Company Alaska Business Unit Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 26,2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 33-6 Short and Long Dear Mr. Aubert: / Enclosed is the 10-403 Application for Sundry Approvals for Marathon well KBU 33-6. /' The proposed work is to target Upper Beluga pay by cutting and pulling the dual monobores at the cement top which is in the intermediate casing string. The Upper Beluga intervals which are being targeted share the same participating area with all other /'. intervals previously open in the well bore. Due to height limitations we will drop the single gate off our normal BOPE stack as maximum anticipated wellhead pressure will be 1,975 ,,-- psi based a normally pressured reservoir and a methane gradient to surface. Reservoir pressure in offsets in the same Upper Beluga intervals have been measured at 1,800 psi. Pre-rig plugging of intervals currently open will begin Wednesday March 3rd pending your approval. Cast iron bridge plugs will be set within 50' of the productive interval with 25' of /' cement dump bailed on top in both monobores. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at D E Eynon@MarathonOil.com. Sincerely, ':-¡"""\ A ß i""' if'-ch ~ Donald Eynon Production Engineer Enclosures BOPE Sketch Sundry Application Detailed Procedure Current wellbore diagram Proþosed wellbore diagram F<E(;EI\/Ei:) FES 2 '7 2004 Ah~~:,'\a Oil & Gas C~flS, COJ1inWUi,ion Am::horage ~(;A~NED MA~ 1 Z; 2004 ORIGINAL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 tUG A- ~ I ¡ / 2-l.?O 'f ~n. ~;j ~ II 11- 1. Type of Request: AbandonD Suspend wellD Operation Shutdown D perforate[K] Variance D Annular Disposal D Alter Casing D Repair wellD Plug perforationsD StimulateD Time Extension D Other[K] Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Deve,opmentB EXP,oratoryB 99-24 / 3. Address: Stratigraphic Service 6. API Number: PO Box 196168, Anchorage, AK 99519-6168 50- 133-20487/ 7. KB Elevation (ft): 9. Well name and number: 87' KB above MSL KBU 33-6 short and long ./ 8. Property Designation: 10. Field/Pools(s): ~6A- A-028142 Kenai Gas Field,4=H'Tyonek Beluga Pool 4"8 S7 ¡ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft.) ITotal Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plug (measured): Junk (measured): 8110 MD 7410 TVD 6321' MD 5814' 6378' MD NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 115 20' 115 115 NIA Surface 1568 13 3/8" 1568 1540 3450 2270 Intermediate 5810 95/8" 5810 5324 5750 3090 Production 8087 3.5" & 2.875" 8087 7452 10160 10530 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: 1TUbing Grade: ITUbing MD (ft.): See attached Diagram See attached Diagram 3.5" Casing L-80 8055 Packers and SSSV Type: Packers and SSSV MD (ft): NIA NIA 12. Attachments: Description Summary of Proposal % 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch Exploratory D Development ~ Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2-Mar-2004 OilD Gas~ Plugged D Abandoned D 16. Verbal Approval Date: WAG D GINJD WINJD WDSPL D Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Donald Eynon Title Operations Engineer Signature ~~,, ~. Phone 283-1337 Date February 26, 2004 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: ¿j t:/ '-/-l)? 1- f Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: ApprweJ F~~a"5 ~~rr tM ~q¡'" vel () C~ftrl <;'-h-iï ik-\Je\"11 ç,../io ~'- /' f.. '...", .~Jll}f ~ ,I~ \~ T I,") ~ .,', j' - ) 'VJ\'L~t.." i . ;"1 " SUbsequ~zZ5j :, . 40 'i i~; h¥ BY ORDER OF Approved: U I /' tr A COMMISSIONER THE COMMISSION Date: "«~A~~~1f~' .C'lro13 "-. RIGINAL /Ubrr/t in du~icate ~:&p". ..,,} JL~ ..~..^'" 0, API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL See 6, T4N, R11W, S.M. Tree cxns: 3-1/2" 8rd Tubing Detail 4-1/2",12.6 ppf, L-80, IBT +1- 5300' Proposed Completion: Upper U55352'-5370' (4899-4906 TVD) U65390'-5406' 9-5/8",40#, L-80, BTC casing @581_Q' Cmt wi 570 sx of Class G Lonqstrinq: 3-1/2", 9.3 ppf, L-SO, EUE 8rd-M w/ see @ SOSS' PROPOSED CiBP @ 6210 wi 25' Cement Current Completion: Longstring-Beluga M12 & M13 6252'-6269' (4spf, 00, 2/23/03) 6296'-6331' (4spf, 00,2/23/03) elBP @ 6378' Historic Info: Longstring Perfs- Tyonek 73-1 7,941'-7,951' 7,960'-7,970' 33~6 120",133#, K-55 Drive Pipe @ 115' I 13-318", 68#, L-80 BTC Casing @ 1568' Cmt wi 600 sx of Class G Chemical injetion Mandrel at +1- 1500' .- Model D Permanent Packer Seal bore Extension, 10' sub, 3.812 X Nipple, 10' sub and Wireline Re-entry Guide 95/8" Cast Iron Bridge Plug will be set if there is room between the bottom perf interval and PBTD Shortstring: 3-1/2" x 2-7/S" tapered 0'-5617': 3-1/2", 9.3ppf, L-SO EUE Srd-M w/ see 5617'-SOS7': 2-7/8", 6.5ppf, L-80, EUE 8rd-M w/ see PROPOSED CIBP @ 6040 wi 25' Cement Current Completion: Shortstrinq-Beluqa M6 6088'-6104' (4spf, 0°, 2/24/03) elBP @ 6250' Historic Info: Shortstring Perfs-Beluga M14, M15 6387'-6410' (4 spf, Odeg, 7/00) 6426'-6442' (4 spf, Odeg, 7/00) 6446'-6460' (4 spf, Odeg, 7/00) 6464'-6471' (4 spf, Odeg, 7/00) 6476'-6482' (4 spf, Odeg, 7/00) 6486'-6490' (4 spf, Odeg, 7/00) PBTD (LS)=8055' PBTD (SS)=8056' TD=8110' Well Name & NumberBul Plug/Cplg KBU 33-6 I Lease I County or Parish: Kenai Pen Bourough State/Provo I AK coun~ USA Angle/Perfs Angle @KOP and Depth KOP TVD BHP: BHT: Completion Fluid: I FWHP: FBHP: I FWHT: I I FBHT: I Other: I Date Completed: RKB: I Prepared By: DMT I Last Revision Date: 06/04/031 Marathon Oil Well KBU 33-6 WO BOP Stack I Flow Nipple I -------. I Flow Line I 13 5/8" 5M Annular Preventer / ~ 13 5/8" 5M Double Ram Preventer Dual Pipe Ram or VBR / ----. 21/16" 5M Manually Operated Valves I Blind Ram I / 3 1/8" 5M Hydraulically Operated Valve ~~ rnrnrnmrnm Œw=J 1135/8"5MGross I ~ I Choke I ,¡ ITI0illOI0IIJ t 13 5/8 5M by 11" 5M DSA 3 1/8" 5M Manually ~ Operated Valve 111" 5M Tubing Head Flange Blow Out Prevention Equipment Marathon Oil Company Alaska Region KBU 33-6 Kenai Gas Field, Pad 41-7 U5-U6 Workover Procedure History: KBU 33-6 was originally drilled as a dual mono-bore with one 3.5" EVE SCC string to TD(long string nomenclature) and the second 3.5" string (short string nomenclature) swaged down to 2.875" OD at 5,617' MD to TD of 8,056'. Originally completed Beluga and Tyonek /~ intervals are now in the same participating unit. Fill has been encountered in the "long string" side of the well at 6,321' MD, covering 10' of perforated interval and 57' above the CIBP which is located at 6378'. The "short string" was tagged with slickline in March of2003 at the CIBP. Objective: Isolate and abandon current zones in well to provide access to U5 and U6 zones inside of 9-5/8" intermediate string. MIRV Glacier rig # 1 to pull dual strings and re-complete ~.. in U5 and U6 of the upper beluga. Procedure: 1. Contact Kenai Gas Field Office daily for work permit, discuss safety and environmental concerns. 2. MIRU flow back tank and choke manifold with chisan off of flow cross on well. RV 2 tiers of scaffolding next to dual tree if well house allows. 3. MIRU Expro wire line. a. Install BOPE and lubricator to crescent shaped Otis flange for Cameron dual wellhead on long string, test to shut in tubing pressure. ? b. Rill with slickline assembly consisting of 2.8" aD gauge ring ( confirm gauge ring has larger OD than 3.5 "9.3 ppfCIBP) , stem, spang jars, oil jars, knuckle joint, stem, knuckle joint, stem, rope socket. Tag fill and POOH. c. RD off long string and RU on short string. RIH with same assembly from previous run and tag tubing swage at 5617', POOH. MU 2.3 gauge ring ( confirm gauge ring has larger OD than 2.875" 6.4 ppf CIBP to be run in next step.) and RIH to PBTD and record depth. d. Change over truck to run e-line equipment. RU on short string and RIH with 2.875 6.4 ppf CIBP on pressure setting tool, correlate to completion perforation record dated 2/24/2003 and set at 6040' MD. POOH. ~/ e. RU to long string, RIH with 3.5' 9.3 ppfCIBP on pressure setting tool, correlate depth with CML log dated September 14th 2000 and set at 6,210'. / f. Blow down both strings to flow back tank. Watch for pressure build over night. Ifno pressure is present RU vacuum truck with clean water and fill both long and short strings to surface. -'.<;1'.. 4. MIRU Pollard wireline service. a. PJSM b. Install BOPE and lubricator to crescent shaped Otis flange for Cameron dual wellhead on long string. c. MV dump bailer, Make Rill with dump bailer to confirm overall length of tool will make it to CIBP at 6,210'. If unable to get to bottom PU a smaller bailer and R T to plug. If round trip with dump bailer is successful, fill with BJ Services cement and RIH with dump bailer to plug. Dump cement and POOH. ....--- d. Repeat RIH and dumping of cement to establish at least 25' of cement (9.1 gallons in 3.5" OD 9.3 ppf casing) on CIBP plug, with 4 runs in hole. (a 2" ID /' bailer with 17' of vertical fill space will deliver 2.75 gallons per run and 7.5'in 3.5" casing). POOH. RD off of long string. e. RU to short string side of dual. MV dump bailer, Make RIH with dump bailer to confirm overall length of tool will make it to CIBP at 6,040'. If unable to get to bottom PU a smaller bailer and R T to plug. If round trip with dump bailer is successful, fill with BJ Services cement and RIH with dump bailer to plug. Dump cement and POOH. f. Repeat RIH and dumping of cement to establish at least 25' of cement (6.1 gallons in 2.875" OD 6.4 ppf casing) on CIBP plug, with 4 runs in hole. (a 1.75" ID bailer with 17' of vertical fill space will deliver 2.12 gallons per run and 8.75 feet in 2.875" casing). g. RDMO Pollard wire line service h. RU Haskel pressure testing trailer and test each string to 2500 psi. / 5. MIRU Expro Americas e-line unit. a. PJSM b. Install BOPE and lubricator to crescent shaped Otis flange for Cameron dual wellhead on short string. Test lubricator to 2500 psi. c. RIH with gauge ring sized to duplicate jet cutter and tag PBTD. (When cutting both strings ensure tubing is full of liquid and valves are closed at surface prior to cutting to ensure drilling mud on annulus does not V-tube up into tubing string, thereby sticking jet cutter.) /' d. Rill with jet cutter for 3 1/2" 9.2 ppfN-80 Buttress tubing. Cut tubing at 5,450', ".-' POOH. RD off short string. e. Install BOPE and lubricator to crescent shaped Otis flange for Cameron dual wellhead on long string, Rill with gauge ring sized to duplicate jet cutter and tag PBTD. POOH. / .,' f. Rill with jet cutter for 3 1/2" 9.2 ppfN-80 Buttress tubing, Cut tubing at 5450'. r" POOH. g. RDMO Expro Americas. 6. Monitor casing head and tree pressure for signs of mud V-tubing out of production annulus into production strings. Contact ABB Vetco wellhead representative, bleed off strings to flow back tank and top off with water. Set BPV in the long and short strings. (3" type "H" BPV is needed) 7. MIRV Glacier Drilling rig #1. ,v-'L a. Check for pressure below BPV. Remove BPV and install two-way check./' b. ND tree. Inspect and verify split dual hanger t threads are 3 1/2" EVE 8RD. (2 - 3Yl" EUE 8rd pup assemblies approx 22' long will be needed for landing joints.) (13 5/8 5M by II" 5M DSA is needed to NU 13 5/8" stack.) NU 13 5/8" 5M Weatherford BOPE equipped with duaI3Yl", 5M rams in upper ram cavity (Weatherford verified availability 2/20/2004), and test BOPE to 75/3000 psi:-Pull two way check. 8. Rig up Weatherford Tubing services with 3 Yl" dual slips, elevators and hydraulic tongs. a. Circulate fresh water down tubing strings at maximum rate and maximum pressure of 2500 psi. Take returns out the casing head valves to the pits, annular volume is 284 bbls, PV on each string checking to see if string is free, (Maximum pull on one 3.5" EVE 8rd string is 202K lbs, an 80% value is 162K). Two chemical injection lines are banded to tubing strings to a depth of978'. RU wooden spool on floor for winding up chemical injection lines. b. If tubing is free TOOH laYing down dual tubing strings as junk while checking /'.. every 10 joints for NORM. Visually inspect tubing for corrosion and take samples of deposits on/in tubing, send in to BJ for analysis. c. If tubing strings will not circulate and are not free, RV APRS and free point both strings. Cut tubing strings with one string 10 feet higher (Consult fishing hand for tubing length needed) than the other to allow fishing tools to latch higher string. TOOH laYing down tubing. d. Close blind rams and pressure test casing to 2500 psi. If casing does not test a /" packer run will be made to isolate leaks in casing. Monitor 9 5/8 by 13 3/8" annulus for pressure during test or open and check for flow if possible. Change out dual rams for 2.875 - 5.5 VBR rams. Set test plug and test BOPE. e. Rill with fishing assembly as per Baker fishing hand recommendation on 4" HT- 38 drill pipe, jar on 3.5" production string and POOH, if tubing does not pull free, release overshot, POOH. Depending on the amount of pipe left to recover, a mill run may be made to deepen to 5420' MD. Remainder of procedure anticipates tubing is recovered to below 5406'. 9. RIH with 8.5" bit and casing scraper on 4" HT -38 drill pipe to top of cut off dual tubing strings. Circulate well clean with fresh water and then fill well bore with 6% KCL. 10. RV Reeves Wire line. a. RIH with acoustic CBL and density Neutron porosity tool string., correlate to open hole gamma ray from original completion. b. Send data into David Brimberry for analysis. c. RDMO Reeves. 11. IF CBL shows poor bond a remedial squeeze job may be performed. Consult Anchorage office for details. RIH with 4" HT -38 drill pipe to PBTD. POOH laYing down drill pipe. Layout, drift, tally and strap 5700' of 4 Y2 " 12.6 ppfIBT tubing. 12. RU Expro Americas wire line unit. a. Depending on PBTD a 9 5/8" CIBP may be run on e-line and set below bottom of anticipated perf interval of 5,406' MD. /' b. RU BOT 9 5/8" Model D Packer with 10 seal bore extension, crossover to 4 Yl" IBT, 10' 4 Yl" IBT pup joint, 4 Yl" 3.812 X-nipple, 10' 4 Yl" IBT pup joint and wire line re-entry guide. c. RIH and correlate to Reeves CBL ran previously. Set Model D packer with wire line re-entry guide 50' above anticipated top perforation of 5,352'.r' 13. RU Weatherford Tubing services to MU 4 Y2' IBT tubing. a. RU Weatherford. b. RIH with Baker Model D seal assembly. ,r' c. When 1500' is left to run RU Pollard to install methanol injection line to methanol inj ection nipple. d. Establish PU and SO weights when approaching packer depth. Tag packer and circulate down tubing to check for seal insertion. Tag top of packer and PU to space out for hanger. Install hanger and methanol injection line on tubing. Land tubing with debris barrier spaced out in top of packer. e. Test annulus to 2000 psi with water. /' f. RD Weatherford and Pollard 14. Set BPV and nipple down BOPE. 15. NU bonnet and 4" 5M tree with master and secondary master. 16. Pull BPV, set two way check, PT to 2000 psi. 17. RDMO Glacier Rig # 1 18. Take off master valves and install CT hanger spool with side outlet and remainder of tree with master valves, flow cross, 3 1/8 5M gate valve and 3 1/8 5M SSV. Test tree to 2500 psi. Pull two way check. 19. RU BJ services to tree. a. RU CT with 4 1/16" 10M BOPE stack and 1.75" CT. b. PT BOPE to 2500Ø psi. ¡uG/i- c. MU BHA with no check valves to reverse circulate out 6% KCL. d. Rill to PBTD, reverse circulate out by pumping nitrogen down CT annulus. e. POOH, pressure up on wellbore to 40% drawdown and pressure up to 900 psi. (900 psi with a nitrogen gradient delivers 1080 psi at top perf interval of 4899 TVD) f. Rig down BJ Coiltech. 20. MI Expro Americas electric line unit. a. RU to 4 %' Otis tree cap. b. Pressure test lubricator and BOPE to 2500 psi. c. Open well and RIH to perforate U5 and U6 intervals selected after CBL logging. Anticipated intervals are U5 5352'-5370' MD, 18' (4899-4906 TVD) and U6 ...,.-' 5390'-5406' MD, 16' (4925-4940 TVD) 21. Open well to flowback tank to blow off nitrogen maintaining a minimum flowing tubing pressure of950 psi. When gas stream is methane flow to system monitoring for gas and water rates. 22. RU BJ Coiltech and Install CT velocity string based on production rates and pressures. /' Contacts: Work Phone Pa2er Drilling Will Tank 564-6310 268-4374 Operations Don Eynon 283-1337 398-9954 Geologist David Brimberry 564-6402 Reservoir Eng Denise Titus 564-6303 394-2733 ( ( Alaska Business Unit ~ Domestic Production M lV!arathon P.O. Box 196168 MARATHON 0.1 Company Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 22, 2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 33-6L Dear Mr. Aubert: Enclosed is the WELL COMPEL TION OR RECOMPLETION REPORT AND LOG form, wellbore schematic, and daily operations summary for Marathon well KBU 33-6L. The work completed included setting a bridge plug above the existing Tyonek zone and perforating the long string in the Middle Beluga. This work was completed February 25, 2003. If you need any additional information, I can be reached at 907-283-1333 or bye-mail at dmtitus @ marathonoil.com. Sinr'~ Den ise M. Titus Production Engineer RECEIVED JAN 2 7 2004 Alaska Oil & Gas Cons. Commission Anchorage @«;'~Ä\~[~EK> IFEB ~ 3 2004 ( (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well olLD GASŒ] SUSPENDEDD ABANDONEDD SERVICED 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 99-24 3. Address 8. API Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20487 4. Location of Well at Surface 9. Unit or Lease Name 37' FNL & 4068' FWL, Sec. 7, T4N, R11W, SM Kenai Tyonek Unit At top of Producing Interval Plug Set Above Tyonek Zone 10. Well Number . . ,KBU 33-61 At Total Depth Perforate In Middle Beluga' 11. Field and Pool 2243' FSL & 2911' FWL, Sec. 6, T4N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kenai Gas FieldfTyonek 87' KB above MSL A-028142 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 16. No. of Completions 4/28/2000 5/20/2000 2/23/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 8,110' 6.378' YesDNo IKJ N/A 22. Type Electric or Other Logs Run Correlating/Perforating Log 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133 K-55 0 115 Driven Driven N/ A 13-3/8" 68 L-80 0 1568 17-1/2" 600 sks N/A 9-5/8" 40 L-80 0 5810 12-1/4" 570 sks N/A 3-1/2" & 2-7/8" 9.3 & 6.5 L-80 0 8087 8-1/2" 339 sks N/A 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) TVD N/A M12: 6252'-6269' MD 5748'-5764' 2" 2006 PJ, HMX, 4spf, 0 deg phase M13: 6296'-6331' MD 5790'-5824' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2" 2006 PJ, HMX, 4spf, 0 deg phase DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/ A flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/26/2003 24 TEST PERIOD ~ 0 0 0 N/A Flow Tubing Pres. Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) 750psi 0 24-HOUR RATE~ 0 0 0 N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core RE C E I VE, [) N/A JAN 2 7 2004 0 Q , G-1 ' ~ I ,~ , Alaska Oil & Gas Cons. Cmmnissícm . \ l .) ~ , " Anchorage Form 10-407 Submit in Triplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE / ltt R90Ms ~t FE80;2 ..'. N:\drlg\kgf\wells\KBU33-6\AOGCC02a Beluga recompletlon 10-407 .xls . ( ( 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Middle Beluga 5750' 5290' RFT data submitted RECEIVED JAN 2 7 2004 Alaska Oil & Gas Cons. Commission 'þ,¡)^u.:horal'Jl? 31. LIST OF ATTACHMENTS Daily operations summary, well bore schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Denise Titus Title Production Engineer Date 1/22/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg\sterling\su32-9\AOGCC02a Beluga recompletion 10-407.xls r'ì ~¡ r /'"'"'\ , " , A' I.; ( ( Dailv Summary for KENAI BELUGA UNIT 33-6 Report Report Summary Date Number """"""''''''''''''''''01''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''""''''''''''''''''''''''''''''''''''''''''''''''''''.'''''''''''''''''''''''''''''''''''''''''''''''''''........"..""...""'.."'.................""."......"""""...."...."'"...,,"'............,,......u........"""'"......",,,,,..,,,,,...,,,,.........,,.. 2003 Recompletion Event: 19-Feb-03 1 L CT Rigged up and ready to BOP/pressure test in AM 20-Feb-03 2-L Well jetted until no further returns. Strap shows 14bbl recovery (18bbl anticipated). Apply 2500psi N2 cap on well in preparation for setting plug with wireline. RD from long string. 20-Feb-03 2-S NU BOPs on short string. Pressure/function test BOPs to 250/3000psi. Rig back injector head. SDFN 21-Feb-03 3-S Short string clear of fill and water to 6400' CTM. Well left with 2500psi N2 cap. 22-Feb-03 4-S RIH in short string with gauge ring. Tag high at 6288'. SDFN. Correlation will require gun gamma ray which will be in use. 23-Feb-03 5-L Set bridge plug at 6378'. Perforated M12 (6252'-6269') " and M13 (6296'-6331 ') in long string from with 2in, 2006 Power Jet, HMX, 4spf, Odeg phase. Pwh=900psi 24-Feb-03 6-S Perforated M6 (6088'-6104') in short string from with 2in, 2006 Power Jet, HMX, 4spf, Odeg phase. Pwh=400psi Printed - 1/22/2004 ( KBU 33-6 ( ~N\) Pad 41-7 DUDO. J l API: 50-133-20487 \20",133#, K-55 Drive Pipe @ 115' I RT-GL: 21.6' 13-3/8",68#, L-80 BTC Casing @ 1568' RT-THF: 17.6' Cmt w/ 600 sx of Class G 37' FNL, 4068' FWL Halliburton Safety Valve Landing Nipples Sec 6, T4N, R11W, S.M. w/ sliding sleeves (requires BXL keys) & 1/4", 0.049 wt control line Tree cxns: 3-1/2" 8rd Model # 721XX028101 X-nipple profiles (ID=2.813") SS @ 911' (opened 6/9/00) LS @ 978' (opened 6/9/00) Note: "Longstring" refers to the 9-5/8",40#, L-80, BTC casing @5810' non-tapered, 3-1/2" string. Cmt w/ 570 sx of Class G "Shortstring" refers to the tapered 2-7/8" x 3-1/2" side. The terms "short" and "Iong" are only used for convenience, Current Completion: since both strings are actually Shortstring-Beluaa M6 run to the same depth. 6088'-6104' (4spf, 0°, 2/24/03) CIBP @ 6250' Tubing Detail Lonastrina: 3-1/2",9.3 ppf, L-80, EUE Lonastring-Beluaa M12 & M13 8rd-M w/ SCC @ 8088' 6252'-6269' (4spf, 0°, 2/23/03) Shortstrina: 3-1/2" x 2-7/8" taper to 8087' 6296'-6331' (4spf, 00, 2/23/03) 0'-5617': 3-1/2", 9.3ppf, L-80 EUE 8rd-M ~ CIBP @ 6378' w/SCC 5617'-8087': 2-7/8", 6.5ppf, L-80, EUE 8rd-M w/ SCC Historic Info: Long string perfs- Tyonek 73-1 7941'-7951' (3 spf, 7/6/00) 7960'-7970' (3 spf, 7/6/00) 8hortstring Perfs-Beluga M14, M15 Note: Tubing is kinked in 6387'-6410' (4 spf, Odeg, 7/00) both strings @ 6410' 6426'-6442' (4 spf, Odeg, 7/00) 6446'-6460' (4 spf, Odeg, 7/00) 6464'-6471' (4 spf, Odeg, 7/00) 6476'-6482' (4 spf, Odeg, 7/00) 6486'-6490' (4 spf, Odeg, 7/00) PBTD (L8)=8055' PBTD (88)=8056' TD=8110' Well Name & Number: KBU 33-6 r Lease 1 County or Parish: Kenai Pen Bourough State/Provo 1 AK Country: I USA Angle/Perfs Angle @KOP and Depth KOP TVD 1 BHP: BHT: Completion Fluid: T FWHP: FBHP: 1 FWHT: I I FBHT: I Other: 1 Date Completed: RKB: I Prepared By: DMT I Last Revision Date: 06/04/031 ( ~ MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from SOIne of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X-06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177-029 KEU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-179 KBU 44-06 ~~CÞ~il~!\NHEli) ~Jg~~~ ~ ~ 2004 Permitto Drill 1990240 DATA SUBMITTAL COMPLIANCE REPORT 713112003 Well Name/No. KENAI BELUGA UNIT 33-06 Operator MARATHON OIL CO APl No. 50-133-20487-00-00 MD 8110 ,--- TVD 7564 Completion Dat 7~6~2000 ~--- Completion Statu 2-GAS Current Status 2-GAS UIC N REQUIRED INFORMATION Mud Log N__9 Sample N._9 Directional Survey N._9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments L L GR/CCL 5 FINAL 5000 7946 CH 8/3/2000 L L GR/CCL 5 FINAL 5000 7595 CH 8/3/2000 L L COMP RCD 5 FINAL 7800 7944 CH 8/3/2000 ,-L'''~ "E'~'''" -..COMP RCD ?J ~,('~' I-3(3"."5 FINAL 6280 6540 CH 8/3/2000 --L"' ~'"' -'P"Ex-cMR/GR 6 FINAL 5810 8066 OH 7/14/2000 ~ _-L---~' --~T 5 FINAL 3396 8031 OH 7/14/2000 .., L--'" ~'1~. f(~PIT 6 FI NAL 5800 8042 OH 7/14/2000 .-I.''~''' ~ ~/NGT 2/5 FINAL 3396 8090 OH 7/14/2000 L L PEX-GR/CAL 2/5 FINAL 5810 8088 OH 7/14/2000 ...E"""'" ,,.lc' .... -fl~X-AIT/GR/CAL 2/5 FINAL 5810 8098 OH 7/14/2000 E" .... ,,,,E~'''''' 'f~GR FINAL 5800 7836 OH 7/14/2000 L L TDTP 5 FINAL 6400 10714 CH 4/10/2000 · .L~ "E'" .......SCMT/PSP 5000 7972 1/9/2001 ~P~ ....... ~I3, .... .,,,,,,F'iffal Well Report FINAL CH 1/5/2001 -,R" ...... ~,~.- ~,,SRvY CALC 155 8110 OH 8/29/2000 5000-7946 5000-7595 7800-7944 6280-6540 5810-8066 3396-8031 5810-8088 5800-8042 3396-8090 5810-8088 5810-8098 5800-7836 6400-10714 5000-7972 Print Final Well Report BHI 155-8110 4/28/00 THRU Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Cuttings 5810 8110 [ O ~ (o ADDITIONAL INFORMATION Permitto Drill 1990240 MD 8110 TVD 7564 Well Cored? Y 1~ Chips Received? -Yw' N J Analysis '~Y / N R P.c.P. ivP. d ? DATA SUBMITTAL COMPLIANCE REPORT 7/3112003 Well Name/No. KENAI BELUGA UNIT 33-06 Operator MARATHON OIL CO Completion Dat 7/6/2000 Completion Statu 2-GAS Daily History Received? Formation Tops Current Status APl No. 50-133-20487-00-00 2-GAS UIC N Comments: Compliance Reviewed By: ........ Date: Marathon OilCompany Alaska Business Unit Domes(t¢ Product;on P.O, Box 19616l] Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907t564-6489 February 17, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7'th Ave Anchorage, Alaska 99501 Reference: KBU 33-6S Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form, wellbore sci~ematic, and operations procedure for Marathon well KBU 33-6S. The proposed work is to set a bridge plug above the existing Lower Beluga zone and recomplete the short string in tile Middle Beluga. if you need any additional information, i can be reached at 907-283,1333 or by e-mail at' dmtitus@marathonoil.com. Sincerely, Denise M. Titus Production Engineer gO 'ti CiLI9 88g LO6 'ON ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type et Reque¢,: Abandon .~X Suspend__ Operation Shutdown __ Re-enter Suspended Well Alter Casing __ Repair Well__ Plugging__ Time Extension__ Stimulate Change Approved Program ~ Pull Tublng__ Variance__ Pelforatc ..~ Other 2, Name of Operator MARATHON O~L COMPANY 3, Address P. O, Box 196168, Ancl~orage, AK 9~951~"6168 4. Location of W~ll at Suda~ J ,J ~ 37' FNL & 4068' FWL, Sec. 7, T4N, RllW, SM At top o1' Productive Interval 1925' FSL & 3410' FWL, Soc. 6, T4N, R1 lW, S.M, At Ell'active Depth At Total Depth 2243' F@L & 2911' FWL, Sr.,e, 6, T4N, R11W, S.M, 5. Type or Well: Developmm 4,_X_,X Exploratory ~ Stratfgraphic,..__ Service Set Plug Above Lower Beluga and Perforate Middle Beluga 6, Datum Elevation (DF or KB) 87' KB above MSL feel ?. Unit or Property Narne Kenal Beluga Unit 8. Well Number KBU 33,6S 9. Permit .N.J,kl~ber 99-24 10. AP] Number 50-133-20487 ~--~.~,~--.,,w,..~,..~.~.,.,..----~, . 1, .---- 1 I. Fiold/Puol Konai Gas FieldtB¢lU(.ta 12. Present Well Condition Summary Total Depth: n'toasure¢ [rue vel tlcal 8110 feet 7565 feet Effective DopLh; measured true vertical 7594 feeL Cement PBTD 7057 fe~t Casing SLruclural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 115 1568 5810 Size Cemented Measured Depth True Verticql D,~ptl~ 20" Driven 115 115 13-3/8" 600 sks 1568 1541 9-5/8" 570 sks 5810 5329 6387-6410', 6426-6442', 6446-6471', 6464-6471', 6476-6482', 6486-6490' true ve~¢cal 5883-590~', 5921-5936', 5940-5954', 5957-5964', 5967,,5974', 5979-5983' Tubing (siz0, grade, and measured depth) 5617' of 3-1/2", 9.2 ppi, L-,80 plus 2439' of 2.,7/8", 6.5 ppi, L-80 tO 8056' MD 1 7511' 'i'VD Packers and SSSV (type and measured depth) N/A 13, Attachments Description Summary of Proposal..,~X.. Detailed Operations' Program__ BOP Sketch ...... 14, Estimated Date for Commencing Operation 2/2112003 1~1, If Proposal was Verbally Approved Name of Approver Date Approved 15. Status or Well C~assifi~ioll as; Oil~ Gas,_X__X Suspended 17. I hereby cerl,ry ti'mt tho foregoing is true .and correct to the best of my knowledge. Signed ~ Denise Titu~ Title Production Engineer Date 2/'17/2u[)3 FOR COMMISSION USE ONLY Conditions el: Approval: Notify Commission so representative may witness '.~~,~ ~ ~,,,,'%¢,x',r,.,,~,~ ~[3"~ [Approval No, Plug Integrity BOP Test'~ Location Clearanc~ Mechanical Integrity Test__ ' Subsequent Form Required 10-~ .... Approved by Order of tl~e CommL~s~on Cortlmis~ioner run. 10 ~03 Rev 0G/15/00 RBBNS BFL . gO 'd q£I9 ggg LO6 'ON XVJ ANYdl,,IO0 "110 NOH,.Lk~7~t~I,,I I,,I¥ gg:O! NON gOOg-L[-fl3J K¢~ai Oas Field 5Veil KBU 33~6, Pad 41-7 Marathon Oil Co., Alaska Region Th, re, ntis "shnrt" ad "loa~" ~e only _I_,.o n.rl,~t'.rj~ - ?yo~.k 73-1 'f~Tl'"':':]951' (3 sr~f -600, I,a.~t Bt:',': _lGI3, 813/00 20", i3~, K45 Drbc pip~,.@ I[5 13-3/1'3", 6Bii-, I.,-P:,O, }3TC Ca~is~g '-0 lli6tl' C,'nt wi 600 i~.~ uf Ch',,:!~ 0 6446'., 64,60' (4 spf, 0% 'VI?Ii)O) 6464' 6¢?t' (4 si':,~', 0~, 717/00) 64,76'.- 64B2.' (4..sift, 0% 71'1/00) 6,~86'- 649(1' (~ ~!:~, ()~, 717100) Tag fil! (8$), ~"' ' a'D (715100) PBTD (L$) = P~TI) (85): B0S6' TD = BiI0' ' I.-80, BUg [lrtl..kt ~vl gCC C,O ,~,(1',i8' Sh ork,~b 3,.112" :x 2-7/~" t~xpcr @ 0'- 561% 3.112", 9,3l), LBO, EUI.~ 8rd-M ~vt 5617' BOB?', .,.-7/8,6.5,[', l.-gO, IiUF 8rd. M wl SCC 339 sks chtss ({ PO 'd _qLI9 88~ LO6 'ON X~J 'ANUdKO0 llO NOH£¥8¥bl blU ~g:OI NOIQ gOO3-LI-flHJ Marathon Oil Cmnpany Alaska Business Unit KBU 33-6L Kenai Gas Field, Pad 41-7 Add Middle Beluga Perforations WBS # TA.03.08288.EXP Ilislory: KBU 33-6 is a dual string monobore completion. Neither string has produced since early 2002, Invesfig:ttion has determined that both cemented strings were kinked at 6410' M D which makes intervention difficult or irnpossible. Long Strhtg: A recent run irt the long string with a 1.750" ID DD bailer slmwcd lhe tubing clear to 6410' WLM. FMd level was located at 4050' (2/12/03), Short &ri.g: A bridge was tagged at 2247' WLM (2/2/03). Slickline wOrke~t a 1.75" bailer but was unable ~o clear flU. Objective: Long String: Set aplug above the tubing kink to isolate the long string Tyonek pcrlbrations, Recomplete uphole with Middle Beluga MI2 and M13 perforations, Short &ring: Sot a plug above tho tubing kir~g to isolate Lower Beluga pol-fora~ions. R¢complete uphole.with Middle Beluga M6 perforations. Note: When bringing the well on, drawdown si~ould be closely co~trolled, The bend inlho tubing below lhese peris may be associated wJtl~ excess drawdown. Procedure: '1) RU CT on K.BU 33-6s. M[J wasl! nozzle and clear tubing to 6200', Fill was last tagged at 2245'. This is most likely a bridge, and others can be expected, 2) once fill is cleared, POOH jetting, Ensure short string is free °fwater and leave 2500psi nitrogen cap. Rig off of short string. 3) RU iajcetor head to long siring. Rill withjctting nozzle. Jet water from 4000' to 6400', Once returns are dry, POOH leaving a 2500psi nitrogen cap. RI)MO coiled lubing unit. 4) RU E-line on KBU 33-6 long string. Hold meeting witl~ production to make provisions for radio silence i~ needed. 90 'd qL[9 SE~E LO8 'ON ×~.q AN~dI400 llO NOH£gS~14 big ~g:0I NOI4,SOO~-L[-8.t.4 5) MU Bilker 035 N-2 wireline set CIBP with Baker 05 setting tool ami CCL. P, IIt anti sot plug '.above tubing obstruction at 6389' MI). 6) MU POT-C peri'oration orientation tool and test/calil.m~te at surface :~s needed using :~ 2- 7/8" x 3-1/2" tubing testing jig. Ensure wellhead pressure is corrcct tO acl~icve required drawdown. 7) R{I'I and correlate (Array Induction Tool log, 2 l-May-2000). Oricntale tool away fi'om short string and pcrlrorate the following zones with 2in, 2006 Power Jet, HMX, 4spI; 0deg phase guns. M12 6252'-6269' (17') M13 6296'-6331' (35') Max gun length is 10'. Six runs will be required. 8) Once lhe long siring is perforated, RI.) lubricator fi'om long string. RU onto slmrt stril~g. 9) MU Baker wircline set CiBP With Baker setting tool and CCI., for the short strit~g. RIH and set plug above tubing obstruction at 6389' MD, 10) MU POT-C perforation orientation tool and test/calibrate at surli~ce as needed using a. 2- 7/8" x 3-I/2" tubing testing jig, E~sur¢ wellhead pressure is correct to ~lchicvc required drawdown. 11) RIH and correlate (Array Induction Tool log, 21-May-2000). Orientate lool away Ii'om long slring and perforate thc following M6 zone with 2in, 2006 PowerJci, I'tMX, 4spl; 0deg phase guns, MO 6088'.6104' (16') Two runs will bc required. 12) Once completed, RDMO E-linc. Flow well per instruction of production engineer. 90 'd CiL'[9' 881~ LO6 'ON ×~.,-t ~N~dl,,IO0 "IIO NOHi,¥EI¥1,,I Marathon Alaska Business Unit Domestic Production P.O, Box 196168 Anchorage, AK 995'19-6168 Telephone 9071561.5311 Fax 9071564-6489 February 5, 2003 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: KBU 33-6L Dear Mr, Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form, wellbore schematic, and operations procedure for Marathon well KBU 33.-6L. The proposed work is to set a bridge plug above the existing Tyonek zone and recomplete the long string in the Middle Beluga. If you need any additional information, I can be reached at 907~283-1333 or by e-mail at dmtitus@marathonoil.com. Sincerely, Denise M. Titus Production Engineer 9L[@ E:8;~ LO6 'ON ×Vi ANgdl400 qIO NOH£V~IgkI Nd [9:];0 (]:BM 8008-90-EI:B.4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend___ Opera[ion Shutdown __ Re-enter Suspended Well Alter Casing __ Repair Well__ Plugging ~ Time Extension__ Stimulate Change Approved Program PuU Tubing __ Variance__ Perforate X Other 2. Name of Operator MARATHON 01L COMPANY 3. Address P. O, Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface ,/ J' J 37' FNL & 4068' FWL., Sec, 7, T4N, R11W, SM 5. Type of Welh Development X Exploratory ~ Stratigmphic ~ Service At top of Productive Interval Set Plug Above Tyonek Zone ^, o,,m and Perforate Middle Beluga At Tolal Depth 22,48' FSL & 2911' FWL, Seo, 6, T4N, R11W, S,M, 12, Present Well Condition Summary Total Depth; measured true vertical 8110 feet 7565 feet EffectiVe Depth: measured true vertical 7965 feet Cement PBTD 7442 feet Casing S[ruclu~al Surf~r,e Intermediale Production Liner Perforation Depth', measured LengU~ 115 6. Datum Elevation (DF or KB) 87' K[3 above MSL feet 7, Unit or Prop..rty Name Kenai ']'yonek Unil 8. Well Nun~ber KBU 33-61 9. Permit Number 99.24 x,/' lO. APl Number 50-133, 20487 :11, Fiolfl/P"o"~- Kenai Gas FieldlTyonek $i;,;e Cemented Measured Depth True Vortical De~,th 20" Driven 1 I5 115 1568 13-3/8" 600 sks t 508 5810 9-518" 570 sks 58 I0 8088 3,-1/2" 339 sks 8088 7941'-7951',7960'-7970' true verUcal 7398'-7408', 7417'-7427' Tubing (size, grade, and mea~.ured depth) 8088' of $-1/2", 9.2 ppf, L-80 Packers and SSSV (type and measured depth) N/A 1541 5329 :":: .' '.' ':,';, l~' ~ '- 13, Attachments Oescription 8umm:.-,ry of' Proposal ~ 0etailed Operations Program BOP 8ketch 14. Estimated Date for Cornmenclng Operation 2/21/2003 16, If Proposal was Verbally Approved Name of Approver Date Approved Status of Well Classification as; Oil Gas X Service Suspended .-- 17, I hereby certify that the foregoing is rue and correct to the best of my knowledge, FOR COMMISSION UgE ONLY Conditions of Approval: Notify Cornmissior~ So representative may wil. r',eSS I:-'lug In~eyrily~ BOP TesI~ Locatkm Clearance Mechanical Integrity Tes[~ Subsequent Form Req~:ed 10- ORIGINAL SIGNED BY Approved by Order of Ihe Commlssion M L Bill Dale 215/2Lx)3 E)al.c; _~J_~_~__~ .... St [Ur;fit In Tr~plicatu 10-403 Rev, 061151~i0 B!l 4S 'BFL ~0 'd 9L[9 ~ LO6 'ON XVJ ANgdI, IO0 'lIO 'gI')r 'F:) Idd iq: [0 ~.qM 800;3-qo-83J Marathon Oil Company Alaska Business Unit KBU 33-6IJ Kenai Gas Fields Pad 41-7 Perforating Procedure W lis # TA,03.08288,EXP Ilistory: KBU 33-6 is a dual string monoborc completion. Neither slrlng has produced since early 2002. Subsequent investigation has determined that botl~ cemented sMogs were kinked r~t 6410' MD which makes intervention di fi'icult or impossible, A recent run in the long string with a 1.750" ID DD bailer showed the tubing clear to 6410' WLM. Objective: Set a plug above tl~e tubing kink to isolate lhc long string Tyonck pcrlbrations. P, ecomplet uphole with Middle Beluga (M6, M12, and M13) perforations, Note: When bringing llae well on, drawdown should be closely controlled. The bend in tiaa lubing below these perfs may be associated with excess drawdown. Procedure: 1) RU E-line on KBU~33-6 long string, I/old mecdng with production to mt.~ke provisions for radio silence if needed. ~ 2) MU Baker 035 N-2 wireline set CIBP with B[~ker 05 setting tool and CCL. It. IH and set plug above tubing obstruction at 6400' MD. 3) MU POT-C perforation orientation tool and test/calibrate at surlhce as needed (MOC will provide 2-7/8" and 3-1/2" pup joints lbr calibrating), 4) RI[f and correlate. Orientate tool away from short string and perforate lite lbllowing zones with 2in, 2006 PowerJet, HMX, 4spl; 0deg phase guns. M6 6088'.6104' M126252'.6274' M136296'-6331' Max gun length is10', Eight runs will be required. 5) Once completed, RDMO E-line. Flow well per instruction of production cl~gineer. IxO 'd qLI9 8~ LO6 'ON ×¥:I ,x,N~dl400 'IlO NOH£¥kt¥I4 bld [~:[0 (I31'1 ~O0~-qO-Et3.q Kenai Gas Field Well KBU 33~, Pad 4!-7 Marathon Oil'Co,, Alaska Region .] nmi-t:rp,.,,rcd., 3-112" ~ring. t,m i'tt;v', ;lC;B, BII/00 '~,~'~IC'T~'$'["'"[~' ~pf,-z60% 7/6/00) '/960'- 79'~0' <3 spf, :t;~0°, '~2 slid~u g ~ke~es (rcquirc~ 13~I. 1/4", 0.04U" ~'r no:nmi tiuu Model ~72IXXO2B101 X-D. ippk profilcg (1D -~; 2,B~3") ~ 911' (ol~uvd 6/9100) 13.,$1B", d~,ft', ],.fi0," .... ~'> . ?BI'D (I,S): 8055' I~BT,I,) ISS) = tt0,56' '.cl.> ~ Sll0' ,°,-$/[1", -~e~'~.,~.~..~-._, .,~- ~., ~.%.~.,., .. ,,__..,..~-~,,,~,.~__,, ,. ~ ,~,~.., .~ / ~I'-'%~/'-'~,~ 6464 -6471'(4 6476' .- 6~2' (4. si)f, 0% 7/7/00) -' 64 ~6' {,4gO' (4 ~l>[, 0~, 7/1/00~ Tug fill cio 'd qL[9 ~93 LO6 'ON X~J AN¥c{I400 llO NOH£MHM~ Nc{ Iq'[o OHM Marathon Oil Company Kenai Gas Field PO Bo× 1949 Kenai, AK g9611-1949 Telephone (907) 283-1300 Fax (907) 283-6175 Fax Cover Sheet DATE: ......... ~/~'/_~ TIMF'__ TO: NAME: FROM: PHONE: ....... .tvA FAX:~,9.,OZ~28~5_ RECEIVED PAGES SENT (Including Cover Sheet) ........... .~ [ ] Response Requested [ ] Immediate [ ] Information Only REMARKS: c I~,, p.(~, ~, ~.~.,! ~~_~.~~ ....... .~_/~_~.,~_=~, ..... ............................. ~,.~ ............ ~,__,.L~ ....... ~___&~ ....... ~ ~....~,,,~ ....... (~....~ .... ¢¢..,,,.,,./ ..................... ~ ;~~, ..... ~_~z_~~.c& ........ ¢.ra_~ ..... ~, ........... ~ ....................................................... ..................................................... ......... .......................................................... [0 'd CiL[9 ~:8;~ LO6 'ON ×VJ ,', ..... il ,,~r ~ ~ ANVctI,IO0 ~lIO NOH£~tV~ Nd Iq' [0 (I~1 SOOg-cio-a~J ¢.. 03:36pm From-~ARATHON OIL {' +9155646489 T-155 P.02/03 F-131 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request'. Abandon Suspend~ Operation Shu~own Re-enter Suspended Well~ Alter Casing ~ Repair Well__ Plugging Time F_xtensior~ Stimulate__ Change Approved Program Pull Tubing Variance Perforate Other X z. N'ame of Operator 5. Type'of Well: - 6, D~tum Elevation [DF o~ MARATHON OIL COMPANY Development...~_X 87' KB above MSL feet ,., 3. Address Exploratory_ 7, Unit or Property Name P. O. Box 196168, Anc..horege, AK 99519-.6.1s8 Stratigraphic~ . Kenal Beluga Unit 4. Location of Well et $urface Service . s. Well Number 87' FNL & 4068' FWL, Sec. 7, T4N, R11W. SM KBU 83-6a At ~op of Productive Interval 9, Permit. Number 1925' FSL & 3410' FWL, See, 6, T4N, RI 1W, S.M. ~~'~i~'~ ...... At Effective Depth (C .... J 10, APl Nu~l~er oil Tubing San'd Wash AtTotal Depth ...... -... '.... 11. FieldJPool 2243' FSL & :~911' F,.WL, Seo. 6, T4N, R11W, S.M. Kenai Gas l=ieldlBe, luga -_ 13. Pre~ent Well condition Summary Total Depth; measured 81 lO feet true vertical 7666 feet Effective Depth; measured 7594 feet Cement PBTD true vertical 7067 feet Caeing Length Size Cemented Measured Depth True Vedi~',al Depth Rtruotural 115 20" Driven 115 11 ~ Conductor S U rf~ce 156 Es 13-8/8' 600 ~k ~ 15B8 I L~4 Intermediate 5810 @-~/B' 570 sks $810 F~329 Production Liner Perforation Depth; measured 6387.6410', 6426-6442', 6446-6471', 6464-647t', 6476-6482', 6486-6490' true vertloal 5883-§90~', 6~21-5936', 5940-$954', 5957-S964', 5957-5974', §979.~9~3' Tubing (size, grade, end measured depth) s617' of 3.1/2", 9,2 ppf, L-80 plus 2439' of 2-?/8", 6,5 ppf, L-a0 to 8066' MD / 7511' TVD P~ckers and $$$V (type and measured depth) N/A 13'i' Attachmente ..... Desc'~i'~tlon summary ;f Proposal_~X ...... Detailed Operations Progr'~'m.__ - ,BOP'Sketch .---- 1~. Estimated Date for commencing Operation ..... ~s. Status of W~II Classifi(ation as: 9/10t2001 la, if Prpj~c~.r.~l was Verbally A. pproved .... Od._. Gas.~X Suspended..._ Date Approved Service $igne_d % ~.~~ ~'{~1~ . ,, Gary Eljer Title Production Engineer ?,ate . 9.!.?'..2_00t__.~ r ~ V ~1'~0 R cOMMISSION USE~NLY- '~onditi~'~'s Apprava'l: hl¢ify..fy.~o" mmis.~ion~'; So representative m~y witness ' %(}(._~I~ %t:: ['~(~'~''~...~..~ Mechanical Integrity Test_~. Subsequent Form Required I O."-~.L.[.(~)~L-~_~ ApptoYed by Order of the Co~isslol'l ........ Commissioner DAte J, hi, Heusser RECEIVED ORIGINAL SEP 6 2001, Anchorage 03:3?pm From-MARATHON OIL +9155646489 T-155 P.03/03 F-1~1 Well KBU 33-6s Coil Tubing Sand Wash AFE 0491201 _.Purpose: Wash fill from the KBU 33-6s Beluga Sand completion to return to production. Procedure: MIRU I~A'' coil tubing and nitrogen on KBU 33-6s. RU choke manifold and flowback iron. Load tank with 500-bbl of 3% KC1. Test BOPE to 3000 psi. Hold safety and operations meeting. 2. Wash sand to __.6600' with 3% KCI. Note: Be aware of the crossover from 3V2" to 2',,'8" tubing at 5617', and be aware of the "tight spot" at 6429'. Circulate clean. , , . , 3. Jet with nitrogen to purge tubing. Unload to an atmospheric tank until adequately cleaned up. Produce as per instructions of Production Engineer. IGE - September 6, 2001 RECEIVED SEP 62001 Alaska Oil & (las Cons. [;~naus~]ot Anchora43e S e p,-.O 6-01 03:~6pm F rom-MARATHON O I L P.01/03 F-191 Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: ,-- Company: Fax No.: Number of Pages (including cover page)', FROM: N ' Location/Exten~i°n:. ~-'~.-. ~ \~. Fax No* 907/564-6489 -. - ~. "',. .... . ...... - .-= , ....... ._ · .., · NOTE: E D A sub~idiaw 0f USX Corpormion EnvironmentalJ~a~?e for the long run, SEP 6 200~ Alaska Oil & Gas Coos. Anehoraoe RECEIVED SEP 62001 ~ka Oil & Ga~ Con~. Anchorage WELL KU 24-7 WELL SCHEMATIC CASING &: ABANDONMENT DETAIL I. Rotary Ta~t~ 0 0.0' I1. Cameron 3-1/2" Duul Tbg Hanger ¢J 27.68* 111. 20" 941{/ H-40 Drive Pipe O 178' IV. 13-$/8" 61f~ K-55 Casing O 2003' V. E.T.D. ~ /.878' TOFO 4848'(3D' of Tbg.) ~. 9-5/8" 43.5~ & ~,7J N-80 Csg ~ 5801' TUBING ,,DETAIL, £ON~ ..S~.!Ng;.. 3- ~/2 ,9,2~ ~-aO 77JBIN¢ 2. Baker M~det "A-5" Du~I P~cker ~ 4312.79' 2 B 3. BI~ Joints From ~385.29' to ~581.52' 4. Otis "~" Sliding Sleeve 5. L~cator Sub ~ 46~.12' 6. Top of 13.72' Seol ~sembly ~ 4678.00' A- 1 0 ~ ~% 7. Medet "S-2" Pro~..Packer ~ 4679' $ond ~ 8. OUs "X" Nipple ~ 4691.72' 3 9. ~69&' Cut ~g on 7/28/88 A- t 1 ~ ~HORT ~/Ng: ~- 1/2" 9:2~ N--80 TUB/NC Sand ----- A. Otis "XA" Sliding Sleeve ¢~ 4267.57' ~?~-~:3:. 'Z.'~" B. Baker Model "A-5" Dual Packer ¢~ 4;3;14.93' C. Otis ~ Nipple = ¢325.~4' ~'~_,'3; ~.-3%'*, ~,-o~ Z.~%"~ S,7 PERFORATION RECORD B--2 ~ 5/27/82 4890'-4905' B-~ Sd. Sqz'd 7/88 S~nd ~ 5/28/82 4905'-4925' B-4 Sd. Sqz'd 7/BB em ~. 5/29/82 4410'--~90' A-lO Sd. PrecluSion V -' - .... 5/30/82 4525'-4560' A--11 Sd P~uction E--4_-- 5/30/82 44t0'-4490' Repe~ora~e A-lO Sd. Sand_ ~ 7/88 4696-~708' B-~ Sd. Production Sqz'~~~. , ~ ~hecked b~ N~ Dra~:ID--I~--8B ~ Zll-J ZO/ZO'd ~l-1 68Y9~16+ llO NOHIV~V~-mo~J md§~:~l [O-90-de$ g:\cmn\ddg\kgl~wells\ku 11-8s~AOGCC03a.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 5. Type of Well: Development x Exploratory Stratigraphic Service 2327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. At top of Productive Interval 137' FNL, 2401' FEL, Sec. 15, T5N, R10W, S.M. at 9440' MD At Effective Depth I Coil Tubing Sand Wash At Total Depth 1080' FNL, 1049' FEL, Sec. 15, T5N, R10W, S.M. 6. Datum Elevation (DF or KB) 87' KB above MSL feet 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 33-6s 9. Permit Number 99-24 10. APl Number 50-133-20487 11. Field/Pool Kenai Gas Field/Beluga 12. Present Well Condition Summary Total Depth: measured true vertical 8110 feet 7565 feet Effective Depth: measured true vertical 7594 feet Cement PBTD 7057 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 115 1568 5810 Size Cemented Measured Depth True Vertical Depth 20" Driven 115 115 13-3/8" 600 sks 1568 1541 9-5/8" 570 sks 5810 5329 6387-6410', 6426-6442', 6446-6471', 6464-6471', 6476-6482', 6486-6490' true vertical 5883-5905', 5921-5936', 5940-5954', 5957-5964', 5967-5974', 5979-5983' Tubing (size, grade, and measured depth) 5617' of 3-1/2", 9.2 ppf, L-80 plus 2439' of 2-7/8", 6.5 ppf, L-80 to 8056' MD ! 7511' TVD Packers and SSSV (type and measured depth) N/A RECEIVED 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure 14. OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Prior to Well Operation 0 0 0 0 Subsequent to Operation 0 2200 1 0 Tubing Pressure 2150 (SI) 1850 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operatiorts X Oil ~'~.~ Gas x Suspended 17. I hereby certi~hat the foregoir~ is true and correct to the best of my knowledge. Sig ned--~ ~\ ~ _'~.,~ J.Gary Eller Title Production Engineer Form 10-404 Rev. 06/15/88~ ,_,~ ORI61NAL Service Date 05/15/01 Submit in Duplicate 010423,XLS MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 4/23/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: AFE 9207301 4900' FIELD: Kenai Gas Field TUBING: N/A Clean out fill, jet WELL # KBU 33-6s CASING: 3.5", 9.3#, N-80 TREE CONDITION: good BENCHES OPEN: Beluga M-14/15 SUMMARY OF OPERATIONS 04/19/01 & 4/20/01 RU diffuser tank, flowback iron, choke manifold, and 1-3/4" BJ coil tubing unit and nitrogen pump onto well KBU 33-6s. Blend 400 bbl of 3% KCI. Pressure test BOPE and flowback iron to 250/3000 psi. Blow reel dry, SDFN. 4/23/01 Change out damaged stripper rubber, and retest to 3000 psi. SITP = 1300 psi. Bled off tubing pressure to diffuser tank, but well would not bleed off. Begain circulating 3% KCI at 0.5 bpm while RIH with coil tubing. Having some difficulty killing well, but eventually kill well and established full circulation. Did not tag up fill at 4900' or at any other time during the remainder of the wash procedure. Also, did not have any difficulty getting past the "tight spot" in the tubing Qt 6429'. Indications of partial lost returns after washing past the perfs. Begin pumping nitrogen at 300 SCFM while continuing to pump 3% KCI at 1 bpm. Continue to wash to 7400'. Increase nitrogen rate to 500 SCFM to unload the well. When the well is coming around, reduce gas rate to 300 SCFM and POOH. When OOH, shut off the nitrogen, close the crown valve, bleed off lubricator, and RD injector head. Continue to flow the well the entire time. Flow well to diffuser tank through 24/64" adjustable choke. FTP = 1250 psi. Having problems with debris and/or ice pplugging the choke. Well does not appear to be making much liquid. Shut-in well to change to a positive choke. Chunks of debris lodging in the chokes. Had about 1 hour of fighting it before able to get the well flowing through a 24/64" positive choke. Continue flowing well. Note; See attached hourly readings from flowing the well during the night. Vendor Equipment Daily Cost Cumulative Cost BJ coil tubing & nitrogen $60,000 $60,000 Veco crane $10,000 $10,000 R&K vac truck $3,600 $3,600 M-I KCl $1,344 $1,344 Misc. $2,000 $2,000 Weatherford choke manifold $1,100 $1,100 DAILY COST: $78,044 CUM: $78,044 REPORTED BY: G. EIler STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:\drlg\kgflA3-6xrdXAOG CC03.xls~~ 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing __ Repair Well__ Plugging__ Change Approved Program Pull Tubing Variance Re-enter Suspended Well Time Extensior Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 37' FNL& 4068' FWL, Sec. 7, T4N, R11W, SM At top of Productive Interval 1925' FSL& 3410' FWL, Sec. 6, T4N, R11W, S.M. At Effective Depth I Coil Tubing Sand Wash At Total Depth 2243' FSL & 2911' FWL, Sec. 6, T4N, R1 lW, S.M. 5. Type of Well: Development X Exploratow.__ Stratigraphic Service 6. Datum Elevation (DF or KB) 87' KB above MSL feet 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 33-6s 9. Permit Number 99-24 10. APl Number 50-133-20487 11. Field/Pool Kenai Gas Field/Beluga 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measu red true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 115 8110 feet 7565 feet 7594 7057 feet Cement PBTD feet Size Cemented 20" Driven 1568 13-3/8" 600 sks 5810 9-5/8" 570 sks RECEIVED APR 10 2.001 Measured Depth True Vertica Depth 115 115 1568 1541 5810 5329 6387-6410', 6426-6442', 6446-6471', 6464-6471' 6476-6482', 6486-6490' true vertical 5883-5905', 5921-5936', 5940-5954', 5957-5964', 5967-5974', 5979-5983' Tubing (size, grade, and measured depth) 5617' of 3-1/2", 9.2 ppf, L-80 plus 2439' of 2-7/8", 6.5 ppf, L-80 to 8056' MD / 7511' TVD Packers and SSSV (type and measured depth) N/A 13. Attaohments Description Summary of Proposal X Detailed Operations Program BOP Sketch 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 4/12/2001 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby c ~'~ that the for,.._~ing is true and correct to the best of my knowledge. Signed ¥'~~ ~,~,.,,,, Gary Eller Title Production Engineer - - ' FOR COMMISSION USE ONLY Conditions of Approval: '~No. tify Commission so representative may witness Suspended Date 4/6/2001 Plug Integrity Mechanical Integrity Test Approved by Order of the Commission Form 10-408 Rev. 06/15/88 BOP Test.~ Location Clearance Subsequent Form Required 10- ORIGINAL SIGNED D Taylor SeamolJn~ IAppr°val N°', Commissioner Date Su~mit in"f'riplicate Ferm 3160-5 (,June 1990) UNI ,'IF-~ STATES SuBMiT ~N DEPARTMEI~ .~F THE INTERIOR TRIPLICATE* BUREAU OF LAND MANAGEMEN'i' (Other instructions on reverse side) SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals. SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas I~ Well I~] Well ~ Other 2. Name of Operato~ Marathon Oil Co. 3. Address and Telephone No. P.O. Box 196168, Anchorage, AK 99519, (907)561-5311 4. Location of Well (Footage, Sec., T., R., M., or Suvey Description) Surface: 37' FNL & 4068' FWL, Sec. 7, T4N, R1 lW, SM Interval: 1925' FSL & 3410' FWL, Sec. 6, T4N, R1 lW, S.M. TD: 2243' FSL & 2911' FWL, Sec. 6, T4N, R1 lW, S.M. FORM APPROVED '"' BUDGET BUREAU NO. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. A-028142 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Kenai Beluga Unit 891006367C 8. Well Name and No. KBU 33-6s 9. APl Well No. 50-133-20487 10. Field and Pool, or Exploratory Area Kenai Gas Field/Beluga Pool 11. County or Parish, State Kenai Peninsula, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION Notice of Intent Subsequent Report Final Abandonment Notice TYPE OF ACTION [~ Abandonment [~] Change of Plans [~] Recompletion r'~ New Construction [~ Plugging Back ~ Non-Routine Fracturing [~ Casing Repair [~ Water Shut-Off ~ Altering Casing [~] Conversion to Injection [~ Other Coil Tubing Sand Wash [~] Dispose Water (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* Marathon proposes to utilize coil tubing to wash sand and fill from KBU 33-6s to return it to production. SIGNED '%~ ~{~ (~k/'" Gary Eller TITLE Advanced Production Engineer DATE April 06, 2001 (This space for Federal. oi~State office use) APPROVED BY Conditions of approval, if any: TITLE DATE Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. *See Insstruction on Reverse Side O:\EXCEL\BLMSUND.XLS 6/96 Well KBU 33-6s Coil Tubing Sand Wash AFE 9207301 Purpose: Wash fill from the KBU 33-6s Beluga Sand completion to return to production. Procedure: , MIRU 13A'' coil tubing and nitrogen on KBU 33-6s. RU choke manifold and flowback iron. Load tank with 500-bbl of 3% KC1. Test BOPE to. 3000 psi. Hold safety and operations meeting. , Wash sand to _+6600' with 3% KC1, applying viscous sweeps as necessary to clean the hole. Note: Slickline tagged fill at +4100'. Be aware of the crossover from 3V2" to 2Y8" tubing at 5617', and be aware of the "tight spot" at 6429'. Circulate clean. 3. Jet with nitrogen to purge tubing. Unload to an atmospheric tank until adequately cleaned up. Produce as per instructions of Production Engineer. JGE - April 6, 2001 {' Kenai Gas Field Well KBU 33-6, Pad 41-7 Marathon Oil Co., Alaska Region API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec. 6, T4N, RllW, S.M. Tree cxns = 3-1/2"', 8rd NOTE: "Longstring" refers to the non-tapered, 3-1/2" string. "Shortstring" refers to the tapered, 2-7/8" x 3-1/2" side. The terms "short" and "long" are only used for convenience, since both strings are actually run to the same depth. Longstring Perfs - Tyonek 73-1 79411- 7951' (3 spf, _60°, 7/6/00). ~.7960 - 7970' (3 spf, +60% 7/6/00) Tag fill (LS) - 7985' MD (7/6/00) Last Rev: JGE, 8/3/00 PBTD (LS) = 8055' PBTD (SS) = 8056' TD = 8110' 20", 133#, K-55 Drive pipe @ 115' Halliburton Safety Valve Landing Nipples w/sliding sleeves (requires BXL keys) & 1/4', 0.049" WT control line Model #721XXO28101 X-nipple profiles (ID = 2.813") SS @ 911' (opened 6/9/00) LS @ 978' (opened 6/9/00) 13-3/8", 68#, L-80, BTC Casing @ 1568' Cmt w/600 sks of Class G 9-5/8", 40#, L-80, BTC Casing @ 5810' Cmt w/570 sks of Class G Shortstring ,P, erfs - Beluga M 14 & M 15 '~ 6387'- 6410 (4 spf, 0% 7/7/00) 6426 - 6442' (4 spf, 0°, 7/7/00) 6446,- 6460' (4 spf, 0% 7/7/00) 6464,- 6471', (4 spf, 0% 7/7/00) 6476 - 6482 (4 spf, 0°, 7/7/00) 6486'- 6490' (4 spf, 0°, 7/7/00) Tag fill (SS)- 7~94~, MD'i~7'5./.0~) ~ ":~:"~-',' .~, :,?,~,~ ~,! ,:~,i:;¢ Longstring 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC @ 8088' Shortstring 3-1/2" x 2-7/8" taper @ 8087' 0'- 5617': 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC 5617'- 8087': 2-7/8", 6.5#, L-80, EUE 8rd-M w/SCC Cement Cemented with 339 sks class G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:\drlg~kgf',A3- 6xrd',AOG CC01 .xl~,~ 1. Type of Request: Abandon Alter Casing Change Approved Program Suspend Operation Shutdown Repair Well Plugging__ Pull Tubing Variance Re-enter Suspended Well Time Extensior Stimulate Perforate Other X 2. Name of Operator MARATHON OI I_ COMPANY Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 37' FNL& 4068' FWL, Sec. 7, T4N, R11W, SM At top of Productive Interval 5. Type of Well: Development.~_X Exploratory Stratigraphic Service At Effective Depth [Coil Tubing Sand Wash At Total Depth 2243' FSL & 2911' FWL, Sec. 6, T4N, R1 lW, S.M. 6. Datum Elevation (DF or KB) 87' KB above MSL feet 7. Unit or Property Name Kenai Tyonek Unit 8. Well Number KBU 33-61 9. Permit Number 99-24 10. APl Number 50-133-20487 11. Field/Pool Kenai Gas Field/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 8110 feet 7565 feet Effective Depth: measu red true vertical 7985 feet Cement PBTD 7442 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 115 Size Cemented Measured Depth True Vertical Depth 20" Driven 115 115 1568 13-3/8" 600 sks 5810 9-5/8" 570 sks 8088 3-1/2" 339 sks 7941'-7951',7960'-7970' true vertical 7398'-7408',7417'-7427' Tubing (size, grade, and measured depth) 8088' of 3-1/2", 9.2 ppf, L-80 Packers and SSSV (type and measured depth) N/A 13. Attachments 1568 1541 5810 5329 8O88 7543 Description Summary of Proposal._~.X RECEIVED APR 1 0 2001 Cen,,, O0mmissi0r~ A)aska. Oil & Gas" '~ Armh0r~ge Detailed Operations Program BOP Sketch ~ 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 4/12/2001 16. If Proposal was Verbally Approved Oil Gas X Name of Approver Date Approved Service 17. I hereby (~-~tify that the for~;]oing is true and correct to the best of my knowledge. Signed {~,~'"~% Gary Eller Title Production Engineer Conditions of App~o~all: "l~ify--~' ~Commission so representativF?mRa~lOwitMnMelsSssION USE ONLY Suspended Date 4/6/2001 IAppr°va'l ¢ 1 Plug Integrity ... BOP Test._~.. Location Clearance Mechanical Inte~'rity Test Subsequent Form Required 10- Approved by Order of the Commission ORIGINAL ~]b',~~ D Taylor Sear:',, Commissioner S'u/bmi~r~Triplicate Form 10-403 Rev. 06/15/88 Form 3160-5 (June 1990) UNIT~ ' STATES SUBMITS, DEPARTMENt, ,= THE INTERIOR TRIPLICATE* BUREAU OF LAND MANAGEMENT (Other instructions on reverse side) SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals. SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas ~ Well ~ Well ~-~ Other 2. Name of Operator Marathon Oil Co. 3. Address and Telephone No. P.O. Box 196168, Anchorage, AK 99519, (907)561-5311 4. Location of Well (Footage, Sec., T., R., M., or Suvey Description) Surface: 37' FNL & 4068' FWL, Sec. 7, T4N, R11W, SM TD: 2243' FSL & 2911' FWL, Sec. 6, T4N, R11W, S.M. FORM APPROVED .°" BUDGET BUREAU NO. 1004-0135 Expires: March 31. 1993 5. Lease Designation and Serial No. A-028142 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Kenai Tyonek Unit 891006367C 8. Well Name and No. KBU 33-61 9. APl Well No. 50-133-20487 10. Field and Pool, or Exploratory Area Kenai Gas Field/Tyonek Pool 11. County or Parish, State Kenai Peninsula, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION Notice of Intent Subsequent Report Final Aba'~donment Notice TYPE OF ACTION [~ Abandonment [~ Change of Plans ~ Rec0mpletion [~ New Construction r--] Plugging Back [~ Non-Routine Fracturing r-~ casing Repair [~ Water Shut-Off [~ Altering Casing ~ Conversion to Injection [~ Other Coil Tubing Sand Wash ~ Dispose Water (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertineni details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* Marathon proposes to utilize coil tubing to wash sand and fill from KBU 33-61 to return it to production. 18. I hereby c' '~e~h._at th g is true and correct SIGNED "~'-~,~ ~X ~)~',/"', Gary Eller (This space for Federa~or State office use) TITLE Advanced Production Engineer DATE April 06, 2001 APPROVED BY TITLE DATE Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. *See Insstruction on Reverse Side O:\EXCEL\BLMSUND.XLS 6/96 Well KBU 33-61 Coil Tubin~ Sand Wash AFE 9~07401 Purpose: Wash fill from the KBU 33-61 Tyonek Sand completion to return to production. Procedure: 1. MIRU 1%" coil tubing and nitrogen on KBU 33-61. RU choke manifold and flowback iron. Load tank with 500-bbl of diesel. Test BOPE to 3000 psi. Hold safety and operations meeting. 2. Wash sand to +8000' with diesel le, adcd wit,h gcl break~x~, applying viscous sweeps as necessary to clean the hole. Note: Slickline tagged fill at _+65'. Be aware of the "tight spot" at 6429'. Circulate clean. 3. Jet with nitrogen to purge tubing. Unload to an atmospheric tank until adequately cleaned up. Produce as per instructions of Production Engineer. JGE - April 6, 2001 Kenai Gas Field Well KBU 33-6, Pad 41-7 Marathon Oil Co., Alaska Region API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec. 6, T4N, RllW, S.M. Tree cxns = 3-1/2", 8rd NOTE: "Longstring" refers to the non-tapered, 3-1/2' string. "Shortstring" refers to the tapered, 2-7/8" x 3-1/2' side. The terms "short" and "long" are only used for convenience, since both strings are actually run to the same depth. x~ ~& ~ ?,, '~,~,ILongstring Perfs- Tyonek 73-1 .::,.,.,.. \\t\\1%% 7941'-7951' (3spf,~60°,7/6/00) 7960'- 7970' (3 spf, ~60°, 7/6/00) Tag fill (LS) - 7985' MD (7/6/00) Last Rev: JGE, 8/3/00 PBTD (LS) = 8055' PBTD (SS) = 8056' TD = 8110' 20", 133#, K-55 Drive pipe @ 115' Halliburton Safety Valve Landing Nipples w/sliding sleeves (requires BXL keys) & 1/4", 0.049" WT control line Model #721XXO28101 X-nipple profiles (ID = 2.813") SS @ 911' (opened 6/9/00) LS @ 978' (opened 6/9/00) 13-3/8", 68#, L-80, BTC Casing @ 1568' Cmt w/600 sks of Class G 9-5/8", 40#, L-80, BTC Casing @ 5810' Cmt w/570 sks of Class G Shortstring ,P, erfs - Beluga M 14 & M 15 '~ 6387', - 6410, (4 spf, 0% 7/7/00) 6426,- 6442, (4 spf, 0~, 7/7/00) 6446 - 6460, (4 spf, 0,7/7/00) '6464', - 6471, (4 spf, 0°, 7/7/00) 6476 - 6482 (4 spf, 0°, 7/7/00) 6486'- 6490' (4 spf, 0°, 7/7/00) Tag fill (SS)- 7~.4~ MD'i~75./.0.Q) , . ,~,:-~3 Longstring 3-1/2', 9.3#, L-80, EUE 8rd-M w/SCC @ 8088' Shortstring 3-1/2" x 2-7/8" taper @ 8087' 0'- 5617': 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC 5617' - 8087': 2-7/8', 6.5#, L-80, EUE 8rd-M w/SCC Cement Cemented with 339 sks class G Alaska l..._,ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 29 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA AIRBORNE EXPRESS The following well logs are enclosed: Marathon Oil Company KBU 3}-6/Kenai Oa~ Field Print Reproducible KBU KBU KBU KBU KBU KBU KBU KBU KBU KBU KBU KBU 33-6 - Dipole Sonic Imager Natural Gamma Tool -5/22/00 ................................................................. 33-6 - Natural Gamma Tool - 5/22/00 .................................................................................................. 33-6 - Density, Neutron, Gamma Ray, Caliper, *Platform Express* - 5/22/00 ................................... 33-6 - Gamma Ray, Caliper, *Platform Express* - 5/21/00 ................................................................. 1 33-6 - Comb. Magnetic Res. Tool, Gamma Ray, Caliper, *Platform Express* - 5/21/00 .................... 1 33-6 - Array Induction Tool, Gamma Ray, Caliper, *Platform Express* - 5/21/00 ............................. 1 33-6 - Repeat Formation Tester, Gamma Ray - 5/22/00 ........................ 2 ............................................. 1 '. 33-6 - GPIT- 5/21/00 ........................................................................................................................... 1 33-6Long - Gamma Ray / CCL Log - 6/30/00 ..................................................................................... 1 33-6Long- Completion Record- 7/6/00 .............................................................................................. 1 33-6Short - Gamma Ray / CCL Log 7/5/00 ......................................................................................... 1 33-6Short- Completion Record - 7/6/00 ............................................................................................... 1 Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Received b~""",~ A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well o.1-1 ^sl-q sus E F-I sE vlcq--I 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 99-24 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 37' FNL & 4068' FWL, Sec. 7, T4N, R1 lW, SM ! ~ ';' ;" At top of Producing Interval 1925' FSL& 3410' FWL, Sec. 6, T4N, R11W, S.M. At Total Depth 2243' FSL & 2911' FWL, Sec. 6, T4N, R11W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 21.6' DF-GL I A-028142 4/28/00 5/20/00 7./~,~ I N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness 8110' MD, 7564'TVD 8056' MD, 7511'TVD YesDN° D N/A feet MD I N/A 22. Type Electric or Other Logs Run CM R-CNL-PEX-AIT-DSI-G PIT-NGT-RFT 8. APl Number 50-133-20487 9. Unit or Lease Name Kenai Beluga Unit, Kenai Tyonek Unit 10. Well Number KBU 33-6 11. Field and Pool Beluga Pool & Tyonek Pool Kenai Gas Field 16. No. of Completions two of Permafrost 23 CASING, LINER AND CEMENTING RECORD I CASING SIZEIWT. PER FT. I 20" I 133 13-3/8" I 68 9-5/8" I 40 3-1/2" & 2-7/8" I 9.3 & 6.5 GRADE K-55 L-80 L-80 L-80 ISETTING DEPTH MD TOP BOTTOM i 115 1568 5810 8087 HOLE SIZE CEMENTING RECORD AMOUNT PULLED Driven Driven N/A 17-1/2" 600 sks N/A 12-1/4" N/A 570 sks 339 sks 8-1/2" 25. TUBING RECORD N/A 24. PefforaUons open to ProducUon (MD+TVD of Top and Bottom and 27. interval, size and number) Beluga M-14 & M-15 Sands 6387' - 6410' MD, 5883' - 5905' TVD 6426' - 6442' MD, 5921' - 5936' TVD 6446' - 6460' MD, 5940' - 5954' TVD 6464' - 6471' MD, 5957' - 5964' TVD 6476' - 6482' MD, 5969' - 5975' TVD 6486' - 6490' MD, 5979' - 5983' TVD 4 spf, 2" scallop ~luns, 0-de~lree phased Date First Production 7/2/00 (LS), 7/' 9/00 (SS) Date of Test Hours Tested 8/2/0O 24 Flow Tubing Pres. Casing Pressure 650 (SS), 725 (LS) 28. SIZE N/A DEPTH SET/MD) PACKER SET/MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL/MD) N/A AMOUNT & KIND OF MATERIAL USED N/A I Method of Operation (Flowing, gas lift, etc.) flowing IPRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD ~ 0 1065 (SS), 628 (LS) CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE ~ 0 1065 (ss), 628 (LS) PRODUCTION TEST RATIO WATER-BBL 0 I CHOKE SIZE IGAS-OIL open I N/A OIL GRAVITY-APl (corr) N/A WATER-BBL 0 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal ....... .... ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in Triplicate N:\drlg\kgf\wells\KBU33-6XAOGCOMPL.xls 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME M EAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Middle Beluga 5750' 5290' RFT data submitted Tyonek 7750' 7207' 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Gary Eller Title Production Engineer Date 8/3/00 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Form 10-407 N:\drlg\kgf\wells\KBU33-6kAOG COM PL.xls ( Kenai Gas Field Well KBU 33-6, Pad 41-7 Marathon Oil Co., Alaska Region API: 50-133-20487 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec. 6, T4N, R11W, S.M. Tree cxns = 3-1/2", 8rd NOTE: "Longstring' refers to the non-tapered, 3-1/2" string. "Shortstring" refers to the tapered, 2-7/8" x 3-1/2" side. The terms "short" and "long" are only used for convenience, since both strings are actually run to the same depth. Longstring Perfs - Tyonek 73-1 7941'- 7951' (3 spf, __.60°, 7/6/00) 7960'- 7970' (3 spf, +60°, 7/6/00) Tag fill (LS) - 7985' MD (7/6/00) Last Rev: JGE, 8/3/00 PBTD (LS) = 8055' PBTD (SS) = 8056' TD = 8110' 20", 133#, K-55 Drive pipe @ 115' Halliburton Safety Valve Landing Nipples w/sliding sleeves (requires BXL keys) & 1/4", 0.049" WT control line Model #721XXO28101 X-nipple profiles (ID = 2.813") SS @ 911' (opened 6/9/00) LS @ 978' (opened 6/9/00) 13-3/8", 68#, L-80, BTC Casing @ 1568' Cmt w/600 sks of Class G 9-5/8", 40#, L-80, BTC Casing @ 5810' Cmt w/570 sks of Class G Shortstring Perfs - Beluga M 14 & M 15 6387'- 6410' (4 spf, 0°, 7/7/00) 6426'- 6442' (4 spf, 0°, 7/7/00) 6446'- 6460' (4 spf, 0°, 7/7/00) 6464'- 6471' (4 spf, 0% 7/7/00) 6476'- 6482' (4 spf, 0°, 7/7/00) 6486'- 6490' (4 spf, 0°, 7/7/00) Tag fill (SS)- 7594' MD (7/5/00) Longstring 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC @ 8088' Shortstring 3-1/2" x 2-7/8" taper @ 8087' 0' - 5617': 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC 5617'- 8087': 2-7/8", 6.5#, L-80, EUE 8rd-M w/SCC Cement Cemented with 339 sks class G · II I I i I I I I i ~1 SURVEY CALCULATION AND FIELD WORKSHEET Jo,.o. o~oo~ S,dot~.=k ~o.~ J~j ~mp.~ ~THON OIL COMPA~ Rig O=.r~.~, · NO. Gl'derDlllllng-Rig ~1 Field ~ ~ FIELD Well Name & No, PAD 41-71~U a~ Su~ Se~ion Na~ BHI ~D BHI Rep, lB I I I I ra~~ ' ~ T~etCoord, NIB 81otC~rd. ~ -17,35 ~rldCo~e~ion O.~ De~ Me~umd From: R~ MSL~ ra~ Desc~i~ion Tmg~ Coerd. ~ Slot C~rd. ~ 40~.!7 Msgn. ~olin~on 21.~ ~ul~on M~od MINIMUM CU~ATURE Farg~ Dir~on ~ BuII~WaI~L per: 1~ ~m~ 10m~ Ve~ See, ~im, ~1.41 Magn. to Map Corn 21.2~ Map No~h lo: ~H~ lU i i suRveY OATA .. Suw~ Suw~ - Vaginal .... ~ ~ Build (+) Right (+) " Comma~ ~tn=l,' H&ie~':::~ Coume ~*~ T~ai-Coo~ln~e Build Rste Walk Rate ::: Type ~ ,*"':' ~ P~ . .,4 ~[on N(+) ia(-) E( W(-) :! ,r~-;OL '- ' '"'~': :~ ....... ::--'- ' - -~ - '~" :' o,~ -' b:~ ~:~ o.~ ......... :1 ._ . . ~ :~.~:~:.~ ~' o,~ o,~ ?::: o.~_~ .~... ~, . _ ~ .......: _. TIE IN ~ - . ~:,e-~:~.~ ~'"i~:~ ~' ~0.~~ ~ .a'~.~;~ ":-~g~:~% ...... ~:~ -'~- ~.~ :-" L'~:o:~r:: ~-"-~ .... ~'~ .... o.a ' -o.~.~: .~ '-- - .... E · _: . -~ .; ~- j . : - ..- ~ -.~ -.~-:':- ~. ~' : '' . ... ~O.AP~':.-:~W~' ~,~ o,~ :~,~ . ~,~ ~,~ 4.~ -~,o~ ?~'--:~',~ ...... :~.~ .... o,~ . ~AP~ MWD S~.oo ~.~e ~,~ ~.0° ~-S~ ~.a~ ~,O~ 4,ar o,~ o,~. . : ' r . , . :~ · . ....... - : : ~R~D ~D 7~,~ 3,~O ~5.~ 60,~ 705.~ 1,61 -1 .~ -I 0,51 1.42 1 ,~ . ~ ~~ M~ 7~.~ 4.10 320.~ ~,~ 7~.71 4,~ 0.~: -la. lO E~ ' ~' :' -.. .. :.~ -.--~ .... : ..... , , . -~4.51 . ,:- .~-~ Ie.~ "' ~ -~ . .~ . . . _. :. : ~AP~. :: ~D B5~.OO :? 5~0-:- ;':~:O0 ....... ~ ........ '~ ' ' '12,~ ~.~6- ........... :17~- ...... ~46' 2.~' 15,~ .. ~AFR~ ~D ~,~ 7,16 ~7~1~ 31 .~ e89,17 16,04 10.51' -19.~ 4.~ 4,71 13,~ ~., .¢~ ~R.00 M~ ~.~ 8,~ 3~,~ SI ,~ ~,59 24.31 18,35 -El ,73 2,15 !.74 8.71 ~~ M~ 983.00 9.9D 3~.~ ~.0D ~1.17 29,~ ~.45 -~.~ 4,~ 4.12 5.76 ~P~ MWD 1014.~ 11.10 . ~.8O 31.~ I011.~ 35,~ a.H -24.~ 3.89 3.87 2,~ ~0-AP~ ~D 1073,~ 12,~ ~7.55 59,~ 1069,~ 47;~ 40,70 ~7,13 2.~ 2,37 1,61 I~APR~ ~O I IH,~ 13,51 ~9,~ 61 ,~ 1128,63 ~.B5 ~,!5 ~,89 1,76 1.66 [70 ~-~Y-OO M~ .o~.oo ~.ae e~,~ ~oo ~.o~ ~o,~ ~.80 ~?~ ~,ee ~.~5 -o,~ .~je -. ;. , ,1-~Y~ ~D 1316,~ 17,~ ~e.~ 60,~ 130~,51 107.95 100,61 ~9,51 ~,~ 2,~ 1,17 2-MAY~ ~D 1371,~ 18,~ 347.70 55,~ 13~,83 124.~ 117,18 -4a.05 3,47 3.45 -0.gl t " ~AY-O0 MWO 1449.00 19.80 8~,80 78,00 1~,46 150,~ 1~.36 ~.E8 I,O1 O,~ 1,41 I ii I , I:gi[ I-"--'SURVEY CALCULATI'ON AND FIELD WORKSHEET Job.°. S,d.,==k.o. [ Compa~ ~THON OIL COMP~ Rig Contm~ & No, ,Glscler D~lling- Rig ~1 Field ~! G~ Welt Nam~ & No, P~ 41-7/~U ~-8 Su~ ~lan Nsme BHI ~WO BHI Rep, [~ ~ WE~DATA ' ' ' ~[gM ~ .~, Tmg~ Cored. ~ Slot ~md. NIS -1~.a5 G~d Co~m~on O.00O De~s Measured From: RKB ~rget Desertion Targ~ Cored. ~ Slot Coord, ~ 4~17 M~gn, Deellnsti~n El,~0 CaloulMIo~ M~od MINIMUM ~et ~{on ~ Buil~Walk~OL pe~ 1~ ~m~ 10m~ Ve~ Geo, ~m. ~!.41 M~n, to M~ ~,, 21,~0 Map No~ to: O~ER I IIIII I III ---"~ .... SURVEY DATA su~ ;''~:"~ ': ':;;' "' ..... ~"-' ~:: T°°l f: ,~-~.~Dep~ '~Angle.~ Dl~n ~nWh ~O ' :~::~on. '~ ...N(+}.I s(-) 'E(+).'I W(-) DL Build (+) .: Right (+). Comment ' Type :- ' ~ -~ *' ~. ~ ~ :'~ ~ '?:~. ~ =.:': :~" ~"~ ,:?~. /~- .: ~rlm~, Drop (.)~-: ::'L~ (-) ..'~' . , ...... .... .... . . .. , ~-MAY~ ~D~ 151'4.~: ~,~ ,: 3~7;~ ': '~.~ 1~:~:~ ' 172.51:~ ~' 1~,24 ~ -:-'--'~2.8E 1,~ ~:' ' 1:,~ -'~{:~' gl,~ = ' .... ~..': ..... :~ '-.:- ........ . ~ : . _ . --'~5;~ :~ -~.--:1:~;~ -¥~:' ::~0.~ ~.0{:" 7:- '0,41' "~" -2,61.' 12 1/4'HOLE "'. ," ~ :CO:OD ~ 1~1,78 234,-~ : -~4,~ ~.~ 2,19 2,~:4-' :'~:'~ -2,3?' ':' ,' M~ 17~,~ 24,~' ~,~ 101 ~ 17~,~ 274;61 '~.09 -~,~ 1,51 1,3a 1,49 . .... ;I.~.~D: 1~ '~27.B0 '--,,: 341;10' --~,~ -1~2~,8~ :~.~7 -'-.~-~48.~:: "~"'~-1~.]3 '' [36 E~ . -1.~ :' ...... ' - . - : ~. , .... . . , " ~... ' ~D ~.00 Re.70 343.4D ~,~ 19~.46 ~.61 ~6,~ -~ 15.07 2.E8 1 ,~ 3,71 ~D. 211~,00 '~D.18 . ..3~2;~ _ ~ ~.~ .~5.05 ~. ~,~ -124.~ 2.~ 2,31 , . . : . . .... : : :. :~ -*=:~--. :.. ..... ~ .... .. ~ .' .... ~ - .-- ....-: .. . *~.: . · . ._ ...... ~.~ '~D~ 231'lf;~~ : ~.14 i': '/-:'~:'~ ,63,~ ~.91 ' 5~ ...... ~:~.08 ":: }:151.~ -~ 1,07 ':' ' ' .- : ~ ~.SE-~' '. -1,90 -. .. : , ~ .* : . . . .. :~ : ' _ :: .. . :. '$-:~: - ..... ~D 24a9:~ ~,~ ' '~.~ l.g8'~ : :~1,.47 ~5~:,~ - ~e:i0 -170,~8 0,5~ 0.34' ;;' ' 0.78. ' , UWO' ~,~ ~.es ~,40 e4,~ ~74,11 0~4.,~ Se~.4E -1~.17 0.15 0.13 ~.16 ., , MWD ~.00 ~0.~ 342.70 '9~.~ 2~1.~ 710~ ~,61 ~7~ 0,~ 0,69 0,~ ~D ~0.00 ~,~ ~.~ ~.~0 ~7~ 74E,~ 710.46 ~16,41 1 ,~ 0,33 2,50 ~D ~5S.~ ~,~ ~,~ 96.00 ~0,~ 7~,31 756.52 ~,~ 0,81 ~.63 -I ,... ,.~_~. ~D ESE5,~ ~,40 ~,80 69,~ ~40,38 ~4,31 789,~ -2~.70 0.54 ~.41 ~,72 ~O 3017.~ ~'80 ~2.10 . ~,~ 2~.38 ~24 e~,~ -~.41 ~.~ 0,~ -0,76 .... -- M~ ~1~,~ 29.39 342.40 1~,~ ~.55 ~3,~ ~,07 -272,~ 0,~ ~,32 0,23 .... ~ ?~:) ~,~,-~ MWD ~00 ~D,~ 341,~ 156.00 ~7.~ 1011,07 ~6.96 ~,~ 0,60 0.58 ~,32 ,, ~D ~93.0D ~,~ ~,70 91.0D 3146,~ 1O~,~ 1010,18 -311,~ 0.80 ~.~ -I.~ ,'~C.:-_~:: [:h~ :::., ........... ~D 3457,~ ~,45 ~0.~ 64,~ 320~,20 10~.38 10~,E ~l.gl 0.8~ -0,~ -! .~ MWO 3~,~ 2g.55 3~1.00 [ ~,~ 32~,~ ! 120,3B l~O, Ig ~,~ ~,~ 0,15 1,~ ~-MAy-O0 ~;.MAY.00 ~'-MAY-00' i'-MAY-00 ?-MAY-OO 7-MAY. OO 7_-MAY-O0 /'.MAY-e0 /'-MAY-OD ?-MAY-OD ?'-MAY..O0 ?-MAY-O0 I'-MAY..O0 ~-MAY--O0 ~-MAY-O0 B.MAY-OO ~-MAY--O0 ~.-MAY-OO 8-MAY-O0 SURVEY CALCULATION AND FIELD WORKSHEET Job.o. o ooo3 Pe.o ~mp~Y ~~QN OIL ~MPANY , . Rlg ~nt~or & No, ~la:ier Drilling- Rig ~l . , R~.. ~1 e~ RELD WeD N~e & No, P~ 41-71~U a~ ~ ~ Suw~ S~lon Name BHI ~D ~ ~ uHI ~ep, _ ..... ~ ' WELL DATA t~D ~ Tmg~ C~, N~ SIM Coo~d. ~ -17,35 Grid Oolm~ion 0.~ Depths Measured From: R~ ~ MSL~ ~ t Dr..~lptlon Tmgel Coord, ERV Slot CooTd. E/W 4066,17 Magn. DedhlMion Method MINIMUM CURVATURE -:_:~- .: Depth ~y.00~ .., ...... _- .. ..... AY. Od': . AY.,OO 8844.4)0 .... ._.. A.Y-Og 4038.00 AY,..0.0 I 4100.00 AY-00 4.2,.~,00 IAY-oO. .... ~.._ IAY. o0- 4834.00 4AY-O0 4,-~7.°0 ~Y-O0 54~!.00 ~AY..O0 5112.00 /',AY-O0 5858,00 ,~AY-O0 5453.130 ,4AY-00 5542.00 ~IAY-O0 5665.00 vIAY-O0 vIAY-O0 ~8b"7,00 VtAY-O0 5988.D0 VIAY-00 6124,O0 Hole :DIre~k3n :: ,.~i2,40 - 342.9'0 ~,1.3,0 coUrse .!87~0B. .__ 12.g.00 lg2.00 340,90 65.00 ........... SURVEY DATA :-~.': :, ','~ - ~- - -. Total Coordinate '::'~ ' ;~.~e~lpn 'N(+} /8(') E(+) IW(-)' ':;::~.'..~12.20 .'---:":~1~0:~- /F~25..~1:: '::::. 341.8o -' 93.0o 446s..4s 17ol.oo 336,97 94,00 4582.~6 1734,94 33,-?.40Ol.OO ,~r/.se lee~_.86 1764.20 e~.~O, as.e0 4~.~ 1~.76 18~0 ~17,~ 89.00 8073,~ 1~7~_ _ 1~8.07 __ :314.~ 123.00 5! ~_,85 2~ ,~ 1905.4~ 315.~ 91.00 5~.65 ~0~61 1924.87 314.~ I 11 .~ 5383.74 ~4,~ 1948,~ 3~0.~ 1~,~ '5507.28 2107.~ 1973,12 a531~,~3 12ao.1'4 1222.~ ' '-'q81.68 _ .. 3704,32 1376,62 .. 1814,O5 . 411,3~- . 3759.86 _1408,41 1 ~,4.20 -421,41 - , 'L-. ':- ..... : ' -~ ;3eeo.93 .1476.7o - . 1409.08 "744~-.~:4; 404,1,34 1664.77 14,92.61 ,..470.65 --162~1;50 i~':;.~ 1549,'1~, _ .... ;,.~.;:-: .- _-~: -: _ . ........ ..: .... rt~.45 I?e5.18 .639.77 1620.47 -552.24 -,566.06 -587,01 -610,49 -848.23 · 674,55 -693.77 -716.60 -744.16 -771 Build (+}: / Right (+) · '; .,. ~..: . ~,?1-- -:::'~. ~'o,61 ' :" ..... 4:4'~ ...... "'~ :' o,g~ 0,~ .. -0.35 ~.~ · .13 _ :~_.~ .... ~,47 ' 0,14 ' TRIP FOR B~, MOTOR '' ::~,31'~: "-'::":~,~. '?'-':' .:.-::;2- _ -. - -0.~ --0.73 , ,.--0.47 · - ~ .......: ~ ~::-. ..... . · ~ - . . ~........% ;? ':_ _:.~;7o: ~ .... : ...... : ' -1,38 1,10' -1,37 -1,83 -1,16 -1.45 -0.62 -0.41 -0.47 :: .o,m 4.93 .,5.O~. -4.23 -4,47 -! ,58 .3,15 -2,11 1.10 -0.35 -1.17 -0.29 .,3.10 -0.23 ..0,86 J: SURVEY IN 121/4 FlflST SVYIN e 1/2 HOLE SURVEY CALCULATION AND FIELD WORKSHEET o e eo3 p..o 4 Company MARATHON OIL COMPANY Rig Contraetor & No. GlacieT. Drilling - Rig #1 Field KENAI GAS FIELD Well Name & No, PAD 41-7/KBU 32-6 Survey Seetlon Name BHI IL~ND BHI Rep. ~ WELL DATA tTVD FO Target Coord, N/8 81et Coord, N/8 -17.35 G~ld Coneatlon O.00O DeFIha Meaaumd From: RKB I~ MSLI-J BsKI t Deeoflptlon t Direotion Survey . . o,oo AY-aa 6610.00 AY-OD AY-D0 6764,0O . AY-DO 6891 · . 7142.00 ..... . . lAY-OD 7633.0o lAY-00 7817,00 LRY-O0 7921 La, Y. O0 8051.0O ~AY.00 8110.O0 Target Coord, E/W Slot Coord. E/W 4066.17 Euild~Walk~DL per:. 10oft~ 30mri lamE! Yeti. S~o. A~im, 341.41 ";-' HBla:' Yertlce..1 Dire~on! Se. bllon N(+) ':' :~iee.~.: =.~:.:. -.'_.~. j= ~: ~:- .-. .... 807.90 'i~b0 6001.84 2.225.27 ~080.94 ~o7,4o ~,0o otis.a5 ~5~ ~oeo.?? :305.90 126.00, 62:4'~.74 2277,9B 2(i~g.~ ..... . -.. ~ .~ _ - _ ... _ . .... 304,30 -- 127,00 .- 6a70.°~ 2302,76 2117.06 SURVEY DATA .................. Magn, Deollflalion 21.220 Msgn. to Map Cogr. 21,220 Cal0ulatlon Method MINIMUM CUFIVATURE Map North to: OTHER TBt8t:C~o~din~°~- ';-':'i:.:, Walk ' '''/: ::'. : -":::.' '" I'-...'::.,~?..:i 302.50 123.O0 6615,04 234g.0~ 2149,50 -9iT,IL~ 301,50 . 184,1XI 7275.76 2454,01 222:0.55 -!095.75 3Q,?.,20 !04,00 7379.16 2469,03 P.P...~).14 -!111 303,,40 130,00 7.,506.31 2465,10 2141.97' -1129,57 303,90 59,.00 7564,49 2492,86 2247,41 -II27,74 .0.32 .O.39 .0,26 -!,19 -0,24 -I -0,30 -1,14 . _ .0,40 .0,41 -0,71 -4),04 " .0.26 0,49 0.67 0,92 LAST SURVEY i 04/24/00 ~/ON 09'47 FAX 190756~6489 liarathonOll Co ~ Anchorage Office Marathon R~ '/ DATE: 04/24/00 LOCATION DA, '/ SPUD DAYS: · Oil Company AFL#' 9203699 GL: . KB: MDC WI: , . WELL: KBU 33-6 RIG: Glacier DHIling FTG: P BTD (TVD) CSG SIZE: CSG MD: CSG TVD: SHOE TEST~ MAX. SI 0 LINER TOP: . PRESENT OP'~IGGING UP MOVE IN AND RIG UP GLACIER DRILLING RIG ~ EXECUTIVE SUMMARY { BIT# SIZE TYPE OFF ,FTG~ HRS FT/HR RPM WOB .lCD LB G CT R CPF COMMENTS ( BIT# SERIAL# PRESS. : GPM JETS TFA ANNULAR VELOCITY BIT HP)' BHA: Length: ............................. DRILL PIPE DESCRIPTION: ' '"~ ............ " "" MAx PULL': ( JARS "MwD MOTOR TORQUE WEIGHT (1~)00) (MEA. DEPTH ANGLE DIRECTION TVD VERT. S..EC. HIS ....... .E/W DOG LEG ~ .... OPERATIONS IN SEQUENCE START END HOURS ' ': ""'" '~' DESCRIPTION f5:00 22:00 7.00 MOVE IN' GLACIER RIG ~I. SET MATTING BOARDS. SET SUBSTRUCTURE, GENERATOR HOUSE, BOILER HOUSE, DIESEL TANK, AND WATER TANK. WELD ON AND TEST 20" s TAI~TING FLANGE. START MOB F/KBU 33-6 ~'5:00 HRS 04/23/00 . AFL: DH TST/CSG ' ': ' COMP TOT I LAST PIT DRILL DATE: 00/00/00 ............. ['~'UD c~c~$T's '~-C-TI~--L .' ........ ' · Wi=LI~0~:I:S AC-'I='0~L:"I LAST BOP TEST DATE: 00/00/00 ..... b'~L~: ' ' 0' '- ~U~i 0': " DAILY: '/'0,3,~) (~[JM: ' '~;3~0 ..... I NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: OLW ~ ~' ~001 04/25/00 TUE 06-26 FAX 19075646489 Marathon011 Co 2 DATE: 04/25/00 LOCATION DA 2 SPUD DAYS: Marathon Rr- Oil Company AFE#: 9203699 GL: 66. KB: '2' MOCWI: Anchorage Office ~ 001 WELL: KBU 33-6 RIG: Glacier Drilling FTG: 0 PBTD 0 ('rVD) 0 ._ CSG SIZE: CSG MD: . CSG TVD: SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP~IOGINO UP · CONTINUE RIGGING UP GLACIER RIG ~o EXECUTiVE SUMMARY · ~-~W vis PV YP GELS WL T 7.5' .' 30 HT FC CRC SAND..SLD .BENT SALT DRILLED BARITE I I I I i I I I i I I 132 I I / ..ps PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbl/fl) BKGD CONN" TRIP MAX ::.,:::::::: :::::: ::::::::::::: :::;::::::: ::::: ::: :::::::::: :::::::::::: :.::::::::::::::: :::;:;:;: :.::::::: ~::::: ~: ~:: :::::::::::: ~ ::: ,.:::: ~:::;:::::::::::: :.::::::::::::::::: ::::::::::::: :::::::::::::::::::::::::: {.. BIT# SIZE TYPE OFF.. . FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS .( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) BHA: Length: · DRILL PIPE DESCRIPTION: ~" "'* MAX PULL: . { , JARS MW~ MOTOR TORQUE WEIGHT (1~)00) ..................ill 1 ' : :IBHA: Pu Rot 'So Eft (MEA. DEPTH ANGLE DIR ,ECTION TVD VERT'. SEC.. 'NIS E/W DOG LEG , , ,, . ., . :::::::::::::::::::::::::::::::::::::::::OPERATIONS IN SEQUENCE::::::::::::::::::::::::::::::::::::'::': :::::::::::::::::::::::::::::::::::::':: ~:~:~~:~.~.~) L . .. START END HOURS' ' "~'~ .... DESCRIPTION 6:00 6:00 24.00 CONTINUE RIG UP GLACIER RIG ~1'i. SET TOP DOGHOUSES~ RIG UP BOP TROLLEY RAILS. RAISE SUBSTRUCTURE AND SET SUB BASE OUTRIGGERS. SET PUMP AND PIT MODULES. . · SET IN TRIP TANK. HOOK UP ELECTRIC, WATER, STEAM, AND AIR LINES TO PITS AND PUMPROOM. . ,, ... .. . ,,, · . AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 00/00/00 ............. -MUD COSTS ACTUAl' ' ......... W-EL'I"'[:::oS'~S A~TU~,L ' LAST BOP TEST DATE: 00/00/00 "'DAiL~i ' 0 CUM: 0, '.. ' "D~ILY':" 2':/,~5~" CUM': "~;,'~8;" NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: OLW ' 04/26/00 WED 06:41 FAX 190.756~',,$9 ~[arathon011 Co ., Marogen ~ ....R~ .~'"' '3 DAT~ ~~ LOCA~ D~t ~. S~UD DA~: Oil Company ; . A~: =~3699 GL: 66. KB: 2',. MOC ~: . . . --- , WELL: KBU33.6 " ' PIG:"Glacl~DnTiing IT(5: PBTD 0.. '~' CT'VD) 0 C,SG SIZE: CSG MD: ' . , 'CSG TVD: SHOE TEST: MAX. SI 0 ., UMER TOP: " PRESEICT OP: ,.. ..~.. ,.,,. . ,'.' ,. ,. ,~, .,., .,.,,,...-. ! ................ ,.,.. . , , ,, . ~. . ,, , . , EXECUTIVE ~': '" ::~' SUMMARY ~: " ':" '"' '-'~ ~' ~'.':: ..i ' . .. , .,.. ...... ,'"~L*;'''''': .... ::*':";' "::''.", *" '," ........ ,.,', ....... ..'': ..... ~,'' :'::'" : "'."_'"','L,~ .... :': ...... : ,"* '":,',' *'= ...... ' ..... _*';,;,'.:-',' ..... ''''"... ~MW VIS P~,,YP GELS .WL,..'.T '7.S~ 30 HT FC CEC SAND ,SLD gENT SALT DRILLED BARITE I .l' . 1, I t 'l I" '-.'"1': ~'.:.'1 I I,,/~'~ ,,, I I. I PPB ' ppB PPB loll 'win pH Pm Pi' W' '¥ Ct. CA L~F_. MUD L.OSSF_S('ob~) BKG[:) CONN 'mn, MAX ,,111 , , ' i , · ' , i ill '1 I I I~ :1 ~".:.'*:'.';'l:','i:: I I ,,,~,.,~ .:.m 1 , [' I .................. , ~ ............... ; "'," ...... ,',: ; ............ ; , ' ............... ;" ." .' ' _' .ti:: ...... :':. " "t ........ ', ...... '" C .rr# s~ · "r~ . O~F.' ,.:..n'e ..s .~....P. woe ,o[:] [.., e OT., CPF ~.,.M~'i'S - . . .... ii (~. BIT# SER ,IAL ~" PRESS.' '~' GPM J,ETS TFA J~NULAR VELO,CITY Brl' · ;7:'..... ~.., ..... ; , ... ........ ,2.' ;,..::;:,', .." , ....................................... ....... , .~ ~j..'. Bl'~: ~'"i' ':..'' 'L';;.~ ,,.': ..... i ........ ," : '," , ~h: ' """" ............................. ~.:.~?~?:'"".' !:?.'- ('ili:!:i :.(';!::':'!'!:':'.":"i)!'ii ....:..,...,... :., ...... .. M.,~,:,Uu..: ~ J~ ' ,,.w." . ~.',: :?,..o',-o. -,-o.c.,E " ' I" . .... 'l~i~, "w.~m,i,'~ . " 1- I ;,",/l.,.,'i . _ ,I , : -..'" .,,t- t' .,~ E~' r.,,, ,' ....;:....,., .................. . " ....... 'V. ....... '" ................ '~ "'"'i .......... ~ ..... '"' ..... '"" .... "''t'! .................... '(MEA. DE ,FI"H A~GI,~ '?'i .... :'D!,.R..E.~0N ' 'TVD .... vERT'.'~EC:. N/~ EAN DOG LEG · . ~ , .'.¥ ?:.,.~.'. . .... ... . .. .... ....': ',..,.... ~ ' ; v ,~ ' ': F .... T~',;",,';' ~ ............ , ~',," .,, ,,*.,' , , · . ~ *I ....... ~:~"~ iF';if ri .... ~" ,' ' , · ..? .. ... .' . ~..,.~ ,' ":';"::Z' "'::*"~ .v.:. ;..,. ,, ;:. ". ...... , , '. .................. ,; ~;' ~,,. ' ......... ' ', '; ., ........ ~', .......... , , ,-,' , ~,L, , , ,.,!.;. ; ...... , ...... ; ', . . , ('~ ' ~ ' :,-,*' ~:'"':'~'~:: ....... OPERATIONS IN SEQUENCE: ' . ': , .... ~.:,,.~' ~ ..::~: .:, , .. . , ,, ,~ , . S~J~i'T Fi~ND ~OURs ~r,,. i,','/, ? ,,,,· ,., , . . , ~ ~ , · ,, ,,. ~,,:., ....... :. .... D_sc~_,..ON 6:00. 6:00, 24.00 '.'CO~NLt~. 'RIG UP G, '.LACI£R .RIG t- RAISE HYDi~,.LILIC LINES ~ ~I{ST FOR. TOP DRIVE, PLrl .... ~.~. ION ON, D~. RICK BOARD, CHECK PRESSURE ON KOOMEY BO. . .TT~. E$, HOOK UP ,, ...'. :..=~ea~E.. R uN, E 'ro CHOKE, L~TALL.PAD E. YES oN c;OWN, eMLD CLAMPS FO~ !.,: :..:: ~ .P. AULIC lINES. LEVEL CARRIER,. INSTALL BEA .V~R $IIDE~ INSTALL WALK WAy BEllINI ~, ..... ,, DERRICKANDSTAII~ TO ~'FROM ~E.,.WORK oN BOP CIfAW. FALL~ AND ..... ;':' ':iN'g~'ON BF-AM~, ; UiVLpAD MUD PROb~TS, DRILL, PIP~,ANO MI$~ 'DR~LUtI~ ~L$, ,, '. STACK LIP DIVERTER SPOOL ANO ANNULAR., INSTALL MUFFLERS ON OAR .Rrt'R , · ' ................ ' ' ' '~ *"'~. ":'i',"' '"':" ..... "i' ~ '"'"' ,. ~. :.i:.!*":.'.'~ii!,:i::.:.'?'.:F... , , .... i , ' i .)'' ,', ,.,., ,. . i ~ ~ ,' '~ '., -,'.,' "'~:,,'*", · , .! ~ '* * ~ '~*':":~!'*:"'"'T:'i ' ,, ~ * ' ~y~...,',. ,: ~', ~ . ' ":' i '".' ':*'~-'.~=i'~',~'': ~ ' '" ' -- ~ ,. .... . ,. , : ,-,.:, ...... ~, .,.,,,.-,,, ':, , . .., ~ ~ , i , , ,,,~,~,:,:,? .. :,,,. ,:,.L ..: . ~ . , ..~ ..... . .... ~.* ,~ :~ r,,,'. :: v.:,~ .... i i i iii ~E: OH. TST~C,S~ · ·. , .COMP TOT LAST Prr DRILL DATE: ~:?,:i!;~i:;.¢:,i~/~ MUD COSTS ACTUAl:"': ':'- ' ~ :~ELL COSTS ACnJN_ ~,:~:~.~iil,~2 LAST 80P ?EST DATE: ~,'l'l'*r, .:,,., :. (,:.,,, ~ . . , . ' DAILY: ' O CUM:'. :: O:,* ...... DAILY: ,~f,0Sf CUM: 52,432' . NO .ACCIDE. NT~ REPO~'TODAY [~001 04/27/00 THU 06-$$ FAX 190756.~459 ~ars~hon011 Co Marathon ': :';.-' K ,,, .. 4 DATE: 04/2?/00 LOCATION L ( ,~ .~ SPUD DAYS: .... Oil Company ~E~ ~2o~ ~c: 6~. KB: ~OC ~: . csG SIZE: CSG MD~:. . CSG TVD: -- SHOE TEST: MAJC SI U~ER TOP: . ' ' , PI~..SENT OP: - , · ..... ,...~..,, .... · ... , -; ........... ,.o., ,,,,,,. ,., ..... &, -~ ~ ~-. ..... , ....... ,,., , ..... ,~, ---, J _ . ..... GENER~'L Ri(; UP OF GLACIER RI$ '1 - PICKING UP TESCO TOP DRIVE. NIPPLE UP DTVERTE~ SYSTEM SUMMARY : . .. · . {MW.:'""~';'"~ ......... Pq YP ~EI~" ' ':'~L'"' ":~'1. ,?.~v ............................ ~' lit ~.':"'":'"'"' CEe' ................................ .~J~iD $1~' ...... ~...~IT':' ..................... ~Ai.l '"; ........................ I' 1.. I I i '1~:I L I t "i"'1 ~ I .... 1 ~ ~P~ PP~ P~ (~OIL WTR pH Pm Pi:. Mf *~ CL CA UII~".~.D,,LI~ES (blzl/f~_ ;BKG_D .. CONN TRIp_ 1' 1' '1 .I :"l ~"'i" [ 1 ld."~, ~"" ' 1 ..................... ;-;...~ ................... ,..~ .............................. ,..; ....... ~, .... .. .............. ........; ....... ; ......... ~,;; .......... ,,,,...... (~ BIT# Sm 'T~'PE ' OFF FTG HRS FT/HR RPM WOB IOD LB O OT R I : " ' , , ,' ' ...., ...~ ~ir.;'. ' ~ 'Sl~:2 SERIAL# PRE$S.~ GpM '" JETS TIaA- ANNULAR V~LOClTY BIT i · i ..... ' ................... i"'.'". ........ ,~ :, ', ' ' " BHA -' · ,' , ::~ ' L '. :L.,i: ;: ,~.L. 4 ........................... ... '. ............. . ,, DRILL DESCRIPTION ,~. ' .... · .......... · MAX PULL PiPE ~ ,~ ¢~,~?;~' ,~'L.':~. ~..,., ,, ,....'*., :,., ..', ..... '~., . ...... . ...................... , ..... :..',.i.',,,,".,i.,'....!.._,. ...... ?,..-,..,.,... ..... ...... ~... ......... -,:,..~:.,,,~ .............. ~.~.::. ................ ,;.~ .......... ., ,, .. (...~.EA.. O£m ,~,_GLE.. ,,,:~ · ,mREC.,,'nO~ . 'nm VEIn'.SEC. , ~S ........ , , , ~, i r~, r ' d " I ' I ,', "iT' ,~ ~*i?:";~:'~''*~''''~ ' ' : , , .-- , . '~ · ~.,., ., .. _,.,.,.,:,.~ ~. ~ ,.,~ , ..~. , : ~.~:'i~, ~.. ., ..... ,,~.~ : .,,,**,,.~*.,~:~! ~.?..~ ..... .............. ~ ,., %:.:.,-,* . .,. ;,. ..... L ,, , .. , . , .,, ,,,~ , . , . .- .... ,:, ~ ..... ,.,. ~ ..... . ...... ,", :... ,,. ,,, ,, ,, :,, ,, .~_ ... ,-., ,, ,,:, ( "i ~: .:.?.,';.!.~..~:;....;;.,.~:~ " "OPERATIONS IN sEQUENcE ' ,' . .,, HOuRS 4...,~:, ~ *. "DESCRIPTION " .. '" START 6:00 S.'Ot7 24'00 CON~, NUE RIG UP.G, UICIER RIG ~. Nii~PLE.Up THE DIVERTE~ SYS. TEM- ScoPE OU~: UpPEj , .. i. SECTJON, OFMAST- LEVEL DE~U~CKA~D SECURE OUt' ~- LEVEL CAT WALK- LE.VE.L "i ,UP.,,J~RICK MONKEY BOARD o,RIG UP DRI! ~ ~_R$ CONSOLE- INSTALL WIND WALJ~ , , ,' ,, ,:,, :, , . ,. , , , - _ ~ ~ , , ARO, UNO .BACK OF R~ FLOOR - SET ~TAIRS o PLUMB FLOWLINE JETS. WORK ON RIG ~ULIC sYsTEM: UNLOAD MUD PRODUCT~- WO~[ ON CiJ77~GS wAsH sYsTEM. ., , ~'-:' [~r~Y.[.~ ROTARYDRIVE MOT.OR o INSTALL 7;ORQUE TUBE FOR TEsco TOP DRIVE- RUN HYDRAULIC LINES TO JoY STICK AT DRILLERS STATION,. TO CO~ MUD P~MP-,. ,, . IN.S...T...A!~.. . VIBERA TORS ,ON. CUTTINGS SHOOTS.- MODIFY RISER TO FIT BETI/VEEN BOP . i :, ~,".L~,~ UP :TOP DMVE AND'B,,~G TO RIG,~a WORKATIN~TALLING"SAME ,,', , I ~, '" · ,. . , ,, .,., , .. ~ ?',i"~ ............ ~"' ~', ,, , ,, . - i,'~ .... .? .~' ..... : ......... ."I ~u~ ¢o~?~ a¢~[-"" '~:' :':' :" ':"' ' ""'"": .... ~"~W~L[ eO~ ^¢TUa[ ['"~"i":~" ~ ~OP ~T .... ..' .. 'DALLY: I} CUM:.- . :"~:;O:'.'~'i;., DALLY: 15,540 CUM: 67)72 NOACClDENT~ REPORTED TODAY I~001 04/28/00 ~-~I 07:09 .FAX .190Y~'564't~i89 MaraT:hon01! Co Ma~o~ . RT ].,.. ~ DATE: . ~8~~ . LOCA~ON D[ ': .5~ SPUD DAYS: OU Company · . '- AF~{ ~3699 GL: 66. KB: ~' MOC ~: - PB~ 0 ~D) 0 ~.-~: . .C~G?'~D~ ~ SHOE TP,.ST: Im~ =~ u UNERTOP: - ' '. "' " : ' ' . ....... .RES NTOP~ ' "' '. ~ ~ ..... i,.--..~.--..-_--~ ~-~~ ~.~'a JFI~ 13R//.LGVG R/G~I- R/GACCEPTED FOR ~ wotm,~uvu, nn,.~ ,,,,. ...... l~ PREPARE TO PiCK UP DRILL PIP~ AND STAND BACK IN MA~I ~K ur ~u.~.. nv~ ........ EXECUTW . ·., ~.::.. :. · ~: .... ~:.~:=:.,~:~,~ ....... :.: ............. · , . Lgng~: .......... : .... -?:"-' ..... ~ ....... i ' ' ......... ~':' · _ ~ : .:: . ',.:. ' .... MAXPULL: ' t ' ', ._~_~! . , ~.....~, ..,,.'.,,~.:,'. : ~ _ , ~ ,:~:~,::. ,,.'.,, '..'"' " ~ ' · . ~ .................. . .~.~ .:. , ...., ~ ........................... : : : ~ -- ._. ~ ' '. START END HOUR~ "l :"~"':-',, '-~ ....... .:. '.'. ............... ' " ~:,o ~ ~ ~m'~m"~ UP TOP ~R~' " aHAN'e~--' --------'- ~ : ~ i:~F "~ FOI~ TOP DRIVE ~. RIG UP FLOW. LINE AND JFT LINE- iNSTALL W~.~.LUUK MUU ' - . . ~HP~I.~KE~.YHOSEAN. D~'INSTALL ~m~pTANK~ --- ,NE. wo, 0,, -; ~ ~'~:"'"'~ ~T. ~Fr-n.ND' WATER TANK= INSTA~ ' FLOW SHOW IN FLOW UNE-/NSTALL , '"-'~ ' -'---: ' ;.~r --- u- =- PiCK UP DR~':1 PIPE*RIG Ar--~F~' I "'~-"FOR W~LL WORK.ON I~L133-6 .~ _~._1, · ':., ," ~r~:~' ,~ " ........ '; 'h '"" ": : ' ' ' ' ,' ~ ,.,. .. ;~.'~.~:?.: .,....,...i!.'..:.: . , , ,. ;.~'., ::,~.:~., - :'.:.? ..:.,.',. :..,.i',,...,;:,. .. . ., , .'.. , ............ ~ ......... ·...·,..~ ................. . .... '. '" ' ,':,',*, '" ',~ :.'1 , ,. ., ~ ,,, ,C,",I.-.?~:...:'"~ c~ ;,~' ~ .. ~ ~.. + .. · ' ~.iii " ;:." '..' ::. :.':': .:% ' ' '" ~ .... ,. ...... ..,,, ,, .... ,. · .~ ,;.. ,., .,, , , , , : , ,,,,,.., ,,., .... - , ..... :', ?iT'..":.:. : ~ ............................ . ., ,..! ,~...~ ............... ~ __---,--- ~~,, )., ~ , .,~ , , ), . ~: ...,.~.. ,~ .~....-. P. FE: DH TSTIC~. ')*.:...:?:" ':'?"?" OOMP' TOT LAST PIT DRILL DATE: · . . v .... v .. ...:,,, ..... ' . ,,., ,'.'- '" ' ' ~.,~,.,~,,,:..:,:;.' ,, ,.,u, :~,1'u,,n n-nSTS AOTIJAL', ................. "'"":' :"": .......... I W~LL COSTS AOTUN- I" ";'.~,l,l,l,';.: LAST BOP TEST DAT£: WOO ~"(':*-*:';+",~"1:' ~::'1 "'"'"' '"'"' ' ' ' .... ~-' '~ ' '~'::' .... ....,...,.~.,. --'---'-~' --'-'" "-=- '-'," " ' CUM" 8''''n'* NOACC/DENTS REPORTED TODAY ,.,~, v. /~ CUM.'- : ...... O! ........ LAm-LT: u ' .. . 04/29/00 SAT 10-47 FAX 1907564~489 l[ararhon011 Co · "~ ' 6* ~DATE: 04/29/~ LOCATION· ;: 6 SPUD DAYS: Marathon I Oil Company AFe~. 920;69~ ~;L: , 66. KB:__.~ __MOC Wi: WFLL:K. BU33-6 RIG: (~lac[erDn'[J~n~ FT"G: 525 .. DEPTH: (MD)_. _525,,..~..(TVO) 525 C~G S~q=_: 20.000-" CSG MD: 110. CSG TVO: 110. SHOE TEST: MAX. SI 0 i'~NERTOP: , -- PRF. S'=NT OP:D~aU. A~E,U~ ~'~' MD '- . . .. . . ' -. ' - n · .. . . . '-., . R~(} UP 'To'*'PmK UP D/aU. STRnVG a,'VO aH,~ - AeX SPUO MUD - SPLm WF-Z.L - oRnJ. ~U-~F_.AD TO SUMMARY ,.,'., ............ , ,.,i.,,,,,,, ...,....,,.,.,,,,,,..,,. ,,.',,'.'".~"""""."''"'' ."."'"'"'''~ ...... "'"''."[ .... .'".'' '.":..'.:'~'-~'.:.'.~,L.~LL:.'.:,;.~_'.~;_'.C._"." '_'' ' ,' ..', ,., , ('MW ~ PT/YP GELS WI. T 7.~ 30- FIT' FC CEC SAND SLD BENT SAI.T DRILLED EIAIalT~.. ~i'f"-~ pH Pm ~ Mf CA CA J.]ME MUD LC)~SF.,S (bbl/~..), BKeD CONN TRIP ...'.0.,,..°..., I . I_ ? l~. I , i . I.?,~, .",:?,."--~.-: _~?~.~...°?,...~ ........... I ...... I ..... ~.?!!~.. ....... . ....... ,:.i~- '."'.:,.iii'7.~:,~-~,::-:i~,1 __ ...... [_-'..i.,.i ............... __! . ................................... {. BIT# 81ZE TYPE OFF FTG HRS FTIH_R~,,,,R~,M_.__..W~._ B ..!. Oi.D .L.B .GOT R CPF COMMENT~ *) ,t.. . *-- .... ............ ( BlT~ 8ERIAJ. t~ PRESS. GPM JETS IFA ANNUL/kRVELOCITY BITHP~ ' ...'.. Ic''~' '1';" I~==1'' ~°~' I"-'=. I _~ '., . * ' _.1 '~.A:~ ~ ~/z. ~rrc ~rr, N~ ~eR~ ~aCH ~ ~O;O~, XO.SUa, S~Ne S~A~,' ~m~, pucs~R sua, xo. su, a, ~r~, xo' 'M?..82 .... :' ...... .... ,,, , oRIu ,l,= =;scRI"~i~"*."~'*.~,~- ~, = Jo- H~e, P, ................. ' ~* .... '" .................... ~x PUL- = i<.'..,.s- .......... ' ~' ' .... Moro. "" -to.,:,.,; w~m',~,~) - .... '----: .......... , ..... ! ' ~ , ,',, , ,c _ '"'" : ......................... .................. ........... ..,...,..,,.., ............................................. , ....................... STTU{T END HOURS DESCRIPTION 6:0O 7:00 7.00 ..,, $'E'~, MUD LOGGER SHACK- ~TRAP DRILI.. PIPE. 7:00 ---~-O:O~ 3.0~ PRE. lOB SAFETY MEETWG. PICK UP 4" DRILL PIPE AND STAND BACK WE IN DERRICK 10:00 t1:00 ~.00 STRAP S' HWDP- FUNCTION T~STAN, NM. AR ANO KMFE VALI~ AS REQUIRED PER,AOGC '- ~.~0- - ~5:0O " 4.00 PICK UPS" i~V~)PAND STAND ,BACKWEIN DE ,P~.K " ,, ., ?S:~ ~7'.30 Z50 i~CK UP AND MAKE UP B, HJL ~1, TAG BOTTOM ~ 46' ~?:30 ~8:30 , 1:00 ,, ATIEM,' PTT° BREAK ClRCUL4TION. TRD,~, LE sHOoT MUD PUMP PLC ~:3, ~9:0O 0.50 RLL HOLE. BREAK. CtRC~YLATION- CHECK FOR LEAKS .... , _ __ ~9:0O 20:00 1,00 ' DRILL FROM 46' TO 67'- CIRCULATE AND CLEAN HOLE- JET FLOWLINE ·.. ,' .,. ,, , ..... 20. ~. ~e.~o o.~ OI~ENT MWD JUm MAKE CONNE~oN 20:30 27:0o' o.~ TR_ OU,.BLE sHoOT MUD PUMP PLC :FOUND BAD. ~CON~IECTIgN IN PLUG 21.'00 21:30 0.50 ~ .F.!~)M 67'70 '129' ,.. 2~:30 2~'00 0.50 CONVEYOR P.I, UGGED UP ~oo o:o0 ~oo D~u.C, FROM ~' TO ~f~' CONmOL b~J. ..... " ,, 0:00 0:30 0.50 WOrK ON.TOP_D_R~_ _ ATrE. MPT T~, BREAK Of~.. .OF ST~.., D. OF. .HW~. P , SHLrrTLE VAL VE · . CARRIER NOTSHIFTING TO GIVE CORRECTHYDRAULlC PRESSURE FOR TASKATHAND · REPAIRED VALVE, U~F.:O~ * " ..... ~ ......... ~ ..... -"*- ........ '*"'"'"*"'*":*~:-'*- -*~ .......................................... '-'""**'-" ........... ='""~'*-*"*--*~'"'- ................. T~T/CSG COMP TOT LAST PiT DRILL DATE: 0WOO/DO ,t,l.I ~ ~ .' . . . . r.?:~::.:?//.:v:**LM.U..D cos.is ACTUAL ~ ,, , WEI.J. COSTS ACTUAL :' LAST BOP TEST DATE; DAILY:. '~ CUU'- 0 DA]L,Y: 29,227 CUM: '/ff,636 NOACC/,.DEN]~ REp.OR.TED TODAY DRILUN~ SUPERVISOR: DARRELL GREEN · , ~001 04/29/00 SAT 10'48 FAX 19075§A,6459 Well: KBU 33-6 {, Date: 29--Apr.-00 · MararhonOil Co Operations Cont {d) START END HOURS DESCRIP11ON - 0'..~O--- 6:00 550 D/i/LL. AHEAD ATCONTROLLED RAY'~ TO ~. ~NAGE FLeD LO~ ATS~~ ~D ~ ~ O~ W~G PROCE~. ,,. , ,,, ,, 002 04/30/00 SUN 07:22 FAX 19075646489 MarathonOll Co .. Marathon R( ·~,...:', 7 DATE: 04/'30/00 LOCATION D ~ ? SPUD DAYS: 2 Oil Company AFE;;[. 203699 GL: 66. KB: MDC Wh . CSG $~,F-_ 20.000 CSG MD: 110. C~I~ TVD: frO. SHOE I'E~T: MAX. SI LI~ER TOP: . . . PRESENT UP:PUMP MOTOR WENT DOWN ON HIGH TEMP. V~RK~NG ON SAME TO RE. START ,...'... .............. _.....j_,..._.,.~. ..... _. .................................. , ......... , ................ ,.,...,.,., ,.,.,,.,.,.,,,.,.,,,.,,,,.,,, ,., ,.,.,...,,.., .................. . .., .. ....... ,. DR/LL'TO 941'- CIRCULATE HOLE CLEAN- CHANGE OUT TOP DRIVE SAVER SUB TO HT-38. DI~LI. AHEAD EXEC~ TO .1usa' SUMMARY '~'i"i~'i'"/~"'~"""~ ...... ~"'"Y"~/ ....... ~,' ..... ~"'-'"~'""'"'"~a~"~.'/~':,m ~-':':'~f~:':~'~--'~,:' I 1' "l"l .... t .... f ..... I" '-I ~ I I'-/'~- ...... I ....... I ' ,PB PP- .~o,,- ~.~_~,_._. p,.' '.. W l ':~c~-2 '~_~_.~_~ .up.L_o~.~,m~ .~oo CON. , .'re'P. . ........... i ...... [ ...... [ .... I ..... ! ........ ! ....... F.. ...... 1 ..... !.d .... ~, ........... ._:,..~ .,~ 1 ...... ._..,,.,.[ ...... : ............... L~.~..! ............ , ........ · , .... ' ' ' . , t,.= J . . .... ......... "' ' ; .... '* ' '" ' .' ' " "' .... "'~ "" ...... :"¥' :.'.::';~"-"-'2_'~"_'z'"';'";' ...... '" .......... "*'",'~ ....... '"'""*''"'"*'""""*' 'BI'lA ': ;l* '17 'I~2" HTC B'IT~ NAVIDRILL MA¢if 1 MOTOR,, XO,,SUB, STRING STAB, MWD, PULSER SUB, XO.SUB, Jam, XO Len[jl~ : Sub, .* DRILL PIPE DESCRIPTION: 23 J,~- .' .HWDP, 3 Jb;- HWDP~ ....... ' -" .. MAX PULL: ~ JAR mm --Mm-OR TOImU~: w~t(~m'(10oo) ~.o l~a`1r,-,o,31 _z:LO-~[~ . --]- ~-O-~[~c~ l ........... [E~i.~" .~i ?~'_~ T_o.-'...t'-.- -~---40-~-~. · ~ , , . .... .,~ . ,. [ MEA, DEPTH ....AN_ e!~, ~, DIRE,'~,O, . TVD ,, .._VER?~-.~.E.C_-. _..N/~__. .......................... DOe 950.00 8.M8 I.' 3~4.,1~ 94~.~9 24.31 '1B.35 -ZI.73 2.t5 %ot4.oo ~.O?O M$'.~o ~,O~%~s 3s.~, 2a.s3 -MU 3.SO .... , ( OPERATIONS IN SEQUENCE .......... · ~ . ..,~.,~ ~,., ,-~,-, , START END HOURS DESCRIPTION .... 6:OO 18:OO ,ZOO DRILL';AHEAD FROM S2S' TO KOP ~, $OO'- ROTATE AND SUDE AS HEEDED Tb BMLD AMD CONTROl. AN~LE AND DIRECTION DRILL AHEAD TO Mf; .. ~ ,~ . '.o~C~)~CULA~ HOLE.C .~. . ..: ......... ' ~9:OO 2~00- - " .3.OO C~... . ._G_EO_UT TOP DR~**.S~. ,VER S, UB, EN_ D ~_ ?:_ ~U!D_ E. AND ELEVATOR INSERTS. ~NOTE s~v~ su~ ~.~ , ,,~ ON ..sT mr~ uP. cw~ our.~v~ s.a SECOND ~;.OO ' , 0:OO . 2'00 ,' DRiLL AHEAD,FROM MI'TO ~OO4'. ......... 0:OO 2.'00 ZOO DRiLL AtJEAD SLIDING FROM 1OO~' TO ~037' AND BACK REAM HOLE SECTION 2:OO 3:1~ 1.011 LA Y DOWN ~ BAD JOINTS 4' DRILL PIPE- PUMP UP TOP DRIVE COMPEN,~t TOR - HAVE Pi7 3:00 4'.30 1.S0 ROTATE FROM 1037' TO 106~' ~UVD ;UDE FROM 106tt' TO 10~' .... ,_ . ,~ _ '._ , ,, : . 4:30 6:00. ,..~ ~ MOfOR NUMBER TWO DOWN ON HIGH TEMP. - WORK PIPE AND C/RCULArE W/TI/ NUMBER ONE PUMP ~ , ...... ~"t · ........ ................... · ,'..,.. ,.,-, ...... , -.,.,,_.,,....~_,_,.,.~.~ .... .,,..,.,.,......,,. ....... :,.,,..., ...... .... ..... ~..~`~v.~:~..~.*`.~..`~`.~'`~.~...~.`~.`~`..~.....~.~.`~..~..~`..~.~"%~` ¥¥.,. ... .... I~FE: DH TSTIGS(~ COMP TOT LAST FIT DRJI. J. DATE: ....T,.I..~,:,..,.~..d.'.;:...] MUD CO~T~ ~,E'i'U~[. rv.'.,'.~ ~.r.u..~..,..,,,, ,.';.~ (, ,~.~,,:., WFH COSTS KCT-I.J~'[.-t~!,:%?~'~:g}. LAST BOP TEST DATE: DAILY: S,'~M CUM: .f.~ ONLY: 27.-.~.~. CUM: `139,080 NOACCIDENT~ REPORTED TODAY , DRILUN$ SUPERVtSOR: DARRELL, ,eRF. EN iii i i i ~001 05/01/00 ~ION 07-28 FAX 19075646489 Marathon011 Co Marathon ,~.?' 8 DATE: 05/01J00 LOcA'rtON , ~' 8 SPUDDAYS: Oil COmpany AFL. 9~o~699 eL: 66. Ira: !' . MOO WI: ... PeeS~ oP~.O~. TO WS~CT ~ TO0~ ~C~ SUUM~ ~ . ........ . . , . ~ ....... ,. t ,;; . .; ... , ~ ,.?.,..,. ~ , , , - .... , , , · , ,.,.~, '", '.~ .... ~ .'..'.;..'..,':,'L'.' ........ . ." ' ' ' '% """" '"' '""" '2L': ~;;. L'..' L.'.,:,':' ' '.'" ~OP_ '~ p. 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','.,,,;.,,, .......... ,.,., .... ,, ........... ,,,,,.,.,..~,.,,.~..,.~ ........ , ....... .~...~ ...... .,,. ....~, ~ DH '"' TST~ ~MP ' TOT ~,~,..I.*,~ * . . . · ~**.:,. ~ MUD COS~S*~UAL ......... .;~';)~, W~ C~S AC~AL }'*.*:;,*:',?~';,~ ~ST BOP ~ST DA~: ...... i. .j , ..~ , . D~y: ~" cuM: 9,69~ D~CY: ~f~a CU~ ~. NOA~~~~DTO~Y . D~LUNG ~UPER~$OR: ~~ GRiN , , ,, ~001 05/02/00 TUE 10'06 FAX 1907564,6489 Marathon011 Co Oil Company AF~ ~)2036~)9 GL 66. KB: I ~OCWI: . MNER TO~: . " PR~S~ OP~ ~'D .... ~C~ SUM~Y . .............. ,, · .... : ............ ,,,: ............... :~, .~.:.: ..................... ,.,.,, :~':' :'~' ..................... ~._.'~ ........... ~1 ~ PV ~ . G~ ~ T 7.5 ~ ~ FC CEC ~O ' ,, ' i., , , , ,, i ~o,~~ ~ ~ ~ m . "'% ~ uuE~uo~~ I ' * I I .I' " ................ ,.7,. ......... .;,. .... ~.. , . ,' .............................. _.? ~, ~ ...................... ;,, ............. _ ....... . ....... : .................... . ..... ,,,., ~ ~ff~ SgE ~PE OFF. ~G flR~ ~/HR RPM WOB I OD LB GOT R ,. ...... ..17'":'1-. .". .......... ,' 1~ t.~...t. ;~'..I '~.~.,~- I ~.o~.I' ' . , . . ' ,,, ;.,.,~,..:.,, ,,~, BHA: 1 . : .'...:..: ............. L~: , .., ........................... , . .; ..... . , , ,,, i,, - , .............. D~LL PiPE O~C~P~ON ': :'"'~':~?:'~'?:'"".':: ................. ~: ......... _ ' , ','',,, ~.' ,- ,, ,, ,' ,r' "",r", I ' ' ' ( JARS ~ Motor ~ORQUE ~ " ........ : ........ ' .......... , ........... ~" '~: ........................ r",', ' ~, .':: ................... :" :",';'~ ......... ::,:.: ......... . ..... :':"':,' ................... ., ...., ~ i ,~ .,. , ,'L" '' '-. ' . ~ '" t' ?~,~""1 '1: , ' " ' ..... .'..~ ........... , ........ =,, . ,, · ........... ; :;,,',';, ..... . ........ ,.. ,:: ...... ".' , ,:. ,.?,. · . ,. . .,.: ~,,,,' ...... ~ .... , ........ ST~T' '~O ' ,OUm.., ' .... oEscm~oa' ' .... .. ' .. ~::-~ .~ "..I 'W~ BR~K ~ ~O MOTOR' IWPE~ F~ ~6E ~O ~~ P~. O~E~ ' .," MO~R~D ~ UP BHA - ' 9:30 10:30 1.~, RJ.H. ~.~ ~ ~0~ ~3:~ 2~:30 ., '.::. '~*,~:'. '~[~:~'~O'~D S~E ~ N~ED ~eOM, ~ TO 13701 SUrE ~E ~ ~,~5 HRS. ~ND ,,.. .... :.',,:. .R~T4~,~ ~ .......... ~ ........ .--.. - 23:~ 4:~ ~ DRI~..AH~D F~M 1370' TO I~S~DE ~ME ~ 3.7S HRS.- ROTA~ ~E ~.~ HRS. 4:= 4=0 0~, ' R~~. =CK ~ TO C~ uP.Ho~ ' ' 4:30 ~:~ , , ' - 0.'~ ",': ~1~'~~ FROM 1~' TO ~' P~P HF~ N~ PLUG S~ Tb C~ HO~- ,, ': , ROTA~E.~HRS "' ,... 5:00 6:~ "' ~.~ D~ M~ FRoM I~3'TO~SW . $~E ~ ~.75 ~ '" , ·, , ,, . .... :- ;;. ,~. '?.~....* ...... ,%'.,., ,.~ *.,; ~.~ ., ......... ~ .... ~ ....... ~... ~ DH ~TI~ '. c~P TOT '~T ONLY: 4,~S CUM: ~4,~'. ~LY: 45,~8 CUM: ~5~6 NO A~DEN~ ~~D ~ Y DRILUNG SUPERIOR: D~R~ ~REEN .... '" . , ,~ ' . :... , ,., ,,., ,. , I~J. uul 05/03/00 WED 06-50 FAX'~':§O?5e':?:489 Marathon011 ..Co Marathon :: · ~ R, . j' f0 DATE: , 0~ LOCA~flN [. .,: IO SPUD DAYS:. 5 LINER'lOP: . .-' .~.,:.-'.-' PRESENT DP:CHANGE OUT ~A,TO~ AND BALES 7'0 RUN.ST~ itl ~BL ¥ ,' __ · · · · .~ ..... .; S.,,__' ............ ~'" '~'~'-'-'"' '~ ~" '-- ........ ~'-"-'-' ........ '-,;"."-' .......................... ' ......... "'" .......... ' ...... """"-'"° '*'~"""'-'""' '"' '" "*' "~" ..... DRILL TO._T',D,.I~:11.575;.- P,O,J,L - RUN t3 3A~ C~ING ~r=-j,, AT '156~i" ' EXECUTIVE :-' ='".'~""::i.:'!~'! -: . .: '.. SUMMARY . .: '.~.:.' . ..... ' :2:*' ::$L,- ~ . · . ...... · . ...... (0IL__ _WTR__ ..... olt ,P_.m P~ -. Mf ' CL C~ UME MUD LOSSES (bbl/It) .. BKGD CONN o.o [~oI ~'~'1 I'~' 1'"-"-:~-I:-~-'l ' 1 [.~i,~; ...... c~' - I I - ...... 1 ..... I- .( ,!]~# ............................. -':"e.~.~""".,-~::.'.:.:':.'" '__""-'_:.,".::::.: :.'::".' '.:'..:"-'?:'.';," ',-:'.-'."""".,~-;.': :. .......... '_""'. .... '. ....... :": ........ :"'~ ...... :: ........ ~_,:.', ......... ~*' '."' SIZE TYPE' '*'"' O,F.F F'I'G ,_H, RS FI*mR RPM WOB I O D L B GOT R CPF COMMENT~ ( BIT# SERIAL# . PRESS;,:...', ~PM JETS TFA ANNULAR VELOCITY B.rr HP · ~0 28 ~ 13 1.050 . t09.3 !' ',,, . . , ...... ......... ..., ..... ~ ...... i,"i:' ~r,~,~''';, ;'/,~?;:..:~ ..... - .... '..:-~ '~ ......... - ........ - ............. - .......................... BHA: 1 ' ' . , ~.', .:~:~!!?....'.,..' ;-.:': ~"- .,, .,i;.~,~;.~.,~;.,,,,,,.¥ . , :i,i?']'/::?'. ?..'L ' ' ...' "' '; ":,',"r' ......... ~',--~..~,' ,i-:*' . . _ -- DRILL PIPE OF, SCRIPTION.:':'"'"::":~:~',~i~':;~ ." MAX pULL :" ' ' 2._..~;~ ' ~ .... '~·~,:I ', ~,~ ' ', .~ ~s raND:;.. ?,.:,'::!'~:,.~,',",. ,.',MOTO~ TOrqUE ' , ' ~BGm0000) ' '. I' ,.' '"l' "i,';.,~','.~:~,,',',,'I' '~ I -[_~L ....... :'-:~'-"-'I,~- ........ ~,;-"--~"~"'~'--"'~i'~- .... ~-." ~ _~.~ o~-:, "~:!.i.:.f!.%~;Ag~g~; ..... ' ...........~"':'"*"""':',,, '"""...v~...c.'"::~'",. ...... , ~""'~':~':"="~::,,. , ........ , ,,,,.~""~'"~'", '* .............. , ,'~'~"?'*~:'" ....... :' "-'"'::"::-", "., , - '"~,~., 'i~,~,.:' ' ...... .':a~:TO- ' ~s~.~ . ~. ~z~. 1,4,W.00 ,~..~,~:,,,,,~.:;:, ~...~.~ I. 1,430',46 IF~17.3~ '!42.36 ..M.~8 t.01 · ' · ..... ·',' ' , "~, '. ""., "-h; ' ,~' ,,, ' ...... ~..,: .............. ._ .., ,,~..-.,,. ...... , ,, ,~ .... ~ ..... ( :. ...................... oPERATiONS IN SEQUENCE · ' ,¥ ', i; ;i ,;;" "1:, ' '" '" ~ ' I ~ r _ ~ _ ._ ' ...... , . STAR~ '- EN'D' HOURS .... ::"':iL.' DESCRIPTION 6:~0 7:00 . .,0,~,',..:i.: ~.**. .,!U~!D C .I,.EAN TIGHT HOLE'1490% '15~7',, ' 8:31) $:00 . O,~i?.~.~!'~U~D,CLE, AN~._~I'Fi~__HO.L,~-=_ ..... ~ ..._ ., 9'.~ ~0:~ '~.~0~. . .:~!~r~ .~:~ OLIT OF THE HOLE TO120~, ...-. !NS~JECT THREA~ ON 4' DitTLL PJPE,~. ' 11:0~ f2:30 ,..ill} :' ".f.~ ?i?i: ii~' '.,~~TE AND COND~, N MUD- PUMp $~ '" .~.~o ~:,~ '.',~, ::~;·i?~ !'.P..:p:;.H,' W~-r ~YDOWiV '.~NSm~EN'r, MOTO~,,"JVD ,err. s~,,rrT.,~ oN err'en'P~MELY ' ' h ,,,r ","*'..',', , ', ,,,' , ' i~ ,, : ,, .__ ~,~ ']..' .......... :'" "'.~' :~!~~'TO~'c,,u'.s~e '~,'v/~s .aNn CO~ "~'7' ,~N"~g~_... .... ' " ..,,~:, ,*'i?~'?''';':'''''':*' , ' .'.L,:~i~ "'~."" '~::~,? 'NG."' ': ' ' ...... ", ": "' ' ..... , ,~o:~" ' ~:. ,' .,._~" ? '~B~*p'~' o.D.. ~ ~0, .To TO ~4~ ~oK~ C~CULA'nON, ~UN ~NAND,se'r CASlN~ '.!. :,.'.L'*i.i'.':",.i IN'BOWLON ~ FLOR, SHOE DEPTH A'T*f56r, RD CASING CREW .....,, ........................ · " .... ":r~f~A; ?,?. ,:,', .................................... ~FE:DH ~ il ,..i i.': ' ' .................................. ' ............ COMP TOT L./~T PIT DRILL DA'I'~: ':'~'?',':.---~,.~"F..;;~MUD COSTS '"~""'"'"~ r~,.,,, ~ .... """"" '"' ":~ ""':' '" ...... '"'?'"' ':":" LAST BOP '~EST DAT~: ~'~./' I ~.~I'~&.,,,F..,",, '?t=':":..~':::?"""',:'"':';' 'r'l ll~r-&,,&.,. ~,e,",,.~ I~.~ #~q,~' ! t]#tL I':.:. i::":':,,'.' ::::::::::::::::::::::::::: ' :',~ll~'l'~'"'l ;1'~I ];l:: ,I I I::'l,I ii I I~ ),:',l ' . . ~..:,qJ L:'~L J, TED ; ,, ;--t,.,.. ,.,,,.,~p~. '~ ., ........ .#, , ..... .. .,, ...,. ..... ONLY: 8 CUM:'~:. :'-i'!.4.J264 ONLY: ~6,7t5 CUM: 382,t51 NO ACCIDENTS REPOR TODAY · ,,,.~ .. .,~ , . ',,..~ , ' ~001 C:SG SIZE: 13.375 CsG'MD--* -~,.~6a. "C~GTVD: ~4~_ SHOE TEST: MAX. SI 0 -- ii . IENERTOP: . . , ,. :pRESENT OP: I " ..... . ........................ .... .., . ' .......... :'"~i ; "::':'"" ':'"'''' ........................................ ' ............ ' ............ ' ........ ,'''~'"' RUN 13 ~ CAS/NG 3ET AT 1568': RUltl IN HOLE IMTH STAB IN ASSEMBLY- CIRCULATE AND CONDITION MUD EXECUTIVE - CEMENT WITH FULL RETURNS- KO, Il. - NiPPlE DOWN D/VERTER SYSTEM SUMMARY :..., -:'~: .' -: - vi~-/:~V YP GELS -Wt. ..,?.$ !'~: ~0'"-I~ F~ CEC. SAND SLD BENT SALT DRILLED BARITE i(-w .... :' ' ' ' "":'." "" :'"""'"' .... ' ' "'~'-"" ..... ' .~. 1~41 ~°.[~41, ~'~; I;~I.',,1':..-.''','/' :-I'.i. [- ~' ~ z,. i-'?~:i .... , ..~ · .- ~oi, win- ~._ .Pm. 'if:. , :.,f.-.. c, ~ - UME UUDLOSS;S.~,bU.) BK;D CON. -'~:~ I"~:"I-~:s 1 ~':.('-~.0. i.:..o~.~,1,..'i.i,~ I 1 ...... I";[~~ .... ~'-~...-, L. ' ....... I ' ;'.: . ' ..... . '.: '. ,"" ~ =..~_" " .............................. '~ .... -;'-';-' .... , ......... ~_"7_:.'-'/";':::.' ",'. ...................... I( "Brr~ SIZE TYPE ........... OFF::~,'FT.G HRS FT/HR ;RPM WOB 'IQD' LB GOT R CPF COMMENTS .. ........... , _ ... ." . - I I I. '1" · · ....... "' ......... - .... ' '.i ............... ':~" .............. :° "° ' ' ................ "' ' "' ' ' .......... ' ............. .. .. . .,... i.:. ,~.. · . . .... ~~ ............ . ,, · . . .nO ........... , .... .. DRILL~PIPE DE~CRIP N '"' ' .... '.' .... :::' ' '" MAX PULL: , -, ",! ~ ?';"' , .,..~'..'; ...... ~ . ' , , , ,,_,.. ....... ............ ' ' . ............. ' "' ' ........... '"" '"" ' ..... '.' ' ' _.~U ..... ~ ': .................. ~ ....... :'"'~'""~"'"""'""'? ..... ;W'""~'" ", ','"' ~ T"';~' .................. (_~ _E~ o~m. ~'i~ .. :':!-,.~.!.~,..cno~-- '~m veer. s~c. ~s ~,~7~.~~ ' f~.~o.?..:~:~?i.':'....:~i~7e ~;3~.~ :i. ~....Tg "1 ...... ~7.~e ' i, '. ...... i, ..... ,' r ," ~:~ ..... "~ "" '?:/.'=I'.' '~'?':.??;:.';':~'"'""::'":'.;'. '. ..................... "'~,~..i .~ ...... '.: .... ..~'.' , ,' ' '.. ":.: ............. ~ ,SEa ' ' . (~ ' "'",..,," .~:~:-'~:'";".',::"'"~:,.,'"': ' "0P !~t110~'1 UENCE:...'..,:,. ,, '"' .... :..:.. ........... ;'~.~:,.'..:i. ~.:,.:~;'/'~ ' :.; .... ' · ~ . ~, ,.,..,, . · ~ START. END. HOURS... ~.'. '...~.:',.~.'"" '.' .... :'" "'",. 'DEscmPTION ' " i :' '. :.' ~ :' ' ' .~' ', I{'"' "' ! "'[~!; .... ' ' 6.,00 7:00 1.00 ...:.:..,.RUNi13~, ~ L.~O, BTC CASlN~;, rAG TiGHT ~f~LE AT fsi: WORK PIPE ?0 'I$~' . ,, '~ . . , _ , ,, ,.,. 7:00 7:30 0.$0~,i,::;,~ ~i~. GiD. OTAfl~ CASING EQUIPMENT 7:30 .9~0" Z'~"' .':.'.' '!RIG,~,.P TO RUN,~TAB IN.A~SEMBLY ' ' ' . . ..f3:~,"/~,:,~'~-oo. ,.. ~e :u~.c.~,E, u3, .su,~.4cE wes, sT~. .~. .o.. . ~LOAT COU,.~ ' .. '14:.~.'f~:O0 Z, O0 .' "ei'~C'U~.TL". ,4ND CONDmO~ MUD, HOLD ,':'/~-~OB SA~E'rY MEE'~N,~ .. "fS:~O 'f~:O~ ~.o~ r. "reST.UNES AT ~ ,':'S~, CEME~r~6' wrm r~ SACKS CLASS '~ +34~, ~-M:+' 0.~ .... :.... ~: ~'.~S....+.. O.~ J~46 + 0.3~ ~7_~....~. D AT'~2.0p,~, wrrH A Y/ELD OF z.~ cu. F~/',S~ , ..',."' . ,,, ~ ~ . ., . .. . . , . , . ~.. .... ,.,~...OA~ , , _ ,~ . . '... . 19:01] 2f:0~" Z00' '~' ' ~R.E.'MD~PLU~' DROP//~ HEAD, PULL !TWO STANDS, WASH ill=' SURFACE E~PMENT, LAY ,, ........ ,...;. ... .... . ,,, .... -" 'D~.~.LU. eD~O~NG H~4~. .:.. ..:~ '" 2,...z,..~o "~,?'"'i'i'~~::To.':'.~.. 70,~i:,~,TU~,E ~..:..::,., ' ' ' .... 21:30 22:08 ' 0-~'? ~,Y:~:~:I/l~g RVE JOINTS.OF4' DRS..L"~ .~.. . :. :'~ '.. '~' .277_'0~_- .... 0:30 '. = .'~'~":i:: 'i~':~,: 'RDENED SAVER/~UB, ~ ~ IN~o.STUMP SEVEN 'TIMES, MAKE'SAME SAVER ~: .. ......... "" "~~?~ii::;,,:~.'~:?~i ::.. '~' ~,' ::¥-'' "~' "'";'"'.'::! :" ";~;;'.,?'/!',:,~:! '." '.: ': ': "'"~' ;~ ~'~;',~ ' '~ ...... ' ........ ~~."~ ~[ID COSTS AcTi:IAI~':.i'i:i!~i~i~,~:~Y~Yi¥~:'T:'i.'.'~~ELL COSTS ACTuA"L' ":: ".' ::'"'i;' "~i~ LAST ..:.'...",'. ........ '.~.+~'.'=1 ' ,.. . I: ............ :':~ ....... ~ ............. ':'==" .._.: , · ..... r .f~.,:~ . BOP TEST DATE: ' DAILY: 1,,73.9 'C[I-M:,..:!..-...t~.~:: , DAILY: .. 70.360. CUM:' 3~$,,~g6 ~ ACCIDENTREPORTED'TODAy .. ~]001 05/05/00 FRI 15'45 FAX 19075646489 MarathonOil Co . Well: KBU 33-6 ( .'. {:,~, Operations Cant (d) Date: SEQUENTIAL OPERATIONS {REPORT TII3HT SPOTS, LOC. TORGUINO UP PROBLEMS, ETC.: 112 HOUR MINIMUM ...... ! 002 START END HOURS . . ;.. DESCRIPTION "::'t sUEI'.'u~P~ ';ON ~3P bRIV~ CHE~,K ~OP DRIV~ FOR A~E~. ~ UP~P e~ TO " D~'~N; ~O mcK 0~. '~:~'W~ 0:30 ~0 ~ Z~:~ p.O.H.:~4'D~~ ~.~.. .. , 5:00 '6:~ ~.~ M~DO~ ~R S~ ' ':: ' - ~. .~. '" ~ --~.. .... · ~. .... ... ~... .. ~."~' ...~ ~ ~ ~ ..... ... ~ .... ,,,, .... .. ............................................. ........... ;,~,,~. ,..,,,~.;,.~..~.;,~:, ~ ............................... . ..... ......... . f,..... ;.~ ..... .... :-..: .~ y...--,. ............. , ............................ ~'~ ...... h' ........ ;~"'"'& .............................. "::' ............. .~i5 .~.."..'. ' .:rYl'j~.':'. ~ ~; , ...'-~ ' . .:: .......' 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'. ~ ~, ' '". . -,.:, ,...,...~ ,, ,,.. ,~ , ..... · ....... : ............................... :., ...... . ........ :,?.,;,,~.,~.,,.... ,~,. ,..,,,,,,~ ......... . ...... : ............... ,.' .......... ; ............. . ......................... ,.. .......... ~ .............. : .... ~ ...... ~ ..... ~-.., ,: .......... ~FE: DH ~T~G'' '.'.'..:. ,~:..?:.v.~.~.::. ' ~MP TOT ~T .... MUD COSTS ACTUAL. . " . ~ COS~ AC~ ~. · . I ~T BOP TEST DA~: ~~" ..--, ..........· ..... ~..~ D~Y: ~ CUM: 1~ ~LY: ~6~13 CUM: 401,~ ~AC~~ ~R~D TODAY D;~UN;SU;;;~o~: ~R~;~?'~E.~:~~' "',. ' "...... ~'~ " ' ' . . .-'."; .~.,..., ~..:'. '~...~:.:~.~ .~. ,, ~. . .. : 05/06/00 SAT 08-57 FAX 19075646489 l~arathon.011 Co Marathon R[ ', i i:i:~ '/3 DATE: 05/06/00 LOCATION D, ' ~3 SPUD DAYS: B Oil Company . ....: At=I;;;(i .Z0~699 GL'. S6. KS: :~" MOC W~: . .., IJNER TOP: . ~, . ."' ' .......... '. ~':...'~..~ ......... ~ .................................. ~,,.,.,,...,: .............. ' , ~ ~ . , ~,., ~- r~'.'~ ............................. , ............................ ~PP~ ~ B.O~..~ ~ST ~O.P. AND RE~ EQ~~- ~~ ~OOT ~CO ~P D~- ~Y ~C~ DO~ D~ ~PE:~.~cKU~B.H~ ~D ~H, - ,, . '~ , , . ~UM~ .~ ,:~.~ c..: ** ., . ,~,,,.,'.'; ,.**..~, .... . .-. , . . .......................... .,.;.,.; ............. ~ B~ "~E ~PE ,, .. . OFF . ~G H~ ~JHR R~ ~B I'OD LBG OT R C ~1~ ~. SERRL~ PRESS. GPM ............ J~S '~A ~U~ ~[~ Bff HP~ -~.-.. ....... ..~%,.. 'Z,..~,'. ' ,,.. ,., , ........ ' ' 18~ : ............................... ~..?~:~. ~,,. ............................................ ..... . ~, ,:,.,,, . ', ~'~ .......... ..................... ~.,~ ......... ',~.. ¥ ....................................... ,. ,, :~.,, '~'~,.;:~; .,~:, :.. ,, :, ,..,. · ................... '., ..:,;.'~;~,:,.: .......... :: .... D~LL PIPE DESC~PTIb~'.'~"";;:~/":~:"*?;F;~?;~:.:~': ? ":'. ' ' '":' ' ............... 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' ~/'.'~"" "~:' ' r',~ ................... , .... ,.,,, .......... ,', , qe:30 fg:~ . . , 0;~.; ~'~ :p~LC~,~,pL'UG AND INS~L ~'~NG. * '..,,,.,., , ................. ~30 t:30,', " ' /.*,' 3:~~, ~'';' R,I..H;,:~H DA~GED 4" D~LL ~- ~H AHD,~y DD~ ............. 2:30 3~30 ' ~ ~:"'""~ ~kC~'~' ";* " ~RI~'E~PE FROM'~UCK ANg '~N~'NM BHA ~ ~G FL~O~ .. ,L I'"" ...... ~'"~h~'~:'' b~, ' '',' ',, '' ' ' : .... .". , 3~0 6:~ ~ ~ ~GK,.,~P NM B~ FOR 12 1~' H~E :: , ' *C,',,'*, ~ " .: .,., _ "?,'.,~"" ?'~,~ ;~ 7:05H~, TO 7:~0 H~-" '" "~'"".. ...... :':":",.. ............. ,::":* ' ' ': lf.~HRS. T0',11:~ HRS. .... :" : ~. . ,',,,:.: ..... :~=..,., .:. ;,..,;,.'~ ,., ~,,~ , , .,, . .... ' ,.-",',,,',; .... ~','-~,'~',~',' ' ~/,.'~.,.~,, ............ ,.,,,,~'~,v , ,. ........ ;,,,',,; ....... ,',:~;,,,,..',~ .............. ,..,,..,. ~E: DH ~T!~' '~?'?~":~:~":"*::;"".. ' COUP ' TOT" ~T ~ D~ .,.,~,,:,~ :~,~ '..!.,.t MuD C~TS A~ i::~'.:;.:',<,:,.,:, ~' .~',"'., '.'"'?. 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ANNUl.Alt V£LOCITY BIT [' ll.K',-- [ ~' .'.9.,~ L,; J'.i ...~-~" -i ,, ,, aO ,, .,- . ._~.~. _ _. k...'L~2.i,:.'::':?':'.!'< , . ........ ' F"'""2' "~:' ":' :' :',".". :' "" :?' .: .... .. %"':~,::.'"':~I' '".i''~ ".:: ","' '~" ' ....... ~ .-' r~L ,J~M~S MWD' ':.: .'.. ~' :"" ":.:"..MOTOR TORQUE Wi~IGHT (1000) ,, , ............. i'-:ii iii:.'i.. i ......... ',,o ' :" :': ..... ,,,,,,-'" ........................... ................... ........... "" .... :' - ""'."° ! ~,,..,~i:,' i'?.!i.'.'::~'- · ,.,,~.,,, ! ~,~." ~., ~ ,.1, ~ I '"-~ .. I i,.:'.'. ':ii~'i. '.,:fi;-,". 1 .........., ........... .................. :: ............. OPERATIONS IN SEQUENCE , , ~, .: .',~:?~!'/,?.",~,':':,',.,...,:.,~: ;, ',, . . , . . ~TJ~T END FIOURS.~. :'.:.~..;/"i.....,i,.i~:i:....:' . ,: ': "D'ESCi~IPTION .'.~. ' ..'.~:® -- ' ,.:,~. .Z~..~'..:',..,~K!U~'~,~:Lo,,.~.~, o~.· ' ~.:. 8:00 10:00 . .2,../~.,,:,..,,.,. ~. P,.~gI':RROKEN ELEVATOR'HosE° AND .GIRARD .' . 11:09 16:3D . 5,50'.:,.:~': :IPI.CK:U~ DRILL PIPE AND STAHD BACK"iN, MAsT FOR NEXT HOLE SECTION , ~, i ' '16'.30 ~7..'00 0.5[!'., .? IL[H:.....~ STAND~ FROM DERR/C'K T0..'1456: '. .... Il'Ill i I 'la:OP ~8:30 TAG CEMENT (~ ~$f8' .... ': 20,'00 CONTION M~ 20:00 20:30 CASINi~ 7'0 '1511~ PSL ................ 20:30 2~110 ~ 1523- WASH TO 1538'TAG CEMENT:.'D~ILL · ','.~,: FLOATSHOE I~ 1568' 22:00 22:30 l~SO 156~' TO BOTTOM AT lb'7.5'- DRILL AHEAD TO 1594' 22:311 23:00 0.~0'. ' "' BOTTOMS UP FOR LE4K oFF TI~T ..... 23.'0~ 0:0~ f.00.*, IMTH 9.2 Pgl~. MUD WF, IGHT..EMW-- ~2.6 PPG (260 P~I.) ' ' 0.'00 2:30 2.50 .... . PIT FLUSH CIIi'CULATIN~ UNE- MI~ SAFE CLEAN SPACER. PUMP SPAC~R .... FLO.PRO MUD' ..:" DH TST/CSO":'"~:!?"'":~!:"~-""'~::"~'.~;'"*i! COMP "" .iL TOT . ,,,.'i,~. i .".~__J .U~T PIT DRILL DATE: ~ ~, ,.,.,.,.,..:.-., ,,,,,, ,~',--,~ ,,;-,,".(:;.;,;'.,,,:.~..,::.,,:.,'::';,,: :.i.,:~, """"'.'."' w,=~ ~ co$~.A~AI-:[~F?....,.'~.!'~.J um-.o, TEST DAm ~ JL.':¥I::¥~ q ":.':"C'¥q m~l~, ~.~,,a ~ ~ ~.. · ~ F..'-.:,~V;~//~ '~ i'~.l..: 5.rE,.'..." .'..'..% ' ' '.'.'.'".~,u,~!~ ..... ' ' * ;".'~iI ' ~.';~ .?,.::m:::!:'': '~',',.~,',:-', ~":~ DAILY: '[.~93 CUM: 't6;5961;: ;'"~i t' DAILY: $3.,2~." CUM: :: 6,:1~,Stl./,.. J NO ACCIDENTS REPORTED ~I'ODAY .... !..... .~ .:j .... ....,.., ...... r:'... ....... ~ ..... .:~,.,,....,..,:~.....~.,........ ,.,. , ./,., . · ., ,,.. ,; ,;.:., ~:,,,.~, ,., ,~. ~.~ . ' :, ', ;~';~,~: .~ .~,!,~. , ........... . , .: ......... :~.. ,~i..:.::.,,..,..i.:.':': 'i' :.... 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'. :':::'..~ ~.~',:~:,::':',?MOTOR, ' TOQUE ~ ~., ',', WBGHT (1D~) ** -. ~_ . ...'.~ ... . . ,, ...... ~ ..... ,,i ............ · ........ , ..... ,[. ,,,~.....,.,,.,r.,::..,.~ ...... , .., ' ................... ~'"''"' ' ;," , .................... ,'m ...... ' ," ; (M~ DEPTH . ~GLEr ~.....::.,.'..':..4',Di~,~ ....... '~ ............ WRT. ~C~ .................... ~ ' ~ DOG LEG '* · ," '.'."'"'""~" ............ '" ' ............ '"" ....... l. i ~ _ ~)25.~ ~' ~,.. ~,,;~ ,, ~:~0 ' ~7~. ,,' , e~3~: ,,. ~9.~ -~.70 ' 0.~ . . ',':' ~ ...... , .... r ~ : ,.:u'" ," ,,,::T,.,~'.',,,, , ' .., ~,~ ,,. ,,: , ·. ~ , ,, :' '~:.~",*~" ,. ~ ......~,.~ ,~: .~ '~'L" , _ ............. ..., ........... , ................ : ............ :.:,,.~?':...;: .... . .. '. . ~',,~ '.~ .,,,, .., . ,...,.,,,.,...:. ,. ,, , ,,, , _ .,,,. ,~ ..... .. ,; :'~,':,..~ ,,,,,~, , ...... ., ............ . .; . ............ ' ~ ' . _ ,, ,,, . ,, ~:~o ~o .~..... .R~.,~.~Uuc~,OS~.pN. c~~.~.:~K....0~ co~J Box 15:~ 16:00 . 1,~?, ~~"BO~O~ Up.':~R SHORT.~p ' ~LL ~ T~K ~D CHECK FOR FLOW" .... '"' ~~ Tff eonS...~':. ;',:,:?~ ~",,.' .., :.....~:....... ........... .... .....: ...... , _ ,..,,..:... ~2o' o~ ~$0. ".D~.~~~M.a~To~ ' -. .... . '" . ,, ,, ..... 2~0 6:~ 3;~ '" :~~, FR~. ~' T0 321~ ..,.::',~:','~,..'.',",,..", .' . , ,* ..... , . . .~' ..::~/'.~ '~'.,.. . . ~.. ~ .: .... ,..:...::,.::',,: ........ .. · · , ....... :.. I~'"'"', ' .... ~..: · ,.., .. :):, ::.~..~ %.~:'~,~?~.~. ~'.;, ..... ., .. ... ~ ~ ~;~,,.~ ... ,~,.~.,,:,,,,, ... ... .., ....,,. ,..'~:",. :.r,,....,. ."L: ...'. ' ' · ,?' ' '~.,',.;",-~"' , " ...... ':'" .... r~" .... . ..... ........ ...:... ..... .:,, ......... ,,, ................ . · . ~7..~:~;.r ~..;{':~.. ~;.~.:.: ~ . '~..': ..~..::~ :{... ...... ,..:,~. ,,, .,, ,, ,,, ,~ ~..,,.,,., ........... ,, ,,,, ,, ,, ,,~ .,~ :,',, ,, ',:,:,,~ ::,,',,,,,, ~..~,, ~F~ n~ .... ' .................... '~':~ ,... i ~T/~G.,~'...,.f:.?.~,.,~'.,~/~' COMP ":':,'.. T~ "'~' ........ ~'. ~TP~D~~: ~~ ....... '.../ ¥.,~ ;... ' " ..... ' ' . ~v ~';:' :"' ' ', ,~ MUO COS~ AC~ , ~I.L costs . ' ~T ~P ~ ~ O~ i ' " ....... AC~ · . · DNLY: 3~(J76 CUM: 48.~2 DNLY: ~f601 ~UM: 76;,~82. ~ NOACCID~ ,, , '.';:' ' "a)r,".... , -. . . ..... ., ~ ,. ~ .,_ ..,. , ~.002 05/09/00 TUE 06:50 FAX 19075'6'46~89 ~ara~honOll Co Marathon "'"s ,'"" 'i'~ 16 DATE: '05/09~0 ' LOCATION [ : 16 SPUO nAYS: Oil Company .' 9z0:~699 GL: 66.*, ',.: . '-'. KB: MOC WI=. ... . ..... '.:: ,..:, ' ,,! . ~ 11 ~,003 NELL: K~U 33-6 CSG SIZE: 13.375 12.50 MA~ SI ~ LINER TOP: ' ': .:- . - · R~.~EENT OP'~J~.L '" , ': ........................................................................ .. ~v,.~ .................................... ~-~ ...... ,....,...,,~.,,...~. ~..v. .. ~ · ~ DRILL AHEAD TO 3'/35'- .MAKE SHORT TR/P- DRILL SUMMARY . · (aiL'- w~ pii"'-?~....... M,r.. : cc c^. u.£ .uocos~;s · 1'.: ..... ~ -: ...... '"'. .... "- "-"~, , ' ,', , ' ....... , . ! BIT# SIZE TYPE : OFFi :'".FTG HRS FT/HR RPM WOB I O D L B G OT R ' CPF CO~iIMENT$ ~ ' MOSSODCL " :.'i*. . Bff# SERIAl' PRESS.... ~M'. '" JETS ~'. .... ,.T_F,_.A& .... Z:. ANNUL~**R'VELOCITY 2 LK61~7 "~6 16,20 12,; . . BIT HP ~ '.. .... : .?..,,. ,...?.,..i'.~.,,:'.:.~.'. ...... ~ ................................................................... , 8~ .......... ::.....,:-,.,.:~-~.:/~':i..',!:~i ................................................... ................................... '" '~RILL PIPE ...... *; .... ::" "*%?"'"*'"' ........... ' ........................ P: ..... DESCRiPT~,ON. ~ ~.:,,,~$ :...~P,~.3 ,J~ :~~..,,}.:: ': MAX PULL: .(~_ JAR,~ 'MI/VD .:,, ". ? ,,':MOTOR TORQUE ' '~0.. I~aY' 'i'".'~o.~ I~" ' I" ~"*s .,.1~"~'~ '1' ' I..~,: P--.S '-R,~- ~' .~, ,~ ~' ' ! , ., ,, . ~ ., ,;, .., ,,.'.., ~, ~ : ,.,', , ,.' ' ,.,,.'~%-,; ,,...,,,.~., . , ........ (~'~IIEA, DEPTH.. 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DRILUIIIG SUPERVISOR: DARRE.'~"~E'.N,, 05/10/00 ~/ED 08'06 FAX 19075646.489 ~[ara~hon011 Marathon · R;" '.,.,':" t7 DATE: 05// OilCompany AFEJ',. J203699 (;I.: 66. immKB: MOCWI: . · : , . . _ .., WELL: KBU33-6 RIG: Glacler Drilling FTG: '/51 DEPTH: (MD~. 4,293 O~/O! 3,915 i:S~S=E: ~3.~75 CS=M0: '.~,..r~...:..:- cs=~m: ~,~z sH0;~'~--" ~zso M~X. SI" ~ MNERTOP: . ' '. ........ ' "~ .. --.. PRESENT OP:TRIP IN HOLE . · .DJgJLLAHEAD TO 4293: ~ACK REAM OUT OF TI4E ,HOLE TO3326'..,~.F/NISH ~P ~~HO/~ CHANGE OUT EXECUTIVE BIT AND MUD MOTOR. TRIP IN HOlE TO `/530'. CUT DRILL LINE AND SERVICE RIG. CONTINUE TRIP IN HOLE. ·. ~.- ,, ~. , '. ? SUMMARY .., · i ~.. ,.. , · ...~ .. , ... · .*... , ,.,~. . , .(OIL WTR ,, pH Pm Pr'.' ;" Mr:. , CE CA UME MUD LOSSES (bbl/ft~. BKGD CONN TRIP MAX 0~ ' "' '"'" ~'" ' · . , _._:_ ~..,~, .' .... · ............................. . ........................................ . ..... ~ .BIT# SIZE TYPE OFF FTG HRS FI'/HR RPM WOB I O D L 9 60T R CPF COMMEN'T~ ') = I ........ I I ....... ( B.rr# $ERIALg PRESS... GP, M JETS TF&. ANNULAR_VELO~ ___ B_ITHP) .1 ILRgM' I ':"1~'" '"/"r'* 1- - ' '/618:2012 '1 ''6.2. I'' ' ~ t ,..' ...... [ ... '.: ,' ........ ' ' ., ..... ~9::/.~4 .: ....................... .. ,. .......... : ......... ....... ~, ~, . . , ~pa · : , ;~ , . ,. MJL1cPUL[:'" .... r,' . , ~ . , ~" ~' "~ · ',';,'. JARS MWD ":,,:....',~,,,.:,,::!::MC)TOE ' TOIKI.~E .... :::, ::~ .:','~',,.:' WEISHT (1000) :'.': ': ' z~ D..~'~' J :2~.0 1~'', ...~'.. "lr'... ~: ,'".,[~,~ ] '":li~"~'; ;' ...... ~, ~'/~'--~- ~'-'SO ~S "'["' :.. 4,-1~.0~ "2~.z~:::. !'~"' F.:'.L~'!.,1o ~,?S~-~e ' ~,4o~?P:::.': ~,~4,~o~ -~.~ '. ' o.Y;- ' "~"'' ",.- ,'n'.,"': ............ . ml' : ' ' , ,, ..... ,.,., ~.;.; ,.,.I..,.,'~ ~, .. ,., ,,.,..,,,,.,,,.;,'~ ...:.,., .................................................... ', ...... ; ........ ' ...... ~..;,.,,',.~;,~-,.T,: ;;4 ,. ,',',..,.,.-T~.'. ........ ',;.~,., ~ . , STA~ EN~ HOU~ ...~ ;.:. :.::: I 'DESC~nON ...... '.'~,' ~0 ~=~ O.a~ . .~c[ ~ OUr OF me HOLE ~RU,:THE S~U~e,~S FOrenOON TO '12~30 , 13:30 '/°00 ~:~'~ ~.~E_~ _ N=' ..~ANI~., TO-- ~ ~~i~ .~-,i~. ~DECR~NG TO'/t}K-151C ........ '13'.30 '15:00 1.50 ,CI~eCULt~ BOTTOM~ UP .' ....... "' ': '/~:on '/6:~0 '/.~ .... ~.~.,~ ,m~', , -nGFrr HO~ ~?o~: 6O,~ZoK DP~4~. co~rnNuE BACK ~EAM TO '/6:30 2/.-'00' .:.: 4..'50. ';.;'i ~.~:i~ ~_ LIT'O' "*LF~.. . ' ~Hr ,RJ~(:-~i~'~:,'~ TO CSG. LAY DOW MUD MOTOR. .' ,'"~;;!~..:!", ~ ~,.,q.T.,,q~,~D STABS oK ON/~-V~SUAL flVS~EC).i".', , ,,.!:., , :,. ........ 2:oo 4:3o ~e ~.': .~ *CUT I]~ UNE AND SERVlCE"~ · i .... ~ '' .:. , ..... ,~: , : .. ! ' , .,:.. ,., , L,,, ..... ,:* ,, , .......... ~::.:-~.~.;.,,.;~.. ..... ::'~,,.~ ..... i..__., .... ).._..... ....... ~'_::*i.~"..,. ,.,,~ ~ ......... ?'~ .... :'*: ...... . ', '.......'.".. ,~ * .. :' N:E: DH 'mTICS~ ".* :.'... :i"~.'* COMp TOT ". ' LAST Prr DlaLL DATE: :....,..: ~..: ~.~,~:...:,....~,.s:~.: ~ ..... costa ACTUAL I!i~:~:~ ~:,*i:` :;:;:.i'~*'~*(,i*i'i~,';/':~;:~:';. 1 W~_ COSTS ....... ACI1JAL .[':'~1'~ C' ,* LAST aDP TEST D~TE: 0S/DS/MI' .... , ..... '1': ::'":":'! ~ :'":"- -': ~! '~' '" "'""! DAILY: 7,?~9 CUB: '67~i:!~.i'/ ' DAILY: .l?,a4f. CUM: - &40,6M NO ACCIDENTS REPOR~.'TODAY ·, , : , ', , . .:,,, . . ,~ iDRILUN(~ SUPERVISOR: OLW ,.~;. ,, , ~ ... ... . ~001 05/11/00 THU 07:13 FAX 19075646489 Marathonotl ~o .... . / -'~: .. ~ :' . ,..:, ,~ Marathon · ~''' [:":~' ~'-..}~..- ~8 DATE: :.O~f~, :-, ~OcA~ON '~,}: T8 SPUD DA~: Oil Company ' AF 9~3699. GL: 66,'~ KB: MOC ~; ', -"r, "' i, ,, PRESENT OP:DRLG I~Ng~l' : ' ' . -.. ,, F'INISH Tt~P IN '~iOLE. ROTATE AND SL/DE DRJ.,G. F/,1293~..4859'~ W/PER TRZP TO 4220. ROTAtlI; AND SUDE . · EXECUTNE DP, t.G F/4859'.49~: I ' .... .. '.- : ... ..'. ~ . ~_OIL ~ pi'il Pm P/ Mr: ' ' !:CL "CA UME MUD:LOSSES (bbl/ff.} !. BKGD CONN ! i,,rJP MAX ..} ................................. "' * ~i .' ' ' .. ;.. - ...... ',:...: .... ". ," , ._~ ............................................ '"'v...'.:.'. ............. 3BIT# $~7~ '"TYPE OFF. ..... , , ,, ...... . ................... ,, .:~,'.:,~ ,.. .~ ' .... ,,. ...... a:30 22:30 14,00:'.. '!i :ROTA.,~!AND sUDE;DRLG F,/4. ,293~8~'[','.,A'VG, I~RAT~ $$;131}'MR WlTtt OCCA~IONAI~ '.,,. ..sWE~.WITH NO MARKED. i,NCREASE !~ ~GS R~RN$ BUT CON. SlDERABLE 23:30' 'hO0 .... -!:.SO ... .'fl}.$TA.ND.i. WIPER _TRI, P 70 ~. ~OK.~OI(.DRAGF/4164'-4675:o IOK-2SK .TORQUE AND.ERRATIC TOOL FACES,.A~ DAILY: 10,046 CUM: -.~[,60(~ DAILY: ~'7,~5! CUM:" 1i9B,545'." :'NO ACCIDENT~ REPORTED TODAY DRILUNG ~UPERVISOR; OLW [F.U. uul 05/12/00 FRI 06'$2 FAX 1,9075~4,6489 ~Iara~honOl~:co /~(/'~ · '" .... :~' '/9 DATE: ' ~~.'2 ' '.LOCAnO; ~: ~9 SPUD DAYS: 14~ Oil Company :.,L ' .> .: ,..~..>~ .., ..... *' CSG SIZE: '/~:37'$ CSG.MD:..;'/,$F,& CSG TVD: · 't,542, "sHoE TEST: 1,!50 MAX. Si 273 UNER TOP: EXEOUTiVE . · ,.' . . ('MW ,VJS.PV YP GELS ~ .,.T 7,6 3~ HT FC CJ~i~ .~ttND,$LD BE~T SALT DRILLED BARITE Co_IL wm p, Pm ~f' m. "C- c~ UME ;~Un~.oss~S:;tb~.. "nKc~ comi' ' ..... i ,.. '.. i ' I . .~ , . , .( .BIT'~ ~,ERUd,.=. PRESS,;'., .},, {:'~PM JETS .i ':.~TFA ." ..: · JU~JNULAR VELOCITY BIT S."~I $."00 24,09 .p. 'R'.O. ~/4ND AND SUDE D ..RLG F/498~.;." ,~. ;,., ';16~' TOTAL SLgDE DRLG ..... . ,, .... DRII.HNO ...... , Mar'dtlloI1 ..../:. ...t',:. 2~ DATE: ' 0E/~A/0 ,~.. LQGATI~K ;~ ':~:~S: 20 SPUD DAY~: 15 Oil ~amp~n¥ .... -... ~.~.o3~ ~'L: ~t'.~'" r~: ~oc~: .., .__:_~ ~TOP '" ,~ ~ ~EC~ ~P O~ OF HO~ TO R~ 9 ~' CA~NG. .': ..... .,' . .,.~ · ,' ',',' I ~ ' '" ' ' ' ...... i , , ,, ' .,I (.OIL. ~g pH ~ ~ ~' GL ~ UME MUD.LO~,ES [bb~, BKGD coNN TRIP ~ ~ , , I , .~ ~ I · ,,',~,,, . , '~ .. , ',....,:, , .... , .... . ',,.'~,'' ,,, .,:. ,,', ~, '.,' ........... · .:~..~,...... ~, _.: ,:.'.: ::.~'. ',:~ .. , .. ~ ~ . . ,~".. ?...,,," , :.'~.~ ~. :. ,. . . . ,...~ ~:.. :: ... :. ~,..,. ....." .~ .... .., ~ ,. . ! '";" .. : : MUD COSTS ACTU~ ! · · ,., ... ~. I w~LL C~', ~~ ~' ~T BOP TEST DA~: 0~ · . · ...... :' ii:::::: ....... ,..: . . [ ~.., ... ;.'.: ~...:~, "..,' , !' .'.... , ...... ~! ........ ,,, ......... .,' ,,,~: i~.,~ ,::, :'k,:.. ,, "': :,:.,' ,,,',:,*'~ ' .. ': ?q~,:~4: ''-.~ ........ .',. ',;,,? ~'~,t¥~ ,:,., , ,. .... ~ ,., ,yl ,~.' .~.~ ',,,...~., ,,, ,,, .. . '.'. ~.. ~.,. [?:'..'~ ... , .... ............ Q ~, ~,,, '~ ~ ........ ..... 1 2., ..... '" ~' '.~".)'."::...~..,:'i :.~' :' ~'' © ~ , ::.~. ,..~ ........ , .: ..... . . .. .. · ~, ,.f 05./._1...4./.00 .... SUN 13:43 FA~ J. gU'I;)ti...4, ti~t~U laa~',.,caonuJ. J. Marathon ,.. .~ ....' ?.i:.,~ ' .....2_!._ DATE:.. Oil Company AL. 9~osa~9 GL: , 1. MOCWI: . ~G ~: 13~75 ~G MD: 1,~. ~ ~" 1,~Z SHOE ~T: 1~ ~ SI 2~ MN~TOP: , . PRESET O~RCU~ W~G ~EG~ ~ST BOP. ~ UP ~D SUM~Y , ,. ' ' .... . ,, , , .... ': ' ' ......... L'2.2.'.:?'2'. ',' ,,""." ':'" "' : ..... . ':'. '..:2-~;'.~'.' '".2 ......................... ' ;'-'- ...... ~ ..................... o., I~l mo1 ~1.~ I ~-' I"~,~1 ,~ .' I"'""; ~ ! ........ [ I I, · .. ,...~= ; · ,' · ,, , ,,, ,' , ,,... .... : ,']., ,, ..... , .................... ............ , ............ .-.~ ...... , .............. , ,, ~ ~ , .~ . ":: ,..:.,.~ ,~ ~ ~: ~:~ ....... . . ~= .... ,,. .. , , ~. , ::~ .,-,. ,::. . : ,. 89~4 .... ( ~S ~ -,. 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KB: '- MOC WI: .m WELL: KBU33-6 PIG: Gtac/~r~g ~*' FTG: 0 DEPTH: (MD) 5.810 {TVD) CSGazF.: ~C~ css~ ~,a~.o. -..c~n.,~:' ~._.~... '-.~.o.~: UAX. St n ' - LINER TOP: . .. PRESENT OP:N/PPLE UPBOPS ' , . , : , · ,' ...... , ....... ,,,.,.~,,,,,.., ..,,.,,,,,. I ,, ;,.,,,..,,, ~ ,, · .:. * . ......... :,. -~'~ ..... , .......... ,., . , ...... 'CEMENTS .~' CAS/~G. ~ DO-WN BOPS AND ~=T,SIIPS. Ctn'OR= C4SmS, ~STAM. TU~WG HEAD EXECUTIVE TEST. NIPPLE UP BOPS: ..... SUMMARY i*' : .... ' . ,. '. -: '*.'., ~ ..... ~*.' .... '" .~. :. .* ' 2.. .,. ', . ~ .......... ' . . .... ['. ,, ' '~:', ..... ' ....... :'~ ........... '--"',' '~'.--'? ' "?~.'. ' ' ' ' I ','~ L'.'-'~ ...... ' ................. ; ............... (-MW v~s ~V YP GELS' ..:.Wt.... T...7.,... ZO. ~ ~c CEC S~,~,O..SU~' ~ S~.T .nm. 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AV~ ROT ROP 60'.,60 "~:~*" ,~[:.'.~CWENT MOTOR ~) DRILL~NG:,STALLS IN THESE SECTIONS. ~OWEVER, ONE, ::~.... ~ I~ '.AL. L REQUIRF-D,TO:...CLEAN !JP... .., AND COt, WECTION ~ AV~ 20~ ,, :r .r I Il ,.,'..r ,. , , I%FE: DH TST~".' "' '-' ..... :'- COMP .... : TOT ....... ,. LAST PIT DI~LL DATE: .... , .... . .~(~l)~r*.~,,'..,: . ' ' ' .... DAft,Y: 14,888 CUM: '~2.;,992 bP,~..Y:' .53,549 .... CUMt'.' '-":!~,'~.g :.NO ACCIDEN~ REPORTED TODAY ~001 0~./..1. 9/00 FR! 06' ~2 F~,/~gb~7":~6~89 ~'~r~ho~'Oll ?"'~C° M~hon :'~': ':'";' (.,/"' ,: _~ On~. ~~:. :: .".LOCA~C (. '~: ~ sPUD ..... ~ ."': .: KB: ~., :1'~1. MOCk: Oil Company ;, ..., : 9~99' '..:G~ '.66~ ,~ WELL:/(BI]334; RIG:'~'G/aC/er ,Dr?§ FTG~' .. 4'/Z DEPTH: (MD) 7,587 (TVI)) 7,050 CSG ~ 9,r],S CS~ Ja~ ~'-.a~.a cs~i~m: ~'~'~'~,~ .i~. S'.OE.TEST: 'T~0 MAX_ Si ~,0S3 ' UNER TOP: .... "-:-~ -"' ': '"" - pRESFJU? OP:TR/P OLffOFHd~E::!~' ' .". :. 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': · ,,' , , ,.: , .'~,,' ,. :.;.;.- :.*.,'~ ;::;,;,': ~,: :,.:~,: . , ....... ., ,r, , ,,,,, .' · ,..,,., .,..: ....... ~.~...'., '"'~:~' ' ..:i':i :;'i:;.': ,,..:..:,.,,:.,f.:..,..., · ;~.~", . I '" '"' ,' .. ,/ ; :, ".:t ....... '-'" ' ............ :.~ ..;.;.,..,.;' :.:i,:..,'~: ....... ' ................... '.:,.,'i'",,'..". :;.; ...... '.' KFE: DH I'~TI(:~,G ~.~:i.?~.:. :i,.'.......:.~.~:'~:..,....,~: COMP ....... ~!: "~ TOT :.:.:~:.:,. :.. . .;:,... ... LAST PIT DFUI !, I~'' '"":.: :i"up cc~'i~T~ AcTuzc'. :'-'.' "" . ~'~.L C~'AC~ :':':~'~_"- L4ST e~Pl'r:s-r DA'm: OS, SOo' DAILY: 2,568 CUM: 136,497., DAILY: 34,53,5 CUM: //f46,/71i NO ACC/D~~~DTODAY . , . ~_,~ ~,¢.,1..,,, . " ~...:.,..:~:~, . .~;;~.,., ,..: ?.:,..:.. ,... I~1002 05/21/00SUN11'27FAX19075646,489 · ~aral::h0:rx01'l CO o. ',';';'i':""d- ''-0,. . .... ..: i , csGs~;~ ~s .C.C.CS~.aO:: ~:.~'f.~:~'.~ CSe"1'V0: ,;;S:,~. i:'.SHO[~'~s'r: f3.4o MAX. S, .~;: -. :.. · .... -..,-....,,... . ..,, . :':.~.~'.'.';..; ,: .... lINER TOP:- . .~. ........ . ' : ......... . ........ PRESENT OP:CIRCULATE ANDRAISE!MUD WT . .;.?. ~::."~ *_.~; ;..?..x':;.; ... - ..... ........... -,-. ..... ,..-...,:::: ..... ',.;,,,-&; ..................................... , .................................. L~,,::;Z,:L*', E','.;' :;i .............................................. ; ................................. ~ .......... EXE~ DRIVE. TRIP IN flOL~:::~~TE AND IM~E MUD ~~. .:-;:: .;.; .'.: ,,SUMMARY .' '. · ': "'::';?: ::", :'; . 'Y'? '".'~.' ", .' .: ' ~ ~.' :..:,' ..:~. - ' ',,~- .-....:.'~1~,c.: ,.4¢ '~,.' _ .,., ,, · .. ,.,,....: · · .. ...; - ............ ~r... ...... . ........ ? .......... ~ ........... . ............. r,~,,~ ..... .-.,..~,:,._..._ ............ · ........... , ..... (~,NW VISi:~/YP GEI.~ WI.-T:' 7.~i .... 3{I lit F¢ CEC .,%~D:-..~U3'::,'BENT ..~M.T DRILLED ¢ O~L wm ~ P= ~:..~.' '"' W".':~.;..:.'CL CA U~,= MUD CO.~'~_"'~::~ .... i~i~=b .... COmN l'~P ,,., ] "i t,:.. ] :1 I i' 'I ,' ',,,- ...... ,', .... '-;-'_-'b ?.'' '.';'_?~; ' .: . ,' .'-,', ,.; ...... , ,,' . .. ? , 'a_/: .............................. ( BIT;~ ~ TYPE OFF ,:FTG' HRS FT/HR RPM WOB]O'D/LB G OT R CPF COMMENTS ,--, ' ........ ' ' ' , ,, , 1 (- ~n~'# ~.L# P_~':/i'..o..PM;, .... .. ,J.~t'~_~/;'.,L'_~.,',,:~A:, ~ut.~~,,.. . ~rr~,_. 4 l~w~ '.q¢.'. '~:..:~' : ?~'.~.~..:. -~'"~"~"" ...... " - ' ,.. . .,..:.. ...... .... :. .---- e~ : ~ ~ ~, ~4~H ~J~ ~..~.~ oEG, s,.~, mm, P~= S~ ~o s~ ~,~ c~ s~, xo s~ ~: .... ': ...;..~L":...',¥.;~. . ;'. .... :... ;~.:::i: ':" ''':' '"" '~'''':'' · ",';'.':i:'~; '~'~;;~;~'.,~?- .................. ,,~ . , ,.,~.,,.,, "%"/" ,; ,,', : ..:., ;', ,, O~k iq~E DESCRIPTION: ~ :~',ilH~& 3~, S~"~~! :"::";~ :';';;"'~:'~ ...... ~'"' "": .... , .. . . . l~.~'rl' "w ~,i," * ?;' '.1"~ he · '~ .... "':"--";*~'""'~ " ' _(..'" ~li~$ ~'a3,, ,.'~',~,;~:i',,q,~,~;~:,a~R .... :~; ;TORQUE "!,'ii;)::,~:.;:~,,':; ;' , W~lGi.rr 11~1 .... , ~ ...... . ........ ;: ,~"-.. ?-"-'-' ;,,, ;:~,. '~",, ...... ," ,~,' .r',~'t.',,,, ' ............ 'I ........ "~'? ......... - ......... ,~'" U'r,??"r ~ ..... "i"', ................ ' ......................... ~"'- ' ' 8,0~'1.00 9.~5t~,~,~.. '?.!;!~.,.'[".[~.~..,:40 ...... 7,S~.!;~'.!~'!t;~;- _2~i_~.il'..i::; ~.::'.. ~199..76_ -1,077.~1 0.16 I, ,~l .... i,., ,i, ......... ~' ~' ":'r~:~ ~...~,..~r.~#~ ~ "L'~' ~'I?11, ..... ',"~ ~ .... ~ ' ....... ~ ' *,'5".,~', , ~',"*"~,~"'-~ -%" ,, ~ "-~--~"*"~-~ · ~ .......... , ....... , v,~% .... .. , , ,, , , .~;~:' '.",..'.,.'.., ? , .., START ENO HOUrs ... '"':'.'.., :i",~::2. . . '.'~,:. ' , L': ?";!'(i~EScm~oM . !' ~" " -' -b :--- ' ·- ! "' "'' ' ' ' : -- 10:00 13:30 3.r~ . , :~!RCUL~/'~,TE BOTTOMS' Up...W.. '~ ON OR, DER~,.,T~ODRILL DEEPER '" ~3~0 .... ~9:0~ : "~' " ' ' ' ........ "''' , ' ,.~ .... :,.L,.,~ -- ~- - '- ....... , ':;'i'~" (' .......... - ' ~~~'~IHOI. E ~,, .:'.,~; . ~:'.,..**hi~..'. !,' ', : .... ' · ;-"~'~,-"~.':,~;.. ,. . ~""~'~'."~,.~:~'~ ~:" ', ', 7.-" -q','a~::';: ,~i\¥, .': ;4 ,. ;,: · fao -- 6.~. .'~,'~.:i~;~: ~~AND ~E M~LWT~.~i~:.U..N~. ~ sw~s. MUD .~,;;~, . ... O~'R~'.O. WG BOP $'TAC~i:'CLOSE~~:.~R AND CIRCULATE THROUGH ,:~v, ,=.,, ,;. ~t~,, ,, .... ,. .... "' .~ "d.~ ' "' :':' .i ........ ..,,., ,., . ::.~. ,. ,. :,,,,.' ...,,;.,. :~:~':.' ' , .,;;.L.,,.,:. *' , :,:',');..~,!:,'. ':. · .... ' .......... :.,-... ;:. ,:..~-;.:-::;:~.:: ....... :,...;~.,.,, .',×,-,..r.~:~,~.,m, ~..,.,',... ...... -~,', -,n, ,. ,':.'v,~,:,.,- ......... ~ ........... !,,,..,'~,.;~ ....... *'-' '*":';!'~* ?;'-'~"-*' "~ ..... , .... .i: i...-:.~,...~__,., ~F;:O, TST~-*~ ,. ".*".? COMP ." :'~i:.;;i ~OT!:,':~i'i':'/".!i!)~!.'?"'i:"". LASTPITDm.LOA~E: ':: ': ...... : :' MUO COSTS Acruat. :'."'."" ':'" :" '"'~' .*.'. ........ :'.wEu.'c0srs Ac~U~'t~i~*:*?il LAST SOF ~ DATE: --- ' "- .................................. :~.* ~'~7.; ........ .;, .:'~..:.~,,..?.~;;:,r.,'~:'-'.:, DAU.Y: Z~oe CUM: f~.;'~,. Dmt.Y: ,74,1~." CU~,,4~0...;0Z tm ACCtDEN'= P, EPOaTEO TODAY ~001 05/22/00 M0N 07'04 FA:E";.190T56'46489 :~Iararh0n011 '.'Co , Marathon RpT~... 2~ QATE: ~:0L__.~. · "'LOCATION DA(" 29 SPUD DAYS: Oil Company .AFE~: 9~3699 G~ 6~.. ~: 21, MOC ~: , , csG $~_E: g.S~.5 CSG MO:"",:~,~.~f& :, CS~ 1~O: ' ~. SHOE ~T: . ,, U~ERTOP: ..... ~ ... .. . .... ...... 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' 05/23/00 TUE 07'21 FAX 19075~.6489 l~arathonOll Co Marathon ·~,F" 30 DATE: 0.~23/00 LOCATIOI~,,.~- 30 SPUD DA~; 2S Oil Comply A~.. ~2~9 ~L: ~. ~a: [ ~oc~: . csnmz~ s~s .... cse Mn:. s,,~o, cse'nm: ~ ~ot'~: ~ ~ , , , ..... : ~--~- -- ~ ~ · · .: ..... ~ · . ~- . . ".,'. ............... ' ....... '""'""'" '"'"'"'*" *"""' ·" """' """"""" ' ' ' .... ' ' ' I ' '' ' ,, ' ............. ' ~ ( ~ S~ ~.- OFF,, ..~G_HRS..~mR R~ ~B tOD LB GOT R C~ COMME~ J ......... ., , . .' ....... , ., lEtO 6:~ 13.~ L~N~3RD RUN:~3 P~S~, ~UNC ~UME~ ~ .., . ., . ................. .... ,. .. ..... , ~, ":":"~ ........ .., ~ "i ,", ': ....... . , . .. '.,. ,,.., ".,.. ,,:: ........ ' ,'.', .,:,'. . ':'.: .... ;,,:"~::':,' ,,,..,,;..,,,. ::%., ..., :,~ ..... r:'. ,,.. ,,, ,' '. ,, ::,,,.,, ,:~:. ~ ...... ,., :. ,. ,,,;. ,,.:~ ,...~ . ..... ' ... ... .... ~.,.. ~ ~001 0~?2&/00 WED 08:22 FAX 1907554.6459 H~,~;hon011 Co . Marathon ....r,; 3~ DAT~ ~o LOGA~OI '~: 31 ~PUD DA~: ~ LUIIER TOP~ . 'P~SENT O~'...C~..,mV~'~Y~oOWW'4' ..... ~, · - . ,. ,--, - ,,,,, , ,- . - , ~, ...,, ,,,.,, ,.,.,.,.,- · , .~ ................... v.~.~..' ...... , ...,..,, ......... . .......... ·. , su M~Y ~OIL ~ PH.. pm ~ ~ ~-"~'~'] [~' t''~l~l'' ~ I "t~-~ =- ' .,. ,, .~ ........... ,, . ........... , .., .... ., ......... I ~ . ( S~t PRESS.. PM-' .'". .... I, ..... ..t. ..' ,,. ' , :'i I .... .................. ::,..,,, * ~ '. ...... .. _z e.]~C~' I · I'~:~,~'. "'~* '=~1'.~~:~,,'~'' 1...' .... 'J" '~.'?;'~*'" .... :::~;='J:~;"".""-~"' v~'"~ ~ ~ ~o~;.s~ · .,~ ....... , ,..., , ......... .y. ............. , .......... ;" . -.. . .......... .,.. J ....... ~'... .............................. ~.,. .llnl i i "~': ..... * .... :*' ...... :'" ";'~ '"'"'? ..... '" ~' * ......' "* '*,' ~' ~1' .... .~-,,' .... ' .......... ~' *" _' "--. ~,..; :r~' 5T~T END HOURS ....... ' ..... ' , ':'.?~ ..... ,.'.~,', ~. ,~...:'.. ,_ ,, ~4:~ ' f6:~O [~ RZH, ~s~ ~7~ ~:~....~. ...O~,~.J~S~.. .......... ' .~ ...... ..... , ........ a~:~, ~:~. ¥~'?~*'";,.. . P:o:~T~S~ . ,~... ~ ~,.-,,r~.,,, ,,,,., ,,,,. ~.~ ?. ,~... ~ ~:=' s:~ .... ~:,.~; ~.o.,~,.~w,; n.o~-.~~ ~e~., .~,..~::'.:~...~:.'.:,.'...;. :.* .... .... ~,~,M~,,~.~ .,.,, , ..., . .... '~'~ ...... ~,,,:.'~'i'2 ....:' i. ........ ..'..'~ :. · . ' ' ........... ~,;,,.,.; ,...~,,~ ..... , .~..,~ ~,.~ ....:, .. ..................... ,,, .-- , ~/~;~i' ;;""'"~ ' ~ ' ' '~" ~' .::,~ ~ ...,~ .... . ......... .~.,~,..~.. .. .. , _ - .:....::~ ~:..*...: ..~ ...... 1, , ..... ,~.~: ''~ . ' . ,. ~ ",1' 'r, , - . ......... ,.~. ...... ~ ·. . ........ :.,:'.,,. .' :~;' .,. .................. . .................................. ,... .......... [,~. ~'. . MUD C~ ~U~"~/~'~''~''"~ .... ONLY: 3,~ CUM; ~,!~:', ONLy;_ ~0 GriM: 1,,~,~ ~A~E~RE~R~TO~Y . .............. , , . [~001 , ::: ,: 05/25/00 THU 06'20 FAX 19075646489 Marathon011 Co -~ Peter Berga · Marathon R; . , 32 DATE: 05/25/00 LOCATION D,,.. 32 SPUD DAYS: 27 Oil Company AFL#: 9203699 GL: 66. KB: 21. MOCWI: WELL: KBU 33-6 RIG: Glacier Drilling FTG: 0 DEPTH: (MD) 8,f10 (TVD) 7,565 CSG SIZE: 9,625 'CSG MD: 5,810. CSG TVD: 5,32~o 'SHOE TESTi . 13.40 MAX. SI 776 ., LINER TOP: , PRESENT OP'~UN DUAL STRINGS OF CASING ~::::::::::::::::::::::;::::::::::~:~::::::::::::::::::::::::::::~:::::::::::::::::;::::::::::::::::::::~:::;:::::~:~:::::::::::::::~::::::5:;::::::~:::::::::::~:r:;~:~:;:;:[:;:;~:;:;:::::::::::::~;:::::::::::::::::::::::::::::::::::::::::: FINISH LAYING DOWN DRILL PIPE AND BHA- CHANGE RAMS AND TEST.- RIG UP AND DUAL STRINGS EXECUTIVE SUMMARY ~'1~{~""~'1~"~'~;-~.'~"~'~$~"~[:'"1:-'f:5 30 .'l:---"~r" CEC SAND SLO BE~T' '~ALT DRILLE~ ~'a~":l~-'i~"~ ~o.o 1~411~ I,,~II. I ~1~.01 ~l I I 1 2.132 0.1 1 t2-71 I 9,9 eps ~'16.4 PPB 24.7 eOB (OIL WTR .pH Pm Pf Mf CE CA LIME MUD LOSSES(bbl/ft) BKGD i.~.0 .! a.~.~.!.i'~. 0."'.]i'.~. ...... 6? ..... '..~? .... 3?00] ...... '.'.' ............ l~a!~ ..... ~..-.~..u..m.'.'...'..'::.] .......... ':' .......... , ...... '.':'.',....:, ...... .-.; ...... .':.':...'.' ...... .....-. ......... .-. ....... : ................ :. ............ .-.! .... ............................. 1 .............................................................. I ........ ] I . ~" alT#' SIZe" TYPE C)EF ...... FT..G, HRS FTIHR RPM WO.B IO D~ L.B G eT R CPF COMMENTS . Wiper trip · , . ,.:". . ~ ~, :..D "j :..'."!:~ , ( BIT # ~ERIAL # PRESS. ?.,GP, M. JETS .' i,; .,TFA ,.- .ANNULAR VELOCITY alT HP)l ................. i ....... . ':i,...il' "'":?', ' - ....., .......... ........... "'""' '" ..................................................................................... . .... BHA- . Len,th: . 'i~i'~ "./'6~':: ~';."-. ,i ..................................................... Z"-'.P . '. ,S~2:i:.', ...... : .~: · .: '..L'.. :..":.%:i::L: ."" ..' DRILL PIPE DEsC'RIPTIO. N: .... .. ~' '~''' 'l''~' ' ...... ' '-A:' "'~' ,- (.. ,,JARS"" ~WD .. MOTOR . TORQUE '.WEI~HT(I~I00) . . I I I I I 1 IBHA: pu 190 eot 140 so 105 Eft ,~ ....... ................. _ .......... ~ DEPTH ANGLE OIRECTION , ,, TVD VERT. sEC. N/S 'E-/W OOG LEG-~,- 7,902.00 9.87'0 "~:~':=~'.~';;, 300.03',7,37't.58:: 2,3a3;S4 ..:~ ','i'[ . a, gg~.Oo ~.~so-:.~.: : ~--~e~.';~4o-, 7',s~a.4s' i:" ::.:: ~,4o3~0z .... . ....... :L:,::::.il ....... ::,::i~:=:~:~:=:~:~':~:;:w, ................ ! ....... '..':i ....... a... :... I'.'! .... :::::::::::::::::::::::: ....... ::,::. ........................ i ...... ::::::::::::::::::::::::::::::::::::::::::::::::::::: ..................... ~': ........ !::::i ......... i::::::::::::::i ....... : ................ ,:,:, ...................... ....... '" ....... :'"'" oPi:RATIONR:I,,N SEQUENCE~'"::" ..... ' START END HoURs'''~ *i?~ ' "':~:":~ ~'"'"'~'""' ...... '~'"" ~' 6:00 r:oo 1.00 .... R[I;'H. i::WITH"4.f STANO$':;.OF ',4"'O~ILL PIPE~, ......... :/': i.:. :'i.'. . 7:00 t0:00 ..... ':":3~0,0 ?~~' P.o'.H:' LAYING DOWN DRII;L"'PIPE ''10:00 13:~0 . ;~:;..'.`1i~.~ '~.:'ri,. ' '"' ~ "rl' 'I' , , ,, ' , ""' LA'Y',OW. N'~.WDP AND:~HA : CLEAR ~['O0,~'O"F"SANDLlNG'TOOLS . : ,, i ,. '~' ~..' , 'i3:30 t6:00 .2..50... PULL W'EAR'~RING AND INSTALL TEST ~kUG'ENER.e. iZE.,.'CHANGE PIPE RAMS TO DUAL ,, .~. · '~,~' :~..'1['Z~B.a~.S',':INSTALL. SE.C. OI~O..: .V...~LVE ON , · ,, ,, i~:oo '1~:.~o 2..~o RiG UP TO TES? ANNULUS V~LVE ON 'rUr. INe.H.EAD AND I:U~NGE. 'rEST D. UAL RA~S. I' ;'.i,'i~.;. .PU~L',gR PLUG- PULL TEST PLUG '1~:30 0:00" ' 5.50" "PJS~"RIG' UP TO RUNDUAt.'STRINGS,: C~A/.NG~. TO LONG LINKS. RIG'UP SPIDER AND ' , ,; ' ' 'l .' ~ ' , ELEVATORS FOR 3 "l~" AND..~ 7'~"- ,UlLD.SAI:ErY JOINTS ,':OR WELL CONTROL~ o:oo 6:00 ..... ?.0o "P'JSllr' ~Ii'AKE. UP FLOAT ECtUiPMENT. CHECK. FLOATS 1RIH WITH DUAL.STRINGS ., . ".7 ...... ' .":i' .'j'~ '...; ." r ,',,..' , . .... . '~,":.:...:.~.:~'~ . . . ':': '.'. ,~ ..i~' '.:, .... " ........ ' '':' ':' "' ." , '~ .. ' '~ ''~. . ',':..,."'1 .:' .; . :. ',, '"' ...... ' i':i.,:':'..:.:, '~ .......... '~. ~,~, · . ! ....... : : ,..'. ' ".:i.:" . ....... .. ,,.., ,., :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::, ": .... 'i '..'.' .~.: .... ,: ,' ............... ' :',' ' [' 'i''i''' t"i ' ' .... _ . ...... ~.,. ........ .. ~...... .............. .... · ............ "~ P "::' "~'"'~ ............ :'~" I.LAST PIT DRILL DATE: o~/2°/0o ~FE: DH TST/CSG.. . ' COM ' TOT ','?:':..": '. i". ·i~IUD COSTS' ....... ACTUAL~'' .................................... WELL COSTS ACTUAL:' ....... '" I LAST BOP TEST DATE: 05/15/00 DA~LY: 7'4~' ~:.¢u~i~.':...~.~k~... ....: .... ,."..,.',~; :..:~,~,.o'AiLY:. .. .2..~.,~0:,.. '.' '.:CUM: . '1,7'7'~,I.7'~.I, .. NO ACCIDENTS REPOF~TED TODAY' ..... . ..... ,. DEILLING SUPERVISOR: .'Da'r. rell Greei, i.' ~. :~'''' '"":~ ..... ~'~;"'"'"'~'"'; I! ;:~: :. ' .. ·. ;.- ',,' ....... ' ,':,,,"', , '.,' ",":'"':, ' ..... ~001 05/2B/UU 1¢.t(.I. U6:,~;J t"'A;~ .[~U'lSO~Oq:ov ~,~s~',u,t,.uu.u.u-x ~u ~arathon "~: 33 DATE: 05/26/01) ' LOcATIOF '~S: 33 SPUD DAYS: O, com . , '" .4 {' ,.:__ . 'WEI..L:KBU33.6 RIG:'~Drfla';g .. Fi"G:'):''. I1 '" DEPTH: (MD) 8,110 fib/D)" 7,565 CSG SIZE: 9.625 CSG MD: ~,810. 'CSG"rt/D: $.,:32g. SHOETEST'~ '/3.40 MAX. S1 748 ..... ~ , ~ ,, .. UNER TOP: . PRESENT OP:RJ.H wrtlH DIZ4L $1'R~NG ...... :'' ....... ' ' ' ' ' .......... ~ ..... ' ....... "' '"' ' ' *' ............ ""; '":: ' ' :: : ' .'. ' "2 "2 ;" ' .'""f" "" ...... '" ....... "' .................... RUN 3 ~,~/D'2 7~" DUAL STRINGS- BREAK CIRCULATION AT 9 ~ C~SING SHOE- MAKE UP CEMEN]]NG ~m.c~ SF,4~- co~gmtU~ Zo J~f,,, .. ... SUMMARY ~., · , ' .... :..,. ,....j.t..:.., ................ ;.:..h: ...... m'. .......... : ................... ' ....... :'..... .:. · .. .............. :;"7:~ ........... ;,: ...... :? .,:. VIs~:'VYP OEI.S WL T ]?,.S :~ th'" FC CRC .eamb ~;Li:~ 'i~ENT SALT DRP_,'eD aARITE ~..z' ........... I, STl"-I~Sl'~,/-i ~l..sl;'4 ~ I I z m "'o.~ I,'~z71 ,.. , 9... P~ m~. PP8 :z. (OIL WI'R pH .Pm. Pf if': CL. CA ~".U. ME MiJ~LOSSE~b_I/[t~. BKGD ¢ONN TRIP MAX ..:.., ..... : ............... ........:! ........ :....,.....::.:, ................ .:..,...f.::;: ...... ~,. 1 111'-__' .-1 .... I -. .... -~ ' _. ·"L~ .... · _ ~, _ .~, t _, .__ ...d .,~ , , ~ ,,,?, ,t,,,~; ~, : ..~,, , , ,., ' ................... ' , ,';-".' --' ' :'. ' ,'. '" ', ',' ":' ..... ~ ......... ( err~ s~e .~ ~YI, e' oF~ :FT~ .HRS FT~r" eP~ WOB I.OD Le. e or. A'--'cP~'" ' - CoMM~m-s- .. . 1~ ........ [,~.~ " .:lr~:':::.. I ,~t~, ., ,': . . ~. .,.. :.,.F..%~.'~ w~.,.~ .... :% . ................... - [ , .... /~:. ........... . .......... ,¥ .......... ..,~..,,. ........................ · ' ~',,,- ..i~: ~ h%' · . '% 'Mhl'i: ' ' ~'';'' : ...... ~ ......................... , . t t~: , . , .... ..................................................................... I~RILL' PIPE' DESt:::RIPTION:~'-~ :7 :};;:.~; 'A~"~ i~ . ;,~'",t',~'(', ~.' ~.'~,' ~'c ..',';,¥,: ?,...:.' .,.'., ,, ~ PULL: · ~.,. , ,. ,,, .e. ,~. ,~ ,t,~, ,%,w,.s s, ', ., .... ', .. , !,...', .L.,s,,~v:i..... · '. ' (' JARS It/I'IN..D:;"**~ .. L:::." '*::' ')!'*'.sMOTOR _ TORQUE ......... WEi~HT.IIDO0) ' F ! "'1"'~ I I f .... ] '", '"i".~:- .. .,~- so ' ,:., ' ......... I ......... t"I1;'l'~I'' I~ ~,I' '' ...... ~;"'_"'19';"M. LI'" ~'I~7!~'_'_' '_' , ';' '" t,.t~t "..'.,~'.'..:.~:'.,;~'~ ";' .' '.~ · .,~''.'.~. .'.. ,.~ ....... ~ ....... : · · I(MEA,,. . DiiiiPIH ANGLE .............. DIREC. TIOI~i ..... ................ .T~D. :...:. ........ VERT,.:.SE¢.~. ................... '...-NJS, .. F, AN DOG LIEG . .~ , ,, ,..., ~, '" . ..... . ,"'~,',, "'?/.'L:7 ................. . ,., ~ ~ , .,, , , .%., ,,..r.,~ ...... .~,,~.,,~,.!,,;...,~-.- ,..,, ....... ,.s ......... :.x, [','.. , ..~ rr '"r"'r'l~ "~ Il . I ' ',ii ...... 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".' ~'~..~' {::~;.:, .:'~':.: :!.',. ::;:' .': :. .... ..'%:;...,.,,,~: ..:.,;:,i,.~.,.::.·. ., .... :,. '.~,,.~' ~.,'!:'~,;... ,. ;.,.,;'.. :~?..,? · ,,... ,~,f -. ~ ...... . , . ... ~- ,- . . .:~::'!::., ,'. l':'~:,~'f.f.'t::."','-":,~?~i:~..: .......... ~= 17 .::~i,:',:.~,'.~-;-"! .- · :~"".:~':':e':: :::.":. '"...'?,:.. . ................................. :. ........ ' " ' ';' ..:~:'~?:?':-",..'~¥ei: . ~/ ~ M:E:~H TSTJC:~G..,-~-T-. :...., c.0.~P....' ~.;;..:..... ..... TOT. .....~,,~:.,.....,,. :~,..,i~,.!-~S...TpITD~LLI:Y¥IE: I.- I ...~ ......... , .,. ' ' L ' ~ ' "~ ' -- ...... '~'~"'" ~."~"'"~ ~ ~:'' '" . i~:'i::.i:~:.,.:~,.!~?,.i:,....::!1 MUD ~OSm ^~TU .~.~!!.:i :;'.".! t~i ~:.';:':':;:~:.:::':~t",:t"..,"~::i ~;:.:.:; LW.:~.C.,L..C.:~ A~ ti:;!!:;'ii':'.'-':;'i::i~ L~ST ~P mST ~T~= DAILY: 6~0 CU~: .'.'N3AT.3.'- .'.' O~LY: .~A~ CU~: ~ '~,a,~$' ~iO ACC~OEm~ REPORTED TODAY -. DRILLIN6 SUPERVI$O~: D,~rrell Greeb '":' .... ' · ': :' .... ' , . ..... · ..~.,,; : ,' · ..,.,~,.,,.~, ..... ...,.,,.n,.,.:~,,m,~ .,,p~,~..~. ,, , ,,, ...,....,..,,~ ,.. ', M':"~:;%:.;~. ?;!?'~' ', ......... ....... ,..'4,.:. :: ' · . . , :'~: ,. ,, ~ ' .,.., i,:,ii., :; ';..' . :. ,':.:,':: ;7., "! ~ ......... ,:..' .......... ' .:,~:F'~.",,~,; .~' ~"... · ",...'.'....,, '.. ~,'.'~.:.,~/'.,..i.,.~::il;i:. "':} '*ii"~" ":: ~"~'?~:~'~(:~'""?' '"' ..'. .. ': ' ';".'"'.' ':":: i' .:.. ,.,'.'. ~.,~..,,,.',~.~,. ' .'~ ',..:'. ".'::.,' ', "...'"'. :...';.'""?." :"::'.'(: .i '. "'.. :'..':'i?~!~7,'," .' '.::....... ...... :.:',:.;:.'.:: 05/29/00 I~0N 11'35 FA~ 1907~646489 ~fara~h°nOll Co '.. Oil Company a~: 9~699 G~ 66. KB: ,1. MOC ~: . ..-. sIZE: 3..~ CSG UD: .. 8,098. cseTvo: 7,M:L SHOE ~ST: M~ 0 UN~ TOP: . " '": ~ ............ ' ~E~ OP~~ ~ BOP~ ' ' .. ~E~ .... ; ............... . . *.: . . · . .. ........ ..... SUM~Y . ~. .. : . ,. · , . . ,.: .. ,..... ......... .. ,, ,,., ~...,,.,-,., ,, ~.,, ,,.., ,...,,,. ,,.~,.,,.~... ,....,,,,,., ......... <qW'" ~ e~ ~-' ~-~':"*'~ :~'+ "+~ "~~' :~C'~*C~='~o**~'.. , {~IL ~ pH Pm ~ * ~ ".CL ~ UME MUDL~SES~b~)' BKGD I I I I "] I" 'I "1 'i~' .. . .... ... ..... [_. ................ ................................. ..~ -~,~" :"*~" OFF ~a .~ 'm""."~" .... I ' :.-" - ' ' "": ................. :. ' '~?:" '"" '","J~/J:':'2'. .......... , ..... 2:?' ~ ....... 2~2 'L [""' ,".' .... :'1 ................. ' ............ ' ...... : ...... ' ....... B~: .~.'.'"~';~.~ ....... .'.~':'.- ' ~:':.:: ~"".',":" ' ..' . ,,~ ..,. ' ~: ..... '~',<~<~. . . . . ..... =. · . ...... ~ ........ , ...................... ,~ :; ...... ,...~ ......... , ,,,= .... ,z...~. ............... ~m~H ..................... - .......... ~-- , . '.,, ~;,~ ~'(~, .~, ~.,,;*, , .... , . , .,,' .................. J~2' "~O .......... ,' 'MOTOR TORQUE "I ' ] ......... .~ ......... :'::,.. ] ..... .)' "'1',' .'.,, .......... .... C~.o~ ~o~,'""'""'"""'~, ........ ~'""~',:"'O,~=~o,:~:'"' .... ~'"""'"' :' 6:~ 7:30 1.~ ' ~ ~NG ~NGS .- : '. ' ':': :CO~ ~E$, ~TAT ~ ~ ~~ P~S~U~ ~1~ ~H. -:~ -,~o ~,. ~,.~,.,~~,c~,~.~:~,: ~;m;a~o Ar ~=~ ..,: eza~u~ ~o ~u~;'p;~ Bom ~aes ' "' SHO~~ 0 a~s ~L t~.e~, cO~Omo~ MUD ~D,eL~N BO~ NGS AT COMBFN~ ~~ ~PM~ ."RECIPHO~,~G 3~ ~TKO~ ......... ",., ~ , . , , = , , , '::~:F~~'*~'' ~kbp;Ho~o~ ~;~'P~u~ ~:',~MC~CH s~G ~M ~ KcL WA~- -,i. r U' '":' *'r" "' '~ ' ' mROUeE~ JOB. ?:,.~;~S~DID Nu , B~P, FLOAt= ~ .OLDING. ........ ~tr ~ , ~r~ ~, ' .... '"", ' _ 'L'L:__.' '_ '_"L' ' ' '" . ..... " ..... ' ·" ' · "' ,'" "' ':~ ..... :": """':":' :--~~'~';;' c~:" """:'~""' ::-~ ': '"' ~'-"~::~"~--:-" -~ ..... ~' '" ' ...... , ,", .... ~E; OH T~I~ ".' '",=:,~'" COMP :~'~':~:,. T~ ........ · ..., ... ~ wE~ ~ ~TU~ I... ' · MU~CO~AC~LI"' . '''"' " ~NLY: 1~0 CUM: ~)~ ~NLY: ~,8~ CUM: 2.122,319 "NO ACClD~ ~R~D ~DAY .~:~e,~-...~. .,,~ ............. , ~,:;f., ~;.'.' L:'. :' .'..,':.~ - , . .. '.~.f~,/..,~.~ ..? ........ ~.:L .' ... ~001 05/29/00 M0N 11'38 FAX 19075646.489 '~arathonOil Well: KBU 33-6 .f ............ ~ ~'"' 't' Operations Cont (d) ...... ;,.'i... ' -~ ....... ~. .......... ... . . . ... ?~'..;. ,.. ..... :. Date: 27-May40 [ SEQUE~ OPE~ONS (REPORT ~S~ SPOre, L~. TORQUING. UP PROB~MS, ~C.~'J~U~' START ENO HOURS .... " --D~P~ .......... ,,,, :,.; ,...;.. ~ .:':. * :~.: ,~.. :,*' '.,', ::'.~:.:.,L". ".,' , ,'::'.:'~ ,;,: .... ':,.. . · 2,.'....,..* :'. '.:.':.*, "** .:" , ..: ",~.,' ........ . .. ..... ',...': , , ,;;',::i;~;~;.'?,£':..,~ ,.; .... ::', ;...' , ~':..:~!',:.)~!:'!:,:,.:.":~:.'!,'. :..... ,,, 1~002 MARATHON OIL COMPANY i'"" DALLY WELL OPERATIONS REP!" PAGE 1 OF I DATE: 6/28/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: Swab down fluid BENCHES OPEN: Well has not been perforated WIRELINE CREW: TIME: WELL #: KBU 33-6L NONE 3-1/2 EUE 8 rd" 8 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor 4old safety meeting and commenced rig up. Rig up swab equipment and hose to open top tank. RIH w/tandem 2.81" OD swab cups on 3/16" braided line. Hit fluid level at 928'. RIH to 1000 through 2,813" profile nipple at 978' KB. Pull up through nipple and gained 200 Ibm. RIH swabbing well by taking 300-450 foot bites of fluid, Only recovered 150' of fluid at surface. Continue swabbing LS down to 2330 feet. Try different cups but returned to black multi lipped cups. Swab run results as follow: RIH w/3,5" Swab Cups to RIH w/same to RIH w/same to RIH w/same to RIH w/same to FL 925' Stop at 1100' POOH FL 1100' Stop at 1300' POOH FL 1200' Stop at 1500' POOH FL 1330' Stop at 1550' POOH FL 1500' Stop at 1800' POOH Change 2 Swab Cups RIH w/same to RIH w/same to RIH w/same to FL 1975' Stop at 2300' POOH FL 2120' Stop at 2470' POOH FL 2170' Stop at 2520' POOH Changed one Swab Cup RIH w/same to RIH w/same to FL 2180' Stop at 2530' POOH FL 2330' Stop at 2680' POOH SD Swabbing operations for the evening. Secure wellhead and location for night with plan to resume swabbing in the moring. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Braided Line Unit $2,200.00 $2,200.00 Pollard Wireline 2 Additional hours $260.00 $2,460.00 Pollard Wireline Tools $225.00 $2,685.00 Total Daily $2,685.00 _ DALLY COST: $2,685.00 CUM: REPORTED BY: Affinito/Titus 05/28/00 StrN 07-29 FAX 190756a~489 l~ara~hon011 Co Msrathon ~ ? DATE: 05f2~70 LocATIoN, t~ '/ SPUD DAYS: Oil Company AF~;.; 9~1~399 OL: '.. 'KB: , MOC WI: I~001 WELl.:/r/?J ~ RIG: G/acief ~ Iq'G: 0 DEPTH: (MD) O' ' (11/D) 0 CsG ~ZE: 2t7.00o C~G MD: ~,/& CSG'TVD: 1-/O. SHOE'rIEST: M/~SI 0 . ,, -- lINER TOP: . PRESENT Op:sCOPE DOWN M,~LST- MOVE WATER TANK " ' ........ · , ....... '... . ............... ~ · · .~ ..... .. .., ................................ .. ... .......... ,, ....................... 'L'L' .............. ,,' ................. NIPPI I= DOWN BOPS-INSTALL TREE- CLF_AN PITS.. RIG DOI4~I.AND MOVE RIG EXECUTNE SUMMARY _ _. .......... t ........ ~ .... ;'"'~' ' ' ,,, ',',',, , .... ... ,,,, ,, ..................... ' ............. ~'." YP ;ELS WL T 7.5 30 HT FC CEC '~d~lD SLD BENT SALT DRILLED BARITE I I I I t ,I '1" I ~ I I'o~ "' I t ,?,::.'-.,'~.-.: ,v~i' ¥,P. _(OI1' WTR ..pH Pm'" Pf Mf CL: CA 'LIM'~E-~'~uD Lt::I~ES (bb.l~...._ BKGD C6~1~ TRIP MAX ............ [ . I ...... I I ...... l.": .... t ': I I _: .... 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II~0) ' .... _ : ........... : ~. _ __ ....... ~., I l' ' .... [' .... ,, I,E ,.I , ' 1 , .IOHA: 'Po .M So .................... ' .......... : ......... ' ' ......... ~II'~; ' ,. .,'..:, ; .... :'.'~:'.,.,' ............. ~ ................ :'-'r: ....... : ........ ... ,,, ,~-n, ,,~ , ....... i: :......... . ........... ~.:~. .... ~ .~ . .... ....... ~,,-. ,/ ,?,~;:,.: :~.~, ~:. , ..... ": ~ i., :,,, ...... =': '~" "'"':";:'~""_. ':;' ' ' ~ ', F, ~"?"~¥'~:' n 'i,",'" ' :,:: ,,,~. :.:~,.:,,~ .,e;,~, ,..~ ~, ',' ' ~., .. ;:.,~: r. ',:.,';.,::.'."., .;:,:,,,:"~ ~ii~', ~, .,, ,,,. "'" ' :' :" "'"' .... "~,?; ~.,..,,-~""---o.",. " START END ,.,~HOUR8,''~-'~''' ' ~':"~'"; DE 6.'00 9,'GO -.:'.: :],:3.00'.~i'.. I NtP~'DoWN.'BLOW OUI"PREVENT~. " ,,~D' R~LA TED £OUIPMENT 9:00 "13:38 ...... ..4,,50:.4:j NIPP ,~::~IP TREE- PI. ILL Bt~,,~ID II~T~MI,....TWO :.WA.Y,.;CtlECK V'AI-VE- TEST TREE, PACK ~;':'*:"~:"~'~'~0FF., '~~L LIN~ ~ ~OA~ - P,O~!'CHECK JOVO .INST,11~ I~L4CK PRF-,,~URE VALVE ?~ '~,.~* ...... , . ,,, , , , , _, . 13:30 2'1."011 7.50,, :: CI.~M/.'.M[/D P/TS ~ MUD.SY~3TEM." }:' "i .... '¥,:.. ":.: .'.. ' - :'",' ~')',, /.~.. d ', '*' ' , 2f."IM $.'00 ; 9,1~ ..i;,... ~.~ .,~G,,~Qii~'N TOP DRY.. ,AND,.,-.~ ~. F.,LOOR-, REMOVE ST, ABING BOARD - DISCONNECT ..... :~:~':',' 'b~CK.c~.. U~ ~o'rOm u~ BO~": ~Ci~'~cr ~. ~oVE .......AND C~.,, ~.W~lLK.,t REMOVE STAIRS AND FLOW LINE, :.,.....;~,...,~:. - ~..'. ..... . .......... :- . .... .... "'" '"," '::'"' .... ' ':":'' ':' ';".'¥'i '~;:"":~":'"::'""'":;';:: ........ '"' ,:' ,:,';"' ' : :.. :' ":: .:: ', :'. ., ',.:' ':'.;"'.','. 2 , '' .'., ' ..., .., .. ,,,.:,: , ,, . , ...... . · ,, ~,, ,',,: ,~, ,; ...... i,, i, '~ '"' ,":"'"' ' ..... R~ RELEASED FROM KBU 33.6 t~ 2 N 5.27.00 ,,, ~., ..~.~,~ .,,~ . ., . .,;~,??~,: .. ?& ~:,, ,: :¥, .~,:..!i~,iC,~ .............. , .... ,,.,,, ~].,:~ ..,.: ,,., , ..... ,., .....~,. :., ' ! ,, ~ .' ,I ..... :,, ".:,, i , ............. ~.'~ ..... ' ' ....": ' .i ., ., .,, .~=,.. '' · , , , : ~ ,,' ~ :~,, ,,,, : ...' .,~:],..,,,.' , ..... . ;: .~ ,,: i.',, .,... ,,, .:,,iil;,.,:,.:: :~i'~,'~*.' ,,. .... '~. ,,' ....... : ....... ' ..... ' ,,'i., , "' ,,~.~:,.' ,-" ",',".,,';'- :,".~:~',!..,~ .. '.~.' ~ ~.:r'i .~: ":' '~"?!"..'*:i'*'i:' ' ........................... . ............ ~, . _ ..,,.. ',...-' . ..... ,. .... , · . ,.,,. · . . , , · .................... I~FE: DH T'3TIC'BG -- COMP TOT LAST PIT DRILL. DATE: , . , , . ,. '. . ;~ ,..4 ~ ' _,,...~ ,. DAILY: 0 'CUM: ..... O'.'F ........... ONLY: 0,,';"., CUM::./,:~i:.'.i-"':O.::',;'i.'-.'NOACCiDENT~~~TODAY,, _ ,_" ,.~,,.; ~ ~ .', ~ ,, :,, .... ,..., SUPERVISOR: OR]LUNG '.~: , .... . . .... . . ' ' I?', .,j..., ' _' ' , ,.- ' ~' ,1.%'~. i.;',~':' '~ ;. ...... ' MARATHON OIL COMPANY DALLY WELL OPERATIONS REi:(" PAGE 1 OF I DATE: 6/29/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 33-6s TUBING: 3-1/2 x 2-7/8" CASING: NONE TREE CONDITION: 3-1/2 EUE 8 rd" Swab down fluid BENCHES OPEN: Well has not been perforated WlRELINE CREW: TIME: 8 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor Hold safety meeting: General Rig up swab equipment and hose to open top tank. RIH w/tandem 2.81" OD swab cups on 3/16" braided line, Hit fluid level at 950'. RIH to 1000 through 2.813" profile nipple at 911' KB. Pull up through nipple and gained 400 Ibm, RIH swabbing well by taking 250 foot bites of fluid, Only recovered 150' of fluid at surface. Continue swabbing SS down to 2130 feet, Try different cups but returned to black multi lipped cups. Swab results as follow: RIH w/3.5" Swab Cups to FL 950' Change Swab Cups RIH w/same to RIH w/same to RIH w/same to RIH w/same to RIH w/same to RIH w/same to Stop at 1350' POOH FL 960' Stop at 1360' POOH FL 1260' Stop at 1660' POOH FL 1490' Stop at 1950' POOH FL 1780' Stop at 2230' POOH FL 2010' Stop at 2460' POOH FL 2130' Stop at 2610' POOH Final Fluid Level = 2130' MD RD swab equipment on SS and clean up location. 4 of 8 hr min = $1100 2 swab cups = $150. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline W/L unit w/2 man crew $1,100.00 $1,100.00 Pollard Wireline Additional hours $150.00 $1,250.00 ,,, Daily Total $1,250.00 DALLY COST: CUM: REPORTED BY: Titus MARATHON OIL COMPANY DALLY WELL OPERATIONS REI~~ ;' PAGE 1 OF 1 DATE: 6/29/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: Swab down fluid BENCHES OPEN: Well has not been perforated WIRELINE CREW: TIME: WELL #: KBU 33-6L NONE 3-1/2 EUE 8 rd" 8 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor Resumed swabbing on the LS. Iniitial fluid level is at 2330' MD. Swab run results as follow: RIH w/3.5" Swab Cups to FL 2350' RIH w/same to FL 2360' RIH w/same to FL 2480' RIH w/same to FL 2600' Stop at 2700' POOH Stop at 2700' POOH Stop at 2880' POOH Stop at 3000' POOH SD Swabbing operations and RD from LS. Secure wellhead and mobilize swab tool to the SS. 4 of an 8 hr minimum for 3/16" braided line = $1100. Final Fluid level is 2600' MD. Mid Perf for Tyonek 73-1 Sand is 7956' MD. 2600' MD = 2458' TVD 7956' MD - 7412' TVD 4954' of fluid af 0.44 psi/ft = 2183 psig The SBHP of the 73-1 sand is approximately 0.46-0,48 psi/ft. Assuming a 0.47 psi/ft this = 3483 psig. 3483 psig SBHP - 2183 psig Hydrostatic = 1300 psig Underbalance for perforating Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Braided Line Unit $1,1 00.00 $1,100.00 Total Daily $1,100.00 DALLY COST: $1,100.00 CUM: REPORTED BY: Affinito / Titus MARATHON OIL COMPANY DALLY WELL OPERATIONS REI~ ' ,, PAGE 1 OF 1 DATE: 6/30/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: Prepare for Perforating BENCHES OPEN: Well has not been perforated WlRELINE CREW: TIME: WELL #: KBU 33-61 NONE 3-1/2 EUE 8 rd" 24 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor. Well is swabbed down to 2600' which will provide a 1300 psig underbalance. The SBHP of 'he 73-1 sand is estimated at 3483 psig. -lold safety meeting discussing Rig operations, underbalance, ladders, pressure, spills, radio silence and attention to environment. Pressure test lubricator/rams against swab valve to 3000 psig using freshwater. RU 1-1/16" OD GR/CCL and RIH. Calibrate depth to PEX-AITH open hole log dated 21-May-2000. Determine PBTD to be 7946' KB. Desired perforation interval is 7941-7951, and 7960-7970'. Thus, unable to get deep enough. Run GR/CCL from 7946 to 5000'. Stand back SWS at 7 PM. RU Pollard 0.125" Slickline unit at 9 PM. Perform wire test to 22 turns. RU 2-25" OD bailer w/spang and oil jars. RIH tagging PBTD at 7948' WL. Bail from 7948-7976' WL on first RIH falling through some bridges. Consistently getting stuck. COH and and emptied 3/4 full bailer for approximately 2-1/2 quarts of wet cement. 07/01/2000 Worked through night using light plant. Ran a total of eight (8) bailer runs and two (2) 2.66" OD gauge ring (pert guns are 2-1/2" OD). Gauge ring was used to remove cement from tubing wall and prevent getting bailer stuck. Cleaned wellbore down to 7986' WL or 8007' KB. Recovered all wet cement with some green looking cement. RD Pollard WL service and call out Schlumberger Logging Service. Vendor Equipment Daily Cost Cumulative Cost Schlumberger ?? Pollard Wireline $1,150.00 Pollard Wireline $150.00 DALLY COST: CUM: REPORTED BY: Affinito/Titus ., MARATHON OIL COMPANY ,, DALLY WELL OPERATIONS REI:( I' PAGE 1 OF 1 DATE: 7/1/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: Perforate Tyonek 73-1 Sand BENCHES OPEN: Well has not been perforated WlRELINE CREW: TIME: WELL #: KBU 33-61 NONE 3-1/2 EUE 8 rd" 8 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor. Hold Safety Meeting. RU BOPs and pressure test lubricator again to 3000 psig. Hold radio silence meeting with Tool Pusher, Company Man, Schlumberger Crew, M©C Production supervisor. Commence Radio silence. PU oriented perforating equipment and a 10' gun loaded 3 SPF at +/- 60 degree phase. CCL to top shot is 17.2 feet. CCL to gun base is 27.9 feet. Run #1 PU orienting tool string from Bakersfield, California and RIH and correlate depth to pup joints at 6030' and 7284'. RIH to 7944' KB measurement never tagging bottom. Function test tool. Tool would not rotate. COH. Suspect a faulty electronic module. Run #2 Change out to alternative tool set from Tyler, Texas. RIH and correlate depth. Function test gun fine. Measure csg amplitude to orient gun 180 degrees away from SS tubing. High side value 1430 units and Iow side value is 480 units. To orient guns away from SS tubing the measurement must read the high side value. Make proper rotation to 1430 units and attempt to fire guns. No indication that guns fired. COH - mis run. Determine that while the gun was rotating, the detonator wires were twisted off the blasting cap. The excess voltage ruined the capacitor on the tool string. Run #3 Pick up Tyler tool string with the Bakersfield questionable electronic unit from run #1. RIH w/ same 10 foot perforating gun and correlate depth but tool would not function test. COH. Stand back SWS at 1800 hrs. Plan to perforate following arrival of new tool string. Secure well~,.o, re~ ,f. ol;,.nigl~t .... ,.,,. ............ ~, Vendor Equipment Daily Cost Cumulative Cost Schlumberger DALLY COST: CUM: REPORTED BY: Affinito/Titus MARATHON OIL COMPANY DALLY WELL OPERATIONS REI~ r PAGE 1 OF 1 DATE: 7/5/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: Perforate T¥onek 73-1 Sand BENCHES OPEN: Well has not been perforated WIRELINE CREW: TIME: WELL #: KBU 33-6s NONE 3-1/2 EUE 8 rd" 17 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor. Hold Safety Meeting. Hold radio silence meeting with Tool Pusher, Company Man, Schlumberger Crew, MOC Production supervisor. Commence Radio silence. PU oriented perforating equipment and a 10' gun loaded 3 SPF at +/- 60 degree phase. CCL to top shot is 17.2 feet. CCL to gun base is 27.9 feet. Plan to perforate the Tyonek 73-1 Sand from 7960-7970'. Schlumberger has repaired the POS-C tool and has a back up on location with a third back-up due into the shop today. Run #1 LONG STRING PU orienting tool string and RIH and correlate depth to pup joints at 6030' and 7284'. RIH tagging solid with base of tool at 7949" KB measurement. Tool functioned fine, but unable to get deep enough. Pull up hole and rotate tool 180 degrees. Attempt to go back down but tagged bottom again at 7949' KB. COH. Run #2 SHORT STRING RU on SS and run 1-11/16" GR/CCL in hole. Tag fluid level at approximately 2135'. Tag PBD at 7594' with wireline. This compares to 7703' w/slickline on 6/9/2000. Run GR/CCL from 7594' to 5000'. Stand back Schlumberger at 1600 hrs. SI wellbore for night. RU Pollard Slickline Unit. LONGSTRING PU 2.25" OD bailer. RIH working through bridge and sticky cmt to 7985'. RD Pollard WL with the intention of coming back at 5 AM to make a run to bottom prior to Schlumberger with perforating guns. SI well bore for night at 2430 hrs. ~:i'"~;~~, ii'i ........ ,.?~ii:,~':~ '.,~ '~, ~. ,""'. ~ ........ ~ ~' Vendor Equipment Daily Cost Cumulative Cost Schlumberger NA Pollard 0 $750.00 DAILY COST: CUM: REPORTED BY: Affinito/Titus MARATHON OIL COMPANY DAILY WELL OPERATIONS REI~i 1' PAGE 1 OF 1 DATE: 7~6~00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 33-61 TUBING: 3-1/2" CASING: NONE TREE CONDITION: 3-1/2 EUE 8 rd" Perforate Tyonek 73-1 Sand BENCHES OPEN: WIRELINE CREW: TIME: 24 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor. RU Pollard Slickline unit. RIH w/2.72" GR to 7985'. COH and RIH w/2.25" OD bailer to 7985'. COH w/sloppy cmt water. RD Pollard WL. RU Schlumberger WL unit on Long String. Pressure test to 3000 psi fine. Hold Safety Meeting. Hold radio silence meeting With Tool Pusher, Company Man, Schlumberger Crew, MOC Production supervisor. Commence Radio silence. PU oriented perforating equipment and a 10' gun loaded 3 SPF at +/- 60 degree )hase. CCL to top shot is 17.3 feet. CCL to gun base is 27.9 feet. !un #1 PERFORATE TYONEK 73-1 FROM 7960-7970' Plan to perforate the Tyonek 73-1 Sand from 7960-7970'. RIH w/POS-C oriented perforating tool. Hit fluid level at 2550'. Correlate depth to GR/CCL dated 30-JUN-2000. RIH to 7944' (CCL which is 7974' at base of tool) never hitting bottom. Get on depth and rotate gun to identify alternate tubing string. High flux reading is 1520 and Iow flux reading is 493'. Guns are loaded oposite high reading. Stop rotation at 1500 units. Fire guns at 1515 hrs. COH all shots fired Run #2 PERFORATE TYONEK 73-1 FROM 7941-7951' Plan to perforate the Tyonek 73-1 Sand from 7941-7951 '. RIH w/POS-C oriented perforating tool. Hit fluid level at 2030' (was 2550 before first run). Correlate depth to GR/CCL dated 30-JUN-2000. RIH and get on depth and rotate gun to Identify alternate tubing string. High flux reading Is 1225 and Iow flux reading Is 680'. Guns are loaded oposite high reading. Stop rotation at 1220 units. 0 psi at surface. Fire guns at 1705 hrs. COH all shots fired. Pressure steadily climbing. RD SLB WL unit for night at 1800 hrs. Pressure response as follow: 1730 hrs 80 psig 1815 hrs 500 pslg 2035 hrs 1500 psig Commence flowing well. Wellbore had 46 bbls of completion fluid. Over the 10 hr night flow it unloaded 43 bbls. Stabilized flow at 593 MCFPD @ 125 psig FTP. SI well at 0600 hrs on 07/07/00. ~)etalled flow is on attached HES document. Well remained shut in and built to 3000 pslg SITP in 12 hours. Vendor Equipment Daily Cost Cumulative Cost Schlumberger NA Pollard 0 $1,350.00 DAILY COST: CUM: REPORTED BY: Affinito/Titus MARATHON OIL COMPANY DALLY WELL OPERATIONS REii r PAGE 1 OF 1 DATE: 7/7/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KU 33-6s TUBING: 3-1/2" & 2-7/8" CASING: NONE TREE CONDITION: 3-1/2 EUE 8 rd" Perforate Middle Beluga BENCHES OPEN: WlRELINE CREW: TIME: 20 hours SUMMARY OF OPERATIONS Arrive @ MOC Pad 41-7. Discuss job w/onsite supervisor. RU Schlumberger WL unit on Short String. Move Halliburton flow equipment to Short String. Pressure test all WL and HES equipment to 3000 psi fine. Hold Safety Meeting. Hold radio silence meeting with Tool Pusher, Company Man, Schlumberger Crew, MOC Production supervisor. Commence Radio silence. PU oriented 3erforating equipment and a 2" x 10' gun loaded 4 SPF at 0 degree phase. fun #1 'ERFORATE BELUGA M15 FROM 6486-6490' & 6476-6482' - 10 ft total Have an 838 psig underbalance. Rill w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to Identify alternate tubing string. High flux reading is 1240 and Iow flux reading is 520'. Guns are loaded oposlte high reading. Stop rotation at 1240 units. Fire guns at 1032 hrs. COH all shots fired. 0 psi SITP. Run #2 PERFORATE BELUGA M14 FROM 6464-6471' - 7 ft RIH w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to Identify alternate tubing string. High flux reading Is 971 and Iow flux reading Is 670'. Lower high flux reading due to device being opposite a centralizer. Guns are loaded oposlte high reading. Stop rotation at 970 units. Fire guns at 1156 hrs. COH all shots fired. 0 psi SITP. Run #3 PERFORATE BELUGA M14d FROM 6446-6460' - 14 ft RIH w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to Identify alternate tubing string. High flux reading Is 1294 and Iow flux reading Is 596'. Guns are loaded oposlte high reading. Stop rotation at 1275 units. Fire guns at 1323 hrs. COH all shots fired. 0 psi SITP. ~un #4 ~ERFORATE BELUGA M 14b FROM 6426-6442' - 16 ft Starting fluid level observed as 2010' w/0 psig at wellhead. RIH w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to identify alternate tubing string. High flux reading is 1107 and Iow flux reading is 587'. Guns are loaded oposite high reading. Stop rotation at 105 units. Fire guns at 1446 hrs. COH all shots fired. Surface pressure began to build. Had 150 psig at 1510 CONTINUED ON PAGE #2 Vendor Equipment Daily Cost Cumulative Cost Schlumberger NA DAILY COST: CUM: REPORTED BY: Affinito MARATHON OIL COMPANYI DALLY WELL OPERATIONS RE~," tT PAGE 1 OF I DATE: 7/7/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KU 33-6s TUBING: 3-1/2" & 2-7/8" CASING: NONE TREE CONDITION: 3-1/2 EUE 8 rd" Perforate Middle Beluga BENCHES OPEN: WIRELINE CREW: TIME: 20 hours SUMMARY OF OPERATIONS CONTINUED FROM PAGE #1 Run #5 PERFORATE BELUGA M 14a FROM 6400-6410' - 10 ft RIH w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to identify alternate tubing string. High flux reading is 1215 and Iow flux reading is 609'. Guns are loaded oposite high reading. Stop rotation at 1237 units. Fire guns at 1609 hrs. COH all shots fired. Pressure has built to 1140 .Dslg SITP by 1800 hrs. Run #6 ~ERFORATE BELUGA M14a FROM 6387-6400' - 10 ft RIH w/POS-C oriented perforating tool. Correlate depth to GR/CCL dated 30-JUN-2000. Get on depth and rotate gun to Identify alternate tubing string. High flux reading is 1230 and Iow flux reading is 515'. Guns are loaded oposlte high reading. Stop rotation at 11235 units. Gun tension was lower than previous runs due ito suspected gas In wellbore. Fire guns at 1811 hrs. COH all shots fired. Pressure has built to 1140 pslg SITP. Pressure response was stable at 1140 psig. RD SLB perforating equipment. Prepare to flow test well. Kick well to atmosphere at 2020 hrs. Well blew down making no liquid. Pressure did not build after 90 minutes. SD flowback operations for night at 2230 hrs. Checked pressure once more at 2330 hrs and It had built to 450 pslg. Pressure at 2400 hrs was 1000 pslg. Well seems to quickly build a small gas bubble after 90 minutes. Wellbore has 36 bbls of comDletion fluid to unload. Well was blown down again to zero pslg on 07/08/00 making no liquid. Blew down well for third time on 07/10/00. Well remained shut in and built to 1000 pslg SITP on 07/10/00 awaiting coil tubing use for unloading. Vendor Equipment Daily Cost Cumulative Cost Schlumberger NA DALLY COST: CUM: REPORTED BY: Affinito MARATHON OIL COMPANY DAILY WELL OPERATIONS REI~i' T PAGE 1 OF 1 DATE: 7/15~00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: FIELD: Kenai Gas Field WELL #: KBU 33-6s TUBING: 3-1/2"to 2 7/8" CASING: NONE TREE CONDITION: 3-1/2 EUE 8 rd" nitrogen jet with coil tubing BENCHES OPEN: well dry CT CREW: Tab, Pat, Mark TIME: SUMMARY OF OPERATIONS INITIAL SITP=1200 PSI. BOP TEST 250#/3000# CONDUCT SAFETY MTG. NOTE PRESSURE, NOISE, TRIP HAZARDS RIH W/1 3/4" CT PUMP 350 SCF/M N2 @ 4500' BEGIN TO SEE BLACK WATER AT ~ .6 BBL/M CUT N2 RATE TO 150 SCF/M RECOVERED ~25BBL, WATER STARTING TO SLOW RUN CT DOWN TO 5000', CONT. TO CIRCULATE @ 150 SCF/M INCREASE N2 TO 350 SCF/M TP=540 PSI, RUN DOWN TO 5500' RECOVERED 2 BBL IN 30 MIN, RIH TO 6500' CIRC. N2 @ 350 SCF/M RECOVER ~ 5.5 MORE BBL IN 50 MIN. CUT RATE TO 250 SCF/M & PU TO 5500' RECOVER 4 BBL WATER RIH TO 6500' ClRC @ 350 SCF/M NO GAS YET DETECTED POH TO SURFACE W/N2 @ 200 SCF/M. FINAL RECOVERY: 37 BBL WATER, NO GAS RD SCHLUMBERGER CT UNIT. SITP=2200PSI Vendor Equipment Daily Cost Cumulative Cost Schlumberger $26,500.00 Weaver Bros 0 R&K DALLY COST: CUM: REPORTED BY: Titus MARATHON OIL COMPANY ALASKA REGION DRILLING REPORT SUMMARY AKR/Kenai PeninsulalKBU 33-6 26-Apr-00 Rig mob. General rig up of rig floor, carrier, substructure and cuttings washer. 27-Apr-00 Rig mob. General rig up of Glacier Rig 1. Scoped up derrick. Secured guy wires. Rigged up driller console. Started rigging up top drive and nippling up diverter system. 1900 hr 04/28/00. Drill ahead to 525'. 28-Apr-00 Continue rigging up Glacier Drilling Rig1. Rig accepted for well work at 0001 hrs on 4/28/00. Prepare to pick up drill pipe and stand back in mast for upcoming hole section. 29-Apr-00 Rig up to pick up drill string and BHA- Mix spud mud - spud well at 1900 hr 04/28/00. Drill ahead to 525'. 30-Apr-00 Drill to 941'- Circulate hole clean. Drill ahead to 1088'. 1 -May-O0 Drill ahead to 1200'- Drive hose failure on mud pump number 1 - MWD failure - POOH. 2-May-00 Trip for MWD tool failure. Change MWD pulser tool. RIH. Drill from 1200'- 1520'. 3-May-00 Drill to T.D. @ 1575'. P.O.H. Run 13 3/8 casing to 1568' 4-May-00 Run 13 3/8 casing to 1568'. Run in hole with stab-in assembly. Circulate and condition mud. Cement with full returns. P.O.H. Nipple down diverter system. 5-May-O0 Nipple down diverter system Install well head. Nipple up B.O.P. 6-May-00 Nipple up and test B.O.P.E. Troubleshoot Tesco top drive. Lay down drill pipe. Pick up B.H.A. and R.I.H. 7-May-00 Pick up B.H.A. and R.I.H. Stand back drill pipe for next hole section, Drill float equipment and perform leak off test. Drill to 1841'. 8-May-00 Drill to 2555'. Circulate bottoms up. Short trip to casing shoe. Drill ahead to 2946'. P,O.H. Five stands. Work on generator. R.I.H. and drill ahead to 3210'. 9-May-00 Drill ahead to 3735'. Make short trip. Drill to 4142'. 10-May-00 Drill ahead to 4293'. Back ream out of the hole to 3326' Finish trip out hole. Change out bit and mud motor. Trip ion hole to 1530'. Cut drill line and service rig. Continue trip in hole. 11-May-00 Finish trip in hole. Rotate and slide drilling F/4293'-4859'. Wiper trip to 4220'. Rotate and slide drilling F/4859'-4981' 12-May-00 Rotary and slide drilling F/4981'-5596' 13-May-00 Drilling F/5596'-5810'. TD to Intermediate hole. Wiper trip F/5810'-3300'. Circulate and condition mud. Trip out of hole to run 9 5/8" casing. 14-May-00 Finish trip out of hole. Lay down directional tools. Install 9 5~8" casing rams an cavity test BOP. Rig up and run 144 JTS. 9 5/8" to casing to 5810'.. Circulate wi casing. Prep to cement. 15-May-00 Cement 9 5~8" casing. Nipple down BOPS and set slips. Cut off casing. Install tubing head and test. Nipple up BOP. 16-May-00 Finish nipple up BOPS. Test BOP's 250 PSI Low/5000 PSI High. Pick up steerable BHA and MWD. Surface test equipment. Pick up 70 JTS 4" Drill Pipe 17-May-00 Finish picking up 4" drill pipe. Trip in hole to 3332'. Test casing to 1500 PSI. Finish trip in hole to top of cement @5732'. Drill cement and float equipment and 20' formation. Run leak off test to 1145 PSI. 13.4 lb/gal EMW. 18-May-00 Drilling with surveys F/6350'-7175'. 19-May-00 Drilling F/175'-7587'-Trip out of hole F/BIT #5 20-May-00 Finish trip out of hole. Change out bit. Surface test MWD. Trip in hole to 5800'. Cut drill line. Finish trip in hole. Drilling F/7587' to 7877'. 21-May-00 Drilling F/7877'-8110'. TD F/Electric Logs. Circulate bottoms up. Wiper trip to 5800'. Repair top drive. Trip in Hole. Circulate and raise mud weight. 22-May-00 Circulate and raise mud wt. Trip out of hole for electric logs. Rig up Schlumberger and logging. 23-May-00 Continue to run electric logs. 2nd run: DSI-NGT F/8106'-5810'. 3rd run: RFT 24-May-00 E-line logging. R.I.H. Condition mud. P.O.H. Laying down 4" drill pipe. 25-May-00 Finish laying down drill pipe and BHA. Change rams and test. Rig up and run dual strings. 26-May-00 Run 3 1/2" and ~_ ~/8" dual strings. Break circulation ~. a 5/8" casing shoe. Make up cementing heads. Continue to R.I.H. 27-May-00 TIH with dual string. Circulate hole. Cement in place. Nipple down BOPE. Install tree. Clean Pits. Rig released at 2100 hrs 5-27-00 28-May-00 Rig down from well KBU 33-6 and move rig to KTU 24-6H. Alaska ~i,' ,on Domestic Idroduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 2 2000 Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL VIA CERTIFIED MAIL The following well logs are enclosed: Marathon Oil Company KBU 33-6 / Kenai Gas Field q'l. ozq Print KBU 33-6Long - Gamma Ray / CCL Log - June 30, 2000 ..................................................... 1 KBU 33-6Short - Gamma Ray / CCL Log - July 5, 2000 ....................................................... 1 KBU 33-6Long - Completion Record - July 6, 2000 .............................................................. 1 KBU 33-6Short - Completion Record - 2" Hyper Dome - July 7, 2000 ................................. 1 Reproducible Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Kaynell Zeman Enclosures Certified Mail Receipt 7099 3220 0007 1780 6908 Received Date: AUG 0 ;5 ?_000 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alask{a r~ ~ Domestic '..Juction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 August 7, 2000 Alaska Oil & Gas Association Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 LETTER OF TRANSMITTAL Hand Delivered Enclosed are the following samples collected for Marathon's KBU 33-6 Kenai Gas Field Well. KBU 33-6 - Kenai Gas Field Dry Samples Depth From Depth To (Feet) (Feet) Box No. 5,820 6,240 lA 6,240 6,680 2A 6,680 7,040 3A 7,040 7,450 4A 7,450 7,980 5A 7,980 8,110 6A Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Enclosures Hand Delivered A subsidiary of USX Corporation Environmentally aware for the. long run. g:~cmn\dd g~kgf~wells~ku 11-8s~AOGCC01 a.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 2327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. At top of Productive Interval 5. Type of Well: Development x Exploratory Stratigraphic Service At EffectiveDepth I Coil Tubing Sand Wash At Total Depth 1080' FNL, 1049' FEL, Sec. 15, T5N, R10W, S.M. 6. Datum Elevation (DF or KB) 87' KB above MSL feet 7. Unit or Property Name Kenai Beluga Unit 8. Well Number KBU 33-61 9. Permit Number ~99-24 10. APl Number 50-133-20487 11. Field/Pool Kenai Gas Field/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 8110 feet 7565 feet Effective Depth: measured true vertical 7594 feet Cement PBTD 7057 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 115 Size Cemented Measured Depth True Vertical Depth 20" Driven 115 115 1568 5810 8088 13-3/8" 600 sks 1568 9-5/8" 570 sks 5810 3-1/2" 339 sks 8088 7941'-7951',7960'-7970' true vertical 7398'-7408', 7417'-7427' Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 1541 5329 7543 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure Refer to attached work history. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 0 0 1200 (SI) Subsequent to Operation 0 1500 2 0 850 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Re~.rt of.,~., Well Operations .~, _~X Oil__ Gas ~ Suspended 17.1 hereby c'~ that the foregoing~ true and correct to the best of my knowledge. Signed "'~"~~ "~'~,,,. Gary Eller Title Production Engineer Form 10-404 Rev. 06/15/88 Service Date 07/31/01 ~ Submit in Dup~ MARATHON OIL COMPANY DALLY WELL OPERATIONS REP[ PAGE 1 OF 1 DATE: 7/16/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: 7987' FIELD: Kenai Gas Field WELL #: TUBING: CASING: TREE CONDITION: BENCHES OPEN: CT Squeeze WlRELINE CREW: KBU 33-6L N/A Good AFE 9207401 TIME: SUMMARY OF OPERATIONS RU CT unit. Held safety and environmental meeting. Discussed procedure with crew. PT BOP to 4500 psig. No problems RIH with 1.75" Coil. Tagged fill at 7930' KBD, WHP= 600 psig. Start pumping 3 % KCL to clear fill. Pumped 41 bbls while working tool string down to 7965'. Bottoms up. Start pumping diesel down well to displace well with diesel. Rate at 2.0 BPM Pumped 62 bbls diesel. S/D pumps to mix Pill. Had to transfer 85 bbls from clean diesel tank to another frac tank. 108 bbls left in tank. Mix chemicals, circulated the tank for 20 minutes prior to pumping the pill. Start pumping the chem. pill pumped 95 bbls(held pump in pressure below 4500 psig and WHP below 2500 psig during chemical pump) After reel volume pumped 30 bbls. Shut in wing valve start chemical squeeze. Switch over to the 3 % KCL to chase the chemical to end of the tubing tail with N2, 3 bbls pumped, Released CES during the water pumping.. Started N2 pumping at 300 SCFM rate. PIP =983 psig, WHP=1827 psig. 7958' KBD. Increase N2 pump rate to 500 SCFM, after KCL at end of the coil increased N2 PI rate to 2250 SCFM for 10 minutes, total N2 pumped 35,000 scf. Shut down pumping wait 1 hr. Pulled up coil :to 5000' Open back side start pumping N2 at 300 scfm to unload liquid from well. Solid stream of liquid to surface. Increased rate to 600 scfm. Work CT up well while pumping N2. Pulled coil up to 1800' Well head dropped to 180 psig with no N2 pumping. :Ran CT back to 7935' KBD. Start pumping N2 at 600 scfm while on bottom for 50 minutes Monitored return and whp while pumping on bottom. WHP up to 700 psig. Good liquid returns. Move CT up hole while pumping N2. Slowed PI rate to 600 scfm. @ 7325' WHP=1309 PSIG, PIP= 2009 psig. 7-17-01 RD Inj head & install night cap RD unit Note: Well flowing @ 1100 psig, 2.58 mmcfpd, 3.5 bbls h20 Vendor Equipment Daily Cost Cumulative Cost VBJ services $67,262.00 DAILY COST: CUM: $67,262 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY DALLY WELL OPERATIONS RE~" " DATE: 7/13/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PAGE 1 OF 1 SUMMARY OF OPERATIONS FIELD: Kenai Gas Field WELL #: KBU 33-61 N/A TUBING: 3 1/2" CASING: N/A N/A TREE CONDITION: Good Wash out sand with KCI BENCHES OPEN: Tyonek Sand AFE 9207401 CT Crew Rafferty, Don, et al Finish RU of coil tubing flowback lines, finish pressure test BOP and flowback iron to 250/4500 psi. Held safety and operations meeting. Have 178 bbl of #2 Williams diesel on location plus 234 bbl of 3% KCI. Reel is full of 21 bbl of 3% KCI. SITP = 2200 psi. Bled well to diffuser tank while pumping 3% KCl at minimum rate. Once the pressure was down to 1100 psi, RIH with coil tubing wash nozzle while circulating at 1 bpm. Wash through proppant at 65' (never set down any weight) and continue to RIH circulating. Returns cleaned up after washing through that initial bridge. At 5000' MD, returns have been clean for some time so cease pumping. Continue to RIH dry No problem at all getting past the tubing deformation at 6429' MD. Continue until set down at 7920' CTM. Kick in the pumps at 1.5 bpm and wash to 7982' CTM. Unable to wash any further. Circulate bottoms up, returns clean. MI fire fighting unit and nitrogen pump. Held safety meeting regarding the diesel-pumping stage of this operation. RU centrifugal pump to frac tank containing 178 bbl of diesel. Discover a significant amount of proppant present in the diesel frac tank! No idea how it got there; possibly was back-flushed when we fractured on 6/3/01. Discussed, determined there was a substantial risk of plugging the coil nozzle or the perfs, or of cutting out something. Decided to cancel the diesel-pumping operation until the proppant could be cleaned out of the diesel. POOH with coil tubing. RD injector head, but left BOPs in pace with night cap. Secure well. SDFN. Vendor Equipment Daily Cost Cumulative Cost BJ Services CT $20,000.00 Weaver Bros Diesel Tanker $9,750.00 Misc. tank rental, etc. $5,000.00 PTS flowback personnel $7,200.00 M-I KCI and CaCI $10,000.00 DAILY COST: $51,950.00 CUM: REPORTED BY: Gary Eller MARATHON OIL COMPANY I" DALLY WELL OPERATIONS RE[~ !' PAGE 1 OF 1 DATE: 7/12/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: N/A FIELD: TUBING: N/A RU CT, Pressure test Complete Kenai Gas Field WELL #: KBU 33-61 3 1/2" CASING: N/A TREE CONDITION: Good BENCHES OPEN: CT Crew Rafferty, Don, et al SUMMARY OF OPERATIONS Diesel being delivered, Grease valves on short string in attempt to remedy hiss before removing bull plug. RU Gas buster and chicksan to R&K tank. Continue to MU tool string and prep to go to well Diesel tank found to be dripping form rear hatch. Place containment. Attempt to tighten, RU transfer pump to move to another tank. Call for clean vac truck(s). Notify operators. Transferring diesel. Continue to RU BJ Safety and procedure meeting Wait on fuel R&K Rental flowback tank found to be leaking from bottom. Break down chicksan and call to have tank replaced. Begin P-Test/Function test 250/4500. Successful P-Test SDFN Vendor Equipment Daily Cost Cumulative Cost BJ Services CT ?? Weaver Bros Diesel Tanker Doyle's Fuel Diesel $475.00 $475.00 DALLY COST: $475.00 CUM: $475.00 REPORTED BY: DM Titus Jul'~-O0 02:10pm F rom-MARATHON O I L +g15584848g T-814 P.OZ/03 F-3gz STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reque~ Abandon~ Suspend~ Oper~Men Shutdown .-.-. Re-enter Suspended Well__. Alter Casing Reps. ir Well~ Plugging ~ Time Extension ...... $1~mulate Change Approved Program Pull Tubing Variance Perforate X Other '-'~. Name Of Operator ~' ~ ~, Type of Well: 6. Dal~m EleVatib~ iDF 0r MARATHON OIL COMPANY .. Development ~ BT' KB above MSL feet S, Address Exploratory.._,_ 7, LT~i~'~r Property 'l~ame '" P, O. Box 196168. An~hora~l.er AK 99519-616B Stratigraphic..__ Kenai Beluga Unit ~-4. Location ~f Well at S~fface Service B. W~ll Numbei ' - 37' FNL & 4068' FWL, Sec. 7, T4N, R11W, SM KBU 33-6e At top of Productive Interval lg2.B' FSL & 3410' FWL, Sec. 6, T4N, R11W, a.M. 99-24 At Effective Depth lO. APl Number 50-133-20487 At Total Depth ~I. Fiel~P0o[ 2243' FSL & 2911' FWL, Sec, 6, T4N, R11W, S.M. Kenai Gee Field/~ elU~la ~1'2. Preeeht'well C,~ndition Summary .......... Total Depth; measured 8110 feet I"e-Perf°rate Short String Effective Depth: measured ?E~94 feet Cement PI~TD true vertical 7057 feet Casing Length Si~e Cemented Measured Depth True Vertical Depth Structural 115 20" Driven 115 115 Conductor ~urf~ce 1588 13-3/E1" 600 sks 1568 15.41 Intermediate 5810 9-5/8' 570 sks 5810 5329 Production Li ne r Perforation Depth; measured 6387-6410', 6426-6442', 8446-6471', 6464-15471', 6476-8482', 6486-6490' flue verticel 5888-6905', 5921-5936', 5940-59~4', 5957-~964', 5967-6974', 5979-5983' T~blng (size, grade, and measured depth) 5617' of 3-1/2", 9,2 ppf, L-80 plus 2439' c)I 2.7/8", 6,5 ppf, L:80 to 8056' MD / 7511' TVD Pa~ckers ~nd S$$V (~pe an~ measured depth) N/A 18. /~}}achments "' DeScfiption'$umm~'~ proposal ~ ~et~il-Ed-Operations Crogram ---. 'BOP ~-k-6mh -,--- -~' Estimated D~te f~r Comme~cingO~-era~on 1B. StatUs of Well' ClassifiCation aa: ......... 7/26/00 '1~. I~ P~pos~l ~-a~ VerbaJj~Approved' Oil ~ G as __X ~u~pended .-.-. Name of Approver Date Approved Service 17. I hereby certil thstthe foregoing is true ~nd ~orrect to the best of my kn0wledge,r Signed ~L~~~~ Denise Titus Title Production En~lineer g~ta 7/20/O0 ......... Fo R-COMMISSiON U S-E"ON L~., ' ' ... -COnditions of ApprOVal: ¢l'0{ify Commission so repreae~ttive may wi~ess "'j~Appr°val No. Plug Integflty__ BOP Test I,," Location Clearance _, Mechanical Integrity Test___ -'-~ubsequent Form Required lO-"'-"~.~_~. ORIGINAL SIGNED BY Commie. si~ner A~3. proved bf.On:leref the Commission r~' '-'~l-'or-y~ ~seamount " Submit in Tripl1~t6 ~ol'm I Q-4~3 Rev, 06f15/~8 ORIGINAL JUL 20 Jul~2~-O0 02:llpm From-MAEATHON OI L +915~$46459 T-814 P.03/03 F-392 WELL KBU 33-6 - AFE 9203699 KENA! GAS FIELD REPERFORATING PROCEDURE 1, RU electric line unit on KBU 33-6s. Test BOPE and lubricator to 3000 psig. 2. Rill with 2", 4 spf, 0° phased, scallop guns with 7,0 gm UltraJet charges (entrance hole 0.24"), Perforate the Middle Beluga Sand pay as follows: M-14a Sand 6387'- 6410' M-14b Sand 6426'- 6442' M-14e Sand 6446'- 6460' M-14d Sand 6464'- 6471' M-14e Sand 6476' - 6482' M-t5 Sand 6486'- 6490' POOH, RDMO electric line. 3. Clean up KBU 33-6s through Marathon production facility. Inject methanol downhole as needed to prevent hydrate formation. luly 20, 2000 N;kD RLG\KG~'6rELLSxI(BU3 3.6kREPP. RI~.WPD RECEIVED JUL 2_0 2900 Jul-~O~-O0 OZ:lOpm From-~ARATHOH OIL +g15564648g T-814 P.01/03 F-3gz facsimile TRANSMITTAL to: fax #; re: date: pages: Mr. Blair Wondzell 907-276-7542 Fax of letter pertaining to Well KBU 33-6s, Re-Perforation of Short String July 20, 2000 3, including this cover sheet. Please treat as original. RECEIVED ,JUL 20 2000 ,% 0i~ & Gas C0~s, Co~r~ From the desk of... Betty J. veldhuis for D-M Titus Marathon Oil Company Alaska Region P. O, E~ox 196168 Anchorage, AK 99519-6168 907/564-6326 Fax: 907/584-6489 Alaska i' )n Domestic ,-'roduction Marathon Oil Company July 12, 2000 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Logs: Iqci· o2¥1) Marathon Oil Company/Kenai Gas Field KBU 33-6 ,~' GPIT May 21, 2000 2) Marathon Oil Company/Kenai Gas Field ,V,,,'r c~ q..q-/.e ~ Array Induction, MCFL Gamma Ray, Caliper, Platform Express** June 29, 2000 3) Marathon Oil Company/Kenai Gas FieldKTU 24-6H Density, Neutron Gamma Ray, Caliper, **Platform Express** June 29, 2000 , 4) Marathon Oil Company/Kenai Gas Field KTU 24-6H Dipole Sonic Imager Natural Gamma Tool June 29, 2000 5) Marathon Oil Company/Kenai Gas Field KTU 24-6H Comb. Magnetic Res. Tool Gamma Ray, Caliper, **Platform Express** June 29, 2000 6) Marathon Oil Company/Kenai Gas Field KTU 24-6H Gamma Ray, Caliper, **Platform Express** June 29, 2000 7) Marathon Oil Company/Kenai Gas Field KTU 24-6H Natural Gamma Tool June 29, 2000 Print Reproducible A subsidiary of USX Corporation Environmentally aware for the long run. 8) Marathon Oil Company/Kenai Gas Field KU 43-6A Perforating Record May 1, 2000 9) Marathon Oil Company/Kenai Gas Field KU 43-6A Pressure, Temperature Gamma Ray, CCL **PSP Tool** May 1, 2000 10) Marathon Oil Company/Kenai Gas Field KBU 33-6 Repeat Formation Tester, Gamma Ray May 22, 2000 11) Marathon Oil Company/Kenai Gas Field KBU 33-6 Density, Neutron, Gamma Ray, Caliper, **Platform Express** May 21, 2000 12) Marathon Oil Company/Kenai Gas Field KBU 33-6 Natural Gamma Tool May 22, 2000 13) Marathon Oil Company/Kenai Gas Field KBU 33-6 Comb. Magnetic Res. Tool, Gamma Ray, **Platform Express** May 21, 2000 14) Marathon Oil Company/Kenai Gas Field KBU 33-6 Array Induction Tool, Gamma Ray, Caliper **Platform Express** May 21, 2000 15) Marathon Oil Company/Kenai Gas Field KBU 33-6 Gamma Ray, Caliper **Platform Express** May 21, 2000 16) Marathon Oil Company/Kenai Gas Field KBU 33-6 Dipole Sonic Imager, Natural Gamma Tool May 22, 2000 1 Please sign and return confirming you have received these documents. MARATHON OIL COMPANY Kirsten K. Wheat Received B Enclosures JUL 1 4 tO00 Alaska 0il & Gas Cons. Commission Anchorage Jul-11-O0 01:~i8pm From-MARATHON OI L Marathon Oil Company P.O. E~ox 196168 Anchorage, AK 99519-6168 Telephone 907/561.5;311 July 11,2000 Mr. Blair Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: Field: Kenai Gas Field Well: KBU 33-6s Permit No.: 99-24 APl Number: 50-133-20487 Project: Coil Tubing Unload Operation Dear Mr, Wondzell: Attached please find FORM 403 - APPLICATION FOR SUNDRY APPROVAL for the KBU 33-6s well. We intend to utilize coil tubing on approximately July 15'h, 2000 to unload the completion fluid from this recently perforated wellbore. Your earliest attention is thus appreciated. Please call me if there is ~my additional data that can be provided. ! can be reached at 907-564-6303 (work) or 231-3775 (pager). Sinc~ely, Ralph J. Afflnito Advanced Production Engineer RECEIVED ,JUL 1 1 2000 AJaska 0~; & Gas Cons. Co.~mission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run, Jul-11-O0 01:D8pm From-MARATHON OIL +9155646489 T-T11 P.O~/05 F-14T STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon ,Suspend __ Operation ShuMown Alter Casing ~ Repair Well.,.,.,_ Plugging Change Approved Program ~ Pull Tubing ~ Variance Re-enter Suspended Well Time Extension Stimulate PerforMe Other x --~, 6;;~ mershon (Dr or KS) - 87' KB above MSL 7, Unit, or Property Name Kenai Beluga Unit S, Wail Number KBU 33-65 9. 2. Name of Operator MARATHON OIL COMPANY $. Addreaa P. O. Box 196168. Anchorage, AK 9951~-6168 s. Type of Well: Development..~,X Exploratonj Stfatigraphf~ Sewice 4. Location of Well at Surface 37' FNL & 4068' FWL, Sec. 7, TdN, R11W, SM At top of Productive Interval 1925' FSL & ,3410' FWL, Sec. 6. T4N, R11W, S.M, At Effective Depth At Total Depth 2243' FSL & 2911' FWL, Sec. 6, TdN, R11W, S.M. Permit Number 99-g4 lO, APl Number so. 133.20487 11. Field/Pool Kenai Gas Field/Beluga lZ, Present Well Condition Summary Total Depth; measured t~ue vertical Effective Depth; measured true vertical Oaaing Structural Conductor ,Surface Intermediate Prod uction Liner Perforation Depth'. measured true vertical Length 115 1~68 5810 Tubing (size, grade, and me~eumd depth) Packers and SSSV (type and measured depth) 8110 feet 7~6!!i feet 7694 feet Cement PIBTD 7057 feet Unload Well w/Coil Tubing Size Cemented Measured Depth True Vertical Depth 20" Driven 115 115 600 sks 1568 t.~41 670 sks 581o 6387-6410', 6426-6442', 6446-6471', 6464-6471', 6476-6482', 6486-6490' ~883.~90~', 8921-5956', 5940-59S4', 5957.5964', ~967-5974', 5979-5983' 5617' of 3-1/2", 9,2 ppf, L.80 plus 243~' of 2-7/8", 6.5 ppf, L-so ~o 80.~6' MD/761 t'TVD N/A 13. Attachments Description Summary of Proposal ~ Derailed Operations Progmm~ %OP Sketch -,-- 1~, I~stimated Date for Commencing Opem~ion 15. Status of Well Classification 7/15/2000 la, If Proposal was Verbally Approved Qil._... Gas..~_X Name of Approver Date Approved Service 17. I hereby certify that the foregoing is'tn.lo and correct to the best Of my knowledge. t¢ '""--' Signed .... Ralph Affinito Title Production Engineer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity..__. BOP Test v'/ Loc~tion Clear, nco Mechanical Integrity Tes£~ '-'~ubsequent Form Required lO- ""-~ ~3 '~ ORIGINAL SIGNED BY Approved by Older of ~e Commission r~ Taylor Seamount Form I ~-40,,3 Re,c, 0(~d$/Se Suspe~ded~ Date. 7./.11/2o0o Commissioner RECEIVED _ . ,JUL 1 t 2000 Alaska 0ii & Gas Cons. C~m~ss~0n ~ Jul-11-O0 Ol:$Spm F rom-MARATHON OIL +g15554648g T-T11 P.04/05 F-147 MARATHON OIL COMPANY ALASKA REGION Kenai Gas Field KBU 33-6S AFE 9203699 Coil Tubing Unload Procedure Use coil tubing to jet-in well KBU 33-6s (Beluga Sand completion) which has not unloaded the completion fluid following initial perforating. Procedure: . MIRU Dowell Schlumberger 1.75" OD coil tubing and nitrogen equipment on short string. Set up Marathon gas buster and open top tank with choke and flowback iron. Note upper tree flange is an RX 25 deep ring, 5 bolt, 'D' shaped flange. , Haul to location 60 bbls of freshwater. Pressure test coil tubing and BOP equipment to 3,500 psi bleeding off to open top tank. Displace coil tubing with nitrogen to open top tank and commence RIH jetting with nitrogen at 300 to 500 SCF/min rate. Continue to RIH and jet as necessary to unload well. POOH and allow well to flow. Note that well should not be drawn down below 800 psig following unloading. Shut-in welt. RD coil tubing. Secure well and clean up location. 3. Produce well to clean up as per engineer's instruction. 12:56 PM 07/t 1/00 Fl :Y3RLG\KG ~W ELLS~bu33-6\$ HOR1hCoit~l)gPro.ac~e RECEIVED JUL 1 t 2000 A~aska Oi'; & Gas Cons. Commission .Anchorage Jul-11-O0 01:58pm From-U^R^THON OIL +gl$SB4848g T-?ll P.05/05 F-14T Kenai Gas Field Well KBU 33-6, Pad 41-7 Marathon Oil Co., Alaska Region APl: 50-133-20¢g7 RT-GL: 21.6' RT-THF: 17.6' 37' FNL, 4068' FWL Sec. 6, T4N, RllW, S,M. Treo cxns --- 3-112", Brd NOTE: "Longstring" refers to the non-tapered, 3-112" string. "Shomtfing" refers to tho tapered, 2-7/8" x 3-1/2' side, The terms "short" and "lan#" are only used for convenience, since both strings are actually r~n to the same depth, mm ..... i ..... m -- L 20', 133#, K-55 Drive pipe @ 1 15' Halliburton ,Safety Valve Landing Nipples wl sliding sleeves {~equir~s BXL keys) & 1/4", 0,049" WT control line Model #721XXO28101 X-nipple profiles (ID -- 2.813") SS @ 91I' (opened 619100) LS ~ 978' (opened 619100) 13.3/8", 68~, L.80, BTC Casing @ 156B' Cmt w/600 sks of Class O 9-518', 40#, L-S0, BTC Casing @ 5810' Cmt wi 570 sks of Cla~ O Tag m~ (ss) ~ ~t;) ~aa) Last Rev: lOt~, 6112100 Ts# fill PBTD (LS) ~ 8055' PBTD (SS) '- 8056' TD = 8110' RECE)VED 3-112", 9.3#, L-80, EUE 8xd.M wi SEC @ -3~718" taper @ 8087' 0' - 5617': 3-1/2", 9.3#, L-gO, EUE gtd-M wi SEC 5617' - g087': 2-718", 6.5#, L-BO, EUE ~rd-M ~vl SCC C~ment Cemented with 339 sks class O JUL 1 t 2000 "'" ~ % o o A~aska 0ii & Gas con~. commission Anchorage Jul-11-O0 01:BSpm From-MARATHON OIL +g1~5846489 T-?ll P.01/0~ F-147 Aleske .1~ ~ Domemi~ .duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER Li~ ~ER JJ' DATE: PLEASE DELIVER THE FOLLOWING TO: company:' Fax No.: Number of Pages ~incl~dlng cover page)'- .. FROM: Location/Extension: Fax No.: 907/564-6489 _ ._ NOTE: transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation Environmentally aware for the Io~CE~VE D JUL 1 1 7.000 Alaska Oii& Gss Cons. Commission .~chorage KBU :,3-6 Well Design Subject: KBU 33-6 Well Design -~' Date: Mon, 22 May 2000 01:45:31 -0500 From: "J Gary Eller" <JGEller~MarathonOil.com> To: Blair_Wondzell~admin.state.ak.us, ABSchoffmann~MarathonOil.com, CEYoung~MarathonOil.com, MJStover~MarathonOil.com, PKBerga~MarathonOil.com Blair - In response to our telephone conversation of Friday, 5/19/00, I wanted to give you some information regarding the well design of KBU 33-6 in the Kenai Gas Field. In particular, you wanted to better understand Marathon's thought process in deciding to cement dual tubing strings instead of setting a liner or doing a more conventional completion. The KBU 33-6 well is designed to achieve several objectives. We wanted to test Beluga Sand intervals that are currently below our pay criteria in the hopes that we could successfully stimulate them and add significant gas reserves. But if unsuccessful, we still wanted to be able to develop the high-quality Beluga Sand pay. The well had to be designed to allow fracture stimulation of either type of pay. And the well had to develop gas at a reasonable cost per MCF, but at this early stage of trying to prove the low-quality pay concept cost was not the primary factor. Marathon used a "peer review process" with people from our world-wide operations to critique the Alaska Region's plans for developing the KGF Beluga Sands. These "peers" considered a dual tubingless completion to be one of the best ways to ideally achieve our goals. Other methods that were considered but discarded included a single tubingless completion, a downhole splitter completion, fracturing via a coil tubing straddle assembly, and a conventional tubing & packer completion. The key aspects that favored the dual tubingless completion as designed in well KBU 33-6 are: 1) Can frac the iow-quality Beluga pay down one string, and can frac high-quality Beluga Sand pay in the other. One string therefore "pays the bills" for the well, while the other is more devoted to the "science" of testing low-quality pay. 2) Can measure the pre and post-frac production from each string. We would not have been able to determine the flow contribution of low-quality pay if it was completed and commingled with the high-quality pay. 3) Allows us to produce the strings to different gathering systems (i.e. high-pressure system versus low-pressure system) if needed. 4) The completion is well suited for minimizing loading problems and ease of coil tubing sand cleanouts. 5) Less rig time, complexity (from a fracture stimulation standpoint), and expense than a conventional dual completion. KBU 33-6 is the first well of this design to be done in Alaska and even within Marathon, but dual tubingless completions are not new to the industry. They have been done in Texas and Louisiana for over 30 years. They have regained renewed interest within the last several years because of the ability to complete different intervals at minimal cost. Marathon has employed the services of Mack Young of Antelope Oil Tools to help design and run the dual tubingless completion. Mr. Young has been successfully running these style of completions for 30 years. Mr. Young also teaches a class on cementing at Halliburton's facility in Duncan, Oklahoma. I hope this answers your questions. Please let me know if I can be of further assistance. 1 of I 5/22/00 7:57 AM MARATHON OIL COMPANY KBU #33-6 KENA I GA S FIEL D, PA D 41- 7 Section 7- T4N-Rlf W, SM Kenai Peninsula, Alaska May 20, 2000 EPOCH TABLE OF CONTENTS MARATHON OIL COMPANY KBU #33-6 WELL RESUME 2 DRILLING AND FORMATION SUMMARY 3 LITHOLOGY SUMMARY 4 DALLY ACTIVITY SUMMARY 5 MUD RECORD 6 7 8 BIT RECORD SURVEY RECORD MORNING REPORTS WELL RESUME MARATHON OIL COMPANY WELL NAME: KBU 33-6 FIELD: KENAI GAS FIELD REGION: KENAI PENINSULA, ALASKA LOCATION: 37' FNL, 4068' FWL SEC 7-T4N-R11W SM BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 87.0' AMSL APl NUMBER: #50-133-20487 OPERATOR: Operator Representatives: Company Geologist: MARATHON OIL COMPANY OTIS WATKINS, DARRELL GREEN DAVID BRIMBERRY CONTRACTOR: INLET DRILLING DRILLING RIG: Toolpusher: GLACIER DRILLING #1 GEORGE BREWSTER MUDLOGGING COMPANY: Logging Geologists: EPOCH WELL SERVICES, INC. JOHN MORRIS, CRAIG SILVA MUD COMPANY: Mud Engineers: MI BOB WILLIAMS, ROD MABEUS MWD COMPANY: MWD Engineer: BAKER HUGHES INTEQ STEVE STURGES DIRECTIONAL COMPANY: Directional Driller: BAKER HUGHES INTEQ TOMM DUNN CEMENT COMPANY: DOWELL SCHLUMBERGER WIRELINE COMPANY: Logging Engineer: SCHLUMBERGER KHEDJER MELLAH MARATHON OIL COMPANY KBU #33-6 DRILLING AND FORMATION SUMMARY PROSPECTUS The primary objectives of the KBU #3306 well were to evaluate productive sands within the Beluga formation within the Kenai Gas Field. BRIEF REVIEW OF ACTIVITY Marathon Oil Company spudded the KBU #33-6 well with Glacier Rig #1on April 28, 2000. 4, 2000, and reached a Total Depth of 8,1t0' M.D. (7,566' TVD) on May 20, 2000. 17 1/2" hole was drilled from surface to 1575'MD, and 13 3~8" Casing was set at 1568'. 12 1/4" hole was drilled from 1575' to 5810'MD, and 9 5/8" Casing was set at 5810'. 8 1/2" hole was drilled to Total Depth at 8110'M.D. There were no major problems that impeded the drilling of KBU 33-6. There were no significant problems after reaching T.D. and completing the well. BRIEF DIRECT,10NAL REVIEW KBU 33-6 was vertical to 600', where a kick off was initiated at Azimuth 285°. Hole Inclination Angle was built to a maximum 30.28° at 2760'. The hole angle was held at 290-30° until 4145'MD/3800'TVD, and then the well path was directed toward vertical as per the well plan, eventually finishing at a projected 9.50° at 8110'MD/7565TVD (TD). The wellpath's most northerly direction of Azimuth 349.20° was reached at 1134'MD/1129TVD, then turned gradually to the west and held in the 341°-343° range until 4932'/4500'TVD, and finally "walked" to the planned 3030-300° target direction as the hole drop was in progress. The projected final Azimuth at 8110'MD/7565TVD (TD) was 303.90°. LOGGING PROCEDURES Epoch Well Services provided RIGWATCH 2000TM Drilling Monitoring services and DMLTM Mudlogging Service. Hydrogen flame ionization total gas and chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by an air motor driven gas trap located at the shale shaker header box and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 10' intervals as directed by MARATHON's sampling program. MARATHON OIL COMPANY KBU 33-6 LITHOLOGY SUMMARY TUFFACEOUS CLAYSTONE ($810'-$840'): LIGHT TO MEDIUM GREENISH GRAY WITH COMMON OLIVE HUES; VERY SOFT TO MODERATELY FIRM; MUSHY TO SLIGHTLY BRITTLE; SMALL IRREG AND BLOCKY CUTTINGS; MATTE TO SLIGHTLY WAXY LUSTER; SMOOTH SCATTERED TO COMMON ASHY STREAKS AND BLEBS; OCCASIONALLY SILTY, GRADING IN PART TO SILTSTONE; NO STRUCTURE; NO OIL. COAL ($865'): DUSKY BROWN TO BLACK; FIRM; BRITTLE; SPLINTERY, BLOCKY AND TABULAR CUTTINGS; SLIGHTLY SHINY LUSTER; SMOOTH TEXTURE; OCCASIONALLY THIN CLAYSTONE LAMS; OCCASIONAL DARK BROWN TO BLACK STREAKS. CLAYSTONE ($855'-5920'): ARGILLACEOUS WITH LOW TUFFACEOUS CONTENT; MEDIUM GRAY TO MEDIUM DARK GRAY; SOFT; SLOWLY SOLUBLE, LESS EASILY DISPERSED THAN TUFF CLAY. SAND/CONGLOMERATIC SAND (5920'-5960'): MEDIUM GREENISH GRAY TO MEDIUM DARK GRAY WITH VERY STRONG GREENISH OR OLIVE SECONDARY HUES; FINE LOWER TO GRANULE; POORLY SORTED OVERALL, BUT TWO MODES: 65% MODERATELY WELL SRTD FINE UPPER TO MEDIUM UPPER, 35% POOR SRTD COARSE UPPER TO GRANULE; ANGULAR TO SUBANG; DISCOIDAL TO SUBDISCOIDAL; ALMOST ALL DISAGGREGATED, APPARENT VERY SOLUBLE TUFFACEOUS CLAY MATRIX SUPPORTED; COMPOSITIONAL GRAYWACKE (>30%lithics); ESTIMATED 30-50% QUARTZ AND COLORLESS TRANSPARENT VOLCANIC GLASS, TRACE FELDSPAR, 20-40% CHERT, 10-15% CHALCEDONY AND OTHER FORMS OF SILICA; 30-40% LITHICS; LITHICS DOMINANTLY FROM LOW GRADE METAGREENSTONE, AND MEDIUM GRADE META DARK GRAY TO BLACK ARGILLITE-PHYLLITE SOURCES. NO OIL INDICATORS. SAND/CONGLOMERATIC SAND ($965'-6075'): -GENERALLY CONTINUED SAME CHARACTERISTICS AS SAND DESCRIBED ABOVE, BUT OVERALL DARKER GREENISH GRAY COLOR, AND LARGER FRACTIONS OF CHERT AND LITHICS; LOCALLY VERY ABUNDANT (>85%) DARK GRAINS, AND SAND COLOR IS GREENISH BLACK; NOTE SPOTTY SMALL PIECES OF CONSOLIDATED FINE TO MEDIUM SANDSTONE WITH MIXED CLAY AND CALCITE MATRIX SUPPORT. SILTSTONE (5810'-6090'): BROWNISH GRAY TO GRAYISH BROWN TO PALE BROWN; SLIGHTLY FIRM TO SLIGHTLY BRITTLE; GRADING TO BOTH TUFF AND ARGILLACEOUS CLAYST; SILTY TO SLIGHTLY ABRASIVE TO VARIABLE MATTE TEXTS; EARTHY LUSTRE. SAND/SANDSTONE (6090'-6175'): GREENISH BLACK TO DARK GREENISH GRAY, DARK GRAY TO GRAYISH BLACK WITH STRONG GREENISH SECONDARY HUES; FINE UPPER TO PEBBLE FRAGMENTS; OVERALL POORLY SORTED BUT APPEARS HAVE NEARLY THE SAME SIZE MODES AS DESCRIBED AT 5930'; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; ALL COARSER SANDS ARE DISAGGREGATED, SPOTTY CONSOLIDATED PIECES OF MOSTLY CLAY MATRIX SUPPORTED; SOME LARGER GRAINS HAVE TINY PATCHES OF CALCITE; COMPOSITIONAL GRAYWACKE (>30%lithics); ESTIMATED 10-30% QUARTZ AND COLORLESS TRANSPARENT VOLCANIC GLASS, TRACE FELDSPAR, 10-40% CHERT, TR-10% CHALCEDONY AND OTHER FORMS OF SILICA; 40-80% LITHICS DOMINANTLY FROM LOW GRADE META GREENSTONES, AND MEDIUM GRADE META DARK GRAY TO BLACK ARGILLITE-PHYLLITE ROCK FRAGMENTS PLUS MAFIC MINERALS. SlLTSTONE (6245'-6270'): BROWNISH GRAY TO GRAYISH BROWN TO PALE BROWN; SLIGHTLY FIRM TO SLIGHTLY BRITTLE; GRADING TO BOTH TUFF AND ARG CLAYST; SILTY TO SLIGHTLY ABRSV TO VARIABLE MATTE TEXTS; EARTHY LUSTRE. SAND (6275'-6320'): DOMINANTLY MEDIUM TO DARK GREENISH GRAY, COMMON MEDIUM TO DARK GRAY, OCCASIONALLY CLEAR TO TRANSLUCENT WHITE; VERY FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAIN; ANGULAR TO ROUNDED, DOMINANTLY SUBANG TO SUBROUND; POORLY SORTED; RARE PEBBLE FRAGS; 50 TO 60% IG/METANOLC LITHICS, 30% CHERT, 20% QUARTZ; DOMINANTLY UNCONSOLIDATED IN SAMPLES; RARELY WITH TRACES OF CALCITE CEMENT ENCRUSTING GRAIN SURFACES; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. TUFFACEOUS CLAYSTONE (6330'-6385'): LIGHT GREENISH GRAY TO PALE YELSH BROWN, OCCASIONALLY MODERATELY BROWN; SOFT TO SLIGHTLY FIRM; MUSHY TO CRUMBLY, OCCASIONALLY SLIGHTLY BRITTLE; SMALL IRREG, BLOCKY AND TABULAR CUTTINGS; MATTE TO OCCASIONALLY SLIGHTLY SHINY LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY MODERATELY GRAINY, SILTY TEXTURE; SLIGHTLY TO VERY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON GLASS SHARDS; COMMON ASHY STREAKS AND BLEBS; NO STRUCTURE. SAND (6400'-6440'): MEDIUM TO DARK GRAY, COMMON MEDIUM TO DARK GREENISH GRAY, OCCASIONALLY LIGHT GRAY TO WHITE; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAIN; ANGULAR TO SUBROUND; MODERATELY WELL SORTED; COMPOSED OF 50% IGNEOUS/META LITHICS, 30% CHERT, 20% QUARTZ; TOTALLY UNCONSOLIDATED IN SAMPLES; RARE GRAINS WITH THIN CALCITE CRUST ON SURFACES; ESTIMATED GOOD VISUAL POROSITY AND PERMEABILITY. SILTSTONE (6450'-6480'): MODERATE TO BROWN, DARK BROWNISH GRAY; SOFT TO FIRM; CRUMBLY TO MODERATELY TOUGH; IRREG, LUMPY SHAPED CUTTINGS; MATTE LUSTER WITH SCATTERED TO COMMON MICROSPARKLES; ROUGH, GRAINY, ABRASIVE TEXTURE; NON-TO MODERATELY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; SCATTERED TO COMMON MICROMICA; ARGILLACEOUS IN PART, GRADING TO CLAYSTONE; ASHY IN PART. SAND (6495'-6545'): MEDIUM TO DARK GREENISH GRAY, COMMON MEDIUM TO DARK GRAY, OCCASIONALLY CLEAR TO TRANSLUCENT WHITE; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAIN; ANGULAR TO ROUNDED, DOMINANTLY SUBANGULAR TO SUBROUND; POORLY SORTED; OCCASIONALLY PEBBLE FRAGMENTS; 50 TO 60% IG/METANOLC LITHICS, 30% CHERT, 20% QUARTZ; DOMINANTLY UNCONSOLIDATED IN SAMPLES; RARELY WITH TRACES OF CALCITE CEMENT CRUSTS ON GRAIN SURFACES; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. COAL (6575'-6590'): BLACK TO DUSKY BROWN; FIRM; BRITTLE; SPLINTERY, BLOCKY AND TABULAR CUTTINGS; SLIGHTLY SHINY LUSTER; SMOOTH TEXTURE; OCCASIONALLY THIN CLAYSTONE LAMS; OCCASIONALLY DARK BROWN TO BLACK STREAKS; OCCASIONALLY VERY ARGILLACEOUS, GRADING TO CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (6595'-6655'): LIGHT GREENISH GRAY TO PALE YELLOWISH BROWN, OCCASIONALLY MODERATELY BROWN; SOFT TO SLIGHTLY FIRM; MUSHY TO CRUMBLY, OCCASIONALLY SLIGHTLY BRITTLE; SMALL IRREGULAR, BLOCKY AND TABULAR CUTTINGS; MATTE TO OCCASIONALLY SLIGHTLY SHINY LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY MODERATELY GRAINY, SILTY TEXTURE; SLIGHTLY TO VERY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON GLASS SHARDS; COMMON ASHY STREAKS AND BLEBS; NO STRUCTURE. SAND (6650'-6710'): MEDIUM TO DARK GRAY, COMMON MEDIUM TO DARK GREENISH GRAY, OCCASIONALLY LIGHT GRAY TO WHITE; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAIN; ANGULAR TO SUBROUND; MODERATELY WELL SORTED; COMPOSED OF 60% IGNEOUS/META LITHICS, 30% CHERT, 10% QUARTZ; TOTALLY UNCONSOLIDATED IN SAMPLES; OCCASIONALLY GRAINS WITH THIN CALCITE CRUST ON SURFACES; ESTIMATED FAIR VISUAL POROSITY AND PERMEABILITY. TUFFACEOUS CLAYSTONE (6710'-6750'): LIGHT MEDIUM GRAY TO PALE YELSH BROWN, OCCASIONALLY PALE BROWN; SFT TO SLIGHTLY FIRM; MUSHY TO CRUMBLY, OCCASIONALLY SLIGHTLY BRITTLE; SMALL IRREG, BLOCKY TO LUMPY CUTTINGS; ASHY TO SLIGHTLY SLTY TO SOFT MATTE TEXTURE; SOFT GLASSY TO SLIGHTLY SPARKLY TO DULL LUSTRE; NON TO SLIGHTLY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; COMMON GLASS SHARDS; COMMON STREAKS WITH WHITE "CLEAN" LESS DISTURBED ASH. SANDSTONE (6600'-6800'): CONSISTENT SPARSELY SCATTERED TO LOCALLY ABUNDANT PIECES OF CONSOLIDATED CALCITE CEMENTED SS; CEMENTATION IS PROMINENT, MANY DISAGGREGATED GRAINS HAVE RIMS OF CALCITE; MEDIUM TO DARK GREENISH GRAY, MEDIUM DARK TO DARK GRAY WITH STRONG GREENISH GRAY SECONDARY HUES; FRIABLE TO HARD; SOME PCS VERY RESISTANT TO BREAKING; STRONG EFFERVESCENCE; ALL SIZE RANGES INCLUDED; OORLY SORTED OVERALL; LOCAL MIX OF CALCAREOUS AND SlLIC CEMENT; COMPOSITIONAL GRAY WKE; ESTIMATED 40-70% LITHICS AND CHERT, 20-50% QUARTZ . COAL/CARBONACEOUS SHALE (6805'-6825'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LOW GRADE COAL, LIGNITE, CLOSELY GRADATIONAL TO ASSOCIATED CARBONACEOUS SHALE; BRITTLE TO FIRM; MARGINALLY TOUGH TO CRUMBLY; NOTE LOCAL VARIATION OF CARB SH IS SOFT AND CLAYEY; DENSE MATTE TEXT; SLIGHTLY RESINOUS TO DULL TO DENSE EARTHY LUSTRE; GEN IRREGULAR PLANAR FRACTURE. SAND/SANDSTONE (6830'-6880'): MEDIUM DARK GREENISH GRAY TO OCCASIONALLY GREENISH BLACK; LOCAL LIGHTER DARK OLIVE VARIATION; FINE LOWER TO GRANULE; POORLY SORTED; MOST ABUNDANT FRACTION IN MEDIUM UPPER TO COARSE UPPER RANGE; ANGULAR TO SUBANG, DISCOIDAL TO SUBDISCOIDAL; MOSTLY DISAGGREGATED; CONOSL PCS ARE MIX OF CLAY MTRX SUPPORTED AND CALCAREOUS CEMENTED; COMPOSITIONAL GRAYWACKE (>30%lithics); ESTIMATED 20-50% QUARTZ AND CLEAR VOLCANIC GLASS, TRACE FSPR, 20-40% CHERT, 5-15% CHALCEDONY AND OTHER FORMS OF SILICA; 30-50% LITHICS; DOMINANTLY LITHICS ARE GREENISH GRAY- GRYSH GREEN LOW GRADE META GREENSTONE ROCK FRAGMENTS AND DARK GRAY -BLK MEDIUM GRADE META ARGILLITEROCKFRGS AND MAFIC MNRLS; NO OIL INDICATORS. SAND/SANDSTONE (6880'-6990'): GENRALLY SAME AS ABOVE BUT DOMINANT GR SIZE IS FINE UPPER TO MEDIUM LOWER; MOST OF THE SANDSTONE IS CLAY MATRIX SUPPORTED, AND LOCALLY IS VERY CLOSELY GRADATIONAL TO A VERY SANDY CLAYSTONE. TUFFACEOUS CLAYSTONE (6880'- 6990'): LIGHT MEDIUM GRAY TO MEDIUM GRAY TO LIGHT GRAYISH BROWN; SFT TO SLIGHTLY BRITTLE; ASHY TO CLAYEY TO SOFT MATTE TEXTURES; SLIGHTLY SPARKLY TO SOFT GLASSY LUSTRE; GEN COMMON VISIBLE GLASS SHARDS; COMMON CONTAINS SAND GRAINS; MASSIVE AND STRUCTURELESS TO SLIGHTLY SHALEY; OVERALL DISPLAYS VARIOUS DEGREES OF REWORKING. SAND/SANDSTONE (6990'-7080'): OLIVE BLACK TO DARK GREENISH GRAY; FINE LOWER TO COARSE LOWER; TWO MODES, BUT 85-90% IS MODERATELY WELL SORTED IN FINE UPPER TO MEDIUM LOWER RANGE; ANG-SBANG, DISCOIDAL- SUB-DISCOIDAL; VERY DOMINANTLY DISAGGREGATED, ONLY LOCAL MINOR PCS CONSOL SS, MORE CLAY MATRIX SUPPORTED THAN CALCAREOUS CEMENTED; CONTD COMPOSITIONAL GRAYWACKE; ESTIMATED 20-50% QUARTZ AND CLEAR VOLCANIC GLASS, TR-5% FSPR, 20-40% CHERT, 10-15 CHALCEDONY AND OTHER FORMS SILICA; 30-60% SAME METALITHICS AS ABOVE. SAND (7t40'-7180'): MEDIUM TO DARK GRAY WITH COMMON LIGHT TO MEDIUM GREENISH GRAY AND COMMON CLEAR TO TRANSLUCENT WHITE; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAINED; ANGULAR TO ROUNDED, DOMINANTLY ANGULAR TO SUBROUND; MODERATELY WELL SORTED; COMPOSED OF 60% IGNEOUS META/VOLC LITHICS, 20% CHERT, 20% QUARTZ RARE MICROCRYSTALLINE PYRITE CHUNKS; VARIABLE MATRIX/GRAIN SUPPORT; TOTALLY UNCONSOLIDATED IN SAMPLES; SOME GRAINS WITH THIN CRUST OF CALCITE; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. TUFFACEOUS CLAYSTONE (7205'-7255'): LIGHT TO MEDIUM GREENISH GRAY, OLIVE GRAY, MODERATELY BROWN, PALE YELSH BROWN; VERY SOFT TO MODERATELY FIRM; MUSHY TO MODERATELY BRITTLE; SMALL IRREG, BLOCKY AND TABULAR CUTTINGS; DULL TO OCCASIONALLY SLIGHTLY SHINY LUSTER; DOMINANTLY SMOOTH TO COMMON MODERATELY GRITTY TEXTURE; SLIGHTLY TO VERY CALCAREOUS; COMMON BLACK PINPOINT SPECKS; SCATTERED TO COMMON GLASS SHARDS; SCATTERED TO COMMON ASHY STREAKS AND BLEBS; OCCASIONALLY SILTY, GRADING TO TUFF- ACEOUS SILTSTONE. TUFFACEOUS SlLTSTONE (7265'-7290'): LIGHT TO MEDIUM GREENISH GRAY, MODERATELY BROWN; SOFT TO FIRM; CRUMBLY TO MODERATELY TOUGH; DULL, EARTHY LUSTER WITH SCATTERED MICROSPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO MODERATELY CALC; ARGILLACEOUS, GRADES IN PART TO CLAYSTONE; SCATTERED ASHY STREAKS AND SPECKS; SCATTERED VOLCANIC GLASS SHARDS. COAL (7300'-7305'): BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; BRITTLE; MODERATELY TOUGH; SHINY LUSTER; SMOOTH TO SLIGHTLY GRAINY TEXTURE; HACKY, SPLINTERY CUTTINGS; OCCASIONALLY DARK GRAY STREAKS WITH HIGH CLAY CONTENT; OCCASIONALLY VERY ARGILLACEOUS, GRADING TO CARBONACEOUS SHALE. SAND (7350'-7400'): MEDIUM TO DARK GRAY WITH COMMON LIGHT TO MEDIUM GREENISH GRAY AND COMMON CLEAR TO TRANSLUCENT WHITE; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAINED; ANGULAR TO ROUNDED, DOMINANTLY ANGULAR TO SUBROUND; MODERATELY WELL SORTED; COMPOSED OF 60% IGNEOUS/META/VOLC LITHICS, 20% CHERT, 20% QUARTZ; RARE MICROCRYSTALLINE PYRITE CHUNKS; VARIABLE MATRIX/GRAIN SUPPORT; UNCONSOLIDATED IN SAMPLES; FEW GRAINS WITH LIGHT CRUST OF CALCITE CEMENT PRESENT. TUFFACEOUS CLAYSTONE (7410'-7445'): LIGHT TO MEDIUM GREENISH GRAY, OLIVE GRAY, MODERATELY BROWN, PALE YELSH BROWN; VERY SOFT TO MODERATELY FIRM; CRUMBLY TO MODERATELY BRITTLE; SMALL IRREGULAR, BLOCKY AND TABULAR CUTTINGS; DULL TO SLIGHTLY SHINY LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY MODERATELY GRITTY TEXTURE; SLIGHTLY TO VERY CALCAREOUS; COMMON BLACK PINPOINT SPECKS. TUFFACEOUS SlLTSTONE (7455'-7490'): LIGHT TO MEDIUM GREENISH GRAY, MODERATELY BROWN; SOFT TO FIRM; MUSHY TO MODERATELY TOUGH; MATTE, EARTHY LUSTER WITH SCATTERED MICROSPARKLES; GRITTY, ABRASIVE TEXTURE; SLIGHTLY TO MODERATELY CALC; ARGILLACEOUS, GRADES IN PART TO CLAYSTONE; COMMON ASHY STREAKS AND SPECKS; COMMON VOLCANIC GLASS SHARDS. COAL/CARBONACEOUS SHALE (7525'-7565'): BLACK TO BROWNISH BLACK TO VERY DUSKY BROWN; LOW GRADE COAL: LIGNITE, BRITTLE, DENSE MATTE TO SMOOTH TEXT, DULL TO PATCHY RESINOUS LUSTRE, IRREGULAR PLANAR FRACTURE; CLOSELY ASSOCIATED CARBONACEOUS SHALE: GRADING AND INTERBEDDED W/COAL, SLIGHTLY TO VERY FRM, ORGANIC TO MATTE TO CLAYEY TEXTS, DULL TO EARTHY LUSTRE; SPOTTY ASSOC SOFT CARB CLAYST; COMMON PCS W/MICROTHIN ALTERNATING INTBDS OF COAL AND CARB SH; LOCAL INTERBEDDED VOLCANIC ASH. SAND/SANDSTONE (7570'-7670'): DARK GRAYISH GREEN TO DARK GREENISH GRAY TO LOCAL GREENISH BLACK OR OLIVE BLACK; FINE LOWER TO VERY COARSE UPPER; POORLY SORTED OVERALL, BUT DOMINANT MODE OF MODERATELY SORTED MEDIUM LOWER TO COARSE LOWER; ANGULAR TO SUBANGULAR, DISCOIDAL TO SUBDISCOIDAL; DISAGGREGATED, SPOTTY CONSOL PCS WiTH MiX OF CALCAREOUS AND SILIC CMT; NOTE DECREASING CALCAREOUS OVERALL, ONLY SPOTTY EFFERVESCENCE; COMPOSITIONAL GRAYWACKE; ESTIMATED 30-60% QUARTZ AND COLORLESS+TRANS- PARENT GLASS, TRACE FELDSPAR, 10-15% CHERT, 5-10% CHALCEDONY AND OTHER FORMS SILICA, 30-50% LITHICS DOMINATED BY GREEN ISH GRAY- GRYISH GREEN GREENSTONE ROCK FRAGMENTS; DARK GRAY-BLK META (ARGILLITE) ROCK FRAGMENTS BECOMING LESS ABUNDANT; NOTE COMMON CLASTIC COAL FRAGMENTS. COAL/CARBONACEOUS SHALE (7585'-7765'): COAL: BLACK TO BROWNISH BLACK; LIGNITE TO SUBBITUMINOUS; BRITTLE; TOUGH TO FRAGILE; SMOOTH TO VERY DENSE MATTE TEXTURE; RESINOUS LUSTRE; IRREGULAR BLOCKY HABIT; IRREGULAR TO SUBCONCHOIDAL FRACTURE; LARGE PCS HAVE PARALLEL ORIENTED PATTERNS; SPOTTY LIGHT YELLOW MASSES OF AMBER; CARB SH; BRNISH BLACK TO VERY DUSKY BROWN; BRIT TO FRM; MATTE TO ORGANIC TO CLAYEY TEXT; VERY EARTHY LUSTRE. TUFF (7735'-7775'): VERY LIGHT GRAY TO LIGHT GRAY TO WHITE; SOFT- SLIGHTLY FIRM; SLIGHTLY SHALEY; ASHY TEXTURE; SOFT GLASSY LUSTRE; ABUNDANT VIS SHRDS. SAND (7775'-7820'): DISTINCTIVE CHANGE FROM SDS ABV, LITHICS % DECREASES; LIGHT GRAY TO MEDIUM LIGHT GRAY W/ONLY FNT GREENISH GRAY SEC HUES; MODERATELY SORTED IN MEDIUM LOWER TO COARSE LOWER RANGE; DISAGGREGATED; ANG-SBANG, SBDSOOIDL-DISCOIDAL; SUBLITHIC ARENITE; 80-85% QUARTZ AND ABNT (>30%) CLEAR GLASS; SPTTY LITHICS. SAND (7820'- 7880'): CLEAR, TRANSLUCENT WHITE, LIGHT TO DARK GRAY, LIGHT TO DARK GREENISH GRAY; FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAINED; MODERATELY WELL SORTED ANGULAR TO SUBROUND; COMPOSED OF 80% QUARTZ, 20% METNVOLC LITHICS; TOTALLY UNCONSOLIDATED IN SAMPLES; INCREASING LITHICS WITH DEPTH: 30% AT 7880'; ESTIMATED GOOD VISUAL POROSITY AND PERM; NO EVID OF MATRIX. COAL (7885'-7905'): BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; BRITTLE, MODERATELY TOUGH; IRREGULAR, HACKLY AND TABULAR CUTTINGS WITH SHARP EDGES; MATTE TO SLIGHTLY SHINY LUSTER; SMOOTH TEXTURE; OCCASIONALLY ARGILLACEOUS STREAKS GRADING TO CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (7915'-7940'): LIGHT MEDIUM GREENISH GRAY, LIGHT TO MEDIUM GRAY, MODERATELY BROWN, PALE YELLOWISH BROWN; VERY SOFT TO FIRM; CRUMBLY TO SLIGHTLY BRITTLE; MATTE TO SLIGHTLY RESINOUS LUSTER; SMOOTH TO MODERATELY GRITTY TEXTURE; NON TO VERY CALCAREOUS. SAND (7940'-7980'): CLEAR, TRANSLUCENT WHITE LIGHT TO MEDIUM GRAY; CLASTS RANGE FROM FINE TO COARSE, DOMINANTLY FINE TO MEDIUM; ANGULAR TO SUBROUND; MODERATELY SORTED; COMPOSED OF 70% QUARTZ, 30% META/VOLC LITHICS; RARELY CONSOLIDATED IN SAMPLES WITH CLAY MATRIX; ESTIMATED GD POROSITY AND PERMEABILITY. TUFFACEOUS CLAYSTONE (7990'-8015'): LIGHT MEDIUM GREENISH GRAY, LIGHT TO MEDIUM GRAY, MODERATELY BROWN, PALE YELLOWISH BROWN; VERY SOFT TO FIRM; CRUMBLY TO SLIGHTLY BRITTLE; MATTE TO SLIGHTLY RESINOUS LUSTER; SMOOTH TO MODERATELY GRITTY TEXTURE; NON TO VERY CALCAREOUS. COAL (801 $'-8045'): BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; BRITTLE, MODERATELY TOUGH; SLIGHTLY SHINY LUSTER; SMOOTH TEXTURE; SPLINTERY, TABULAR AND IRREGULAR CUTTINGS WITH COMMON CONCHOIDAL FRACTURE SURFACES; RARE CLAY LAMINATIONS; RARE GAS BUBBLES ON FRACTURE SURFACES. SAND (8095'-8110'): LIGHT GRAY TO LIGHT GREENISH GRAY; FINE LOWER- COARSE LOWER; MODERATELY WELL SORTED IN FINE UPPER-MEDIUM LOWER RANGE; 80% SBANG- ANGULAR AND SUBDISCOIDAL, 20% RD-SBRD AND SBSPHERICAL; DISAGGREGATED; LITHIC QUARTZ ARENITE AT TOP, THEN SUBLITHIC ARENITE; 80-90% QUARTZ FRACTION INCLUDES 20-40% COLORLESS AND TRANSP VOLCANIC GLASS, TRACE FSPR, TR-5% CHRT, 10- 15% GREENSTONE METALITHICS; LSE SD NON-CALC, TR-5% SANDSTONE VERY CALCAREOUS. MARATHON OIL COMPANY KBU 33-6 DAILY CHRONOLOGY 412712000: Finish picking up Top Drive. Change saver sub to 4 %"IF connection and install end bell guide for 5" HWDP. Install casing stabbing board. Install purge air for Top Drive. Rig up flow line and jet line. Install rig floor mud manifold. Hang kelly hose and cement hose. Install trip tank flow line. Finish installing diverter line. Work on water line to tanks from water well. Spot second water tank. Install Flowshow in flow line. Install mouse hole. Fold up derrick windwalls. Install geolograph line. Prepare to pick up drill pipe. 412812000: Rig accepted for well work on KBU 33-6 at 00:01Hrs on 4~28~2000. Set mudlogging unit. Strap drill pipe. Hold PJSM. Pick up 4" drill pipe and stand back same in derrick. Strap 5" HWDP. Function test annular and knife valves as required per AOGC. Pick up 5" drill pipe and stand back same in derrick. Pick up and make up BHA#1. Tag bottom at 46'. Attempt to break circulation. Trouble shoot mud pump PLC. Fill hole. Break circulation. Check for leaks. Drill from 46' to 67'. Circulate and clean hole. Jet flowline. Orient MWD and make connection. Trouble shoot mud pump PLC and find bad connection in plug. Drill from 67' to 129'. Conveyer plugged up. Control drill from 129' to 217'. 4129/2000 Work on Top Drive. Attempt to break out stand of HWDP. Shuffle valve on carrier not shifting to give correct hydraulic pressure for task at hand. Repaired valve. Control drill from 129' to 525'. Manage fluid losses at shakers with gravel washing process. Drill ahead from 525' to KOP at 600'. Rotate and slide as needed to build and control angle and direction. Drill ahead to 941'. Circulate hole clean. Change out Top Drive saver sub, end bell guide, and elevator inserts. Saver sub was galled on the first make up and had to be changed out a second time. Drill from 941' to 1004'. 4~30~2000: Drill ahead sliding from 1004' to 1037', and back ream hole section. Lay down 2 bad joints of 4" drill pipe. Pump up Top Drive compensator. Hold pit drill. Rotate drill from 1037' to 1068'. Slide drill from 1068' to 1088'. Pump Motor #2 went down due to high temperature. Work pipe and circulate on Pump #1. Start Pump #2, and run and inspect same. Drill from 1088' to 1200', sliding for 3.25 hours and rotating for 1.5 hours. Blow hydraulic drive hose off Pump #1. Circulate and parts to repair Pump #1. Change liners in pumps to 5 ~". Work on mud system. Install new hose and test run Pump #1. 510112000: MWD failed to generate a pulse. Surge, rotate, and jar on MWD tool. Sweep with 10 barrels of water but still no pulse. Back ream 5 stands. Lay down and replace two bad joints of 4" HT-38 drill pipe while POOH for MWD inspection. Circulate bottoms up and pump dry job. Continue POOH. Break down and lay down MWD tool. Retrieve damaged Pulsar. Pulsar in 3 pieces. Break bit and motor. Inspect for damage and fragmented pulsar parts. Orient motor and make up BHA. RIH and test MWD tool. Continue RIH to bottom. Inteq working on computer software problem to achieve an MWD tool face. Drill ahead and slide as needed from 1200' to 1370'. Slide time at 4.75 hours and rotating time at 1 hour. Circulate hole clean. Change out Top Drive saver sub. Service rig. Drill ahead from 1370'. 510212000: Continue drilling to 1468'. Slide time 3.75 hours and rotating time 0.75 hours. Ream and back ream to clean the hole. Drill from 1468' to 1503'. Pump high viscosity nut plug sweep to clean hole. Rotating time 0.5 hours. Drill ahead from 1503' to 1527'. Sliding time 0.75 hours. Circulate high viscosity sweep. Ream and clean tight hole from 1490' to 1527'. Drill ahead from 1527' to casing point at 1575'. Ream and clean tight hole. Back ream out of hole to 1200'. Inspect threads on 4" drill pipe. Find damaged threads in box and pin area of new pipe from U.S. factory. The center connections had no damage. RIH to bottom without encountering any fill. Circulate and condition mud. Pump sweep. POOH wet. Lay down instrument, motor, and bit. "Shirt tail" on bit is extremely worn, all the way down to the lubricator cap snap ring grooves. Lubricator cap snap rings and covers left in hole. Hold PJSM. Change bales and elevators. Rig up to run 13 3/8" casing. Run 13 3/8" O.D., 681b, L-80 BTC casing. $10312000: Continue running 13 3/8" casing to tight hole at 1550'. Break circulation. Run in and set casing in slip bowl on rig floor. Shoe depth at 1568'. Work pipe to 1568'. Rig down casing equipment. Rig up to run Stab-In assembly. RIH with Stab-In assembly. Pick up 5 joints of 4" drill pipe. Rig up cementing head and surface lines. Stab into float collar. Circulate and condition mud. Hold PJSM. Test lines at 3000psi. Cement with 600 sacks class G cement (with 34% D-124, + 0.65% D-65, +0.1% D-46, + 0.3% D-79) mixed at 12.0ppg with a yield of 2.38 cu/ft per sack. Cemented with full returns and circulated 100 sacks to surface. CIP at 19:00 hours. Bump dart and check fiow back. Unsting from Stab-In float collar. Floats holding. Remove plug dropping head. Pull 2 stands. Wash up surface equipment. Lay down plug dropping head. Adjust Top Drive torque tube. Lay down 5 joints of 4" drill pipe. Work hardened saver sub. Make up into stump 7 times. Make saver sub up on Top Drive. Check Top Drive for alignment. 5/0412000: Make up Top Drive to drill string and back out. (Saver sub had been damaged). POOH with 4" drill pipe. Rig up to remove slip bowl. Change elevators. Pick up casing and land. Nipple down diverter system. Pick up diverter. Make rough cut on casing. Lay down casing and continue to nipple down. Work on casing head. Cut off 20' flange and set out. Crib up cellar for welder platform. Make final cut on 20" casing. Center up 13 3~8" casing in 20" conductor and stabilize. Set in 13 3~8" head. Level and weld out. Let head cool. Test to 1500psi with nitrogen. Tested OK. Install double studded adapter and spacer spool. 510512000: Nipple up BOPs and related equipment. Pick up tools and pick up around rig and location. Function test BOPs. Rig up to test BOPE. Set test plug. Rig up test manifold to Top Drive. Test BOPs and related equipment at 250psi Iow and 3000psi high. Pull test plug and install wear ring. Change saver sub on Top Drive. Work with TESCO on pipe galling problem. RIH with damaged 4" drill pipe. $/0612000: POOH and lay down damaged 4" drill pipe. Lay down 17 ~" drilling tools. Unload drill pipe from truck and bring new BHA to rig floor. Pick up new BHA for 12 ¼" hole section. Make up BHA #3. Load MWD and orient. Repair broken elevator hose and guard. RIH with BHA #3, Place corrosion ring in top HWDP. Pick up drill pipe and stand back in mast for next hole section. RIH with stands from derrick to 1466', Pick up drill pipe and stand back in mast. Trip in hole and tag cement at 1518'. Circulate and condition mud. Pressure test casing to 1500psi. Drill cement and float collar at 1523'. Wash to 1538'. Tag cement. Drill cement and float shoe at 1568'. Wash from 1568' to bottom at 1575'. Drill new hole from 1575' to 1594'. Circulate bottoms up. Perform Leak Off Test with 9.2ppg mud weight. 510712000: Clean pill pit. Flush circulating line. Mix Safe-Clean spacer. Pump spacer and displace well with FLO-PRO mud. Drill and slide from 1594' to 1892'. Repair hydraulic hose on carrier. Check out Cotta Box. Drill and slide from 1892' to 2555'. Circulate bottoms up. Fill trip tank and check for flow. POOH to 13 3/8" casing shoe at 1568'. Monitor well. RIH to bottom. Tag up on 6' of fill. Wash to bottom. Drill and slide ahead from 2555' to 2946'. 510812000: Generator goes down during drilling. Attempt "quick fix" of generator without success. POOH 5 stands and work pipe while working on generator. Complete fix of generator and RIH. Wash and ream from 2878' to 2946'. Tag fill at 2935'. Drill and slide ahead from 2946' to 3735', Circulate bottoms up until clean. POOH to 2475'. Service rig and Top Drive. Monitor well. RIH. Tag and work through bridge at 3652'. Wash and ream from 3699' to 3735'. Ream through 12' fill. Drill and slide ahead from 3735' to 4028'. Shear nail on pop off valve. 510912000: Work on mud pump. Inspect filters on hydraulics. Drill and slide ahead from 4028' to 4293'. Penetration rate slowed from 60'/hr to 25'/hr. Motor stalling easily on bottom with only light bit weight. Heavy drag (60K-70K) picking up off bottom. Back ream out of hole through the Sterling (Sands) Formation to 4169' with 40K 60K drag. Repair hydraulic hose on rotary table drive motor. Continue back ream to 3771' with 40K drag decreasing to 10K to 15K. Circulate bottoms up. Resume trip. Tight hole at 3706' (60K-70K drag). Continue backreaming to 3326'. Drag decreases to 10K. Finish trip out of hole. Recorded only light (10K-8K) drag pulling to casing. Lay down mud motor. Motor and stabilizers are OK on visual inspection. Pick up new motor. Install MWD. Surface test MWD. 511012000: RIH with New Bit #3 to 1530'. Slip and cut drill line. Service rig. Continue RIH. Work through tight hole at 3737' with 40K-50K. Tag fill at 4253'. Wash to bottom. Rotate and slide from 4293' to 4859'. Average penetration rate is 65'-130'ft/hr, but occasional 20'-30' sections of slower 25-33ft/hr drilling with frequent motor stalls. Pumped 2 high viscosity sweeps with no marked increase in cuffings returns, but considerable improvement in torque and drag reaction. Circulate another high viscosity sweep. 5111121)00: Do 10 stand wiper trip to 4220'. Experience 50K-80K drag from 4764' to 4675' and 10K-25K drag from 4675' to 4220'. Have no problems tripping back to bottom. Rotate drill and slide drill from 4859' to 5442'. 162' total slide drilling at average 10-20'/hr, with reactive torque and erratic tool faces. Average 40'/hr rotary drilling with occasional high torque and frequent motor stalls at Iow bit weights. High viscosity sweeps very successful in improving hole conditions. Backreaming all connections. Consistent 10K-30K drag in hole. 511212000: Rotate and slide drill from 5442' to intermediate casing point at 5810'. Total 10' of slide drilling at 10'/hr. Circulate bottoms up. Level derrick. Do wiper trip from 5810' to 3310'. Backream from 5810' to 4350' with 30K-100K drag and frequent high torque. Pull without backreaming and only 10K.20K drag from 4350' to 3300'.Trip in hole with no problems. Tag on 40' of fill. 511312000: Wash to bottom. Circulate hole clean. Condition mud. POOH. Lay down directional tools. Install 9 5/8" casing rams in BOP's. Pull wear bushing. Install test plug. Cavity test BOP's at 250psi Iow, 3000psi high. Rig up to run casing. Run 9 5/8" casing. 5/1412000: Continue running 9 5/8" casing (114 joints total). Wash 50' to bottom at 5810'. Circulate with casing and prepare to cement. Hold PJSM. Cement 9 5/8" casing with lead slurry of 40bbls Mudpush XL Preflush, and tail slurry of 570 sacks Class G cement (+ 34% D-124 + 0.65% D-65 + 0.1% D-46) at 12.0ppg and a yield of 2.38 cubic ft/sack. Displace with 438 bbls of 9.2 mud. Observed full returns and did not bump plug. Final displacement pressure is 645psi. Shut down. Release pressure. Floats holding. Wait on cement. Nipple down BOP's. Set slips on casing with 200K hanging weight. Set out spacer spool and DSA. Nipple up 13 3/8" 3Mx11"5M tubing spool and test to 2100psi. Nipple down and set out single ram. Nipple up BOP's. 511512000: Continue to nipple up BOP's. Modify bell nipple and trip tank lines. (Note two ram configuration approved by AOGCC and BLM. Received issue of non- compliance from BLM for requirement of kill line check valve and/or 1" ball valve on annular hydraulic closing line). Finish nippling up BOP's. Test BOP's. (Annulars: 250psi Iow / 2500psi high. Pipe rams, Blind rams, Choke and Kill line valves, Choke manifold, upper and lower Kelly cock valves, all Floor valves: 250psi Iow / 5000psi high). Install wear bushing. Hook up flow line and trip tank. Align BOP stack and tighten turnbuckles. Dress floor. 511612000: Pick up steer able BHA and MWD. Surface test same. RIH with HWDP. Strap and pick up 70 joints 4" drill pipe. RIH to 3332'. Test casing to 1500psi. Service rig and Top Drive. Continue RIH. Tag float collar at 5732'. Apparently no cement on top of float collar. Appeared to be drilling light scab cement in shoe joints with 0-5K weight. Drill cement and float equipment. Drill 20' of new formation to 5830'. Circulate bottoms up. Rig up Dowell and perform Leak Off test. Pump into formation at 1145psi / 13.4EMW. Rotary drill and slide drill from 5830' to 6116'. Average ROP is 50-60ft/hr with light to moderate torque. Drag is 50K-60K while backreaming first time on connections, and 10K-15K on second pass. 511712000: Rotary drill and slide drill and survey from 6116' to 6956'. Average ROP sustained at 50-60 ft/hr. Note that there is no sliding after 6293'. $#182000: Continue to rotary drill and survey from 6956' to 7587'. Average P, OP sustained at 50-60 ft/hr. Frequent motor and drill string stalls. 20K-70K drag and 10M- 15M torque while backreaming over short (2'-8')intervals. One backream pass is usually all that is required to clean up after stalling. Connection times, with one or two backreaming and reaming passes included, are 20-40 minutes. At 7587', despite progressively lighter attempted bit weights, there is significantly increased torque and constant motor stalling. CBU. POOH. Pull from 7587' to 7265' with 30K to 90K drag. Backream from 7265' to 7040'. 511912000: Pull from 7040' to 6310' with 25K to 80K drag. Backream from 6310' to 5845' with moderate to heavy torque. During backreaming there is frequent stalling despite generally light drillstring weights. Finish POOH. Change out bit. Surface test MWD. RIH with Bit #6 to 5796'. Service rig and Top Drive. Slip and cut drill line. Continue RIH. Take 50K-70K drag while running in after 7295'. RIH to 7485'. Wash from 7485' to 7587' without fill. Drill from 7587' to 7694'. ,512012000: Continue drilling from 7694' to 7980'. Hole conditions unchanged. 25K- 70K drag while working pipe. Stalling motor off bottom. Stopped backreaming at 7705' with no problems. Drilled sand from 7940' to 7980' and had a gas peak of 1183 units. Background gas fell to 35 units. CBU. Continue circulating while waiting on orders to drill deeper. Drill from 7980' to 8110' (T.D.). CBU. Background gas is 35 units. POOH to 5800'. Alternately pull and backream from 8110' to 7450' with 40K-100K drag. Pull from 7450' to 5800' with 15K-40K drag. Replace grabber dies on Top Drive. Service rig. 512112000: RIH to 8110' with 15K-40K drag. No fill. Gas was bubbling in the header boxes while running in, and gas units increased from 35 to 100. Circulate at 8110'. Had 2500 units of gas at 2000 strokes, 3500 units at 3300 strokes. Mud overflowing BOP stack. Close annular preventer and circulate through choke manifold for 1% hours at a reduced pump rate. Maximum gas is 3545 units. Circulate and build mud weight to 10.6ppg. Open annular and increase pump rate. Circulate around and kill high gas. Gas reduced to 65 units. Shut down pumps for 30 minutes and observe well. CBU. Gas decreased from 65 units to 25 units. Drop gyroscopic survey and pump to bottom. POOH. Pull from 8110' to 5810' with 25K-60K overpull. Finish POOH. Lay down mud motor and MWD. Retrieve Gyro. Rig up Schlumberger for wireline logs, Begin logging. First run is CMR-CNL-PEX-AIT. Log from wireline TD of 8106'. 512212000: Finish first logging run. Do second logging run with DSI-GPIT-NGT. Finish second logging run. Start first of 3 passes with RFT tool. Finish third logging run. 512312000: Do fourth and fifth logging runs with RFT tool. Sample at numerous points. Finish wireline logging and rig down Schlumberger. Pick up and make up BHA. RIH with 4" drill pipe to 9 5/8" shoe at 5810'. Circulate at shoe. Continue RIH to 8105'. Tag fill. Wash down to 8110'. Circulate rotate and reciprocate pipe. Had 440 units of Trip Gas. Condition Mud. Spot seven-barrel 16.0ppg pill on bottom, POOH to 5750'. Service rig. POOH laying down 4" drill pipe. 512412000: Continue POOH laying down 4" drill pipe. RIH with 41 stands 4" drill pipe from derrick to lay down. POOH laying down drill pipe. Lay down HWDP and BHA. Clear floor of handling tools. Pull wear ring. Install and energize test plug. Change pipe rams to dual 3 %" rams. Install second valve on tubing head. Rig up to test annulus valve on tubing head and flange. Test dual rams. Pull VR plug. Pull test plug. Hold PJSM for dual string rig up. Rig up to run dual strings. Change to long links. Rig up spider and elevators for 3 ½" and 2 7/8" strings. Build safety joints for well control. 512512000: Hold PJSM for making up float equipment. Make up dual string float equipment. Check floats. RIH with dual strings. 512612000: Continue RIH with dual strings to shoe. Switch over from backside well control to dual string circulating head. Fill pipe and circulate bottoms up at shoe. Switch over from circulating head to backside well control. Continue RIH with dual strings. A d ~_ ~ ~ ~ d ~, z < ~. z ,, z T ~] ~ ~ 8 ~ ~ ~ ~ = ~ = z o E ~71 24.0 24.0 ~8 ~ 2.5 1,0 1,0 0.5 19,0 24.0 ~ ~.0 1.0 3.0 24.0 ~0 8,5 14.5 1,.0 24.0 '05~1 9.5 5.0 ZO 1.0 1.0 5.5 24.0 05102 8.5 3.5 2.5 1.5 8.0 24.0 05/03 4,5 Z5 9.0 5.5 2.5 24.0 , , 051~ 2,5 13.5 8.0 24.0 05105 1.5 I, 3.5 6.0 13.0 24.0 05/~ 0.5 9,5 1.5 3,0 2.0 6.5 1.0 24.0 , 05/07 17.0 3.5 2.5 1.0 24.0 , 05/08 16.5 0,5 1.5 3,5 0.5 1.5 24.0 05109 10.5 2.5 2.5 1.5 1.5 0.5 5.0' 24,0 05/10 14.0 5.5 0.5 1.0 0.5 0.5 2.0 24.0 , 05/il ~.0 1.0 24.0 , 05/12 15.5 ZO 5.5 1.0 24.0 , ~ ....... 05/13 7.0 0.5 2.0 6,0 6.0 2.5 24.0 , , , , , 05/14 2,0 5.5 3.0 0.5 7.5 5.5 24.0 , , ........ 05115 12.0 9.0 3.0 24.0 0~16 8.o 8,0 1.0 0,5 4.5 i,0 1.0 24.0 05/17 ~.0 1.0 24.0 ,, ,, , , ,i,, , , I, ,,~, 0~18 ~.5 2.0 1,5 24.0 ..... 05/19 3.0 13.0 3.5 0,5 1.0 3.0 24.0 .......... 05~0 15.5 3.0 4,5 1.0 I 24.0 . .......... 05~1 11.0 6.0 1.0 5.5 , ,,, , 0'5 24.0 os= =4.o ~.01 ,,, , ~, , , , , , os~a o~s a.o o.s ~zo ~.o ~4.o' ,, , ,,, , , ,,,, . Ofi~ ~ ~.5 4.5 24.0 ...................... os~ a.s o.o a.o a.s 4.o ~4.o ,I , , , 0.0 O.0 , , ,,, , , ~ , , O.0 o.o ..... 0.0 0.0 , , , ,, ,, 0.0 ,,, 0.0 0.0 , , 0.0 .... 0.0 , . ,,, TOTAL 217.5 9~5 19.0 4~ 7~ 7.0 ~5 Z0 2~ 41.5 3.5 69,5 12.5 0.0 76.5 27.0 17.5 31.0 1.0 z0 0.0 0.0 0.0 ~.0 7~.0 I . ......... ~ ~.1g%: 13.,~% 2.~% 5.~% 1.~% 0.g7% 3.12% 0.28% 0.35% 5.76% 0.~% g.~% 1.74~ 0.~% 10.62% 3.75% ~%~ 4.~% 0.14~ 0,28% ;0.~% i I I I II IIII I I I I RiG ACTiViTY SUfFfNARY RIG UP/DWN EQUIP, DRILL CEMENT CMTt RUN CASING TEST LINES/BOPE BHA I NIPPLE UP/DOWN , TEST CASING LEAK OFF TEST ! , FISHING ¢,, DtR. WORK - MISCELLANEOUS DRILL WIRELINE LOG SURVEY SLIP DRILL LiNE ,' RiG REPAIRS RIG SERVICE SHORT TRIP CCRCULAT~NG REAM TR~P I BDRtLL ~TRIP D REAM D CIRCUI,Ji, TING~SHORT '¥'RtP DRtG SERVICE ~RtG REPAIRS DSLIP DRILL LINE ~SURVEY ~WIRELINE LOG DTOP DRIVE ~RUN CASING ~CMTING ACTIVITY ~DRILL CEMENT ~RtG UP/DWN EQUIP,l~B N A ~]'EST L!NES/BOPEDNIPPLE UP/DOWN ~TEST CASING ~LEAK OFF TEST ~FtSHING ~DiR. WORK MCLEAN PITS ~MtSCELLANEOUS MUD REPORT RECC '. MARATHON OIL COMPANY KBU 33-6 ,, , KENAI GAS FIELD ., GLACIER DRILLING RIG #1 APINumber: 60.t~3-20467 Depths: 46' to 8110' DATE DEPTH MW VIS PV YP GELS FL FC SOL 0IL SD MBT pH AIk Cl- Ca+ MD/T~ 4/28/00 217/217 8.90_J 158 t 9 62 4,5/50/5013.6 3 t 4.0 0 2.00 17.5 ' 9.0 0.20 900 t 40 4/29/00 1~ ..... -~_~-_0-- ~2'-~' .-_' 16 44'-- -30/70/54 122 3 6.0 0 3.00 17:5 9.0 0.10 500 40 4/30/00 1200/1146 9.00 L_ 95 15 40 27/56/42 10.4 3 ' 5.0 0 2.00 15.0 8.5 0.10 400 40 5/1/00 .... 1448/1384 ~]~ ~_~0~"__-- ..... 1.9___ 46 29/46,'52---9.-~--- .~---_ 7.0 -'---~"' ...... 2--.-(~ ..... ,~7.--~--,---~.-~-- mR 400 40 ~ 1575/1548 9.20 85 19 37 26/44/46 9.8 3 6.0 0 2.00 20.0 8.5 TR 400 60 5/3/00 1575/1548 9.25 44 20 14 6/12/26 9.2 3 7.0 0 2.00 17.5 8.5 TR 400 40 5/4/00 ._,_1575/1548 9.30 42 '- 1~"- .... ~---'---3~1'-5 .... 22.----'d-- 3 7.0 0 2.25 17.5-- 8.5 TR '~ ..... -~-'- 5/5/00 1575/1548 9~ ..... -~1-~ .... 15 .... '7-- ....... .' 4/7/1.6__ __ 22.0 3 --~'-.~ .......... 3 ..... 2.00 __ ~5/~o/~)~____1_660/162_~7 8.80 52 ...... ~--'-' 23 15/1~1~-~ -~'~)-:~--- .... ~ ........... ~:~ ........ 3 ..... T5~ .......... 5/8/00 4028/3700 8.90 --"4T-" 7 23 12/17118" T{:.~ ....... --~' ....... -~;.-~ ...... --~ ........ ~'T~:) .... -'¥~.~' :~J_-'._/~.'_ ...... 4~2~3~/3.__9.3_9_ ....... ,.9._0(~___ :..'-~[~".'_-.: ...... .8._ ......... _2__1_._ 10/15/17 11.8 2 4.0 0 0.50 10.0 8,5 0.95 18000 920 _,.5/1~0/~0- .... ,4858/4440 9.10 53 11 33 '~'a~-~/2'"~' ..... "~.'5- ......... ~- "---~.-~ ........ '~ ......... 0.'"-~ ....... ~"'.~ ....... -~,'.~' ...... O'".'~-a- ....... :1~ ...... '92-"~~'' _~_~__. ,____~2/462----~ ........ 9.-~'~ ...... __:-_~-~-__: .... 1-~- ......... 3~ .... ~'~26/2-'--s ..... 8.--3- ....... -~ ........ -776 .......... b- ........ '~.~'b ........ -~.~' .......... §.-E ............ 6.~b ........ ~-0(~ ...... 'l~b .... 5/12/00 5810/5329 9.30 53 15 25 -~/33/42 -'~:~ ............ ~'~ ........ '7.-~ ............ ~ ...... '~i ....... -{~.~- ...... '~:~' .......... ~-.2'6 ........ T~'i:~i~ .... ~'~:~ .... ~.i~:: Z:~-.~_~:Z ::.'.~-_.~_-Z :':..-_"~_': :::fi_q:'. ::Z.:~E:'~ 5.:~_:~_~_~.': ::-E~-'. '"::-:~: ...... -sT0 ........... ~- ............ ,~ ........... ~'~:r ....... ~:~-'-~ "'-~:~--'-~ ..... ~ .... 5/16/00 6111~4 9.10 44 12 18 7/2~ 7~' '~':~ ........ -~ ......... ~ :'1~ ........ ~)~ ........ ~1~- ........ ~'~;:~ ...... -~.-,~ ........... ~:~-~ ....... -~'(~' - ~'~ 5/17/00 ..... .7_~ ....... ~ ....... ~ ......... .1..3, ....... _3_2 .... ::~'.,~._~,.,: .__7=4, ...... ::'"~-Z.,:-: ..... 'l~:'b- ..... _ ,0 ........... ~J~- ........ - ~'J~" 7731/7191 9.70 51 13 26 15/34/45 7.6 '--'~ ........... ~l:~- .......... b ...... ~.~'5~ ...... BIT RECORD KBU 33-6 MARATHON KENAI GAS FIELD TYPE SER NO. i JETS i DEPTH DEPTH FTG i HRS ROP I # " ; ] ~ ~ IN OUT ~ Avg t · t 1 17 5. t . ~ 40 1575 2 12.25iSTC MOS$ODCL ,1 LK6167 ; 16-18-20-12i 1575 4293 2718 i 27.45 116.5 3 12.25iSTC FOSC I LR9549 ! 16-18-20-12! 4293 5810 1517 i 35..75~ 42.5 4 8.5 iSTC M15TPS ! LW1330 [ 18-18-16 I 5810 7588 1778 { 35.02 75.2 - '5 ! 85 iSTC M15TPS ! LW1306 i 18-18-18 I 7588 I 8110 522 i 15 52 57.6 WOB Hi-Lo-Avg 35 - 3 - 13.7 55 - 3 - 35.0 75 - 11 - 34.2 42 - 14 - 35.9 RPM i PP GRADE I Hi-Lo-Avg i Hi-Lo-Avg I - O - D - L - B - {3 - OT - R N/^ I1605-485-1390 2-2-E/R-A-E-OM-N-PR N/A !2325-1315-1665 5-6-BT-A-E-118-NO-TD N/A i2400-1384-2070 3-6-BT-M-F-1/16-CC-TQ N/A i2347-1447-2177 2-2-N0-A-E-1-NO-TD MARATHON OIL COMPANY KBU 33-6 KENAt GAS FIELD -- ~'--J-J'- -['- Survey Measured Incl Hole Course TVD Verldcal Displ I Displ DLS Build # depth angle Direction length depth sect~n +FUS-I +E/W- (degJ Rate (ltl (cleul (deal (ffl (ftt Iftl (ftt (ft~ lOOfl i I 155.00 0.50 225.70 155.00 155.03 -0.29 -0.47 I -0.48 0.32 0.32 2 348.00 0.78 223.40 193.00 347.99 -1.28 -2.01 -1.99 0.15 0.15 3 527.00 1.18 236.90 179.00 526.96 -2.31 -3.91 -4.37 0.26 0.22 4 585.03 1.85 283.30 58.00 584.94 -1.98 -4.02 -5.78 2.32 1.16 -- 5 615.00 2.20 288.50 20.00 614.92 -1.38 -3.74 -6.81 1.23 1.17 6 646.00 2.50 293.30 31.00 645.90 -0.58 -3.31 -8.00 1.32 0.97 7 706.00 3.10 305.80 60.00 705.82 1.61 -1.84 -10.51 .1..42 1.03 8 765.00 4.10 320.30 59.00 764.71 4.87 0.72 -13.16 2.28 1.96 9 795.00 4.70 332.30 30.00 794.62 7.04 2.51 -14.59 2.05 2.00 10 825.00 5.02 327.80 20.00 824.51 9.47 4.60 -16.04 1.88 1.07 11 859.00 5.70 333.00 34.00 858.38 12.59 7.38 -17.60 2.46 2.03 12 890.00 7.16 337.17 31.00 889.17 16.04 10.51 -19.05 4.94 4.71 13 919.00 8.00 341.30 29.00 917.91 19.86 14.09 -20.40 3.46 2.90 14 950..0B 8.54 344.00 31.00 948.59 34.31 18.35 -21.73 2.15 1.74 15 983.00 9.90 345.90 33.00 981.17 29.59 23.45 -23.09 4.22 4.12 16 1014.00 11.10 346.60 31.00 1011.65 35.22 28.94 -24.43 3.89 3.87 17 1073.00 12.50 347.55 59.00 1069.40 47.22 40.70 -27.13 2.40 2.37 18 1134.00 13.51 349.20 61.00 1128.83 50.85 54.15 -29.89 1.76 1.66 19 1198.00 14.35 348.80 62.00 1189.01 75.64 86.80 -32.74 1.36 1.35 20 1259.00 15.78 347.50 50.00 1246.94 91.13 64.06 -35.95 2.45 2.38 21 1316.00 17.00 348.20 60.00 1304.51 107.95 100.61 -39.51 2.06 2103 22 1371.00 18.90 347.70 55.00 1356.83 124.79 117.18 ..43.05 3.47 3.45 ' 23 1449.00 19.60 348.80 78.00 1430.48 '150.32 142.36 .48.28 1.01 0.90 24 1514.00 20.62 347.80 65.00 1491.50 172.51 164.24 -52.82 1.86 1.57 25 1606.00 21.00 345.40 92.00 1577.50 205.50 198.03 ..60.40 1.01 0.41 26 1686.00 22.60 343.50 80.00 1651.78 234.72 224.64 -86.38 2.19 2.00 27 1787.00 24.00 545.00 101.00 1744.54 274.61 263.09 -79.20 1.51 t .39 28 1 '~62.00 25.80 342.50 75.00 1812.57 306.16 293.39 -88.08 2.78 2.40 29 1926.00 26.30 342.00 64.00 1870.07 334.26 320.16 -96.63 0.65 0.78 30 .1992.00 27.80 341.10 66.00 1928.84 364.27 348.63 -106.13 2.38 2.27 31 2054.00 28.70 343.40 62.00 1983.46 396.61 376.58 -115.07 2.28 1.45 32 2118.00 30.18 342.80 64.00 2039.20 425.05 406.67 -124.22 2.36 2.31 33 2248.00 29.47 343.70 130.00 215~.98 489.67 468.58 -142.86 0.65 -0.55 34 2311.03 29.14 342.50 63.00 2206.91 520.50 498.08 -151.82 1.07 -0.52 35 2439.00 29.58 343.50 128.00 2318.47 583.23 558.10 -170.16. 0.51 0.34 36 2503.00 29.66 373.40 64.00 2374.11 614.64 588.42 -179.17 0.15 0.13 .... 37 2598.,00 29.40 342.70 96.00 2457.64 . 662.13 633.86 -192.97 0.45 -0.27 39 2696.00 30.07 342.70 97.00 .2541.87 710.23 679.61 -207.27 0.69 0.69 39 2760.00 30.28 344.30 64.00 2597.20 742.38 710.46 -214.41 1.30 0.33 -- 40 2856.00 29.68 343.30 96,00 2860.35 790.31 756.52 -229.79 0.81 -0.63. 41 2925.00 29.40 342.80 69.00 2740.38 824.31 789.06 .239.70 0.54 -0.41 42 3017.00 29.80 342.10 92.00 2820.38 869.74 832.39 -253.41 0.57 0.43 43 3146.00 29.38 342.40 129.00 2932.55 933.45 893.07 . -272~83' , 0.34 ..0.32' 44 ~ 3302.08 30.30 341.90 156.00 3067.86 1011.07 966.96 -296.63 0.60 0.58 45 3393.00. 29.89 .340.70 91.00 314,6.59 1056.70 1010.18 ..311..26 0.80 -0.45 46 3457.00 29.45 340.00 .64.00 3202.20 1088.38 1040.02 -321.91 0.86 -0.69 47 3522.00 29.55 341.00 65.00 358.77. 1120.38 1070.19 -332.60 0.77 0.15 48 3649.00 29.80 342.00 127.08 3369.12 1183.25 1129.81 -352.54 0.44 0.20 49 3715.00 29.33 342.40 66.03 3426.52 i215.81 1160.82 -362.50 0.77 -0.71 50 3844.00 30.51 342.90 129.00 3538.33 1280.14 1222.23 _ -38!..68 . 0.93 0.91 ._ 51 4038.00 29.83 341.30 192.00 3704.32 1376.62 1314.05 -411.32 _ 0..55 ~0.35 52 4100~00 29.75 341.70 64.00 3759.86 1408.41 1344.20 -421.41 0.33 -0.13 .. .53 4239.00 29.10 341.90 .!39.00 3880.93 1476.70 1409.08 -442.74 0.47 -0.47 54 4357.00 28.73 341.50 118.00 3984.22 1533.75 1463.24 -460.66 0.35 -0.31 55 4422.00 28.28 340.90 65.00 4041.34 1564.77 1492.61 -470.65 0.82 - '-0.69 56 4550.00 27.35 341.50 128.00 4154.55 1624.50 1549.15 -489.90 0.76 -0.73 57 4678.00 26.45 .340.90 .128.00 4268.70 1682.41 1603.97 -508.56 0.73 -0.70 ... 58 4741.00 - - 25.18 342.20 63.00 4325.41 1709.64 1629.99 .517.25--' 2.21 -2.02 59 4834.00 23.90. 343.30 93.00 4410.01 1748.45 1666.87 -528.71 1.46 -1.38 60 4927.00 22.63 341.60 93.00 4495.45 1765.18 1701.90 -539.77 1.54 -1.37 61 5021.00 21.54 336.97 94.00 4582.56 1820.47 1734.94 -5.52.24. 2.18 -1.16 62 5112.00 20.22 332.40 91.00 4667.58 1 652.66 1764.26 -566.08 2.30 -1.45 63 5235.00 . 19.46 327.20 123.00 4783.29 1893.52 1800.32 -587.01 1.56 -0.62 64 5358.00 18.95 327.70 123.00 4899.46 1932.19 1833.22 -610.49 1.53 -0.41 65 54.53.00' 18.50 320.20 95.00 4989.43 1960.76 i858.90 -629.69 "0169 -0.47 66 5542.00 18.37 317.40 89.00 5073.86 1986.73 1878.07 -648.23 1.01 -0.15 , 67 5665.00 17.62 314.80 123.00 5190.85 2120.08 1905.46 -674.55 0.89 -0.61 68 5756.00 17.31 . 315.80 91.00 5277.65 2045.61 1924.87 -693.77 0.47 -0.34 69 5867.00 16.92 314.50 111.00 5383.74 2074.90 1948.03 -716.80 0.49 -0.35 70 5996.00 16.55 310.50 129.00 5507.28 207.40 1973.12 -744.16 0.94 -0.29 71 6124.00 16.25 309.40 128.00 5930.07 2138.23 1996.33 -771.86 0.34 -0.23 72 6253.00 15.79 308.60 129.00 5754.06' 2168.29 . 20!8.73 -799.53 0.40 -0.36 73 6380.00 15.44 308.20 127.00 5876.37 2196.98 3039.97 -826.32 0.29 -0.28 74 6510.00 14.90 307.90 130.00 6001.64 2225.37 2060.94 -853.10 0.42 -0.42 75 ' '6638.00 ' 1'4.49' ' 307.40 128.00 6125.65 2252.37 2080.77 -878.81 0.34 -0.32 76 6764.00 14.16 305.90 126.00 6247.74 2277.98 2099.38 -903.82 0.39 -0.26 77 6891.00 13.86 304.30 127.00 6370.98 2302.75 2117.08 -928.97 0.39 -0.24 78 7019.00 13.47 303.90 128.00 .6495.34 2326.81 2134.02 -954.01 0.31 .-0.30 79 7142.00 13.10 302.50 123.00 6615.04 2349.02 2149.50 -977.65 0.40 -0.30 80 7265.00 12.62 301.30 123.00 6734.96 2370.14 2163.97 -1000.89 0.45 -0~39 81 7385.00 12.07 300.30 120.00 6852.18 2389.62 2177.11 -1022.92 0.49 -0.83 82 7527.00 11.70 300.90 142.00 6991.14 2411.75 2191.99 -1048.10 0.27 0.42 83 7633.Q0 11.19 300.60 108.00 7095.03 2427.71 2202.75 -1066.17 0.48 -0.28 84 7817.00 10.44 301.50 184.00 7275.76 2454.01 2220.55 -1095.75 0.42 -0.41 85 7921.00 9.70 302.20 104.00 7378.16 2468.03 2230.14 -1111.20 I 0.72 -0.71 86 8051.00 9.65 303.40 130.00 7506.31 2485.10 2241 ~97 -1129.57 0.16 -0.04 87 8110.00 9.50 303.90 59.00 7564.49 2492.8~. 2247.41 , -11~7,74 Daily Report Page I of I MARATHON KBU 33~ DALLY WELLSITE REPORT EPOCH REPORT FOR DATE May 21, 2000 TIME 24:00 / 00:00 DEPTH 8110 YESTERDAY 8110 PRESENT OPERATION= WlRELINE LOGGING 24 Hour Footage 0 CASING INFORMATION 9 5~8" @ 5810' DEPTH. INCLINATION SURVEY DATA AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 5 8.5" STC M15TPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.65 VIS FC 2 SOL MWD SUMMARY INTERVAL SIN JETS IN OUT FOOTAGE HOURS LW1306 18,18,18 7587 8110 523 15.52 HIGH LOW AVERAGE DEPTH: 8110 / 7565TVD 61 PV 16 YP 25 FL 7.2 Gels 14 SD 0.25 OIL 0 MBL 20.0 pH CONDITION T/B/C 2-2-WT-A-E-I-NO-TD CURRENT AVG REASON PULLED TD ft/hr amps Klbs RPM psi 15/3746 CL- 31000 8.5 Ca+ 720 CCI INTERVAL TO TOOL8 GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C~4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL i i IIIL I I I I LITHOLOGY N/A PRESENT LITHOLOGY N/A DAILY ACTIVITY SUMMARY 11 i i. iii i i iiiii i HIGH LOW 3545 @ 8110 25 @ 8110 CHROMATOGRAPHY(ppm) N/A LITHOLOGY/REMARKS , Ill Il 1· AVERAGE 1100 TRIP GAS= WIPER GAS= 3545 SURVEY= CONNECTION GAS HIGH" AVG= CURRENT CURRENT BACKGROUND/AVG 25 GAS DESCRIPTION i i iii i i iii i llt iiii i i i RIH; HIGH WIPER GAS, 3545 UNITS, CIRCULATE GAS THROUGH DEGASSER; RAISE MUD WT TO 10.7ppg; CIRCULATE GAS DOWN TO 50 UNITS; SHUT DOWN PUMPS AND MONITOR FOR 30 MINUTES; BREAK CIRCULATION AND CIRCULATE AROUND; CIRCULATE BACKGROUND DOWN TO 25 UNITS; OBSERVE WELL; DROP GYRO SURVEY; POOH; PUMP DRY JOB AT SHOE; CONTINUE POOH; HANDLE BHA; RIG UP SCHLUMBERGER; RUN WIRELINE LOGS. Epoch Personel On Board= 2 Daily Cost 2570 Report by: CRAIG SILVA fi l e://C:hnarathonL20000522, htm 5/22/00 Daily Report Page 1 of 2 MARATHON OIL COMPANY KBU 33.6 DAILY WELLSITE REPORT EPOCH REPORT FOR OTIS WATKINS DATE May 20, 2000 TIME 24:00 / 00:00 DEPTH 8110 (T.D.) YESTERDAY 7694 PRESENT OPERATION= WIPER TRIP CASING INFORMATION 9 5/8" @ 5810' ~ SURVEY DATA BIT INFORMATION NO. SIZE TYPE 5 8.5" STC M15TPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.7 VIS 55 FC 2 SOL 9.0 MWD SUMMARY 24 Hour Footage 416 DEPTH 7817 7921 8051 8110 (Projected) S/N LW 13O6 JETS 18,18,18 INCLINATION AZIMUTH 10.44 301.50 9.70 302.20 9.70 303.40 9.70 303.40 ! INTERVAL IN OUT FOOTAGE 7587 8110 523 HIGH LOW 363.5 @ 7945 3.3 @ 7939 N/A @ N/A @ 41 @ 7712 14 @ 7966 N/A @ N/A 2347 @ 7954 1918 @ 7879 DEPTH: 8110 / 7565 TVDD PV 14 YP 30 FL SD 0.25 OIL 0 MBL VERTICAL DEPTH 7275.76 7378.16 7506.30 7564.46 CONDITION HOURS T/B/C 15.52 AVERAGE cuRFt~EN~ AV{3' - , 60.9 65.9 N/A ,.. 33.3 36.0 N/A 2186.8 2282 ii REASON PULLED fi/hr amps Klbs RPM psi 7.2 Gels 18/43/54 CL- 30500 17.5 pH 9.0 Ca+ 800 i iii ii i i i i i i ii iiii i=1 i ii CCI INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY _ DAILY ACTIVITY SUMMARY HIGH LOW AVERAGE 1183 @ 7966 20 @ 7931 171.5 CHROMATOGRAPHY(ppm) 233464 @ 7966 3968 @ 7931 33529.9 204 @ 7966 3 @ 8028 24.7 121 @ 7966 I @ 8053 11,9 32 @ 7966 @ 2.4 NONE TRIP GAS= 825 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUNDIAVG 35 LITHOLOGY/REMARKS GAS DESCRIPTION Major Sand/Sandstone, Coal, Tuffaceous Claystone, Tuff. Minor Tuffaceous Siltstone, Arenaceous Siltstone, Argillaceous Claystone, Carbonaceous Shale SAND, TUFFACEOUS CLAYSTONE, COAL i ii ii ii ii i i i i DRILL FROM 7694' TO 7980'; CBU; RECEIVE 1183 UNITS GAS FROM SAND; DRILL AHEAD TO 8110'; CBU; POOH TO SHOE; WORK ON RIG, MONITOR WELL; RIH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA Daily Report Page I of I MJARATHON OIL COMPANY KBU 33-6 REPORT FOR OTIS WATKINS DATE May 19, 2000 TIME 24:00 / 00:00 SIN LW 1330 LW1306 CASING INFORMATION 9 5/8" @5810' DEPTH SURVEY DATA 7633 BIT INFORMATION NO. SIZE TYPE 4 8~5" STC M15TPS 5 8.5" STC M15TPS DRILLING PARAMETERS RATE OF PENETRATION 191.0 SURFACE TORQUE WEIGHT ON BIT 42 ROTARY RPM PUMP PRESSURE 2250 DRILLING MUD REPORT MW 9.7 VIS 51 PV FC 2 SOL 9.0 SD MWD SUMMARY INTERVAL TO TOOLS DAILY WELLSITE REPORT DEPTH 7694 YESTERDAY 7587 24 Hour Footage 107 JETS 18,18,16 18,18,18 i ii i INCLINATION 11.19 INTERVAL IN OUT FOOTAGE 5810 7587 1777 7587 107 _ HIGH LOW @ 7620 14.1 @ 7618 @ N/A @ N/A @ 7638 16 @ 7619 @ N/A @ N/A @ 7681 1447 @ 7619 DEPTH: 7731 / 7191TVD 13 YP 26 FL 0.25 OIL 0 MBL , IIIU lis IIII · II IIII I I I I I I IL IIIII IIIII (~A~ ~UM'MARY(units) HIGH LOW AVERAGE DITCH GAS 158 @ 7589 19 @ 7587 90.5 CUTTING GAS @ CHROMATOGRAPHY(ppm) METHANE(C-I) 31669 @ 7589 3807 @ 7588 ETHANE(C-2) 23 @ 7589 5 @ 7588 PROPANE(C-3) 11 @ 7599 2 @ 7609 BUTANE(C-4) 5 @ 7620 1 @ 7666 PENTANE(C-5~ i i iiii ii i.ll~ i i iii i _ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS i AZIMUTH 300.60 HOURS 35.02 2.88 AVERAGE 44.9 18088.3 11.5 5.9 1.1 35.6 2139.7 EPOCH ii i i i i iiii ii ill ii iii ii iii LI.THOLOGY Major Sand, Coat, Tuffaceous Claystene, Minor Tuffaceous Siltstone, Tuff PRESENT LITHOLOGY SAND, COAL, TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY PRESENT OPERATION= DRILLING i VERTICAL DEPTH 7095.03 CONDITION REASON T/BIC PULLED 3-6-BT-M-F-1/16-CC-TQ TORQ i ii CURRENT AVG · ~.".~4.1 fi/hr N/A amps 27.3 Klbs '"'N/A RPM 2209 psi 7.6 Gels 15/34145 CL- 30500 17.5 pH 9.1 Ca+ 720 CCI TRIP GAS= 825 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 18 GAS DESCRIPTION iii i i i iii ii i i i ii POOH; CHANGE BIT - RIH TO SHOE; SLIP AND CUT DRILL LINE; RIH TO BOTTOM; DRILL FROM 7787' TO REPORT DEPTH. Epoch Personel On Board= 4 Daily COSt 2570 Report by: CRAIG SILVA Daily Report Page I of 2 MARATHON OIL COMPANY KBU 33-6 REPORT FOR OTIS WATKINS _DA~_E M_ay !8, 20_00 TIME 24:00 / 00:00 CASING INFORMATION 9 5/8" @ 5810' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 8.5" STC M15TPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.6 VIS 48 FC 2 SOL 9.0 MWD SUMMARY INTERVAL TO TOOLS DALLY WELLSITE REPORT D. ~PTH 758_7 YESTERDAY 6956 24 Hour Footage 631 EPOCH DEPTH INCLINATION 7119 13.47 7142 13.10 72_65 !?,6_2. 7365 12.07 7527 11.70 INTERVAL SIN JETS IN OUT LW1330 18,18,16 5810 7587 HIGH LOW 345.0 @ 7275 10.7 @ 7576 @ N/A @ N/A 75 @ 7047 12 @ 7501 @ N/A @ N/A 2271 @ 7478 1689 @ 7271 DEPTH: 7587'/7050TVD PV 12 YP 24 FL 7.2 SD 0.25 OIL 0 MBL 20.0 PRES_~NT OPE_RATION= PUggING_ O_UT OF HO_ _L_~ AZIMUTH 303.90 3O2.50 301.30 300.30 300.90 FOOTAGE 1777 VERTICAL DEPTH 6495.34 6615.04 673.4..96. 6852.18 6991.14 CONDITION REASON HOURS T/B/G PULLED · ROP 35.02 ,,~., "~ , CURRENT AVG -20.2 fi/hr N/A amps 36.5 Klbs N/A RPM 2003 psi AVERAGE 57.8 38.3 2125.0 Gels 12/27/37 CL- 30000 pH 9.0 Ca+ 880 CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(O-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY HIGH LOW AVERAGE 389 @ 7364 10 @ 7451 77.0 CHROMATOGRAPHY(ppm) 77776 @ 7364 1997 @ 7451 15365.2 76 @ 7364 1 @ 7451 13.7 15 @ 7545 @ 1.0 o @ @ o @ NONE LITHOLOGY/REMARKS ..-- TrIP GAS= wIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG 12 GAS DESCRIPTION Major Tuffaceous Claystone, Sand, local Coal-Carbonaceous Shale. Minor Tuffaceous Siltstone, Tuff, Arenaceous Siltstone, Argillaceous Claystone, Tuffaceous Shale. SAND, COAL, TUFFACEOUS CLAYSTONE DALLY ACTIVITY SUMMARY DRILL FROM 6956' TO 7587'; SLOW PENETRATION RATE & HIGH TORQUE LAST 5'; CBU; POOH. Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA Daily Report Page 1 of 1 MARATHON OIL COMPANY KBU 33-6 DALLY WELLSITE REPORT EPOCH REPORT FOR OTIS WATKINS DATE M~ay !?, .2_0_00 TIME 24:00 / 00:00 DEPTH 6056 YESTERDAY 6116 PRESENT OPERATION= DRI.L__L!NG 24 Hour Footage 840 CASING INFORMATION 9 5/8" ~. 5810 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH ,SURVEY DATA 6764.00 14.16 305.90 6247.74 6891.00 13.91 304.30 6370.95 .................................. / .................................................. ~L. ..................................... J..__J£ ...... 2JL~ ._.L .............. L--L ............................................... BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS 4 8.5" STC M15TPS LW1330 18,18,16 DRILLING PARAMETERS HIGH RATE OF PENETRATION 452.0 @ 6670 SURFACE TORQUE @ N/A WEIGHT ON BIT 45 @ 6859 ROTARY RPM @ N/A PUMP PRESSURE 2400 @ 6846 DRILLIN(~ MUD REPORT DEPTH: 7030' MW 9.35 VIS 53 PV 13 YP FC 2 SOL 8.0 SD TR OIL MWD SUMMARY IN OUT 5810 LOW 13.7 14 1384 FOOTAGE HOURS ' T/BIC PULLED 1146 19.52 AVERAGE CURRENT AVG · 6300 80.4 ,-~¥:7 ..t., ft/hr N/A NIA amps 6698 30.7 34.7 Klbs N/A 'N/A RPM 6246 2072.1 2154 psi 32 FL 7.4 Gels 16/34/41 CL- 30000 0 MBL 17.5 pH 8.5 Ca+ 480 CCI INTERVAL TO TOOLS ~A~ ~UMMARY(unit~) DITCH GAS CUTTING GAS mi i i HIGH 333 @ @ METHANE(C-1 ) 79877 ETHANE(C-2) 121 PROPANE(C--3) 12 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL lilt i mii i i LITHOLOGY i i ) ii i i i i i Il i ill ii LOW AVERAGE 6528 6 @ 6691 54.7 TRIP GAS= @ WIPER CHROMATOGRAPHY(ppm) SURVEY= 6525 t415 @ 669-1 t1585, t CONNECTION GAS HIGH= 6262 1 @ 6942 7.7 AVG= 6815 1 @ 6876 0.2 CURRENT 0 @ 0.0 CURRENT BACKGROUNDIAVG 12 o @ o.o NONE LITHOLOGY/REMARKS GAS DESCRIPTION Major Sand - Sandstone, Tuffaceous Claystone; Minor Coal - Carbonaceous Shale, Tuffaceous Siltstone-Tuff, Argillaceous Claystone PRESENT LITHOLOGY SAND, TUFFACEOUS CLAYSTONE, COAL i ii iii n l iii ii ii i i i iiii] i i i m, DAILY ACTIVITY SUMMARY DRILL FROM 6116' TO REPORT DEPTH Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA i _ · Ul_ iii , , 11 , , Daily Report Page 1 of 1 MARTHON OIL COMPANY KBU 33-6 REPORT FOR OTIS WATKINS DATE May 16, 2000 TIME 24:00 / 00:00 i CASING INFORMATION 9 5/8" @ 5810' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 4 8.5" STC M15TPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.1 VIS 44 FC 2 SOL 6 . MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 142 CUTTING GAS ! DEPTH 6124.00' DALLY WELLSITE REPORT SIN LW 1330 PV SD 472.6 0 42 0 2179 METHANE(C-1 ) 28494 ETHANE(C-2) 14 PROPANE(C-3) 0 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL DEPTH 6116 YESTERDAY 5810 24 Hour Footage 306 INCLINATION 16.3 INTERVAL JETS IN OUT 18,18,16 5810 HIGH LOW @ 5839 1.5 @ @ N/A 0 @ @ 5811 11 @ @ N/A 0 @ @ 5810 1468 @ DEPTH: 6118 12 YP 18 FL TR OIL 0 MBL [:l EPOCH PRESENT OPERATION= DRILLING i AZIMUTH VERTICAL DEPTH 309.4 5630.07' ii i i ii iii iii iiiii iiiii i i i HIGH LOW AVERAGE @ 5867 1 @ 5810 26.5 CHROMATOGRAPHY(ppm) 5867 399 @ 5811 5296.7 6100 0 @ 0.7 o @ o.o o @ o.o o @ o.o NONE LITHOLOGY/REMARKS CONDITION REASON FOOTAGE HOURS T/B/C PULLED 306 5.23 N/A AVERAGE CURRENT AVG 5838 97.0 -~..63_.4 ft/hr N/A 0 ~-~C-,(~ "~" amps 5839 35.3 34.0 Klbs N/A 0.0 ,..'0 RPM 5838 1953.6 1977 psi 9,2 Gels 7/21/24 CL- 31000 12.5 pH 9.5 Ca+ 320 GAS CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUNDIAVG 11 DESCRIPTION _ LITHOLOGY Major Tuffaceous Claystone, Sand; Minor Argillaceous Clay, Tuffaceous $ilstone, Coal PRESENT LITHOLOGY SAND, TUFFACEOUS CLAYSTONE, TUFFACEOUS SILTSTONE, ARGILLACEOUS CLAY DAILY ACTIVITY SUMMARY RIH; TEST 9 5/8" CASING; DRILL OUT FLOAT COLLAR-CEMENT-SHOE-10'; P.I.T.; DRILL AHEAD Epoch Personel On Board= 4 Daily Cost 2570 Report by: CRAIG SILVA ~ I1 '7/AA Daily Report ,{' Page 1 of 1 MARATHON OIL COMPANY KBU 33~ REPORT FOR OTIS WATKINS DATE May 15, 2000 TIME 04:00:00 i i CASING INFORMATION 9 518" @ 5810' SURVEY DATA BIT INFORMATION NO. SIZE TYPE S/N JETS , , ~ DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS DEPTH METHANE(C-1 ) @ ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) @ PENTANE(C-5) @ i i iii ill ii IL I II HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY i ii i i i i i i ii i NO NEW HOLE DALLY WELLSITE REPORT EPOCH DEPTH 5810 YESTERDAY 5810 24 Hour Footage 0 i INCLINATION INTERVAL IN OUT ! HIGH LOW 55 PV SD FOOTAGE ! AZIMUTH PRESENT OPERATION= NIPPLE-UP i HOURS AVERAGE i VERTICAL DEPTH CONDITION T/B/C REASON PULLED DEPTH: 5810 YP OIL CURRENT AVG E/hr amps Klbs RPM FL Gels MBL pH psi HIGH LOW AVERAGE CHROMATOGRAPHY(ppm) NONE LITHOLOGY/REMARKS CL- Ca+ CCI TRIP GAS= 8 WIPER GAS= N/A SURVEY= NIA CONNECTION GAS HIGH= NIA AVG= N/A CURRENT N/A CURRENT BACKGROUND/AVG 2 DAILY ACTIVITY SUMMARY RUN CASING, CEMENT, NIPPLE-UP. GAS DESCRIPTION Epoch Personel On Board= 2 Dally Cost Report by: JOHN MORRIS ,=/1 z; t(~(t Daily Report Page 1 of 1 MARATHON OIL COMPANY KBU 33-6 REPORT FOR OTIS WATKINS DATE May 14, 2000 TIME 04:00:00 i i CASING INFORMATION 13 3/8" @ 1568' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3 12 1/4" STC FGSC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,5 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS DALLY WELLSITE REPORT DEPTH 5810 YESTERDAY 5810 24 Hour Footage 0 i DEPTH INCLINATION INTERVAL SIN JETS IN OUT. LR 9549 16,18,20,21 4293 5810 HIGH LOW EPOCH 69 PRESENT OPERATION= RUNNING CASING i i i i AZIMUTH VERTICAL DEPTH CONDITION FOOTAGE HOURS T/BIC 1517 35.75 5 6 BT A AVERAGE CURRENT ~/G ' i i iii i I ii DEPTH: 5810 PV YP SD OIL HIGH LOW AVERAGE CHROMATOGRAPHY(ppm) METHANE(C-1 ) @ @ ETHANE(C-2) @ PROPANE(C-3) @ @ BUTANE(C-4) @ PENTANE(C-5) @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS LITHOLOGY NO NEW HOLE PRESENT LITHOLOGY i i ii i ii i ii il i i i i DALLY ACTIVITY SUMMARY LAY DOWN BHA, PREPARE TO RUN 9 5/8" CASING, RUN CASING. FL Gels CL- MBL pH Ca+ ii REASON PULLED TD fi/hr amps Klbs RPM psi CCI TRIP GAS= N/A WIPER GAS= N/A SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= N/A CURRENT N/A CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION E3och Personel On Board= 2 Daily Cost Report by: JOHN MORRIS Daily Report ~( Page 1 of 1 MARTHON OIL COMPANY KBU 33-.6 DALLY WELL$1TE REPORT EPOCH REPORT FOR OTIS WATKINS DATE May 13, 2000 DEPTH 5810 TIME 04:00:00 YESTERDAY 5535 PRESENT OPERATION= TRIPPING 24 Hour Footage 275 i ii CASINg INFORMATION 13 3/8" @ 1568' DEPTH INCLINATION SURVEY DATA ii iii BIT INFORMATION NO. SIZE TYPE S/N JETS 3 12 1/4" STC FSD-C LR 9549 16,18,20,12 4293 5810 ii i ii AZIMUTH DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 FC MWD SUMMARY INTERVAL IN OUT FOOTAGE HOURS HIGH LOW 1517 AVERAGE 51.8 235.0 @ 5639 12.2 @ 5590 41 @ 5800 5 @ 5704 25.5 2221 @ 5800 1757 @ 5642 2059.3 DEPTH: 5810 VIS 53 PV YP FL SOL SD OIL MBL i i VERTICAL DEPTH iiii CONDITION REASON TIB/C PULLED CASINg i i ii CURRENT AVG 71.8 fi/hr · ,~,._, ,. amps 3"1'. 7 ~ ' Klbs RPM 2179 psi Gels CL- pH Ca+ CCI -- i i i i ii iiii iii i INTERVAL TO TOOLS gAS SUMMARY(units) HIgH LOW AVERAGE DITCH GAS 117 @ 5688 5 @ 5808 23.6 CUTTING GAS CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 5810 0 @ 5810 0.0 ETHANE(C-2) 0 @ 5810 0 @ 5810 0.0 PROPANE(C-3) 0 @ 5810 0 @ 5810 0.0 BUTANE(C-4) 0 @ 5810 0 @ 5810 0.0 PENTANE(C-5) 0 @ 5810 0 @ 5810 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOgY/REMARKS iii i i i i L I III I lUl I1,1 I LITHOLOgY 50% CLAYSTONE, 30% SAND, 20% COAL PRESENT LITHOLOGY i i ii1! [ i i - lf~ i JL _ [I IIII IIIII L II II IIIIL. _ _111 . J _ I II IIIII DALLY ACTIVITY SUMMARY DRILL TO 5810', CBU, BACK-REAM TO 4350', RIH, CIRCULATE HOLE CLEAN, POOH. TRIP GAS= N/A WIPER GAS= 20 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKgROUND/AVG 4 GAS DESCRIPTION Epoch Personel On Board= 2 Daily Cost Report by: JOHN MORRIS Daily Report ,.,,:, Page 1 of 1 MARATHON OIL COMPANY KBU 33-8 DALLY WELLSITE REPORT REPORT FOR OTIS WATKINS DATE May 12, 2000 TIME 04:00:00 DEPTH 5535 YESTERDAY 4920 24 Hour Footage 615 CASING INFORMATION 13 3/8" @ 1568' ii i i ii i L · I Ill · ! I II DEPTH SURVEY DATA BIT INFORMATION 'NO. SIZE TYPE S/N 3 12 1/4" STC FSD-C LR 9549 ii ii i il · l DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.1 VIS 53 FC SOL i ~IL I I I II II II , ill , 1. MWD SUMMARY INCLINATION JETS 16,18,20,12 HIGH 359.1 @ 5282 33 @ 4972 2153 @ 5295 INTERVAL IN OUT 4293 ! LOW PV SD AZIMUTH FOOTAGE [:l EPOCH PRESENT OPERATION= DRILLING HOURS ! i iii iii AVERAGE 10.0 @ 5446 56.3 2 @ 5192 16.3 1606 @ 4921 _ DEPTH: 5500 YP FL OIL MBL INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 155 @ 5356 3 @ 4949 29.8 CUTTING GAS CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 5505 0 @ 5505 0.0 ETHANE(C-2) 0 @ 5505 0 @ 5505 0.0 PROPANE(C-3) 0 @ 5505 0 @ 5505 0.0 BUTANE(C-4) 0 @ 5505 0 @ 5505 0.0 PENTANE(C-5) 0 @ 5505 0 @ 5505 0.0 ii iii i HYDROCARBON SHOWS ' NONE INTERVAL LITHOLOGY/REMARKS LITHOLOGY 50 % CLAYSTONE, 30% SAND, 20% COAL PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY 'DRILL AHEAD TO 'REPORT DEPTH. VERTICAL DEPTH i! CONDITION REASON T/B/C PULLED 1482.8 2046 i i i CURRENT AVG 35.9 ftJhr · ,,~, amps 27.1 Klbs RPM psi Gels CL- pH Ca+ COl TRIP GAS= N/A WIPER GAS= N/A SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 20 GAS DESCRIPTION Epoch Personel On Board= 2 Daily Cost Report by: JOHN MORRIS Daily Report Page 1 of 1 MARATHON OIL COMPANY KBU 33-6 DALLY WELLSITE REPORT REPORT FOR OTIS WATKINS DATE May 11, 2000 TIME 04:200:00 DEPTH 4920 YESTERDAY 4293 CASING INFORMATION 13 318" @1568' I SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN 3 12 1/4" STC FSD-C LR 9549 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.1 VIS FC SOL MWD SUMMARY DEPTH 24 Hour Footage 627 ! ! INCLINATION INTERVAL JETS IN OUT 16, 18,20,12 4293 HIGH LOW 302.8 @ 4772 8.3 @ 32 @ 4544 3 @ EPOCH PRESENT OPERATION= DRILLING AZIMUTH FOOTAGE HOURS , ii AVERAGE 4355 106.8 INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 62 @ @ 4730 30.2 i i II I VERTICAL DEPTH CONDITION REASON T/B/C PULLED CURRENT AVG 52.2 o 2~.S 2116 @ 4858 1288 @ 4358 2617.5 2040 DEPTH: 4895 51 PV YP FL Gels CL- SD OIL MBL pH Ca+ CCI i II i i i I 1,,, ,11 11, ,11 , 111 fi/hr amps Klbs RPM psi METHANE(C-I) 0 @ 0 @ 4892 0.0 ETHANE(C-2) 0 @ 0 @ 4892 0.0 PROPANE(C-3) 0 @ 0 @ 4892 0.0 BUTANE(C-4) 0 @ 0 @ 4892 0.0 PENTANE(C-5) 0 @ 0 @ 4892 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS LITHOLOGY [ Il IIi Ill II I I I Il j [ HIGH LOW AVERAGE 4468 0 @ 4625 23.0 TRIP GAS= 50 @ WIPER GAS= 23 CHROMATOGRAPHY(ppm) SURVEY= 0 4892 CONNECTION GAS HIGH= 0 4892 AYG= 0 4892 CURRENT 0 4892 CURRENT BACKGROUNDIAVG 10 4892 ii i i ii ii ii GAS DESCRIPTION PRESENT LITHOLOGY ' FORMATION LOGGING NOT BEING PERFORMED. I ii I I i I! i t I IIIII I DALLY ACTIVITY SUMMARY SERVICE RIG, RIH, DRILL TO 4859', WIPE HOLE 10 STANDS, DRILL TO REPORT DEPTH. Epoch Personel On Board= 2 Daily Cost Report by: JOHN MORRIS ~/1 1/1313 Daily Report Page 1 of 1 MARATHON OIL COMPANY KBU 33-6 REPORT FOR DATE May 10, 2000 TIME 04:00:00 62 i CP, OINO INFOR:M^TION 1~ ;3fO" I~ 15OO° DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE 2 12 114" STC MO550DCL 3 12 1/4" STC FSD -C DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.9 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS Il I Ill I llll GAS SUMMARY(units) DITCH GAS CUTTING GAS DALLY WELLSITE REPORT SIN LK 6167 LR 9549 344.5 29 1799 40 HIGH DEPTH 4293 YESTERDAY 4083 24 Hour Footage 210 INCLINATION INTERVAL JETS IN OUT 2X16, 20, 12 1575 4293 16,18, 20, 12 4293 HIGH LOW @ 4293 8.3 @ 4153 @ 4284 4 @ 4090 @ 4293 1288 @ 4156 DEPTH: 4293 PV YP SD OIL 4266 15 @ 4293 CHROMATOGRAPHY(ppm) METHANE(C-I) ETHANE(C-2) @ PROPANE(C-3) @ BUTANE(C-4) @ PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY NOT TAKING SAMPLES. LOW AVERAGE 23.7 NONE EPOCH PRESENT OPERATION= TRIPPING i i i AZIMUTH VERTICAL DEPTH CONDITION REASON FOOTAGE HOURS T/BIC PULLED 2718 27.45 2 2 E/R A PR ii i AVERAGE 63.2 21.8 LITHOLOGY/REMARKS GAS CURRENT AVG 56.9 21.8 1640.4 1618 FL Gels CL- MBL pH Ca+ fi/hr amps Klbs RPM psi CCI TRIP GAS= N/A WIPER GAS= N/A SURVEY= 0 CONNECTION GAS HIGH= 5 AVG= 0 CURRENT 0 CURRENT BACKGROUNDIAVG 20 DESCRIPTION DALLY ACTIVITY SUMMARY DRILL TO 4293°, CBU, POOH, REPAIR HYDRAULIC LINE, PICK UP MOTOR AND BIT, RIH. Epoch Personel On Board= 2 Daily Cost Report by: JOHN MORRIS file://C:\WINDOWS~Desktop\marath9on~0000509.htm Daily Report Page 1 of 1 MARATHON OIL COMPANY KBU 33-6 REPORT FOR D. GREEN DATE May 09, 2000 TIME 04:00:00 DALLY WELLSITE REPORT DEPTH 4083 YESTERDAY 3050 24 Hour Footage 1033 i DEPTH INCLINATION i INTERVAL SIN JETS IN OUT LK 6167 2X16, 20,12 1575' 601.0 32 1720 42 i i CASING INFORMATION 13 3/8" @ 1568' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 2 12 1/4 STC M0550DCL DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE i i L I IIII I DRILLING MUD REPORT MW 8.8 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS HIGH @ 3339 @ 3970 @ 3970 PV SD LOW 13.0 @ 3525 0 @ 3357 952 @ 3200 DEPTH: 4050 YP OIL EPOCH PRESENT OPERATION= DRILLING AZIMUTH FOOTAGE HOURS ii AVERAGE 143.5 15.3 --i . i i i i ! i iiii 11 i i i GAS SUMMARY(units) HIGH LOW DITCH GAS 74 @ 3833 2 @ 3168 20.7 CUTTING GAS @ METHANE(C-I) 0 @ ETHANE(C-2) 0 @ PROPANE(C-3) 0 @ BUTANE(C-4) 0 @ PENTANE(C-5) 0 @ i ii i i ii i i i ii i HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY NOT SAMPLING FORMATION. DAILY ACTIVITY SUMMARY AVERAGE CHROMATOGRAPHY(ppm) 4037 0 @ 4037 0.0 4037 0 @ 4037 0.0 4037 0 @ 4037 0.0 4037 0 @ 4037 0.0 4037 0 @ 4037 0.0 NONE LITHOLOGY/REMARKS 1394,7 VERTICAL DEPTH CONDITION T/B/C i . REASON PULLED CURRENT AVG 72.2 15.4 ,, 1592 fi/hr amps Klbs RPM psi FL Gels CL- MBL pH Ca+ CCI TRIP GAS= NIA WIPER GAS= 10 SURVEY= 0 CONNECTION GAS HIGH= 9 AVG= 7 CURRENT 0 CURRENT BACKGROUNDIAVG 25 GAS DESCRIPTION i i i i ii _ i i i i i i i i ii. f i ii ii ii i i i i i DRILL TO 3735', CBU, WIPE HOLE TO 2475', RIH, WASH AND REAM 3699' TO 3735', DRILL TO 3998', REPAIR PUMPS, DRILL TO REPORT DEPTH. Epoch Personel On Board= 2 Daily Cost Report by: JOHN MORRIS Daily Report .... Page 1 of I KBU 33-6 REPORT FOR D. Green DATE May ga, 2000 TIME 04:00:00 DALLY WELLSITE REPORT ii i [ i i i DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN 2 12 114 STC MO550DCL LK 6167 DRILLING PARAMETERS RAT~ OF D~N~TRATION ~7~.~ SURFACE TORQUE WEIGHT ON BIT 24 ROTARY RPM PUMP PRESSURE 1346 DRILLING MUD REPORT MW 8.7 VIS 45 PV FC 1 SOL 4 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS DEPTH 30~0 YESTERDAY 1740 24 Hour Footage 1310 INCLINATION METHANE(C-I) 0 @ ETHANE(C-2) 0 @ PROPANE(C-3) 0 @ BUTANE(C-4) 0 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL ii iiii iiiii i iii i i i iiii ii LITHOLOGY PRESENT LITHOLOGY Not taking lith samples. DAILY ACTIVITY SUMMARY JETS 2X16, 2O, 12 HIGH ~ 1948 @ 2868 DEPTH: 2946 6 YP .5 OIL INTERVAL IN OUT 1575' LOW @ 0 @ 370 @ i i. i i i lq AZIMUTH EPOCH PF(E~ENT OPERATION= Drilling FOOTAGE VERTICAL DEPTH 1 og I CONDITION HOURS T/B/C ,, , AVERAGE a17.g 2309 11.2 1893 1112.8 ,i , CURRENT AVG 02.:2 REASON PULLED 1225 25 FL 9.6 Gels 13/16/21 CL- 0 MBL pH 8 Ca+ ft/hr amps Klbs RPM psi 17000 8O CCI lilt I L I III I II II HIGH LOW AVERAGE 20 @ 2215 1 @ 1758 8.7 TRIP GAS= N/A @ @ WIPER GAS= 10 CHROMATOGRAPHY(ppm) SURVEY= O 2914 0 @ 2914 0.0 CONNECTION GAS HIGH= 0 2914 0 @ 2914 0.0 AVG= 0 2914 0 @ 2914 0.0 CURRENT 0 2914 0 @ 2914 0.0 CURRENT BACKGROUND/AVG 5 2914 0 @ 2914 0.0 i ii iii i _ ii i i i i i i NONE LITHOLOGY/REMARKS GAS DESCRIPTION i i i L I I I I I II I II I I ! I I I I I I II I Drill to 1892', repair hydraulic hose, drill to 2255', wipe hole to shoe, drill to 2946', POOH 5 stands while repairing generator, drill to report depth. Epoch Personel On Board= 2 Daily Cost Report by: John Morris fi le://C:\WlNDOWS~E)esktop\marath9onL20000507, htm 5/8/00 'M~y-18-00 O~:18pm From-MARATHON OI L +g15564648g T-ZSO P.01/02 F-gZ9 Alaska Regii Domestic Prouuction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99~;19-6168 Telephone 907/561-5311 May 18, 2000 Mr. Blair Wondzell, P.E. State of Alaska Alaska Oil and Gas Cons Comm 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KBU 33-6 Dear Mr. Wondzell: Enclosed is the completed Application for Sundry Approvals form for Well KBU 33-6. The sundry involves a minor change in the approved casing program in KBU 33-6 (permit #99-24). The current application states the two strings of 3-1/2", 9.3 ppf, L-80 tubing will be cemented in place in an 8-1/2" hole. This application requests that one string be straight 3-1/2 tubing, and the other string taper from 3- 1/2 to 2-7/8", 6.5 ppf, L-80 tubing across the open-hole section. In the 9-5/8" casing, both strings will be 3-1/2". A wellbore schematic displaying the proposed change is also attached. Please advise if additional information is required. I can be reached on 564-6315. ~i~0~~,i ~Si erely, J, G~Eller '---.J Production Engineer Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. May-I 8-00 02:lSpm F rom-MARATHON 01L +9155646489 T-280 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.0Z/02 F-gz9 1. Type of Reque~ Abandon Suspend ~ Operation Shutdown Re-enter Suspended Well ~ Alter Casing Repair Well ~ Plugging ~ Time Extension ---... S~mulate ~ Change Approved Program X Pull Tubing Variance Perforate ~ Other_._. 5. Type of Well; Development .~X St~-,tlgmphic__= Service 2. N~me of Operator MARATHON OIL COMPANY 3. Address P, O. Box 196168, Anchorage, AK. 9951a-6168 4. Location of Well at Surface 37' FNL & 4068' FWL. Sec. 7, T4N, R11W, SM At mp of Productive Interval 1925' FSL& 3410' FWL, Sec. 6, T4N, RI1W, $,M. At Effective Dspth IUse of Tapered Prod, String At Total Depth 2243' FSL& 2911' FWL, Sec. 6, T4N, R11W, $,M. 13, Present Well Condition Summary ToAI Depth; me.~sured 9535 feet Plugs (measured) true vertical 8892 feet J 6, Datum Elevation (DF or KB) 87' KD above MSL feet ?. Unit or Property Name Kenal Beluga Unit 8. Well Number KBU 33-6 9. Permit Number g9-24 lO, APl Number 50-133-20487 11. Field/Pod Kenai Gas Fleld/~eluga Effective Depth; measured 9461 feet Junk (measured) tree vertical 8821 feet Casing Length Size Cemented Structural 8o- 1 O0 20" Driven Conductor Surface 1765 18.3f8" 1136 sx Intermediate 587{3 9-5/8" 500 sx P~3durtien 8065 9-5/8" 715 so( Liner perforation Depth; measured N/A Measured Derh 80-100 1765 ~870 8066 True Ve~ical Depth 80. t00 1714 5887 7500 true vertical NIA Tubing (size, grade, and measured depth) P~ckem and $SSV (type and measured depth) 3-1/2", 9,2 ppf. L-a0, ard to 8065' (string ~1) ~600' of ~.1/2", 9,2 ppf, L-80 plus 2465' of 2-7/8", 6.6 ppf, L-s0 to 8065' (string #g) N/A Attachments De~fiption S'ummary of Proposal ~ Detailed Operations Program ..-- 14. Estimated Date for Commencing Operation 115, Status of Well Classification as: ~I22/00 . 16. If Proposal was Verbally Approved Oil.._ Gas ~ Name of Appr0ver D~te Approved Service ~rtify th~t~e and correct to the bes~ ct my knowledge. Signed- ~[~k.' ~k ,-, (~ary IBler T,t,e Production I~ngineer ' ' ~'~ --" - 'FOR coM;ISSlC~N USE ONLY Conditions of Ap~rovah Neti~ommieSion so representative may ;itness plug Integrity ~ BoP Test Location Clearance_~,~ Mechanical Integrity Test '"'~ubsequent Form Required 10- ~ '~ BOP Sketch Suspended..._. D~'[e Approved by O~der of the Commission 'erin 10-do9 Re,/. ORIGINAL SIGNED E~'~' D Taylor Seamount Commissioner Submit In -Triplicate RECEIVED MAY 1 8 2000 Oii& Gas 6one. O~ammissior~ Ma~-18-O00~:~Opm From-BARATHON OIL +g155848489 ~ rauru~u i Kenai Gas Field Well KBU 33-6, Pad 41-7 Marathon Oil Co,, Alaska Region T-Z84 P.OZ/O~ F-g3g API: 50-133- RT-GL: 21,00' 20", 133#, K-55 Drive pipe (~ 100' 37' FNL, 4068' FWL Sec, 6, T4N, RI1W, $.M. Chemical injection mandrels wi X-nipple profiles (ID = 2.813") SS: 950' LS: 980' 13-3/8", 61#, K.557 BTC Casing @ 1763' Cmt w/1136 sks of Class G 9-518", 40#, L-80, BTC Casing @ 5870' emi wi 590 sks of Class G Last Rev: IGE 3/18/99 PBTD = TD -- I1065' Longatring 3-1/2", 9.3#, L-80, EUE 8rd-M w/SCC @ 8065' Shortsmng 3-112" n ;~-7/8" taper ~ 8065' 0' - 5600'; 3-1/2", 9.3~, L-S0, EUE Srd-M wi SCC 56oo' - 8065': 2-?t8", 6,5#, L-gO, tiUE 8rd-M w/SCC Cement RECEIVED Cemcnled with 670 sk S'...fy fo~ KBU 33-6: Change Tbg Size Subject: Sundry for KBU 33-6: Change Tbg Size Date: Wed, 17 May 2000 19:56:37 -0500 From: "J Gary Eller" <JGEller~MarathonOil.com> To: Blair_Wondzell~admin.state.ak.us CC: CEYoung~MarathonOil.com Blair - I wanted to notify you ahead of time regarding a sundry I'm ready to submit regarding well KBU 33-6. The sundry involves a minor change in the approved casing program in KBU 33-6 (permit #99-24). The application currently states that two strings of 3-1/2", 9.3 ppf, L-80 tubing will be cemented in place in an 8-1/2" hole. I propose that one string be straight 3-1/2" tubing, and the other string taper from 3-1/2" to 2-7/8", 6.5 ppf, L-80 tubing across the open-hole section. In the 9-5/8" casing both strings will be 3-1/2" I have a wellbore schematic that will display the proposed change more clearly. The reason for the change is to improve the annular clearance in the open-hole section, thereby increasing the likelihood that the strings can be run to bottom without getting stuck. It also enhances our ability to get an effective cement sheath around both strings of tubing. The cement volume will be increased from 670 sacks to 715 sacks to account for the increase in cross sectional area. The 2-7/8" tapered string is fully adequate in terms of collapse,~ burst, and tensile loading requirements. I'll get the sundry faxed to you today. It looks like we could be running the pipe in KBU 33-6 on Monday or Tuesday. Thanks for your time. 5/18/00 8:51 Re: [Fwd: KBU 33-06 BOP Variance] - - PTD #99-0i? Reply Subject: Re: [Fwd: KBU 33-06 BOP Variance] -- PTD #99-024 -Reply Date: Wed, 17 May 2000 14:38:00 -0800 From: Blair WoncLzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: J Gary Eller <jgeller~marathonoil.com> CC: CEYoung~GROUPWISE.MarathonOil.com, OLWatkins~GRO UP WI S E.MarathonOil. co m, PKBerga~GROUP WI S E.MarathonOil. com, Jack Hartz <jack_hartz~admin.state.ak.us>, Tom Maunder <tom_maunder~admin.state.ak.us> ary, hanks for the explanation. I agree that we can classify your predicament as a bonafide emergency. Nothing more need be said. Sincerely, Blair J Gary Eller wrote: > Blair - My apologies, because we really dropped the ball here.. Sunday evening after cementing the 9-5/8" casing, we installed the 11" 5M tubing head as per the well plan. Our BOP stack has 13-5/8" 5M flanges, but the lower pipe ram is equipped with studs looking down. Unfortunately, and strictly due to our screw up, we were prepared to install an adaptor on the tubing head that had studs looking up. Once we realized that we were going to have studs looking at studs, Craig, Otis, and myself began the desperate Sunday-night search for the proper adaptor spool. > > Our options for a replacement adaptor were not attractive; the only options we could find would have required extensive onsite modifications and, because of the total height, would have made our trip tank unavailable. At that point, trying to make the best of a bad situation, we opted for dropping off the bottom studded ram. > > We are obviously going to try to prevent this from happening again. The next well will have the proper 11" x 13-5/8" adaptor spool, plus the stack will be positioned so we don't have to compromise our trip tank. We plan to resume our typical three-ram arrangement (one blind, two pipe) for the rest of our 2000 drilling program. > > Once again I apologize, and please let me know if I can be of further assistance. > > >>> Blair Wondzell <blair wondzellOadmin.state.ak.us> 05/15/00 04:27pm >>> -- > Hello Gary, > I agree that a variance from the approved Permit To Drill is acceptable > > I do not understand why this question came up at 11:00 PM and especially > on a Sunday evening. The Permit To Drill "99-024" was approved on June > 29,1999. The well was spudded on April 28, 2000 and on May 12, 2000 a > Craig E. Young, Marathon Senior Drilling Engineer, sent an E-mail to Tom > Maunder with "cc:" to me with Marathon's plan to change the cement > program on the intermediate casing. There were several opportunities to > review the approved drilling program. > An explanation would be appreciated. > > Sincerely, Blair Wondzell > > > Subject: [Fwd: KBU 33-06 BOP Variance] PTD #99-024 > Date: Mon, 15 May 2000 16:27:35 -0800 .> From: Blair Wondzell <blair_wondzellOadmin.state.ak.us> 1 of 2 5/17/00 2:38 PM [Fwd: KBU 33-06 BOP Variance] - - PTD #99-024i Subject: Date: From: Organization: To: CC: [Fwd: KBU 33-06 BOP Variance] -- PTD #99-024 Mon, 15 May 2000 16:27:35-0800 Blair Wondzell <blair_wondzell~admin.state.ak.us> State of Alaska, Dept of Admin, Oil & Gas Gary Eller <jgeller~marathonoil.com> Jack Hartz <jack_hartz~admin.state.ak.us>, Tom Maunder <tom_maunder~admin.state.ak.us> Hello Gary, I agree that a variance from the approved Permit To Drill is acceptable I do not understand why this question came up at 11:00 PM and especially on a Sunday evening. The Permit To Drill "99-024" was approved on June 29,1999. The well was spudded on April 28, 2000 and on May 12, 2000 a Craig E. Young, Marathon Senior Drilling Engineer, sent an E-mail to Tom Maunder with "cc:" to me with Marathon's plan to change the cement program on the intermediate casing. There were several opportunities to review the approved drilling program. An explanation would be appreciated. Sincerely, Blair Wondzell Subject: KBU 33-06 BOP Variance Date: Mon, 15 May 2000 09:51:18 -0700 From: Jack Hartz <jack_hartz~admin.state.ak.us> Organization: Alaska Oil and Gas Conservation Commission To.' Blair Wondzell <blair_wondzell~admin.state.ak.us> Blair, Answering service called about 11:00 p.m. Sunday night with a message from Gary Eller of Marathon for a callback. He requested a variance for the BOP arrangement that was different from what was stated in the PTD application. The approval was for a 3000 psi BOP, however, they had stated they would have a full stack with 2 pipe rams, a blind ram and annular preventer. The variance was to drill with only one pipe ram, a blind ram and annular. The variance conforms with the 3000 psi requirements. Their only need was to inform AOGCC that they would vary from what they stated in the permit package. I gave a verbal ok on the variance and informed Eller I would talk to you in the a.m. Jack Sr. Reservoir Engineer lAlaska Oil & Gas Conservation Commission I of 2 5/15/00 4:27 PM Unocal Alaska Resources Unocal Corporation 909 West 91'h Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd@, unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 To: Lori Taylor 3001 Porcupine Anohorage, AK gg501 AlaSka Oil & Gas Frorn: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: · tt¢ e;oT.~ SCU 12-9 ~" SCU 12-9 SCU 12-9 SCU 12-9 ~ ~ 12A-3 i~'0' 12A.3 '§~1-12A-3 ~ ~o, o ~ ~. SCU 14-4 ~ ~SCU 14-4 {SCU 21A-9 I~~ ~' 21A-9 SCU 1 i-9 "rilernlal 'rime ~.5 irich Thermal Decay.......T...!.....m....e.......L.....o..g.. 5 inch Record 5 inch Record 5 inch Record/Correlation 5 inch Recor~.~?~!.~.!i..~.~o~c~ inch Perforating. Record/Correlation5 inch Perforatin¢ Record/Correlation 5 inch Possiset Plu, 5'Cement 5 inch Plu, 5'Cement i5 inch Perforatin( Record/Correlation Lo( ~5 inch 'Perforatin Record/Correlation Lo( 5 inch Perforatin( Record, 5 inch Record 5 inch i 9/6/99 6400-10714' i ! I B-,Line i' 9/6/99 6400-10714 ! 1 Film ~ 2/3/00 10150-10330 i 1 B-Line ...... i ................... ~§~i~'~"i"~'~"~'ib':'i"~§'~'ib' ............................................................................................ ~"t"i~ii~ ........................... ~ 1/16/00 10000-10500 1 iB-Line .............. 1~1~6/00 10000-~1..~.~g0~ ..................... 1 Film i 3/15/00 10200-10550 1 B-Line i' 3/15/00 3/11/00~ 3/11/00~ 1/14/00 1/14/00 2/1/00 2/1/00 10200-10550 10200-10545 10200-10545 1O0O0-1O610 10000-10610 10500-10700 10500-10700 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 33~CU 22-4 I MD ~ Field Print 5 inch 10/8/99 10340-11140 1 B-Line ~ ,o_ ~~.~ ~_M,~ ComR~site ~e~ ~J~n-t~ ,.~.~[~.~,~ ......................... (~-0g-~'~74" ...... ~-~~OT~i~-'~'~T~'~ ............................ 5 inch 10/8/99 10340-11140 1 B-Line [,.~,g.g..,,~:5. ................... ~V.D...~9.m.~.~.!t.e....E!~.?,~!,~ .......................................... ~,..,!.p.~.b ................................ ~..0(~(9~.j.0.~.9,;~,..!..,!,59 ............................................................................................ !....,E~,m ........................... ~0.~u ~ SCU 24A-5 Completion Record :5 inch3/13/00 10200-10640 1 B-Line .... ~SCU 43B-8 ~Com~lehon Record ~5 tach , jSCU 43B-8 ~Com~tion Record ~5 inch I ~, ti- il' ~ I ....... ~. KBU 33-6 Intermediate Cement ,,,, Subject: KBU 33-6 Intermediate Cement Date: Fri, 12 May 2000 19:35:10 -0500 From: "Craig E Young" <CEYoung~MarathonOil.com> To: Tom_Maunder~admin.state. AK.US CC: Blair_wondzell~admin.state.AK.US Mr. Maunder, This is to confirm Marathon's plan to change the intermediate casing cement program on KBU 33-6 per our telephone conversation today. The plan will change to as follows with the cement top being higher than what was in the permit. Cement type: Class G + 34% Extender + 0.65% Dispersant + 0.1% Anti-foam Weight: 12.00 PPG Yield: 2.38 ft3/sx Mix fluid: 8.066 gal/sx Desired top of cement 3000' MD / 2802' TVD Compressive Strength Time 500 psi 5:48 Hrs:MM 2000 psi 10:00 Hrs 2900 psi 16:00 Hrs If there are any problems or you need any additional information, please give me a call at 564-6310. Thanks for your help. Craig E. Young Senior Drilling Engineer Marathon Oil Company 1 of 1 5/15/00 3:28 PM X. POTENTIAL HAZARDS Well KBU 33-6 To comply with state regulations the Potential Hazards section and the well shut in procedures must be posted in the drillers dog house. The man on the break(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/- 3557' tvd/3872' md to total depth of the well. These sands will run from normal pressured to severly depleted and lost circulation and differential sticking are protential hazards. The FIopro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. page 10 n:\drlg\kghwells\kbu 33-6\336prog.xls TONY KNOWLES, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 29. 1999 P. K. Bcrga Drilling Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 Rc~ Kenai Unit KU 33-6 Marathon Oil Company Permit No: 99-024 Sur Loc: 37'FNL. 4068'FWL. Sec. 7. T4N, RI IW. SM Btmhole Loc. 2243'FSL, 2911'FWL. Sec. 6, T4N, RI IW. SM Dear Mr. Bcrga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal is not authorized for this well. Authorization may bc granted tbllowing receipt and Commission approval of Form 10-403 containing information rcquired by 20 AAC 25.080. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to alloxv a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission at 279-1433. ~Robcrt NhC r'lst~mson. P.E. - Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. Alaskai, ;ion Domesti',. )roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 6, 1999 Mr. Robert N. Christenson, P.E. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Annular Disposal Request for Wells KBU 33-6 and KBU 42-7 Dear Mr. Christenson: In response to your letter of April 22, 1999, we request that you do not hold the drilling permits for wells KBU 33-6 and KBU 42-7 any longer. We will pursue the annular disposal through an Application for Sundry Approval at a later date. Sincerely, P. K. Berga Drilling Superintendent Alaska Oil & Gas Cons. Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COM~HSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 22, 1999 P.K. Berga Drilling Superintendent Marathon Oil Company PO Box 196168 Anchorage, AK 99519-6168 Re: Annular Disposal Request for Wells KBU 33-~, KBU 42-7 Dear Mr. Berga: Thank you for your recent Applications for Permit to Drill for wells KBU 33-6 and KBU 42-7 in the Kenai Gas Field. Blair Wondzell's notes indicate that you may want to dispose of waste via annular injection in these two wells. Authorization for annular disposal of drilling waste may be requested with the application for these Permits to Drill or by a subsequent Application for Sundry Approval. In either case, 20 AAC 25.080 requires the applicant to provide certain information to the Commission (copy of regulation attached). If you would like the request to conduct annular disposal operations to be evaluated with the Applications to Drill we can hold the applications until the necessary information is received. However, if you would prefer to seek that authorization at a later time please let us know and we will continue processing these permits. Sincerely, Robert N. Christenson, P.E. Chairman slh/enclosures 996 MISCE~OUS BOARDS I. 20 AAC 25 is amended by adding a new section to article 1 to read: 20 AAC 25.080. ANNULAR DISPOSAL OF DRILLExIG WASTE. (a) A person may not dispose of drilling waste through the annular space of a well unless authorized by the commission under this section. An operator may request authorization for such a disposal in an application for a Permit to Dr/il (Form 10-401) or an Application for Sundry Approvals (Form 10-403). (b) A request for authorization under this section must include (1) a designation of the well that will receive drilling waste; v' (2) the depth to the base of freshwater aquifers and permafrost, if present; (3) the depth and thickness of the receiving zone and the confining zone, and sufficient information to demonstrate confinement; (4) a list of all publicly recorded wells within one-quarter mile, and all publicly recorded water wells within one mile, of the well that will receive drilling waste; (5) an estimate of the maximum volume and density of waste slurry to be disposed; (6) a description of any waste sought to be determined as drilling waste under ~,..~., (h)(3) of this section; (7) an estimate of the maximum anticipated pressure at the outer casing shoe during disposal operations and calculations showing how this value was determined; (8) details that show that the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation; 996 ,.MISCELLANEOUS BOARDS (9) details that show that the inner and outer casing strings have sufficient strength in collapse and burst to witkmtand the anticipated pressure of disposal operations; and (10) any additional data required by the commission to confirm containment of drilling waste. (c) The commission will, in its discretion, authorize disposal of drilling waste through the annular space of a well permitted under AS 31.05.090 if it determines that (1) the waste w/il be contained in a suitable receiving zone; (2) the disposal will not (A) contaminate freshwater;, 03) cause drilling waste to surface; (C) impair the mechanical integrity of the well used for disposal; or CD) damage a producing or potentially producing formation or impair the recovery of oil or'gas from a pool; and (3) the disposal will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (d) Unless the operator demonstrates, by written application, that it is imprudent to comply with a limitation established in (1) - (4) of this subsection, the commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space ora single well; (2) for a period longer than one year through the annular space of a single well; (3) into a hydrocarbon-bearing strauan; Register .... 1996 MISC~I.!ANEOUS BOARDS (4) throu~ the annular space of a well not located on the same dr/Il pad or platform as the drfl~g operation generating the dr[tling waste. (e) In addition to any other conditions that the commission in its discretion imposes on a cae-by-cae basis, an authorization to dispose of drilling waste under this section is subject to the following conditions: (1) if drilling waste appears above the confining zone, the operator shall immediately cease disposal, notify the commission, and take appropriate remedial action; and (2) if the commission notifies the operator that disposal operations pose a threat to safety., oil or gas recovery, or freshwater, the operator shall immediately cease disposal and take appropriate remedial action as approved or required by the commission. (f) For each well authorized for disposal under th/s section, the operator shall report to the commission in writing (1) the date and the method by which the annulus was closed if closed at the end of the disposal operatiom, or the condition of the annulus if left open for future disposal operations; and (2) the total volume of drilling waste disposed of, by the following categories: (A) the aggregate of all drfl~g wastes described in (h)(1) of this section; (B) the aggregate of all drilling wastes described in (h)(2) of thin section; and (C) each substunce determined to be a drilling waste under (h)(3) of this section. A report under this subsection is required when a Well Completion or Recompletion Report and Log (Form 10-407) or Report of Sundry Well Operations (Form 10404) for plugging the well is required to be filed for the well, or no later than 30 days after the disposal atrdaofization expires, whichever occurs first. (g) The provisions of 20 AAC 25.252 and 20 AAC 25.402 - 20 AAC 25.460 do not apply to the disposal of drilling waste authorized under this section. 1996 MISCE~OUS BOARDS Ca) In this section, "drilling waste" me~ns the following substances, unless identified as a hazardous waste in 40 C3.R. Pan 261: (1) drilling mud,, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completion fluids, and formation fluids associated with the act of drilling a well permitted _. under 20 AAC 25.005; (2) drill fig wash fluids and drill rig domestic waste water;, and (3) other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. (i) For purposes of this section, in AS 31.05.030(e)(2), "oil or gas well" means a well permitted under AS 31.05.090 other than a water well associated with oil or gas exploration and production. (Eft. / / , Register ) Authority: AS 31.05.030 Domestic P'roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 15, 1999 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Kenai Unit KBU 33-6 Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, P. K. Berga Drilling Superintendent PKB:nrs N:\DRLGtKG~WELLS~kbu33-6~aogc¢clt.doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. g:\cmn\drlg\sterling\su44-10~Aogccptd.xlw L/'i"' STATE OF ALASKA . A ..,A OIL AND GAS CONSERVATION COMic-. :~ION PERMIT TO DRILL 210 AAC 25.OO5 la. Type of Work DrillE~ Re-DrillE~ lb. Type of well. ExploratorYr~ Stratigraphic TestE~ Development oilE~] Re-EntryE~] DeepenE~ Servicer-'-] Development GasE~ Single Zoner"--~ Multiple ZoneE~] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 87' KB feet Kenai Gas Field/Beluga 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 A-028142 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 37'FNL, 4068'FWL, Sec. 7, T4N, R11W, S.M. Kenai Unit Blanket Surety At top of Productive Interval 8. Well Number Number 1925'FSL, 3410'FWL, Sec. 6, T4N, R 1 lW, S.M. KB U 33-6 5194234 At Total Depth 9. Approximate Spud Date Amount 2243'FSL, 2911'FWL, Sec. 6, T4N, R1 lW, S.M. 7/1/99 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Line(unit boundary) 12500 feet 440 feet 6000 8065' MD/7500' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 600 feet Maximum Hole Angle 29 o :Maximum Surface 2559 psig atTotat Depth (]'VD) 7500' 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 P E 80-100' 0' 0' 80-100' 80-100' 17-1/2" 13 3/8" 61 K-55 BTC 1763' 0' 0' 1763' 1714' 1136 sx . 12 1/4" 9 5/8" 40 L-80 BTC 5870' 0' 0' 5870' 5387' 250 sx 1 st 340 sx 2nd 8 1/2" Dual 3 1/2" 9.2 L-80 EUE 8rd 8065' 0' 0' 8065' 7500' 670 sx ~""~ I"~ I ~"~1 I I .~ I . , ' Kenai Unit well KBU 33-6 will be directionally drilled to an estimated total depth of 8065' MD, 7500' TVD from the "Kenai Gas Field pad 41-7.The production interval will be cased with dual 3.5" strings cemented in place and run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing FeeE~] Property PlatE~ BOP Sketch[~ Diverter Sketchr-~ Drilling Programr-~ Drilling Fluid Program[-~ T,me vs Depth P,ot[-'"] Refraction Ana,ysis[-'"1 Seabed Report[--] 20 AAC 25.050 Requirements[--"] 21. I hereby certify that the foregoing is true and correct to the best of my knowledfle Signed P.K. Berga ~~ Title Drilling Superintendent Date 3/15/1999 Commission USe OnlY Permit Number IAPI Number IA,,row, Date .~<:~pr~ ISee Cover Letter ' /~',,~ -.2. ~_.]Z 5~--/.~.~ -- ~ o ~ 2 7 IFor Other Requirements Conditions of Approval Samples Required r-]Yes l~No Mud Log Required L_JYes [~No Hydrogen Sulfide Measures r'-'~Yes r~No Directional Survey Required ~Yes r"~No Required Working Pressure for BOPE D2M [~3M F"~SM F"-]lOM F"~lSM Other: ORIGINAL SIGNEDI~Y by order of Approved by ~ ...... ,.,~.,4,.,~,,,,e~,~. Commissioner the Commission Date /~7 Form 10-401 Rev. 12-1-85 Triplicate DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: KBU 33-6 PaD: 41-7 SLOT: NA REVISION NO.: 0 SURFACE LOCATION: TARGETS Middle Beluga FIELD: Kenai Gas Field AFE No.: 9203699 TYPE: Development. DATE: 3/15~99 37' FNL, 4068' FWL, Sec. 7, T4N, R11W, S.M. 1925' FSL, 3410' FWL, Sec. 6, T4N, R11W, S.M. BOTTOMHOLE LOCATION: 2243' FSL, 2911' FWL, Sec. 6, T4N, R11W, S.M. KB ELEVATION: GL ELEVATION: 87 ft. mean S.L. (est.) 66 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FOR M ATI ON DEPTH ( M D) DEPTH (TVD) Sterling 3872 3557 Upper Beluga 5089 4662 Middle Beluga 5798 5317 Lower Beluga 6553 6044 Tyonek 7771 7217 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION DEPTH(MD) Sterling 3872 Upper Beluga 5089 Middle Beluga 5798 Lower Beluga 6553 Tyonek 7771 TD 8065 POTENTIAL DEPTH(TVD) ~ CONTENT 3557 gas/water 4662 gas/water 53~, 35-~' gas/water 6044 -'- gas/water 72 ~ ,-z,5-_~-~) gas/water 7500 gas/water page 1 g:\cmn\drlg\kgf\wells\kbu 33-6\336progoxls III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 20" X 3000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING FLANGE: 20 3/4" 3M Flange top x 20" weld on bottom. CASING HEAD: 13 5/8" 5000 psi top x 13 3/8" sow bottom with base plate for 20". CASING HEAD: TUBING HEAD: 11 "-5000 psi top xl 3 5/8" - 5000 psi bottom. CHRISTMAS TREE: 3 1/8" - 5000 psi dual christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 g :\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls IV. CASING PROGRAM: CASING DESCRIPTION TYPE SIZE SET SET HOLE WT. GRADE THREAD FROM TO(md/tvd) SIZE - CONDUCTOR: 20" SURFACE: 13 3/8" INTERMEDIATE 9 5/8" 133 ppf K-55 PE Surf 80-100~80- Driven 100 61 ppf K-55 BTC Surf 1763'/1714' 17 1/2" 40 ppf L-80 BTC Surf 5870'/5387' 12 1/4" PRODUCTION: 3 1/2" x 3 1/2" 9.2 ppf L-80 EUE 8rd Surf 8065'/7250' 8 1/2" CASING DESIGN SIZE WEIGHT GRADE SETTING FRAC GRD FORM PRSS DESIGN FACTORS DEPTH,TVD ~ SHOE ~b SHOE MASP TENS COLL BURST 13 3/8" 61 ppf K-55 1714' 11.5 800 603 10.47 1.28 3.35 9 5/8" 40 ppf L-80 5387' 14.0 2520 1900 4.93 2.42 1.68 3 1/2" x 9.2 ppf L-80 3 1/2" 7250' 15.2 3393 2559 2.80 5.08 3.96 All tubulars are new. page 3 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls V. CEMENTING PROGRAM SURFACE: 13 3/8" 1763'/1714' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: SURFACE 12.8 ppg. 2 cu. ft./sk gal/sk hrs:min 50 % in open hole. 653 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 1263 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % in open hole. 483 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 1 shoe joint. Check float. Fill pipe until circulating, 3. M/U stabin float collar, (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U circulating head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Run inner cementing string with stabing sub and centralizer. Baker has false rotary and slips. 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry. 10, Mix and pump tail slurry. 11. Displace cement. Sting out. 12. Check floats, 13. POOH with inner string. WOC 14. N/D diverter. Weld on casing head and N/U blowout preventers. 15. Test BOPE, Run wear bushing. page 4 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 9 5~8" @ 5870'/5387' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: Stage 1 5170 ft. 12.8 ppg. 2.00 cu. ft./sk gal/sk hrs:min 50 % - 100 sks. Stage 2 3900 ft. 12.8 ppg. 2.0 cu. ft./sk gal/sk hrs:min 50 % 240 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: 5600 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 50 % ESTIMATED VOLUME 150 sks. 4925 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 % 100 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1, Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing, M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer, 8. Pump spacer as follows: To be designed. 9. Mix and pump lead slurry, 10. Mix and pump tail slurry. Drop top plug. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U tubing spool. N/U BOP stack. 15. Test BOPE. page 5 g :\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 3 1/2" x 3 1/2" 8065'/7250' LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: ft. ppg. cu. ft./sk gal/sk hrs:min %(use 25% over caliper log.) sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 5700 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 25 % over caliper log. 670 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head and test all lines, 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug. 10, Displace cement with water. Reciprocate as long as possible. Land tubing hanger. 11. Bump plug w/a minimum of 1875 psi. Check floats. 12. WOC page 6 g :\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 1714' 8.6-9.0 80-250 15-30 Freshwater gel 1714' 5387' 8.6-9.0 42-80 < 12 Frreshwater/gel/LCM 5387' 7500' 9.0-9.5 50-70 < 8 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS \~,L,~, ~' LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: RUN #1:AITIDSIILDTICNL/GR. RUN #3: RFT/GR. RUN #2: AIT/MSFL/LDT/CNL/NGT. RUN #4: MSCT/GR. COMPLETION: Gammaray/CCL. MUD LOGGING The well will be mud logged from 1763' md(casing point) to TD at 8065' md. CORING PROGRAM Side wall cores will be taken during the logging program. TESTING PROGRAM No open hole tests are planned for this well. Each string will be pre and post frac tested. page 7 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS See attached sheet for anticipated bottomhole pressures for all sands. Lost returns are possible. Hydrogen sulfide gas has not been encountered in any well in the Kenai Gas field IX. OTHER INFORMATION DIRECTIONAL PLAN NORTH DESC MD TVD INCL AZIM COORD WEST COORD VERT SECTION RKB 0 0 0 0 0 KICKOFF 600 600 0.0 345.5 0 build @ 2.5 deg/100ft HOLD 1763 1714 29.1 345.5 280 0 72 0 288 DROP 4408 4025 29.1 345.5 1524 394 1571 END of DROP 5767 5287 1 5.6 302.5 1962 658 2O69 Total Depth 8065 7500 15.6 302.5 2280 1157 2529 POTENTIAL INTERFERENCE: WELL DISTANCE (ft.) No serious interference exists. DEPTH (MD) page 8 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls X. DRILLING PROGRAM CONDUCTOR: Drive 20" conductor to +-100 ft. RKB. Weld starting flange to drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 17 1/2" hole to 1763' md/1714' tvd per the directional plan. Run and cement 13 3/8" casing. WOC. Cutoff 13 3/8" and 20". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3000 psi. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE Drill out float equipment and make 5-10' of new hole. CBU. Test shoe to leak off. Estimated EMW is 11.5 ppg. Drill 12 1/4" directional hole to 5870' md/5386' tvd as per directional plan. Lost circulation is possible through this entire interval. Make wiper trip. Run and cement 9 5/8" casing. WOC. N/U 13 5/8" 5M x 11" 5M head. Test BOPE to 250/5000 psi. Set wear bushing. Test casing to 2600 psi. PRODUCTION: Drill float equipment and 10' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14 ppg. Drill a 8 1/2" hole from 5600' to 7932' per the directional program. Log. Make a wiper trip. Pull wear bushing. Run dual 3 1/2" casing strings and land hanger in tubing head. Cement. Bump plug with 1875 psi. WOC. COMPLETION: Set BPV's in hanger. N/D BOPE and N/U dual tree. Test tree to 5000 psi. Perforate and frac each string as per program. page 9 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls NOTES: MASP CALCULATIONS: Surface casing: 13 3/8" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (11.5 ppg + 1.0 ppg) x .052 x 1714' - (.115 x 1714') MASP = 1114psi- 197psi MASP = 917 psi. Intermediate casing: 9 5/8". MASP -- Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (14.0 ppg + 1.0 ppg) x .052 x 5387' - (.115 x 5387') MASP = 4201 psi- 619 psi MASP = 3582 psi. Production casing: Dual 3 1/2" strings. MASP = Formation pressure - Hydrostatic pressure of gas column. MASP = 9.0 ppg x.052x7250' -(.115x7250') MASP - 3393 psi - 834 psi MASP = 2559 psi. Cementing The cementing of the 9 5/8" casing may or maynot be done in stages. The actual procedure and amount of cement will be determined once the severity of lost cirulation is determined, Tubulars All tubulars are new. page 10 g:\cmn\drlg\kgf\wells\kbu 33-6\336prog.xls 20 3/4" SM Diverter IDiverter Spool I I I\ 6" Automatic Hydraulic Valve Marathon Oil Company Diverter Configuration J FIow Nipple J13 5/8" 5M Annular Preventer JFIow Line J I J13 5/8" 5M Double J Ram Preventer J3 1/8" 5M Manually Operated Valves Ram Preventer JPipe Ram J JBlind Ram J JPipe Ram J Operated Valve J3 1/8" 5M Hydraulically Operated Valve /I Marathon Oil Company BOP Configuration 2 9/16" 10M Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke Marathon Oil Company Choke Manifold Configuration 4OO 800 1200 1600 2000 2400 2800 5200 3600 4OO0 4400 4800 5200 5600 6000 6400, 6800 Estimated RKB 87' KOP 2.50 5.00 7.50 10.00 12.50 DLS: 2.50 deg per 100 ft 15.00 1 7.50 20,00 22.50 25.00 27.50 EOC - 13 5/8 CSG Pt Begin Angle Drop Target Angle 15.64 Deg M . ATHON 0il Compan Structure : Pad 41-7 Well : KBU55-6 F~eld : Kenal Gas FIelc[ Location : Kenai Peninsula. Alaska, TD LocaL(on: 1 ~63' FILL. 29t0' FI~ 1200 1000 See. 6, T4N. RIIW ~ ~ ~ ~ 7200 7600 TARGET - NorthWest BH <- West (feet) 800 500 d-O0 I I I I i I I TD - 7 Casing Pt Target #2 Loca~on: 22~5' FSL. 3969' FWL See. 6. T4N, RIIW TARGET - T/ Mid Beluga 200 Target Location: 1945' FI!IL. 3409' F~L Sec. 6, T4N, Rl lW 341.47 AzimuLh 2529' (To Target) Plane of Proposal Maximum Angle 29.08 Deg End Angle Drop Begin Angle Drop EOC - 13 3/8 CSO P~ PROFILE COMMENT DATA ..... Point ..... MD Inc Olr T~ North i KOP 600.00 0.00 ] EOC - 13 $/8 C~ Pt 176,3.2429.08 3,1-,5.50 1713.~ 279.72 -7Z. 3Z El~In An~le OrIN) 440~,04.2g.08 J4~O 402~,~11 1~4.2g -3g&.12 End Amlle Oreo 5767,22 15.64 302,47 5287.00 1~6.91-63~91 9 5/8 Cai/n9 Pt, 58713.9615.64..302.47 5386.g0lgBI.g2 -657.51 TARGET - r/ Mid {~IlU 5871.0~ t5.64 302.475387.001961.g4 -6.57.55 27.92 26.68 25.46 24.27 23.1 2 22.00 DLS: 1.50 deg per 100 ft 20.95 1 9.92 18.96 18.08 17.28 1 6.58 End Angle Drop .98 TARGET - T/ Mid Beluga TARCET - NorthWest BH ~_~~ TO - 7 Casing Pt i [ I I I I I ] T I II i I I 0 400 800 1200 1600 2000 2400 2800 Vedicol Section (feet) -> TARG~"I' - No~:hW,~t g 750~.r~ t5.64 302.4.7 7250.D02241.93 -1097.5~ TO - 7 Caelnq Pt 8065.30 t5.6~.302.477500.00 227g.51 -1156.57 2400 2200 2000 1800 1600 1400 1200 1000 8OO 600 400 20O 0 v. Sect Oe~/I O0 288.21 2.50 ono 1 205~. I ?o.oo 206~. ! g0.00 2474.4.;)O.O0 252&8~ 0.00 Azimuth 341.47 with reference 0.00 N, 0.00 W from slot #KBU53-6 For: P Bergal ~ot Reef',ce ;s KSIJ ~3-6 ve,~an ~2. · C,~wdinal~m are ;n feet refee~'~ce Tn~e ~ JD~ptJ~ o~ ~e~n~e ESL RKB . MA[oATH0 N 0 il C o mp arty Structure: Pad 41-7 Well: KBU33-6 Field : Kenai Gas Field Location : Kenoi Peninsula, Alaska~ 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 goo <- West (feet) 200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 , I I I I I i i I ~ , , I , ~ 7 I10 (~ 000~!~J~ 1 , , I I I , , I ~ ~ , I ~ ~.73oo 7100 ~ 6700 ~ ~6go0 "\ ~%...6700 '~ 6500 ~ 6500 '~ 6300 ~..6300 -., 6100 ~ ~sgo0 ~ 6100 ".~...5700 ~ 5500 / 5900 %5100 \ ~ 5700 ~ 4900 \ ~ 5500 % 4700 \ ~ 5300 % 4500 \\ ~ 5100 ~\4300 \ ~go0 700 I % 5100 600 ~ 4900 -,,, 4700 500 4100 \ 4700 ~ 3900 \ 4500 ~ 5700 · 4500 \ 33OO ~ 5~00 ~ 2900 5700 \~ 2704 3500 ~ 25~ )5300 ~ 2: ~1oo 4100 t3900 5700 3500 200 11 O0 1000 900 800 700 600 500 400 500 200 1 O0 0 1 O0 200 , 5300 5100 ~ 2900 4100 ~2700 3900 !2500 O0 2100 24OO 2500 2200 2100 20OO 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 9OO 800 700 6OO 500 <- West (feet) For: P Bergal 9-M,o~- 1999 True ~ D~O~ om ~'~-.c~ Fit. RKB . INTgO :MA!'~ATHON Oil Compa(,,y Structure : Pod 41-7 Well : KBU35-6 Field : Kenai Gas Field Location : Kenai Peninsula, Alaska <- w~,, (~) · Zo,, (f~t) -> 420 560 .500 240 180 120 60 0 60 120 ! flO 24,0 500 360 420 960 9OO 840 780 720 660 600 540 420 560 300 24-0 180 120 6O 120 180 \ 2900~ \ \ \ \ 2700~ 2500~ 3700 ~ 2500 \, ',, \, ~ 3500 "~ 3300 2300 I1 ~ 2100 2300 ~ 31 O0 \\ ~1 270 2900 19o& 1 ~ /,oo -. ,,oo, ~2~oo "~ / / ~ , , / 29~..~ ~ 2300 ~ ~ 700 ~ %~700 ~ 300 / /1500 ~ ~23oo ~ /~oo ,,oo~ ~~,oo ~%% ~ / / '~ x. _ 11oo ~3oo ~3oo 5oo ~ X ~5oo ~oo ,,.~ / ,~oo; ,~,oo / / ~ood } / ~ 300 ~ / ~ 900 ~ x / / ,,00"~ , ~oo,4!~oo / ~ , ,oo ,,,~ , / 420 360 500 240 180 120 60 0 60 120 180 240 300 560 420 <- West (feet) · Eesf (feet) -> 96O 9OO 840 780 720 660 6OO 540 /X 4.20 55O 500 240 120 60 60 120 1BO Z 0 MARATHON Oi 1 Company Pad 41.7 KBU33-6 slot ~KBU33-6 Kenai Gas Field Kenai Peninsula. Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : KBU 33-6 Version#2 Our ref : prop3343 License : Date printed : 9-Mar-99 Date created : 2-Mar-99 Last revised : 9-Mar-99 Field is centred on n60 27 33,151,w151 16 7.223 Structure is centred on 270908.300.2362070.010,999.00000,N Slot location is n60 27 33.892.w151 14 47.869 Slot Grid coordinates are N 2361974.310, E 274973.220 Slot local coordinates are 17.35 S 4066.17 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company Pad 41-7,KBU33-6 Kenai Gas Field,Kenai Peninsula. Alaska PROPOSAL LISTING Page 1 Your ref : KBU 33-6 Version#2 Last revised : 9-Mar-99 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 0.00 0.00 0.00 0.00 100.00 0.00 345,50 100.00 200.00 0.00 345.50 200.00 300.00 0.00 345.50 300.00 400.00 0.00 345.50 400.00 0.00 N 0.00 W 0.00 0.00 0.00 N 0,00 W 0.00 0.00 0.00 N 0.00 W 0.00 0.00 0.00 N 0.00 W 0.00 0.00 0.00 N 0.00 W 0.00 0.00 500.00 0.00 345.50 500.00 0.00 N 0.00 W 0.00 0.00 600.00 0.00 345.50 600.00 0.00 N 0.00 W 0.00 0.00 KOP 700.00 2.50 345.50 699.97 2.11 N 0.55 W 2.50 2.18 800.00 5.00 345.50 799.75 8.44 N 2.18 W 2.50 8.70 900.00 7.50 345.50 899.14 18.98 N 4.91 W 2.50 19.56 1000.00 10.00 345.50 997.97 33.71 N 8.72 W 2.50 34.73 1100.00 12.50 345.50 1096.04 52.60 N 13.60 W 2,50 54.19 1200,00 15.00 345,50 1193.17 75.61 N 19.55 W 2.50 77.90 1300.00 17.50 345.50 1289.17 102.70 N 26.55 W 2.50 105.81 1400.00 20.00 345.50 1383.85 133.81 N 34.60 W 2.50 137.87 1500.00 22.50 345.50 1477.05 168.90 N 43.67 W 2.50 1600.00 25.00 345.50 1568.57 207.89 N 53.75 W 2.50 1700.00 27.50 345.50 1658.25 250.71 N 64.82 W 2.50 1763.24 29.08 345.50 1713.93 279.72 N 72.32 W 2.50 2000.00 29.08 345.50 1920.85 391.14 N 101.13 W 0.00 174.02 214.20 258.31 288.21 EOC - 13 3/8" CSG Pt 403.00 2500.00 29.08 345.50 2357.81 626.42 N 161.97 W 0.00 3000.00 29.08 345.50 2794.78 861.71 N 222.80 W 0.00 3500.00 29.08 345.50 3231.75 1096,99 N 283.64 W 0.00 4000.00 29.08 345.50 3668.72 1332.28 N 344.47 W 0.00 4408.04 29.08 345.50 4025.31 1524.29 N 394.12 W 0.00 645.42 887.84 1130.26 1372.68 1570.52 Begin Angle Drop 4500.00 27.92 343.95 4106.13 1566.61 N 405.67 W 1,50 4600.00 26.68 342.12 4195.00 1610.48 N 419.03 W 1.50 4700.00 25.46 340.12 4284.82 1652.05 N 433.24 W 1.50 4800.00 24.27 337.94 4375.55 1691.31 N 448.26 W 1.50 4900.00 23.12 335,55 4467.13 1728.23 N 464.11 W 1.50 1614,32 1660.16 1704.09 1746.09 1786.14 5000.00 22.00 332.94 4559.48 1762.79 N 480.76 W 1.50 5100.00 20.93 330.06 4652.54 1794.95 N 498.20 W 1.50 5200.00 19.92 326.89 4746.25 1824.70 N 516.42 W 1.50 5300.00 18.96 323,41 4840.55 1852.02 N 535.41 W 1,50 5400.00 18.08 319.60 4935.38 1876.88 N 555.15 W 1.50 1824.19 1860.23 1894.22 1926.16 1956.01 5500,00 17.28 315.42 5030.65 1899.28 N 575.64 W 1.50 5600.00 16.58 310.87 5126.33 1919.20 N 596.85 W 1.50 5700.00 15.98 305.96 5222,32 1936.61 N 618.78 W 1.50 5767.22 15.64 302.47 5287.00 t946.91 N 633.91 W 1.50 5870.96 15.64 302.47 5386.90 1961.92 N 657.51 W 0.00 1983.76 2009.38 2032.86 2047.43 End Angle Drop 2069.17 9 5/8" Casing Pt 5871.06 15.64 302.47 5387.00 1961.94 N 657.53 W 5900.00 15.64 302.47 5414.86 1966.13 N 664.11 W 6000.00 15.64 302.47 5511.16 1980.60 N 686.86 W 6100.00 15.64 302.47 5607.46 1995.07 N 709.60 W 6200.00 15.64 302.47 5703.76 2009.55 N 732.34 W 0.00 2069.19 KBU33-6 Top Mid Beluga 0.00 2075.25 0.00 2096.20 0.00 2117.15 0.00 2138,10 6300.00 15.64 302.47 5800.05 2024.02 N 755.09 W 0.00 2159,05 6400.00 15.64 302.47 5896.35 2038.49 N 777.83 W 0.00 2180.00 6500.00 15.64 302.47 5992.65 2052.96 N 800.58 W 0.00 2200.95 6600.00 15.64 302.47 6088,95 2067.44 N 823.32 W 0.00 2221.90 6700.00 15.64 302.47 6185.25 2081.91 N 846.06 W 0.00 2242.85 All data is in feet unless otherwise stated. Coordinates from slot ~i<BU33-6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oi 1 Company Pad 41- 7. KBU33- 6 Kenai Gas FieldoKenai Peninsula. Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : KBU 33-6 Version#2 Last revised : 9-Mar-99 Dogleg Vert Deg/lOOft Sect 6800.00 15.64 302.47 6281.54 2096.38 N 868.81 W 0.00 2263.80 6900.00 15.64 302.47 6377.84 2110.86 N 891.55 W 0.00 2284.75 7000.00 15.64 302.47 6474.14 2125.33 N 914.30 W 0.00 2305.70 7100.00 15.64 302.47 6570.44 2139.80 N 937.04 W 0.00 2326.65 7200.00 15.64 302.47 6666.73 2154.28 N 959.78 W 0.00 2347.60 7300.00 15.64 302.47 6763.03 2168.75 N 982.52 W 0.00 2368.55 7400.00 15.64 302.47 6859.33 2183.22 N 1005.27 W 0.00 2389.50 7500.00 15.64 302.47 6955.63 2197.69 N 1028.01 W 0.00 2410.45 7600.00 15.64 302.47 7051.93 2212.17 N 1050.75 W 0.00 2431.40 7700.00 15.64 302.47 7148.22 2226.64 N 1073.50 W 0.00 2452.35 7800.00 15.64 302.47 7244.52 2241.11N 1096.24 W 0.00 2473.30 7805.69 15.64 302.47 7250.00 2241.93 N 1097.53 W 0.00 2474.49 NorthWest BH 8000.00 15.64 302.47 7437.12 2270.06 N 1141.72 W 0.00 2515.20 8065.30 15.64 302.47 7500.00 2279.51N 1156,57 W 0.00 2528.88 TD - 7" Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #KBU33-6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MAPJkTHON Oil Company Pad 41-7.KBU33-6 Kenai Gas Field. Kenai Peninsula. Alaska PROPOSAL LISTING Page 3 Your ref : KBU 33-6 Version #2 Last revised : 9-Mar-99 Comments in wellpath MD TVD Rectangular Coords. Comment 600.00 600.00 0.00 N 1763.24 1713.93 279.72 N 4408.04 4025.31 1524.29 N 5767.22 5287.00 1946.91 N 5870.96 5386.90 1961.92 N 5871.06 5387.00 1961.94 N 7805.69 7250.00 2241.93 N 8065.30 7500.00 2279.51 N 0~00 W KOP 72.32 W EOC - 13 3/8" CSG Pt 394.12 W Begin Angle Drop 633.91 W End Angle Drop 657.51W 9 5/8" Casing Pt 657.53 W KBU33-6 Top Mid Beluga 1097.53 W NorthWest BH 1156.57 W TD - 7" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOW 1763.24 1713.93 279.72N 72.32W 13 3/8" Casing 0.00 0.00 O.OON O.OOW 5871.06 5387.00 1961.94N 657.53W 9 5/8" Casing 0.00 0.00 O.OON O.OOW 8065.30 7500.00 2279.51N 1156.57W 7" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised KBU33-6 Top Mid Belu 274353.646.2363948.475.0.0000 5387.00 1961.94N 657.53W 27-Jan-99 NorthWest BH 273919.139.2364236.887.0.0000 7250.00 2241.93N 1097.53W 27-Jan-99 MARATHON Oil Company Pad 41-7.KBU33-6 Kenai Gas Field,Kenai Peninsula. Alaska Measured Inclin, Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 17.35 S 4066.17 E 100.00 0.00 345.50 100.00 17.35 S 4066.17 E 200.00 0.00 345.50 200.00 17.35 S 4066.17 E 300.00 0.00 345.50 300.00 17.35 S 4066.17 E 400.00 0.00 345.50 400.00 17.35 S 4066.17 E 500.00 0.00 345.50 500.00 17.35 S 4066.17 E 600.00 0.00 345.50 600.00 17.35 S 4066.17 E 700.00 2.50 345.50 699.97 15.24 S 4065,63 E 800.00 5.00 345.50 799.75 8.90 S 4063.99 E 900.00 7.50 345.50 899.14 1.63 N 4061,26 E 1000.00 10.00 345.50 997.97 16.36 N 4057.46 E 1100.00 12.50 345.50 1096.04 35.25 N 4052.57 E 1200.00 15.00 345.50 1193.17 58.26 N 4046.62 E 1300.00 17.50 345.50 1289.17 85.35 N 4039.62 E 1400.00 20.00 345.50 1383.85 116.47 N 4031.57 E 1500.00 22.50 345.50 1477.05 151.55 N 4022.50 E 1600.00 25.00 345.50 1568.57 190.54 N 4012.42 E 1700.00 27.50 345.50 1658.25 233.36 N 4001.35 E 1763,24 29.08 345.50 1713.93 262.38 N 3993.85 E 2000.00 29.08 345.50 1920.85 373.79 N 3965.04 E 2500.00 29.08 345.50 2357.81 609.07 N 3904.21 E 3000.00 29.08 345.50 2794,78 844,36 N 3843.37 E 3500.00 29.08 345.50 3231.75 1079.64 N 3782.54 E 4000.00 29.08 345.50 3668.72 1314,93 N 3721.70 E 4408.04 29.08 345.50 4025.31 1506.94 N 3672.06 E 4500.00 27.92 343.95 4106.13 1549.27 N 3660.51 E 4600,00 26.68 342.12 4195,00 1593.13 N 3647.14 E 4700.00 25,46 340.12 4284.82 1634.70 N 3632.94 E 4800.00 24.27 337.94 4375.55 1673.97 N 3617.91 E 4900.00 23.12 335.55 4467.13 1710.89 N 3602.07 E 5000.00 22.00 332.94 4559.48 1745.44 N 3585.42 E 5100.00 20.93 330.06 4652.54 1777.60 N 3567.98 E 5200.00 19.92 326.89 4746.25 1807.35 N 3549.76 E 5300.00 18.96 323.41 4840,55 1834.67 N 3530.77 E 5400.00 18.08 319.60 4935.38 1859.54 N 3511.02 E 5500.00 17.28 315.42 5030,65 1881.93 N 3490.54 E 5600.00 !6.58 310.87 5126.33 1901.85 N 3469.32 E 5700.00 15,98 305.96 5222.32 1919.26 N 3447.40 E 5767.22 15.64 302.47 5287.00 1929.56 N 3432.26 E 5870.96 15.64 302.47 5386,90 1944.57 N 3408.67 E 5871.06 15.64 302.47 5387.00 1944.59 N 3408.64 E 5900.00 15.64 302.47 5414.86 1948.78 N 3402.06 E 6000.00 15.64 302.47 5511,16 1963.25 N 3379.32 E 6100,00 15.64 302.47 5607.46 1977.72 N 3356.57 E 6200.00 15.64 302.47 5703.76 1992.20 N 3333.83 E 6300.00 15.64 302.47 5800.05 2006,67 N 3311.08 E 6400.00 15.64 302.47 5896.35 2021.14 N 3288.34 E 6500.00 15.64 302.47 5992.65 2035.62 N 3265.60 E 6600,00 15.64 302.47 6088.95 2050.09 N 3242.85 E 6700.00 15.64 302.47 6185.25 2064,56 N 3220,11 E PROPOSAL LISTING Page 1 Your ref : KBU 33-6 Version #2 Last revised : 9-Mar-99 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 2.50 2.18 2.50 8.70 2.50 19.56 2.50 34.73 2.50 54.19 2.50 77.90 2.50 105.81 2.50 137.87 2.50 174.02 2.50 214.20 2.50 258.31 2.50 288.21 EOC - 13 3/8" CSG Pt 0.00 403.00 0.00 645.42 0.00 887.84 0.00 1130,26 0.00 1372.68 0.00 1570.52 Begin Angle Drop 1.50 1614.32 1,50 1660.16 1.50 1704.09 1.50 1746.09 1.50 1786.14 1.50 1824.19 1.50 1860.23 1.50 1894.22 1.50 1926.16 1.50 1956.01 1.50 1983.76 1.50 2009.38 1.50 2032.86 1.50 2047.43 End Angle Drop 0.00 2069.17 9 5/8" Casing Pt 0.00 2069.19 KBU33-6 Top Mid Beluga 0.00 2075.25 0.00 2096.20 0.00 2117.15 0.00 2138.10 0.00 2159.05 0.00 2180.00 0,00 2200.95 0.00 2221.90 0.00 2242.85 All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 7. T4N. R11W, SM and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7.KBU33-6 Kenai Gas Field. Kenai Peninsula. Alaska PROPOSAL LISTING Page 2 Your ref : KBU 33-6 Version #2 Last revised : 9-Mar-99 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 6800.00 15.64 302.47 6281.54 2079.04 N 3197.36 E 0.00 2263.80 6900.00 15,64 302.47 6377.84 2093.51 N 3174.62 E 0.00 2284.75 7000.00 15.64 302.47 6474.14 2107.98 N 3151.88 E 0.00 2305.70 7100.00 15.64 302.47 6570.44 2122.45 N 3129.13 E 0.00 2326.65 7200.00 15.64 302.47 6666.73 2136.93 N 3106.39 E 0.00 2347.60 7300.00 15.64 302.47 6763.03 2151.40 N 3083.65 E 0.00 2368.55 7400.00 15.64 302.47 6859.33 2165.87 N 3060.91 E 0.00 2389.50 7500.00 15.64 302.47 6955,63 2180.35 N 3038.16 E 0.00 2410.45 7600.00 15.64 302.47 7051.93 2194.82 N 3015.42 E 0,00 2431.40 7700.00 15.64 302.47 7148,22 2209.29 N 2992.68 E 0.00 2452.35 7800.00 15.64 302.47 7244.52 2223.76 N 2969.94 E 0.00 2473.30 7805.69 15.64 302,47 7250.00 2224.59 N 2968.64 E 0.00 2474.49 NorthWest BH 8000.00 15.64 302.47 7437.12 2252.71N 2924.45 E 0.00 2515.20 8065.30 15.64 302.47 7500,00 2262.16 N 2909.60 E 0.00 2528.88 TD - 7" Casing Pt All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 7. T4N, R11W. SM and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7.KBU33-6 Kenai Gas Field. Kenai Peninsula. Alaska PROPOSAL LISTING Page 3 Your ref : KBU 33-6 Version #2 Last revised : 9-Mar-99 Con~nents in wellpath _ _ MD TVD Rectangular Coords. Con~nent 600.00 600.00 17.35 S 4066~17 E KOP 1763.24 1713.93 262.38 N 3993.85 EEOC - 13 3/8" CSG Pt ~408.04 4025.31 1506.94 N 3672.06 E Begin Angle Drop 5767.22 5287.00 1929.56 N 3432.26 E End Angle Drop 5870.96 5386.90 1944.57 N 3408.67 E 9 5/8" Casing Pt 5871.06 5387.00 1944.59 N 3408.64 E KBU33-6 Top Mid Beluga 7805.69 7250.00 2224.59 N 2968.64 E NorthWest BH 8065.30 7500.00 2262.16 N 2909.60 ETD - 7" Casing Pt Casing positions in string 'A' L , Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 17.35S 4066.17E 1763.24 1713.93 262.38N 3993.85E 13 3/8" Casing 0.00 0.00 17.35S 4066.17E 5871.06 5387.00 1944.59N 3408.64E 9 5/8" Casing 0.00 0.00 17.35S 4066.17E 8065.30 7500.00 2262.16N 2909.60E 7" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised KBU33-6 Top Mid Belu 274353.646.2363948.475.0.0000 5387.00 1944.59N 3408.64E 27-Jan-99 NorthWest BH 273919.139.2364236.887.0.0000 7250.00 2224.59N 2968.64E 27-Jan-99 MARATHON Oil Company Pad 41-7.KBU33-6 Kenai Gas Field. Kenai Peninsula, Alaska PROPOSAL LISTING Page 1 Your ref : KBU 33~6 Version #2 Last revised : 9-Mar-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 0.00 0.00 0.00 0.00 O,OON O.OOW 0.00 0.00 274973.22 2361974.31 100.00 0.00 345.50 100.00 O.OON O.OOW 0.00 0.00 274973.22 2361974.31 200,00 0.00 345.50 200.00 O:OON O.OOW 0.00 0.00 274973.22 2361974.31 300.00 0.00 345.50 300.00 O.OON O.OOW 0.00 0.00 274973.22 2361974.31 400.00 0.00 345.50 400.00 O.OON O.OOW 0.00 0.00 274973.22 2361974.31 500.00 0.00 345.50 500.00 O.OON O.OOW 0.00 0.00 274973.22 2361974.31 600.00 0.00 345,50 600.00 O.OON O.OOW 0.00 0.00 274973.22 2361974.31 700.00 2.50 345.50 699.97 2.11N 0.55W 2.50 2.18 274972.71 2361976.43 800.00 5.00 345.50 799.75 8.44N 2.18W 2.50 8.70 274971.20 2361982.79 900.00 7.50 345.50 899.14 18.98N 4.91W 2.50 19.56 274968.68 2361993.38 1000.00 10.00 345.50 997.97 33.71N 8.72W 2.50 34.73 274965.16 2362008.18 1100,00 12.50 345.50 1096.04 52.60N 13.60W 2.50 54.19 274960.64 2362027.16 1200.00 15.00 345.50 1193.17 75.61N 19.55W 2.50 77.90 274955.13 2362050,28 1300.00 17.50 345.50 1289.17 102.70N 26.55W 2.50 105,81 274948.65 2362077.49 1400.00 20.00 345.50 1383,85 133.81N 34.60W 2.50 137.87 274941.21 2362108.76 1500.00 22.50 345.50 1477.05 168.90N 43.67W 2.50 174.02 274932.81 2362144.01 1600.00 25.00 345.50 1568.57 207.89N 53.75W 2.50 214.20 274923.49 2362183.19 1700.00 27.50 345.50 1658.25 250.71N 64.82W 2.50 258.31 274913.24 2362226.21 1763.24 29.08 345.50 1713.93 279.72N 72,32W 2.50 288.21 274906.30 2362255.36 2000.00 29.08 345.50 1920.85 391.14N 101.13W 0.00 403.00 274879.65 2362367.31 2500,00 29.08 345.50 2357.81 626.42N 161.9~ 0.00 645.42 274823.36 2362603.71 3000.00 29.08 345.50 2794.78 861.71N 222.80W 0.00 887.84 274767.07 2362840,11 3500.00 29.08 345.50 3231.75 1096.99N 283,64W 0.00 1130.26 274710.79 2363076.52 4000.00 29.08 345,50 3668.72 1332,28N 344.47W 0.00 1372.68 274654.50 2363312.92 4408.04 29,08 345.50 4025.31 1524.29N 394.12W 0.00 1570.52 274608.56 2363505.85 4500.00 27.92 343.95 4106.13 1566.61N 405.67W 1.50 1614.32 274597.83 2363548.39 4600.00 26.68 342.12 4195.00 1610.48N 419.03W 1.50 1660.16 274585.32 2363592.50 4700.00 25.46 340.12 4284.82 1652.05N 433.24W 1.50 1704.09 274571.92 2363634.34 4800.00 24.27 337.94 4375.55 1691.31N 448.26W 1.50 1746.09 274557.65 2363673.88 4900.00 23,12 335.55 4467.13 1728.23N 464.11W 1.50 1786.14 274542.52 2363711.10 5000.00 22.00 332.94 4559.48 1762.79N 480.76W 1.50 1824.19 274526.54 2363745.96 5100.00 20.93 330.06 4652.54 1794.95N 498.20W 1.50 1860.23 274509.73 2363778.46 5200.00 19.92 326.89 4746,25 1824.70N 516.42W 1.50 1894.22 274492.08 2363808.55 5300.00 18.96 323.41 4840.55 1852.02N 535.41W 1.50 1926.16 274473.62 2363836.23 5400.00 18.08 319.60 4935.38 1876.88N 555.15W 1.50 1956.01 274454.36 2363861.47 5500.00 17.28 315.42 5030.65 1899,28N 575.64W 1.50 1983.76 274434.31 2363884.26 5600.00 16.58 310.87 5126.33 1919.20N 596.85W 1.50 2009.38 274413,49 2363904.57 5700.00 15.98 305.96 5222.32 1936.61N 618.78W 1.50 2032.86 274391.90 2363922.41 5767.22 15.64 302.47 5287.00 1946.91N 633,91W 1.50 2047,43 274376.97 2363932.99 5870.96 15.64 302.47 5386.90 1961.92N 657,51W 0.00 2069,17 274353.67 2363948,46 5871.06 15.64 302,47 5387.00 1961.94N 657.53W 0.00 2069.19 274353.65 2363948.47 5900.00 15.64 302.47 5414.86 1966.13N 664.11W 0.00 2075.25 274347.15 2363952.79 6000.00 15.64 302,47 5511.16 1980.60N 686.86W 0.00 2096.20 274324.69 2363967,70 6100.00 15.64 302.47 5607.46 1995.07N 709,60W 0.00 2117.15 274302.23 2363982.61 6200.00 15.64 302,47 5703.76 2009.55N 732.34W 0.00 2138,10 274279,77 2363997.51 6300.00 15.64 302.47 5800.05 2024.02N 755.09W 0.00 2159.05 274257.30 2364012.42 6400.00 15.64 302.47 5896.35 2038.49N 777.83W 0.00 2180.00 274234.84 2364027.33 6500.00 15.64 302.47 5992.65 2052.96N 800.58W 0.00 2200.95 274212.38 2364042.24 6600.00 15.64 302.47 6088.95 2067.44N 823.32W 0.00 2221.90 274189.93 2364057.15 6700.00 15.64 302,47 6185.25 2081.91N 846.06W 0.00 2242.85 274167.47 2364072.05 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU33-6 and TVD from Est. RKB (87,00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~ MARATHON Oil Company Pad 41-7,KBU33o6 Kenai Gas Field.Kenai Peninsula. A1 Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 6800.00 15.64 302.47 6281.54 6900.00 15.64 302.47 6377.84 7000,00 15.64 302.47 6474.14 7100.00 15.64 302.47 6570.44 7200,00 15.64 302.47 6666.73 7300.00 15.64 302.47 6763.03 7400.00 15.64 302.47 6859.33 7500.00 15.64 302,47 6955.63 7600.00 15.64 302.47 7051.93 7700.00 15.64 302.47 7148.22 7800.00 15.64 302.47 7244.52 7805.69 15.64 302.47 7250.00 8000.00 15.64 302.47 7437.12 8065.30 15.64 302.47 7500.00 aska RECTANGULAR COORDINATES PROPOSAL LISTING Page 2 Your ref : KBU 33-6 Version#2 Last revised : 9-Mar-g9 Dogleg Vert G R I D C 0 0 R D S Deg/lOOft Sect Easting Northing 2096.38N 868.81W 0.00 2263.80 274145.01 2364086.96 2110.86N 891.55W 0.00 2284.75 274122.55 2364101.87 2125,,33N 914.30W 0.00 2305.70 274100.09 2364116.78 2139.80N 937.04W 0.00 2326.65 274077.63 2364131.69 2154,28N 959.78W 0.00 2347.60 274055.17 2364146.59 2168.75N 982.52W 0.00 2368.55 274032.71 2364161.50 2183.22N 1005.27W 0.00 2389.50 274010,25 2364176.41 2197.69N 1028.01W 0.00 2410.45 273987.79 2364191.32 2212.17N 1050.75W 0.00 2431.40 273965.33 2364206.22 2226.64N 1073.50W 0.00 2452.35 273942.87 2364221.13 2241.11N 1096.24W 0.00 2473.30 273920.42 2364236.04 2241.93N 1097.53W 0.00 2474.49 273919.14 2364236,89 2270.06N 1141.72W 0.00 2515.20 273875.50 2364265.85 2279.51N 1156.57W 0.00 2528.88 273860.83 2364275.59 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KBU33.6 and TVD from Est. RKB (87.00 Ft above mean sea level). Bottom hole distance is 2556.13 on azimuth 333.10 degrees from wellhead. Total Dogleg for wellpath is 49.47 degrees. Vertical section is from wellhead on azimuth 341.47 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ MARATHON Oil Company Pad 41-7,KBU33-6 Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref : KBU 33-6 Version #2 Last revised : 9-Mar-99 Comments i n wel 1 path _ _ MD TVD Rectangular Coords. Con~nent 600.00 600,00 O.OON 1763,24 1713,93 279,72N 4408,04 4025,31 1524,29N 5767,22 5287,00 1946,91N 5870,96 5386,90 1961.92N 5871,06 5387,00 1961,94N 7805,69 7250,00 2241,93N 8065,30 7500,00 2279,51N O.OOW KOP 72,32W EOC - 13 3/8" CSG Pt 394.12W Begin Angle Drop 633.91W End Angle Drop 657.51W 9 5/8" Casing Pt 657.53W KBU33-6 Top Mid Beluga 1097.53W NorthWest BH 1156.57W TD - 7" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords, Casing .... ~i ~ ..... ~i ~ ........ ~i ~ ........ il ~"i~;~i~"i~i~i¢~ ...... ~¢i~ ...... ~' ~i~"i~'~:.'~;~i;; .... 0,00 0,00 O,OON O.OOW 5871.06 5387,00 1961,94N 657,53W 9 5/8" Casing 0.00 0.00 O.OON O.OOW 8065,30 7500,00 2279,51N 1156.57W 7" Liner Targets associated with this wellpath Target name Geographic Location T.V.D, Rectangular Coordinates Revised KBU33-6 Top Mid Belu 274353,646,2363948.475,0,0000 5387.00 1961,94N 657,53W 27-Jan-99 NorthWest BH 273919.139,2364236.887,0,0000 7250,00 2241,93N 1097,53W 27-Jan-99 KBU 33-8 ESTIMATED TOPS AND PRESSURES* 3/11199 LOWEST PRESSURE LOWEST TOP SSTVD TVD GRAD. PRESSURE STERLING A8 3470 3557 0,08 285 A9 3510 3597 0.08 288 Al0 3535 3622 0.08 290 All 3605 3692 0.08 295 B1 3672 3759 0.08 301 B2 3740 3827 0.08 306 B3 3805 3892 0.08 311 B4 3873 3960 0.08 317 B5 4060 4147 0.31 1286 Cl 4345 4432 0.08 355 C2 4525 4612 0.08 369 BELUGA U1 4575 4662 0.08 373 U2 4625 4712 0.08 377 U3 4665 4752 0.08 380 U4 4683 4770 0.08 382 U5 4725 4812 0.08 385 U6 4785 4872 0.44 2144 U7 4823 4910 0.08 393 U8 4879 4966 0.08 397 U9 4905 4992 0.08 399 U10 4979 5066 0.08 405 Ull 5102 5189 0.08 415 U12 5192 5279 0.08 422 U13 5210 5297 0.44 2331 M1 5230 5317 0.2 1063 M2 5245 5332 0.44 2346 M3 5305 5392 0.2 1078 M4 5350 5437 0.44 2392 M5 5487 5574 0.2 1115 M6 5578 5665 0.2 1133 M7 5625 5712 0.44 2513 M8 5668 5755 0.2 1151 M9 5685 5772 0.44 2540 M10 5713 5800 0.44 2552 M11 5747 5834 0.44 2567 M12 5760 5847 0.44 2573 M13 5776 5863 0.2 1173 M14 5873 5960 0.2 1192 M15 5949 6036 0.44 2656 L1 5957 6044 0.18 1088 1,2 6005 6092 0,46 2802 L3 6052 6139 0.18 1105 L4 6112 6199 0.18 1116 L5/6 6253 6340 0.46 2916 L7 6307 6394 0.46 2941 L8 6394 6481 0.46 2981 L9 6418 6505 0.18 1171 L10 6490 6577 0.18 1184 Lll 6650 6737 0.18 1213 L12 6715 6802 0.18 1224 L13 6795 6882 0.18 1239 L14 6842 6929 0.18 1247 L15 6889 6976 0.46 3209 L16 6947 7034 0.18 1266 L17 6991 7078 0.18 1274 L18 7063 7150 0.18 1287 TYONEK 7130 7217 72-8 7155 7242 0.37 2680 73-1 7200 7287 TOTAL DEPTH 7300 7387 HIGHEST PRESSURE HIGHEST GRAD. PRESSURE 0.25 990 0.11 513 0.11 518 0.11 523 0.11 525 0.11 529 0.11 540 0.11 546 0.11 549 0.11 557 0.11 571 0.11 581 0.44 2339 0.44 2372 0.44 2453 0.44 2493 0.44 2532 0.44 2580 0.44 2622 0.46 2780 0.46 2824 0.46 2852 0.46 2992 0.46 3025 0.46 3099 0.46 3129 0.46 3166 0.46 3187 0.46 3236 0.46 3256 0.46 3289 0.46 332O 0.46 3331 0.46 3352 NEARBY BELUGA COMPLETIONS KB23X-6 KTU 43-6X KTU 13-5 X X x x x CASING POINT *Middle and Lower Beluga depletions possible in zones identified by "X" in the nearby wells. Sterling and Upper Beluga depiefio~s expected across the field. CONTROL Used this horizons structure Used M. Beluga structure and KTU 43-6X well ,, Used L. Beluga $lucture and KTU 43-6X well o:~Beluga SandsV~FE~33_6tops.xls DLB 3/11/99 KBU 33~ Location Kenai Gas Field Alaska Region Top Lower Beluga CI = 100 feet 3/99 O:~eluga Sands 1998LA_FE\Well 33-6\33-61oc.doc DLB 03/15/99 I: 31.I .. ,..%. z' -' T. SN. 13 o _. T \J · .;.~!= J_~:..'~.: ....... / 5 *' .. ~' --~ - r" ' - ..... '?.--Z- .~ '-~: - .,, _ - I :'- ' '1". ~ "7. ' ' ' -"'-" ,4 -- N ~,t .- .~ .... j~_...- j ,-.- .,.,-7. ~,. -,.,:~ .,?_--.~ i'.;- ............ .~i J · I ="' · ...... T~ Gravel, /I o : .... ' i' ~' 30. ~ ..... ~'~-- 28 -;'. Piti ; ~ -=_- '- 25 [ :.':;i :,,~7~o, "- ' ;1 J/Il LiLJ · : i ~ - ~ ' ~ '~ ~ , II '-T--II ,, '% \ ~" ! ': I ] : ~. ,Il I ,, , , , ~~1=[I Ifil J"'' -- "~ '~,' .... I~ ' ~l --~ ~ ............... ×~ "L ...... /// ...... '.. ....~I--L____II_JI.!__~I, Nj' '"' ' ' , :.L I ; / ;"x_JI---t: I :.::-,( //' -- - Unit Bpundary jJ i':i'i.i,.~, gas Wells .. I J ~...; ~ ........ g I ~:..,., . . I ; I !?:i'~\ ""~ ., ! ,::.?i, ,,,,, 'i' '.. -'. .... -~" ~'? ,~ ~ . _.-5. _:.. - .: %' ~ : 3 . ~ I -' - ..:- J ' ~;°"" ,%~o. __. " '~ -":' i.:. J- - "'~ .... ' If: ' °":' '"' '*:" ' .... ' -i~,¢ ..-: ; I !i'~.t .s w,,,,_'. ,,,_~. ~.,-7:: :-: '-'- "J: :.: :'--'~~'1l "~' ' '12' '' .... I ' ; ~ ...... , I i!i:l-,.- . :.~¢ -" . . --..:--'"'. - .-.-: :.._ L.. · -... . j ~ '., : / '" ' ' ':4 :.-'-'; i ·~ . . .; 11 _ T : ' I ~-: ~ ~ I '-.~.-.-:~ '-., ": ; ~._.--.I . I · '.. !,~: j J .:, ',_, ~o .- "'" ~' - J :'q~ "' J .... ~ .: .-7' .% "~, . 4 ,' [ /'~ ' ~ ' I~'- ~4"",'? · ., , ' ............ , ........:" -- ~ '-r-- N ,, · I" ;,,--S ,.,-¢,,';-~ ..-- . ~ ' ."// ~ f ' h -.. -.. ,... /" ' '. -', J' ?; , ";' Y, 'L-'. ',-,'.: ] :" !: ' '.. - -. Ct · ,. // :... ,. ,, ,.... ,: '("~' ' ' * ; ."J fi/~.','. '- - .... L.-'' ' .:!.: ~,,w,,,0 "--~------'~.... :-.'" '"-:~ · . ' ......... '-T ....... "'' ': ! .4 / ~ ~) ~:~ ./':':':" ::i:ii , ... ,,/-..'~ "-'; · ." ..f: ;.~:: :/.' ~ 'r----',o,, w,,, ~...,:..4'--='-._ ~" ,' · ' ~ '.~-- J-~ -4 j :-:'. ': .,"::?;: :.-, 24. La,,.- : '- '"" ' . ../"'?.!;?'2 . - .... --¢ -, · / . ::.:..'j: i,/ ; .... 7- ; ~ "- · ' ./'..- 'i':.":.';1. , . i ' ' /' : h ......... :"":' .!':..: '.ij':'~//r::': '~'- ...... 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DETAIL I I sa[ OETA~L-~~ / gl SEC'm3N 7 Y - Io~ANI' Ilrlthofl 011 0omplny t XIIAI GAl FILD PAD 41-7 I ~1~1,.... i ; ' , , , , . ~ i~m. . i l ~"~"~~m-~ ~*~ ,~-7 0o .o mm o FORM ~2 REV. 4,~7 Marathon Oil Company Ray to the order of: ANCHORAGE~ 013 6 0 Alaska Oil & Gas Conservation Commission 3./15/99 ,'. 3001 Porcupine Drive MO DY YR ii]Li'~]...,An_~h'?age, Alaska~ .. · i' '. ,'!'" :;~:&'':' '"'"": ":' ..:BAY: .. :]~ ... I:: One. hundred and no/lO0 ............. 99501-3192 I MATCH AMOUNT IN WORDS WITH NUMBERS $ loo. oo VOID AFTER 180 DAYS THE AMOUNT IN NUMBERS MUST MATCH THE AMOUNT IN WORDS ............................. DOLLARS 57 ! 1252~ 1 .::;i. :'. :' :. :''/. '. (-- Ma on Oil C mpa "';:/ ""'ANCHORAGE, ALASKA .By/~~ ........................ ..'.: . / .XUTHORIZED SIGNATURE -. . ' ~. .-~.."..~, ',~, ~ ~ ~ ': ;~ i~ 5 i~OO0 5 ?':0 ;~,'0 ? G 5 F: :iii' 013 ;0 ;100 )0 Marathon Oil Company P,O. Box 196168 ALASKA 99519-6168 PERATOR -- TY OR FATE -- -- NON-REPORTING 100% REPORTABLE INTEREST REPORTABLE RENTS INDICATE SERVICES TYPE OF NON-EMPLOYEE COMP. PAYMENT PRIZES. AWARDS, OR DAMAGES Filing Fee for Permit to Drill ..................... Ke'nai'unit KBU 33~6 WELL PERMIT CHECKLIST FIELD & POOL ~/'~ ~" ADMINIST~tATION / - Permit fee attached ................ ' ....... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE INIT CLASS 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. WELL NAME~,t' ,..~_~ - ~ PROGRAM: exp dev ',~ redrll GEOL AREA ?.7 _o serv wellbore seg UNIT# ,j"/l ~_. o ann. disposal para req ON/OFF SHORE 14. Conductor string provided ................... r,~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... (:~fP N 19. Casing designs adequate for C, T, B & permafrost ....... ~) N 20. Adequate tankage or reserve pit ................. ~ N 21. If a re-drill, has a 10-403 for abandonment been approved... -.Y--N-/~JF~- 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... (~ N 24, Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to ~,~._ (:~ psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N 28. Work will occur without operation shutdown ........... (~ N 29, Is presence of H2S gas probable ................. Y ~ GEOLOGY APPR DATE ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~ 31. Data presented on potential overpressure zones ....... ~ ~ / ,/? 32. Seismic analysis of shallow gas zones ............. 33. seabed condition survey (if off-shore) ............. ./~ Y N' ' ' 34. Contact name/phone for weekly progress reports [exploratory/only] Y N 35. With proper cementing records, this plan ~,,,t.~u.p ,~-~,,~ (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQGY: ENGINEERING: UIC/Annular COMMISSIO_..N.L. JDH '~ RNC co ~ Comments/Instructions: 'X,,c:\msoffice\wordian\diana\checklist 0 0
