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184-108
Suspended Well Inspection Review Report InspectNo:susJJ220110145004 Well Pressures (psi): Date Inspected:12/22/2021 Inspector:Jeff Jones If Verified, How?LAT / LONG Suspension Date: Tubing:0 IA:2 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Andy Graves Date AOGCC Notified:12/10/2021 Type of Inspection:Initial Well Name:KENAI TYONEK UNIT 13-05 Permit Number:1841080 Wellhead Condition Wellhead in good condition, valves & gauges in place & operable, no leaks Surrounding Surface Condition Clean gravel pad (frozen) good road access to pad Condition of Cellar Cellar appears clean, no hydrocarbon sheen, frozen water in bottom Comments some well house metal deterioration around base Supervisor Comments Photos (3). No suspension 10-403, 10-404 or well completion report received from Hilcorp. Unclear why the well status was changed in RBDMS to SUSP on 1/22/2021. Suspension Approval: Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, February 2, 2022 :Z͖ϮͬϮͬϮϬϮϮ 2021-1222_Suspend_KTU_13-05_photos_jj.docxPage 1 of 2 Suspended Well Inspection – KTU 13-05 PTD 1841080 AOGCC Inspection # susJJ220110145004 Photos by AOGCC Inspector J. Jones 12/22/2021 Inspection Supervisor Note – There is no record of an approval for suspending this well; no 10-403, 10-404, or Well Completion Report. 9-%5 2021-1222_Suspend_KTU_13-05_photos_jj.docxPage 2 of 2 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: Suspended Well Inspection 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: Total Depth measured 8231 feet 4560, 4950, 8039 feet true vertical 7822 feet NA feet Effective Depth measured 2988 feet 7600, 7707, 7841 feet true vertical 2959 feet 7239, 7341, 7470 feet Perforation depth Measured depth See attached schematic True Vertical depth See attached schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) 3 - Otis GP Pkrs 7600'; 7707'; 7841' MD 7239'; 7341'; 7470' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name:Josh Allely Contact Email:josh.allely@hilcorp.com Authorized Title: Operations Manager Contact Phone: 907-777-8505 N/A Sr Pet Eng: 8,540psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 0 9,020psi measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 000 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 136' 2,500' N/A 0 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-108 50-133-20370-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028142 Kenai Gas Field - Sterling Pool(s) 3, 4 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 3. Address: Kenai Tyonek Unit (KTU) 13-05 Hilcorp Alaska, LLC measuredPlugs Junk measured N/A Length 110' 2,474' Size Conductor Surface Intermediate 20" 13-3/8" 9-5/8" Production Production 8,206' 3,755' 856' Casing 136' 2,401' 7,832' 3,600' 4-1/2" 8,232' 3,755' 4,611' 4,401' 5-1/2" 4,750psi 6,290psi 1,530psi 5,020psi 6,870psi 7,740psi Burst Collapse 520psi 2,260psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 7:24 am, Jan 21, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.01.20 14:48:39 -09'00' Dan Marlowe (1267) RBDMS HEW 1/27/2022 KEN December 2021 Suspended Well Inspection Data Well: KENAI TYONEK UNIT 13-05 Surface Location: 144’ FNL, 4,169’ FWL, Sec. 7, T4N, R11W, S.M. Permit to Drill: 184-108 API: 50-133-20370-00-00 AOGCC Inspection Date: 12/22/21 Size Pressure (psi) Tubing NA Prod CSG 5-1/2” 0 Int CSG 9-5/8” 2 Surface CSG 13-3/8” 0 *Note: Wellhead pressures to be recorded monthly at minimum. x Condition of Wellhead: Good condition, no leaks, valves operable. Cellar clean with frozen water. Wellhouse clean with some corrosion around bottom. x Condition of Surrounding Surface Location: Clean, covered with snow. x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore KEN December 2021 KEN December 2021 KEN December 2021 KEN December 2021 KTU 13-05 S004N011W KENAI UNIT KBU 41-07 KBU 31-07 KBU 31-07RD KBU 42-07 KTU 32-07 KU 31-07X KBU 44-06 KBU 24-06 KBU 41-07X KDU-01 KBU 42-07RD KBU 34-06 KDU 09 KDU 10 KU 14-05 KGF 41-07 Pad Sec. 5Sec. 6 Sec. 8Sec. 7 0 250 500 Feet Alaska State Plane Zone 4, NAD27 Legend Quarter-Mile Radius around SHL Oil and Gas Unit Boundary Map Date: 1/20/2022 KENAI KTU 13-05 Suspended Well 59' FNL, 869' FEL, Sec 7, T4N, R11W, SM, AK Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol Unknown Gas AGas SI Gas P&A SHUT-IN Suspended Document Path: O:\Alaska\GIS\cook_inlet\wells\oil-gas\TRS_Distance\mxd\2022\SuspendedWells\Suspended_Wells_DonnaAmbruz_2022_SHL_DDP_v01.mxd David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 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: 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: Total Depth measured 8,231 feet 4560, 4950, 8039 feet true vertical 7,822 feet NA feet 7600; Effective Depth measured 2,988 feet 7600, 7707, 7841 feet true vertical 2,959 feet 7239, 7341, 7470 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)3 - Otis GP Pkrs 7600'; 7707'; 7841' MD 7239'; 7341'; 7470' TVD 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:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 8,540psiProduction 856'4-1/2"4,611'4,401'9,020psi WINJ WAG 0 Water-Bbl MD 136' 2,500' 0 Oil-Bbl measured true vertical Packer 5-1/2"3,755' 7,832' 3,600' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai Gas Field - Sterling Pool(s) 3, 4N/A measured TVD Tubing Pressure 00 Kenai Tyonek Unit (KTU) 13-05 N/A FEDA028142 8,232' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-108 50-133-20370-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-507 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 110' 2,474' 8,206' 3,755' Conductor Surface Intermediate Production 6,290psi Casing Structural 20" 13-3/8" 9-5/8" Length 6,870psi 5,020psi Collapse 520psi 2,260psi 4,750psi jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 1,530psi 7,740psi 136' 2,401' 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 1:18 pm, Feb 16, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.02.15 11:09:41 -09'00' Taylor Wellman (2143) DSR-2/16/21 RBDMS HEW 2/16/2021 SFD 2/17/2021gls 2/22/21 Rig Start Date End Date Rig 401 12/6/20 1/22/21 01/06/2021- Wednesday MIRU Rig 401, remove flowlines, work on wellhead. 01/07/2021 - Thursday PTSM, Spot rig eq. r/u circulating. lines prep & stand mast, secure same, repair exhaust on Generator,. Check well static, set BPV'S, N/D tree. Prep Wellhead, install blanking subs. N/U 11 x 13-5/8" adaptor spool, mud cross, double gate, annular, install floor, choke & kill line, hand rails. Night watch rig, tq. flanges on BOPE, install cellar winterization, run accumulator lines. 01/08/2021 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 13-05 50-133-20370-00-00 184-108 01/09/2021 - Saturday PTSM, troubleshoot & repair mast lights, pressure up accumulator, function test BOPE good. M/U 2-7/8" tj, & install, r/u gas alarm system & calibrate same good, fill surface eq. & BOPE, work on getting a shell test 250/2,500 good. Finish berming around rig, calibrate PVT good. Test BOPE as per Hilcorp & AOGCC requirements test was witnessed by AOGCC inspector Lou Laubenstein, tested 2-7/8 & 3-1/2" TJ, 250/2,500 good. R/D test eq. break down test joints, m/u landing jt. blow down lines, R/U handling eq. Secure well for night. Night watch rig. PTSM, Blow through surface lines good, check well static, m/u landing jt t/short string hanger, pull l/d pins, pull hanger free @ 35k, cont. wk pipe up, saw collars passing wk up t/ 72k over when came free. R/U attempt to pump down tubing, pressured up t/ 375 psi shut down & held for 5 min w/no bleed off. lined up & pumped down Annulus 102bbls @ 3.2 bpm w/no returns. Break off hanger & landing jt, l/d same, break down landing jt, c/o handling eq. for pulling. POOH f/4,856' l/d 3-1/2" IBT completion. Pulling wet string. t/ 4,137' running cont. fill on annulus. Secure well, repair chain guard on pipe skate & replace swab's on pump. Cont. POOH f/4,137' l/d 3-1/2" IBT completion. Pulling wet string t/ 1,849' up wt 17k, l/d 97 jts total, running cont. fill on annulus filled 430 bbls total, no returns. Blow down lines, night watch rig. 01/10/2021 - Sunday PTSM, Check well, static, Cont. POOH f/1,849' l/d 3-1/2" IBT SS completion, had full recovery. M/U landing jt t/ long string hanger, c/o handling eq. t/ 2-7/8", BOLD pins. Pull hanger off seat @ 20k, cont. pulling staging up t/80k string came free, appears to have 21k hanging. l/d hanger & landing jt. c/o elevators t/2-7/8". POOH w/2-7/8" L-80, 6.5# IBT tubing f/ long string, pulled & l/d 4,978' of tubing, pups, sliding sleeves, packer & 12.21' parted Carbide blast joint on 2- 7/8" tubing, leaving Top of fish @ 5,003', Discuss fishing options with ops Engineer. decide to bring out W/L & fish loose rings from parted blast joint. Blow down lines, & secure well while waiting on W/L to arrive. R/U w/l, p/u 3-1/2" magnet, RIH t/4,984' wlm., POOH recovered several pieces of broken rings. RIH w/3-1/2" magnet, RIH t/4,984' wlm, POOH recovered pieces of broken rings. RIH w/3-1/2" magnet, RIH t/4,984' wlm., POOH recovered small amount of swarf. RIH w/ 6" LIB t/4,984' wlm, POOH had impression of parted tubing stub, Secure well, R/D w/l. Night watch rig. Rig Start Date End Date Rig 401 12/6/20 1/22/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 13-05 50-133-20370-00-00 184-108 01/12/2021 - Tuesday PTSM, TIH p/u 2-7/8" P110 wk string, f/3,901' t/ 5,003' up wt 36k, dn wt 29k. Engage fish, work pipe, start jarring staging up t/ 35kover & pulling staging up t/90k wk for hour stage up t/98k, came free w/ ~2,100# extra weight. POOH standing back 71 stands wk string, l/d 19 jts 2-7/8" wk string,. L/D BHA, stand back 1 stand 4-3/4" DC, l/d rest of BHA t/fish. L/D fish, - 12.29' of parted blast joint w/1" carbide rings, pup jt, 10 full joints, 30.6'parted blast jt w/upper stop no rings = 350.63' leaving top of fish @5,354.57'. RE/U E-line, RIH w/ 7.71" drift t/ 4,980', log up send log to Res for correlation, make adjustment as requested. M/U 9-5/8 CIBP, RIH correlate on depth of 4,950', set plug, drop down & verify good, POOH. Fill hole w/ 325 bbls while r/u 5" dump bailer. RIH to top of CIBP w/ 5" x 40'bailer loaded w/36.87gal 16# class G CMT, p/u t/4,940' dump on plug, POOH. RIH t/4,900' w/ 5" x40'bailer loaded w/36.87gal 16# class G CMT, dump on CIBP, POOH. RIH t/4,860' w/ 5" x 40'bailer loaded w/36.87gal 16# class G CMT, dump on CIBP, POOH, leaving total of 35’ cmt on top of plug, exp top of cmt 4,915’. Break down Bailer, P/U 9-5/8 CIBP. RIH log up & correlate on depth & set @ 4,650', set back down on plug t/verify good, POOH, fill hole 23bbls, r/d e-line. Secure well, night watch rig. 01/11/2021 - Monday PTSM, Service rig, unload & spot CMT silo, compressor & 400 bbl upright tank, unload & strap 2-7/8" P110, PH6 wk string. Unload & prep fishing tools, c/o handling tools for p/u BHA. P/U BHA #1, - Skirted spear, xo sub, bumper sub, 2- 4 3/4" DC, Jars, xo sub = 94.74'. TIH p/u 2-7/8" P110 wk string, t/3,901' up wt 30k, dn wt 27k. Night watch rig 01/13/2021 - Wednesday Conduct Safety Meeting with crew, emphasis on RIH with RTTS, working on wellhead. Conduct equipment checks. Open to well, no pressure and fluid at surface. Prep location to run work string with Drill Collars. Make up 8 Drill Collars, RIH on 2-7/8" workstring. PUW 35k, SOW 29k. Crossover to RTTS Packer and hang off at 120'. Set packer per Halliburton rep. Rig up to pressure test below packer. Fill pipe, begin to pressure up, generator failure shut down all equipment. Troubleshoot, start test over. Pressure test to 500 psi, solid test with no bleed. POH with 4 joints of workstring and RTTS running tool. Lay down same. Clear and clean rig floor. Remove pipe skate, prep for ND of BOP and Casing spool. Empty cellar of water. Rig up torque wrench. Turn over to night watch. Night watch team to monitor well, begin breaking bolts on BOP and on Casing spool (leaving them in place for removal in morning). 01/14/2021 - Thursday Safety Meeting with crew, emphasis on monitoring well during ND of BOP and Casing spool. Conduct equipment checks. Remove rig floor. ND BOP and Casing spool. Dress base flange to prep for new casing spool. NU new casing spool to BOP, set on to base flange, NU and torque to spec. Concurrent Ops: welder on location making improvements to rig floor. Move in and install rig floor. Install windwalls and stairs, Install tarps around cellar. MU test joint, conduct function test of BOP. Shell test BOP, good test. Blow down circulation lines. Turn location over to Night Watch. Did they test lower flange of new casing spool? Rig Start Date End Date Rig 401 12/6/20 1/22/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 13-05 50-133-20370-00-00 184-108 01/15/2021- Friday Safety Meeting with crew, emphasis on pressure control while testing BOP, prepping for pulling RTTS and workstring. Check equipment. Line up for BOP test. Test BOP with 2-7/8" and 5-1/2" test joints to 250 psi low / 2,500 psi high, conduct accumulator drawdown. Witness waived by AOGCC. RD and clean up test equipment. Prep location for pulling workstring. Pick up landing joint and pull test plug. RIH with 2-7/8" joints, engage RTTS, release and POH. LD RTTS and work string. Hand location over to Night Watch. Night Watch stage in Lay Down machine (Skate), stage over 12 jts of 4- 1/2" to include float equipment, move out joints that will not be run from remaining 4-1/2". 01/16/2021 - Saturday Safety Meeting with crew and Weatherford casing crew, emphasis on working with third party during casing MU. Check equipment and fuel levels. Clear rig floor, mobilize in casing running equipment. Confirm pipe layout. MU and RIH with 4-1/2" liner track: 11 jts 4-1/2" 13.5# L-80 BTC with Float Collar and Shoe track (BakerLok). Fill and check float, good function. Full XO jt to VAMTOP and run 8 jts of 4-1/2" VAM. Floating Centralizers on all 4-1/2" jts. MU XO from 4-1/2" to 5-1/2" with integral 4" PBR. MU and RIH with 91 jts of 5-1/2" 17# L-80 CDC HTQ casing (total 111 jts run). MU Fluted hanger assembly on landing joint, land out completion. Final PUW 53k, SOW 45.5k. Set packoff, RILDS. RU for circulation long ways and taking returns through annulus valve to ensure good circulation path for cement job. Turn operations over to Night Watch. Night Watch move out lay down machine, stage in cementing auxiliary pump unit, circulate around to ensure lines are good throughout night. 01/17/2021 - Sunday Safety Meeting with crew and Halliburton cementers, emphasis on monitoring for leaks, high pressure pumping, noise levels. Conduct equipment checks. Stage in cementing equipment, rig up cement head at floor, MU hoses. Circulate through system, all good. Pressure test to low kickout, test to 4,000 psi high to trips. Conduct cement operations per schedule: fresh water ahead, 163 bbls of 12.0 ppg lead cement, 67 bbls of 15.3 ppg tail cement chased by plug and displaced with fresh water. Plug landed, pressure up 500 psi over circ pressure and hold. Floats held. CIP at 1235 hrs. RD cementing unit. Crew beginning to remove flange bolts, cleaning up from cement job. Flow check well, all static from Annulus and casing string. Set TWC. Remove remainder of flange bolts. Remove stairs and rig floor. ND BOP from Casing Spool. NU new tubing spool to BOP, set back into place on Casing Spool. Install bolts, torque to spec. Test flange connection and against packoff. Conduct shell test against BOP and new spool against TWC in Casing Spool. Install rig floor, pull TWC, hang tarps around cellar. Turn over location to Night Watch crew. Night Watch to prep location for RU Slickline unit. ?????????????? RIH with casing . This cement job did not go as planned.... 5 1/2" tubing packoff shifted and short circuited the cement . TOC not as expected. gls . Rig Start Date End Date Rig 401 12/6/20 1/22/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 13-05 50-133-20370-00-00 184-108 01/18/2021 - Monday Safety Meeting with crew, emphasis on poor weather conditions, Slickline runs. Spot in and RU Slickline unit. RIH with BHA to tag PBTD. Tag early at 2,811'. Confirm set down, spang into plug several times, moved 4'. Call out to shop, have LIB and centralizers sent out. MU, RIH with Swage, centralizer and additional weight bars (190 lbs). Attempt to pound down, no movement. POH and RD Slickline unit. Order out BHA from Yellow Jacket. Crew mobilizing 2-7/8" work string, strap. Stage in and RU lay down machine / skate. Move workstring and load onto stands for pick up. Mobilize tongs to floor, change out dies in tongs. Prep slips and elevators. Waiting on trucking of BHA to arrive. Offload truck. MU milling BHA: 4.79" Insert Junk Mill, Mud Motor, Bumper Sub, Jar, 4 drill collars. Install head pin, surface test motor at 3 bpm. RIH with BHA on 2-7/8" workstring. Hang off workstring in stack for evening, secure well. Turn location over to night watch crew for remainder of evening. 01/19/2021 - Tuesday Safety Meeting with crew, emphasis on ground conditions, RIH with milling BHA. Inspect equipment. Open up to well, static. RIH with Milling BHA #1 on 2-7/8" workstring, hard tag at ,2814'. Line out circulation path and cuttings box during trip. Begin milling operations: circ rate of 2.5 bpm, free spin rate of 840-850 psi, slack off to engage mill at 1-3k down weight. Differential of 30-60 psi, milling quickly. Good returns with fine ground cement coming back. Pump hi-vis sweep every 90'. Diff increased, ROP slowed 100' into milling (2,918'). Increased Diff at 2,941', torquing the pipe, large chunks rubber across shaker. Have to stop circ, PU to unwrap Kelly hose. Pump down Hi-Vis pill, circ around until returns are clean. POH with workstring and stand back 2 stands. Blow down, secure well. Turn over to Night Watch to monitor location. 01/20/2021 - Wednesday Safety meeting with crew, emphasis on monitoring milling operations, monitoring fluids, and proper torque on the workstring. Inspect equipment, check fluids, blow through with air to ensure lines are good. PU the two stands stood back last night, MU Kelly Hose. Break circulation, check lines, good returns. Begin milling operations with Milling BHA #1 from 2,941'. Circ rate 2.5 bpm, free spin 800 psi. Differential pressure range from 840-930 psi. Consistent rubber across shaker, rubber returned with each sweep. Vary down weight from .5-6k, maintain constant 2.5 bpm, Differential as high as 980 psi. Mill to 2,955' with slow progress. POH (wet) to swap over to tri-cone bit, stand back workstring and BHA. Swap out elevators to handle BHA. MU Milling BHA #2: 4-3/4" medium mill tooth roller cone bit, 3-1/8" mud motor, bumper sub, oil jar, 4 each drill collars. Swap out elevators to handle elevators. RIH with BHA #2 on 2-7/8" workstring. Resume milling operations with Milling BHA #2 from 2,955'. Circ rate 2.5 bpm, free spin 800 psi. Differential pressure range from 820-850 psi. No rubber seen across shaker. Vary down weight from .5-2k (going light to avoid torque turn), maintain constant 2.5 bpm. Mill to 2,988'. Pump Hi-Vis sweep, circ all the way around. Pick up 60' off bottom. Turn well over to Night Watch. They will break circulation each hour and then stage BHA to bottom for us to resume milling immediately in the morning. Rig Start Date End Date Rig 401 12/6/20 1/22/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KTU 13-05 50-133-20370-00-00 184-108 01/21/2021 - Thursday Safety Meeting with crew, discussed milling operations with new crew. Mill ahead with Milling BHA #2. Circ rate of 2.5 bpm, free spin ~800 psi, Differential psi 840 psi. Mill progress to 2,976' md (RKB of 14.7'). Received call from town, decision made to move off of well. Prep to POH with workstring. Clear floor, blow down lines. POH and lay down singles of the 2-7/8" work string. Pull and lay down BHA. Begin rig down process, cleaning up location, staging equipment, preparing for ND of BOP. Concurrent ops: test cemented liner to 2,500 psi for 30 min on chart - good test. Turn location over to Night Watch. They will continue with RD of hoses, staging equipment, have BOP prepped for ND. 01/22/2021 - Friday Safety Meeting with crew, emphasis on overhead lifts, pad conditions, energized systems. ND BOP. Concurrent ops: RD pit system, break down circulation lines, RD hydraulic lines. RU dry hole tree. Pressure test to 2,500 psi. Continue with ND and RD of equipment. Trailer equipment and mobilize to Paxton pad as trailers get full. SCHEMATIC Well Name: County or Parish:USA Perforations: (MD) Angle/Perfs:KOP TVD: Date Completed: Revised By: Kenai Tyonek Unit 13-5 Kenai Peninsula Borough 4,987'-8,004' Lease: Perforations: (TVD) Kenai Gas Field Alaska Country: 4,762'-7,626' 87' State/Prov : Angle @ KOP and M Depth: Donna Ambruz 2/8/2021Last Revision Date: KB Elevation:KB Height Above Ground Level:21' Kenai Tyonek Unit 13-5 Kenai Gas Field 144' FNL, 1,101' FEL Sec. 7, T4N, R11W, S.M. Conductor: 20" 93# 0.438" Top Bottom MD 0' 136' TVD 0' 136' Surface Casing: 13-3/8" 61# N-80 Top Bottom MD 0' 2,500' TVD 0' 2,396' Intermediate Casing: 9-5/8" 47# N-80 Top Bottom MD 0' 8,232' TVD 0' 7,822' Perfs Date Interval Condition 11/5/84 4,987' - 4,996' Upper Beluga Sd. - Isolated 11/5/84 5,343' - 5,366' UB Sd. - Isolated 11/5/84 5,401' - 5,416' UB Sd. - Isolated 10/27/84 6,580' - 6,602' Lower Beluga Sd. - Isolated 10/23/84 6,956' - 6,962' LB Sd. - Isolated 10/25/84 7,320' - 7,330' LB Sd. - Isolated 10/18/84 7,642' - 7,668' Upper Tyonek Sd. - Squeezed 10/17/84 7,916' - 7,932' UT Sd. - Squeezed 10/14/84 7,936' - 7,950' UT Sd. - Squeezed 10/7/84 7,989' - 8,004' UT Sd. - Squeezed TD: 8,232' MD 7,822' TVD 14 15 16 17 18 19 20 21 Long String:2-7/8", 6.4ppf, N-80 tubing Jewelry Long String Depth: 14. Top of 2-7/8" Tubing Stub (parted) ~5,354' 15. Otis 9-5/8" GP Pkr w/Seal Assembly 7,599.60'-7,610.51' 16. Gravel Pack 7,610.51'-7,707.27' 17. Otis 9-5/8" GP Pkr w/Seal Assembly 7,707.27'-7,717.27' 18. Otis "X" Nipple 7,750.13' 19. Otis 9-5/8" GP Pkr w/Seal Assembly 7,840.73'-7,853.31' 20. Gravel Pack 7,853.31'-8,039' 21. Cement Retainer Bridge Plug 8,039' KB:87' (21' AGL) API #:50-133-20370-00-00 PTD:184-108 Property Des:A-028142 X= Y= Lat: Long: Spud: TD:8,232' MD Released Rig: PBTD: 2,988' MD 2,959' TVD 13-3/8" @ 2,500' 20" @ 136' 9-5/8" @ 8,232' Upper Beluga Perfs Lower Beluga Perfs Upper Tyonek Perfs Tapered Production Casing: Top Btm 5-1/2" 17#, L-80 0' 3755' XO, PBR w 4.00" Seal Bore 3755' 3765' 4-1/2" 13.5#, L-80 3765' 4611' Cemented with 163bbls 12# Lead, 67bbls 15.3# tail (01/1//21) ** Wellhead Packoff leaked while pumping displacement ** ** 32bbls cement left inside casing ** CIBP 4950' w 35' cement cap TOC @ 4915' (1/12/21) CIBP 4650' (1/12/21) PBTD inside 5-1/2 @ 2988' 1/21/21 2-7/8" tubing parted while fishing @ 5354' (1/12/21) TOC 5-1/2 x 9-5/8 annulus @ 820' (01/25/21 CBL) TOC 9-5/8 x 12-1/4 annulus @ 3640' (09/06/84 CBL) 2988' 1/21/21PBTD inside 5-1/2@ 22 12988 1/21/21 4611' ulus @ 820' (01/25/21 CBL)TOC 5-1/2 x 9-5/8 annn B0@(// ) nulus @ 3640' (09/06/84 CBL)TOC 9-5/8 x 12-1/4 ann 4 0 // TOC 2988' 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: 01/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KTU 13-05 (PTD 184-108) RCBL Radial Cement Bond Log 01/25/2021 Please include current contact information if different from above. PTD: 1841080 E-Set: 34635 Received by the AOGCC 01/29/2021 Abby Bell 02/01/2021 STATE OF ALASKA Reviewed By: JX OIL AND GAS CONSERVATION COMMISSION P.1. Sup" a3 2s z -I BOPE Test Report for: KENAI ,rYONEK UNIT 13-05 Comm Contractor/Rig No.: Hilcorp 401 . PTD#: 1841080 - DATE: 1/8/2021 Inspector Lou Laubenstein Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Harold Soule Rig Rep: Chad Johnson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopLOL210112095641 Rams: Annular: Valves: MASP: Type Test: INIT 320-507 - 250/2500- 250/2500 250/2500 1499 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: Quantity P/F Upper Kelly Visual Alarm Location Gen.: P Trip Tank NA_ NA Housekeeping: P Pit Level Indicators P P PTD On Location P Flow Indicator NA NA Standing Order Posted P Meth Gas Detector P - P Well Sign _P H2S Gas Detector __P P Drl. Rig P MS Misc NA NA Hazard Sec. P BOP Misc 0 Misc NA FLOOR SAFTY VALVES: Quantity Quantity P/F Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP l P FSV Misc 0 NA BOP STACK: Quantity Size Stripper 0 Annular Preventer 1 13 5/8" #1 Rams 1 2-7/8 x 5-1/2 #2 Rams 1 Blinds #3 Rams 0 #4 Rams 0 #5 Rams 0 #6 Rams 0_ Choke Ln. Valves 1 2-1/16" HCR Valves 1 ' 2-1/16" Kill Line Valves 2 2-1/16" Check Valve 0 BOP Misc 0 Number of Failures: 0 ✓ Remarks: Test Results ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 P Pressure After Closure 1950 - P 200 PSI Attained 33 P Full Pressure Attained 174 - P_ Blind Switch Covers: yes P Nitgn. Bottles (avg): 6 @ 2000 P ACC Misc 0 NA CHOKE MANIFOLD: P/F Quantity P/F NA No. Valves 8 P P Manual Chokes 2 P P Hydraulic Chokes 0 NA P CH Mise 0 _- NA NA NA NA INSIDE REEL VALVES: NA (Valid for Coil Rigs Only) P Quantity P/F P Inside Reel Valves 0 NA P NA NA Test Time 3.5 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: ___________________ 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): 8,232'N/A Casing Collapse Structural Conductor 520psi Surface 2,260psi Intermediate Production 4,750psi Liner 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: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 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: January 10, 2020 2-7/8" LS Packers and SSSV Type: Otis Dual Hydraulic Pkr; Packers and SSSV MD (ft) and TVD (ft): 4,850' MD/4,631'TVD 8,232' Perforation Depth MD (ft): See Attached Schematic 8,206' 7,843'9-5/8" 20" 13-3/8" 110' 2,474' 1,530psi 5,020psi 136' 2,401' 136' 2,500' 6.4# / N-80 TVD Burst ~7,980' 6,870psi MDLength 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 184-108 50-133-20370-00 Kenai Tyonek Unit (KTU) 13-05 Kenai Gas Field - Sterling Pool(s) 3, 4 COMMISSION USE ONLY Authorized Name: Tubing Grade: 9.2# / N-80 Tubing MD (ft): 4,871' See Attached Schematic jake.flora@hilcorp.com 7,843'8,039'7,659'1,499 N/A (3) Otis 9-5/8" GP Pkrs; N/A 7,600'; 7,707'; 7,841' MD/7,239'; 7,341'; 7,470' TVD Perforation Depth TVD (ft): Tubing Size: 3-1/2" SS Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:38 am, Dec 10, 2020 320-507 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.12.09 17:42:49 -09'00' Taylor Wellman SFD 12/10/2020 *2500 psi BOPE test SFD 12/10/2020 -00 X rig 401 DSR-12/11/2020 10-404 gls 12/14/20 q Yes C 12/18/2020 dts 12/15/2020 JLC 12/16/2020 RBDMS HEW 12/21/2020 Well Prognosis Well: KTU 13-05 Date: 12/08/2020 Well Name:KTU 13-05 API Number:50-133-20370-00 Current Status:Shut-In Gas Well Leg:N/A Estimated Start Date:January 10, 2020 Rig:401 Reg. Approval Req’d?10-403 Date Reg.Approval Rec’vd: Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:184-108 First Call Engineer:Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer:Ted Kramer (907) 777-8420 (O) (985) 867-0655 (M) AFE Number: Maximum Expected BHP:~ 1927 psi @ 4284’ TVD (Based on 0.45 psi/ft gradient) Max. Potential Surface Pressure:~ 1499 psi (Based on BHP minus 0.1 psi/ft) Brief Well Summary: Kenai Tyonek Unit 13-05 (KTU 13-05) was drilled and completed in late 1984 as a dual completion Beluga and Upper Tyonek gas well. To control production/drawdown, and thus minimize sand production, the Upper Tyonek intervals (accessible through the 2-7/8” Long String) were gravel packed and isolated from the Upper and Lower Beluga sands (perforated and open via the 3-1/2” Short String). KTU 13-05 produced gas on a relatively continuous basis from December 1984 through October 2009. After being shut-in for nearly four years, the well was opened September 2013 through September 2015 and produced at an average rate of less than 60 Mcf/d. KTU 13-05 was shut-in in September 2015 for IA x OA communication issues. In July 2017, Hilcorp flowed KTU 13-05 for several weeks (flowing at ~250 Mcf/d). At this time it was reported that there was continued bubbling in the conductor/surface casing annulus. KTU 13-05 has been shut-in since September 2017, due to IA & OA integrity issues. The purpose of this Sundry is to P&A the Tyonek and Beluga perforations in the KTU 13-05 wellbore, and then re-complete the well as a Sterling gas well. To address the IA & OA integrity issues, production casing will be run (inside the existing 9-5/8” casing) and cemented to surface. Tubing x IA x OA History 10/08/17 Filled OA w 17 bbls water, saw water coming from IA 09/21/17 Temp log while pumping 100 degree water down OA with returns up IA. Est leak depth at 65ft 09/06/17 Attempt water flow log, IA pressures up with 1.75 gpm, too low of rate to log 08/08/17 Pumped 25 bbls down OA, saw returns from IA 08/06/17 Set plug in SS @ 4193’ Drift LS, tag top of fish at 4810’ (1.75” slick-line toolstring, 1.75” cutter, 1.5” cutter, LIH in 2009) 08/05/17 Slick-line drift & tag SS, couldn’t pass 4214’ w 1” LIB 7/28/17 RU to LS, Set plug at 4663’, MIT tbg to 500psi w gas, held for 90 min, holding, pull plug Pre Rig 1. Bleed off WHP to zero on tubing, IA, OA. 2. RU pump truck and bullhead both tubing strings with KWF. Load IA with KWF. The purpose of this Sundry is to P&A the Tyonek and Beluga perforations in the KTU 13-05 wellbore, and then re-complete the well as a Sterling gas well. To address the IA & OA integrity issues, production casing will be run (inside the existing 9-5/8” casing) and cemented to surface. Tubing x Well Prognosis Well: KTU 13-05 Date: 12/08/2020 Rig 401 3. MIRU Rig 401. 4. Set Back Pressure valve(s). ND wellhead, NU 13-5/8” BOP with 2-7/8” – 5-1/2” VBRs and test 250 low & 2,600 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre-charge pressures and chart tests. Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. a. Perform Test. b. Test VBR rams on 2-7/8” and 5-1/2” test joints. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. PU 3-1/2” landing joint, engage short string, pull tension to shear collet, POOH while laying down 3- 1/2” tubing. If the 3-1/2” will not pull discuss contingency plan with OE. a. Contingency Plan if 3-1/2” short string will not pull from dual packer: RU to 2-7/8” long string, pull to shear dual packer, with packer free RU eline to long string and jet cut tubing at ~4800’, pull and LD long string, pull and lay down 3-1/2” short string, dual packer, and 2- 7/8” long string. b. Contingency plan if Neither string will pull and shear: jet cut long string as deep as possible (~4800’), jet cut short string as deep as possible (~4200’), RIH with OS & jars, engage 3-1/2” short string and jar to shear, LD 3-1/2” tubing. RIH with OS & jars, engage 2-7/8” long string and jar to shear dual packer, POOH & LD completion. 6. PU 2-7/8” landing joint, engage long string, pull tension to shear dual packer and POOH while laying down 2-7/8” long string completion. Typically has 6 shear screws and shears at 30K, could have up to 16 screws and shear at 80K (= 107K hook load with water packed wellbore). Isolate Lower Beluga, Upper Beluga, & Upper Tyonek Perforations beneath CIBP 7. RU E-Line, set 9-5/8” CIBP at 7500’, dump 35’ cement on top of plug. 8. Set 9-5/8” CIBP at 4950’ above open perfs at 4987’. Dump 35’ cement on top of plug. 9. Set 9-5/8” CIBP at 4650’, this plug will shorten the rathole below the new casing. RD E-line. 10. Run 9-5/8” storm packer, set @ ~ 200 ft. 11. ND BOP. 12. ND tubing head. 13. NU new casing head. NU spacer spool. 14. NU BOP. Shell test stack. 15. Pull storm packer. Run and Cement 4.5” x 5.5” Tapered Casing 16. Run and land 4.5” x 5.5” casing including the following: a. 4-1/2” float shoe, 2 joint shoe track, float collar. b. 4-1/2” casing from 3760’ - 4600’ (float shoe, 2 joint shoe track, float collar (PBTD ~ 4520’)). c. 4-1/2” x 5-1/2” XO. d. 5-1/2” casing to surface. e. Casing hanger. 17. RU Cementers and cement the casing to surface. Pump ~280 bbls of cement (5-1/2” x 9-5/8” annulus with 35% XS). BHT is approximately 85 degrees at 4600 ft. Drop Wiper plug, latch plug with ~ 99 bbls displacement. WOC. Run 3-1/2” Tubing w Seal Assembly 18. Set BPV in 5-1/2” hanger. 19. ND & raise BOP. 2500 psi BOPE test 6 Test below packer to 1500 psi to verify integrity. gls 12/10/20 Pull short string Pull long string 3 CIBP's Well Prognosis Well: KTU 13-05 Date: 12/08/2020 20. ND spacer spool, NU tubing head. 21. NU BOP. Shell test. 22. Pressure test new Production Casing to 2500 psi, for 30 minutes, as per 20 AAC 25.030 (e). 23. RU Slickline. Brush PBR. Log memory CBL, tag TD, notify OE if the new PBTD is higher than 4500’. 24. MU & RIH with below completion: a. 4.00” seal assembly b. 3-1/2” tubing surface to 3760’ 25. Engage seal assembly per vendor recommendation. Space out and Land tubing string. 26. ND BOP and NU Tree. 27. MITIA 3-1/2” x 5-1/2” annulus to 1500 psi. 28. RDMO workover Rig 401. Post Rig 29. RU Slick-line. PT Lubricator. Swab well down to 5000’. 30. RU E-line, PT lubricator. Perforate the below zones from the bottom up: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom P3_A8 ±3,787' ±3,794' 7' ±3,615' ±3,621' P3_A9 ±3,820' ±3,830' 10' ±3,646' ±3,656' P3_A10 ±3,854' ±3,861' 7' ±3,679' ±3,685' P3_A10 ±3,874' ±3,903' 29' ±3,698' ±3,725' P3_A11 ±3,956' ±3,970' 14' ±3,776' ±3,789' P4_B1A ±3,994' ±4,046' 52' ±3,812' ±3,862' P4_B2 ±4,078' ±4,093' 15' ±3,892' ±3,906' P4_B2A ±4,103' ±4,121' 18' ±3,916' ±3,933' P5.1_B4B ±4,287' ±4,320' 33' ±4,133' ±4,164' P5.2_B5B ±4,379' ±4,448' 69' ±4,218' ±4,284' a.If necessary RU Nitrogen to pressure up the well for perforating. b.Each pool will need to be fully abandoned beneath a CIBP with cement top prior to perforating zones in any uphole pool. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. 1. POOH. 2. RD E-Line. (forward CBL to AOGCC for review) Well Prognosis Well: KTU 13-05 Date: 12/08/2020 3. Turn well over to production.(Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 4-1/2” through tubing plug above the zone and dump 35’ of cement on top of the plug. Attachments: Actual Schematic Proposed Schematic Current Wellhead Proposed Wellhead BOPE Schematic Standard Well Procedure – N2 Operations RWO Sundry Revision Change Form Well Name: County or Parish:USA Perforations: (MD) Angle/Perfs:KOP TVD: Date Completed: Revised By: ACTUAL SCHEMATIC Kenai Tyonek Unit 13-5 Kenai Peninsula Borough 4,987'-8,004' Lease: Perforations: (TVD) Kenai Gas Field Alaska Country: 87' State/Prov : Angle @ KOP and M Depth: Paul Winslow 1/23/2020Last Revision Date: KB Elevation:KB Height Above Ground Level:21' Kenai Tyonek Unit 13-5 Kenai Gas Field 144' FNL, 1,101' FEL Sec. 7, T4N, R11W, S.M. Note: CIW Dual Tubing Hanger @ 25.90' Conductor 20" 93# 0.438" Top Bottom MD 0' 136' TVD 0' 136' Surface Casing 13-3/8" 61# N-80 Top Bottom MD 0' 2,500' TVD 0' 2,396' Production Casing 9-5/8" 47# N-80 Top Bottom MD 0' 8,232' TVD 0' 7,822' Perfs Date Interval Condition 11/5/84 4,987'-4,996' Upper Beluga Sd. Open Prod. 11/5/84 5,343'-5,366' UB Sd. Open Production 11/5/84 5,401'-5,416' UB Sd. Open Production 10/27/84 6,580'-6,602' Lower Beluga Sd. Open Prod. 10/23/84 6,956'-6,962' LB Sd. Open Production 10/25/84 7,320'-7,330' LB Sd. Open Production 10/18/84 7,642'-7,668' Upper Tyonek Sd. Open Prod. 10/17/84 7,916'-7,932' UT Sd. Open Production 10/14/84 7,936'-7,950' UT Sd. Opem Production 10/7/84 7,989'-8,004' UT Sd. Open Production TD: 8,232' MD 7,822' TVD 1 A B, 4 C D 2 3 4 5 6 7 8 9 10 11 12 13 15 16 17 18 19 20 21 Fish (bottom) @ 4803"-10' wire, 1-3/4" x 4'cutter, 1-1/2" x 4' cutter, 1-3/4" x 24' tool string (4/2/2009) Tag 3/30/10 (EXPRO): 2.29" GR @ 4626' MD RKB 2.20" LIB @ 4656' 2.00" bailer @ 4710' 1.75" GR @ 4757' Long String: 2-7/8", 6.4ppf, N-80 tubing Jewelry Long String Depth: 1. 3-1/2" x 2-7/8" crossover 26.68' 2. Otis "XA" Sleeve 4,814.42' 3. 2-7/8" x 3-1/2" crossover 4,848.88' 4. Otis Dual Hydraulic Packer 4,850.02'-4,856.68' 5. Mandrel Extension 4,856.68' 6. 3-1/2" x 2-7/8" crossover 4,858.10' 7. Otis "XA" Sleeve 4,889.38' 8. Carbide Blast Joints 4,991.73'-5,014.73' 9. Carbide Blast Joints 5,347.45'-5,384.45' 10. Carbide Blast Joints 5,407.09'-5,436.09' 11. Carbide Blast Joints 6,589.72'-6,625.72' 12. Carbide Blast Joints 6,967.37'-6,987.37' 13. Carbide Blast Joints 7,332.71'-7,356.71' 14. Otis "XA" Sleeve 7,504.12' 15. Otis 9-5/8" GP Pkr w/Seal Assembly 7,599.60'-7,610.51' 16. Gravel Pack 7,610.51'-7,707.27' 17. Otis 9-5/8" GP Pkr w/Seal Assembly 7,707.27'-7,717.27' 18. Otis "X" Nipple 7,750.13' 19. Otis 9-5/8" GP Pkr w/Seal Assembly 7,840.73'-7,853.31' 20. Gravel Pack 7,853.31'-8,039' 21. Cement Retainer Bridge Plug 8,039' Short String: 3-1/2", 9.2ppf, N-80 tubing Jewelry Short String Depth: A. Otis "XA" Sleeve 4,783.35' B. Otis Dual Hydraulic Packer 4,850.02'-4,856.68' C. Mandrel Extension 4,846.68' D. Otis "XN" Nipple 4,870.86' KB: 87' (21' AGL) API #: 50-133-20370-00-00 PTD: 184-108 Property Des: A-028142 X= Y= Lat: Long: Spud: TD: 8,232' MD Released Rig: IA x OA leak @65ft XA sleeve PROPOSED WBD Well Name: County or Parish:USA Perforations: (MD) Angle/Perfs:KOP TVD: Date Completed: Revised By: State/Prov : Angle @ KOP and M Depth: Jake Flora 11/30/2020Last Revision Date: KB Elevation:KB Height Above Ground Level:21' Kenai Gas Field Alaska Country: 87' 12/7/2020 Kenai Tyonek Unit 13-5 Kenai Peninsula Borough 4,987'-8,004' Lease: Perforations: (TVD) Kenai Tyonek Unit 13-5 Kenai Gas Field 144' FNL, 1,101' FEL Sec. 7, T4N, R11W, S.M. Conductor: 20" 93# 0.438" Top Bottom MD 0' 136' TVD 0' 136' Surface Casing: 13-3/8" 61# N-80 Top Bottom MD 0' 2,500' TVD 0' 2,396' Intermediate Casing: 9-5/8" 47# N-80 Top Bottom MD 0' 8,232' TVD 0' 7,822' Perfs Date Interval Condition 11/5/84 4,987' - 4,996' Upper Beluga Sd. -Isolated 11/5/84 5,343' - 5,366' UB Sd. -Isolated 11/5/84 5,401' - 5,416' UB Sd. -Isolated 10/27/84 6,580' - 6,602' Lower Beluga Sd. - Isolated 10/23/84 6,956' - 6,962' LB Sd. -Isolated 10/25/84 7,320' - 7,330' LB Sd. -Isolated 10/18/84 7,642' - 7,668' Upper Tyonek Sd. -Squeezed 10/17/84 7,916' - 7,932' UT Sd. -Squeezed 10/14/84 7,936' - 7,950' UT Sd. -Squeezed 10/7/84 7,989' - 8,004' UT Sd. -Squeezed TD: 8,232' MD 7,822' TVD 14 15 16 17 18 19 20 21 Long String: 2-7/8", 6.4ppf, N-80 tubing Jewelry Long String Depth: 14. Top of 2-7/8" Tubing Stub ~7,510' 15. Otis 9-5/8" GP Pkr w/Seal Assembly 7,599.60'-7,610.51' 16. Gravel Pack 7,610.51'-7,707.27' 17. Otis 9-5/8" GP Pkr w/Seal Assembly 7,707.27'-7,717.27' 18. Otis "X" Nipple 7,750.13' 19. Otis 9-5/8" GP Pkr w/Seal Assembly 7,840.73'-7,853.31' 20. Gravel Pack 7,853.31'-8,039' 21. Cement Retainer Bridge Plug 8,039' KB: 87' (21' AGL) API #: 50-133-20370-00-00 PTD: 184-108 Property Des: A-028142 X= Y= Lat: Long: Spud: TD: 8,232' MD Released Rig: PBTD: 4,850' MD 4,619' TVD 13-3/8" @ 2,500' 20" @ 136' 9-5/8" @ 8,232' Upper Beluga Perfs Lower Beluga Perfs Upper Tyonek Perfs Tapered Production Casing: 4-1/2" x 5-1/2" L-80 Top Bottom MD 0' 4600' TVD 0' 4400' Tubing: 3-1/2" 9.3# L-80 Top Bottom MD 0' 3760' TVD 0' 3589' 3750' 4-1/2" x 5-1/2" XO 3760' 3-1/2" TT w seal assembly 4-1/2" seal bore (4.00" ID) 3787' - 4448' Sterling perfs 4520' float collar, new PBTD 4600' 4-1/2" casing CIBP 4950' CIBP 4650' CIBP 7500' fully cement 5 1/2" x 4 1/2" liner 9 5/8" casing TOC @3400 ft Kenai Gas Field KTU 13-05 Current 11/17/2020 Casing head, Cameron WF, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO 2 1/16 5M CIW ball valve Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Tree assy, dual block, CIW-F, 11 5M X 3 1/8 5M X 3 1/8 5M, prepped on 5 3/64 center, 3'’ CIW seal pockets, ½ npt control line exits Tubing hanger, dual, CIW- DCB, 11 5M X 3 ½ EUE 8rd lift X 3 ½ IBT bottom, w/ 3'’ type H BPV profile, 1/8 non cont control line ports in hangers Kenai Gas Field KTU 13-05 20 X 13 3/8 X 9 5/8 X 3 ½ X 2 7/8 Valve, CIW-F, 2 1/16 5M FE, HWO, AAm replace Kenai Gas Field KTU 13-05 Proposed 11/018/2020 13 3/8'’ 9 5/8'’ Valve, Master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FLS 3 1/8 5M FE, HWO, EE trim Valve, Wing, CIW-FC, 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 3 1/8 5M FE x 6.5 Otis quick union top Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Tubing head, Cactus C-HPS, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO New spool Casing spool, Cactus C-29L- HPS, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO New spool Kenai Gas Field KTU 13-05 20 x 13 3/8 x 9 5/8 x 5 ½ x 3 ½ or 2 7/8 Casing hanger, CW, 11 x 5 ½ DWC/C box btm x 6.125'’ LH stub acme box top, w/ 7 5/8 od neck, 5'’ type H BPV profile, DD-NL material 2 7/8'’ Tubing hanger, Cactus-EN-CL, 7 x 3 ½’’ EUE 8rd lift and susp, w/ 3 type H BPV profile, 1- ¼npt control line port Adapter, Cactus-EN, 7 1/16 5M Stdd x 3 1/8 5M prepped for 5 ½ extended neck hanger 3 ½’’ or 5 ½’’ Casing head, Cameron WF, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2 1/16 3M EFO 2-7/8" x 5-1/2" VBR X 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 KTU 13-05 (PTD 184-108) Sundry #: XXX-XXX 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 1 Carlisle, Samantha J (CED) From:Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent:Tuesday, December 15, 2020 12:23 PM To:Schwartz, Guy L (CED) Subject:RE: [EXTERNAL] KTU 13-5 (PTD 184-108) RWO sundry Attachments:us50133203700000_KTU 13-05_CBL.TIF HiGuy, There’saCBLonthe9Ͳ5/8”showingcementtopat3400’,withgoodcementstatingat3700’.Ourtopproposedperfs areat3787’andwebelievethezonesareprotected. I’veattachedtheCBL,it’saTIFF. SorryI’vebeenmovingourstuffoutdowninDenverandjustreturnedtoAK. Thanks, Jake From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Thursday,December10,20204:35PM To:JakeFloraͲ(C)<Jake.Flora@hilcorp.com> Subject:RE:[EXTERNAL]KTU13Ͳ5(PTD184Ͳ108)RWOsundry Onemorequestion… Sincethiswellhadbubblingattheconductorisitlikelythe133/8”surfacecasinghasissues/leakaswellattheshallow depth? Whatisthecementinghistoryforthe95/8”casing.Idon’tseeaDVcollarsodoubtitistosurfaceasthewellsketch diagramshows.MightbeworthlookingatadownsqueezeintotheOAorseewhattheinjectivityis.Imightbe missingsomethingofcourse. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). 2 From:JakeFloraͲ(C)<Jake.Flora@hilcorp.com> Sent:Tuesday,December8,20202:19PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Subject:RE:[EXTERNAL]KTU13Ͳ5(PTD184Ͳ108)RWOsundry Guy, CanIemailyouacorrectedversionoftheprogram/sundrypackage?Therearetwoadditionalsandsthegeowantsto addthatdeepenthenewcasingdepthalongwitheditsperyourcomments. Responsestoyourcomments: Ͳ WearegoingtobrushthelinertopwithslickͲlineafterthecementjob,theywillalreadybethererunningaCBL Ͳ Imusthavebeenstaringatthe3.5”tieback,displacementvolumeisasyoustated Ͳ IhavetheWHdiagrams Ͳ NotedontheCIBPat7500’ Ͳ TheTOCcommentpertainstotheNewPBTD,IseehowitalsoseemstoreferenceannularTOC,willchangeto PBTD Ͳ NotplanningonsqueezingtheOA.AssumingwegetthecasingandMITIAofthenewIAtopass,thisshould solvetheANNCOMMissue. From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Tuesday,December8,202011:02AM To:JakeFloraͲ(C)<Jake.Flora@hilcorp.com> Subject:[EXTERNAL]KTU13Ͳ5(PTD184Ͳ108)RWOsundry Jake, Acoupleofquestions: 1. Idon’tseethe38bblsfordisplacementforthewiper.Shouldn’titbe95bblstothefloatcollar?Areyouusinga taperedwiperplug? 2. Provideadiagramofexistingandproposedwellhead. 3. AnadditionCIBPisrequiredat7500fttoisolatetheLBperfsfromTyonek. 4. ThecommentaboutTOChigherthat4150ftisconfusinginstep22.thelinershouldbefullycementedwhen completed. 5. AreyougoingtotrytosqzanycementintotheOAleak? GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this 3 email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Krut 13-05 • PT6 IS4Ic 5o Regg, James B (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday,July 25, 2017 5:19 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Quick, Michael J (DOA);Wallace, Chris D (DOA); Loepp,Victoria T (DOA); Chet Starkel; Ted Kramer; Christopher Walgenbach; Pete Iverson; Sean Maguire; Larry Greenstein Subject: RE: KGF KTU 13-05 PTD# 184-108 conductor bubbling Attachments: KTU 13-05 pressure monitoring July 2017.xlsx Jim, As we discussed on the phone, below is our plan forward. Attached is a spreadsheet with the bleed info I have to this point. ( k1 aztoted • 1-►z' l The plan forward as we discussed is: 1. Continue flowing the well to reduce the casing pressures, as the pressures are dropping. 2. Vent the OA casing pressure to 0 psi while monitoring the small bubble rate. (Bubbles are approximately%-%2" diameter.) 3. Once the OA pressure is 0, pump 8.4 ppg produced lease water into annulus until the annulus is full or have pumped more than 150 bbls (annulus volume). Once full, try and determine an injection rate without exceeding 500 psi. The goal of this diagnostic work is to determine if the bubbles are coming from the surface casing into the conductor or from swamp gas or something in the ground just below the conductor. 4. Once annulus is full, we will SI and repeat the following day to see what the leak rate is and if we think it is possible to complete a surface casing cement/polymer job (a sundry and more discussions will be had before any cement work is completed. 5. If bubbles persist when surface casing is full of fluid, we will try to maintain a high fluid level for several days to see if the bubble rate changes at all. We will continue to keep AOGCC informed of the progress with these bubbles and will try and determine if there is a way to collect a sample for analysis and how to eliminate these bubbles from continuing. My review of the history on this well, it appears that there were some difficulties with the surface cement iob on this well and there is reference in one report to a top job being completed. If you have any questions or would like to discuss in more detail, please feel free to contact Ted Kramer or myself. Chad SCANNED AUG 0 $ 20,17' From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 25, 2017 10:00 AM To: Chad Helgeson Cc: Schwartz, Guy L (DOA); Quick, Michael J (DOA); Wallace, Chris D (DOA) Subject: RE: KGF KTU 13-05 PTD# 184-108 conductor bubbling Please provide an update which includes: • Results of diagnostics to date • Plans for additional diagnostics • Gas sample taken for analysis; • p Y , Last document in our records was Marathon's cancellation of a planned workover—approved sundry 306-238; cancelled 11/9/2007. Proposed work was to replace the dual-tubing completion with a single (eliminate SS and LS communication; add perfs in Beluga to improve production efficiency and water removal). I am curious the relationship of tubing communication to bubbling from the conductor/surface casing annulus. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this a-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Monday,July 24, 2017 7:01 PM To:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>; Regg,James B (DOA)<iim.regg@alaska.gov>;Quick, Michael J (DOA) <michael.quick@alaska.gov> Cc: Christopher Walgenbach <cwalgenbach@hilcorp.com>; Pete Iverson<jpiverson@hilcorp.com>;Ted Kramer <tkramer@hilcorp.com>; Larry Greenstein <Igreenstein@hilcorp.com>; Chet Starkel <cstarkel@hilcorp.com>; Sean Maguire <smaguire@hilcorp.com>; Chad Ebenezer<cebenezer@hilcorp.com> Subject: KGF KTU 13-05 PTD# 184-108 conductor bubbling At the Kenai Gas Field on the 41-07 Pad we found the conductor on well KTU 13-05 leaking gas between the conductor and the surface casing. The well has been shut in since September 2015 because of annuli communication. We do not think this is something that has recently occurred, but with the rain from last week, the cellar fluid level had risen enough to see bubbles. (We estimate the rate of bubbles were a little less than a small fish tank air bubbler.) As you can see in the attached TIO plot the dual strings, casing and OA have been tracking a little over 600 psi for the last 2 years. We have removed the wellhouse and secured the area. We are bleeding down the tubing and casing tonight to see if the rate of the bubbles changes. The conductor was driven to 136', so hopefully we can determine if it is swamp gas or gas coming from the wellbore. This is not a storage well in Kenai Gas Field, but a well dual completed in the upper Beluga and lower Tyonek formations. I wanted you to be aware of the situation, and if you need more information, please do not hesitate giving me a call (229-4824). Please let me know which Engineer Ted Kramer or I should follow-up with a phone call tomorrow on what we find and a proposed plan forward. Regards, Chad Helgeson Operations Manager Kenai Asset Team Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 2 • • a ..i.,U 00 b0 'p C C o0 La L . . a o N� a O N C c I I I I C 0 0 c •i-, b�0 0 N O Op IL 0onIA b+ C N C •C > N G! N E a) E L O c ro 0 N Ln N Y .) 01 W C4 13 0 0 0 0 NN O 01 0 3 E m m M M m m L) O CU N LL W 0_ 00 C Q O N O Ln O O 00 Ln 01 Ln o M N LD N Ln M N N 01 N Q lD lD LD *h Cr Cr) M M M N .-ICC O 0 i_ I n M n L1 0 a 0 0 Ln Ln O N 00 01O O N D Cr M .--I LO - N Lr m M m O1 1— L Q t0 LO LO Ct M M M M -N . 1 00 C 0 J '= 0 Ln In LO O O O .-1 M 0.0 N 00 00 C fl- LO d' Cr) M N N .--I .--1 i M 3 I- N 0 t H r" O OO bp v. °M° U. 000 000 CO 000 NCO 0 C 00 NO ,-1 :c 3 ~ 0 0 0 0 0 0 0 0 0 0 0 Ln CO 0 0 0 N o M o o Ln O o o OM o 0 (isd)aJnSS.lad E r-1 .-1 N N Cr) c-I N Cr LD N l- N N N .-1 c-I .--1 .--I .-I N N N N N N N N N N N N .--1 .--I .-I .--1 .--I ,--I .--I .--1 .--1 .--1 .--1 ri O O O O 0 0 0 0 0 0 0 0 N N N N N N N N N N N N - \ - \ \ \ - \ \ \ \ ----- a) Q) cr Ln Ln Ln Ln Ln in Ln L!1 Ln 0• N N N N N N I-, N N N N N • • 87 (21'AGL) Pit#:184-1-10811 #: 50-133-20370-00-00 Permit*: Kenai Tyonek Unit 13-5 1 Property Des: A-028142 Kenai Gas Field x= 144'FNL, 1,101' FEL "! ttt c } <` Y= Sec.7, T4N, R11 W,S.M. Lat: Long: Conductor 20" 93# 0.438" Spud: )1 r' 1 Top Bottom TD: 8,232' MD 0' 136' g ND 0' 136' Released Rig: f Surface Casinq 13-3/8" 61# Bottom Top Bott MD 0' 2,500' TVD 0' 2,396' Note: CIW Dual Tubing Hanger©25.90' Production Casinq 9-5/8" 47# N-80 Top Bottom MD 0' 8,232' ND 0' 7,822' 2 � /�'�� ti Tag 3/30/10(EXPRO): Ao �jl/vrAcrL 2.29"GR @ 4626'MD RKB - - 3 2.20"LIB©4656' 5 C..7(2.�j1-� B 4 _ 21:7050::bailer@4710' "% 4 GR a 4757 �. D rxl 'Long String 2-7/8",6 4ppf, N-80 tubing Fish(bottom) 4803"-10'wire,/-3/4' x Jewelry Long Strinq Depth �A I 8 4'cutter 1-1/2"x 4'cutter,1-3/4"x-24'tool 1. 3-1/2"x 2-7/8"crossover,_ 26.68' string(4/2/2009) 2. Otis"XA"Sleeve 4,814.42': ` 9 3. 2-7/8+'x 3-1/2"crossover 4,848,88' �: 4. Otis Dual Hydraulic Packer,, 4,$50 02'-4,856.68' 5. Mandrel Extension 4,856.68' 6. 3.1/2''x 2-7/8"crossover 4,$5$.10 10 7, Otis"XA"Peeve. 4,889.38' 8. Carbide Blast Jonts 4,991.73'5,014-73' 11 9. Carbide Blast Joints 5,347.45-5,384.45' . 10. Carbide Blast ktints 5,407.09`5,436.09' 11. Carbide Blast°Joints 6,5$9.72'6 625.72' .` ;� 12 12. Carbide Blast Joints 6,967.37'-8 987.37' 13. Carbide Blast'Joints � ,,,,73;52.7i,,,,7,35.6,11,,, , 2.71'-7,356. t` 14, Otis XA"Sleeve 7;504.1(1_7 • 13 15. Otis 9-5/8"ie Pkr w/Se'al Assseembl 77191:11'4:707,2_7 599 51707.21' III y X761051'770727 15 � Perfs 16. Gravel Pack' 7,707.2r-7,71,71f,` 17. Otis X518"GP Pkrw/Seas(Assembly -7,750.13". "`""� 16 Date Interval Condition 18 Otis''X"Nipple _ yip. . < /;88543a3716::57,08359)3.,?-1,`. 1115184 4,987 4,996' Upper Beluga Sd.Open Prod. 20. GPak PkrwJ, .. Set rtfbly ,8, / 17 1115/84 5,343'-5,366' UB Sd.Open Production 21 Gravel Pack„ 8 039 21. CeMentRet4Aper!lino?!mug Depth 18 11/5/84 5,401'-5,416' L weer Beplu Production 10/27/84 6,580'-6,602' Lower Beluga Sd.Open Prod: ShortString: 311/2", 9:.2ppf,N-80 tubing 4,783.35' 10/23/84 6,956'-6,962' LB Sd.Open Production 4,850,02'4,856.68' 10/25/84 7,320'-7,330' LB Sd.Open Production A. Otey A"Sleein 4,846.6$ 19 :::!=,,,,,,;,,,,,'!',,,.n",177,'1,4 10/18/84 7,642'-7,668' Upper Tyonek Sd.Open Prod. A. Otis Hyde 4,870.06 10/17/84 7,916'-7,932' UT Sd.Open Production B. DualOtisxtension Packer' C. Mandret ExtenSlon w ' 10/14/84 7,936'-7,950' UT Sd.Opem Production D. Otis"CCN"Nipple l 20 10/7/84 7,989'-8,004' UT Sd.Open Production 21 TD: 8,232'MD 7,822'TVD Well Name&Number: Kenai Tyonek Unit 13-5 I Lease:/ Kenai Gas Field County or Parish. Kenai Peninsula Borough State/Prov:1 Alaska I Country:/ USA Perforations:(MD) 4,987'-8,004' Perforations:(TVD)I Angle;Perfs: Angle @ KOP and M Depth: I KOP ND: Date Completed: KB Height Above Ground Level: 21' KB Elevation: 87' Revised By: James Ostroot I Last Revision Date. 3/31/2010 K•KTU 013-05 - [50.0669.0033]. -500 200 700 • emmion. 111111 600 ■ ■ arr wM► 150 500 400 u 100 300 200 50 100 0 _. — 0 1 06/2015 09/2015 12/2015 03/2016 06/2016 09/2016 12/2016 03/2017 06/2017 Tub ng Tub ng 2 — IA — OA -- Gas Production Well:KTU 13-055 Desc:Shut-In Permit to drill:1841080 Admin Approval:N/A API:50-133-20370-00-00 Date Range:06/01/2015-07/24/2017 i • Marathon Oil Company Marathon Alaska Asset Team P.O. Box 1949 MARATHON O~[ Company Kenai, AK 99611 Telephone 9071283-1371. Fax 9071283-1350 November 9, 2007 Mr. Tom Maunder ~~~~~ Alaska Onl & Gas Conservation Commission NOV 1 3 2007 333 W 7 Ave Anchorage, Alaska 99501 Atasita Oi18, Gas Cans. Commission Anchorage Reference: 10-404 Sundry Report Field: Kenai Gas Field . ~;~ Well: Kenai Tyonek Unit 13-5 aj~ ~~~I~ N©V ~ 5 2007 ~ Dear Mr. Maunder: Attached is a Sundry Report 10-404 for KTU 13-5 well under Sundry #306-238. Marathon has decided to forgo performing the intended-wor1c~n this well. KTU 13-5 has a stable gas production of 2mm/day. Every work over has an inherent risk associated with it. Marathon has chosen to continue operating this well, in the present manner, rather than jeopardize current production. Please contact me if you have any questions. You can contact me at (907)283 -1371. Sincerely, t -~~~,1~~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS ~~ STATE ol= ALASKA ALASKA OIL AN® GAS CONSERVATION COMMISSION REGEIVE[~ NOV 1 3 2007 REPORT OF SUNDRY WELL OPERATIC Dil & Gas Cons. Commission Anrhorane -a- 1. Operations Abandon Repair Well Plug Perforations Stimulate ~ Other ~ NonWork Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development^ Exploratory^ 184-108 " 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20370-00-00 7. KB Elevation (ft): g. Well Name and Number 87° KB (21' AGL Kenai T onek Unit 5 ' 8. Property Designation: 10. Field/Pool(s): A-028142 Kenai Gas Field /Beluga & Tyonek 11, Present Well Condition Summary: Total Depth measured 8,232° ~ feet Plugs (measured) NA true vertical 7,843' - feet Junk (measured) N,q Effective Depth measured 8,039' feet true vertical 7,659' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 110 20" 136 136 1,530 520 Surface 2,474 13-3/8" 2,500 2,401 5,020 2,260 Intermediate 0 0 0 0 0 0 Production 8,206 9-5/8" 8,232 7,843 6,870 4,750 Liner 0 0 0 0 0 0 Pertoration depth: Measured depth: Gross 4,987° - 8,004' True Vertical depth: Gross 4,750' - 7,605' Short String 3-1/2" N-80 4,871' Tubing: (size, grade, and measured depth) Long String 2-7/8" N-80 - 7,980' Packers and SSSV (type and measured depth) Otis Dual Hydraulic Packer 4,850' Otis 9-5/8" GP Packer 7,600° Otis 9-5/8" GP Packer 7,707' Otis 9-5/8" GP Packer 7,841' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA ~"~~ E~`(-t~) ~ 1~~7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA Subsequent to operation: NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ^ Development ^ Service ^ Daily Report of Well Operations NA 1 B. Well Status after work: OiI ^ 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: 306-238 Contact Kevin Skiba (907) 283-1371 Printed Narne Kevin Skiba Title Production Technician Signature `~~ ~ Phone (907) 283-1371 Date November 9, 2007 Form 10-404 Revised 04/2006 ~" ~`~ O R I G I N A L Submit Original Only ~iJ! \1\ ALA OIL AND GAS CONSERVATION COMM SION 7 1006 () 1'\ APPLICATION FOR SUNDRY APPROV ~a Oil & Gas Cons. Comm'ss' 20 AAC 25.280 _ I Ion 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate [] vvalver LJ ~ Other 0 Alter casing 0 Repair well [] Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing [] Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development [] / Exploratory 0 84-108 ~. 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. BOX 196168, ANCHORAGE ,AK 99519-6168 50-133-20370 / 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 [] KTU 13-5 / 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A-028142 8TKB 121' AGL Kenai Gas Field 1 Beluga - Tyonek 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): 8232' 7843' 8039' 7659' NA NA Casing Length Size MD / TVD Burst Collapse Structural Conductor 110 20" 136' 136' 1530 520 Surface 2474 13-3/8" 2500' 2401' 5020 2260 Intermediate Production 8206' 9-5/8" 8232 7843' 6870 4750 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: . 1þl611 Tubing Grade: Tubing MD (ft): See Wellbore Diagram I See Wellbore Diagram 2-7/8" 3 /',,, " L-80 7600' J . Packers and SSSV Type: Packers and SSSV MD (ft): Otis Hydraulic GP Packers 1 No SSSV GP Packers at 7600',7701',7841' / 13. Attachments: Description Summary of Proposal [] 14. Well Class after proposed work: Detailed Operations Program 0 BOP S~h 0 Exploratory 0 Development [] Service 0 15. Estimated Date for {71006 16. Well Status after proposed wor>- Commencing Operations: Oil 0 Gas [] Plugged 0 Abandoned 0 t 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 James R. Thompson Printed Name 713-296-2730 Title Sr. Completions Engineer Signature ~M,¿,t4- ¡2 t~- Phone Date ~ /_ ~ .... l 3/ ;¿O¿:J ~ ( j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ .. ~B Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: T ..e > t 130 f L= +-0 ~OOO fUt. RBDMS BFL JUL 1 3 2006 Subsequent Form Required: to - st 0 4- . Approv~by f) J/ß APPROVED BY 7//3/k:, COMMISSIONER THE COMMISSION Date: "\.V' ..... fp0 7 )I&/d ~ ~ ~" . [iff /.-~ Ûç,·] STATE OF ALASKA ' (, ~ / t( t:: (; I:: ~1 J I L.t U> ole JUL 0 Form 10-403 Revised 06/2006 0 R , GIN A l Submit in Duplicate e e Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 July 3, 2006 RECEIVED JUL 0 7 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commissiol1 Anchorage Reference: Application for Sundry Report 10-403 for permit 84-108 Field: Kenai Gas Field / Beluga & Tyonek Well: KTU 13-5 Dear Mr. Aubert, Enclosed please find an Application for Sundry Approvals form 10-403 for Kenai Gas Field well KTU 13-5 and associated attachments. This well was originally completed as a dual completion, with the long string producing from gravel packed Tyonek intervals, and the short string producing form several Beluga intervals. Request for approval is being made to pull the dual tubing completion, add / reperforate Beluga intervals, and run ,,/ a single 2-7/8" tubing string. Should you require further information, I can be reached at 713-232-9347 /713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, ~ø¡(. ~/ {' James R. Thompson Sr. Completions Engineer Enclosures: AOGCC Form 10-403 Existing and Proposed Well bore Diagram Operational Procedure Summary JRT i\ \ \ \']j) Marathon Oil Company Alaska Region \ KTU 13-5 W orkover Procedure \ Kenai Gas Field, Pad 41-7 \¡ ,~"~-ì Historv: KTU 13-5 is a IQw pressure Beluga / TYOnel'~1 lth two gravel packed completions over four Tyonek in1£rvals, and conventionallì perfornted casing complei.:fin seven Beluga in1;ervals. Communication between the 2-7/8" long string and 3-l/2,jshort string has been well documented and the well is currently producing approximately 1,400 mcfd an¡j 300 mcfd from the long and short strings, respectively. \ \. , Objective: Pull dual cOlI!~on,-add perforations in four Beluga intervals, and recomplete well as a ,/'/ single Beluga I Tyonek ~mi!!gleà'cbmpletion. The new completion will allow for incremental production from the four added Beluga intervals and more efficient production and water removal from the Tyonek and Beluga intervals. . "" ~ -1/ 'i' \i e Pre-Ri!!: Procedure: 1. Obtain Work Permit and PJSM 2. Perform slickline work and set plug to isolate Tyonek 3. Flow test well 4. Continue slickline operations for workover / 5. Cut LS below SS tubing tail 6. Kill well 7. Install two-way check valves Ri!!: W orkover procedure 8. MIRU Glacier Drilling rig #1. . I u.. lBo"" t.::. ,....... I .t-..l ~ J_ 9. Pull 3-1/2" SS -<,~ í "V........ 4. 't"C-.;>(¡ TV 10. Pull LS and Dual Packer / 11. Fish LS blast joints 12. Add I ReperfBeluga intervals 13. Run 2-7/8" tubing and associated downhole jewelry 14. Space out tubing 15. Set BPV 16. ND BOP I NU tree 17. Test Tree 18. RDMO Glacier Rig # 1 ~ooo ('(...), lJ 6A-- Post Ri!!: Procedure 19. Prepare well for Coil Tubing Wark 20. RU surface equipment and test BOP 21. RU slickline and open lower sliding sleeve 22. Perform CTU N2 Jetting operations to unload packer fluid. 23. MIRU slickline unit and close sliding sleeve and pull LS plug 24. Turn well over to production and flow test 25. Open Beluga for production sliding sleeves 1 26. Turn well over to production and flow test JRT ,'I (;:;17" [¡)ÎV'!iV'1V'V tv-t!h\J{,; . ¡:;,prn€D ¿r)/v. ' -. e e WELL KTU 13-5 CASING & ABANDONMENT DETAIL I.) Rotary Table Measurement at 0.00' II.) CIW Dual Tubing Hanger at 25.90' III.) 20", 93#, 0.438" Wall Casing at 136' IV.) 13 3/8", 61#, N-80 Casing at 2500' V.) Cement Retainer Bridge Plug at 8039' VI.) 9 5/8·, 47#. N-80 Casing at 8232' II i I mJJ IV UPPER I BELUGA I ZONE = ¡ lOWER l. BELUGA f ZONE == UPPER TYONEK :0('1 ~. I xi' T I 1~18 r ¡}:;< I::::::: F"'~ t;·::-: V VI ( 1 ! I I I 1 I i ¡ I I l- 4 TUBING DETAIL . LONG STRING: 2 7/8", 8.4#, N..SO .TUBING 1.) 3 1/2" x 2 7/8" Crossover at 26.68' . 2.) Otis ·XA· Sleeve at 4814.42' 3.) 2 7/8" x 3 1/2" Crossover at 4848.88' 4.) Otis Dual Hydrauüc Packer from 4850.02' to 4856.68' 5.) Mandrel Extension at 4856.68' 6.) 3 1/2" x 2 7/8" Crossover at 4858.10' 7.) Otis 'XA" Sleeve at 4889.38' 8.) Carbide Blast Joint from 4991.73' to 5014.73' 9.) Carbide Blast Joint from 5347.45' to 5384.45' 10.) Carbide Blast Joint from 5401.09' to 5436.09' 11.) Car.bide Blast Joint from 6589.72' to 6625.72' 12.) Carbide Blast Joint from 6967.37' to 6987.37· 13.) Carbide Blast Joint from 7332.71' to 7356.71' 14.) Otis 'XA" Sleeve at 7504.12' 15.) Otis 9 5/8" G.P. Packer with Seal-- Assembly irom 7599.60' to 7610.51' 16.) O:is 9 5/8" G.P. Packer with Seal Assembly from 7707.27" to 7117.27' 17.) Otis 'X" Nipple at 7150.13' 18.) Otis 9 5/8" G.? Packer with Seal Assembly from 7840.73' to 7853.31' SHORT STRING: 3 1/2", 9.2#:, N-SO TUBING A.) Otis 'XA" Sleeve at 4783.35' S.) Otis Dual Hydraulic Packer from 4850.02' to 4856.68' C.) Mandrel Extension at 4846.68' D.) Otis 'XN" Nipple at 4870.86' PERFORATION RECORD DA TE INTERVAL CONDITION , s 16 ro/07/84 10/14/84 10/17184 10/18/84 10/23/84 10/25/84 10/27/~4 11/05/84 11/05/84 11/05/84 7989'-8004....... 7936'-7950'- 7916'-7932' 7642'-7668' 6956'-6962' 7320'-7330' 6580'-6602' 51'b"1;:"~~i6' 5343'-5366' 4987'-4996' .! Upper Tyonek Sd. Open Prod. . Upper Tyonek Sd. Open Prod. Upper Tyonek Sd. Open Prod. Upper Tyonek Sd. Open Prod. Lower Beluga Sd. Open Prod. Lower Beluga Sd. Open Prod. Lower Beluga Sd. Open Prod. Upper Beluga Sd. Open Prod. Upper Beluga Sd. Open Prod. Upper Beluga Sd. Open Prod. . Å f[ NOTE: See Sheet 2 lor Toø Gravel Pack. Isolalion Packer. anó Bononl Gravel Pack Asaertlllly O.tall WELL KTU 13 -5 WELL SCHEMATIC ~... ..8..Ji..£.... C_O. _ '-_'0. ~WI NKS SCAU: NDN£ D.Tf 1122/Ø~ UNION OIL. COIolPAHY 0' CALIFORNIA .l.IIICMO"AGI. 'lAS.. '.UTS ""~u .f KTU 13-5 2006 Workover Proposed Well bore Diagram RKB elevation of 26' 20",93 #,0.438" Wall at 136' 13-3/8", 61#, N-80, at 2500' Upper ¡ Lower Beluaa Perforations MD / TVD (~987 :,14996' 14762-4771' /" 5343 - 5366' /5102-5124' 5401 5416' 15157-5172' 6426 - 6436' 16123-6132' (New Add Perfs) 6500 - 6515' 16192-6206' 6580 - 6602' I 6268-6289' 6856 - 6861' 16529-6534' (New Add Perfs) 6956 - 6962' 1 6624-6630' 7225 - 7233' 16880-6888' (New Add Perfs) 7320 - 7330' 16971-6980' 7504 - 7512' 17147-7154' (New Add Perfs) 2-7/8",6.5#, L-80, EUE Modified 8rd tubing 2-7/8" Sliding Sleeves at 4990', 5400',6540',7350' 2-7/8" Seal Bore Nipple with Locator profile at 7585' 9-5/8" Otis GP Pkr at 7600' Upper Tvonek Perforations MD ¡ TVD 7642 - 7668' 1 7279-7304' 9-5/8" Otis Isolation Pkr at 7701' 3-1/2" BTC 9.3# Blank Pipe 2-7/8" X Nipple at 7750' 9-5/8" Otis GP Pkr at 7841' 3-1/2" BTC 9.3# Blank Pipe wI 3-1/2" pipe based .008 screen Upper Tvonek Perforations MD ¡ TVD 7916 - 7932' I 7542-7551' 7936 -]950' 17561-7574' 7989'/: 800,v 17612-7626' 9-5/8" Cement Retainter at 8039' 9-5/8",47#, N-80 at 8232' Alaska Oil and Gas Conservation Commisssion - Conservation Orde... http://www.state.ak.us/local/akpages/ADMIN/ogc/orders/co/co500_,.. e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Marathon Oil ) Conservation Order No. 510 Company for an order to define a new ) gas pool, Beluga/Upper Tyonek Gas Pool) Kenai Gas Field ) Sterling Gas Pools 3, 4, 5.1, 5.2, 6; ) Beluga/ Upper Tyonek Gas Pool; (') ) andTyonek Gas Pool 1 I 01) ) ~~v ) February 11, 2004 \ ~ ) IT APPEARING THAT: 1. By application dated October 21, 2003, Marathon Oil Company ("MOC") in its capacity as Operator of the Kenai Gas Field requested an order from the Alaska Oil and Gas Conservation Commission ("Commission") to formally define an additional gas pool within the field. 2. Notice of a public hearing was published in the Anchorage Daily News on October 29, 2003. 3. The Commission received no objections to the application or request for public hearing. FINDINGS: 1. Conservation Order 82 set forth Pool Rules for several gas bearing formations within the Kenai Gas Field on December 3, 1969. 2. The pools were designated as Sterling Gas Pools (five separate pools numbered 3, 4, 5.1, 5.2, and 6) and Tyonek Gas Pool. 3. Conservation Order 175 amended spacing restrictions forweHs within the Kenai Gas Field on July 9,1981. 4. MOC requested that the interval from 4587' measured depth (MD) and 9155' MD in the KDU 1 well be defined as the Beluga/Upper Tyonek Gas Pool. 5. The top of the proposed Beluga/Upper Tyonek Gas Pool is coincident with the base of the Kenai Sterling Pool 6. 6. The bottom of the proposed Beluga/Upper Tyonek Gas Pool is coincident with the top of the Kenai Deep Tyonek gas pool. 7. The proposed Beluga/Upper Tyonek Gas Pool is consitent with the recently approved Bureau of Land Management Beluga/Upper Tyonek Commingled Participating Area. CONCLUSIONS: 1. It is appropriate to define a new gas pool per MOC's request. 2. To eliminate confusion, all rules applying to the Kenai Gas Field should be included in one order. NOW, THEREFORE, IT IS ORDERED that: 1. Conservation Orders 82 and 175 are superceded by this order; 100 7/12/20062:51 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... http://www.state.ak.us/loeal/akpages/ ADMINI ogel ordersl eol eo500 _... e e 2. the area described as follows is affected by this order: Seward Meridian T4N, R11W, Section Sections Section Section Sections Section Section Section Section Section Section T4N, R12W, Section T5N, R11W, Section Section Section Section Section Sections Section Section Section T5N, R12W, Section Section Rule 1. Definition of Pools 3: Lot 4, SW 1/4 NW 1/4, W 1/2 SW 1/4 4,5,6,7, and 8: All 9: N 1/2, SW 1/4, W 1/2 SE 1/4 16: N 1/2 NW 1/4, SW 1/4 NW 1/4, NW 1/4 SW 1/4 17 and 18: All 19: Lot 1, NE 1/4 NW 1/4, NE 1/4 20: N 1/2 NW 1/4, SW 1/4 NW 1/4 1: All 2: E 1/2 E 1/2 11: E 1/2 NE 1/4 12: All 13: Lots 5 through 12, easterly 2.50 acres of Lots 13 through 16, E 1/2 NW 1/4 NE 1/4, E 1/2 E 1/2, E 1/2 W 1/2 SE 1/4 NE 1/4, E 1/2 W 1/2 NW 1/4 SE 1/4, E 1/2 SW 1/4 NE 1/4, E 1/2 NW 1/4 SE 1/4, All of W 1/2 NE 1/4, E 1/2 NW1/4 lying westerly of coastline 17: Lots 8 and 9, NW 1/4 SW 1/4, S 1/2 SW 1/4, AI! of Kenai River 18: SE 1/4 SE 1/4 19: Lots 2, 6 through 13, SE 1/4, E 1/2 E 1/2 SE 1/4 SW 1/4, NE 1/4, AI! SE 1/4 NW 1/4, NE 1/4 SW 1/4, S 1/2 SW 1/4 lying westerly of coastline 20: S 1/2, NW 1/4, SW 1/4 NE 1/4, NW 1/4 NE 1/4 28: NW 1/4 NW1/4, S 1/2 NW 1/4, SW 1/4, W 1/2 SE 1/4, SE 1/4 SE 1/4 29 and 30: All 31: Lots 3 through 10, E 1/2, All that portion lying westerly of coastline 32 and 33: All 34: NW 1/4 NW 1/4, S 1/2 NW 1/4, SW 1/4, W 1/2 SE 1/4 25: SE 1/4 NE 1/4, E 1/2 SE 1/4 36: E 1/2 a. The Kenai Sterling Gas Pool 3 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 4,175' to 4,374' in the KU 21-6 well. (Source CO 82) b. The Kenai Sterling Gas Pool 4 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 4,412' to 4,558' in the Ku 21-6 well. (Source CO 82) c. The Kenai Sterling Gas Pool 5.1 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 4,576' to 4,859' in the KU 21-6 well. (Source CO 82) d. The Kenai Sterling Gas Pool 5.2 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 4,880' to 5,213' in the KU 21-6 well. (Source CO 82) e. The Kenai Sterling Gas Pool 6 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 5,250' to 5,520' in the KU 21-6 well. (Source CO 82) 20f3 7/12/20062:51 PM Alaska Oil and Gas Conservation Commisssion - Conservation Orde... e " hrtp:/ /www.state.ak.us/loeal/akpages/ AD MIN/ oge/ orders/ eo/ e0500 _... e f. The Kenai Beluga/ Upper Tyonek is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 4,St37' to 9,155' in the KDU NO.1 well. (Source this order) g. The Kenai Tyonek Gas Pool 1 is defined as the accumulation of gas common to and which correlates with the accumulation found in the interval 9,155' to 9,890' in the KDU NO.1 well. (Source CO 82) Rule 2. Well Spacina There shaH be no restrictions as to well spacing except that no gas pay shall be opened in any well which is closer than 1,500 feet to the unit boundaries. (Source CO 175) Rule 3. Casina and Cementina Requirements Surface casing shall be landed at not less than 1,200' or more than 2,000' and cement shall be circulated to the surface. (Source CO 82) Production casing shall be landed through the completion zone and cement shall cover and extend to at least 500' above each potentially productive sand interval. The use of multi-stage cementing procedures shall be permitted. Alternatively a casing string shall be adequately cemented at an intermediate point and a liner landed through the completion zone, If a liner is run, the annular space behind the liner shall be filled with cement to at least 100' above the casing shoe or the top of the liner shall be squeezed with sufficient cement to provide at least 100' of cement between the liner and casing annulus. Cement must cover all potentially productive intervals behind the liner. Casing and well head equipment shall be hydrostatically tested to not less than 2,000 pounds per square inch pressure. (Source CO 82) Rule 4. Computed Bottom Hole Pressure Surveys A key well bottom hole pressure survey shall be taken in each pool upon Commission request; however, such surveys shall not be required more often than twice in any calendar year. Bottom hole pressure may be computed from surface measurements taken with a dead weight tester provided, however, than an approved bottom hole measuring device shall be used when the accuracy of the computed bottom hole pressure is questionable. The time, length and kind of survey, number and location of the wells to be tested, datum and other details may be determined by the operator subject to Commission approval. (Source CO 82) IT IS FURTHER ORDERED that: Commingling of production from the Kenai Sterling Gas Pool 4 and the Kenai Sterling Gas Pool 5.1 in well KU 33-32 is allowed. (Source CO 82) DONE at Anchorage, A!aska this 11th day of February 2004. John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission --,,;;,~=-.- Conservation Order Index Home Webmaster _~_X_"_"'X_"_H_V__',___,_ 3 of3 7/12/20062:51 PM ( { MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the Dl 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 some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X -06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 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 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32~07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 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 200-1 79 KBU 44-06 S(ÇA~~~eD Jt\N 2) @ 2004 Union Oil and Gas [~--"~on' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union January 28, 1985 Dear Hr. Chatterton: Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUNDRY NOTICE KTU 13-5 Attached is a Sundry Notice Subsequent showing correct values for the Completion Report submitted to your office on January 19, 1985 If you have any questions, please do not hesitate to contact me at the telephone number listed above, Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachment RECEIVED JAN 2 9 1985 Alaska Oil & Gas Cons. Commiss{on Anchorage STATE OF ALASKA ALASKA (.,iL AND GAS CONSERVATION CO~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-108 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 so- 133-20370 4. Location of Well 144'S & 4169' E of NW Corner, T4N, RllW, SM 5. Elevation in feet (indicate KB, DF, etc.) PAD 66' MSL 6. Lease Designation and Serial No. A-02814-2 9. Unit or Lease Name KENAI TYONEK UNIT 10. Well Number KTU 13-5 11. Field and Pool KENAI GAS FIELD 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please correct the following values on the Completion Report previously submitted to your office on January 19, 1985. 8232' TVD & 7843' TMD Top of Production - 1074'N & 232' W of SE Cot, Sec 7, T4N, RllW, SM Bottom Hole - 1958' N & 274' E of SW Cot, Sec 5, T4N, RllW, SM. RECF_iVF_D ~ 6 hi '1¢' Alaska Oil & (;as cOons. Oommission Anchorage 14. I hereby~hat t~fo~~e and correct to the best of my knowledge. S~,n.d Lawrence u. uu~znq Title ENV~RONNENTAL SPEC~AL~ST The space below for Commission use Date 01/28/85 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date .... Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /-~.- Union Oil Company.o~,California unl,on DOCUMENT TRANSMITTAL January 4, 1985 HAND DELIVERED TO: William Van Alen FROM: R.C. Warthen N. L. Gilmont LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Regarding well KTU 13-5~ Kenai Gas Field: One (1) list of sidewall core'depths One (1) copy Sperry-Sun Directional Survey #AK-BO-40076 One (1) copy each Formation Testing Service Report (Halliburton) for DST nos. 1,2,3,4,5,6a,6b,7,8,9,10,12 One (1) blueline and one (1)'sepia of the following logs: 2" DIL-GR 5" DIL-GR 2" BHC-GR 5" BHC-GR 2" LDT-CNL Raw Data 5" LDT-CNL Raw Data 5" LDT-CNL Porosity 5" Gamm_9.~qay Correlation Log 5"C/em'entBond Log ~~PLEASE ACKNOWLEDGE RECEIPT BY SIGNING RETURNING ONE COPY OF THIS DOCUMENT DATED: Alaska Od ~ f~s Cons. Comm'ssior, Union Oil Company c'-.California union January 4, 1985 SIDEWALL CORE DEPTHS, WELL KTU 13-5 3389' 3389.5' 3390' 3391' 3392' 4082' 4092' 4112' 4114' 4116' 4145' 4147' 4233' 4263' 4304' 4312' 4324' 4343' 4372' 4387' 4990' 4994' 5141' 5285' 5404' 5920' 6584' 6598' 6955' 6962' 7508' 7643' 7645' 7647' 7649' 7653' 7655' 7657' 7663' 7667' NLG/pg 694D Union Oil and Gas Di~-"3n: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union January 21, 1985 Hr. C.V. Chatterton Ak. Dept. of Oil & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, AK 99501 Dear Hr. Chatterton: Well Completion KTU 13-5 Kenai Gas field Please find attached the Well Completion Report for KTU 13-5. The well was completed as of January 4th, 1985. Completion equipment was installed and the well was placed on an extended test on December 22nd, 1984. The drill-rig was placed on standby over the well with temporary production hook-ups through January 4th, 1985. Experiencing no further problems with the gravel pack from the long-string, the well was shut-in on January 4th, and the drill-rig was removed. Rermanent hook-up was made to the production facilities and the well was placed on full production on Sanuary llth, 1985. LOC/ti Very truly yours, Lawrence O. Cutting ENVIRONHENTAL SPECIALIST RECEIVED JAN 2 1 1985 Alaska 0il & Gas Cons. Commisslon Anchorage STATE OF ALASKA :,-~-' ALASKA L~-_ AND_GAS CONSERVATION COb., =,,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well · OIL [] GAS ~i SUSPENDED [] ABANDONED [] SERVICE [] :~. Name of Operator 7. Permit Number UNION 0TL COMPANY OF CALTFORNTA 84-108 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- ] 33-20370 4. Location of well at surface 9. Unit or Lease Name 144'S & 4169' E of NW Cor, Sec. 7, T4N, RllW, SN Kenai Tyonek Unit At Top Rroducing Interval 10. Well Number 4184'S & 4809' E of NW Cor, Sec. 6, T4N, RllW, SN. KTU 13-5 At Total Depth 11. Field and Rool 3306' S & 65' E of NW Cor, Sec. 5, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kenai Gas Field Pad 66' MSL A-028142 12. Date Spudded 13. DateT. D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 8-14-84 8-31-84 01-04-85 N/A feet MSL] 2 17. To~tal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8232 'MD + 7828 ' T ID YES ~ NO []I N/A feet MD 22. Type Electric or Other Logs Run LDT/CNL/GR/CAL; VDL/CBL, DISF/GR/SP/BHC 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 136, Driven --- 13 ~/~ 6i~ K-~ surface z~O0' i? i/2" ±3uu sxs ci ,,G,, ___ 9 5/R' 474~ N-SO S~irfae~ R?37' ]? ]/4 ]gOO .~xs n] ,,~,,, ___ 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) U. TYONEK BELUGA -~ 1/2" ~-~ 4877' 4RSR' 7989' -8004 ' W/16HPF 7320 '-7330' w/8HPF 2 · 7/R" LS 7gl ] ' 7gO~] ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7936 ' _7950 ' w/8HPF 6956'-6962, W/12HPF .. 7916 '-7932 ' w/4HPF 6580'-6602' w/8HPF DEPTH INTERVAL (MD) AMOUNT a KIND OF MATERIAL USED 7642 '-7668 ' w/9HPF 5401 '-5416' w/8HPF 7~?,-Rn?o, Gravel_ P~ok w/40-60 _~nd 5343'-5366' w/8HPF 7989'-~nn4' Ac~_d~zed w/200n?~ HP.~ 4987 '-4996' 'w/8HPF · SEE ATTACHED CDDENDUN , 27. PRODUCTIoN TEST Date~First' Production I Method· of Operation (Flowing, gas lift, etc.) i 01-11-85I Flo~J~ng DateofTest Hours Tested PRODUCTION FOR OIL-DEL C_~;M~F. 9~ ~~L CHOKESIZE IGAS-OILRATIO 12-22-84 24 hrs., L. ~T. ES~ F~.R~O.D ~ ........ LS, O. 7E MM£FPD,- F~)~O~bi~lsi~t~asing Pressure CALCULATED_ ~' OIL-DEL ~3~S,-MS~m6 WATER-DEL OIL GRAVITY-APl (corr) Rrb~'800 l')-q!':as N/A 24-HOuRRATE~'w LS,-Same ! 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Sidewall Cores were taken at. the. following depths. 3389 ' 4112' 4263' 4387' 5902' 7643' 7657 ' 3~89.5" - 4114' 4304.' 4990' · 6584' ,7645' 3390' 4116' 4312' 4994' 6598' 7647' 7667,:,r;~ 3391 ' 4145 ' 4324 ' 5141 ' 6955 ' 7649 ' 4082' 4147' ~4343' ~ -:5285r 6'62' 7653' 4092 ' 4233 ' 4372 ' 5404 ' 7508 ' 7655 ' Form 10-407 Submit in ~l~l,i,c, ate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. · " ' ' '30. " . . ~, GEOLOGIC MARKERS FORMATION TESTS ~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top A-8 3786' 3613' 1.) Attached is a list of intervals tested Top B-1 3986' 3804' with results. Top C-1 4704' 4490' 2.) Gravity of the gas recovered was 0.557 Top Beluga 4936' 4713' 3.) Upper Beluga Zone 4987'-4996' was Top Tyonek 7618' 7255' tested for pressure build-up. A stable reservoir presssure of 1173 psia was recorded with a calculated permeability of 180md SEE ATTACHED ADDENDUM 31. LIST OF ATTACHMENTS 32. I hereby~t/~.ore~and correct to the best of my knowledge S~g.ehawrence 0.CuttingTitle FNVTRRNMENTA. L Date n] _] R_~c; ~F'r'T ~1 T~T ~ 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". LLIBURT SERVICES NO. 65226900 29-NOV-B4 KENR] FORMRT I ON TEST I NG SERV I CE REPORT ~q2~ 0 BLANKED OFF: NO HOUR OF CLOCK: GAUGE NO: 216 DEPTH: .~ .... i ! PRESSURE TIME !TYPE ID DESCRIPTION ~N~TI~L HYDROSTRTTC .~ P92} 2924 i , i B [NZT~RL FIRST FLOW GAUGE NO= 2i5 DEPTH= 5926°0 BLANKED OFF= NO HOUR OF CLOCK; 12 IDI DESCR}PTtON I PRESSURE TIME TYPE REPORTED J CALCULATED REPORTED I CALCULATED R !N!TiP,,L HY~ROST;qTiC I 2933 29450 B INITIfiL FIRST F', OW 2]9 95,0 95,0 F C FINAL FIRST, . FLnWu 2i9 233 o 3 D FINtqL HYFJROSTRTIC 2933 EQU IPHENT & HOLE DATA TICKET NUMBER: 6522~900 FORMATION TESTED: BELUG~ NET PRY [ft)~ DRTE~ 11-18-84 TEST NO~ 3 GROSS TESTED FOOTAGE: 404.0 TYPE DST: WATER SHUT OFF ALL DEPTHS MEASURED FROM: KELLY BUSHING CASING PERFS, (ltl: HALLIBURTON CAMP: HOLE OR CASING SIZE [in]: 9°625 HENRI ELEVATION [¢~1: 91 TOTAL DEPTH (ft): 6320.0 DICK PIKE PACKER DEPTH[S) (ft): s9~6 TESTER:. FINAL SURFACE CHOKE [in)~ 0.250 BOTTOM HOLE CHOKE [in]: 2°250 WITNESS: MUD WEIGH~ Ilb/gol]: 10.00 MUD VISCOSITY 'DRILLING CONIRR£TOR: ESTIMATED HOLE TEHP, l°F]: 120 BRINKERHOFF SIGNAL ACTUAL HOLE TEMP, (°F): ~ Ct FLUID PROPERTIES FOR RECOVERED MUD & WATER SAMPLER DRTR SOURCE RESISTIVITY CHLORIDES Petg RT SURFACE: ~ °F pp~ cu,ft, OF ORS: © °F ppm cc OF OIL: ~ __OF ppm cc OF WATER: © __°F ppm cc OF MUD: 0 I°F ppm ©__°F ppm TOTAL LIQUID HYDROC9RBON PROPERTIES CUSHION DRTR OIL GRAVITY [°RPI}: © __oF lYRE AMOUNT WEIGHT GAS/OIL RRTIO:(cu.ft, pen bbl): FRESH H20 (FT.) 470.0 8.33 GAS GRAVITY: RECOVERED: REMARKS: REPORTED ELEVATION HERSURED RI GROUND LEVEL IS 66'° UNABLE TO RERD FINAL HYDROSTATICS DUE TO GAUGES BEING OVERPRESSURED. ! TYPE & SIZE MEASURING DEVICE: I TICKET NO: 65226900 T~"E S~E PS! M£F BPD 1G30 5THRTED CLOCKS 1850 STARTED IN HOLE WITH TOOLS 1925 SET PHCKER ~930 .25 OPENED HUXILIflRY VHLVE LIGHT BUBBLES IN BUCKET ~9A5 .25 NO BUBBLES 2105 SHUT IN HT SURFHCE FILLED DRILL PIPE WITH MUD 2120 PULLED RTTS LOOSE-REVERSEO OUT. 2200 RUN ~ STHNO IN REVERSE OUT 2225 PULLED OUT OF HOLE 1230 OUT OF HOLE WITH TOOL TICKET NO. 65226900 LENGTH DEPTH DRILL PIPE ...................... aUXILIaRY VALVE ................. CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... BUNDLE CARRIER .................. 3.500 2.802 5901.0 4.680 2.400 6,000 2.620 6,500 2.400 7.950 8.400 6,000 2.620 5,380 2,250 7.6 0.7 4.0 5.9 1.0 7.9 5906.0 5912.0 5916.0 5926.0 TOTRL DEPTH 6320.0 EQUIPMENT DATA EQUATIONS FOR DST LIQUID WELL ANALYSIS kh 162.6 QB md-ft Transmissibility - p, m cp Indicated Flow kh Capacity kh -- -- P- md-ft Average Effective kh md Permeability k = '~- Damage Ratio DR = .183 P*- Pf Theoretical Potential Q~ = Q DR BPD w / Damage Removed Approx. Radius of r~ = 4.63\. kt ft Investigation EQUATIONS FOR DST GAS WELL ANALYSIS Indicated Flow 1637 Qg T md-ft Capacity kh = m Average Effective kh md Permeability k = ~ Skin Factor S = 1.151 k(t/60) ] m(P*)-m(Pf)m - LOb d, I~ Ctrw2 -t- 3.23 Damage Ratio DR -- m(P*)- m(Pf) m(P*) - m(Pf) - 0.87 mS Indicated Flow Oe m(P*) MCFD Rate (Maximum) AOF~ -- m(P*)- m(Pf) / Indicated Flow .& / m(P*) MCFD Rate (Minimum) AOF2 -- QgV m(P*)-m(Pf) / Approx. Radius of ,~,/ k(t/60) ft Investigation r~ = 0.032V 4)p, ct LLIBURT SEP, VICES TICKET NO. 65227000 29-NOV-84 KENR] FORMRT I ON TEST I NG SERVI CE REPORT .i, OPtUGF_ NO: 81.'4", OEP-tH: ..... 8'-~6,q "-'_, BL,qNKFD_ OFF: NO HOUR OF CLOCK:.. _2/¢_ IB DESCRi PT iON F f N"-" '-'~ _ n~ H'-(i i,,Oq i HT i C PRESSURE REPORTED I £RL£ULRTEO 212 215,6 212 215,6 3]58 3172:6 R E F';":P, T E 6 -' ~LCUL~i ED 1' Y P E GOUGE NO: 6!42 OEPTH: 6:3?2: 8LBNKEO OFF: NO HOUR OF CLOCK:_ _~-'~ DESCRI PT i i ,i"'TTiFt HYDROSTRTiL- I ~ I iNiTIF~L FIRST I C ! FiN~L FIRST F~ I D PRFSSU~ REPORTED j £,qL £UI_I~T EO 3!6:? 3172.0 REPORTED 98:0 22W 221.7 IF!N~L HYDROSTATIC 3i63 3181~ I EQUIPMENT ~ HOLE DATA TICKET NUMBER: 65227ooo FORMATION TESTED: BELUGA NET PAY (f~): DATE: .11-18-84 TEST NO: 4 GROSS TESTED FOOTAGE: 81.0 TYPE DST: WATER SHUT OFF ALL DEPTHS MEASURED FROH: KELLY BUSHING CASING PERFS. HALLIBURTON CRHP: HOLE OR CASING SIZE Iin): ~.~5 KENAI, ELEVATION {?~): 91 TOTAL DEPTH (f~): 6421.0 DICK PIKE PACKER DEPTH[S) {Pt): 6360 TESTER: FINAL SURFACE CHOKE {in): 0°250 BOTTOM HOLE CHOKE Iin): 2 250 WITNESS: HUD WEIGHT (lb/gal): 10o00 MUD VISCOSITY DRILLING CONTRACTOR: ESTIMATED HOLE TEMP. [°F): 120 B~INKERHOFF $iGN~L ACTUAL HOLE TEMP. (°F): © ft FLUID PROPERTIES FOR RECOVERED HUD ~ WATER SRHPLER DRTR SOURCE RESISTIVITY CHLORIDES Ps~g RT SURFACE: 0 __OF ppm cu, ft. OF ORS: o __°F ppm cc OF 0 IL: © __°F ppm cc OF WRTER: © __°F ppm cc OF HUD: o __°F ppm o__°F ppm TOTAL LIgUID cc: HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY (°CPI]: ~ __oF TYPE AMOUNT WEIGHT GAS/OIL RATIO (cuof~. pep bbl): FRESH WATER (FT) 470.0 8.33 GRS ORRVITY: RECOVERED: REMARKS: REPORTED ELEVATION MEASURED ~l GROUND LEVEL IS 66'. TYPE ~ SIZE HEASUR]NG BEV]CE: I TICKET NO: 65227000 SURFACE GAS LIQUID T~ CHo~ ~ssu~ ~ ~T~ RE H~RKS ......... 174~ STARTED CLOCKS. 0050 STARTED TOOLS IN THE HOLE. 0330 ON BOTTOH WITH TOOLS. 0355 .25 0 OPENED TOOL WITH LIGHT BUBBLES THROUGH THE HOSE. 0410 .25 0 NO BUBBLES. 0533 CLOSED TOOL. FILLED DRILL PIPE WITH HUB. REVERSED OUT. 0620 STARTED OUT OF THE HOLE. 0827 OUT OF THE HOLE. . TICKET NO, 65227000 ! 97 5 56 71 5 5 80 80 O.D. I.D. LENGTH DRILL PIPE ...................... AUXILIARY VALVE ................. CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... CROSSOVER ....................... AP RUNNING CASE ................. AP RUNNING CASE ................. 3,500 2.602 6346,0 4.680 2.400 6.000 2.620 6.500 2,400 7.950 2,400 6.000 2.620 4.750 2,620 5.000 2.250 5.000 2,250 6,8 0.7 4,0 5.9 1.0 1.0 4.2 4.2 TOTAL DEPTH EQUIPMENT DATA DEPTH 8251.0 6S56.0 6360.0 6368.0 6372,0 6421.0 LLIBURT SEI~ViC£$ TICKET NO. 65227]00 30-NOV-84 KENRI FORMRT I ON TEST I NG SERV I CE REPORT GAUGE ID b~SCr~.! PT I ON ~NiT~'-"~,= MYDROST;qTIC .. ~.~, r LO~ F:~NA',~ FIRST FINAL HYDROSTaTiC NO: 6'!4! DEPTH: 6368.0 BLANKED OFF: NO HOUR OF CLOCK: PRESSURF REPOEIED i CRLCULFITED ~,..8:7 257.4 T ! ME REPORTED I CALCULATED--' 100.0 100:0 3213 3!54~ ! TYPE ORUOE aO: 6~=~ BcPTH~,_ 637s._,0 DESmRiPTIONu _ BLANKEO OFF: PRESSURF REPORIEO i gi:IL C UL P,~- [ O l'.iO HOUR OF CLOCK: 24 · TiME ..... J TYPE 3!48 2OO 254 ]O0~ 0 F 3148 EOU i PMENT ~ HOLE DATA TICKET NUMBER= 65227100 FORMaTiON TESTED: BELUGfl NE7 PRY [ftJ: BRTE: ,I1-19-84 TEST NO: 5 GROSS TESTED FOOTRGE: 119o0 TYPE DST~ WRTER SHUT OFF RLL DEPTHS HEgSURED FROH~ KELLY BUSHING CRSING PERFS. Ifil: HRLLIBUR~ON CRMP~ HOLE OR CgSING SI~E [in]: 9.825 HENRI ELEVRTION (ltl: B1 TOTRL DEPTH If~]~ 8~79.0 OICR PIKE PRCKER DEPtH(SI (f~]: 6380 ~ESTER~ FINRL SURFRCE CHOKE Iin]: 0.250 BOTTOM HOLE CHOKE (in]: 2.250 WITNESS: HUD WEIGHT lib/roll: ~0.00 MUD VISCOSITY DRILLING CON~RRCTOR~ ESTIMRTED HOLE TEMP. [°FI~ 120 BRiNKERHOFF SIGNBL RCTURL HOLE ~EMP. (°F): ~ FLUID PROPERTIES FOR $flHPLER DRT~ RECOVERED MUD & W~TER SOURCE RESISTIVITY CHLORIDES Psig R~ SURFRCE: o ~F ppm cu.f~, OF ORS: © °F ppm cc OF OIL: © °F ppm co OF WRTER: o °F ppm cc OF HUD: 0 °F ppm © °F ppm TOTRL LIOUID cc: HYDROCRRBON PROPERTIES CUSHION DRTR OIL GRRVITY I°R?II~ e ~°F TYPE RHOUN7 WEIGHT ORS/OIL RRTIO (cuofto per bb!): FRESH WRITER [FT] 470.0 8°33 ORS GRRVITY: RECOVERED: o> , REM~R~$: REPORTED ELEVRTION HEflSURED RT GROUND LEVEL IS _ TYPE & SIZE I'.iE6iSUR]NG DEW]CE: I T~CKET NO~ 65227100 SURFRCE GAS L]OU]D CHOKE ~ s~ ~su~ ~ ~ REMARKS PS] HCF BPO .......... 11-18-8A ~815 STRRTEB CLOCKS 1845 STRRTEO TOOLS IN HOLE 2115 ON BOTTOM 2255 SET RTTS 2300 .25 0 OPENEO RUXIL!RRY VRLVE WITH LIGHT BUBBLES IN BUCKET 11-19-84 0030 .RS 0 LIGHT BUBBLES 0040 SHUT IN RND PUHPEO OOVN DRILL PIPE TO FILL 0055 PULLED PRCKER LOOSE RNO REVERSEO OUT 0230 STRRTEB OUT OF HOLE ,, 0430 OUT OF HOLE . , TICKET NO: 65227100 CLOCK NO: 13737 HOUR: 24 REi~i~ MINUTES IPRESSUREI /~P FIRST FLOW B 1 3 5 9 lo 0.0 lO.O 20, 1 30 0 4o 0 5o 0 60 0 7o 0 8o 0 90,0 100.0 208.7 211.4 215.0 218.3 222.0 227.4 234.6 241.4 248.9 257. 1 257.4 2 8 3 8 3 3 3 7 5 4 7 2 6 8 7.5 8.1 0.3 i GRUGE NO: 614_i DEPTH: 6368,0 REF I MINUTES IPRESSUREt AP ,, REHRRKS: TICKET NO: 6.5227100 CLOCK NO: 16147 HOUR: 24 HINUTE5 PRE.oUR.: AP ~ t xAt I · t t+At I ~ °g'"~- FIRST FLOW 0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 loo.o 22O 6 223 5 226 6 23O 0 233 7 239 2 245 8 253.3 261.4 269.4 270.8 2.9 3.2 3,3 3.7 5.6 6.5 7.5 8,1 8.0 1.4 '--~ GRUGE NO_: F;'i LLIBUB?©N' DE-PTH- 6372 t t+At I~ t+At REHRRKS: TICKET NO, 65227[00 O.D. LENGTH DRILL PIPE ...................... RUXiLIRRY VgLVE ................. CROSSOVER ....................... RTT5 CIRCULRTING VRLVE .......... CRSING PgCKER ................... CROSSOVER ....................... CROSSOVER ....................... BP RUNNING CgSE ................. RP RUNNING CRSE ................. 2.602 6346.0 4.680 2.400 6.000 2.620 6.500 2.400 7.950 2.400 6.000 2.620 4,750 2,620 5.000 2.250 5.000 2.250 7,6 0.7 4.0 5.9 1.0 1.0 4.2 4.2 TOTAL DEPTH EQU I PMENT DRTR DEPTH 6351.0 6356.0 6360,0 6368.0 6372,0 6479,0 LLIBURTO $ E P~/! C ES _ ?]CKET NO. 65229]00 29-NOV-84 KENR] F ORHR T I ON TE $ T I NG SERV l CE REPORT GRUOE NO: G1~'1 DEPTH: n330.6 BLBNKEO OFF: N8 HOUR OF CLOCK:._2/~ iD D PRESSURE REPORTED J CRL CULF-;T ErJ 3148 3121~3 i'65 207~6 165 207,6 FiNSL HYDe-TEST P 3127~5 INITIAL HY© !L© T~JTTTOi ......... rLO?/ TEST F~NRL FLO\4- L:.Jl 3!46,4 165 2!0.9 !65 2!0,9 3!48 3i39:7 T JHE 9]: T Y P E nUuL NFl:_ 6142. OFF ~H:_ .G 93 "'=: ~, Ri .... F-tNfiEn OFF: NO HOUR OF DE.C, OR i PT ~ i r,,i T T T"-:' FL .... ~L TEST FT_N'-"'nL FLOW-TFqT fi ITNiTiP, I HY'~ T~-ST FiNR~ FI OW TEsi 5 H FIN~.~ HVD -FF°T F~ ~ ~ .... - _o 3'-"~9~, J 1.39 INTTiRL F' nW-TEST F! _ - ~ t_ L-' , , _ J iN~L HYD.-TEST fi 3!2q~3 h _ T ] ME -r ',' P F- REPORTED __ _ . 9I . 0 .} EOU I PMENT & HOLE DATA TICKET NUMBER, 65229100 FORMATION TESTED= NET PAY (¢t)= BATE= ~1-20-8~ TEST GROSS TESTED FOOTAGE: 107.0 TYPE DST: W~TER SHUT-OFF ~LL DEPlHS MEASURED FROM: R~ KELLY BUSHING C~SING PERFS. [f~): H~LLIBURTON C~HP: HOLE OR CASING SIZE (tn): 9.625 KENRI ELEVATION (ft): 91 TOTAL DEPTH Irt): 6~32.0 J. R~ POINOEXTER PACKER DEPTH[S) (fi): 6325 ~ESTER: . FINAL SURFACE CHOKE {~n): 1.000 BOITOM HOLE CHOKE [~n): 0.750 WITNESS LARRY GRAHAM MUD WEIGHT Ilb/gol): 10o20 MUD VISCOSITY (seo): DRILLING CONTRACTOR: ESTIMATED HOLE TEHP. [°F): 150 BRINKERHOFF SIGNAL ACTUAL HOLE TEMP. [°F): m fi FLUID PROPERTIES FOR SAMPLER DATA RECOVERED MUD & WATER SOURCE RESISTIVITY CHLORIDES Psig RT SURFACE: o °F ppm cu.¢t. OF GRS: © °F ppm cc OF OIL: ~ °F ppm cc OF WflTER: e __OF ppm cc OF HUD: ~ __°F ppm © __°F ppm TOTAL LIQUID cc: HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY [°BPI]: ~ __oF TYPE AMOUNT WEIGHT GAS/OIL RATIO [cu.ft. per bbl): FRESH WATER [FT] 470.0 8~33 GAS GRAVITY: RECOVERED: REMARKS: REPORTED ELEVRIION MEASURED RT GROUND LEVEL IS ALL DEPTHS FOR SECOND TEST (TEST 88) ARE 35' LOWER THAN DEPTHS LISTED ON THESE SHEETS. ....... 0026 STARTED CLOCKS 0030 MADE UP TOOLS 0104 RAN IN HOLE WITH TOOLS 0340 MADE UP HERO ANO SURFACE EOUIPMENT 0358 SET RTTS 0401 OPENEO TOOL 0~02 1 0 0 0 VERY WEAK BUBBLES 04]8 NO BUBBLES 05~3 UNSERTEO PACHER TEST "BTM 0535 RAN IN HOLE 35' 0547 SET PACKER 05~§ 1 0 0 0 OPENEO TOOL 0550 VERY WEAK BUBBLES 08]0 NO BUBBLES 0720 UNSEATEO PACKER 0725 RIGGEO DOWN TEST LINES 0732 RAN IN HOLE TO 84]2' 0734 RIGGEO UP TO REVERSE OUT 0752 SHERREO PUMP OUT SUB 0755 STARTEO CIRCULATING HOLE 0830 PULLEO OUT OF HOLE WITH TOOLS ]054 TOOLS OUT OF HOLE TICKET NO, 65229100 O.D. LENGTH DRILL PIPE ...................... PUMP OUT REVERSING SUB .......... CROSSOVER ....................... HYDROSPRING TESTER .............. CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... CROSSOVER ....................... AP RUNNING CASE ................. RP RUNNING CASE ................. 3.500 2.602 63!0.0 4.000 2.250 5.000 2.300 5.000 O.TEO 6.250 2.250 6.250 2.250 6.250 2.250 5.000 2.330 5.000 2.310 5.000 2.250 5.000 2,250 1,0 5.0 1.0 4.1 5.9 1.0 1.0 4.! 4.! TOTAL DEPTH EQUIPMENT DATA DEPTH 63!0.7 6315.0 6318.7 6325.0 8330.6 6334.7 6432.0 i LLIBURT SERVICES TICKET NO. 65229200 29-NOV-84 KENRI FORMRT I ON TEST I NG SERV I CE REPORT GAUGE NO: 6!41 DEPTH: 65!0.3 BLANKED OFF: NO HOUR OF CLOCK: t PRESSURE TIME DESCRIPTION REPORTED ! CRLCULATED REPORTED I CALCULATED I fi TN!Ti~' . , c · _ nL HYOROSTfiT i C 3180 3.si04 ? 342 250~2 iN!TlfiL FIRST FLOW i F!NfiL FIRST FLOW 102.0 102.0 I~INAL HYDROST~TiC 3P46 sP's4 O TYPE GP, USF_ NO: Gl -'-'_'.2. DEP}H: 6514.q.. BI_P, NKED OFF: lq'-'., HOUR OF CLOCK ' t PRESSUP'E ] TIME ITYPE iD ! DESCRIPTION ~u , OR ~TtC 3i 81 31°- t I B _lNiTifi'~ FIRST FLO~I 3SF) 253 ~ ]02.0 ]02.0I F ....... ~' ~ 576:P J El ~ FINAL HYDROSTaTiC 3185 3~35~6 ~. TIHE CHOEE PRESSURE RATE RATE REHRRKS SIZE PS1 MCF APO .... 11-21-84 1050 STARTED MAKING UP TOOLS 1055 STARTED CLOCKS 1112 RAN IN HOLE WITH TOOLS 1335 RIGOEO UP HERO & SURFACE EQUIP- MENT 1350 SET RTTS PACKER 1353 1 0 0 0 OPENED TOOL WITH R WEAK BLOW 1400 1 0 0 0 STRONG BLOW-REMRINEO SAHE UNTIL 1S28 1S26 CLOSED ON SURFACE 1533 OPENED ON SURFACE ]S3S STARTED PUMPING FOR INJECTION ]SS0 STOPPED INJECTION TEST AT 1000~- , 55 PSI/MIN. BLEO OFF 1555 TOOLS BLEO DOWN 15S7 UNSEATED PACKER 1828 RAN IN HOLE ANO TAGGEO CEMENT RETAINER 16SS SHEAR PUHPOUT AND STARTEO REVERSE CIRCULATING - PULLED OUT OF HOLE . NO: 65229200 CLOCK NO: 13729 HOUR: 24 / GFIUGE NC]: 614i / 1 DEPTH- F~510:3 NINUTES PRESSURE /~P 't -',- At o g.~,.{- FIRST FLOW B 2 3 8 '7 8 9 11 12 13 0 0 8 0 16 0 24 0 32 0 4O 0 48 0 56 0 64.0 72.0 80,0 88.0 96,0 102.0 250.2 356.2 385.2 423.8 446.1 467 3 486 4 504 8 518 1 525 6 530 0 536 3 550 9 572 1 106.0 29.0 38.6 22,3 21.2 19.1 18.4 13.3 7,5 4.4 6.3 14.6 21.1 REMRRKS: LLIBURT DEPTH: 6S 14 3 CLOCK NO: ~i47 HI]UR: 24 ...¥,¢.. ~ I i I t~' I' '*~*ll I I I I ,x~, MINUTES PRESSURE AP t+Atj'og I REF MINUTES PRESSURE BP t FIRST FLOW B i 0.0 253.2 2 8.0 359,6 3 16.0 390.1 4 24.0 422.4 5 32.0 451.9 6 40.0 472.0 7 48.0 490.0 8 56.0 508. t 9 64.0 520.5 10 72,0 528, ! 11 80,0 532.4 12 88.0 539.6 13 96.0 555,5 C 14 102.0 576.2 106 5 30 4 32 4 29 5 20 1 180 18 1 124 7.6 4.3 7,3 15,8 20.7 REMRRKS: TICKET NO, 65229200 O.D. LENGTH DRILL PIPE ...................... PUMP OUT REVERSING SUB .......... CROSSOVER ....................... HYDROSPRING TESTER .............. CROSSOVER ....................... CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... CROSSOVER ....................... AP RUNNING CASE ................. NP RUNNING CNSE ................. 3.500 2.602 6486.9 3.500 2.250 3.750 2,300 5.000 0.750 5.000 2.250 6.250 3.000 6.25O 2,250 6.250 2.250 6.250 2.S00 5.000 2.250 5.000 2.250 5.000 2.250 1,0 0.7 5.0 0,7 0.7 4.0 5.8 0.7 1,0 4.0 4.0 TOTAL DEPTH EQUIPMENT DATA OEPTH 6486.8 0493.0 6498.0 6504.0 6510.3 6514,3 6566.0 LLIBURT SERVICES TICKET NO. 65229400 29-NOV-84 KENR] F ORMR T I ON T E $ T I NG SE RV I C E REPORT 6RUGE NO: 6 4! DEPTH: 6510.3 BLRNKED OFF: NO HOUR OF CLOCK r- i I PRESSURE ! TIME TYPE IDi DES£R]PTIONi REPORTED I CRL£ULRTED ~ I !NiTi~L ,'-¥~O~!C I 3197 3198~ J B ~ INIT~RL Fi?ST FL3¢/ 3~ 2~0,7 - 27, C,, 2-/, 0 F C · FINAL FiS~:'3T Fi ;-~,~: 389 I . . · o204 32 I GRUGE NO: 6!42 DEPTH: 6214.3 BLRNKED OFF: NO HOUR OF CLOCK: i PRESSURE ] TIME TYPE IDI DESCRIPTION i R~PORTEO] CnLCULnTEO i REPORTEO ' ERLC~,L~TEb i S INITiaL ~vBRAST~*~- i 3J38 3~02 7I 8 INITifiL FIRST FLOW I .Ju 262c8 27,0 '' - OI FINAL HYDROSTBT~E I 3656 3228 7I EQUIPMENT & HOLE DATA TICKET NUMBER: ~5229~00 FORMATION TESTED: NET PAY Irt): BATE: 11-23-8A ~EST NO: 8 GROS~ TESTED FOOTAGE: 62,0 TYPE DST: WATER SHUT OFF ~LL DEPTHS MEASURED FROM: R.KELLY BUSHING C~SING PERFS. {Fi]: H~LLIBUR}ON C~HP: HOLE OR C~SING SIZE I~n]: ~.825 KENBI ELEVATION (rt}: 91 TOTAL DEPTH [f~): 6566.0 J.R. POINDEXTER PACKER DEPTH[S) {ri): 6504 TESTER: FINAL SURFACE CHOKE [in): 1.000 . PRUL SPIRO BOT}OM HOLE CHOKE (tn): 2 250 WITNESS: MUD WEIGHT [lb/g~l): I0.20 HUD VISCOSITY (sec): 28 DRILLING CONTRACTOR: ESTIMATED HOLE TEMP, {°F): 140 BRINKERHOFF SIGNAL ~5~ ACTUAL HOLE TEMP. (°F): ~ f~ FLUID PROPERTIES FOR SAMPLER DRTR RECOVERED MUD & WRIER SOURCE RESISTIVITY CHLORIDES Pst§ RT SURFACE: © °F ppm cu. f t. OF GAS: © °F ppm cc OF OIL: © OF ppm cc OF WATER: © °F ppm cc OF HUD: ' ~ __°F ppm ©__°F ppm TOTAL LIQUID cc: HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY (°PPI): a °F TYPE RHOUNT WEIGHT GAS/OIL RATIO Itu. Ct. per bbl): FRESH H20 fFT.] 450.0 8.33 GAS GRAVITY: RECOVERED: 442' OF FORMATION WRIER ~ REMARKS: REPORTED ELEVATION MEASURED RT GROUND LEVEL IS 66 FEET. TYPE & SIZE MEASURING DEVICE: l" FLOOR MaNIFOLO J TICKET NO: 85229400 SURFACE GAS LIQUID T~ CHO~ P~Ssu~ ~T~ R~ REHRRKS SIZE PS] HCF 8PO 11-22-84 0020 MROE UP TOOLS 0022 STRRTED CLOCKS 0039 VENT IN HOLE VITH DRILL PIPE RND TOOLS ]1-23-84 0~30 RIGGEO UP SURFRCE EOUIPHENT 0356 SET RTTS 0358 OPENED TOOL VITH R STRONG BLOV 0400 STRONG BLOV 0425 FILLED DRILL PIPE VITH HUD 0440 UNSERTED ?RCKER 0445 CIRCULRTE HOLE 0800 PULLED OUT OF HOLE ]030 TOOLS OUT OF HOLE CLOCK NO: 13172 HOUR: 24 LI '×~ I]o~~t t+At FIRST FLOW B 1 3 5 6 ? 8 9 12 13 14 0 0 2 0 4 0 6 0 8 0 10 0 12.0 14.0 16.0 18.0 20.0 22.0 24.0 26.0 27.0 260.7 335.4 355.4 367.8 378,4 393.2 409.7 424 9 440 3 455 7 468 1 482 2 494 1 503 9 511 2 74.7 20.1 12.4 10.6 14.8 16.5 15.2 15.5 15.3 12.4 14.2 11.9 9.8 7.3 GAUGE NO: 6141 DEPTH: 6510o3 MINUTES PRESSURE Ap t+at ]~og~ REMRRKS: TICKET NO: CLOCK NO: 16174 HOUR: 24 Bp t+At 1 2 3 4 5 6 7 8 9 ~o 12 ~3 14 0.0 2 0 4 0 6 0 8 0 10 0 120 14.0 16.0 18.0 20.0 22,0 24.0 26.0 27.0 FIRST FLOV 262, 8 339.4 76.7 358.2 18.8 371.3 13. 1 381,5 10.2 398.2 16.7 414.3 16.1 429.0 14.7 443.4 14.3 458.7 15.3 472.1 13.4 484.2 12. l 495.2 11.0 505.6 10.5 512.4 6.8 GRUGE NO: 6142 DEPTH: 6514,3 MINUTES J PRESSURE J BP log REMRRKS: TICKET NO, 65229400 1 5 97 5 5 56 71 5 5 80 80 O.D. 1.0. LENGTH ORILL PIPE ...................... CROSSOVER ....................... RUXILIRRY VALVE ................. CROSSOVER ....................... CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... CROSSOVER ....................... RP RUNNING CASE ................. RP RUNNING CRSE ................. 3,500 2.602 9.500 2.250 4.680 2.400 5.000 2.250 6.250 2.250 6.250 2,250 6.250 2.250 3.500 2.250 3.500 2.250 5.000 2.250 5.000 2.250 6485.9 0.8 6.8 0°7 0.7 4.0 5.8 0.7 1,0 4.0 4.0 TOTAL DEPTH EQUIPMENT DATA DEPTH 6488.7 6498.0 6504.0 6510.3 6514.3 6566.0 LLIBURT SEF~VICE$ TICKET NO. ~5229600 30-NOV-8~ KENR] FORMRT ! ON TEST ~[NG SERV! CE REPORT GRUGE NO: 6141 OEPTH: G5i0:3 BLFINKEO OFF: NO HOUR OF CLOCK: PRESSURE 3S;~i 29 i, 7 '~ 4iSO i,~59 P, 104.0 Ro~ fLOW IN~T~L, ~ FI ~ ' FIN~L FIRST FLOW TIME - JTYF'E [I~LCUL~TED D FINFIL HYDROST,qTIC q.':-:iq~::_. ~,'~179. _1 ~ GAUGE NO: 5i42 DEPTH: 6514.3 BLANKED OFF:'¥'ES HOUR OF CLOCK: I PRESSURE : T I ME i TYPE DESCRIPTION I REPORTED i CALCULATED ; REPORTED I CALCULA~--i aL ~ ~ RST FLOW ' ~ .... I HYOROSTRTiC 31 ,,'b '3!?;~::? ' EQUIPMENT & HOLE DATA 1ICKET NUMBER: 65229600 FORMATION TESTED: BELUG~ NE~ PRY (f~]: DATE: 11-25-84 TEST NO: 9 GROSS TESTED FOOTAGE: 62.0 ~YPE DST: WATER SHUT OFF ALL DEPTHS MEASURED FROM: R KELLY BUSHING CASING PERFS. (¢~/: HALLIBURTON CAMP: HOLE OR CAS]NO SIZE [tn}: 9.6~5 KENRI ELEVATION (Ft): TO~RL DEPTH (~t): 6566.0 POINDEXTER PACKER DEPTH(S) (Ct): 6so~ TESTER: FINAL SURFACE CHOKE [~n]: 1,000 , PAUL SPIRO BOTTOM HOLE CHOKE {~n): 2 250 ~ITNESS: MUD ~EIOHT {lb/col): 10.20 MUD VISCOSITY (sec): 28 DRILLING CONTRACTOR: ESIIMflIED HOLE TEMP. {°F): 140 BRINKERHOFF SIGNAL ACTUAL HOLE TEMP. {°F]: © FLUID PROPERTIES FOR RECOVERED MUD & WATER SAMPLER BRTR SOURCE RESISTIVITY CHLORIDES Ps~g RI SURFACE: © __°F ppm cu, Ct. OF OAS: o __°F ppm cc OF 01L: e __°F ppm cc OF WATER: 0 __OF ppm cc OF MUD: O __°F ppm ~ __°F ppm TOTAL LIQUID cc: HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY {°RPI}: e __°F TYPE AMOUNT WEIGHT ORS/OIL RATIO [cu,Cto per bbl): FRESH WATER-FT. 450.0 8.34 GAS GRAVITY: RECOVERED: REMARKS: REPORTED ELEVATION MEASURED fiT GROUND LEVEL IS , ! TYPE & SIZE HERSUR]NG DEVICE, 1" NO, 65229800 PRESSURE RATE RATE REHflRRS SIZE PS] MCF BPD 11-24-84 1845 MADE UP TOOLS 1858 STARTEO CLOCKS 1728 RRM IN HOLE WITH TOOLS 1934 NRDE UP SURFACE EQUIPHENT 1949 SET RTTS 1950 1 OPENED TOOL .... BUBBLES. 2002 STRONG 8LOW THROUGHOUT PERIOD° 2134 UNSEATED RTTS 2140 REVERSEO OUT 2400 RULLED OUT OF HOLE WITH TOOLS 11-25-84 0232 TOOLS OUT OF THE HOLE. CLOCK NO-' 13172 HOUR: 24 REF J MINUTES J PRESSURF J ~P FIRST FLOW B 1 3 4 5 7 8 9 10 11 13 0.0 291 7 8.0 249 6 16.0 322 9 24.0 411 6 32.0 524 2 40.0 625 6 48.0 734 1 56.0 831 3 64.0 924 5 72.0 1018 0 80.0 1098 2 88.0 1178 0 96.0 1252. 1 104.0 1459.8 -42.1 73.4 88.7 112,6 101.4 108.5 97,2 93.3 93.5 80.2 79.8 74. l 207.7 GRUGE NO: 6141 DEPTH: G510.3 REMRRKS: 'I'ICKET NO: 65229600 1 (~A ~ O~ t CLOCK NO: lSl?4 HOUR: 24 LLIBURT llIVl¢l$ 6RUGE NO: 8!42 DEPTH: 6514.3 REF H]NUTES PRESSURE Bp t+At MINUTES PRESSURE AP t+At j,og-~- FIRST FLOW B 1 2 3 4 5 6 7 8 9 10 13 0 0 8 0 160 24 0 32 40 48 56 64 72 80.0 1260 88.0 1341 96.0 1418 104.0 1458 292.6 417.6 485.0 576.8 0 686.7 0 787.8 0 894.6 0 988 0 0 1082 7 0 1175 4 2 1 1 125.0 67.4 91.8 109.9 I00.9 106.9 93.5 94.7 92.7 84.9 80.9 75.0 42.1 REMRRKS: TICKET NO. 65229600 O.D. LENGTH DEPTH DRILL PIPE ...................... CROSSOVER ....................... RUXILINRY VNLVE ................. CROSSOVER ....................... CROSSOVER ....................... RTTS CIRCULNTING VRLVE .......... CRSING PRCKER ................... CROSSOVER ....................... CROSSOVER ....................... NP RUNNING CgSE ................. RP RUNNING CRSE ................. 3.500 2.602 6486.0 3.500 2.250 0.8 4.980 2.400 6.8 5.000 2.250 0,7 6.500 3.000 0.7 6.250 2.250 4.0 6.250 2.250 3.500 2.300 5.000 2,250 5.000 2,250 5.000 2.250 5.8 0.7 1.0 4.0 4.0 6486.7 6498.0 6504.0 6510.3 6514.3 TOTgL DEPTH 6566.0 EQUIPMENT DATA LLIBURT $EflVICE$ T]CKET NO. 65229800 04-DEC-84 KENR] FORMRT I ON TEST I NG SERVl CE REPORT GAUGE NO: 6141 DEPTH: 6510,0 BLANKED OFF: NO HOUR OF CLOCK: PRESSURE TIME I ID DESCR]PT:[ON I TYPE REPORTEDI I:RL(:UL RI'E O REpI~RI'ED J I:RLgULRTED Fl, INITIAL HYDROSTATIC 3181 3182o2 -- B INITIAL FIRST FLOW 1169 1128:6 110,0 llO.O F C FINF~L FIRST FLOW 1784 1777o8 D FINRL HYDROSTFtTIC 3181 3182,~ ORUOE NO: 6142_ DEPTH: 6514,0 BLRNKED OFF: NO HOUR OF CLOCK: 24 PRESSORE T !HE t TYPE DESCRIPTION R£PORT£DI [:RL£ULRTED REPOR'I'ED I £RL £ULI:I'I'E D I N I T i FiL HV...qp'-' -T , i ,~,,u.S,P. TfC 3~78 3182 6 INITIfiL FIRST FLO~d 1175 1129o7 110,0 119.0I F FIN,qL FIRST FLOgI 1779 1-/81.6 ...... FINAL HYBROST,qTII~ 3178 3162.6 EQUIPMENT & HOLE DRTR TICKET NUMBER:¢5229800 FORMATION TESTED: BELUGA NET PRY {¢t}~ 7,0 DATE: 11-25-84 TEST NO: 10 GROSS TESTED FOOTRGE~ 65,0 -'- TYPE DST: WATER SHUT-OFF ALL DEPTHS MEASURED FROM: R.K,B, - CASINO PERFS, (¢t]: 65~6.' - 6523' HALLIBURTON CAMP: HOLE OR CASING S]ZE [tn)= 9.625 KENA[ ELEVATION [Ct); 9~ ' TOTAL DEPTH [¢t)~ .... 6566.~ POZNDEXTER PRCKER DEPTH[S) (¢t): 65o~ TESTER: FINAL SURFACE CHOKE [~n]~ ~,000 BOTTOM HOLE CHOKE [~n): .. 2,250 . . WITNESS: PAUL M. SP]RO MUD WEIGHT lib/gui): 10.10 MUD VISCOSITY I~ec): 28 DRILLING CONTRACTOR: ESTIMATED HOLE TEMP, [°F): BRiNKERHOFF SiGNQL RCTUflL HOLE TEMP, (°F): ... ~ , FLUID PROPERTIES FOR RECOVERED HUD & WATER SAMPLER DRTR SOURCE RESISTIVITY CHLORIDES P~tg RT SURFACE: · ~F ppm cu. Ft. OF GAS: m °F ppm cc OF OIL: 0 OF ppm cc OF WRIER: o "F ppm cc OF MUD: 0 OF ppm ~__,°F ppm TOTAL LIQUID cc: , HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY [°PPI): © oF TYPE AMOUNT WEIGHT ORS/OIL RATIO {cu.ft, pep bbl): FRESH WRIER [FT] 450.0 8.33 ORS GRRVITY: RECOVERED: REMARKS: REPORTED ELEVATION MEASURED aT GROUND LEVEL IS REPORTED TOTAL DEPTH - BOTTOM TESTED INTERVAL IS ACTUALLY PLUG BACK DEPTH _ , ~¥PE & SIZE "ERSUR]NS BEV]CE= _ ~" SURFREE MANIFOLD ! ~]CKET NO: 65229800 TI"E SIZE PS] MCF BPO 1645 MADE-UP TOOLS 1648 STARTED CLOCKS 173S RUN IN HOLE WITH TOOLS 8045 RIGGED-UP SURFACE EQUIPHENT . 8049 SET R.T.T.S. .. , 8148 LOROEO DRILL PIPE WITH GAS .. CUSHION. 2228 CLOSED SURFRCE MANIFOLD WITH 750# ON DRILL PIPE. 2249 OPENED AUXILIARY VALVE. . . 2251 BLEO OFF GAS CUSHION .... 2326 1 STRONG BLOW 2328 MODERATE BLOW 2329 2330 ...... 2382 ,, .., 2349 11-26-84 0081 FILLED DRILL PIPE WITH MUD .., OOg9 UNSET PACKER 0045 CIRCULATING RNO CONDITIONING , .... HOLE. 0430 PULLED OUT OF HOLE WITH TOOLS .... 070S TOOLS OUT OF HOLE ., .. ., .. .... .... , , , TICKET NO: 65229800 t ~ JGRUGE NO: 6141 CLOCK NO: 13739 HO.UR: 24 DEPIH: 6510.0 FIRST FLOV 4 6 7 8 )0 0.0 1128.6 lO.O 1184.0 -4.7 20.0 976.9 -147. I 30.0 890.1 -86.8 40.0 898.4 8.9 50.0 1043.8 14S.4 60,0 1206.3 162.5 70.0 1365.9 159.6 80.0 1500.9 135.0 90.0 1613.6 112.7 100.0 1709,8 98.3 110.0 1777.8 68.0 REMRRKS: CLOCK NO: 16147 HOUR: 24 ! REF IHINUTESiPRESSURE ~P FIRST FLOW 6 7 8 9 ~0 0.0 1129,7 lO.O 1109.1 -20.6 20,0 976.6 -132,5 30.0 885.1 -91,4 40.0 910,2 25.1 SO.O 1045,5 13S.~ 60.0 1207.8 162,3 70.0 1368.7 160.9 80,0 1497.9 189,2 90.0 1616.0 118.1 100.0 1707.8 91.7 110.0 1781.B 73.9 GRUGE NO: G142 DEPTH: G514.0 ,,xA, REF' MINUTES 'PRESSURE) Ap , .,.A, I I I . REMRRKS: .~.~ ,r.~--~.. TICKET NO. 65229800 O.O, I.D. LENGTH DEPTH ORILL PIPE ...................... CROSSOVER ....................... RUXILIARY VALVE ................. CROSSOVER ....................... CROSSOVER ....................... RTT$ CIRCULATING VRLVE .......... CRSING PRCKER ................... CROSSOVER ...................... CROSSOVER ....................... RP RUNNING CASE ................. RP RUNNING CRSE ................ 3.500 2.602 3,500 2.250 3.625 2,000 3,500 2,250 6.500 3.000 6.500 2.250 6,500 2.250 6.500 2.250 5.000 2.250 5.000 2.250 5.000 2.250 6485.9 0.8 6.8 0,7 0.7 4,0 5.9 0.7 1.0 4.0 4.0 6487.0 6495.0 6501.0 6510.0 6514.0 TOTAL DEPTH 6566.0 EQUIPMENT DRTR i I i LLIBURT SERVICES TICKEI NO. 65280000 04-DEC-84 KENA! FORMAT I ON TEST I NG SERV I CE REPORT GAUGE NO: 6141 DEPTH: 6510,3 BLANKED OFF: NO HOUR OF CLOCK 24 ID I DESCRIPTION PRESSURE TIME TYPE I REPORTED I (::RLCULRTED REPORTED I CRLCULRTED FI INITIFIL HYDROSTRTIC 3180 3200.0 B INITIFtL FIRST FLOW 390 391ol 110.0 . . C FINFtL FIRST FLOW 423 419. 1 C INITIFtL FIRST CLOSED-IN 423 419o 1 10.0 10.0 , . D FINFtL FIRST CLOSED-IN 520°0 ~ _ E FINFtL HYOROSTFtTIC 3180 3188.3 GAUGE NO; 6]42 DEPTH: 6514.3 BLANKED OFF: NO HOUR OF CLOCK: 24 IDI DESCRIPTION PRESSURE TIHE TYPE REPORTED J CRLCULRTED REPORIED J CRLCULRTED Fi, INITIRL HYDROSTRTIC 3178 3203.8 B,J INITIRL FIRST FLOW 414 415,3 llO.O llO.O F C FINRL FIRST FLOW 445 429.2 C INITIF~L FIRST CLOSED-IN z~4S 429,2 10.0 10.0 C Il FINAL FIRST CLOSED-IN 586.8 -- E FINF~L HYDROSTRTIE 3178 3195,0 ! TYPE ~ SIZE HEnSURING BEV]CE: ]" SURFRCE MRNIFOLO I~C~ NO: 85230000 SURFnCE GnS LISU1D TIME CHOKE PRESSURE RnTE RATE REMARKS SIZE PSI M£F BPD , 11-28-84 1148 STRRTED CLOCKS 1155 MRDE UP TEST TOOLS 1224 RRN IN HOLE WITH TOOLS 15]0 RIGGEO UP SURFRCE EOUIRHENT 1536 SET RTTS 1540 700 LOROED 0.?. WITH LERSE GRS 1600 OPENED RUXILIRRY VRLVE 1602 BLEO OFF GRS TO FLRRE TRNK ]609 1 0 0 0 STRONG BLOW THROUGH BUBBLE HOSE ]6]5 SRHE 1706 SRME ,, ]730 SRHE ]?50 CLOSEO ON SURFRCE 1800 FILLED ORILL RIPE WITH MUO ]830 960 PRESSUREO UR ON FORMRTION THROUGH ORILL PIPE ,, ]848 BLEO OFF DRILL PIPE ]851 0 UNSERTED RRCKER 1852 REVERSE CIRCULRTED .., 2130 PULLED OUT OF HOLE WITH TOOLS 23~0 OUT OF HOLE .. TICKET NO. 65230000 0.0. 1.0. LENGTH DRILL PIPE ...................... CROSSOVER ....................... AUXILIARY VRLYE ................. CROSSOVER ....................... CROSSOVER ....................... RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... CROSSOVER ....................... RP RUNNING CASE ................. AP RUNNING CASE ................. 3.~00 2.602 3.500 2.250 5.000 2.250 5.000 2.250 6.500 3.000 6.500 2.250 6.500 2.250 5.000 2.000 5.000 2.250 5.OOO 2,250 5.000 2.250 6485.9 0.8 6.8 0.7 0.7 4.0 5.9 0.7 1,0 4.0 4.0 TOTAL DEPTH EQUIPMENT DATA DEPTH 6487.0 6495.0 6501,0 6510.0 6514.0 6566.0 LLIBURT SERVICES TICKET NO. 65226800 29-NOV-84 KENR] FORMFIT I ON._.. TEST I NG SERV I CE_.. REPORT GRUGE NO: 215 DEPTH: 5118,0 BLRNKED OFF: NO HOUR OF CLOCK: 12 I PRESSURE I TIME ID DESCRIPTION REPORTED] CRLCULRIED I R£PORIEO ! C,LCUL.TED TYPE A I INITiSL HYDROSTATIC 2527 2531~4I I I 8 I INITiaL FIRST FLOW 200 209°2 I 105o0 105,0 F I C I FINfiL FIRST FLOW 246 258,9 I B I FINAL HYDROSTATIC 2542 2531.2 I GRUGE NO: 216 DEPTH: Sl18.0 BLRNKED OFF: NO HOUR OF CLOCK ' 1 ID I DESCRIPTION PRESSURE I TIME TYPE i REPORTED I CALCULATED REPORTED I CALCULATED ~ I INITIAL HYDROSTFtTiC I 2520 2531o0 B tNTTI~L FIRST FLOW 203 202,8 105.0 105,0 F C FINP, L FIRST FLOW 250 253.9 I FINAL HYDROSTFtTIC 2520 2531.0 D I EOU I PMENT & HOLE DATA IICKET NUMBER= 65226800 FORMATION TESTED: BELUGA NET PAY (¢t): DflTE~ 11-16-84 TEST NO: 2 GROSS TESTED FOOTflGE: 73.0 TYPE DST: W~TER SHUT OFF ALL DEPTHS MEASURED FROM: KELLY BUSHING CASING PERFS. (fi): HALLIBURTON CAMP: HOLE OR CASING SIZE (Ln]: 9.625 HENRI ELEVATION [¢t)= TOTAL DEPTH [ft): 5181.0 DICK PIKE PACKER DEPTH[S) [f~): 5~08 TESTER: FINAL SURFACE CHOKE BOTTOM HOLE CHOKE (~n): 2.250 WITNESS: HUD WEIGHT (lb/gall: 10.00 MUD VISCOSITY DRILLING CONTR~£TOR: ESTIMATED HOLE TEMP. [°F): 120 BRINKERHOFF SIGNAL ACTUAL HOLE TEMP, {°F]: ~ ft FLUID PROPERTIES FOR SAMPLER DATA RECOVERED HUD & WATER SOURCE RESISTIVITY CHLORIDES Psig RT SURFACE: © __°F pp~ cu, f t. OF ORS: ~ __°F ppm cc OF OIL: © __°F ppm cc OF WATER: © __OF ppm cc OF HUD: © __°F ppm © °F ppm TOTRL LIQUID cc: HYDROCARBON PROPERTIES CUSHION DATA OIL GRAVITY [°RPI): ~ __oF TYPE RHOUNT WEIGHT ORS/OIL RRTIO (cu,fto per bbl): FRESH WATER-FT. 470.0 8.33 ORS GRAVITY: RE6OVEREB= REMARKS: REPORTED ELEVATION MEASURED RT GROUND LEVEL IS 66 FEET. I TYPE & SIZE HERSURING DEVICE: ND~ 65226800 suRF.CE CHOKE PRESSURE RRTE RRTE RE H~RKS TIME SIZE PSI Mcr BPD 11-~5-8~ 1537 STHRTED CLOCK5 16Z2 STRRTED TOOLS IN HOLE 1800 TOOLS ON BOTTOM ~835 SET PHCKER 18~0 .25 OPENED RUXILIRRY VRLVE. BUBBLES THROUGH HOSE 2025 SHUT IN...FILLED gRILL PIPE WITH MUD 2035 PULLED PRCKER LOOSE, REVERSED OUT 2150 J STHRTEB OUT OF THE HOLE ! 2330 J TOOLS OUT OF THE HOLE. ! I ~ICKET NO: 65226800 CLOCK NO: 22925 HOUR: MINUTES PRESSURE BP FIRST FLOW 0.0 209,2 lO.O 212.8 3.6 20.0 219.1 6.3 30.0 223. ? 4.6 40.0 229.1 5.4 50.0 233.5 4.3 60.0 237.2 3.7 70.0 242.4 5.3 80.0 246.7 4. ~ 90.0 250.6 3.9 lOO.O 255.5 4.9 105.0 256.9 1.4 GRUGE NO: 215 DEPTH: 5118.0 MINUTES PRESSURE BP t+At REHRRKS: TICKET NO: 6522G800 CLOCK NO: 22899 HOUR: MINUTES IPRESSUREI AP FIRST FLOW I t xAt I · t + At t+At I ~ °g~-{-' 0.0 202.8 10.0 208.9 4.1 20.0 212.8 6.0 BO.O 218.3 5.5 40.0 223.8 5.5 50.0 228.5 4.7 60.0 233.2 4.7 70.0 237.9 4.7 80.0 242.0 4.1 90.0 246.5 4.5 100.0 250.9 4.4 lO5.O 253.9 3.0 GRUOE NO: 218 DEPTH: 5118.0 AP t+At ii °g--~- REMRRKS: TICKET NO, 85226800 O.D. I.O. LENGTH DEPTH DRILL PIPE ...................... 8.500 2.602 5093,0 RUXILIRRY VRLVE ................. CROSSOVER ....................... RTTS CIRCULRTING VRLVE .......... 4.680 2.400 6.000 2.620 6.500 2.400 CflSING PRCKER ................... 71950 2.400 CROSSOVER ....................... BUNDLE CRRRIER .................. 6.000 2,620 5.S80 2.250 6.8 0.7 4.0 5.9 1.0 7.9 5099.0 5104.0 5108.0 5118.0 TOTRL OEPTH 5181.0 ~-. E QU I PME NT DR T FI ~. LLIBURT SE~VIC£$ T]£KET NO. 65~42300 26-NOV-84 KENR] F ORMR T I ON T E S T I NG SE RV I C E REPORT GAUGE NO: 218 DEPTH: 5041:0 BLANKED OFF: NO HOUR OF CLOCK: I - PRESSURE I O DESCR I PT I ON ! REPORTED I CALCULATED ~L,O 204 8 C FINflL FIRST FLOW i ~03 207.~ £0~ GAUGE NO: 2!5 DEPIH: 5041.0 BLANKED OFF: NO HOUR OF CLOCK 12 PRE SSURE I T I ME BE SCR I P T I ON TYPE REPORTED } CALCULATED I REPORTED J CALCULATED INiTiP, L HYDROST,q-TIC 2zt97 2502~6 iNITiAL FIRST FLC!W 2i5 210~2 110.0 !I0~0 F C F!N~L FIRST FLOW 215 21].9 D I F !N~L HYDRO;-STP.,TTC 12512 2500.9I EOU I PMENT & HOLE DATA TIGHET NUMBER~ 652~2~00 FORMATION TE~TED~ BELUGA NET PAY [fi}: DATE~ 11-13-84 7E87 NO: 1 GROSS TESTED FOOTAGE: 78.0 TYPE DST; CASED HOLE ALL DEPTHS HERSUREB FROM= KELLY BUSHING CASING PERFS, [fi): HALLIBURTON CAMP: HOLE OR CASING SIZE [tn): 9.825 KENRI ELEVATION Ill)= 91 TOTAL DEPTH If±)= 5108.0 DAVE NEWTON PACKER DEPTH(S) (ft): 5030 TESTER: FINAL SURFACE CHOKE (tn)= 0.250 BOTTOM HOLE CHOKE (tn)= 2.250 WITNESS: MUD WEIGHT (lb/gal): 10o00 MUD VISCOSITY [sec]: DRILLING CONTRACTOR: ESTIMATED HOLE TEMP. [°F]: 120 BRINKERHOFF SIGNAL ACTUAL HOLE ~EHP, (°F)= ~ ft FLUID PROPERTIES FOR RECOVERED MUD & WATER SAMPLER DRTR SOURCE RESISTIVITY CHLORIDES Psig RT SURFACE: ~ °F pp~ cu,ft, OF GAS: ~ __°F ppm CC OF OIL: © __°F ppm cc OF WATER: © __°F ppm cc OF HUD: © __°F ppm ~__°F ppm TOTAL LI@UID cc: HYDROCARBON PROPERTIES CUSHION DRTR OIL GRAVITY (°PPI): m __°F TYPE AMOUNT WEIGHT GAS/OIL RATIO (cu:f±. pep bbl): WATER -FEET 470.0 8.33 ORS GRAVITY: RECOVERED: ~ REMARKS: TYPE & SIZE MEASURING DEVICE: J TICKET NO: 652~2300 size PRESSURE R~E R~TE REMARKS j PSI MCF BPB ,. o=~ I I i ~=o ~o~ 0?45 J STARTEO TOOLS IN HOLE 0930 J ON BOTTOH WITH TOOLS 1200 I SET PBCKER BT 5030' 1210 .25 0 OPENED BUX!LIARY VALVE 1215 .25 I NO GBS =~oo j OPENED BYPASS J REVERSED OUT PULLED OUT OF THE HOLE. I ~ i I I I -- I I I I ,~ TICKET NO, 65242300 I LENOTH BEPTH 1 9? 5 56 71 5 84 DRILL PIPE ...................... aUXILiaRY VALVE ................. CROSSOVER RTTS CIRCULATING VALVE .......... CASING PACKER ................... CROSSOVER ....................... BUNDLE CARRIER .................. 8.500 2.600 5015.0 4.680 2.400 6.000 2.620 6.500 2.400 7.950 2.400 6,000 2.620 5.380 2,250 6,8 0.7 4.0 5.9 1.0 7.9 5021,0 5026.0 5030.0 5041.0 TOTAL DEPTH 5108.0 EQUIPMENT DATA UNION OIL cOMpANY OF CALIFORNIA WELL RECORD ORI Gl SHEET A ~ii PAGE NO. i LEASE: Kenai T¥onek Unit A-028142 WELL.NO. KTU 13-5 SPUD DATE: 8/15/84 COMP. DATE: 12/22/84 FIELD:'Kenai Gas Field LOCATION: 4169' E & 144' S of NW Corner Sec 7~ . T4N~SM PERMIT NO. 84-108 TD 8232' MD SERIAL NO. A-028142 TVD 7828' CONTRACTOR Brinkerhoff RIG NO. 54 TYPE UNIT National 110 UE DRILL PIPE OESCRIPTION 5" DP ELEVATIONS: WATER DEPTH - RT-TO OCEAN FLOOR - RT TO GL 25.35' DEVIATION (BHL) 2423' N 29° 3' 2" E RT TO DRILL D~ (GL-MS~66_.l') COMPANY ENGINEER ~e~-h~-~e~ RT TO PRODUCTION DECK N/A APPROVE[~ /] L /'~,//~/,. J~__ ~._ CASING-& TUBING RECORD _ 'SIZE WEIGHT . . THREAD GRADE DEPTH REMARKS 20" 93# " (.438"-Wall) N-80 136' : Driven to Refusal: 250 BPF usinq a D-22 hammer 13 3/8" 61# Buttress N-8.0 2500' FC at 2456' Cmtd w/ 1300 sx "G" w/ additives 9 5/8" 47# Buttress N-80 8232' FC at 8145'. Cmtd w/ 2250 sx "G" w/ additives~ plus 1100 sx "G" w/ additives thru DV at 4925' 3 1/2" 9.2# Buttress N-80 4872' 2 7/8" 6.4# Buttress N-80 7611' PERFORATING RECORD DATE INTERVAL E,T.D" REASON .. PRESENT CONDITION 1. 10/07/84 7989-8004' :8039, Production 2. 10/14/84 ' 7936-7950' .8039' Production 3. '10/17/84 7916-7932' 8039' Production 4. 10/18/84 7654-7668' '8039"' Production 5. 10/23/84 6956-6962' 8039': Production Upper Tyonek Sand - Open Upper T¥onek Sand r..Open Upper Tyonek Sand - Open Upper T¥onek Sand - Open Lower Beluqa Sand - Open 6. 10/25/84 7320-7330' 7. 10/27/84 6580-6602' 8039' Production 8039' Production Lower Beluqa Sand - Open Lower Beluqa Sand - Open 8. 11/05/84 5401'5416' 8039' Production 9. 11/05/84 5343-5366' 8039' Production 10.11/05/84 4987-4996' 8039' Production 11.09/07/84 12.09/11/84 13.09/16/84 8095-8097_'. 8039' Production 8088-8090T ~-8039' Production 7652-7654' '8039' Production 14.09/18784 7518-7520' 8039' 15.09/18/84 6515~6517' 8039' Production Production Upper Beluqa Sand - Open Upper Beluga Sand - Open Upper Beluqa Sand - Open Sqzd w/ 148 sx class "G" w/ additives Sqzd w/ 148 sx class "G" w/ additives Sqzd w/ 148 sx class "G" w/ aOditives Sqzd w/ 160 sx class "G" w/ additives Sqzd w/ 143 sx class "G" w/ additives 16.09/20/84 7335-7337' 8039' Production Sqzd w/ 145 sx class "G" w/ additives 17.09/21/84 6116-61t3' 8039' Production Sqzd w/ 190 sx class "G" w/ additives 18.09/21/84 5008-5010' 8039' Production Sqzd w/ 771 sx class "G" w/ additives 19.09/21/84 5054-5056' '8039' Production Sqzd w/ 431 sx class "G" w/ additives 20.09/22/84 4975-4977' 8039' Production '21.09/22/84 4895-4897' 8039' Production 22.09/23/84 4698.4700' 8039' Production 23.09/26/84 4998-5000' 8039' Production 24.10/21/84 7502-7520' 8039' Production 25.10/28/84 6500-6515' 8039' Production 26.10/29/84 6426-6436' 8039' Production 27.11/01/84 6324-6330' 8039' Production Sqzd w/ 488 sx class "G" w/ additives Sqzd w/ 476 sx class "G" w/ additives Sqzd w/ 486 SX class "G" w/ additives Sq.zd w/ 485 sx class "G" w/ addit across DV Sqzd w/ 197 sx class "G" w/ additives Sqzd w/ 270 sx class "G" w/ additives Sqzd w/ 134 sx class "G" w/ additives Sqzd w/ 170 sx class "G" w/ additives 28.11/01/84 6370-6376' 8039' Production Sqzd w/ 165 sx class "G" w/ additives 29.11/03/84 5914-5924' 8039' Production Sqzd w/ 163 sx class "G" w/ additives 30.1i/04/84 5994-6003' 8039' Production Sqzd w/ 165 sx class "G" w/ additives 31.11/05/84 5141-5161' 8039' Production Sqzd 31 & 32 w/ 161 sx class "G" 32.11/05/84 5110-5135' 8039' Production w/ additives 33.11/05/84 5073-5081' 8039' Production 34.11/05/84 5059-5066' 8039' Production Sqzd 33 & 34 w/ 140 sx class "G" w/ additives INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS SS: UPPER & LOWER BELUGA 4.99 MMSCFD AT 700 PSI SURFACE PRESSURE LS: UPPER TYONEK .70 MMSCFD AT 1800 PSI SURFACE PRESSURE WELL HEAD ASSEMBLY t'~ i' ~'- E-~i\,-; ~ D CASING HEAD: 'WF' 12" 3000 PSI W/ 2X2" 3000 PSI WP FLANGED OUTLETS^, ..... ,,, ,, ..... ,,,,,m. 6gllimissi0l~ Anohorago TUBING HEAD: Type 'DCB' 12" 3000 PSI X 11" 5000 PSI W/ 2X2" 5000 PSI FLANGED OUTLETS TUBING HANGER: Dual 'DCB' 11" Nominal w/ 3 1/2" x 3 1/2" Buttress UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. i LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS KTU #i3-5 (uoco. 50.00%) AFE # 341103 DAILY cosT: $ 120,601 ' CUM COST: $ 160,776 RECEIVED VERBAL F/ BLM TO COMMENCE OPERATIONS. BRINKERHOFF SIGNAL COMPLETED TURN KEY RIG MOVE & RIG UP OPERATIONS ~ 1000 HRS, 8/12/84. AFE' AMT: · $3,969,000 DAILY COST: $ 16,7!i CUM. COST: $ 177,487 AFE AMT: $3,969,000 · 1 DAY 8/14/84. ' 20" D 136' 65 PCF 115 SEC.~ .. DAILY COST: $ 33,336 CUM COST: $ 210,823 CONT RIG UP OF UOC EQUIP IN PREP TO SPUD: INSTALLED CENTRIFUGE, DUG DITCHES, PLUMBED .RESERvE. TANKS, INSTALLED DIVERTER LINE, WELDED 20" CONDUCTOR PIPE TOGETHER. RECD BLM · PERMIT & PUT RIG ON FULL OPER RATE ~ 1700 HRS. PU HAMMER & BEGAN DRIVING 20" CONDUCTOR '(LOTS OF TROUBLE W/ HAMMER TRIP ON 1ST OT). DROVE TO REFUSAL W/ 240 BPF ~ 136' PT, 111' BGL (25.35 RT TO GL). CUT OFF & LD DRZVE PIPE. DROVE RATHOLE. LD HAMMER. WELDED ON 2000# 20" FLANGE. PULLED RT & SET 20" HYDRIL & PITCHER NIPPLE. TIED DIVERTER LINES IN. AFE AMT: '$3,969,000 447' / 422' 2 DAY 8/15/84 20" D 136' 66 PCF ilo SEC DAILy cosT: $ 34,783 CUM COST: $ 245,606 REINSTALLED RT & CHAIN. DRESSER SLEEVE WOULD NOT MATE BELL NIPPLE TO FLOW LINE- REMOVED, REPAIRED & REPLACED NIPPLE. SET FLOOR PLATES & CHAIN GUARD. PU KELLY (DROPPED KELLY & SOCK). MU 17 1/2" BHA & CO CONDUCTOR & DRLD TO 447'. POOH. 3 HRS DOWNTIME TO REPAIR CLUTCH ON #1 PUMP. AFE AMT: $3,969,000 1165' / 718' 3 DAY 8/16/84 20" D 136' 66 PCF 96 SEC DAILY COST: $ 143,736 CUM COST: $ 389,342 AFE AMT: $3,969,000 TIH W/ 17 1/2" BIT #2 ON BHA #2 (DYNA- DRILL & CHRISTENSEN MWD TOOL) ORIENTED & DYNA~DRLD DIRECTIONAL HOLE F/ KOP ~ 447' TO EOC @ 1165' (+19° N28°E). POOH -RAN 17 1/2" RR #1 ON FOLLOW-UP ASSY- BHA #3, AlasKa UlI & u~s boris. Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1926'/ 761' 4 DAY 8/17/84 20" D 136' 67 PCF 102 SEC DAILY COST: $ 40,887 CUM COST: $ 430,229 AFE AMT: $3,969,000 RIH W/ BHA #4 & DRLD 1165-1343'. CIRC & POH. RIH & DRLD 1343-1499'. CHANGED OUT STANDPIPE UNION. POH FOR BHA CHANGE. RIH W/ BHA #5 & DRLD 1499' TO 1786'. WORKED ON #2 PUMP. POOH FOR BHA CHANGE. RIH W/ BHA #6 & DRLD 1786-1926'. 2501'/ 575' 5 DAY 8/18/84 20" D 136' 13 3/8" ~ 2500' 69 PCF 91 SEC CONT DRLG TO 2501'. POH. CHECK PUMPS-OK. RIH, ClRC & COND FOR CSG. POH, LD TOOLS. RU & RUN 13 3/8" 61#, K-55, BUTT CSG TO 2500' W/ FC ® 2456'. RU TO LAND CSG. DAILY COST: $ 159,639 CUM COST: $ 589,868 AFE AMT: $3,969,000 2501'/ O' 6 DAY 8/19/84 20" D 136' 13 3/8" ~ 2500' 66 PCF 40 SEC DAILY COST: $ 32,968 CUM COST: $ 622,836 AFE AMT: $3,969,000 CUT 13 3/8" CSG ABOVE SLIPS. RIH W/ STAB- IN TOOL. STABBED INTO FC & CIRC. RU CMT LINES & TESTED TO 5000 PSI. PUMPED CAUSTIC FLUSH & WATER AHEAD, BEGAN PUMPING CMT BUT HAD PROBLEMS W/ SHIRRING LINES-CIRC OUT ALL CMT. MIXED & PUMPED 1050 SX CL "G" CMT W/ 2% CACL2.& 2 1/2% RREHYDRATED GEL (13.1- 13.4 RRG) FOLLOWED BY 250 SX CL "G" CMT W/ 2% CACL2 (15.8-16.0 RRG), & DISRL ~ ll BRM. CIR ~ 1845 HRS, 8/19/84. (DOWN ARRROX l0 HRS DUE TO HOWCO EQUIP PROBLEMS.) FLOATS HELD. ROH, WASHING & RATTLING DR. CLEANED UR & RD. 2501'/ O' 7 DAY 8/20/84 20" D 136' 13 3/8" ~ 2500' 66 PCF 38 SEC RD CSG TOOLS. PULLED RT, RISER & 20" ANNULUR. CUT OFF 20" & 13 3/8". WELDED ON 13 3/8" SOW HEAD. GROUTED IN CELLAR. INSTALLING BOPE. DAILY COST: $ 33,441 CUM COST: $ 656,277 AFE A~T: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2501'/ O' 8 DAY 8/21/84 20" C. 136' 13 3/8" C. 2500' 65 PCF 35 SEC CONT INSTALLING BORE. INSTALLED CHOKE & LINES. 2 HRS REPAIR TO REPLACE BLOWN SEAL IN SINGLE GATE BOP. TESTED BORE. DAILY COST: $ 47,142 CUM COST: $ 703,419 AFE AMT: $3,969,000 2510'/ 9' 9 DAY 8/22/84 20" C. 136' 13 3/8" C. 2500' 65 PCF 48 SEC DAILY COST: $ 34,469 CUM COST: $ 737,888 AFE AMT: $3,969,000 TSTD BOPE TO 3000 PSI. STRAPPED IN HOLE W/ BHA #7 & BIT #3, CHKG HWDP FOR CMT (LD 18 STS). STAGE IN, TAGGING GREEN CMT ~ 2042', HARD CMT ~ 2444'. DRD TO 2456' & TSTD CSG TO 2500 PSI. DRD FC & HARD CMT TO 2490' & RETESTED CSG 2500 PSI. DRD HARD CMT, SHOE, & FORM TO 2510'. PULL UP TO SHOE, C & C, PERFORM LEAK-OFF TST TO 93 PCF EMW. POOH. 2510'/ O' 10 DAY 8/23/84 20" C. 136' 13 3/8" C. 2500' 65 RCF 44 SEC DAILY COST: $ 42,636 CUM COST: $ 779,524 AFE AMT: $3,969,000 RIH W/ HOWCO EZSV & SET ~ 2440'. BROKE DOWN SHOE ¢ 800 PSI, PUMPED ~ 4 BPM, il00 PSI. BLED TO 375 W/ PUMPS OFF AFTER 5 MIN. MIXED & PUMPED 450 SX CLASS "G" CMT W/ 2% CaCi2 & 1% CFR-2 ~ 16.4 PPG. DISPL 439 SX BELOW TOOL ~ i/i6 BPM, 1400 PSI. HELD iIO0 PSI AFTER 5 MIN. CIP @ 0545 HR, 8/23/84. PU REVERSED OUT. POOH. RIH W/ BIT #4 ON BHA #7 & TAGGED CMT ~ 2434'. CO CMT & RET T/2490'. TSTD CSG T/ 2500 PSI- OK. CO CMT T/2508' & PERFORMED LEAK-OFF TEST TO 99 PCF EMW. 4326'/ 1816' 11 DAY 8/24/84 20" C. 136' 13 3/8" C. 2500' 68 RCF 48 SEC CIRC BTM UP & POH. RIH W/ BIT #5 ON BHA #8 (LOCKED-UP: TANDEM NEAR-BIT W/ ALTERNATING STABS & DC'S) & DRLD I2 I/4" HOLE F/ 2508' (2' OF CMT) TO 4326'. DAILY COST: $ 31,915 CUM COST: $ 811,439 AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4890'/ 564' 12 DAY 8/25/84 20" C. 136' 13 3/8" C. 2500' 69 PCF 56 SEC DAILY COST: $ 33,445 CUM COST: $ 844,884 AFE AMT: $3,969,000 CONT DRLG 12 1/4" HOLE TO 4358'. CIRC BTM UP & POH. (TIGHT 3760-3420' & 3340-3109', PULLED MAX 65,000# OVER NORM). RIH W/ BIT #6 ON BHA #9 (DROPPED ONE NEAR BIT)-TIGHT HOLE 3560-3680'. REAMED 4295-4358' & DRLD 4358-4890'. CIRC BTM UP & POH-FREE, EXCEPT 30,000# OVERPULL ~ 4109'. 5755'/ 865' 13 DAY 8/26/84 20" C. 136' 13 3/8" C. 2500' 71PCF 49 SEC DAILY COST: $ 33,158 CUM COST: $ 878,042 AFE AMT: $3,969,000 RIH W/ BIT #7 ON BHA #10 (40' BELLY) - TOOK 5000# @ 4100'. TAGGED 10' OF FILL ~ 4880'. CO TO 4890' & DRLD TO 5755'. CIRC BTM UP & POH (MAX 45,000# OVERPULL). RIH W/ BIT #8 ON BHA #11 (30' BELLY). NOW: DRLG ~ 6042' ~ 0600 HRS. 6447'/ 692' 14 DAY 8/27/84 20" C. 136' 13 3/8" C. 2500' 72 PCF 48 SEC FINISHED RIH (HOLE FREE) TAGGING 5' OF FILL ~ 5750'. CO TO 5755' & DRD 12 1/4" HOLE TO 6447'. CIRC BTM UP & POH-PULLED 60,000# OVER ~ 5768-5675'. RIH W/ BIT #9 ON BHA #12 (NB, 20', ST, 22', ST). DAILY COST: $ 36,317 CUM COST: $ 914,359 AFE AMT: $3,969,000 7114'/ 667' 15 DAY 8/28/84 20" C. 136' 13 3/8" C. 2500' 73 PCF 49 SEC DAILY COST: $ 38,040 CUM COST: '$ 952,399 WASH & REAM F/ 6360-6447'. DRLD 12 1/4" HOLE F/ 6447' TO 7114'. DRLG BREAK ~ 7056'. CHK FOR FLOW ~ 7083'-N0 PIT GAIN, NO SI PRESS. CIRC & COND ~ 7114', RAISED MUD WT F/ 72 TO 73 PCF FOR TRIP MARGIN. POH-TIGHT F/ 6560' TO 6375' (45,000# OVER NORMAL). RIH W/ BIT #10. AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7768'/654' 16 D 8/29/84 20" C. 136' 13 3/8" C. 2500' 73 PCF 57 SEC DAILY COST: $ 46,041 CUM COST: $ 998,440 AFE AMT: $3,969,000 DRLD 12 1/4" HOLE F/ 7114' TO 7768'. CHECKED FOR FLOW ~ 7307' 7615' & 7768' - NO FLOW. CIR & COND MUD' POOH. 8108'/340' 17 D 8/30/84 20" C. 136' 13 3/8" C. 2500' 76 PCF 54 SEC DAILY COST: $ 42,774 CUM COST: $1,041,214 AFE AMT: $3,969,000 TESTED BOPE. RIH W/ BIT #13 RR. WASHED 15' OF FILL TO BTM. DRLD F/ 7768' TO 8023'. FILL ON CONNECTIONS. GAS CUT MUD BUT NO SI PRESS & NO FLOW. DRLD F/ 8023-8108'. GAS CUT MUD OVER ENTIRE INTERVAL. +40 BBLS OF FLUID LOST TO HOLE DURING PAST 12--HRS. RAISED MUD WT TO 76 PCF. CIRC BTMS UP. 8232'/ 124' 18 D 8/31/84 20" C. 136' 13 3/8" C. 2500' 75 PCF 59 SEC DAILY COST: $ 28,912 CUM COST: $1,070,126 AFE AMT: $3,969,000 POH TO CHANGE BIT & MWD INST PKG. MWD TOOL STILL BAD AFTER CHANGE-LD MWD. RIH & TAGGED 25' OF FILL. DRLD 8108-8232' TD. CdC MUD & WIPED HOLE TO 13 3/8" SHOE. RAN BACK TO BTM TAGGING 11' OF FILL. CIRC BTMS UP. GAS HAS BEEN BUBBLING UP THRU MUD CONTINUOUSLY. 8232' TD 19 D 9/01/84 20" C. 136' 13 3/8" C. 2500' 75 PCF 55 SEC DAILY COST: $ 38,224 CUM COST: $1,108,350 POH TO LOG, TAKING MULTISHOTS EVERY 90'. RU SCHLUMBERGER & RIH W/ DISFL/GR/SP/BHC/CAL, TAGGING BOTTOM ~ 8204'. TOOLS NOT WORKING. POH & LD CAL. RIH & LOGGED FROM 8204'. RIH FOR VDL-TOOLS MALFUNCTIONED. POH & CHANGED TOOLS. RIH & RAN VDL FROM 8204'. RIH W/ LDT/CNL/GR/CAL TO 8204'. AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8232' TD 20 D 9/02/84 20" C. 136' 13 3/8" C. 2500' 75 PCF 59 SEC DAILY COST: $ 119,602 CUM COST: $1,227,952 AFE AMT: $3,969,000 RAN LDT/CNL/GR/CAL LOG. RAN EPT LOG FROM 8204'. RIH & SHOT 45 SWC: 2 DID NOT FIRE, 2 NO RECOVERY, 41 RECOVERED, NONE LOST IN HOLE. RD LOGGERS & RIH W/ BIT, TAGGING l' OF FILL-NO TIGHT SPOTS. C&C FOR CSG, ADDING GEL. GAS STILL BREAKING OUT ~ SURF, AS IT DID THROUGHOUT LOGGING. ROH. CLOSED BLINDS & PULLED WEAR BUSHING. 8232' TD 21D 9/03/84 13 3/8" C. 2500' 9 5/8" ~ 8232' 76 PCF 54 SEC DAILY COST: $ 454,595 CUM COST: $1,682,547 AFE AMT: $3,969,000 INSTALLED 9 5/8" PIPE RAMS. RU CSG TOOLS & RAN 9 5/8", 47#, N-80, BUTT CSG TO 8232' TD. RECIPROCATED WHILE CIRCULATING PRIOR TO CEMENTING. 8232' TD 22 D 9/04/84 13 3/8" C. 2500' 9 5/8" ~ 8232' 72 PCF 34 SEC DAILY COST' $ 138,642 CUM COST: $1,821,189 AFE AMT: $3,969,000 CONT RECIPROCATING CSG W/ +60' STROKES WHILE i CIRC W/ 300 PSI. RU HOWCO, TSTD LINES TO 3000 PSI. PUMPED 50 BBL SEPIOLITE SWEEP AHEAD MIXED & PUMPED 500 SX "G" W/ .75% CFR-2, .6% HALAD 24, 5% SALT ~ 14.8 PPG, FOLLOWED BY 1750 SX "G" W/ .75% CFR, .6% HALAD 24, 5% SALT ~ 15.6 PPG. DROPPED CLOSING PLUG & DISP W/ MUD, BUMPED PLUG. CIP ~ 0620 HRS. RECIPROCATED THROUGHOUT ENTIRE SOB. DROPPED OPENING BOMB & OPENED DV COLLAR W/ 900 PSI. LOST RETURNS. PUMPED 50 BBL SEPIOLITE SWEEP AHEAD, MIXED & PUMPED 1100 SX CMT (SAME SLURRY) ® 14.3 PPG THRU DV COLLAR ® 4925'. DROPPED DV CLOSING PLUG & DISP W/ MUD. CLOSED DV W/ 2000 PSI. CIP ~ 11:54 AM. NO RETURNS ON STAGE SOB. LIFTED BOP STACK & INSTALLED DCB TBG SPOOL. NU BOPE & CHG LOWER RAMS TO 5". 8232' TD/ 8135' ETD 23 D 9/05/84 13 3/8" C. 2500' 9 5/8" ® 8232' 72 PCF 34 SEC DAILY COST: $ 25,927 CUM COST: $1,847,116 AFE AMT: $3,969,000 TSTD BOPE: HYDRIL TO 3500 PSI, REMAINDER TO 5000 PSI. ATTEMPTED TO RETRIEVE TEST PLUG W/O SUCCESS-STUCK IN TBG SPOOL. CHANGED OUT DCB TBG SPOOL. NU & RETESTED BOPE: ANNULAR TO 3500 PSI, RAMS TO 5000 PSI. INSTALLED WEAR BSG. RIH W/ BIT #13 TAGGING CONTAMINATED CMT 4' ABOVE STAGE COLLAR. CO CMT TO STAGE COLLAR @ 4925'. CIRC CLEAN. TSTD SURF LINES TO 6000 PSI. TSTD CSG TO 5000 PSI. CO STAGE COLLAR & CONT RIH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8135' ETD/ 8232' TD 24 D 9105/84 13 318" C. 2500' 9 5/8" ~ 8232' 72 PCF 32 SEC DAILY COST: $ 27,932 CUM COST: $1,875,048 AFE AMT: $3,969,000 TAGGED FIRM CMT 8005'. CO FIRM CMT TO 8090', SOFT CMT TO 8128', FIRM CMT TO 8135' (10' ABOVE FLOAT COLLAR). CIRC & TST SURF LINES TO 6000 PSI & CSG TO 5000 PSI. CIRC 8U & POH. RAN SCRAPER TO 8135', CIRC & POH. RAN GEARHART CBL FROM 8113' DIL. RU SPERRY-SUN & ORIENTED & RAN GYRO. 8135' ETD/ 8232' TD 25 D 9/07/84 13 3/8" C. 2500' 9 5/8" $ 8232' 72 PCF 32 SEC DAILY COST: $ 54,454 CUM COST: $1,929,502 AFE AMT: $3,969,000 RIH W/ GEARHART 4" CSG GUN & SHOT 4 HPF 8095-8097'. RIH & SET RET ~ 8045' DIL. RIH W/ STINGER ON DR & TAGGED RET ~ 8061' DRM. RU HOWCO & TSTD SURF LINES TO 5000 PSI. BROKE CIRC & STABBED INTO RET. PRESS TO 4900 PSI ATTEMPTING TO BREAKDOWN W/O SUCCESS. HELD 3700 PSI'W/ RUMPS OFF AFTER i HR. ROH. INSTALLED TSTG FACILITIES: HEATER/SEPARATOR, FLARE PIT, & LINES. 8135' ETD/ 8232' TD 26 D 9/08/84 13 3/8" C. 2500' 9 5/8" ~ 8232' 72 PCF 32 SEC DAILY COST: $ 41,875 CUM COST: $1,971,377 AFE AMT: CONT INSTALLING TST FACILITIES. RIH W/ GEARHART 4" CSG GUN & SHOT 4 HPF 8002-8004'. RIH & SET RTTS ~ 7975' DRM (7959' DIL). RU & TST SURF LINES & TST MANIFOLD TO 5000 PSI. TSTD LINES TO FLARE TO 3000 PSI. OPENED RTTS BYPASS & DISRL TO RTTS W/ BO N2. CLOSED BYPASS & OPENED WELL TO TEST: FINAL RATE (2 HR TEST): 1.2 MMCFD ~ 730 PSI - NO APPARENT WATER. OPENED BYPASS & REV CIRC GAS FROM THE DR. VOLUME PUMPED TO GET FLUID RETURNS TO SURFACE INDICATED NO WATER ENTRY (NITRATE TST INDICATED APRROX 200' OF WATER REVERSED OUT WAS ALL DRLG MUD.) 8135' ETD/ 8232' TD 27 D 9/09/84 13 3/8" C. 2500' 9 5/8" ® 8232' 75+ PCF 34 SEC DAILY COST: $ 29,536 CUM COST: $2,000,913 AFE AMT: $3,969,000 CONT REV OUT GAS CUT MUD THRU CHOKE. UNSET RTTS & RIH TO 8021' & CONT REV OUT - WELL FLOWING. SPOTTED KCL-XC-CACO3 RILL. ROH i STAND & CIRC BOT UR THE LONG WAY - WELL STILL FLOWING. SET RTTS ~ 7928' DIL & BULLHEADED RILL ~ 1500 PSI SURF PRESS. HELD 15 MIN-RRESS BLED TO llO0 PSI. RELEASED RTTS & CIRC BTM UP. 150 UNITS OF GAS DISSIPATED-WELL DEAD. ROH-WELL BEGAN FLOWING AGAIN W/ 50 STANDS OUT. RIH & CIRC THRU CHOKE, RAISING MW F/ 72 PCF TO 75+ PCF. WELL DEAD-NO FLOW, NO GAS. ROH. RIH W/ BIT #14 & OUNK SUB. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8154' ETD/ 8232' TD 28 D 9/10/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 RCF 33 SEC DAILY COST: $ 27,244 CUM COST: $2,028,157 AFE AMT: $3,969,000 TAGGED RET 8 8061' DPM (8045' DIL). DRLD UP & PUSHED TO CMT TOP 8 8019' DIL. CO RET & CMT TO 8124' DIL. POH FOR BIT. RIH W/ BIT #15 & CO CMT TO 8170' DRM (8154' DIL), ENCOUNTERING FC ~ 8125' DIL. CIRC CLEAN (GAS) & ROH. RU SCHLUMBERGER & RIH W/ CET LOG. 8154' ETD/ 8232' TD 29 D 9/11/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 33 SEC DAILY COST: $ 63,883 CUM COST: $2,092,040 AFE AMT: $3,969,000 FINISHED RUNNING CET. RAN CBL. RIH W/ BIT #15 & SCRAPER TO 8170' DPM (ETD) & CIRC OUT GAS-CUT MUD THRU CHOKE. GAS HAD CONTINUOUSLY BROKEN OUT OF MUD ON SURFACE THROUGHOUT LOGGING OPERATIONS & LOGS WERE AFFECTED BY GAS IN THE BOREHOLE. SI-NO SI PRESS IN 3 MINUTES. BROKE CIRC & POH 5 STANDS-WELL BEGAN FLOWING. RIH TO BTM & RAISED MW 75+ to 76+ PCF. POH & TSTD BOPE: HYDRIL TO 2500 PSI, REMAINDER TO 3000 PSI. RIH W/ GEARHART 4" CSG GUN & SHOT 8 HOLES 8088-8090' DIL. RIH W/ RTTS ON DP TO TEST PERFED ZONE FOR WATER. 8154' ETD/ 8232' TD 30 D 9/12/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 30,704 CUM COST: $2,122,744 AFE AMT: $3,969,000 SET RTTS ~ 8060' DIL. RU TST MANIFOLD & SURF LINES-TSTG TO 5000 PSI, LINES TO SEPARATOR TO 3000 PSI. DISPL DP W/ N2 & CLOSED RTTS BYPASS. OPENED WELL & BLED OFF N2. TOOK 5 HOURS TO GET GAS TO SURF, PRESS DROPPED FROM 3150 TO 420 PSI. SI 1/2 HR LATER FOR BUILDUP. TOOK 6 1/2 HOURS FOR SI PRESS TO BUILD FROM 200 TO 720 PSI. TSTD FOR 3 HRS, STABILIZED RATE: 106 MCF ® 735 PSI, NO WATER. SI WELL, FILLED ANNULUS & REC CIRC. FLUID TO SURF IN 1860 STROKES, INDICATIVE OF 23 BBL FLUID INFLUX. SURF PRESS SPORADICALLY HIGH WHILE REV (BYPASS PLUGGING?). CONT CIRC OUT THE LONG WAY. 8154' ETD/ 8232' TD 31D 9/13/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 47,037 CUM COST: $2,169,781 AFE AMT: $3,969,000 RIH TO 8104' & REV CIRC. STOPPED & CHECKED- NO FLOW, NO SI PRESS. ROH. RIH & SET RET ~ 8061' DIL. RU & TSTD SQZ MANIFOLD & LINES TO 6000 PSI. BROKE DOWN TYONEK TEST PERFS 8088-8090' (& SQZ HOLES 8095-8097'?) W/ 2900 PSI. PUMPED AT 2 BRM, 3000 PSI. HELD 1400 PSI AFTER 4 MIN W/ RUMPS OFF. MIXED 175 SX CL "G" CMT W/ .3% HALAD 24, 1% CACL2, & .75% CFR-2 & DISRL 148 SX BELOW RET TO FINAL S~Z PRESS OF 3650 PSI ~ 1/4 BRM. HELD 3350 PSI AFTER 5 MIN W/ RUMPS OFF. CIR ® 1245 HRS, 9/13/84. REV OUT 27 SX CMT. CIRC, CKG FOR GAS FLOW & ROH. RIH & SET BR ~ 7960' ON WL. SHOT 4 HRF 7948-7950' W/ 4" CSG GUNS FOR 3RD TYONEK TEST. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7664' BP/ 8154' ETD 32 D 9/14/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 34,488 CUM COST: $2,204,269 AFE AMT: $3,969,000 RIH & SET RTTS ~ 7928' ON WL. TSTD MANIFOLD TO 5000 PSI & LINES TO SEPARATOR TO 3000 PSI. OPENED BYPASS & LOADED DP W/ N2. CLOSED BYPASS & OPENED WELL TO ATMOSPHERE THRU CHOKE. PRESSURE DROPPED FROM 3250 PSI TO 1035 PSI IN 4 HRS WHEN GAS BROKE TO SURFACE. TSTD FOR 2 HRS TO 766 MCF ® 740 PSI, DRY. SI, OPENED BYPASS & FILLED ANNULUS (TOOK THEORETICAL VOLUME). REV OUT, APPARENT 10.9 BBL INFLUX (36 PPM NITRATES). DROPPED DOWN TO BP ~ 7960' & REV OUT. CKD FOR FLOW-OK. POH. RIH W/ EZSV BP ON WL TO 500'-FOUND SHORT IN LINE. POH & FIXED. RIH & SET BP @ 7664' DIL. 7664' BP/ 8154' ETD 33 D 9/15/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 37,087 CUM COST: $2,241,356 AFE AMT: $3,969,000 RIH W/ 4" CSG GUNS & SHOT 8 HOLES 7652-7654' FOR 4TH TYONEK INTERVAL TEST. RIH W/ RTTS, PU 3 1/2" DP. TESTED MANIFOLD TO 5000 PSI, LINES TO 3000 PSI. SET RTTS ~ 7632' DIL. OPENED BYPASS & LOADED DP W/ N2. CLOSED BYPASS & OPENED WELL TO ATMOSPHERE THRU CHOKE. GAS TO SURFACE IN 2 HOURS, PRESS HAD DROPPED FROM 3150 PSI TO 58 PSI. SI FOR BUILDUP TO SYSTEM PRESS: TOOK 5 1/4 HRS TO BUILD FROM 30 PSI TO 740 PSI. TESTED FOR 2 HOURS TO 97.7 MCFD ~ 710 PSI, DRY. 7664' BP/ 8154' ETD 34 D 9/16/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DALLY COST: $ 48,891 CUM COST: $2,290,247 AFE AMT: $3,969,000 SI, OPENED BYPASS & FILLED ANNULUS. REV OUT (HAD TO STOP TO UNPLUG MANIFOLD.) DROPPED DOWN TO TAG BP 8 7664' & FOUND RTTS HAD BEEN SET 100' HIGH (WAS AT 7532' DIL, THOUGHT TO BE AT 7632'). REV OUT. PULLED UP TO 7624' & RESET PKR FOR ANOTHER TEST OF SAME ZONE, 7652-7654'. OPENED BYPASS & LOADED DP W/ N2. CLOSED BYPASS & OPENED WELL TO ATMOSPHERE THRU CHOKE. TOOK 2 1/4 HRS TO GET GAS TO SURFACE, PRESS DROPPED FROM 3150 TO l0 PSI. BUILT UP PRESS W/ SYSTEM GAS TO AVOID LENGTHY NATURAL BUILDUP & PUT TO TEST SEPARATOR. NO FLOW. RESHOT PERFS 4 HPF W/ 2 1/8" THRU-TBG GUNS-STILL NO FLOW. RIH W/ HR PRESS & TEMP SURVEY: FOUND FL 8 7507' DIL, BHP:917 PSI ~ 7567', TEMP:ll9° F ~ FL. PULLED TOOL INTO LUBRICATOR & OPENED WELL TO ATMOSPHERE UNCHOKED ATTEMPTING TO UNPLUG PERFS. PRESS DROPPED TO ATMOSPHERIC-STILL NO FLOW (APPARENTLY NO PERFS OPEN). UNION OIL COMPANY OF CALIFORNIA WELL RECORD · LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 SHEET D PAGE NO. 10 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7664' BP/ 8154' ETD 35 D 9/17/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ RCF 35 sec DAILY COST: $ 38,125 CUM COST: $2,328,372 AFE AMT: $3,969,000 SI, OPENED BYPASS & FILLED ANNULUS. REV OUT. DROPPED BELOW PERFS & CONT REV OUT. STRAPPED OUT OF HOLE (CONFIRMED CORRECT RTTS DEPTH). RIH W/ EZSV BP ON WL - HUNG UP 8 5412'. SET BP & POH W/ WL. RIH W/ 8 1/2" BIT & JUNK SUB & DRLD UP BP, PUSHING TO 7664'. CIRC & POH. RAN 8.1" GAGE RING & JUNK BASKET ON WL. RECOVERED FULL BASKET OF RUBBER PIECES. RERAN GAGE RING & JUNK BASKET, RECOVERING SMALL RUBBER PIECES. 6527' BP/ 8154' ETD 36 D 9/18/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ RCF 36 SEC DAILY COST: $ 58,032 CUM COST: $2,386,404 AFE AMT: $3,969,000 RIH W/ EZ DRILL BP ON DP & SET 8 7532' DIL. POH. RU GO & PERF F/ 7518' TO 7520' W/ 4" CSG GUNS ~ 4 HPF. RIH W/ EZ DRILL RET ON DP & SET ~ 7481' DIL. POH. SQZ THRU RET W/ 160 SX OF "G" W/ 1% CACL, .3% HALAD 24 & .75% CFR-2. FORMATION HELD 2500 PSI W/ PUMPS OFF. POH. TST BOPE. TEST PLUG SEALS FAILED- WILL HAVE TO COMPLETE BOPE TEST TOMMOROW. RIH W/ EZ DRILL BP ON DP & SET ~ 6527' DIL. POH. PERF F/ 6515' TO 6517' W/ 4" CSG GUNS ® 4 HPF. RIH W/ HOWCO TEST TOOLS. 7664' BP/ 8154' ETD 37 D 9/19/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 36 SEC DAILY COST: $ 36,676 CUM COST: $2,423,080 AFE AMT: $3,969,000 CONT RIH W/ RTTS & AUXILIARY VALVE, FILLING 1ST 11 STANDS W/ WATER CUSHION. TSTD MANIFOLD & SURF LINES TO 5000 PSI. SET RTTS ~ 6474'. RIH W/ NEUTRON LOG, TAGGING FL ® 5334'. OPENED AUX VALVE TO PUT WELL ON TEST. SLIGHT BLOW. SI ~ SURF 2 HRS LATER & RECHECKED FL $ 5167' (167' RISE, 1.1 BBL GAIN). OPENED BYPASS & REV OUT. UNSET RTTS, RIH BELOW PERFS & CONT REV OUT. POH. RIH W/ BIT #17 & JUNK SUB & DRLD UP RET ® 6527', PUSHING TO 7492'. CIRC & POH. TSTG BOPE. 6469' RET/ 8154' ETD 38 D 9/20/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 37 SEC DAILY COST: $ 78,546 CUM COST: $2,464,950 AFE AMT: $3,969,000 TSTD BOPE TO 5000 PSI. RIH W/ BP ON WL & SET $ 7345' DIL. RIH & PERFED 7335-7337' LOWER BELUGA DIL 4 HPF W/ 4" CSG GUNS. RIH W/ RET ON 5" DP & SET ® 7290'. BROKE DOWN FORM W/ 2750 PSI, PUMPED INTO $ 2 BPM W/ 2650 PSI. HELD 2000 PSI AFTER 10 MIN W/ PUMPS OFF. MIXED & PUMPED 150 SX CL "G" CMT W/ 1% CACL2, 0.3% HALAD 24 & 1% CFR-2. DISPL 145 SX BELOW TOOL TO FINAL PRESS OF 2900 PSI $ 1 1/2 BPM. HELD 2250 PSI AFTER 5 MIN W/ PUMPS OFF. CIP $ 1013 HRS. REV OUT & POH. RIH & SET BP ON WL $ 6532' DIL. RIH W/ RET ON 5" DP & SET ® 6469'. BROKE DOWN MIDDLE BELUGA PERFS 6515-6517' W/ 2300 PSI, PUMPED INTO $ 1 1/2 BPM W/ 2250 PSI. HELD 1800 PSI AFTER 15 MIN W/ PUMPS OFF. M & P 150 SX CMT (SAME SLURRY) & DISPL 143 SX BELOW TOOL TO FINAL PRESS OF 2850 PSI $ 1 3/4 BPM. HELD 2100 PSI W/ PUMPS OFF AFTER l0 MIN. CIP 2030 HRS. REV OUT & POH. RIH W/ BP ON WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5032' RET/ 8154' ETD 39 D 9/21/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 36 SEC DAILY COST: $ 31,627 CUM COST: $2,552,964 AFE AMT: $3,969,000 SET BP $ 6126' DIL. RIH & PERFED MIDDLE BELUGA 6116-6118' DIL 4 HPF W/ 4" CSG GUNS. RIH W/ RET ON 5" DR & SET ® 6066'. BROKE DOWN FORM W/ 1950 PSI. PUMPED INTO $ 2 BRM W/ 1750 PSI. HELD llO0 PSI AFTER 5 MIN W/ RUMPS OFF. MIXED & PUMPED 200 SX CL "G" CMT W/ 1% CACL2, 0.3% HALAD 24 & 1% CFR-2. DISRL 190 SX BELOW TOOL TO FINAL PRESS OF 2100 PSI $ 2 3/4 BRM. HELD 1550 PSI AFTER l0 MIN W/ RUMPS OFF. CIR @ 0919 HRS. REV OUT & ROH. RIH & SET BR ON WL $ 5070' DIL. RIH & RERFED UPPER BELUGA 5054-5056' DIL. RIH W/ RET ON 5" DR & SET $ 5032'. ATTEMPTED TO OBTAIN BREAKDOWN, 8UT MUD PUMPED AWAY W/ 900 PSI $ 2 BRM, 1200 PSI ® 4 1/2 BRM. WOULD NOT HOLD ANY PRESS W/ RUMPS OFF. M & R 300 SX CMT (SAME SLURRY) & DISRL 293 SX BELOW TOOL TO FINAL PRESS OF 1300 PSI $ 3 BRM. HELD 1050 PSI W/ PUMPS OFF AFTER 5 MIN. CIP ~ 1938 HRS. REV OUT & POH. RIH & PERFED UPPER BELUGA 5008-5010' DIL 4 HPF W/ 4" CSG GUNS. 4713.5' BP/ 8154' ETD 40 D 9/22/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 36 SEC DAILY COST: $ 76,325 CUM COST: $2,629,289 AFE AMT: $3,969,000 RIH W/ RET ON 5" DP & SET $ 4995'. BROKE DOWN FORM W/ 1000 PSI. PUMPED INTO $ 3 BPM W/ 750 PSI. PRESS BLED TO 0 PSI AFTER 10 MIN W/ PUMPS OFF. MIXED & PUMPED 500 SX CL "G" CMT W/ 1% CACL2, 0.3% HALAD 24 & 1% CFR-2. DISPL 486 SX BELOW TOOL TO FINAL PRESS OF 1750 PSI $ 2 BPM. HELD 1500 PSI AFTER 10 MIN W/ PUMPS OFF. CIP ~ 0434 HRS. REV OUT & POH. RIH & PERFED UPPER BELUGA 4975-4977' DIL 4 HPF W/ 4" CSG GUNS. RIH W/ RET ON 5" DP & SET ~ 4934'. BROKE DOWN W/ 1300 PSI, PUMPED INTO $ 2 BPM W/ 950 PSI, 3 BPM W/ 1100 PSI. HELD 300 PSI AFTER 10 MIN W/ PUMPS OFF. M & P 500 SX CMT (SAME SLURRY) & DISPL 488 SX BELOW TOOL TO FINAL PESS OF 1550 PSI ® 3 BPM. HELD 1100 PSI W/ PUMPS OFF AFTER 10 MIN. CIP ~ 1258 HRS. REV OUT & POH. RIH & PERFED C-2 SAND 4895-4897' DIL 4 HPF W/ 4" CSG GUNS. RIH W/ RET ON 5" DP & SET 4852'. BROKE DOWN FORM W/ 1000 PSI. PUMPED INTO $ 3 1/2 BPM W/ 600 PSI. HELD 0 PSI W/ PUMPS OFF. MIXED & PUMPED 500 SX CMT (SAME SLURRY) & DISPL 476 SX BELOW TOOL TO FINAL PRESS OF 1500 PSI ® 2 BPM. HELD 1300 PSI AFTER 10 MIN W/ PUMPS OFF. CIP ® 1920 HRS. REV OUT & POH. RIH & SET BP ON WL ~ 4713.5' DIL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D RAGE NO. 12 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4695' TOC/ 8154' ETD 41D 9/23/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ RCF 36 SEC DAILY COST: $ 25,335 CUM COST: $2,654,624 AFE AMT: $3,969,000 RIH & PERFED B-5 SAND 4698-4700' DIL 4 HPF W/ 4" CSG GUNS. RIH W/ RET ON 5" DP & SET $ 4658'. BROKE DOWN FORM W/ 1500 PSI. PUMPED INTO $ 2 BRM W/ 650 PSI. HELD 0 PSI W/ RUMPS OFF. MIXED & PUMPED 500 SX CL "G"'CMT W/ 1% CACL2, 0.3% HALAD 24 & 1% CFR-2. DISRL 486 SX BELOW TOOL TO FINAL PRESS OF 1700 PSI ® 3 BRM. HELD 1300 PSI AFTER l0 MIN W/ RUMPS OFF. CIR $ 0430 HRS. REV OUT & ROH. WOC. RIH W/ BIT #18 & 20UNK SUBS, RUBBERING DR. TAGGED FIRM CMT $ 4651' & CO TO RET ~ 4657'. CO RET & CMT TO 4695'. 4995' RET/ 8154' ETD 42 D 9/24/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 35 SEC DAILY COST: $ 53,940 CUM COST: $2,708,564 AFE AMT: $3,969,000 CONT CO FIRM CMT 4695' TO BP ® 4713.5'. PRESS TSTD SQZ HOLES 4698-4700' TO 1500 PSI FOR 5 MIN - OK. DRLD UP BP & CHASED TO 4757.5' DRLD SUNK & PUSHED TO TOP CMT ~ 4836'. ~RLD OUNK & FIRM CMT TO 4837' & POH. RIH W/ BIT #19 & DRLD SUNK, CMT, RET ~ 4852', & FIRM CMT TO 4925'. PRESS TSTD SQZ HOLES 4895-4897' TO 1500 PSI FOR 5 MIN- OK. DRLD FIRM & SEMI-FIRM CMT 4925' TO RET ~ 4934'. DRLD ON RET & POH. RIH W/ BIT #20 & DRLD RET ~ 4934', FIRM CMT TO 4977', & SEMI-FIRM CMT TO 4983'. FELL THRU TO RET ~ 4995' PRESS TSTD SQZ HOLES 4975-4977' TO 1500 ~SI FOR 5 MIN - OK. 5070' RET/ 8232' ETD 43 D 9/25/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 37,662 CUM COST: $2,746,226 AFE AMT: $3,969,000 DRLD RET 4995' & FIRM CMT TO RET ~ 5032'. PRESS TSTD S~Z HOLES 5008-5010' TO 1500 PSI. BLED TO 540 PSI IN 5 MIN. REPEATED TEST W/ SAME RESULTS, ENSURING NO SURFACE LEAKS. CIRC BTM UP & POH. RAN CSG SCRAPER TO 5032', CIRC & POH. RIH W/ RTTS & SET 4713' (BELOW TOP S~Z HOLES). TSTD BACKSIDE TO 1500 PSI FOR 5 MIN-OK. UNSET RTTS, RIH, & RESET ® 4934' (BELOW NEXT SET OF SQZ HOLES.) TSTD BACKSIDE TO 1500 PSI FOR 5 MIN - OK. RIH & RESET RTTS ~ 4995' BELOW NEXT SQZ HOLES & TSTD BACKSIDE TO 1500 PSI -OK. PRESS UP DP & TSTD SQZ HOLES 5008-5010' TO 1500 PSI FOR 20 MIN - OK. RIH W/ RTTS RESET ~ 5032' BELOW ALL PERFS & TSTD BACKSIDE TO 1500 PSI FOR 5 MIN - OK. POH W/ RTTS. RIH W/ BIT #21 & CO RET ~ 5032', FIRM CMT TO 5063', '& STRINGERS TO 5070'. PRESS TSTD SQZ HOLES 5054-5056' & ABOVE TO 1500 PSI - BLED TO 750 PSI IN 5 MIN, 250 PSI IN 10 MIN. (APPEARS THAT DV COLLAR ~ 4998-5002' WAS SHIFTED OPEN WHEN DRLD THRU, CLOSED BY SCRAPER RUN, & REOPENED WHEN RTTS WAS POH.) UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5070' RET/ 8232' ETD 44 D 9125184 13 318" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 25,003 CUM COST: $2,771,229 AFE AMT: $3,969,000 PULLED ABOVE DV 8 4998' & RETSTD - NO GOOD. POH, CLOSED BLINDS & RETSTD - NO GOOD. RIH W/ RTTS & SET ~ 4985' (JUST ABOVE DV). TSTD BACKSIDE - OK. PRESS DOWN THRU TOOL- GOT BLEED OFF. TSTD SURF LINES & ATTEMPTED BREAKDOWN W/ HOWCO TO 2700 PSI - HELD STEADY. ATTEMPTED BREAKDOWN W/ RIG PUMPS - STILL NO BREAKDOWN OR BLEED OFF. RELEASED RTTS & POH TO 4970'. CIRC DP CAPACITY TO ENSURE DP & RTTS CLEAR, THEN CLOSED 8AG PRESS ANNULUS - NO LEAKS ANYWHERE IN CSG. RIH W/ RTTS TO 5065' & RETSTD - AGAIN NO LEAKOFF. PULLED UP TO OV, CLOSED 8AG & STRIPPED THRU DV W/ PRESS ON BACKSIDE - SUCCESSFULLY OPENING DV. SET RTTS TSTD BACKSIDE - OK. PRESS UP DP TO 1500 PSI - BLED TO 1150 PSI IN 5 MIN. REPRESSURED DP - DV APPEARED TO SLAM SHUT & PRESS SPIKED 2100 PSI, THEN BLED OFF RAPIDLY, INDICATING POSSIBLE SQZ BREAKDOWN. RESET RTTS 8 5004' & TSTD BACKSIDE - OK (DV CLOSED). PRESS DOWN DP - PUMPED AWAY, INDICATING A SQZ BELOW THE DV HAD BROKEN DOWN. RESET RTTS & REPEATED TST ~ 5007' & 5009' TO ENSURE DPM OK. POH, DRAGGING RTTS THRU DV TO PERMANENTLY CLOSE IT. RIH & SHOT 8 HOLES 4998-5000' 4 HPF W/ 4" CSG GUNS (THRU DV). POH, CLOSED BLINDS & PRESS TSTD CSG - BLED FROM 1200 TO 200 PSI IN 2 MIN. 4990' TOC/ 8232' TD 45 D 9/27/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 56,376 CUM COST: $2,827,605 AFE AMT: $3,969,000 RIH W/ RET ON 5" DP & SET ~ 4985'. PUMPED THRU RET 8 2 BPM, 1700 PSI. ALL PRESS BLED OFF AFTER 1MIN W/ PUMPS OFF. MIXED & PUMPED 500 SX CL "G" CMT W/ 1% CACL2 1% CFR-2 & .3% HALAD-24. DISPLACED 485 SX BELOW RET TO FINAL PRESS OF 1850 PSI 8 2 BPM. HELD 1400 PSI AFTER 5 MIN W/ PUMPS OFF. CIP 8 0230 HRS. REVERSED OUT & POH. RIH TO 4948' & WOC. DRLD SOFT CMT 4981-4985', RET 4985-4988' & 2' OF GREEN CMT TO 4990'. POH W/ 5" DP. RIH W/ 3 1/2" DP & POH, LAYING DOWN IN PREP TO RATTLE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD 'DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4991' RET/ 8232' TD 46 D 9/28/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76+ PCF 34 SEC DAILY COST: $ 51,561 CUM COST: $2,879,166 AFE AMT: $3,969,000 5028' RET/ 8232' TD 47 D 9/29/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 33 SEC DAILY COST: $ 40,293 CUM COST: $2,919,459 AFE AMT: $3,969,000 6066' RET/ 8232' TD 48 D 9/30/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST': $ 26,822 CUM COST: $2,946,281 AFE AMT: $3,969,000 RIH W/ BIT #23 & DRLD FIRM CMT 4990-5004'. TSTD SQZ $ STAGE COLLAR TO 1500 PSI - OK. CONT DRLG CMT TO 5006', FELL THRU TO 5010' & DRLD STRINGERS TO 5016'. TSTD CSG TO 1500 PSI - NO GOOD. CONT CO TO 5020' & ROH. RAN JUNK BASKET & GAGE RING TO 5020'. RAN & SET EZSV RET ON WL ® 4991'. RIH W/ DP & STUNG INTO RET. TSTD SURF LINES & MANIFOLD TO 5000 PSI. BROKE DOWN PERFS 5008-5010' W/ 1800 PSI, PUMPED AWAY $ 1600 PSI, 1 1/2 BPM. HELD 600 PSI AFTER 4 MIN W/ PUMPS OFF. MIXED & PUMPED 300 SX CL "G" CMT W/ 1% CACL, 1% CFR-2, & .3% HALAD 24. DISPLACED 285 SX BELOW RET $ FINAL RATE OF 1 1/2 BRM, 1900 PSI. HELD 1350 PSI AFTER 5 MIN W/ RUMPS OFF. CIR ~ 1750 HRS. REVERSED OUT & ROH. RATTLED 3 1/2" DP & 5" DP WHILE WOC. RIH W/ BIT #24, TAGGING CMT ~ 4848' CO CMT & RET ~ 4991' TO 5004'. TSTD C~G TO 1500 PSI - OK. CONT CO CMT TO 5016' & TSTD CSG TO 1500 PSI - OK. DRLD CMT TO 5020', BOTTOM OF CMT & CO TO 5063'. TSTD CSG TO 1500 PSI- BLED OFF TO ll20 PSI IN 7 MIN. CIRC & ROH. RIH W/ EZSV RET ON 5" DR & SET ® 5028'. TSTD SURF EQUIP TO 5000 PSI. BROKE DOWN P~RFS @ 5054-5056' W/ 1750 PSI. PUMPED AWAY ~ 1 1/4 BPM, 2000 PSI. HELD 500 PSI AFTER 5 MIN W/ PUMPS OFF. M & P 150 SX CL "G" CMT W/ 1% CACL2, 1% CFR-2, & .3% HALAD 24. DISPL 138 SX BELOW RET TO FINAL SQZ PRESS OF 2250 PSI ~ 1 BPM. HELD 1650 PSI W/ PUMPS OFF AFTER 6 MIN. CIP ® 2114 HRS. REV OUT & POH. STRAPPED, CLEANED & REDOPED 3 1/2" DP W/ TEFLON DOPE WHILE WOC. RIH W/ 8IT #25 & DRLD CMT 5022-5028' & RET 5028-5031'. CONT CO CMT TO 5063' & TSTD CSG TO 1500 PSI - OK. DRLD CMT TO 5070' & BP ~ 5070', CHASING IT TO 6054'. CO JUNK & CMT TO RET ® 6066'. DRLD ON RET, THEN POH FOR BIT CHANGE. RIH W/ BIT #26 & DRLD ON RET $ 6066'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 15 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7287' ETD/ 8232' TD 49 D 10/1/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 35 SEC DAILY COST: $ 25,771 CUM COST: $2,972,052 AFE ANT: $3,969,000 DRLD OUT RET 6066-6069' & CMT TO 6126'. TSTD CSG & SQZ HOLES 6116-6118' TO 1500 PSI - OK. DRLD UP BP @ 6126' & PUSHED TO 6464'. DLRD JUNK & RET TO 6468' & POH. RIH W/ BIT #27 & DRLD RET & CMT TO 6533'. TSTD CSG & SQZ HOLES $ 6515-6517' TO 1500 PSI - OK. DRLD UP BP $ 6533' & CHASED TO 7284'. DRLD ON BP JUNK & RET TO 7287'. POH FOR BIT CHANGE. 7668' OUNK/ 8232' TD 51 D 10/3/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST: $ 29,136 CUM COST: $3,028,380 AFE AMT: $3,969,000 8047' ETD/ 8232' TD 52 D 10/4/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST: $ 27,713 CUM COST: $3,056,093 AFE AMT: $3,969,000 CONT DRLG JUNK & RET 7480-81' & CMT TO 7493' ON REPAIR RATE TO REPAIR THROWN ROTAR~ CHAIN. CONT DRLG CMT TO 7505'. PUMPED PILL & POH FOR BIT CHANGE. RIH W/ BIT #30 & DRLD CMT 7505-32'. TSTD CSG & SQZ HOLES 7518-20' TO 1500 PSI - OK. CO RET ~ 7532' & RIH TO 7664'. CO SUNK 7664- 68' & ROH FOR BIT CHANGE. RIH W/ TRI-STATE 8-BLADE MILL. MILLED RET ® 7668' & RIH TO 7959'. MILLED ON RET 7 1/2" HRS & POH - FINDING MILL 100% WORN OUT. RIH W/ BIT #31 & DRLD RET ~ 7959' IN 20 MIN. CHASED JUNK & SET DOWN ® 8047' (14' ABOVE WHERE RET ~ 8061' IS SUPPOSED TO BE). POH. WILL CONFIRM DEPTHS W/ CBL. 8047' ETD/ 8232' TD 53 D 10/5/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST: $ 49,885 CUM COST: $3,105,978 AFE ANT: $3,969,000 RAN SCRAPER TO 8047' ETD (8063' DPM). CIRC CLEAN & POH. RAN GEARHART CBL 8045-4000'. RIH OE W/ DP WHILE CLEANING PITS. BEGAN MIXING COMPL FLUID. 8047' ETD/ 8232' TD 54 D 10/6/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST: $ 79,125 CUM COST: $3,185,103 AFE ANT: $3,969,000 CONT MIXING 76 PCF 6% KCL/CACL2 COMPL FLUID. CHANGED OVER HOLE TO COMPL FLUID. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8047' ETD/ 8232' TD 55 D 10/7/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF 34 SEC DAILY COST: $ 40,036 CUM COST: $3,225,139 AFE AMT: $3,969,000 8047' ETD/ 8232' TD 56 D 10/8/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF 34 SEC DAILY COST: $ 34,241 CUM COST: $3,259,380 AFE AMT: $3,969,000 COMPLETED CHANGE OVER. RIH W/ BAKER 6" TBG-CONVEYED GUNS LOADED 12 HPF ON 3 1/2" DP. TAGGED BTM ~ 8064' DPM. TSTD LUBRICATOR TO 4000 PSI. RAN GR-CCL TO PROPERLY POSITION GUNS 8004-7989' DIL W/ PKR 8 7959' & RA SOURCE 8 7926 1/2'. POH WL. PLACED 3000 PSI BHP (REFERENCE: TOP SHOT ~ 7990' MD DIL, 7614' TVD DIL) N2 CUSHION IN DP (2323 PSI SURF PRESS). DROPPED FIRING BAR, GUNS SHOT i MIN 55 SEC LATER. NO SIGNIFICANT PRESS CHANGE ~ SURFACE AFTER 55 MIN. OPENED WELL TO FLOW IN ATTEMPT TO BRING ON - BLED TO ATMOSPHERIC AFTER 1 HR. SI WELL 3 HR 50 MIN AFTER OPENING TO FLOW. SI PRESS BUILT FROM 0 TO 33 PSI IN 15 MIN. FILLED DP & UNSET PKR. REV CIRC BTMS UP. RIH & TAGGED 1' OF FILL. REV CIRC +5000 STROKES BEFORE GAS DISSIPATED (BTMS UP = 900 STROKES). POH - ALL GUNS HAD FIRED, FORM SAND ON BTM 3 1/2'. RIH W/ RTTS & HYDRO- SPRING ON DRY DP. TAGGED BTM ~ 8064' DPM, 8047' DIL. PICKED UP & SET RTTS @ 7951.5' DIL W/ TAIL TO 7962.5'. WITH WELL SI ~ SURF, OPENED HYDROSPRING ~ 1828 HRS. PRESS ~ SURF BUILT TO 562 PSI BY 1940 HRS WHEN WELL WAS OPENED TO ATMOSPHERE. BLED TO 25 PSI IN 15 MIN. 8047' ETD/ 8232' TD 57 D 10/9/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 34 SEC DAILY COST: $ 31,996 CUM COST: $3,291,376 AFE AMT: $3,969,000 LEFT WELL OPEN FOR 4 HR 20 MIN - FLOWING THRU 1" CHOKE ~ 31 PSI. SI FOR 1 HR & BUILT PRESS TO 830 PSI. OPENED WELL TO ATMOSPHERE, BLEEDING TO 29 PSI IN 15 MIN. FLOWED FOR 1 1/2 HRS ~ 36 PSI. PUT INTO SYSTEM FOR 6 HR TEST: RATE INCREASED F/ 471 TO 499 MCFD ~ 710 PSI THRU 1" ORIFICE. CLOSED HYDROSPRING & FILLED DP, SHEARING PUMP-OUT SUB. REV CIRC DP & UNSET PKR. RIH TAGGING BTM ~ 8063' DPM & REV OUT 2 1/2 TIMES DR VOL. BEGAN ROH. SNAGGED COMING UR THRU RERFS & COULD NOT GET BACK BELOW THEM. DR DEAD BUT ANNULUS FLOWING. PUMPED 3 MORE DR VOL - GAS STILL BUBBLING ® SURF. BEGAN PUMPING THE LONG WAY. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 17 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8047' ETD/ 8232' TD 58 D 10/10/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 22,686 CUM COST: $3,314,062 AFE AMT: $3,969,000 CONT PUMPING THE LONG WAY UNTIL WELL DEAD. POOH. RIH W/ BIT & SCRPR HITTING TIGHT SPOT ~ 8020' DPM. WORKED TIGHT SPOT A DOZEN TIMES, TAGGED FILL ~ 8036' DPM & CO TO 8064' DPM. CIRC, CK FOR FLOW & POOH. RIH W/ 15' OF BAKER 4 HPF 90° PHASING, TBG CONVEYED GUNS W/ PKR & UNDERBALANCING DISC ON DRY DP. TAGGED BTM & PICKED UP TO POSI- TION GUNS. RU & TEST LUBRICATOR TO 4000 PSI. RIH W/ GR TO CORRELATE & PROPERLY POSITION GUNS. 8047' ETD/ 8232' TD 59 D 10/11/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 61,996 CUM COST: $3,376,058 AFE AMT: $3,969,000 POSITIONED GUNS W/ GR & SET PKR. RERAN GR- FOUND TOP SHOT ~ 7988'. RELEASED & RESET PKR. RERAN GR - FINDING SHOTS POSITIONED 7989.12 - 8004.12'. PUT FIRING BAR IN LUBRICATOR & LOADED DP W/ N2 CUSHION (1900 PSI BHP, i516 PSI SURF PRESS). DROPPED BAR - TOOK 1:29 MIN FOR GUNS TO FIRE. PUT HP PRESS GAGE IN LUBRICATOR & TSTD TO i520 PSI. OPENED WELL TO ATMOSPHERE 40 MIN AFTER FIRING GUNS W/ 1527 PSI SURF PRESS. SI WELL AFTER 4 i/2 HRS TO BUILD PRESS - TOOK i i/2 HRS FOR PRESS TO BUILD FROM i5 PSI TO 725 PSI, SEPARATOR PRESS. FLOW TSTD FOR 8 HRS W/ RATE CLIMBING FROM 339 MCFD TO STEADY 388 MCFD. SI, FILLED ANNULUS & REV CIRC. CIRC LONG WAY. UNSET PKR & ATTEMPTED TO DROP DOWN - UNABLE TO DO SO. CONT CIRC. 8047' ETD/ 8232' TD 60 D 10/12/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 21,135 CUM COST: $3,397,193 AFE AMT: $3,969,000 PU 2 STS & CHECKED PKR - WAS INDEED UNSAYED, INDICATING THAT SAND FILL HAD PREVENTED US FROM DROPPING DOWN. POH & TSTD BORE: HYDRIL TO 2500 PSI, REMAINDER TO 5000 PSI. RIH W/ BIT & SCRAPER TO 7989'. WORKED THRU PERFS & SAND FILL TO 8004' (AVG 40,000# OVERPULL BOTH UP & DOWN, AS HIGH AS 75,000# OVER COMING UP). CO TO 8047', CIRC & POH (PULLING 25,000# OVER ~ 7989-95'). RIH W/ TAPERED MILL & MILLED 7989-8004'. RIH TO 8047', CIRC, & POH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD . LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 SHEET D PAGE NO. 18 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8047' ETD/ 8232' TD 61 D 10/13/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 55,482 CUM COST: $3,452,675 AFE AMT: $3,969,000 RIH W/ RTTS & 2 7/8" TBG TAIL & SET @ 7957'. RU HOWCO, DOWELL & BO LINES, TSTG TO 5000 PSI W/ N2. OPENED PKR BYPASS & DISPL DP W/ N2 TO 3190 PSI SURF PRESS. CLOSED BYPASS & PUMPED 25,000 SCF N2 TO A SURF PRESS OF 4700 PSI ATTEMPTING TO BREAKDOWN PERFS. RETSTD SURF EQUIP TO 7200 PSI W/ N2. WELLHEAD PRESS HAD FALLEN TO 4335 PSI. CONT PUMPING N2 DOWN DP TO A TOTAL OF 45,000 SFC THRU TOOL W/ BREAKDOWN 8 5300 PSI SURF PRESS. SI FOR 30 MIN, PRESS FELL TO 4700 PSI. PUMPED 2000 GALS OF DOWELL'S MSR-iO0 ACID (HCL) W/ .5% A250 INHIBITOR NITRIFIED W/ 800 SCF N2 PER BBL. INITIAL PRESS OF 5100 PSI, FINAL PRESS OF 4100 PSI. DISPL ACID INTO FORMATION W/ 82,000 SCF N2 TO FINAL PRESS OF 3841 PSI. BLED OFF N2 & ACID THRU 1/4" CHOKE. NOTICED ANNULUS PRESS HAD BUILT F/ 500 TO 1000 PSI DURING JOB, INDICATING COMMUNICATION BEHIND PIPE F/ ACIDIZED PERFS ® 7989-8004' TO TEST HOLES @ 7948-50'. BLED OFF GAS IN ANNULUS & FILLED W/ +100 BBLS. CIRC TO KILL WELL. 8047' ETD/ 8232' TD 62 D 10/14/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 33,077 CUM COST: $3,485,752 AFE'AMT: $3,969,000 DROPPED DOWN & TAGGED TIGHT SPOT (OR FILL) 8 7996'. CIRC & POH, CHECKING, REDOPING, & RETORQUING ALL CONNECTIONS. RU GEARHART & PERF 7936-7950' 8 HPF W/ 4" CSG (WIRELINE) GUNS (2 RUNS). RIH W/ BIT & SCRAPER - TIGHT 7989-8004' (30,000# OVERPULL AVG, 60,000# MAX). WORKED THRU TIGHT SPOTS UNTIL OVERPULL WAS ONLY 15,000#. RIH TO 8047' & CIRC. POH (70,000# OVER THRU TIGHT SPOT). RIH W/ RTTS & TBG TAIL & SET 8 7875' W/ TAIL TO 7909' (ABOVE BOTH PERFED TYONEK INTERVALS)'. 8047' ETD/ 8232' TD 63 D 10/15/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 19,068 CUM COST: $3,504,820 AFE AMT: $3,969,000 8047' ETD/ 8232' TO 64 D 10/16/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 23,451 CUM COST:$3,528,271 AFE AMT: $3,969,000 RIH W/ HP PRESS RECORDER. FOUND FLUID LEVEL ~ 7853'. DST THE TYONEK SANDS 7936-7950' DIL & 7989-8004' DIL. SANDS PRODUCED +.42 MMSCFD ~ 730 PSI SURF PRESS THRU A 3/4" CHOKE. BLOW WELL DOWN TO ATM. REFF! rD Alaska Oil & 6aa bu~ts, uommissio~ Anchora§o PROD RATE INCREASED TO .579 MMSCFD. OPEN WELL TO ATM. PUT WELL BACK iNTO PROD ~ A RATE OF .730 MMSCFD W/ A SURFACE PRESS OF 770 PSI, THRU A 1" CHOKE. RIH W/ 16' OF 2 1/8" PERFORATING GUNS, 4 HPF, 0° PHASING ~ 2400 HRS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 19 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8047' ETD/ 8232' TD 65 D 10/17/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF DAILY COST: $ 39,746 CUM COST: $3,568,017 AFE AMT: $3,969,000 PERF F/ 7916-7932' DIL. OPEN WELL TO ATM. SHUT IN FOR TEST & BUILD-UP. OPEN TO ATM. SHUT IN FOR TEST. TYONEK PRODUCED 1.03 MMSCFD W/ SURF PRESS OF 740 PSI THRU A i" CHOKE. PERFS OPEN IN TYONEK (7936-7950') (7989-8004')(7916-7932'). KILL WELL & POOH. 7750' (CMT RET)/ 8232' TD 66 D 10/18/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 35,884 CUM COST: $3,603,901 AFE AMT: $3,969,000 RAN 8 1/2" GAGE RIG & JUNK BASKET TO 7800'. RIH & SET SET CMT RET ON WL ABOVE PERFS ~ 7750' DIL. RERFD U. TYONEK F/ 7668'-7642' DIL W/ BAKER 6" TBG CONVEYED GUNS, LOADED 9 HRF, 60° RHASING, UNDERBALANCED W/ 3100 RSI BHR, 2460 RSI SURF.TSTD TYONEK SD 8 +.48 MMSCFD W/ A SURF RRESS OF 730 RSI THRU A 1" CHOKE. 7750' (CMT RET)/ 8232' TD 67 D 10/19/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF DAILY COST: $ 45,229 CUM COST: $3,649,130 AFE AMT: $3,969,000 DST THE TYONEK (7668-7642' DIL) SAND $ 1.00 MMSCFD W/ A SURF PRESS OF +700 PSI THRU A 1" CHOKE. UNION OIL COMPANY OF CALIFORNIA NELL RECORD SHEET D PAGE NO. 2O LEASE KENAI TYONEK UNIT A-028142 NELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD 7750' (CMT RET)/ 8232' TD 68 D 10/20/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF DAILY COST: $ DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS CONT DST TYONEK (7668-7642' DIL). RATE INCREASED TO 1.14 MMSCFD ~ A SURF PRESS OF 706 PSI. KILL WELL. FOUND NO SAND ON CMT RET ~ 7750' DIL. REVERSING WELLBORE CLEAN. 30,110 CUM COST: $3,679,240 AFE AMT: $3,969,000 7600' (CMT RET)/ 8232' TD RAN 8.156" GAGE RING TO 7620". RAN & SET CMT RET ON WL ABOVE THE TYONEK ~ 7600' OIL. 69 D 10/21/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 58,202 CUM COST: $3,737,442 AFE AMT: $3,969,000 RIH W/ BAKER 5", 9 HPF, 120° TBG CONVEYED GUNS ON DP TO PERF THE L. BELUGA 7502-20' DIL W/ RTTS SET 8 7468'. DIS W/ N2 TO A SURF PRESS OF 3033 PSI. BLED N2 OFF TO 1292 PSI SURF PRESS. DROPPED FIRING BAR. ATTEMPT TO BRING WELL ON. 7475' (CMT RET)/ 8232' TD 70 D 10/22/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST' $ 32,539 CUM COST: $3,769,981 AFE AMT: $3,969,000 LOWER BELUGA SAND (7502-7520' DIL) WOULD NOT PRODUCE ANY GAS. FINAL SURFACE PRESS BUILD-UP = 5.8 PSI. KILL WELL. POH. TESTED BOPE. RIH & SET CMT RET ~ 7468' DIL TO SQZ OFF THE LOWER BELUGA SAND (7520-7502' DIL). 7475' DIL (CMT RET)/ 8232' TD 71D 10/23/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 37,920 CUM COST: $3,807,901 AFE AMT: $3,969,000 SQZ THE LOWER BELUGA SAND (7520'-7502' DIL) W/ 197 SXS CMT. POH. RIH DST TOOLS SET RTTS ~ 6894' DIL, TAIL ® 6929' DIL. DISPLACE DP W/ N2 TO A SURFACE PRESS OF 2864' PSI. CLOSED BY PASS & BLED N2 ~ SURFACE TO 1360 PSI GIVING BHP = 1700 PSI. PERF F/ 6956' - 6962' DIL W/ 2 1/8" LINK TORNADO GUNS, 0° PHASING, 4 HPF. PROCEDE W/ DST. PRESS BUILT TO 136 PSI ® SURFACE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 21 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7475' DIL (CMT RET)/ 8232' TD 72 D 10/24/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 36,872 CUM COST: $3,844,773 AFE AMT: $3,969,000 DST L. BELUGA (6956-6962' DIL). SAND NOT PRODUCING. RIH & FOUND FLUID LEVEL ~ 5604' DIL (i320' VERTICAL FLUID COLUMN ABOVE PERFS). DISPLACE DP W/ N2 & REPERF SAND W/ 2 1/8", 4 HPF, 0° PHASING GUNS. SHOT UNDERBALANCED W/ iO00 PSI ON SURF & DP FULL OF N2. RETEST SAME SAND (6956-6962' DIL) $ 2400 HRS. 7475' DIL (CMT RET)/ 8232' TD 73 D 10/25/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 23,532 CUM COST: $3,868,305 AFE AMT: $3,969,000 L. BELUGA SAND 6956-6962' TSTD TO 89 MCFD. SI WELL & RIH W/ 10' OF GEARHART'S 2 1/8" 4 HPF 0° PHASED TORNADO GUNS. LOCATED GUNS 7320-30', BLED OFF WELL TO ATMOSPHERE & SHOT GUNS UNDER-BALANCED. SI & POH W/ GUNS. OPENED WELL TO ATMOS FOR i i/2 HRS. SI FOR BUILDUP & THEN OPENED WELL TO SYSTEM FOR TEST - TSTG BOTH ZONES ~ STABILIZED RATE OF 98 MCFD. 7475' DIL (CMT RET)/ 8232' TD 74 D 10/26/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 41,504 CUM COST: $3,909,809 AFE AMT: $3~969,000 7475' DIL (CMT RET)/ 8232' TD 75 D 10/27/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 37,364 CUM COST: $3,946,841 AFE AMT: $3,969,000 DST L. BELUGA SANDS (6956-6962' & 7320-7330). SHUT WELL IN FOR BUILDUP. OPEN WELL TO ATM. PUT PRODUCTION INTO SYSTEM W/ A FINAL TEST RATE OF .iii MMSCFD @ 655 PSI SURF PRESS. KILL WELL. POH. RUN GAUGE RIG TO 6900'. RIH & SET BP ON WL ~ 6900'. PU & RIH W/ RTTS. SET RTTS W/ TBG TAIL e 6550' DPM. TST SURF EQUIP. DISPLACE DP W/ N2 TO A SURF PRESS OF 2710 PSI. LOAD 22'-2 1/8", 4 HPF, 0° PHASE TORNADO GUNS IN LUBRICATOR. BLED SURF PRESS TO 763 PSI (APPROX 920 PSI BHP). PERF F/ 6580-6602' DIL. POH W/ WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 22 ' LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7475' DIL (CMT RET)/ 8232' TD 76 D 10/28/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 52,606 CUM COST: $3,999,447 AFE AMT: $3,969,000 6550"BP ETD / 8232' TD 77 D 10/29/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 34,620 CUM COST: $4,034,067 AFE AMT: $3,969,000 DST L BELUGA SD (6580-6602' DIL). PRODUCED ~ 1.80 MMSCFD ~ SURFACE PRESS OF 680 PSI. KILL WELL. RIH W/ GAUGE RING & HIT SOMETHING @ 2700'. WORKED GAUGE RING THRU & RIH TO 6550'. POH. RIH & SET DRILLABLE BP ~ 6550'. POH W/ WL. RIH W/ TEST TOOLS. SET PKR ~ 6432' (TAIL ~ 6466'). DISPLACE DP W/ N2. RIH W/ 15', 2 1/8", 4 HPF, 0° PHASE TORNADO GUNS. BLEED SURFACE PRESS TO 750 PSI, (BHP = 906 PSI). PERF F/ 6500-6515' POH W/ GUNS. RIH W/ HP PRESS RECORDER. ~URF PRESS BUILT TO 753 PSI IN 37 MIN. PU 15' OF NEW GUNS. REPERF L BELUGA F/ 6500-6515' W/ 2 1/8", 4 HPF 0° PHASING TORNADO LINK GUNS W/ 505 PSI ON SURF. BLED WELL TO ATM. SHUT IN TO BUILD- UR. FINAL BUILD-UP AFTER 4 HRS WAS 35 PSI ~ SURF. KILL WELL. PULL UP & RESET RTTS ~ 6360' (TAIL ~ 6394'). RIH W/ 10' OF GUNS (SAME TYPE AS ABOVE). LOST GUNS DOWN HOLE. POH & FOUND GUNS BROKEN OFF. RIH W/ 10' OF NEW GUNS & PERF 6426-6436' DIL W/ 2 1/8", 4 HPF, 0° PHASE TORNADO LINK GUNS W/ 750 PSI ON SURF. SURF PRESS INCREASED TO 768 PSI IN 15 MIN. BLED WELL TO ATM. SHUT WELL IN FOR BUILD-UP ~ 2300 HRS. PRESS BUILT TO 240 PSI ® 2400 HRS. 6550' BP ETD / 8232' TD 78 D 10/30/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 30,231 CUM COST: $4,064,298 AFE AMT: $3,969,000 PERFORM DST #78 (LB PERFS F/ 6500-6515' & MB PERFS F/ 6426-g43g'). OPENED WELL TO ATM, BLED DN TO 15 PSI. SI FOR BUILD-UP. FLOWED TO SEP, FINAL RATE OF .120 MMCF/D. OPENED TO ATM, BLED DN TO 2 PSI. SI FOR BUILD-UP. FLOWED TO SEP, FINAL RATE OF .098 MMCF/D. OPENED TO ATM, BLED DN TO 19 PSI. RIH W/ HP PRESS REC, SI FOR BUILD-UP. FLOWED TO SEP, FINAL RATE OF .112 MMCF/D ~ 600 PSI. KILL WELL. POH. 6406' CMT RET/ 8232' TD 79 D 10/31/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 55,453 CUM COST: $4,119,791 AFE AMT: $3,969,000 RAN GR & JB TO 6510'. POH. RAN HOWCO EZ DRL RET & SET ~ 6464' DIL (6479' DPM). POH. RIH W/ STINGER ON 5" DR. SQZD THE L. BELUGA SD (6500-6515' DIL) W/ 90 SX OF CLASS "G", .3% HALIDE 24, 19% CFR-2, 1% CACL2 SLURRY BELOW RET. HAD FINAL PUMPING RATE OF 1.25 BBL/MIN ~ 2900 PSI. SQZ JOB HELD 2500 PSI W/ RUMPS OFF AFTER 2 MIN. CIR ® 0930 HRS. ROH. RIH W/ GR & OB TO 6450'. RAN HOWCO EZ DRL RET & SET 8 6406' DIL (6421' DRM). ROH. RIH W/ STINGER. SQZD THE M. BELUGA SD (6426-6436' DIL) W/ 134 SX OF CMT (SAME SLURRY) BELOW RET. HAD A FINAL PUMPING RATE OF 1.25 BBL/ MIN 8 3000 PSI. SqZ SOB HELD 2500 PSI W/ RUMP OFF AFTER 2 MIN. CIR 8 1945 HRS. ROH. PULLED WEAR BUSHING F/ DCB SPOOL. SEAT TEST PLUG &RRER TO TEST BORE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 23 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6406' CMT RET/ 8232' TD 80 D 11/01/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 40,081 CUM COST: $4,159,832 AFE AMT: $3,969,000 6350' CMT RET/ 8232' TD 81D 11/02/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 40,880 CUM COST: $4,200,172 AFE AMT: $3,969,000 6304' CMT RET/ 8232' TD 82 D 11/03/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 39,165 CUM COST: $4,239,877 AFE AMT: $3,969,000 5891' CMT RET/ 8232' TD 83 D 11/04/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 56,003 CUM COST: $4,295,880 AFE AMT: $3,969,000 TEST BOPE. RIH W/ TEST TOOLS. SET RTTS ~ 6265' DPM (6249' DIL). DISPLACED DP W/ N2. CLOSED BYPASS & BLED N2 TO 580 PSI SURF PRESS. PERFED F/ 6324-6330' DIL W/ 2 1/8" LINK SET GUNS TWICE. HAD NO PRESS INCREASE. PERFED F/ 6370-6376'. HAD NO PRESS INCREASE & NO GAS TO SURF. REPERFED F/ 6370-6376' W/ 4 HPF, 0° PHASE 2 1/8" TORNADO LINK JET GUNS. M. BELUGA SDS (6370-6376')(6324-6330') WOULD NOT PRODUCE ANY GAS. FINAL FLUID LEVEL WAS 560i' MD, AN INCREASE OF 700' IN 3 i/2" DP. KILL WELL. COND MUD. POH. RUN & SET HOWCO E-Z DRILL RET ® 6350' DIL (6366' DPM). POH W/ WL. PU & RIH W/ STINGER ON 5" DP. SQZ THE M. BELUGA SD (6370-6376') W/ 165 SX CMT BELOW RET W/ A FINAL PUMPING RATE OF 1.5 BBL/MIN @ 2900 PSI. SQZ SOB HELD 2250 PSI W/ PUMPS OFF AFTER 1 MIN. CIP @ 2330 HRS. (CMT SLURRY: "G", 1% CFR-2, 1% CACL2, 3% HALIDE 24). POH ~ 2400 HRS. POH W/ DP. RIH & SET HOWCO E-Z DRL CMT RET ~ 6304' DIL/ 6320' DPM. SQZ M. BELUGA SD (6324-6330') W/ 170 SX CMT BELOW RET W/ A FINAL PUMPING RATE OF 2 BBL/MIN ~ 2500 PSI. SQZ OOB HELD 2200 PSI W/ PUMPS OFF AFTER 2 MIN. CIP ~ 0535 HRS. USED SAME SLURRY AS LAST SQZ. RIH W/ DST TOOLS. SET RTTS ~ 5844' DIL. DISP DP W/ N2 TO 2450 PSI ~ SURF. RIH & PERF F/ 5914-5924' (M. BELUGA) W/ 4 HPF, 0° PHASE, 2 1/8" TORNADO LINK JET GUNS W/ A SURF PRESS OF 550 PSI (BHP=700 PSI). SD WOULD NOT PRODUCE ANY GAS. FLUID LEVEL ROSE OF 5303'. KILL WELL. PULL RTTS LOOSE & RIH & SET RTTS ~ 5937' DIL. DISP DP W/ N2. BLEED N2 TO A SURF PRESS OF 533 PSI. RIH & PERF F/ 5994-6003' DIL W/ 4 HPF, 0° PHASE, 2 1/8" TORNADO LINK JET GUNS. BLED WELL TO ATM. SD WOULD NOT PROD ANY GAS. FLUID LEVEL ROSE TO 2735' MD. KILL WELL. POH W/ DST TOOLS. RIH & SET HOWCO CMT RET ~ 5974' DPM. SQZ THE M. BELUGA SD (5994-6003') W/ 165 SX CMT BELOW RET W/ A FINAL PUMPING RATE OF 1.5 BBL/MIN ~ 2500 PSI. SQZ JOB HELD 1750 PSI W/ PUMPS OFF AFTER i MIN. CIP ~ 1652 HRS. POH. RIH & SET HOWCO CMT RET ~ 589i' DPM. SQZ THE M. BELUGA SD (5914-5924') W/ 163 SX CMT BELOW RET W/ A FINAL PUMPING RATE OF 2 BBL/MIN ® 2250 PSI. SQZ JOB HELD 2100 PSI W/ PUMPS OFF AFTER 3 MIN. CIP ® 2227 HRS. CIRC & CDND MUD. ADD 15 LBS/BBL CACO3. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 24 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5891' RET/ 8232' TD 84 D 11/05/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 1/2 PCF 34 SEC POH. RU GEARHART & PERF U. BELUGA 5401-16', 5343-66', 5141-61', 5110-35', 5073-81', 5059-66', & 4987-96'. ALL SHOTS WERE 4" CSG GUNS LOADED 4 HPF, 120° PHASING. RIH W/ DST TOOLS. DAILY COST: $ 66,955 CUM COST: $4,362,835 AFE AMT: $3,969,000 5450' BP / 8232' TD 85 D 11/06/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 36 SEC DAILY COST: $ 40,195 CUM COST: $4,403,030 AFE AMT: $3,969,000 SET RETRIEVABLE BP ® 5450' DPM. PU 2 STANDS & RAN GEARHART CORRELATION LOG (5232' DRM = 5221' DIL, ll' DIFFERENCE). RIH & SET RKR ~ 5378' DIL W/ TAIL TO 5386' DIL. OPENED BYPASS & DISRL DR W/ N2. CLOSED BYPASS & OPENED TO ATMOS FOR 3 HRS- FLUID LEVEL ROSE 902' TOTAL. SI FOR l0 1/2 HR BUILDUP - PRESS BUILT TO 463 PSI. 5381' BP / 8232' TD 86 D 11/07/84 13 3/8" C. 2500' 9 5/8" C. 8232' 73 PCF 35 SEC DAILY COST: $ 30,371 CUM COST: $4,433,401 AFE AMT: $3,969,000 5096' RBP / 8232' TD 87 D 11/08/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 35 SEC DAILY COST: $ 41,333 CUM COST: $4,474,734 AFE AMT: $3,969,000 BLEW WELL TO ATMOS. AFTER 3 1/2 HRS, W/ STABLE FLOWING PRESS OF 104 PSI, WELL WAS SI. TOOK 1/2 HR TO BUILD TO SYSTEM PRESS. TSTD FOR 5 1/2 HRS W/ RATE DECREASING F/ 197 MCFD TO 185 MCFD. SURGED WELL BY SI, THEN BLOWING TO ATMOS, THEN SI FOR TEST AGAIN. RATE ON FINAL TST DECLINED FROM 149 TO 122 MCFD. KILLED WELL. DROPPED DOWN & CIRC ON RBP ~ 5439'. LATCHED ONTO RBP & RESET ~ 5381'. SET RTTS 8 5328'. TSTD SURF EQUIP TO 4000 PSI W/ N2. OPENED BYPASS & DISPL FL TO 5303' W/ N2. CLOSED BYPASS & BLED OFF TO ATMOS. PUT TO TEST: RATE DROPPED F/ 1.78 TO 1.43 MMCFD IN 2 HRS. SI. KILL WELL. RETRIEVE BP & SET SAME ® 5176'. SET RTTS ~ 5095'. DISP DP W/ N2 TO A SURF PRESS OF 2150 PSI, (FLUID TOP ~ 5033' MD). CLOSE BYPASS & OPEN WELL TO ATM. TST THE U. BELUGA SDS (5110-5135') & (5141-5161'). SDS PRODUCED .689 MMSCFD W/ A SURF PRESS OF 665 PSI, BUT THE FLUID LEVEL ROSE TO +2500' MD INSIDE 5" DP. KILL WELL. FOUND 2--5' OF FICL ON TOP OF RBP. RETRIEVE BP & SET SAME ~ I 5096'. SET RTTS TAIL $ 5044'. DISP DP W/! N2 TO A SURF PRESS OF 2118 PSI (FLUID TO~ ~ 4970' MD. CLOSE BYPASS & OPEN WELL TO A{TM TST THE U. BELUGA SDS (5059-5066')i ~ i UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 25 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5096' RBP / 8232' TD 88 D 11/09/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 33 SEC DAILY COST: $ 21,391 CUM COST: $4,496,125 AFE AMT: $3,969,000 5021' CMT RET/ 8232' TD 89 D 11/10/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 33 SEC DAILY COST: $ 49,726 CUM COST: $4,545,851 AFE AMT: $3,969,000 5021' CMT RET/ 8232' TD 90 D 11/11/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 33 SEC DAILY COST: $ 31,501 CUM COST: $4,577,352 AFE AMT: $3,969,000 5021' CMT RET/ 8232' TD 91D 11/12/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 34 SEC TST THE U. BELUGA SDS (5059-5066') & (5073'- 5081'). SDS PRODUCED ONLY .0044 MMSCFD ~ 663 PSI ON SURF. FLUID LEVEL ROSE INSIDE 5" DP TO +3600' FROM AN ORIGINAL LEVEL OF 4970'. KI--LL WELL. RETRIEVE RBP & POH. RUN GAUGE RIG & OUNK BASKET TO 5100'. PU HOWCO EZ DRL BP & RIH ~ 2400 HRS. SET DRILLABLE BP ~ 5093' DIL. PU & RIH W/ CMT RET. SET SAME ~ 5021' DIL. SQZ U. BELUGA PERFS (5059-5066')(5073-5081') W/ 140 SXS CLASS "G", 1% CFR-2, 1% CACL2, .3% HALIDE 24) BELOW CMT RET ~ 5021' DIL. CIP ~ 0520 HRS, 11/10/84. SQZ OOB HELD 1650 PSI W/ PUMPS OFF AFTER 5 MIN. POH. TST BOPE. PU RTTS ON 3 1/2" DP & RIH. SET RTTS ~ 4971'. DISP DP W/ N2 (SURF PRESS = 2110 PSI, BHP = 2437 PSI). CLOSE BYPASS & OPEN WELL TO ATM. U. BELUGA SD (4987-4996') WOULD NOT PROD ANY FLUID OR GAS ~ 2400 HRS. DST U. BELUGA SD (4987-4996'). RIH W/ 2 1/8" 0° PHASE, 4 HPF TORNADO LINK GUNS & REPERFED F~ 4987-4996' AFTER REPRESSURING DRILL STEM W/ FIELD GAS TO A SURF PRESS OF 675 PSI. OPEN WELL TO ATM. SD PRODUCED .476 MMSCFD ~ 672 PSI SURF PRESS. RUNNING HR PRESS RECORDER FOR A BUILD UP ~ 2400 HRS. CONT DST U. BELUGA SD ('4987-4996'). RAN HP PRESS RECORDER ACROSS PERFS & SI FOR A BUILD UP. BHP ATER 9 HRS WAS 1172 PSI. POH W/ HP. KILL WELL. POH W/ DST TOOLS. RIH W/ 8 1/2" BIT. DRLG ON CMT RET ~ 5022' ~ 2400 HRS. DAILY COST: $ 27,806 CUM COST: $4,605,158 AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA . WELL RECORD SHEET D PAGE NO. 26 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5799' CMT JUNK/ 8232' TD 92 D 11/13/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 30 SEC DAILY COST: $ 30,770 CUM COST: $4,635,928 AFE AMT: $3,969,000 5101' CMT RET DPM/ 8232' TD 93 D 11/14/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 30 SEC DAILY COST: $ 38,100 CUM COST: $4,674,028 AFE AMT: $3,969,000 94 D 11/15/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 26,093 CUM COST: $4,700,121 AFE AMT: $3,969,000 5170' CMT RET DPM/ 8232' TD 95 D 11/16/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 30 SEC DAILY COST: $ 22,814 CUM COST: $4,722,935 AFE AMT: $3,969,000 DRLG RET F/ 5022 - 5024'. DRLG CMT F/5024 - 5104'. CIRC BTMS UP. POH. RIH W/ BUNDLE CARRIERS & SET TAIL OF CARRIERS ~ 5019'. DRY TST SqZD DST #14 INTERVAL - OK. REV OUT CUSHION & CIRC OUT GAS. POH. RIH W/ CO ASSY & DRILL ON BP F/ 5093 - 5094'. BP FELL FREE. WELL FLOWED - CIRC OUT FAS. CHASED BP TO 5799' CHASE DRILLABLE BP TO 5905' DPM. POH. RUN GAUGE & JB TO 5250'. RIH W/ DRILLABLE BP & SET SAME ® 5170' DIL. ROH W/ WL. RIH W/ CMT RET ON DR & SET RET 8 5lO1' DRM (5090' DIL). SqZ FOR ABANDONMENT THE UPPER BELUGA SANDS (5110-5135') & (5141 - 5161') W/ 161 SXS OF CMT BELOW RET. (CLASS "G" , 1% CFR-2, .3% HALIDE 22-A, 1% CaC12). FINAL PUMPING RATE OF .25 BBL/MIN ~ 3700 PSI. S~Z SOB HELD 2750 PSI W/ RUMPS OFF AFTER 2 MIN. CIR 8 1337 HRS. ROH W/ DR. RU & RIH W/ 8 1/2" BIT. CIRC & WOC $ 2400 HRS.5170' CMT RET DRM/ 8232' TD CONT TO WOC FOR 16 HRS. DRL CMT RET 8 5101' DPM. DRL CMT TO 5181' DPM POH. RIH W/ RTTS DRY TEST PERFS ~ 5110 - 5135' & 5141 - 5161' DIL. PERFS DRY TESTED, OK. BHP = + 200 PSI. POH. RIH W/ 8 1/2" BIT IN PREP TO DRL CMT RET 5181' DPM. CO~ RIH W/ 8 1/2" BIT. DRL RET @ 5181' DPM (5170' DIL). RIH. DRL RET ® 5970' DPM (5891' DIL). CO CMT TO 5950'. DRL RET 8 5990' DPM (5974' DIL). CO CMT TO 6033' DPM & RIH TO RET 8 6320' DPM. CIRC HOLE & POH. MU DRY TEST TOOLS ON 3 1/2" DP & RIH. SET RTTS @ 5916' DPM (5900' DIL). OPENED AUX VALVE & DRY TSTD M. BELUGA PERFS (5994 - 6003')(5914 - 5924'). INITIAL BHP = 218.5 PSI. FINAL BHP = 218.5 PSI. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 27 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5170' CMT RET DPM/ 8232' TD 96 D 11/17/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC MU & RIH W/ 8 1/2" BIT. DRL RET ~ 6320' DPM. CO CMT TO 6364'. DRL RET ~ 6366' DPM. CO CMT TO 6421'. CIRC & POH. TESTED BORE. DAILY COST: $ 21,605 CUM COST: $4,744,540 AFE AMI: $3,969,000 5170' CMT RET DPM/ 8232' TD 97 D 11/18/84 13 3/8" C. 2500' ~ 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 27,435 CUM COST: $4,771,975 AFE AMT: $3,969,000 COMPT'D BORE TEST. RIH W/ DRY TEST TOOLS. SET RTTS ~ 6360' DPM (6344' DIL) DRY TST M. BELUGA PERFS (6370-6376'), OK. INITAIL BHP = 223 PSI. FINAL BHP = 223 PSI. POH W/ TEST TOOLS. PU & RIH W/ 8 1/2" BIT. DRL RET ® 6421' DPM (6406' DIL). CO CMT TO 6476' DPM. TAGGED RET ~ 6479' DPM (6464' DIL). CIRC & POH. RIH W/ DRY TEST TOOLS. ATTEMPTED TO SET RTTS ~ 6415' DPM W/O SUCCESS. PULLED UP HOLE TO 6360' & SET RTTS. DRY TEST M. BELUGA PERFS (6424-36'). NOTE: DUE TO RTTS SETTING ~ 6360' THE M. BELUGA PERFS (6370 - 76') WILL BE RETESTED. OPENED AUX VALVE ® 2300 HRS. 6479' CMT RET DPM/ 8232' TD 99 D 11/20/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 30,107 CUM COST: $4,848,460 AFE AMT: $3,969,000 6550' CMT RET DIL/ 8232' TD 100 D 11/21/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 44,078 CUM COST: $4,892,538 AFE AMT: $3,969,000 DRY TESTED M. BELUGA PERFS (6324-6330') & (6370- 6376'). PULLED RTTS LOOSE & RESET ~ 6344' DIL. DRY TESTED PERFS (6370-637g') FOR 1.5 HRS. POH. INITIAL BHP = 162.5 PSI. FINAL BHP = 162.5 ON BOTH DRY TESTS PERFORMED. ATTEMPTED TO LAND DUAL TBG HANGER W/O SUCCESS. PU 8 1/2" BIT & RIH. DRLD RET ~ 6432'. CHASED TO 6479'. DRL ON RET ® 6479' ~ 2400 HRS. FINISHED DRG RET ~ 6479-80' DPM/ 6463-64' DIL & CMT F/ 6482-6550' DPM/ 6466-6534' DIL. WASHED DOWN TO RET ~ 6566' DPM/ 6550' DIL & POH, REPLACED WORN DP RUBBERS. RIH W/ HOWCO RECORDERS, RTTS, BYPASS, HYDROSPRING, & PUMP OUT SUB ON 3 1/2" DP FOR DRY TEST #7. SET RTTS ~ 6501' DPM/ 6485' DIL W/ TAIL TO 6514' DPM/ 6498' DIL. OPENED M. BELUGA PERFS 6500-6515' DIL TO 1 1/2 HR TEST - HAD MODERATELY STRONG BLOW ENTIRE TEST, BUT NO WATER WAS UNLOADED. SI TEST, FILLED DP & PRESSURED UP FOR BREAKDOWN/ LEAK-OFF TO 1200 PSI. BLED TO 1050 PSI IN 3 MIN. MUD VOLUME TO FILL DP INDICATED A 600' FLUID RISE. UNSET RTTS & DROPPED DOWN TO TAG RET ~ 6563' (3' HIGH). PRESSURED UP TO SHEAR PUMP OUT SUB 1350 PSI & REVERSED OUT. SAW A MAX OF 7400 UNITS OF GAS. POH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD · LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 SHEET D PAGE NO. 28 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6550' CMT RET DIL/ 8232' TD 101 'D 11/22/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 30 SEC DAILY COST: $ 21,711 CUM COST: $4,914,249 AFE AMT: $3,969,000 6440' CMT RET DIL/ 8232' TD 102 D 11/23/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 29,187 CUM COST: $4,943,436 AFE AMT: $3,969,000 6550' CMT RET DIL/ 8232' TD 103 D 11/24/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 33,117 CUM COST: $4,876,553 AFE AMT: $3,969,000 SET CMT RET ~ 6495' DPM/ 6479' DIL. SQZ CMTD 140 SX (CLASS "G" 1% CACL2, .3% HALAD 24, 1% CFR-2) BELOW CMT RET. FINAL PUMPING RATE OF 1 BPM ® 2800 PSI. SQZ SOB HELD 1250 PSI W/ PUMPS OFF AFTER 2 MIN. CIP 8 0208 HRS. POH. POH. WOC & CLEAN & REDOPE 3 1/2" DP. RIH W/ 8 1/2" BIT. DLRD UP CMT RET ~ 6479'. DRLD SOFT CMT TO 6560'. FELL THRU TO NEXT RET ® 6563'. CIRC & POH. RIH W/ HOWCO RECORDERS, RTTS & AUX VALVE ON 3 1/2" DP FOR DRY TEST #8 (RETEST OF #7), FILLING 1ST 5 STANDS W/ H20 CUSHION, REMAINDER DRY. SET RTTS ~ 6493' DPM/ 6477' DIL W/ TAIL TO 6506' DPM/ 6490' DIL. ROTATED TO OPEN AUX VALVE & OPEN M. BELUGA PERFS 6500-6515' TO 1/2 HR. TEST-MODERATELY STRONG BLOW ENTIRE TEST, NO WATER UNLOADED. SI TEST & FILLED DP - VOLUME INDICATED A 442' FLUID RISE. UNSET PKR & REVERSED OUT (UP TO 7500 UNIT OF GAS, AS IN PREVIOUS DRY TEST). DROPPED BELOW PERFS & CONT REV OUT. POH. (BTM RECORDER: IH=3338 PSI, IF=350 PSI, FF=404 PSI, FH=3656 PSI; TOP RECORDER: IH=3197 PSI, IF=342 PSI, FF=389 PSI, FH 3204 PSI.) RIH W/ HOWCO EZSV RET ON 5" DP & SET @ 6492' DPM/ 6476' DIL. SQZD CMTD W/ 161 SX (CLASS "G", 1% CACL2, 1% CFR-2, .3% HALAD 24) BELOW CMT RET. FINAL PUMPING RATE OF 1/4 BRM ~ 3050 PSI. SQZ OOB HELD 2350 PSI W/ RUMPS OFF AFTER 5 MIN. CIR ® 1615 HRS. RIH W/ BIT #40 & WOC UNTIL 0400 HRS (APPROX 12 HRS). TAGGED CMT $ 6456' DPM & DRLD SOFT CMT 6463' DRM. WOC AN ADDITIONAL 4 HRS. DRLD FIRM CMT 6463' TO RET $ 6492' DRM/ 6476' DIL. DRLD UR RET & CO FIRM CMT 6495-6559' DRM & FELL THRU TO 6563' DRM/ 6547' DIL. CIRC BTMS UR (MAX 250 UNITS GAS) & ROH. RIH W/ HOWCO RECORDERS, RTTS & AUX VALVE ON 3 1/2" DR FOR DRY TEST #9 (2ND RETEST OF #7), FILLING 1ST 5 STANDS W/ H20 CUSHION, REMAINDER DRY. SET RTTS ® 6494' DRM/ 6478' DIL W/ TAIL TO 6507' DPM/ 6491' DIL. ROTATED TO OPEN AUX VALVE & OPEN M. BELUGA PERFS 6500-6515' DIL FOR 1 HR 50 MIN TEST. MODERATELY STRONG BLOW ENTIRE TEST, NO H20 UNLOADED. SI TEST & FILLED DP - VOLUME INDICATED A 3500' FLUID RISE. UNSET PKR & REVERSED OUT. DROPPED BELOW PERFS & CONT REV OUT. HOWCO CHART RECORDERS FROM DRY TEST #9: BTM TOP RECORDER RECORDER DEPTH 6510' DPM 6506' DPM IH 3178.4 PSI 3213.4 PSI IF 334.4 PSI 358.4 PSI IF 1444.4 PSI 1459.7 PSI FH 3178.4 PSI 3213.4 PSI UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 29 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6550' CMT RET DIL/ 8232' TD 104 D 11/25/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 27,784 CUM COST: $5,004,337 AFE AMT: $3,969,000 6550' CMT RET DIL/ 8232' TD 105 D 11/26/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 35,545 CUM COST: $5,039,882 AFE AMT: $3,969,000 6477' CMT RET OIL/ 8232' TD 106 D 11/27/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 21,831 CUM COST: $5,061,713 AFE AMT: $3,969,000 CONT REV OUT F/ DRY TEST #9, SEEING MAX OF 4900 UNITS OF GAS. POH. RIH & SET EZSV RET ON 5" DP ~ 6503' DPM/ 6487' DIL. TESTED LINES & SURF EQUIP TO 5000 PSI. PRESSURED TO 5000 PSI BELOW RET ATTEMPTING BREAKDOWN - HELD STEADY, NO DROP IN PRESS IN 20 MIN. BLED BACK IN ATTEMPT TO CLEAR POSSIBLY PLUGGED TOOL & REPRESSURED TO 5000 PSI - STILL NO BREAKDOWN. POH W/ STINGER. RIH W/ BIT #41 ON 5" DP & DRLD UP RET $ 6503' DPM & CO 7' OF SUNK 6556-6563'. CIRC BTMS UP & POH (SAW MAX OF 120 UNITS OF GAS). RIH W/ HOWCO RECORDERS, RTTS, & AUX VALVE ON 3 1/2" DP FOR DRY TEST #10 (3RD RETEST OF #7), FILLING 1ST 5 STANDS W/ H20 CUSHION, REMAINDER DRY. SET RTTS ~ 6494' DPM/ 6478' DIL W/ TAIL TO 6507' DPM/ 6491' DIL. LOADED DP W/ 820 PSI FILED GAS CUSHION. ROTATED TO OPEN AUX VALVE. BEGAN BLEEDING OFF GAS CUSHION THRU CHOKE ON FLOOR MAINIFOLD. NOTICED ANNULUS LEVEL DROPPING INDICATING THAT RTTS OR BYPASS WAS LEAKING. LOST 17 BBLS IN ANNULUS IN 1 HR 40 MIN. CIRC & POH W/ TST TOOLS. RIH W/ NEW RTTS, AUX VALVE & RECORDERS. SET RTTS $ 6464' DIL (6480' DPM). DRY TST M. BELUGA PERFS (6500'- 6515') W/O SUCCESS. DOWNHOLE TOOLS LEAKING AGAIN. CIRC WELL DEAD. OBTAIN BREAKDOWN ON M. BELUGA PERFS (6500-6515') OF 1.75 BPM @ 3000 PSI. POH W/ TST TOOLS. RIH W/ HOWCO EZSV CMT RET ON 5" DP. FOUND FAULTY BYPASS VALVE WHICH CAUSED LEAK IN TST TOOLS. SET RET ~ 6493' DPM/ 6477' DIL & SQZD M. BELUGA PERFS 6500-6515' DIL W/ 180 SX CMT BELOW RET. FINAL PUMPING RATE OF 1.5 BPM ~ 3150 PSI. SQZ OOB HELD 2650 PSI W/ PUMPS OFF AFTER 3 MIN. CIP ~ 0229 HRS. CMT SLURRY: (CLASS "G", 10% SILICA SAND, 1% CACL2, 1 CFR-2, .3% HALAD-24). PU 45' & REV OUT THRU CHOKE UNTIL MUD NO LONGER GAS CUT. POH & WOC 7 HRS. RIH W/ BIT #42, TAGGING CMT ~ 6458' DPM. CO FIRM CMT TO 6482' DPM & CIRC BTMS UP. WOC AN ADDITIONAL 3 HRS. POH. TESTED BOPE & ASSOCIATED EQUIP: HYDRIL TO 2500 PSI, REMAINDER TO 5000 PSI. UNION OIL COHPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 30 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6550' CMT RET DIL/ 8232' TD 107 D 11/28/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC DAILY COST: $ 23,679 CUM COST: $5,085,392 AFE AMT: $3,969,000 CO F/ 6482-6493' DPM. DRL CMT RET ~ 6493' DPM (6477' DIL). CO HARD CMT TO 6558' DPM. WASH TO 6563' DPM. CIRC & POH. RIH W/ TEST TOOLS & SET RTTS ~ 6501' DPM (6485' DIL). PUT 700 PSI GAS CUSHION ON DP. OPEN AUX VALVE $ 1600 HRS. DRY TESTED M. BELUGA PERFS (6500-6515'). HAD A HARD BLOW FOR 1 HR 50 MIN. FILLED DP W/ 75 PCF FLUID. CIRC & POH. PRESS BOMBS: (IF=414 PSI, FF=445 PSI) (IH=3178 PSI, FH=3178 PSI). LD TEST TOOLS. 7600' CMT RET DIL/ 7620' DPM 108 D 11/29/84 13 3/8" C. 2500' 9 5/8" C. 8232' 75 PCF 29 SEC LB TEST TOOLS. RIH W/ 8 1/2" BIT & CO TO 7495' DPM (7475' DIL). TRIP FOR BIT. RIH & CO TO 7620' DPM (7600' DIL) ~ 2400 HRS. DAILY COST: $ 27,548 CUM COST: $5,112,940 AFE AMT: $3,969,000 8063' DPM CMT RET/ 8232' TD 109 D 11/30/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 28 SEC CO CMT & CMT RET'S TO 8063' DPM. CIRC GAS OUT OF WELLBORE. PU & RIH W/ 9 5/8" CSG SCRAPER. DAILY. COST: $ 30,994 CUM COST: $5,143,934 AFE AMT: $3,969,000 8063' DPM CMT RET/ 8232' TD 110 D 12/01/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 28 SEC RIH W/ 9 5/8" CSG SCRAPER. CIRC BTMS UP. CLEANED SURF MUD SYSTEM. CIRC OUT GAS CMT FLUID. DAILY COST: $ 22,535 CUM COST: $5,166,469 AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 31 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 111 D 12/02/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 28 SEC DAILY COST: $ 50,157 CUM COST: $5,216,626 AFL AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 112 D 12/03/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF 28 SEC DAILY COST: $ 37,807 CUM COST: $5,254,433 AFL AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 113 D 12/04/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF FINISHED CLEANING SURF MUD SYSTEM. TRANSFERED NEW 76 PCF KCL & CACL2 F/ STORAGE TO ACTIVATE SYSTEM, CHANGED HOLE OVER W/ VISCOUS PILL FOLLOWED BY CLEAN FLUID. POH W/ BIT & SCRAPER. RIH W/ GAUGE RING TO 8030' DIL. POH. RIH W/ HOWCO E-Z DRILL BRIDGE PLUG & SET SAME ~ 8020' DIL (BASE OF GRAVEL PACK). POH W/ WL. MU 9 5/8" BAKER WASH TOOL & RIH W/ 2 STANDS. WELL BEGAN BLOWING EXCESSIVE AMOUNTS OF FLUID & GAS. POH. RIH OPEN ENDED & CIRC WELLBORE CLEAR OF GAS. POH. PU & RIH W/ WASH TOOL~ COULD NOT GET WASH TOOL INTO BTM PERFS (7989-8004'). CAME UP HOLE & WASHED U. TYONEK PERFS (7936-7950')(7916- 7932')(7642-7668') W/ +150 GPM. INITIAL PUMPING PRESSURES WERE AS HIGH AS 2400 PSI & FINAL PRESSURES WERE AS LOW AS 800 PSI. POH W/ WASH TOOL. LAY DOWN 5" DP. RIH W/ 3 1/2" DP OPEN ENDED IN PREPARATION TO FILTER COMPLETION FLUID PRIOR TO GRAVEL PACKING. DAILY COST: $ 23,927 CUM COST: $5,278,360 AFL AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 114 D 12/05/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF FILTERED ENTIRE SYSTEM THRU 10 MICRON FILTERS. REFILTERED ENTIRE SYSTEM THRU 2-5 MICRON FILTERS. POH. RIH W/ 3 1/2" SSWW. DAILY COST: $ 21,691 CUM COST: $5,300,051 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 115 D 12/06/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 35,000 CUM COST: $5,335,051 AFL AMT: $3,969,000 MU & RIH W/ 3 1/2" WIRE WRAPPED SCREEN & BTM HOLE GRAVEL PACK ASSY. SPACE OUT & SET 9 5/8" GRAVEL RACK PACKER 8 7823' DIL. GRAVEL RACK THE FOLLOWING U. TYONEK SDS (7916-7932')(7936-7950'), & (7989-8004') W/ 98 SXS OF 40-60 SD. DID NOT GET SD OUT. REV CIRC & POH W/ GRAVEL PACK TOOLS ON 3 1/2" DP. RU & RUN DENSITY LOG. LOG SHOWED GOOD PACK F/ BTM - 7882'. POH W/ WL. PREP TO REPACK U. TYONEK SDS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 32 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 116 D 12/07/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF DAILY COST: $ 50,102 CUM COST: $5,385,153 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 117 D 12/08/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 42,062 CUM COST: $5,427,215 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 118 D 12/09/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 28,466 CUM COST: $5,455,681 AFE AMT: $3,969,000 RIH W/ 3 1/2" DP OPEN ENDED TO 7820' DPM. CIRC GAS OUT OF WELLBORE. POH. RIH W/ OTIS GRAVEL PACKING TOOLS. STABBED INTO GP PACKER ~ 7823' DIL & REPACKED THE U. TYONEK W/ 3 BBLS VISCOUS PRE-PAD, 7 BBLS OF 10 PPG W/ (20 SX) GRAVEL SLURRY OF (40-60) OTTAWA SD, FOLLOWED BY 3 BBLS OF VISCOUS POST-PAD. DISPLACED W/ 39 BBLS OF COMP FLUID ~ 3.25 BBLS/MIN ~ 800 PSI. SLOWED RUMPS TO i BBL/ MIN & PUMPED AN ADDITIONAL ll BBLS OF COMP FLUID (50 BBL TOTAL) ~ (200-275) PSI. GIR ~ 1715 HRS. CLOSED TOOL. RU & REVERSED OUT. FOUND SMALL AMOUNTS OF SD IN RETURNS. CIRC THE LONG WAY & FILTER COMP FLUID THRU l0 MICRON FILTERS. CONT FILTERING THRU 10 MICRON FILTERS 1.6 SYSTEM VOLUMES UNTIL FILTERS LASTING A REASONABLY LONG TIME. POH W/ GRAVEL PACK TOOLS. PU & RIH W/ 244' (7 JTS) OF 1 1/4" CS HYDRIL TBG TAIL. TAGGED 65' OF FILL INSIDE 3 1/2" SSWW SCREEN @ 7954' DIL & CO TO BTM OF SCREEN ~ 8019' DIL. CONT REV OUT UNTIL ALL RETURNS SD FREE. PULLED UP TO ABOVE PKR & CIRC LONG WAY W/ NO SIGN OF GAS. POH & LD 1 1/4" TAIL. RIH W/ OTIS MULE SHOE COLLET LOCATOR & PROD SEAL UNIT ON 3 1/2" DP. SNAPPED INTO PKR TO LOCATE, THEN PU 2' ABOVE PKR TOP. RU LINES & FLOOR MANIFOLD. TSTD LINES TO 5000 PSI W/ N2. DISP FLUID OUT OF DP W/ N2. SI HEAD PIN & STABBED INTO PKR W/ SURF PRESS AT 3040 PSI OPEN WELL TO FLARE LINE THRU CHOKE ON FLOOR MANIFOLD. SLOWLY BLED OFF WELL TO 1950 PSI IN 18 MIN, THEN OPENED UP CHOKE IN ATTEMPT TO UNLOAD RATHOLE FLUID. BLED TO ATMOSPHERIC PRESS 30 MIN INTO TEST AT WHICH TIME 1ST GAS DETECTED IN RETURNS. AT 41 MIN INTO TEST, SI FOR BUILDUP. BY 1 HR, 42 MIN INTO TST HAD BUILT PRESS TO +700 PSI & PUT INTO SYSTEM FOR RATE. BY MIDNITE RATE 8 0.43 MMCFD & BUILDING SLOWLY. LEFT WELL ON TST FOR TOTAL OF 15 HRS. STARTED BLEEDING BACK WELL DURING LAST 12 HRS OF TST. FINAL STABILIZED PRESS OF 1760 PSI W/ 0.33 MMCFD RATE. KILL WELL THRU CHOKE. FILTERED SYSTEM THRU l0 MICRON FILTERS WHILE CIRC. ONCE ALL GAS CIRC OUT OF HOLE, RELEASED BACKRRESS ON 'ANNULUS & CONT CIRC & FILTERING, SWITCHING TO 2 - 5 MICRON FILTERS. ROH W/ OTIS SEAL UNIT. RRER TO RUN DENSITY LOG INSIDE GRAVEL RACK. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 33 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 119 D 12/10/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 125,006 CUM COST: $5,580,687 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 120 D 12/11/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 48,952 CUM COST: $5,629,639 AFE AMT: $3,969,000 FINISHED POH W/ OTIS SEAL UNIT. RU GEARHART & RAN GR/CCL LOG TO REEVALUATE L. GRAVEL-RACK. LOG SHOWED TOP OF GRAVEL TO BE 8 7858' (40' ABOVE TOP OF SCREEN, 24' HIGHER THAN PREVIOUS LOG RUN BEFORE REPACK & TEST). DID NOT TAG ANY FILL, RD GEARHART. MU & RIH W/ OTIS "GR" ISOLATION RKR & 40TS OF 3 1/2" BLANK TBG W/ OTIS 2 7/8" "X" NIPPLE i ST BELOW ISOLATION RKR. SPOTTED RKR FLUID (6% KCL - CACL2 BRINE TREATED W/ 10 BBLS OF NALCO 3900) BETWEEN BTM "GP" PKR & ISOLATION PKR. STABBED INTO BTM "GP" PKR & SET ISOLATION PKR ~ 7689' DIL. POH W/ PKR RUNNING TOOLS. MU & RIH W/ U. GRAVEL PACK ASSY. STABBED INTO ISOLATION PKR. SWAPPED OUT OF IOLATION PKR TO CONFIRM LOCATE, THEN RESTABBED INTO IT SET UPPER "GP' PKR ~ 7689' DIL. CLOSED HEAD PIN & TSTD LINES TO 5000 PSI. OPENED HEAD PIN & PUMPED 3 BBLS VISCOUS PREPAD AHEAD, FOLLOWED BY 13 1/2 BBLS OF 10 PPG (39 SX) GRAVEL SLURRY OF 40-60 OTTAWA, & 3 BBLS VISCOUS AFTERRAD. DISPLACED W/ 43 3/4 BBLS COMP FLUID. PUMPED ALL BUT LAST l0 3/4 BBLS OF DISR ® 3 BRM, THEN SLOWED RUMPS TO i 3/4 BRM ~ 400 PSI. BY 42 BBLS DISR PRESS WAS VARYING BETWEEN 1200-1700 PSI & TRYING TO SAND-OUT. CRAWLED IN LAST BBL ® 2700 PSI ACHIEVED SAND-OUT ® 2700 PSI W/ 43 3/4 BBLS DISPL PUMPED (NOT INCL AFTERRAD). SI RUMPS, PRESS 8LED TO 1800 PSI VERY SLOWLY (ARRROX 4 MIN). BLED OFF REMAINING PRESS, RU TO EXPOSE PORTS ABOVE PKR, & REV OUT. (GIP ~ 2315 HRS.) EST LESS THEN 5 SX GRAVEL REV OUT. CONT REV UNTIL CLEANED UR (1 1/2 DR VOLS). WAIT ON GRAVEL RACK TO SETTLE. WAITED 3 HRS FOR BREAKER TO REACT & SD TO SETTLE. (ROH llO' WHILE WAITING TO CLEAR 2 3/8" TAILRIRE OUT OF RKR). RIH & STABBED INTO RKR. FILLED LINES, PRESS TSTD LINES TO 5000# THEN PUMPED INTO PACK TO TEST IT: COULD ONLY PUMP ~ 1BPM ~ 2300 PSI. SHUT DOWN PUMPS, PRESS BLED SLOWLY TO 450 PSI IN 30 SEC. TST INDICATIVE OF A GOOD PACK. POH & LD GRAVEL PACK TOOLS ® 2 3/8" TAILPIPE. RU GEARHART & RAN GR/CCL LOG TO EVALUATE GRAVEL-PACK. LOG SHOWED U. ZONE PACKED FULL TO TOP OF BLANK. RIH W/ OE 3 1/2" DP, CIRC BTMS UP TO CLEAR GAS & POH LD DP. CHANGED U. RAMS TO DUAL 2 7/8" X 3 1/2". RU TO RUN TBG. BEGIN RUNNING 2 7/8". UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 34 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 121D 12/12/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF DAILY COST: $ 22,407 CUM COST: $5,652,046 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 122 D 12/13/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 49,211 CUM COST: $5,701,257 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 123 D 12/14/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF CONT RUNNING 2 7/8" LS TO SPACE OUT CARBIDE BLAST JTS ACROSS THE BELUGA SDS. WITH ALL BLAST JTS RUN, POH & STOOD 8ACK IN DERRICK. RIH W/ A 9 5/8" RETRIEVABLE 8RIDGE PLUG ON 3 1/2" DP IN PREPARATION TO ISOLATE THE GRAVEL PACKS FROM PERFORATING DEBRIS. RIH & SET RBP $ 7408' DPM. CIRC. SPOT 4 SX OF SD ON TOP OF RBP. POH. REPERF THE FOLLOWING BELUGA SDS W/ 4 HPF, 120° PHASING 4" CSG GUNS. DIL CBL 4987-4996' DIL 5343-5366' DIL 5401-5416' DIL 6580-6602' DIL 6956-6962' DIL 7320-7330' DIL 4976-4985' 5333-5356' 5391-5406' 6575-6597' 6951-6957' 7318-7328' PU BAKER BP RETRIEVING TOOL & RIH. CIRC GAS F/ WELLBORE. PREP TO RETRIEVE BP. RETRIEVE BP & POH. LD 3 1/2" DP. RIH W/ DUAL COMP ASSY (3 1/2"-SS, 2 7/8"-LS). CIRC GAS OUT OF WELLBORE $ 2400 HRS. DAILY COST: $ 39,549 CUM COST: $5,740,806 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 124 D 12/15/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF CIRC GAS F/ WELLBORE. RUN DUAL COMP ASSY. STAB LS INTO TOP GR RKR ~ 7600'. TST, OK. SPACE OUT. RU TBG HANGERS & LANDING STS 8 2400 HRS. DAILY COST: $ 21,369 CUM COST: $5,762,175 AFE AMT: $3,969,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 35 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 125 D 12/16/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 93,875 CUM COST: $5,856,050 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 126 D 12/17/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 PCF DAILY COST: $ 269,820 CUM COST: $6,125,870 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 127 D 12/18/84 13 3/8" C. 2500' 9 5/8" C. 8232' LAND DUAL COMP ASSY W/ 10,000 LBf WT ON TOP OF GP PKR ® 7600'. SET BPV IN LS. R/U OTIS LUBRICATOR ON SS & RIH W/ PLUG. SET PLUG IN XN BELOW DUAL PKR. SET DUAL HYD PKR ® 1700 PSI. TST BACK SIDE OF DUAL PKR TO 300 PSI. OK. R/D OTIS LUB. SET BPV IN SS. CHANGE OUT RAMS. NIPPLE DOWN BOPE. N/U DUAL 3 1/2" TREE & TST TO 5000 PSI, OK. PULL BPV'S IN LS & SS ~ 2400 HRS. DISPLACE PKR FLUID INTO ANNULUS. PUMP N2 DOWN SS, TAKING FLUID RETURNS UP LS. BELUGA FORMATION TAKING N2 GAS. RIG UP ON LS & DISPLACE SAME W/ N2 TO "XA" ® 7504'. INITIAL PRESS IN LS BUILT TO 950 PSI. INITIAL RATE OF THE SS WAS 2.03 MMSCFD & INCREASING. RIG UP TO FLOW BOTH STRINGS. LS PRODUCED .31 MMCFD ® 700 PSI SURF PRESS INITIALLY & THEN INCREASED TO .7 MMCFD. RIH & OPEN XA SLEEVE IN LS ® 7504'. POH W/ WL. PREP TO RU COILED TBG UNIT TO LIFT FLUID OUT OF WELLBORE. DAILY COST: $ 22,336 CUM COST: $6,148,206 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 128 D 12/19/84 13 3/8" C. 2500' 9 5/8" C. 8232' DAILY COST: $ 44,655 CUM COST: $6,192,861 AFE AMT: $3,969,000 RU COILED TBG UNIT OVER LS. RIH TO 7504' WLM. CIRCULATED N2 DOWN COILED TBG & UR 2 7/8" X i 1/4" ANNULUS. NOT GETTING ANY LIQUID RETURNS. POH W/ COILED TBG. RU & RIH W/ SHIFTING TOOL TO 7504' WLM. CLOSE "XA" SLEEVE. ROH. CHANGE SHIFTING TOOL & RIH TO 7504'. OPEN "XA" SLEEVE ~ 7504'. PRESSURE DIFFERENTIAL BETWEEN LS & SS BLEW SHIFTING TOOL UR HOLE. TOOL STUCK ® +7442' WLM. DISPLACE 7 BBLS DIESEL & 5 GAL OF OIL ACROSS FISH ~ 7442' W/ N2. WORK WL W/O SUCCESS. RU TO CUT WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD . LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 SHEET D PAGE NO. 36 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 129 D 12/20/84 13 3/8" C. 2500' 9 5/8" C. 8232' DAILY COST: $ 90,967 CUM COST: $6,283,828 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 130 D 12/21/84 13 3/8" C. 2500' 9 5/8" C. 8232' 76 RCF (KILL FLUID) DAILY COST: $ 30,605 CUM COST: $6,314,433 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 131 D 12/22/84 13 3/8" C. 2500' 9 5/8" C. 8232' DAILY COST: $ 62,976 CUM COST: $6,377,409 AFE AMT: $3,969,000 RU TO CUT WL. CLOSED OTIS BORE - BORE NOT HOLDING. PACKED OFF W/ GREASE. DROPPED GO-DEVIL. PACKED OFF BORE W/ GREASE. ATTEMPT TO DROP CUTTER. CUTTER HUNG UP BY BROKEN WL STRANDS IN LUB. CLOSED IN SS. FLOWED LS TO PIT W/ 500 PSI BACK PRESSURE. MIXED 458 BBLS OF 76 PCF FLUID (6% KCL W/ CACL & CACO3 PILL). RU BO & BULLHEADED 227 BBLS DN LS. SI LS. SITP = 500 PSI. CIRC OUT GAS IN SS THRU CHOKE. CONT CIRC DN LS TAKING RETURNS FROM SS. SHUT-IN FOR 1 HR - WELL DEAD. PULLED OTIS LUB. PULLED WL - FISH CAME FREE. POH W/ WL & RECD RUNNING TOOL. RECOVERED 1/4" BRAIDED WL & SHIFTING TOOL. RU MYER'S WL & "XA" SHIFTING TOOL. RIH TO CONFIRM THAT "XA" SLEEVES 8 4814' & 4889' WERE CLOSED, OK. POH W/ WL. RU ARTIC COILED TBG & B.O. N2 ON LS. RIH TO 7520' TBG MEAS W/ 1 1/4" COILED TBG. UNLOAD BOTH LS & SS W/ N2 ("XA" ~ 7504' IN LS OPEN). RIH W/ COILED TBG TO 7890' TBG MEAS. PUMPED OFF CACO3 FILL TO 7900' TBG MEAS. FILL WOULD NOT PUMP OFF ~ 7900'. FINISHED POH W/ COILED TBG. PU 1 3/4" DYNA DRILL & 1 7/8" FISH TAIL~BIT ON COILED TBG. RIH. CO CACO3 BRIDGE ®__+7900' TBG MEAS. RIH TO TD 8 8018' TBG MEAS. UNLOAD FLUID F/ WELLBORE. POH W/ COILED TBG. RU MYER'S WL & RIH. SHIFTED "XA" SLEEVE 8 7504' TBG MEAS CLOSED. ROH W/ WL. RIG ON STAND-BY ~ 2100 HRS,12/22/84 FOR EXTENDED FLOW TESTING. INITIAL PROD TEST: STABLE RATE SS 4.99 MMSCFD 8 700 PSI ~ SURF LS .70 MMSCFD ~ 1800 PSI 8 SURF SS = 5.2 MMCE/D LS = 0.75 MMCF/D UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 37 LEASE KENAI TYONEK UNIT A-028142 WELL NO. KTU 13-5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8020' DIL CMT RET/ 8232' TD 140 D 12/23-30/84 9 DAYS 13 3/8" C. 2500' 9 5/8" C. 8232' WELL ON EXTENDED FLOW TEST. SS PRODUCTION: 5.2 MMCF/D FOR 168 HRS LS PRODUCTION: 0.75 MMCF/D FOR 144 HRS DAILY COST: $ 62,976 CUM COST: $6,377,409 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 144 D 12/31/84-01/03/85 4 DAYS 13 3/8" C. 2500' 9 5/8" C. 8232' WELL ON EXTENDED FLOW TEST. SS PRODUCTION: 6.4 MMCF/D FOR 72 HRS LS PRODUCTION: 0.75 MMCF/D FOR 96 HRS DAILY COST: $ 62,976 CUM COST: $6,377,409 AFE AMT: $3,969,000 8020' DIL CMT RET/ 8232' TD 145 D 01/04/85 13 3/8" C. 2500' 9 5/8" C. 8232' DEMOB RIG TO KBU 23X-6. DAILY COST: $ 62,976 CUM COST: $6,377,409 AFE AMT: $3,969,000 _,N OIL COMPArqY E)F (]AI....IFORN]I'A UNIP' .. WEI_I_ RECORD S H E'. E'/" D F::' A G E N 6.) ,, 20" DR I V E F::' I F::'E .. ' .... ":R T .. Llii[ 1",1(3"1" H B 0 T T 0 M T (] F::' J '1" S J.) E.::) ._, R I F' i 0 N 0 D X I D 4 "20" 93 d: ( ,, 4. 38" W A L.. L... ) 136. (") 0 136, ('.~(') 0. C) 0 6 2 13 3/8" CASilqG DEl'AIL. b":';.'.. W .1. 3 3/" R"u) B .... U T T F L 0 A"f' S H 0 E :1.;5 3/8" 6.1.:~ N-SC, BLJTT CASING B&W !:]; 3/8" BUTT FL..OA"I" COL. L. AR 13 3/8" 61-'1~: N-80 BUTT CASING CIW 13 3/8" SOW X 12" 30()0¢1: CSG I...IIEAD LANDED BEL. OW KB (KB 'fO RT) :L. ,';:3 .1. 250 o. 0 C) 24- 98. 19 "::~:~ :31 2498 19 2458 88 · ,~1 In # ~ · "'3 r::' 1:7 .1. :':":4 '~r .1. 0() 9c:~ 6 6 29.66 29.66 0 ,, ,:") 0 80 9 5 / 8" C ¢../S I 1',.t(3 D IEi;T A I L. B;~.~W 9 5/8" Br..ITT FL. OAT SHOE 9 5 / 8" 47'I:1: N- 80 B t..JT T CAS I I",IG G B&W 9 5/8" BU"FT FI_OA"F C6.}LL_AR 9 5/8" 47d: r.,I.--80 BUTT CASING HAL. L... I BURTON CMT Ir',lG DV 9 5/8" 47¢1:N-80 Bt..JTT CASING C I t.'.,.J 9 3/' c:t'"'" 3000 ¢I: X 11" 500 C,:I:t: D C B S P 00 L. L...Ar'-.IDE;D BELOW KB (KB TO RT) .1.. 66 827.;2, 0(') 82:::.!;0, 3-'.'.I 83., 34 82 :f. 0, :34 81./.17'. 0 () :t,, ....~'=' ,..~ '= 814 '7. ,:"). ("~.8 .1./'1. ....,'::"' .4 :::; .... ":r'"., 16.8 9 8 .1. 4 5 4.':=, Zl. 9 2,..,c:) ,..,6'=' ._l .~:. # .... '1 · 7.;. 2'7 4928.46 4-925 ,, 29 · q. 895.63 4925.29 29.66 RE,r'F VED Alaska Oll& b~s Ou.s. I~ommlsslon Anchorage LJN l ON (3 ii .... COMPANYt..,-'~r,-' CAI.. iI::'[3F<I',II A WELL. R'. E CX] F~'. D LEASE: A-(}28 :i. 42 WELL l',Ir2 ,,: I<TiJ .1. 3-5 F I ELD: KIEI'qA :1: GAS F: I I.:.:./...D c:.. r-, LONG ....,Tr,, NG TUB II'..IG DETAIl... ].1 D E S E: R i F'T I 0 F..I 0 ir.)X i C' S E A L A S.'E; Y I I',-I "i" 0 P G F' F:'I--':: I:.1'. SEA/_ ASSY~-:.ur,:~_ ........ 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"'~ (") '"' ":-' 0 .._~, 10 20 ;I-,:"~. 9..". ,:: .... ",,..~ ........ 246.93 2 () ::.5 .':5 . 8 :3 1 '788.90 '"'" 0 4 ,1. '788, 9 (") .1. '7 ,El :::";, ,.8 ,_5 ]. -"4. 8, '71 ]. 785.86 1635. 15 5.08 16":"'::' ]. 5 .-.,j. 16:];Q. (')7 WELL_ RECORD D E: E; C:: I::-"-.' i F:' T ]: FZ~ l"--J DD X tO · ':_:'-" *':" '" ' ~:~ S S Y i J'"-.l i'3 f'l'l" ",r' 0 M G F:' I:::: i'::: F;.: :, E. I'"i ~ ~':'J l:.:.: (-'% [.~ '/::'~S(~3Y "-"='Fi~nz' i:"i'q''r''r'r~''''~ "F~L;(~ pL.-iq, t-l&.., ,., '~ i._ _, .... I I ~,,.~1 t , I'-.l , TBE'i (:'d)&F'TEF;.'. :3 1/2" I.'ZU E':×,.".l-"EI.J F'II"'-.I .7'; 1 / .--:, ,,.... c? ,2:1:t: i"-.i- :q .... (':,'"--." i T-r 'T'B G 'i'SG F-'~DF:fi::'T :2 7/i::l" BUT'T' F'X.3 1/2" BLI'I-'I" ") "7 / C) ~ ! =',' I ' -r ,."z. i:::, i'-' ........ ~:,,..JT, -, ...... 1_ Ci_I:"::(:'fi:;:'~iNCFZ COUF'I._. T r"l .... S ..... " ,.... 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N G T H B O'T' T (")M "[' 0 P BR ;[ I:)F4~:-T._,,... F:'i.._L.iG B! t[ I PLUG '.'z '~ /":'" EU BOX ' ~-4F'"~"."'"'~'O,,...,,,.,,...,,...,.. SMITH SCREEN- , ,:-:, ,..-:, ,c:, , , ...... GAUGE '""5" m 3 1/2" let_! F' W/ 8..,::.. ._ I-'IOWP~RD SidiTH ,-- ;'-- .u,, _r= r_ ',.. ,, .~-"....- I ,,,i=0 F".i ".i .... HOWARD o,'tlTH,~ ,., ,'-',: ~ ~ t"-., -c'" '-"-" "- '-" ~ HOWARD SMi'TH Ri-:.,-,r=.~.lq " ...... '~ v'-- ,L-7. ~'. t! HOWARD SMITH HOWARD. SM I TH ._., :.., ,::: ""' c' ~= ~ ;'"~-.,_,.._, T B G ¢~_.~ ~.F ~ 3 ~, / .."":'" B U T ff' ~::= ..'>-'." ...... :3 1 / 2 P- U F' 3 i "-"" 3 i..,:='""" c.:,,, :5'24+ ,,,~"L'-c"'-;,..,,_. BUT"i- "l"F.:r=~ .... TBG ADAF'"F 5" !_TC BX.3 1/2': BUTT F' OT ]: S c:.Lm :~ SHEAR c-i ~',.=,-,:--. -' !=i" ._ ................... ~ 2 _ F' i S HNECi.-':: EI'T' :[ :iS; 9 5/8" GF:' [:'KR 2 0.2 0 8 0.1. 7.7 7 7 9 9 7.5 7 2 (). 21 '7 9 9 7.5'? 7 9 7 7.3 6 .....2'."),, 22 '7c"'7'7, , 36 '79'=-`.,,..., / J..4 '~) i") :"; '"" .... ¢ ......... " ......... · : ...= / -/,'::., 7, 1..4 7 9.'_', 6.9.:.2 2." (). "2:5 ..7... c,, -'z...._, ,..,/'- ,, 5:' 2 .... / c;,, :[ 6 · 6 '7 ,:":, 8 2 "'-; '""...:, :L ' 6 7 ~':' . ,=,. '791..._~. 8 5 7;0 ";' ''?' '7'::" ...... . , , · ? 15 ,, ',=:.¢5 7885, (";,8 :];(.) ,, 38 7885,08 785Zl.. 7() ,:'::, ,, 8 :::='; '78 5.'::1-. '70 7 8 .753 ,, 8 7 :L. 4 5 '78 5 3 ,, 13'7 7 8 5 2. q- 2 1 ;'~...., 9 37 8332 ,, 4 2 "'~,,..8 .,.'.t, :/ , 4 9 Alaska Oil d~ b~,~ ~,5, 6ommission Anchorage WELL KTU' 13-5 ' CASING & ABANDONMENT DETAIL II .... ~ ~ I I.) Rotary Table Measurement at 0.00~ i ' II.) CIW Dual Tubing Hanger at 25.90' i III.) 20", 93~, 0.438' Wall Casing at 136' Iii ; IV.) 13 3/8', 61~, N-80 Casing at 2500' i~ V.) Cement Retainer Bridge Plug at 8039' ' ~ VI.) 9 5/8", 47~,, N-80 Casing at 8232' .~' - TUBING DETAIL ^ x_..Z_~ 'x.._~.A 2 LONG STRING: 2 7/8 , 6.4~, N'80 .TUBING 1.) 3 1/2" x 2 7/8' Crossover at 26.68' 3 I4 2.) Otis 'XA" Sleeve at 4814.42' B~C i~ 51~I 3.) 2 7/8" X 3 1/2' Crossover at 4848.88' ~ i! 4.)'Otis' Dual Hydraulic Packer from 4850.02' to 4856.68' DlXN} ~.~ 7 5.) Mandrel Extension at 4856.68' == ' I~ 8 6.) 3 1/2' x 2 7/8' Crossover at 4858.10' UPPER 7.) Otis 'XA' Sleeve at 4889.38' BELUGA -~-~ ! [ 9 8.) Carbide Blast Joint from 4991.73' to 5014.73' ZONE ~= i I' O- 9.) Carbide Blast Joint from 5347.45' to 5384.45' 10.) Carbide Blast Joint from 5407.09' to 5436.09' LOWER "" 11.) Cad3ide Blast Joint from 6589.72' to 6625.72' BELUGA ~- I~ -12.) Carbide Blast Joint from 6967.37° to 6987.37' 13.) Carbide Blast Joint from 7332.71' to 7356.71' ZONEJ=== I, 3 14.) Otis 'XA' Sleeve at 7504.12' ~ 4 15.) Otis 9 G.P. Packer 5/8' with Seal Assembly -kom 7599.60' to 7610.51° . --~~'--~:,S' 16.) Otis 9 5/8' G.P. Packer with Seal Assembly ======================================================~.~ -~ :::::::::::::::::::::::: ,, ~ UPPER ~ ~8.) Otis 9 5/8' G.P. Packer with Seal Assembly ................... ~ from 7840.73' to 7853.31~ A.) Otis 'XA' Sleeve at 4783.35' B.) Otis Dual Hydraulic Packer {rom 4850.02' to 4856.68' C.) Mandrel Extension at 4846.68' X---" I 7 D.) Otis 'XN' Nipple at 4870.86' PERFORATION RECORD -- DA TE INTERVAL CONDITION TYONEK ~i:i~i!i~!~?iii~i!i~?~!~!~L :i:~:~:~:~ 10/07/84 7989'-8004' Upper Tyonek Sd. Open Prod. ::::::2:::: ...... 10/18/84 7642'-7668' Upper Tyonek Sd. Open Prod.. ===================================- :.:.:.:.:.:.: 10/23/84 6956'-6962' Lower Beluga Sd. Open Prod. ZONE _~.:.:.:.:.:.:.:.:.:.:.:.:.-:-:-:.:-----.:.:.:.:.:.:. 10/25/84 7320'-7330' Lower Beluga Sd. Open Prod. ::::::::::::::::::::::::::::::::::: ~-::::::::::::: 10/27/~4. 6580'-6602' Lower Beluga Sd. Open Prod. -'-'-'-'-'-'"-"'.'-'-'-'-'-'-'-'-', .11/05/84 5401'-5416' Upper Beluga Sd. Open Prod. ~ 11/05/84 4987'-4'996' Upper Beluga Sd. Open Prod. V NOTE: See Sheet 2 for Top Gravel Pack, Isolation Packer, and Bottom Gravel Pack Assembly Detail REV. [. ~,AT[ DRAWN ~H ~ CKI3. · ~ ,- SCALE NONE D~T[ 1/22/85 t WELL SCHEMATIC t UNION OIL coMpANY OF CALIFORNIA ! ;. ,NCHORAGE, ALASKA ' SNF.[T$ i S.[[T Io¢ 2. WELL KTU 13-5 ' 7707.27 7706.80 7705.68 · 7685.47 7643.69 7611.99 7610.51 7599.60 Top 7841.49 7840.73 7839.92 7751.47 7750.13 7748.86 7717.91 7716.40 771g.66 7707.27 Bottem 7717.27 7707.27 7706.80 7705.68 7644.50 7612.83 7611.99 7610.51 Bottom 7853.31 7841.49 7840.73 7752.03 7750.76 7749.42 7718.72 7717.91 7716.40 7712.66 Top Gravel Pack Assembly Lngth Description 10.00 .47 1.12 20.21 .81 .84 1.48 10.91 Seal Assy. in Isolation Pkr Seal Assy. above Isolation Pkr "0" Ring Sub Howard Smith Screen - .008" guage Tubing Adapter '.,. Tubing Adapter \ Otis Swivel Shear Sub ~ Otis 9-5/8" GP Pkr ~ \ Isolation Pkr Assembly Lngth Description 11.82 .76 .81 .56 .63 .56 .81 1.51 3.74 5.39 Seal Assy. in Bottom GP Pkr Seal Assy. above bottom GP Pkr Tubing Adapter Tubing Adapter Otis 2-7/8" 'X' nipple Tubing Adapter Tubing Adapter Otis Swivel Shear Sub Extension Below GP Pkr Otis 9-5/8" GP Pkr Top 8038.50 8037.99 8017.77 7915.85 7853.87 7852.42 7841.49 Bottom 8038.50 8037.99 7916.67 7854.07 7853.87 7852.42 Bottom Gravel Pack Assembly Lngth Description .51 20.22 .82 .83 1.45 10.93 Bridge Plug Bull Plug 3-1/2" bu box Howard Smith Screen - .008" Guage Tubing Adapter Tubing Adapter Otis Swivel Shear Sub Otis 9-5/8" GP Rkr REV. OAT[ ! WELL KTU 13-5 UNION OIL COMPANY OF CALIFORNIA ANCHORAGE , ALASKA OnAW. I~HE CKO. ~ APP'D. ~CALF SHEETS j SHEET2 of 2 I0" ~5ooo~ MILCHEM INCC3RPORATED / P. O. BOX 22111 / HOUSTON, TEXAS 77027 This space is for your convenience when using the Supplementary Data form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. Contractor BRIN~OFF F RILLING OPERATOR UNION OIL CO. OF CALIFORNIA MUD R CAP LEGAL API# 50-133-20370 DESCRIPTION SEC 7,T4N, RllW, SM Anchorage Rig No. 54 06-023 Milchem Well No. 09969 Well Name And No. KTU 13-5 Field KENAI GAS FIE~ COUNTY KENAI STATE AK Milchem Spud TOTAL . Warehouse KENA_I Date 08-15-84 No. Drilling DATE T.D ....... TOTAL 8232 Days To T.Q 16 REACHEDU~-J'L-~z~ DEPTH COST $ 426393 16 CASING PROGRAM Depth (ft) Size (in) 2500 13-3/8 8232 9-5/8 DATE 8-12 2200 TIME I DEPTH I{ft) BITS TYPE MUD SYSTEM SOLIDS CONTROL EQUIPMENT ADDITIONAL, INFORMATION No. Size (in) Type Depth Interval (ft) Type Depth Interval (ft) 1-3 17-1/2 4-12 12-1/4 GEL-BENEX (SPUD) 0-2500 GEL-BENEX NON-DISP. - 2500-8232 12-45 8-1/2 PLASTIC YIELD GELS VISCOSITY POINT (lb/100ft2) cp @ I °F (Ib/10Oft2) 0/10 pH APl FUNNEL [ VISCOSITY WT t (se_c/q t)__ (PPg) / AP~ °F BRANDTSHAKEES 0-8232 PICATEER DESANDER 0-4500 PIONRRR DESILTER 0-8232 PICNEERM[3DCLEANER600-8232 b-A~CO~GE 280028232- PumpSpecifications (2) GDPZ9 .066 BBL/ST 19.5#-- HWD.P. FILTRATE i Alkilinity ]Chloride(ppm) (ml/30min) iCakel Pf/Mf t HT-HP OF [ (3in~ Pm Calcium (ppm) Sand (% by Vol.) D.P. and D.C. Other Oil (% by Vol.) 65+ 72 62 11 100 Solids (% by Vol.) 8"&. 6-1/4" D.C. 24/32 8.5 NC Water MethY.Blue (% byl (me/mi Vol.) mud) 2 .20' 5/.9 150 40 NIL 3 97 26.0 Circ. I Volume REMARKS (bbl) 850 MIX SPUD ;~3D 25 B-13 2030 65+ 45 66 12 100 29 26/32 9.0 NC 2 .7 .6/1.3 150 TR NIL 3 97 26.0 -'850 RIG UP 8-14 2000 65+ 115 72 11 100 49 26/36 9.0 NC 2 .7 .6/1.2 150 TR NIL 3 97 26.0 850 RIG UP 3-15 2100 468 66+ 110 70 10 100 25 15/31 9.5 15.2 2 .4 .,3/.9 300 TR 1/2 4 96 20.0 807 SPUD 08-15-84 3-16 1900 1200 66+ 96 68 11 100 33 24/32 9.5 15.6 2 .4 .3/.9~ 250 TR 1/2 4 96 18.75 1391 DRTTZ, 3-17 1730 1787 67+ 102 69 14 100 38 26/35 9.5 16.2 2 ,.25 .2/.5 250 TR 1/3 5 95 25.0 1418 DRTTZ, 3-18 1100 2500 69+ 91' 60 13 100 29 18/30 9.5 14.9 2 .3 .2/.4 250 20 3/4 6 94 22.5 1454 TDSURFACE @ 2500 3-19 1430 2500 66+ 40 63 7 100 13 3-20 1730 2500 66+ 38 64 7 100 8 ]_,2/13 12.0 NC ' 5/11 12.0 NC . 6.3 3.5/4.1 850 TR 1/3 4 96 15.0 1280 CM~SURFACE 5.4 3.0/4.5 800 40 1/4 4 96 15.0 1120 NIPPLE UP 3-21 1700 2500 65+ 35 61 7 100 11 8-22 2200 2510 65+ 44 68 10 100 15 8/9 12,0 NC ' 5.4 2.9./3.5 400 60 1/4 4 96 ]3.75 16/18 11.0 13.8 27.0 200 2 1.4 1.2/1.7 400 20 TR +3 97 22.0 899 NIPPLE UP 769 DRTT/.O~-DISPI_ACE 9-23 1700 2510 65+ 43 66 12 100 12 8/14 11.0 13.6 29.4 200 2 1.3 1.2/1.6 250 20 NIL 4 96 20.0 1009 RF_~QUEEZE CM~ 8-24 1400 3457 67 44 82 8 100 19 20/28 11.0 10.6 26.0 200 2 1.4 1.3/1.6 350 TR 1/4 6 94 23.0 1231 DRILL AHE 8-25 1600 4830 68 53 94 16 100 15 6/18 10.0 7.8 18.8 200 2 .6 .5/.8 300 20 1/2 7 93 25.0 1183 DRILL~ 8-26 2200 5755 71 49 96 20 100 16 4/19 11.0 8.0 18.2 200 2 .9 .7/1.2 300 20 1/4 8 92 28.0 1430 DRILL AHF_AD 8-27 2330 6447 72 48 98 ~22 100 15 4/15 11.0 7.8 17.0 200 2 .8 .7/1.0 300 20 1/8 +9 91 22.0 1489 DRTT~,AHEAD Milchem 2-2 q-;g4 ~-~.~.:~, ~ .......... :,,~ THRAPP/O'MAT,T.R¥-~FvFg/O~TFgRW~ This space is for your convenience when using the Drilling Mud ,~ecap form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. ' F1RILLING MILCHEM INCORPORATED/P.O. BOX 22111/HOUSTON, TEXAS 77027 Contractor B~]~-[OFF OPERATOR MUFI REECA API# 50-133-20370 LEGAL DESCRiPTiON SEC 7,T4N,RllW, SM Well Name Rig No. 54 And No, [C~.] 13-5 Field ~ ~ FT~,~ COUNTY ~ STATE VISCOSITY VISCOSITY Sand Solids Oil Water Blue Volume REMARKS DATE TIME DEPTH WT I (sec/clt) i(lb/100ft2) Chloride Calcium (% by (% by (% by (% by (me/mi (ft) (ppg) cP @ OF HT-HP Pm PT Vol.) Vol.) Vol.) Vol.) mud) I o,,o %5 )8-28 2300 7114 73 49 100 20 100 15 5/16 10.5 7.6 16.6 200 2 .9 .8/1.4 300 20 1/4 10+ 90 25.0 1490 DRILL AHEAD TO 7; ) )8-29 2330 7768 73 57 100 16 100 21 7/9 10.5 7.8 16.2 200 2 1.0 .9/1.6 300 TR 1/4 11 89 22.0 1651 DRLG )8-30 2300 8108 75+ 54 98 23 100 29 5/11 10.5 7.2 16.2 200 2 .9 .8/1.4 400 TR 1/4 13 87 26.25 1597 WGTUP-DRILL 38-31 2300 8232 75+ 59 100 22 100 31 4/9 10.5 6.2 15.0 200 2 .8 .7/1.5 350 TR 1/8 13 87 23.75 1712 DRILL TOTD @ 8232 39-01 2300 8232 75+ 55 88 20 100 29 4/9 10.5 6.2 15.2 200 2 .7 .6/1.2 350 TR 1/8 13 87 22.5 1775 ~ING 39-02 2300 8232 75+ 59 92 21 100 31 39-03 2230 8232 76- 54 66 21 100 26 8/14 10.5 7.0 16.2 200 2 .7 .6/1.5 400 TR 1/8 13 6/10 10.5 7.2 15.8 200 2 .7 .6/1.2 350 TR 1/8 13 87 23.75 87 22.5 1617 LOG-CT.~.AN OUT 1551 RUN 9-5/8 CSG 39-04 2300 8232 72+ 34 69 10 100 4 1/3 10.0 12.2 28.0 200 2 .4 .3/.5 300 20 TR 10 90 15.0 857 CMTCSG 39-05 2200 8232 72+ 34 74 10 100 5 2/3 10.0 12.2 27.4 200 2 .4 .3/.5 300 20 TR 10 90 15.0 858 NIPPLE UP-DRILL D.V. 39-06 2000 8135 72+ 32 62 10 100 3 1/1 11.0 13.0 27.6 200 2 1.2 1.4/1.8 900 20 TR 10 90 15.0 838 SCRAPER RUN-LOG 39-07 2330 8135 72+ 32 64 9 100 3 1/1 11.0 13.2 28.4 200 2 1.2 1.1/1.6 900 20 TR 10 90 15.0 937 SET RETAINER 39-08 2100 8135 72+ 32 64 9 100 3 1/1 11.0 13.2 28.4 200 2 1.2 1.1/1.6 900 20 TR 10 90 15.0 865 PERF & TEST ZONE ~9-09 1700 8135 75+ 34 86 10 100 5 2/3 11.0 14.5 29.6 200 2 1.5 1.4/1.8 800 20 TR 12 88 17.0 921 WGTUP SYSTEM )9-10 2100 8170 75+ 33 84 10 100 4 2/2 11.0 14.6 29.0 200 2 1.6 1.5/1.8 800 20 TR 12+ 88 17.0 39-11 2300 8170 76+ 33 80 8 100 4 2/2 11.5 17.2 33.8 200 2 1.0 .7/.8 900 20 1/8 13 87 17.5 979 DRILL RETAINER 979 RAISE MUD ~"T )__ 39-12 2300 8170 76+ 34 73 8 100 4 2/4 11.5 17.0 36.6 200 2 1.2 1.0/1.3 900 20 1/8 14 86 17.5 1057 TEST 39-13 2300 8170 76+ 34 74 9 100 7 4/10 11.5 16.8 38.2 200 2 1.4 1.0/1.4 800 40 1/8 13 39-14 2300 7960 76+ 34 74 9 100 6 4/10 11.5 19.0 41.4 200 2 2.6 1.2/1.4 850 20 1/8 13 87 18.75 979 TEST, SQUEEZE 87 17.5 1044 TEST 39-15 2300 7664 76+ 34 83 9 100 7 4/10 11.5 18.6 2 2.5 .9/1.25800 20 1/8 13 87 18.75 1060 TEST 39-16 2300 7664 76+ 34 77 10 100 6 4/10 11.5 20.2 2 2.8 .9/1~2 75,0 20 1/8 13 87 17.5 1075 TEST 39-17 2300 7664 76+ 35 81 10 100 6 4/11 11.0 21.6 2 2.8 .9/1.3 650 20 1/8 14 86 16.0 1042 TEST 39-18 2300 6527 76+ 36 80 9 100 8 5/14 11.0 20.8 2 2.6 .85/1.2 650 20 1/8 13 87 17.5 859 TEST, SQUEEZE 09-19 2300 7491 76+ 36 78 9 100 8 4/14 11.0 21.4 2 2.1 .8/1.2 700 40 1/8 13 87 17.0 915 Dl~rrI. OUT EZ DRILL 09-20 2200 '6484 76+ 37 78 10 100 7 4/17 11.0 22.2 2 1.9 .7/1.1 650 20 1/8 13 87 17.0 833 SQUEEZE 09-21 2200 5039 76+ 36 80 10 100 7 4/15 11.0 22.0 2 1.8 .7/1.1 650 20 1/8 13 87 17.0 612 SQUEa~ZE 09-22 2200 4946 76+ 36 78 9 100 10 6/20 11.0 22.6 2 1.9 .8/1.3 650 TR 1/8 13 87 17.0 653 DRILL OUT Milchem Date 12-23-84 Technical Representative TSD- (")MR ¢,'))- 1/7] THRAPP/P'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 2 OF 6 This space is for your convenience when using the Drilling Mud Recap form in conjunction with the "form holder." DO HOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MILCHEM INCORPORATED/P.O. BOX 22111/HOUSTON, TEXAS 77027 Contractor BR_INKERHOFF nRil LING MUD REC.A.P UNION OIL CO. OF CALIFORNIA LEGAL OPE RATOR DESC R I PTI ON API# 50-133-20370 SEC 7 ,T4N,RllW,SM Rig No. 54 Well Name And No. KTU 13-5 Field KEN,AZ GAS FIE~ COUNTY ~ .STATE AK ., FUNNEL PLASTIC YIELD GELS I FILTRATE Alkalinity t Mett~y. j Circ. Sand 5olid$ Oil Water Blue Volume REMARKS ~)ATE TIME DEPTH WT VISCOSITY VISCOSITY (mi/30 rain) Cake Chloride Calcium (% by (% by (% by (% by (me/mi (ft) (ppg) (sec/qt) POINT (lb/100ft2) pH (32nd Pm Pf Mf (bbl) (1984) ~l~ OF cp (D j OF (Ib/10Oft2) 0/10 HT-HP OF I (ppm) (ppm) Vol.) Vol.) Vol.) Vol.) mud) I AP, i.) KC1 09-23 2230 4707 76+ 36 78 9 100 9 8/17 11.5 23.2 2 3.6 1.7/2.0 700 40 1/8 13 87 17.0 662 DRILL OUT ) 09-24 2230 5007 76+ 35 80 9 100 9 7/16 11.5 29.2 2 4.2 3.1/3.3 1200 40 1/8 13 87 17.0 668 DRL OUT-TEST SQUEEZE 09-25 2300 5083 76+ 34 80 9 100 5 3/6 12.0 28.2 2 6.2 4.0/4.6 750 20 1/4 13 87 16.0 668 TEST DRILL CMT 09-26 2300 5083 76+ 33 79 6 100 6 3/9 12.0 27.4 2 7.8 3.0/3.6 650 40 1/4 13 87 15.0 668 TEST-PERFORATE 09-27 2300 5083 76 34 78 8 100 6 2/7 12.0 28.2 2 8.2 3.8/5.2 650 TR 1/4 13 87 15.0 705 SQUEEZE-DRILL 09-28 2215 4991 76+ 34 76 9 100 6 3/10 12.0 27.4 2 8.0 3.4/5.0 750 20 1/4 13 87 16.25 880 DRILL-SQUEEZE 09-29 2200 5028 76 33 77 09-30 2300 6083 76 34 80 9 100 6 3/7 12.0 28.4 2 8.8 4.2/5.6 850 40 1/4 13 87 13.75 8 100 8 5/14 12.0 29.2 2 9.8 4.7/5.7.1500 40 1/3 '13 8'7 .16.25 950 DRILL-SQUEEZE 995 DRILL RET & CM~ 10-01 2200 7310 76 35 90 9 100 10 10-02 2200 7497 76 34 98 8 98 11 10-03 2330 7683 76 34 103 6 103 11 7/14 12.0 31.0 6/13 12.0 32r6 11/17 12.0 33.2 2 11.4 4.6/5.6 1400 40 1/4 13 2 ]_i.9 4.6/5.8 1400 60 1/4 13 2 11.2 4.1/4.5 950 40 1/4 13 10-04 2230 8062 76+ 34 102 7 102 9 7/13 12.0 33.0. 10-05 2300 8062 76 CaC1/KC1 IN PRE-HY TANK 8.5 2 11.4 3.9/4.2 1100 60 1/4 13 194000 112000 1½ 87 15.0 1028 DRILL RET & CM~ 87 15.0 979 DRTT/, RET & C/V5' 87 15.0 1143 DRTTZ, BRIDGE PLUGS 87 15.0 · 1162 D1RTT,'r, & MILL PLUC~ 98½ 6% 280 CT,VAN PITS-START MIX 10-06 2200 8062 76 8.5 196000 115000 1½ 98½ 6% 1576 MIX & DISPLACE HOLE 10-07 2200 8064 76 8.5 193000 114000 1½ 98½ 6% 1245 PERF & TEST ZONE L 10-08 2230 8064 76 8.5 190000 112000 1½ 98½ 6% 1243 TRIP & TEST 10-09 2330 8064 76 8.5 188000 113000 1½ 98½ 6% 1220 TEST & CIRC 10-10 2300 8064 76 8.5 192000 112000 1½ 98½ 6% 1150 PERF-TEST 10-11 2300 8027 76 10-12 2300 8015 76 8.5 190000 111000 1½ 98½ 6% 8.5 192000 108000 1½ 98½ 6% 1099 TEST-CIRC 1110 TEST-MILL 10-13 2330 7975 76 5.8 186000 114000 1½ 98½ 6% 1096 ACIDIZE 10-14 2230 8064 76 10-15 2200 7983 76 10-16 2000 '7893 76 10-17 2100 7950 76 8.0 182000 116000 1½ 98~ 6% 910 TEST 188000 122000 iR 98~ 6% 909 TEST 186000 116000 1½ 98½ 6% 913 TEST 8.2 8.4 8.6 188000 114000 1½ 98½ 6% 858 POOH PERF & TEST 10-18 2300 7687 76 8.4 186000 112000 1½ 98½ 6% 919 TEST Date 12-23-84 TSD-- DMR (2) -- 1/71 Milchem Technical Representative THRAPP/O'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 3 OF 6 -..~ · This space is for your convenience when using the Drilling Mud Recap form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. r-)RILLING REC.A.P MILCHEM INCORPORATED / P. O. BOX 22111 / HOUSTON, TEXAS 77027 ~PT# 50-133-20370 Contractor BP~OFF OPERATOR UNION OIL OF CALIFORNIA DESCRIPTIoNLEGAL S~C 7,T4N, RllW, SM Alaska Rig No. 54 Well Name KTO 13-5 COUNTY KENAI And No. Field KENAI GAS FIELD STATE AK ' i J so,ids FUNNEL PLASTIC YIELD J GELS FILTRATE Alkalinity J J Methy. Circ. DATE TIME DEPTH WT VISCOSITY VISCOSITY POINT ( (ml/3Omin) Cake Chloride Calcium (% by (% by (% by;(% by (me/mi i (ft) (ppg) (sec/tit) [ J(I O/10 pH HT-HP / ( 984 APl@ OF J cp @ OF b/lOOft2) APl OF (,32ndin) Pm Pf Mf (ppm) (pDm) Vol.) Vol.) Vol.) Vol.) mud) KC1 (bbl) 10-19 2300 7750 76 8.6 186000 114000 1½ 98½ 6% 926 TEST ) 10-20 2300 7750 76 8.6 188000 114000 1½ 98½ 6% 935 TEST 10-21 2200 7488 76 10-22 2200 7606 76 8.4 188000 114000 1½ 98½ 6% 8.4 178000 111000 1½ 98½ 6% 891 TEST & KILL WFq, T,T, 863 POOH R_iH W/RETAINER 10-23 2200 6912 76 8.6 182000 112000 1½ 98½ 6% 887 SQUEEZE-TEST 10-24 2300 6912 76 8.6 188000 109000 1½ 98½ 6% 885 TEST 10-25 2330 6912 76 8.6 180000 116000 1½ 98½ 6% 885 TEST 10-26 2200 6900 76 8.6 184000 112000 1½ 98½ 6% 765 TEST 10-27 2330 6900 76 10-28 2200 6550 76 8.4 183000 114000 1½ 98½ 6% 8.6 188000 110000 1½ 98½ 6% 768 TEST ~r- I Jill 10-29 2230 6557 76 8.6 180000 118000 1½ 98½ 6% 798 TEST-KILLWRTI, 10-30 2200 6557 76 8.6 186000 112000 1½ 98½ 6% TEST 10-31 2200 6406 76 8.6 186000 114000 1½ 98½ 6% 796 SQUEEZE 11-01 2130 6266 76 8.6 182000 112000 1½ 98½ 6% '790 TEST 11-02 2300 6365 76 8.6 186000 112000 1½ 98½ 6% 752 TEST & SQUEEZE .~_ 11-03 2100 5862 76 8.6 186000 114000 1½ 98½ 6% 784 TEST & KILL WELL 11-04 2200 5907 76 8.6 186000 114000 1½ 98½ 6% 690 SQUEEZE 2 ZONES 11-05 2100 5907 75+ 34 8.5 152000 92000 1/8 3 97 6% 793 i~G UP S~S~OO3 11-06 2200 5387 75 36 8.5 150000 91000 1/8 3 97 6% 793 q~.qm 11-07 2200 5332 75+ 35 8.6 154000 94000 1/8 3 97 6% 11-08 2230 5055 75+ 35 8.7 158500 96000 1/8 3 97 6% 11-09 2200 5055 75+ 33 777 TEST & KILL W~T,T, 727 TEST & KILL WRT.T, 8.6 159500 92000 1/4 3 97 6% 737 TEST & KTTLWETI, 11-10 2200 4982 75+ 34 8.7 160000 92000 1/8 3 97 6% 798 TEST & SQUEEZE 11-11 2130 '4982 75+ 33 8.7 164000 97000 1/8 3 97 6% 778 TEST 11-12 2100 5032 75+ 34 8.5 166000 94000 1/8 3 97 6% 759 TEST-KILL WELL-DRILL 11-13 2130 5104 75+ 30 9.7 160000 96000 TR 2 98 6% 739 DRILL RETAINER-TEST Milchem Date 12-23-84 Technical Representative TSD-- DMR (2) -- 1/71 THRAPP/O'MALLEY-KEYES/0GLESBEE District Region ALASKA PAGE 4 OF 6_ This space is for your convenience when using the Drilling Mud Recap form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MILCHEM INCORPORATED/P.O. BOX 22111/HOUSTON, TEXAS 77027 Contractor OPERATOR DRILLING MUD RECAP LEGAL API~ 50-133-20370 UNION OIL OF CALIFORNIA DESCRIPTION S~C 7,T4N,RllW,SM Well Name Rig No. 54 And No. ~ 13-5 Field ]<ENA~ GAS FZ]~LD COUNTY [qgNAI STATE FUNNELI PLASTIC YIELD GELS FILTRATE Alkalinity DATE TIME DEPTH WI VISCOSITY VISCOSITY Methy. Circ. (lb/100ft2) (mi/30 min) t / Sand Vol.) j Oil Water Blue1 Volume · (ft) (ppg) (sec/qt) POINT 0/10 Cake Chloride Calcium (% by (% by (% by (% by (me/mi REMARKS (1984) APl@t OF J cp @ OF (ib/10Oft2) pH (32nd Pm Pf Mf (bbl) , J APl HT-HP OF in) (ppm) (ppm) Vol.) Vol.) Vol.) mud) KC1 11-14 2100 5101 75 30 9.8 155000 91000 TR 2 gR 6% 688 SQUEEZE/W.O.C. .'~_ 11-15 2200 5181 75 29 10.4 149000 88000 1/8 2+ 98 6% 794 DRL ~-TEST 11-16 2200 6238 75 30 11-17 2200 6421 75 29 11-18 2200 6479 75 29 10.5 148000 87000 1/8 3 97 6% 10.5 148000 87000 TR 3 97 6% 10.5 145000 84000 TR 2+ 98- 6% 835 DRL RET/DRY TF~qT 829 DRILL RETAINERS 761 DRL RET/DRY TEST 11-19 2300 6432 75 30 10.8 142000 82000 TR 2+ 98- 6% 791 DRILL RETAINER 11-20 2300 6479 75 29 11-21 2300 6566 75 29 10.5 146000 83000 TR 2+ 98- 6% 781 DRILL RETAINT~R 10.5 146000 82000 TR 2+ 98- 6% 775 DRY TEST 11-22 2300 6500 75 29 11.0 146000 83000 TR 3 97 6% 765 SQL~EEZE 11-23 2300 6500 75 29 11.0 145000 85000 TR 3 97 6% 751 SQUEEZE 11.5 146000 84000 TR 3 97 6% 756 DRITI. RETAINF~ 11-24 2300 6500 75 29 11-25 2300 6566 75 29 11.0 145000 83000 TR 3 97 6% 740 DRY TKqT 11-26 2300 6566 75 29 10.8 146000 84000 TR 2+ 98- 6% 766 DRY TEST 11-27 2300 6480 75 29 11.0 145000 84000 TR 2+ 98- 6% 751 SQUEEZE 11-28 2300 6563 75 29 11.0 145000 83000 TR 2+ 98- 6% 787 DRLRET/DRY TEST .~_. 11.0 148000 83000 1/8 3+ 97- 6% 806 DRL CMT & RET 11-29 2330 7617 75 29 11-30 2030 8063 76 28 11.0 164000 88000 TR 3 97 6% 924 DRLRET 12-01 2330 8063 76 28 11.0 164000 85000 TR 3 97 6% 536 CT.WAN PITS 8.0 183000 88000 2+ 98- 6% '845 DISPLAL~HOLE 12-02 2200 8063 76 12-03 2200 8040 76 8.0 182000 84000 2+ 98- 6% 1078 WASH PERFS 12-04 2030 8040 76 8.0 182000 84000 2+ 98- 6% 1084 LAY DOWN 5" D.P. 12-05 2200 8040 76 8.0 182000 84000 1 99 6% 1083 POOH 8.0 182000 84000 1 99 6% 912 LOGGING 12-06 2200 7820 76 12-07 2200 .7820 76 8.0 182000 84000 1 99 6% 927 FILTER 12-08 2200 7820 76 8.0 182000 84000 1 99 6% 892 TESTING 12-09 2200 7820 76 8.0 182000 84000 1 99 6% 952 TRIP Milchem Date 12-23-84 Technical Representative TS[:) -- DMR (2) -- 1/71 THRAPP/O'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 5. OF 6 This space is for your convenience when using the Drilling Mud Recap form in conjunction with the "form holder.,' DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. ' nRILLING MILCHEM INCORPORATED/P.O, BOX 22111 /HOUSTON, TEXAS 77027 Contractor BRINKERHOFF OPERATOR UNION OIL OF CALIFORNIA MUn RECAP LEGAL DESCRIPTION API# 50-133-20370 SEC 7, T4N, RllW, SM Rig No. 54 Well Name KTU 13-5 COUNTY KENAZ STATE AK And No. Field KENAI GAS FI~Tr,D GELS' [ I [ Sand Solids Oil Water Blue Volume REMARKS ~' ~.,I~DATE TIME DEPTH WT VISCOSITYj VISCOSITY l(Ib/10Oft2) 0/10 (mi/30[ min) Cake// Chloride Calciumj(% bYJ(°,%Vol.)by (%Vol.)bY (%Vol.)by (me/mi mud) (bbl) (ft) (PPg) (sec/clt) POINT pH t(32nd Pm Pf Mf (ppm) (ppm) I Vol.) ,.9..~, ,a~DI L~ OF cp @ °F APl 1HT-HP °F in) I KC1 12-10 2200 7602 76 8.0 182000 84000 1 99 6% 896 GRAVEL PITS 12-112200 7602 76 7.0 182000 84000 1 99 6% 826 CHGRA~ 12-12 2200 4860 75 7.0 183000 84000 1+ 99- 6% 613 PREP TOPERFORATE 12-13 2230 7408 75+ 6.5 182000 82000 i+ 99- 6% 811 PERFORATE & CIRC. 12-14 2300 7408 75+ 6.5 186000 84000 2 98 6% 800 SET LOWERPACKER 12-15 2200 7580 75+ 6.5 186000 85000 2 98 6% 772 RUN DUAL STRING 12-16 2300 4871 75+ 6.5 186000 84000 2 98 6% 577 NIPPLE DOLON 12-17 2100 4871 P I T S E M P T Y DISPLACE W/PACKtKRFLUII 12-18 2100 4871 P I T S E M P T Y TEST W~IrI. /COIT.A-D TUB~G Date 12-23-84 TSD--DMR (2)- 1/71 Miichem Technical Representative THRAPP/0'MALLEY-KEYES/0GLESBEE District Region ALASKA PAGE_ 6' I OF 6 This space is ~or your convenience when using the Supplementary Dala form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MILCHEM INCORPORATED/P. O. BOX J;JJ 11 /HOUSTON, TEXA~ 770~'7 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 _DESCRIPTION SEC 7, T 4N, R llW, SM DATA MilChem Well No. 06-023-09969 Well Name And No. KTU 13-5 COUNTY KENAI STATE., ALASKA DATE DEPTH INFORMATION i i il i i i i i Illll J Jill I I 8-12 BEGIN MIXING SPUD MUD. PKEHYDRATING GEL. 8-13 CONTINUE TO RIG UP. 'HYDRATE GEL. ' ...... , 8-14 CONTINUE TO RIG UP. WAITING UNT%L JUST BEFORE SPUD TO MAKE BE~EX..ADDITIQN TO ALIGN TO REQUESTED . . PROPERTIES. ~ , 8-15 468 .BRING MUD UP TO SPECS AT 1:30 AM, FINISH RIGGING UP, NIPPLE UP BOP AND DIVERTER. PICK UP KELLY ETC., MAKE UP BIT, DRILL, CBU AND POOH AT 468' FOR DYNA-DRILL, MAKING UP DYNA-DRILL AT REPORT TIME, MUD IN GOOD SHAPE, CLEANING HOLE'WELL, NO PROBLEMS WITH EQUIPMENT. " 8-16 1200 FINISH MAKING UP DYNA-DRILL, ORIENT, RIH, DYNA-DRILL AND SURVEY TO 1200', POOH FOR ASSEMBLY CHAN~E, MUD SPECS .MAINTAINED THROUGHOUT DYNA-DRILL RUN. ALTERNATING USE OF DESILTER AND MUD CLEANER TO MAIN- TAIN WEIGHT AND VOLUME, BUILT SOME VOLUME TO PREPARE FOR NEXT RUN, ALL EQUIPMENT OPERABLE. , ~ 8-17 1787 RIH, DRILL FROM 1165' TO 1343' CIRCULATE, POOH FOR ASSEMBLY CHANGE, RIH AND DRILL 1343'-1499' POOH FOR ASSEMBLY CHANGE, DRILL TO 1787', MUD STAYING CONSISTENT~. DESANDER CENTRIFUGAL OUT BUT RUNNING DESANDER AND DESILTER OFF SAME PUMP WITHOUT PROBLEM TO THIS POINT. , 8-18 2500 RIH WITH NEW ASSEMBLY~ DRILL TO TD OF SURFACE CASING, SURVEY~ WIPER TRIP (HOLE IN GOOD SHAPE), CBU AND CONDITION MUD, POOH, RIG UP AND RUN CASING TO CALCULATED DEPTH. PREPARE TO CEMENT, REDUCED VOLUME WHILE CIRCULATING PRIOR TO COMING OUT, WILL THIN MUD BACK WHEN CIRCULATING CASING. 8-19 . 2500 RIH WITH STRINGER~ PICK UP 14 JOINTS~ RIG UP AND CIRCULATE CASING~ TEST LINES~ PUMP CEMENT~ ABORT CEMEN JOB AND PUMP CEMENT AROUND BACKSIDE AND TO RESERVE PIT, MUD BADLY CONTAMINATED AND CLABBERED, CIRCULATE AND CONDITION, RIG UP HOWCO, TEST AND CEMENT AGAIN, RIG DOk~. , 8-20 2500 RELEASE SLIPS ON 13-3/8 CASING~ NIPPLE DOWN 20", CUT 20" ETC, DO TOP JOB, GROUT CELLAR, INSPECT CROSS- . .. OVER SPOOL~.NIPPLE UP BOP~ WILL DRILL OUT WITH THIS MUD AND ATTEMPT TO DRILL AHEAD IF POSSIBLE. 8-21 2500 NIPPLING UP THROUGHOUT DAY, WORKING ON PITS, I.E. CHANGED SCREENS, WORKED ON PUMPS, CLEANED PITS, , FIXED RISER BETWEEN DESANDER AND DESILTER PITS, WORKING ON DRESSER SLEEVE PRESENTLY, HAVE BEEFED UP _ PREHYDRATED GEL TO 25 PPB IN TANK. _ 8-22 2510 DRILL OUT CEMENT~ TEST CASING~ DRILL TEN FEET HEW HOLE, CIRCULATE HOLE CLEAN, DUMP CONTAMINATED MUD, CONDITION MUD, DISPLACE HOLE, DO LEAK-OFF TEST, POOH. Mtlchem T--L.,..! ~ ....... ,~.,. THRAPP / O ' MALT,EY-KEYER/OCT.ESBEE .:. ,.~,..,,, AT,ASWA ','~7'"' :'i2: ~,. ~ ,i ,.'7-' ~J ,,,J~ This space is for your convenience when using the Supplementary Data form in conjunction wilh the "form holder. DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MILCHIrM INCORPORATE:D /L;). O, BOX 22] ] ] /HOUSTON~ TEXAS 7702~' OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 _DESCRIPTION, SEC 7~ T 4N~ R l lW~ S.M . , DATA Milchem 1¥ell No. 06-023-09969 Well Name And No. 'KTU 13-5 ,COUNTY KENAI STATE ALASKA i , , 11 i ii i 11 i i ii i i iii ii i i 11 , i i l DATE DEP TH INFO RMATION 8-23 251.0.. BAD LEAK-OFF. SET RETAINER AND SQUEEZE SHOE. REVERSE OUT. RIH. DRILT. OUT RETAINER. MODERATE CEMENT CONTAMINATION.. TEST CASING. DRILL OUT SHOE. LEAK-OFF TEST. , , 8-24 4309 LEAK-OFF TEST GOOD. RIH, DRILL AHEAD. END OF BIT RUN BEGAN OBSERVING PROGRESSIVE GELS. BEGAN TREAT- · , , MENT PRIOR TO BIT TRIP. ,, 8-25 4890 POOH, BIT CHANGE AND BHA CHANGE. CENTRIFUGE INOPERATIVE UNTIL 1300 HRS. BEGAN OPERATING TO REDUCE SOLIDS IN SYSTEM. '8-26 5755 BIT & BHA CHANGE, RIH, DRILL AHEAD TO 5755'. pOoH. GENERATOR FAILURE REQUIRED USING FEWER SOLIDS CONTROL. TO CONTROL PROPERTIES HIGHER UILUTION RATE AND INCREASED PRODUCT USAGE WAS NECESSARY. BIT RUN #7. 8-27 6447 DRILL AHEAD TO 64'47'. POOH. ONE STAND TIGHT (#8). SERVI'CE RIG, RIH. , 8-28 7114 DRILL AHEAD TO 7114'. POOH. AS PER REQUEST MUD WEIGHT RAISED TO 73 P.C.F. AS PER R~QOEST PV IS BEING! REDUCED. LIMITATIONS DUE TO POWER SHORTAGE - cOULD NOT RUN CENTRIFUGE DUE TO POWER SHORTAGE THUS MAKING PV REDUCTION A COSTLY DILUTION AND CHEMICAL ADDITION PROCESS. PV BEING REDUCED SLOWLY SO AS NOT TO SHOCK HOLE. 8-29 7768 IN COMPLIANCE WITH COMPANY REPS REQUEST A PROGRAM TO ALTER PV/YP RATIO WAS INSTITUTED. HEAVY DILUTION, DITMPING AND LARGE QUANTITIES OF CHEMICALS HAVE BEEN NECESSARY. BIT TRIP INTERRUPTED PROGRAM. 8-30 8108 RIH, DRILL 7764-8023', CIRCULATE OUT GAS, DRILL TO 8128', SURVEY. GAS STILL A PROBLEM SO WEIGHT UP , TO 75+ TO 76- POOH, MUD RHEOLOGY RESPONDING WELL TO WEIGHT UP, FLUID LOSS STAYING LOW, YP/PV NOT 1:5 DURING WEIGHT-UP TO KEEP RHEOLOGICAL CONTROL, WIL~ BUMP ~P RATIO wHEN BA'cK TO DRILLING. ,, , 8-31 8232 POOH, CHANGE BIT AND BHA, RIH WITH 25' FILL, DRILL 8108-8232' , CBU, WIPER TRIP, CBU, MUD READY FOR LOGS t NO PROBLEMS WITH EQUIPMENT. 9-01 8232 LOGGING THROUGHOUT DAY, WILL RECONDITION MUD PRIOR TO RECIRCULATION. , 9-02 8232 FINISH LOGGING~ RIG DOWN SOS, RIH WITH ONE FOOT OF FILL, CIRCULATE HOLE CLEAN, POOH. MUD IN Good SHAPE WITH ALL PARAMETERS IN ORDER. READY FOR CASING RUN, WILL REDUCE SURFACE VOLUME WHEN CIRCULATING CSG. 9-03 8232 RIG UP AND RUN 9-5/8" CASING (WELL RECEIVED), BREAK CIRCULATION, RECIPROCATE PIPE, WILL SLOWLY DROP YP BACK AS WE CIRCULATE, SEPIOLITE FLUS~ READY TO BE MIXED. Milchem T,....t.:.-.l ~, ........,.,~... TNRAPP/O'MAT,T,EY-KEYEg/OCT,EgBEE m:.,.~., AT,A,qKA .,.,.,, 2 .t This space is for your convenience when using lhe Supplementary Data form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE: UNTIL THI~ DATA IS CO),~PLF:TE. MILCHEM INCORPORATED I I). O. BOX 221111 HOUSTON, TEXAS 770Z7 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 DESCRIPTION_ SEC 7, T 4N' R llW, SM DATA Milchem Well No. 06-023-09969 Well Name And I'~o. KTU 13-5 COUNTY KENAI . : STATE... ALASKA DATE DEPTH INFORMATION , ii i i i i iii i lllll III I I · 9-04 8232 CEMENT 9-5/8 CASING, LIMITED RETURNS ON SECOND STAGE SO TOOK ON 200 BBLS OF ~T.~R TO HAVE ADEQUATE DISPLACEMENT VOLUME. MUD GOOD ENOUGH TO DRILL AND CLEAN OUT. WAITING ON NIPPLE UP AND TEST TO COMPLET BEF0~E ANY TREATMENT. ' , 9-05 8232 NIPPLE UP BOP, TEST. TEST PLUG STUCK" TEAR DOWN, NIPPLE UP AGAIN~ TEST STACK. 'RIH WITH 8~ BIT TO , DV AT 4925' DRILL DV TEST CASING TO 5000# RUN TO BOTTOM~ CIRCULATE, POOH 9-06 8232 PICK UP CASIN9 SCRAPER, RIH, CIRCULATE~ POOH~ RIG UP AND RUN OB~. 9-07 8135 SET RETAINER, PREPARE TO SQUEEZE~ WAITING ON ORDERS. . 9-08 8135. PERFORATE AND TEST ZONE. 9-09 8135 REVERSECIRCULATE THROUGH CHOKE. PULL 50 STANDS. WELL BEGAN TO YLOW. RT~. WEIGHT ~D ~TP TO 7~+ CIRCULATE UNTIL SYSTEM FREE OF GAS~ POOH. .. . · 9-10 8170 DRILL RETAINER AND CEMENT TO FLOAT POOH, CHANGE BIT RIH~ DRILL TO 8170' CIRCULATE AND POOH , , ' , ' ~ , , · 9-11 8170 LOG WITH SOS, PICK UP CASING SCRAPER ETC, RIH~ CIRCULATE HOLE CLEAN BUT GAS ELEVATED~ ~RCULATE AND RAISE MUD WEIGHT TO 76+ ELIMINATINC PROBLEM WITH GAS, PUMP PILL, POOH, TEST BOPS, FILTER CAKE IN GOOD SHAPE (FIRM AND PLIABLE), WILL VISCOSIFY MUD A BIT IF MORE WEIGHT IS NEEDED. 9-12 8170 RIH WITH RTTS~ DISPLACE WITH NITROGEN~ BLEED OFF, TEST~ MUD THINNING OUT.AT MIDDAY CHECK SO MIXED TEN · SACKS GEL TO BOLSTER SYSTEM AND GUNNED PITS TO PICK UP ANY LOOSE BAR, DEGASSER INOPERABLE AT THIS TIME, MECHANIC IS WORKING ON IT. , ,, 9-13 8170 CIRCULATE OUT GAS, SET E-Z DRILL AND SQUEEZE WITH 15.8 PPG CEMENT, REVERSE CIRCULATE OUT ..CEMENT TO RESERVE PIT~ POOH~ RIG UP G.O. FOR BRIDGE PLUG ETC.~ ADDED A LITTLE GEL TO RAISE YP~ NO CEMENT CON- J TAMINATION DURING S~UEEZE, DEGASSER OPERABLE. 9-14 7960 RIH WITH RTTS, DISPLACE WITH N?~ BLEED OFF DP~ TEST~ KILL WELL~ CIRCULATE OUT GAS~ PUMP PILL~ POOH~ UP G.O., WIRELINE, ADDED USUAL GEL TO SY~?~FLUID LOSS CREEPING UP AS POLYMERIC FILTRATE AGENTS (DRISPAC) PLAY OUT BUT IN CASED HOLE, EVERYTHING OK. 9-15 7664 SET E-Z DRILL AT 7664' PERFORATE~ PICK UP RTTS AND 3~" DP~ RIH~ DISPLACE WITH No ETC FLOW TEST --, -- ~ i , , ,,, · · 9-16 7664 KILL WELL~ CIRCULATE OUT GAS~ PERFORATE~ FLOW~ WIRELINE ETC. ADD BAR TO CONDITION MUD, OTHERWISE MUD STABLE· M~!chem ---- T,ch,ical Representative. THRAPP/O'MALLEY-KEYES/OGLESBEE District. ALASKA Page 3 of 10 This space is for your convenience when using Ihe Supplementary Data form in conjunction with the "form holder. DO NOT DI=TACH ALONG PF:RFORATF:D LINF: UNTIL. THi= DATA IS COMPL.F-TE. MII. CHEM INCORPORATED/P. O. BOX 2,~1Jl i HOUSTON, TEXAS 7702~' OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 _DESCRIPTION,,. SEC 7, T 4N, R llW, SM DATA Milchem , Well No.._ 06-023.-09969 W, ll Name And No. KTU 13-5 . COUNTY KENAI . STATE. ALASKA DATE DEPTH INFORMATION ii i i i ii i il J J i il i i J _ _1 __ 9-17 7664 KILL WELL., REVERSE CIRCULATE OUT GAS, POOH, SET E-~ DRILL EARLY, RIH WITH BIT. CHASE E-Z DRILL TO ..~ BOTTOM, CBU, POOH, RIG UP G.O., WIRELINE. .. ,, 9-18 6527 SET E-Z DRILL, RIG UP TO CEMENT, SQUEEZE WITH 15.6 PPG CEMENT, REVERSE OUT, CBU, POOH, TEST BOPS, SET E-Z DRILL, PERFORATE, PREPARE TO FLOW TEST, BUILT 65 BBLS OF. NEW MUD TO SUPPLEMENT SYSTEM. EVERYTHING .- INGOOD S~'APE. " ' ' ,, 9-19 7491 TEST WITH RTTS AT 6494'. KILL WELL, REVERSE OUT, POOH, RIH WITH BIT #17, DRILL OUT E-Z DRILL AT 6542'. CHASE TO'7491'. CLEAN OUT TO 7492'. PooH. '" 9-20 6484 SQUEEZE 7313 -.7345'. REVERSE OUT, POOH. SET E-Z DRILL AT 6532', RIH AND SET E-Z DRILL AT 6484~. SQUEEZE ZONEz REVERSE OUT~ POOH. 9-21 5039 SET BRIDGE PLUG AT 6143' PERF 6116 - 6118' SET E-Z DRILL AT 6083' SOUEEZE~ REVERSE OUT~ POOH: SET BRIDGE AT 5081', RIH, SET E-Z DRILL AT 5039' , SQUEEZE, REVERSE OUT, POOH. 9-22 4864 SET E-Z DRILL AT 5007' SQUEEZE, REVERSE OUT~ POOH~ PERFORATE~ RIH~ SET EZ DRILL AT 4946' SQUEEZE REVERSE OUT, POOH, PERF, SET EZ DRILL AT 4864' , SQUEEZE, REVERSE OUT, POOH. 9-23 4707 SET RETAINER, PERF ZONE. SET EZ DRILL AT 4669'. SQUEEZE, REVERSE OUT, POOH. WAIT ON CEMENT. BEGIN DRILLING OUT. TAG CEMENT AT 4663'. CONDITION MUD FOR CEMENT CONTAMINATION. , 9-24 5007 DRILL FIRST EZ DRILL~ TEST CASING TO 1500 PSI. BIT TRIP: DRILL EZ TO 4946'. POOH: RIH~ DRILL ON EZ DRILL AT 5007'. __9-25 5083 RIH WITH RTTS. TEST EACH SQUEEZE ZONE DRILLED. ALL TESTS OK. RIH WITH BIT 21, DRILL TO 5083, POOH. 9-26 5083 RIH WITH RTTS, TEST BACKSIDE ETC., POOH WITH RTTS, TEST BoP'S RIG UP G.O. AND PERFORATE, PREPARE Ti SQUEEZE, ADDED A LITTLE GEL AND BICARB OTHERWISE blUD coNSiSTENT WITH NO PROBLEMS. 9-27 ~.~93 , .RIG UP HOWCO~ SQUEEZE WITH 15.9 PPG CEMENT~ REVERSE OUT DUMPING CEMENT~ RETURN HOSE BLEW OFF FLOW Li~E CAUSING SOME MUD LOSS, PUMP PILL, POOH, RIH AND DRILL RETAINER, CONDITIONED MUD WITH BICARB, POOH , ,, LAYING DOWN 3½" DP. 9-28 . ..4991 DRILL CEMENT, NO TEST, POOH, RIH WITH EZ DRILL, RIH WITH DP, SQUEEZE WITH 15.8 PPG CEMENT, POOH, EMPTYING PREHYDRATE INTO""PITS AND CLEANING TANK IN PREPARATION FOR COMPLETION FLUID· , ,, 9-29 5028 RIH WITH BlT, DRILL CEMENT, NO TEST, POOH, SET EZ DRILL, SQUEEZE WITH 15.8 PP~' C~MENT, REVERSE'OUT DUMPING CEMENT, CBU, POOH, ADDED 1 SACK OF UNI-CAL TO HELP BREAK OUT ENTRAINED AIR. Mtlchem THRAPP/O ' MALLEY-KEYE S /OGLESBEE ALASKA This space is for your conYenience when using lhe Supplementary Data form in conjunction with the "form holcle.~." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS CO/~PLETE. MII. CHEM INCORPORATED I P. O. BOX 22]~1 / HOUSTON~ TEXAS 77021 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUP P L EM E NTARY 'DATA LEGAL API #50-133-20370 _DESCRIPTION SEC 7, T.4.N, ~ llW. SM . .. Mile:hem Well No. ~ 06-02~-099~q Well Name And No. KTU 13-5 COUNTY KENAI STATE ALASKA it ,11 , , , ,1 i 11 i i i ill , 11 , , , , i ii 11 i, , . ,, , ,, ,,. DATE DEPTH INFORMATION i i I I I , I I I I Ill I I In Ill 9-30 6083 RIH WITH BIT AND DRILL RETAINER AND CEMENT, TEST OK. DRILL. Pooh FOR BIT. ~TH. DRTT.T.. MID A~ATT~G .. UP AT 1300 HOURS CHECK, INCREASE IN C1- WHEN DRILLING LAST SQUEEZE.PROBABLY CONTRIBUTING FACTOR. ~. TREATING WITH'LD-8 TO BRE'AK IT OUT, 'MUD RESPONDING. 10-01 7310 DRILL ON gETAINERS AND CEMENT THROUGHOUT DAY~ ADDED SMALL AMOUNTS OF UNI-CAL TO RHEOLOGICALLY CONTROL MUD. ALSO ADDING A LITTLE BICARB FOR CA++ CONTAMINATION. EVERYTHING IN GOOD SHAPE. 10-02 7497 DRILL ON RETAINERS AND CEMENT TH.gOUGHOUT..DAY. M~D HEATING UP AND HAVING USUAL EFFECT ON RHEOLOGY. ADDED SMALL AMOUNTS OF UNI-CAL DURING THE DAY. PRESENTLY WEIGHT IS HIGH ENOUGH TO PERMIT ADDITION OF WATER TO HELP OUT DEHYDRATION. MUD GENERALLY IN GOOD sHAPE. 10-03 7683 DRILL OUT CEMENT AN~ RETAINERS TO 7683'. TEST CASING, TRIP OUT. 10-04 8062 MILL ON BRIDGE PLUG AT 7683'. MILL TO 7978'. POOH, RIH WITH BIT 31, DRILL OUT TO 8062', CIRCULATE . HOLE CLEAN, POOH. 10-05 8062 POOH, CASING SCRAPER RUN. RIG UP GEARHART, RUN CBL. BEGIN CLEANING PITS. BEGIN MIXING COMPLETION FLUID IN PREHYDRATION TANK. DIRfP ALL MUD. 10-06 8062 COMPLETE CLEAN-UP OF MUD PITS. MIX COMPLETION FLUID TO 6% KCL CONCENTRATION AND RAISING THE FLUID WEIGHT TO 76 PCF WITH ADDITIONS OF CaC12. DISPLACE HOLE WITH cOMPLETION FLUID. POOH. 10-07 8064 POOH, PICK UP PERF GUN AND RIH PICKING UP 3½" DP. PERF ZONE AND TEST. 10-08 8064 CONTINUE TESTING. REVERSE OUT, POOH, PICK UP TOOLS, RIH, SET PACKER AT 7972'. PUT WELL ON TEST. . 10-09 8064 FINISH TEST. REVERSE OUT. CONTINUED INTRUSION OF GAS. CIRCULATE LONG WAY. 10-10 8064 CIRCULATE OUT GAS, RIH WITH SCRAPER, JUNK BASKET ETC, CIRCULATE, POOH, RIH WITH ~E~F GUNS, PERF, MUD AT DESIRED SPECS. , . 1'~-11 8027 DROP BAR TO PERF, DISPLACE WITH N? ETC, TEST, OPEN BYPASS, REVERSE OUT, CIRCULATE LONG WAY, ADDED A LITTLE KCL TO SWEETEN SYSTEM OTHERWISE NO CHANGE. 10-12 8015 CIRCULATE, POOH, PICK UP BIT AND SCRAPER ETC, RIH, CIRCULATE OUT SAND RETAINING SAMPLES, POOH AND PICK ,. UP MILL, RIH, MILLING AT REPORT TIME, MAGNETS IN PLACE. 10-13 7975 POOH LAYING DOWN MILL ETC, TEST AND DISPLACE WITH N2, BREAKDOWN, P'UMP ACID ETC, TEST, SHUT DOWN AGITATION TO INITIATE SETTLING OF SILT, ACID DISPLACED TO MUD SYSTEM BY MISTAKE RESULTING IN LOWER , , pH BUT NO OTHER HARMFUL EFFECTS. MIIchem Technical Representative. THRAPP/O ' MALLEY-KEYES/OGLE~BEE District., ALASKA F'ag~ 5 of 10 This space is for your convenience when using the Supplementary Data form in conjunction with th~ "|arm holder. DO NOT DETACH ALONG PERFORATED LINE UNTIL THF: DATA IS COMPLETE. MII.CHEM INCORPORATED I I~. O. BOX 2211] I HOUSTON, TEXA~ 77021 OPERATOR ~T51ION 0TT, C0~AN¥ 0F CALIFOR51IA SUPPLEMEN'TARY LEGAL API #50-133-20370 DESCRIPTION SEC 7, T 4N, R llW, SM DATA Milchem Well No. ,_ 06-023-09969 ,_ Well Name And No. KTU 13-5 ,COUNTY KENAI ,, .STATE., ALASKA DATE DEPTH INFORMATION iii ii i ii i i Il i _10-14 8064 CIRCULATE, POOH, PERF, MAKE SCRAPER RUN, POOH, RIH-WITH 3½" DP, PREPARE TO TEST, ADDED 3 SACKS CAUSTIC ,, _ ._ TO SYSTEM TO HELP NEUTRALIZE ACID. pH = 8.0 ...1..0-15 7983 OPEN BYPASS, DISPLACE WITH N2, OPEN TO FLARE PIT, TESTING, PH uP I~RGINALLY OTHERWISE NO CHA51GE IN MUD.j' _ 10-16 7893 TEST WELL THROUGHOUT DAY. --_ . 10-17 7950 FINISH TESTING WELL, KILL WELL. CIRCULATE HOLE, RIH TO BOTTOM PERFS, CIRCULATE HOLE. 10-18 7687 RIG UP AND SET RETAINER, 7768'. RIH WITH PACKER. SET PACKER AT 7687'. PERF AND PUT WELL ON TEST. ' MAKE ADDITIONAL 100 BBL VOLUME ...... 10-19 7750 CONTINUE TO TEST WELL. NO CHANGES. 10-20 7750 CONTINUE TO TEST WELL. MIX HEC/.CaCO~ PIL..L... BULL HEAD KI'LL WELL. REVERSE CIRC~'LATE'TO KILL. 10-21 7600 KILL WELL. POOH~ RIG UP G.O. SET RETAINER AT 7600'. RIH WITH GUNS AND RTTS. PERF ZONE, PUT WELL ON TEST. 10-22 7606 TEST ZONE. KILL WELL. RIH PAST PERFS, CIRI~CLATE, pOoH, RIH WITH RETAINER, PREPARE TO .SQUEEZE ZONE. ,, .10-23 6912 RIH WITH RETAINER, SQUEEZE ZONE, REVERSE OUT, POOH, RIH WITH RTTS. SET PACKER AT 6912'. MAKE MORE' VOLUME AND BRING SYSTEM UP TO 76 PCF. PERFORATE A51D PUT WELL ON TEST. 10-24 6912 TEST;, RIH WITH GEARHART (SINKER BAR AND FLO~ METER), ~ERF, TEST WITH 5I7, DISPLACE HOLE, ?ERF, TEST. MUD WEIGHT STEADY AT 76PCF. 10-25 6912 TEST WE. LL THROUGHOUT DAY~ REPERFORATE~ TEST. .... 10-26 6900 TEST, KILL WELL {REVERSE CIRCULATE), CIRCULATE LONG WAY, CIR.C.ULATE AT RETAINER,.. S. POT 20 PPB CaCO~ (F) PILL, POOH, GET READY TO TEST NEXT SECTION. 10-27 6900 TEST WELL THROUGHOUT DAY, KILLING WELL AT REPORT TIME. 10-28 6550 REVERSE CIRCULATE, CIRCULATE LONG WAY TIL CLEAN, DROPPED TO RETAINER AND CIRCULATED CLEAN, SPOTTED 20 PPB CaCO3 PILL, POOH, RAN GAUGE RING ETC, RIH WITH RTTS, TEST, BUILT pILL PIT (68 BBLS) OF MUD TO SUPPLEMENT VOLUME. ,. 10-29 6550 TEST, KILL WELL, RETEST. . . , 10-30 6550 TEST THROUGHOUT DAY, REVERSE CIRCULATE TIL CLEAN, CIRCULATE LONG WAY, DROP DO~2~I ASD CIRCULATE TIL CLEAN POOH. , ~ . MI Ichem THRAPP/O ' MALLEY-KEY E S / OGLESBEE ALASKA Technical Representati~e.,, Dislrict,. Page,,6 o! 10 This space is for your convenience when using the Supplementary Data form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COI,'~PLETE. MILCHEM INCORPORATED I II). O. BOX 22311 ! HOUSTON, TEXAS 71027 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 DESCRIPTION_ SEC 7, T 4N, R llW, SM DATA Milchem ,.Well No. 06-023-09969 Well Name And No. KTU 13-5 ,COUNTY KENAI STATE .... ALASKA DAT£ DEPTH INFORMATION . . ,, , , I .I Ill 11, . I I I 10-31 6406 SQUEEZE ~ONE~ REVERSE OUT. RIG UP G.O. RUN EZ DRILL~ RIH: SET RETAINERs.SQUEEZE ZONE~ REVERSE OUTt POOH. ,, · 11-01 6266 TEST STACK. WIRELINE. RIH WITH RTTS. PUT WELL ON TEST. 11-02 6365 FINISH DRI.~L STEM TEST. KILL WELL AND CIRCULATE~ PO0~. RIG UP WIRELINE. SET EZ DRILL AT 6365'. RIH,. SQUEEZE ZONE~ REVERSE OUT. DITMP CEMENT AND CONTAMINATED MUD~ POOH. 11-03 5862 POOH, SET RETAINER, SQUEEZE ZONE, REVERSE OUT. SET PACKER AND PUT WELL ON TEST. FINISH TEST. BULL . - HEAD KI~L WELL WITH CaCO3 PILL. REVERSE OUT. 'RIH TO NEW TEST ZONE. ,, 11-04 5907 TEST ZONE. END TEST~ KILL WELL. SPOT CaCO~ AND BULL HEAD PILL INTO PERFS. PICK UP EZ DRILL~ RIH. SET PACKER AT 5990', SQUEEZE ZONE, REVERSE OUT~ POOH, PICK UP EZ DRILL, RIH. SET PACKER AT 5907'. ,, SQUEEZE, REVERSE OUT, PREPARE TO VISCOSIFY SYSTEM AND PUT IN 15 PPB CaC0~. . 11-05 5907 CIRCULATE AND CONDITION MUD WITH XC POL.YMER AND 15 PPB CaCO% (C,M,F)~ POOHz PERF RUNS 1 THROUGH 7~ RIH. 11-06 5387 FINISH PERFORATING. RIH WITH TEST BHA. SET FIRST TEST AT 5387'. WELL ON TEST. , 11-07 5332 TEST WELL~ CIRCULATE LONG WAY~ DROP DOWN TO BRIDGE PLUG~ CIRCULATE HOLE CLEAN~ RETRIEVE AND RESET BRIDGE PLUG, RESET RTTS ETC, TEST. 11-08 5055 TEST WELL, CIRCULATED LONG WAY, DROP DOWN TO BRIDGE PLUG, CIRCULATE HOLE CLEAN, ~ETRIEVE AND RESET BRIDGE PLUG AND RTTS, PREPARE TO TEST, BUILDING SOME VOLUME AT REPORT TIME. 11-09 5055 TEST WELL, CIRCULATE LONG WAY, DROP TO BRIDGE PLUG, CIRCULATE HOLE CLEAN, RETRIEVE B.P. AND POOH TO , WIRELINE (GAUGE RING ETC). · 11-10 4982 RUN BRIDGE PLUG, PICK UP RETAINER AND RIH, SQUEEZE WITH 15.8 PPG CEMENT, REVERSE OUT, TEST BOP'S, PICK UP RTTS AND RIH, SET AND TEST, BUILT 65 BBLS OF VOLUME TO s'UPPLEMEN~ SYSTEM. 11-11 4982 TEST~ PERFORATE~ OPEN AND SHUT IN WELL PERIODICALLYt TEST AND RUN H.P. . 11-12 5032 TEST~ KILL WELL~ REVERSE CIRCULATING, CIRCULATE LONG WAY, DROP TO RE~AINER, CIRCULATE HOLE CLEAN, POOH, PICK UP BIT, DRILL COLLARS AND 5" DP TO DRILL RETAINERS ETC, RIH. , 11-13 5104 DRILL RETAINER AND CEMENT TO 5104', POOH, PICK UP 3½" DP AND RIH, DRY TEST SQUEEZE, CIRCULATE HOLE CLEAN, POOH AND PICK UP DRILLING ASSEMBLY, RIH AND DRILL ON RETAINERS. 11-14 5101 TEST SQUEEZE, TEST FAILED. RIH, SET BRIDGE PLuG AT 5170'. RIH, SET RETAINER AT 5101'. SQUEEZE ZONE. ..................... , ......... REVERSE OUT, POOH,. PICK UP BIT & BHA, RIH TO TOP OF CEMENT, CIRCULATE WHILE WAITING ON CEMENT. Mllchem T,.rhn;~-.l R~.nre,~entaflve THRAPP / O ' MALLEY-KEYES/OGI.E SBEE Di,~frlef ........................ ALASKA ................................ Pc,.e_7_ ..... 10 This space is for ),our convenience when using the Supplementar), Data form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MILCHEM INCORPORATED I P. O. BOX 22] ] l I HOUSTON, TEXAS 77027 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 _DESCRIPTION. SEC 7~ T 4N~ R llW~ SM DATA Milchem Well No... 06-023-09969 Well Hame And No. KTU 13-5 COUNTY KENAI .STATE ALASKA i i i i i ii ii ii ii ii i · i i ii ,, , DATE DEPTH INFORMATION ti , , i , , i i i i i i ii ii ii i i 11.~15 5181 DRILL RETAINER AND CEMENT TO 5181'. CIRCULATE BOTTOMS UP~ POOH~ PICK UP RTTS~ RIH AND DRY TEST~ SQUEEZED ZONE. TEST OK. POOH. - , , 11-16 6238 DRILL BRIDGE PLUG AT 5181', CHASE TO 5898', DRILL JUNK TO 5907', DRILL CEMENT FROM 5910 - 5990'. DRIL{ FROM 5990 - 6030', CHASE TO 6238" ', cBU, POOH, RIH WITH TEST TOOL'. SET TOOL AT 5916', PuT'"'WELL ON DR~ TEST. TEST OK, REVERSE CIRCULATE, POOH. , , 11-17 6421 POOH, LAY DOWN TEST TOOL. RIH WITH BIT #36, DRILL RETAINERS AND CEMENT TO 6421', POOH, TEST BOP. , , 11-18 6479 RIH WITH TEST TOOL DRY TEST OK POOH, RIH WITH BIT 37~ DRILL RETAINER AND CEMENT TO 6479' CBU POOH, RIG UP AND RUN TEST TOOL. PREPARE TO DRY TEST. 11-19 6432 DRY TEST FAILED. POOH, SET RETAINER AT 6432'. RIH, PREPARE TO SQUEEZE - FORMATION wouLDN'T BREAK DOWN. 11-20 6479 RIH WITH TEST TOOL. DRY TEST. POOH, RIH WITH BIT 38, DRILL OUT EZ DRIL~, DRILL ON RETAINER AT 6479'. 11-21 6566 DRILL RETAINER AND CEMENT TO 6550' POOH RIH WITH DRY TEST TOOLS, DRY TEST #7, PUMP AND ESTABLISH , , BREAKDOWN, REVERSE OUT, 7400 UNITS GAS (MAX), POOH, LAY DOWN TOOLS, RIH. ' 11-22 6566 RIH, RIG UP HALIBURTON, PUMP 30 BBLS CEMENT AND DISPLACE, STING IN AND PUMP SQUEEZE, PULL UP FIRST JOINT AND REVERSE OUT, POOH BR~kKING AND MAKING UP EVERY JOINT, RIH WITH DRILL STRING, DRILL UP EZ DRILL. 11-23 6500 POOH, PICK UP DRY TEST TOOLS, RIH, DRY TEST #8, POOH, LAY DOWN TOOLS, RIH WITH EZ DRILL, ESTABLISH INJECTION RATE, PUMP CEMENT, SQUEEZE, REVERSE OUT, POOH. 11-24 6566 WAITING ON CEMENT, RIH, TAG CEMENT AND DRILL RETAINER AND cEMenT BELOW RE{AINER, POOH, RIH WITH DRY TEST TOOLS, DRY TEST #9, POOH. , 11-25 6503 RIH WITH RETAINER AND SET, RIG UP HALLIBURTON, ESTABLISH INJECTION RATE, NO BREAKDOWN, POOH, PICK UP BIT, RIH, DRILL UP RETAINER, POOH, PICK UP DRY TEST TOOLS, RIH. DRY TEST #10. , , , 11-26 6566 POOH, REDRESS TOOLS, RIH, DRY TEST #11, POOH, PICK UP EZ DRILL CEMENT RETAINER, RIH. , , 11-27 . .6480 PUMP 5 BBLS ACID, WATER CUSHION.AND CEMENT, STING IN A~p_SQUEEZE, PULL UP AND REVERSE O~T. WAITING ON CEMENT. DRILL RETAINER. '11-28 6563 RIH WITH BIT 42, DRILL RETAINER AND CEMENT TO 6563', CIRCULATE & POOH, RIH WITH TEST TOOL, SET TEST , TOOL AND DRY TEST, POOH. Mllchem Techn;¢al Remesentati,e ............. THRAPP/O' MALLEY-KEYES/OGLESB~E .......... Dis trlct.__ ALASKA Paae 8 of ..!0 ..... This space is for )'our convenience when using the Supplementary Data form in conjunclion wilh the "form holder." DO NOT DETACH AL,ONG PERFORATED L. IHF: UNTIl_ THE DATA IS COMPLETE. MII. CHEM INCORPORATED I P. O. BOX 221111 HOUSTON, TEXANS 77027 OPERATOR. UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API ~!50-133-20370 DESCRIPTION, SEC '7,~_ T 4N, R. iiW, SM DATA Milchem Well No.._ 06-023-09969 Well Name And No.. , KTU 13-5 COUNTY KENAI STATE., ALASKA DATE DEPTH INFORMATION ii i i ii ii i i i i i l! illl i Ill Il I J Ill Il 11-29 7617 . DRILL RETAINERS AT 6566' AND 6908'. STATIC MUD BETWEEN RETAINEgS CAME .UP...L!GHT. REOUIRING TREATMENT. TRIP FOR BIT. RIH, DRILL ON RETAINERS AT 7490' AND 7617'. 11-30 8063 DRILL OUT RETAINERS AT 7620', RIH TO 7768', CIRCULATE AND POOH, CHANGE BIT. RIH~ CIRCULATEz. GAS THROUGH CHOKE. CLEAN OUT TO 8063' CIRCULATE AND POOH. , , 12-01 8063 PICK UP CASING SCRAPER. RIH TO 8063' CIRCULATE PICK UP TO 7580' DUMP PITS CLEAN PITS 12-02 8063 FINISH CLEANING PITS.. TRANSFER ~LgAN BRINE TO PITS~ MIX.ANOTHER BATCH OUTSIDE AND FILTER I~T0 PITS, MIX HI-VIS SWEEP, PUMP SWEEP AND DISPLACE HOLE WITH CLEAN BRINE. CIRCULATE AND POOH, RUN GAUGE RING. ..12-03 8'040 SET BRIDGE AT 8040'. ATTEMPT TO RUN WASH TOOL. GAS TO S~.RFACE. RIH. AND CIRCULATE HOLE. ..MIX..BA%CH OF BRINE AND FILTER INTO SYSTEM. POOH, RIH WITH WASH TOOL, WASH PERFS. 12-04 8040 FINISH WASHING DOWN PERS, POOH, LAY DOWN WASH TOOL~ RIH WITH.. ~IT,. gIRCU~AT~,. POO~ LAYING DOWN 5" DP. RIH WITH 3½" DP. !2-05 8040 FILTER AND CIRCULATE BRINE WITH 10 MICRON FILTERS~ FILTER AND CIRCULATE WITH ~.MICRON FILTERS,POOH, 12-06 7820 RUN IN WITH SCREEN AND OTIS PACKER, TEST LINES, PUMP PACKER FLUID AND SAND, STING IN AND DISPLACE, STING OUT AND REVERSE OUT - LARGE AMOUNT OF SAND iN BOTTOMS UP RETURNS, POOH. .12-07 7820 LOG, RIH, CIRCULATE GAS OUT, POOH, PICK UP OTIS TOOLS, RIH, PUMP GRAVEL PACK, UNSTING AND REVERSE CIRCULATE LONG WAY THROUGH CHOKE TO CLEAN UP GAS - FILTER ALL FLUIDS THROUGH 10'S WHILE CIRCULATING. .. 12-08 7820 POOH, PICK UP 1½" TAIL PIPE, RIH, REVERSE OUT GRAVEL PACK, SAND INSIDE SCREEN. POOH~ PICK UP PACKER~ RIH, DISPLACE NITROGEN AND BRINE - WELL ON TEST. 'i2-09 7820 TEST WELL, REVERSE THROUGH CHOKE AND FILL DRILL PIPE, CIRCULATE LONG WAY, KILL wELL, FILTER WHILE CIRCULATING, POOH FOR LOGS. 12-10 7820 LOG, RIH WITH PACKER, SET PACKER, POOH, PICK UP sCREEEN AND PACKER, RIH, SET SCREEN AND PACKER, PUMP UPPER GRAVEL PACK, REVERSE OUT. . 12-11 7820 POOH~ LOG~ RIH~ CIRCULATE GAS OUT~ PULL OUT LAYING DOWN - CHANGE RAMS. 12-12 4860 SET PACKER, RIG UP AND RUN DUAL PRODUCTION STRING (3-1/2, 2-7/8). POOH, SET RETRIEVABLE BRIDGE PLUG , · AND PREPARE TO PERFORATE. 12-13 4860 SET BRIDGE PLUG. PERFORATE ZONES. RIH WITH B.P. RETRIEVAL TOOL, CIRCULATE GAS OUT THROUGH CHOKE. ,. Milchem Technical Representative THRAPP/O ' MALLEY-KEYES / OGLESBEE District__ ALASKA Page_.~9 of .10 This space is for ),our convenience when using Ihe Supp~emenlar), Data form in conjunction with the "form holder. DO NOT DETACH ALONG PERFORATED LINE UNTIL THE DATA IS COMPLETE. MII.CHEM INCORPORATED I P. O. BOX 221 ] 1 / HOUSTON, TEXAS 77027 OPERATOR UNION OIL COMPANY OF CALIFORNIA SUPPLEMENTARY LEGAL API #50-133-20370 DESCRIPTIO~L SEC 7~ T 4N~ R llW~ SM DATA Milchem Well No. 06-023-09969 Well Name And No. KTU 13-5 .COUNTY KENAI ,STATE. ALASKA 1. ,mill J, i i ii i iii i ii i ii , DATE DEP TH INFO RMATION 12-14 7402 POOH, RIH WITH LOWER PRODUCTION ASSEMBLY. WIRELINE CORRELATION~ SET .STRING,. PULL UP AND CIRCULATE OUT GAS. REQUIRE WEIGHT UP TO 75+ TO KILL WELL. 12-15 7580 CIRCULATE, POOH LAYING DO~N 3½, DP,~RIG UP AND RUN DUAL PRODUCTION TUBING. 12-16 4871 L~.~D TUBING. TEST TUBING. SET PACKER~ NIPPLE DOWN BOP'S. 12-17 4871 DISPLACE PACKER FLUID INTO ANNULUS. DUMP AND CLEAN PITS. DISPLACE TUBING WITH NITROGEn. PUT WELL ON TEST. 12-18 4871 TEST SHORT STRING. FLOW AND SHUT IN. TEST LONG STRING. 12-19 7580 RUN COIL TUBING, POOH, RUN WIRELINE TO CLOSE XO~ WIRELINE STUCK. 12-20 7580 MIX KILL FLUID TO 76 PCF, MIX CaClo PILL, BULL HE.~D AND KILL WELL. CIRCULATE THROUGH BJ UNIT TO CLEAN -- UP GAS. 12-21 7580 RIG DOWN LUBRICATOR - STUCK TOOL FREE FROM PUMPING - PULL TOOL~ RIG UP COIL TUBING~ RIH - INJECT NITROGEN WHILE RUNNING IN HOLE - DISPLACE FLUID. , 12-22 HIT BRIDGE 90' OFF BOTTOM~ POOH~ PICK UP DYNA DRILL~ RIH~ NO BRIDGE, POOH, RIH WITH COIL TUB.%NG, ' DISPLACING WITH NITROGEN, POOH, RIH WITH WIRELINE, CLOSE XO - RELEASE MUD ENGINEER. , , ,, , Mtlchem Technical Representative THRAPP/0' MALLEY-KEYES/OGLESBEE District. ALASKA · Page 10 of 10 This space is for your convenience when using the Daily Drilling ~,ud Additions farm in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LIH5 UNTIL THE DATA IS COMPLETE. BR_INKERHOFF OPERATOR UNION 0IL COMPANY OF CALIFO..~IA Contractor MUD AnDITinNS API# 50-133-20370 LEGAL DESCRIPTION $EC7 ,T4N,RllW, SM ~, R. C~NDER 1985 Rig No. 54 06-023 Miichem Well No. 09969 Well Name And No. KTU 13-5 Field KENAI GAS FIELD COUNTY KENAI STATE AK Milchem Spud No. Drilling DATE T.D, TOTAL TOTAL Warehouse KENAI Date 08-15-84 DaysToT.D. 16 REACHED 08-31-84 DEPTH 8232 COST $ 426,393.16 /'~/ et~/ ~l_~/' ~k/ ~.'~ t ~I/ ~il ,~'"~/ ~.~" h' ~,," ~,'~/" c'_~/ ¢,"~v" et~ / ~/'"~ e,':~/ ~.'_~/'~_~/ ~' ~ ~1 e ~., el ~,' / ., ,~ ., ,, ~ ~'/~ -. ,,... '" oot,"/ oo'/7 o~'.'o? °°97 °°%-- /...'f oO., o- oO .,.o. oO..., o.~ Z/ "~ ,, .. o°./o- · o~.,o~ Z,'f '""~ ~ ' .r~ , ./o~' , ~, - .~ ..o°/O'~. t ~ - .~ -t .- ~/ ~ - ,' .- G,lo.-/ .... - oo,/O o°13 oO~/j~ oO/o~ oo~ o~oo/o'' ~ . , ,.' ~ / o / ~ / ,~ ,~ o' cu~u~.~.v~ 18-14 0 2 I I t ,i t ~ 1/2 1/2 250.00 j 4403.30 ,~-is ~6~ ~ il' IIl .!j , t , i/~i/~ ~so.oo ,' ~S~.so ~-i~ l i:oo ~se io I I I J _i/l i/~~sos.io j ~is~.~o ,~-i~ ~soo : t l~s I~ I ~ i~:i/:i~i~.oi l i:o~.:~ i I It .... ,~-lo ~soo t t I j i/:i/1lis.oo l i:is~.:~ ,s-:i lsoo soI I i t I i I i/li/~ioi:.so i i~::l.~ ,s-~] 2sio ~o is~ i2 , I I I i J z i/2 i/~I ~s~s.~9 2~gs2.~s ,8-26 5755 ~,29 2 ~ 11 6 I ~ 21 1/2 1/2 6447.15 38757.09 [8-28 7114 125 4 '10 13 5 1~2 1/2 5982.70 52432.23 8-30 8~08 35~' 26. ~ 8 12 7 I I .. ~ ~ ~2 ~ " ~/2 ~/2 1~2s6~.,s 8004~.~3 2-23-84 Milchem THRAPP / O ' MALLEY-KEYES / OGLESBEE ALASKA 1 7 rSD--OMA-- 1/73, Technical Representative District Region PAGE OF ~ This space is for your convenience when using the Daily Drilling >';ud Additions form in conjunction with the "Jafra holder." DO NOT DETACH ALONG PERFORATED Lllq5 UNTIL THE DATA [5 COMPLETE. -~':~: :' '~:'~%~:::':'~ DA! LY D FR ! L L i N ~.L4Lr,-=L~-~.~i.'. '~."~z~,"~.,~ MILCHEM INCORPORATED / P, O. BOX 2211 ]. / HOUSTON, TEXAS 77C'27 Contractor ]3~RIqOFF OPERATOR L,,~ION 01I, COM?.LXY 0.1: C.&1`T_FOE'.;IA MUD ADDITIONS API# 50-133-20370 LEGAL DESCRIPTION SEC7 ,T4N,RllW, SM Rig No. 54 06-023 Milchem Milchem Well No. 09969 Warehouse Name And No. KTU 13-5 Field KENAI GAS FIELD COUNTY KENAI STATE Spud No. Drilling DATE T.D. TOTAL KENAI Date 08-15-84 Days To T.D. 16 REACHED 08-31-84 DEPTH 8232 TOTAL COST $ 426,3'93.16 DATE 08-31 09-01 C'9-02 ~'9-03 09-04 :9-05 09-06 09-07 39--08 09-09 09-10 09-11 29-12 3.9-13 23-14 :~.9-15 39-16 ~9-17 39-18 8232 122 8232 55 8232 55 8232 8232 298 8232 I , , 8135 61 t 8135 28 I 8135 I 8135' 493 , ,aToI 5~I 817o 18o I 8170 7~ot z~ t 76641 76641' 58 i 62 32 51 15 l°I vi zs! I 41 8 t . M3chem ~-~0-~_ Technical Representative 'rSD--DMA -- 1/9'1 THRAPP/O'MALLEY-KEYES/OGLESBEE District Region __ 1/2 t1/2 i3'985'00 1/2 11/2 I 1550.40 1/2 11/2 !2249.25 1/2' 11/2 215.00 I1/2 t112 1/2 t1/2 fl/2 14685.00 215.00 84026.53 85576.93 87826.18 88041.18 92726.18 92941.18 1242.82 94184.00 635.00 94819.00 I I i I 1/2 ,, 11/2 1/2 t1/2 , I 969.40 1/2 j1/2 I 7971.75 1296.82 95788.40 103760.15 105056.97 3130.00 108186.97 1. I 589.50 108776.47 11964.00 110740.47 1 I 751.65 111492.12 1 t 653.30 112145.42 I 964.50 113109.92 1255.00 114364.92 1 i 1 }1944.25 116309.17 ALASKA PAGE 2 OF 7 This space is for your convenience when using the Daily Drilling ~'~ud Additions form in conjunction with the "form holder." ih_ UNTIL THE DATA IS COMPLETE. DO NOT DETACH ALONG PERFORATED L '~ L'~ ~ ' ~, : DAli Y D_ILI lNG Contractor BRINI~RHOFF OPERATOR UNION OIL COMPANY OF CALIFOE:~IA MUD ADr"]ITIONS API# 50-133-20370 LEGAL DESCRIPTION SEC7 ,T4N,RllW,SM Rig No. 54 06-023 Milchem Milchem Well No. 09969 Warehouse Well Name And No. KTU 13-5 Field KENAI GAS FIELD COUNTY KENAI STATE AK Spud,, ,. No. Drilling DATET.D. TOTAL KENAI Date 0~-1D-84 D~ys ToT.D. 16 REACHED 08-31-84 DEPTH 8232 TOTAL COST $ 426,393.16 DATE r',~ 84) 09-19 7491, 09-20 6484 09-21 5039 09-22 4864 09-23 4707 09-24 09-25 09-26 09-27 09-28 09-29 09-30 10-01 10-02 10-03 10-04 10-05 10-06 10-07 80 58 55 107 60 1 50071 55 4 l so~l ' ~o j ~o~I ~s 49911 721 10 t~°~-~ , ~ t I ~o~.~ ,t7 t zo '7310 55I 74~7 , 25 7683 38~ '] ~o~4 2 t i '8062 60 1 :8062 ,r 3 4 17 2 1420 I 67 24 41 J , . COST 1630.00 1383. 1255 64 .00 CUM UI_~T! V E C DST 117939.17 119322.81 120577.81 2076.82 122654.63 1503.09 124157.72 1 1915.68 126073.40 · 1 2741.74 128815.14 1032.19 1935.71 1836.78 1411.75 2169.96 '1 1569.28 I 1135.75 t 1183.75 11172.90 IZSO~S 88 152405 50 129847.33 131783.04 133619.82 135031.5? 137201.53 138770.81 139906.56 141090.31 142263.21 157309.06 209714.56 210144.56 D~t~ 12-23-84 TSD--OMA- ~l~em Te~ni~lRepre~n~tive THRAPP/0'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 3 OF~ This space is {or your convenience when using the Daily Drilling ~',ud Additions form in conjunction with the "torm holder." DO NOT DETACH ALONG PERFORATED LIH5 UNTIL THE DATA IS COMPLETE. Contractor BPINKERHOFF DAILY DRILLING LCHEM INCORPORATED /P. O. BOX 22111 / HOUSTON, TEXAS 77027 OPERATOR UNION OIL COMPANY OF CALIFOENIA MUED ADDITIFINS API# 50-133-20370 LEGAL DESCRIPTION SEC7 ,T4N,R_llW, SM Rig No. 54 Well Name And No. KTU 13-5 Field KENAI GAS FIELD COUNTY KENA1 STATE AK Milchem 06-023 Milchem Spud No. Drilling DATE T.D. TOTAL Well No. 09969 Warehouse KENAI Date 08-15-84 Days To I.D. 16 REACHED 08-31-84 DEPTH 8232 TOTAL COST $ 426,393.16 DATE I:~84~ 10-08 8064i 8064 10o09 :LO-ZO 8o64t 10011 10-12 10-13 10-14 L0-15 L0-16 L0-17 L0-18 L0-19 L0020 L0-21 L0-22 L0023 10-24 L0-25 [0-26 8027 8015 79_7.5 8064 79~3t 7450 7687 7750 77501 76061 6912 6912 ,. 6912 6 ob 2 I t 140 ' I 20 20 44 36 1 1 J CUM'JL. ATIVE COST 1 430.00 1 430.00 1 430.00 1 670.00 , I 1 ' I .t 1/2 I 1/2 tz/ [210574.56 1211004.56 [211434.56 1212104.56 430.00 i212534.56 339.40 !212873.96 592.60 i213466.56 215.00 1213681.56 215.00 1213896.56 215.00 1214111.56 5580.00 1219691.56 I1/2 t 1/2 t1/2 I 1/2 211/211/2 1/2 1/2 1/2 11/2 Iz/2 i z/2 1/2 11/2 1/2 11/2 1/2 ll/2 '105 215.00 1219906.56 507.20 1220413.76 215.00 1220628.76 215.00 1220843.76 4274.75 1225118.51 215.00 1225333.51 215.00 1225548.51 2011.10 i 227559.61 D~t~ 12-23-84 TSD--DMA -- I/71 Milchem Technical Representative THRAPP/O'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 4 OF 7 This space is for your convenience when using the Daily Dr:lling ~.",ud Additions form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED L '~ I!',,.. UNTIL TH.: DATA IS COMPLETE. ~;;~~~ MILCHE. M INCORPORATED / P. O. BOX 22111 ! HOUSTON, TEXAS 77027 Contractor BR_Ilql<EIR}]O?F OPERATOR UNION OIL coMP,~xY OF CALIFO,,:~IA MUD AnDITInNS LEGAL API# 50-133-20370 DESCRIPTION SEC7 ,T4N,RllW,SM Well Name Rig No. 54 And No. KTU 13-5 Field KENAI GAS FIELD COUNTY KENAI Milchem 06-023 Mifchem Spud No. Drilling DATE T.D, TOTAL Well No. 09969 Warehouse KENAI Date 08-15-84 Days To T.D. 16 REACHED 08-31-84 DEPTH 8232 STATE TOTAL COST $ 426,393.16 DATE ~ 84~ CUMULATI VIi COST .,, L0-27 ! 69001 L0-28 t 6S501 L0-29 16557 LO-30 16550 L0-31 16406 L1-01 16266 ~z-o~ 1~365 L1-03 j5862 _1-04 5907 .].-os s 67 .1-06 5387 .1-07 5332 .1-08 5055 .1-09 5055 .1-1o 49821 .1-11 .1-12 .1-13 .1-14 17 20 I 10 15 7 · ,, 255 3 20 18 t ! I t 7o l~.15 t 7ol 70 95 120 14 14 21 27 I . I2 j1/2 i 1/2 t 215'00 11/2 11/2t !1/2 "t 1/2 I 112 11/21 112 t 1/21 ]./2t ]-/21 1/2 I' 1/2'! 6428. ]./2 , ]./2 I ].O:L~. ,.. ]_/2~ ]_/2 120622. ]./2]./2j 2zs. 1/2 1/2 I 215. ]_/2 ]./.2 t ~3.~z. ~ .1_ I 430. I I I 430. I 430. i 4216. 227774.61 4298.20 232072.81 215.00 232287.81 215.00 232502.81 3017.50 235520.31 215.00 235735.31 215.00 235950.31 75 242379.06 20 243393.26 80 264016.06 00 264231.06 00 264446.06 50 268837.56 00 269267.56 80 2~3999.36 00 274429.36 00 274859.36 25 279075.61 430.00 279505.61 Mile. ham 12-23-84 Technical Representative FSD---DMA- 1/71 THRAPP/O'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE ,5 ,. OF 7 This space is for your convenience when using the Daily Drilling ,":;ud Additions form in conjunction with the "torm holder." DO NOT DETACH ALONG PERFORATED LI '; 1'~,. UNTIL THE DATA IS COMPLETE. DAILY DRILLING ~:~ ~;~.~_"~'-':J MILCHEM INCORPORATED / ~. O. BOX 22111 / HOUSTON TEXAS 77027 ~ntracfor BP~~O~ OPERATOR UNION OiL COMP.%YY OF CALIFO..:~IA MUD Ar-)DITIONS API# 50-133-20370 LEGAL DESCRIPTION SEC7 ,T4_N,RllW, SM Well Name Rig No. 54 And No. ~ 13-5 Field KENAI GAS FIELD COUNTY KENAI STATE A.K Milchern 06-023 Milchem Spud No. Drilling DATE T.D. TOTAL TOTAL Well No. 09969 Warehouse KENAI Date 08-15-84 Days To T.D. 16 REACHED 08-31-84 DEPTH 8232 COST S 426,393.16 DATE ~9 84 11-15 11-16 11-17 11-18 11-19 11-20 ll-21 L1-22 L1-23 L1-24 .1-25 .1-26 .1-27 .1-28 .1-29 62381 6421j 6479t 64791 6566I 6500t 65o01 65661 ' 1 68031 I 16480 t65~~ ' ]76i7, ' i ! i i t I i i t301 I '3~6 I i I t 7]. 1187 I t 72 I I lio5 2O ! t I I t 127I 53t I 9oi . t I1 '1 1 1 1. 1. 1 1 t CUMULATIVE COST 430'00 1279935.61 430.00 t280365.61 430.00 1280795.61 430.00 1281225.61 12880.95 1294106.56 ! 4322.95 !298429.51 t14111.80 I 312541.31 430.00 J312971.31 430.00 I 313401.31 4258.58 1 31768¢.86 7474.35 1325134.21 3157.60 1328291.81 430.00 J328721.81 430.00 [329151.81 4057.75 1333209.56 i I 8665.00 1341874.56 ?_-o]. 18o~. .2-02 !, 8063[ . .~--o~! 8o~oI zl 1210 I t I 391 6ol I 120 I 60 35 ,', 3 i I 430.00 t342304.56 1 115724.05 I 358028.61 1 t12458.65 [ 370487.26 12-23-84 $O---C~MA -- 1i71 Milchem Technical Representative THRAPP / O ' MALL EY-KEYE S L OGLE S BEE District Region ALASKA PAGE,., 6 OF 7 This space is for your convenience when using the Daily Drilling ?,ud Additions form in conjunction with the "form holder." DO NOT DETACH ALONG PERFORATED LIH5 UNTIL THE DATA IS COMPLETE. ~, :' .... ~"- DAILY DRII_~LING ~,,':~.~,~ L._~,.~.~%~_~;[:,:_~;.~,,.~ MILCHE,%'I I~CORPORATED / P. O. BOX 22111 / HOUSTON. TEXAS 77027 ~ntractor B~~O~ OPERATOR UNION OIL COMPA%Y OF CALIFOF. XIA MUD ADDITInNS LEGAL .A_P I :~ 50-133-20370 DESCRIPTION SEC7 ,T4N,~LllW, SM Rig No. 54 06-023 Milchem Milchem Well No. 09969 Warehouse Well Name And No. ~ 13-5 Field KENAI GAS FIELD COUNTY KENAI STATE AK Spud No. Drilling DATE T.D. TOTAL KENAI Date 08-15-84 Days To T.D. 16 REACHED 08-31-84 DEPTH 8232 TOTAL COST $ 426,393.16 12-04 12-07 12-08 12-09 12-10 12-05 60401 12-06 7820 78'20 7820 12-11 12-12 7820 7502 4860 · 4860, 7402 . 7580 1.2-13 1.2-14 L2-15 L2-]6 L2-!7 1.2.--18 I 175 175 , 40 60 ~-'I ~o z, ' ~3o 1t71431 ' 430 1 17455 · 1 I 43o 1 1 111 I I I ' 1 I CUMULATIVE COST COST '00 1370917.26 .00 1371347.26 .00 1371777.26 .75 i 378921.01 .00 i 379351.01 .75 1386806.76 ,00 I 387236.76 430.00 1387666.76 I 430.00 [388096.76 1 430.00 388526.76 1114265.05392791-81 430.00 t393221.81 1 I 430~00 1393651.81 L2-19 k2__- 20 L2-21 L2-22 4871 48~z t~7~ ~8~z(' ,t8711 I I " I I I [ 15~5 t I 105 I 9 .t 430. O0 394031.81 I 430.00 394511.81 '1 ,~o.oo t29719,65 I 424661.46 11301.70 I 425963.16 'l [ 430,00 1426~93,16 Date 12-23-84 Miichem T~chnical Representative TSD--DMA- ~[/73 THRAPP/0'MALLEY-KEYES/OGLESBEE District Region ALASKA PAGE 7, OF 7 D ~. U.~ '~''' "' nuorlE..O DI I I~r'~'UI'~U ~. m ) j , ,, SHEET '! OF' FILE NUMBER I I IIII I I NOT USE ~g~ egPTH s~ ACCU~.W~. v~ ~UM~ S P M MUD DULL, COND. ~O~A~ON NO. SIZE MAKE TYPE 3ZND IN SgRIAL FEET HOURS ~Oo~ FTHR'DRLG. 1000 R P M DEV,PRESS CALL DATgS TYPE ~ OUT H~. E~, I Z WT.~ VIS. W.L, T B G OTHER, REMARKS ia li~ ,' . " i~'..... " " " ~ ~,l~fi isa I~ ~]~I~o:-'~ ~~, " -, ~ ~,' ' , i~'' " '~ , " " ~1~ ~'~ I'~'.~ ~ ~'~~ " "~'~ " I III I I ~ I II ...... ~ ~ ~ ~ ~ ~ t~-~= " , ~., ~' ' ..... ~ ' ' I I I I I II I I I il II I ~ ~ ,- ,, ~, ~ ~~~c, , ~s ~ ..... ~ ~ ~'~ ', ,~ ,,,, ~ ~ ~ ~~'~ II I I I I I III I I I /' t . BIT CONDITION CODE: RP' REPAIEED RR'R£RUN ORIGINAL-REGION OFFICE tours for the asking . . . 'echnical information and ~elp to get your holes down aster with fewer problems. ~dvice on rock bit perfor- nance, bit selection, drill tring analysis, hydraulics ~rograms and recommen- lations on the best bit veight and rotary speed. r'his information is tail- )red for you, your Ioca- ion and your rig. (our Hughes Tool Corn- )any representative is your ~est source for drilling nformation.., wherever ,ou drill. Compliments of FIUGHES TOOL COI~IF~ANY Houston, Texas U.S.A. COUNTY / PRINTED IN U, S. A, B'T RECORD CO NTRA~ ~~1~/ FIELO Z~ ISTA~K ISECTION JOINTS COLLAR5 ' . ~ . , ACCUM WT. VERT PUMP PUMP S P M MUD DULL. COND. FORMATION NO SIZE MAKE TYPE JET SERIAL DEPTH FEET HOURS FT/HR DRLG. 1000 R P M OPER- 32ND IN~ OUT HRS. LBS, DEV, PRESS ATION ~ z WT. VIS. W.L. T B G OTHER REMARKS o,/,/ Yours for the asking ... Technical information and help to get your holes down faster with fewer problems. Advice on rock bit perfor- mance, bit selection, drill string analysis, hydraulics programs and recommen- dations on the best bit weight and rotary speed. This information is tail- ored for you, your loca- tion and your rig. Your Hughes Tool Com- pany representative is your best source for drilling information.., wherever you drill. Compliments of HUGHES TOOL COMPANY Houston, Texas U.S.A. COUNTY,/ PRINTED IN U. S. A. BIT RECORD A~STATE I SECTION ITOWNSHIP IRANGE ~ccu. WT. V[~T PUMP PUMP S P M MUD DULL. COND SIZE MAK~ TYPE JET SERIAL D~PTH FEET HOUES ~/HE ~RL~. 000 E P ~ OPEE- ' FORMATION 32ND IN OUT HRS. LaS, DEV PRESS ATION REMARKS I 2 WT, ViS. W,L, T B G OTHER ADDENDUM TO COMPLETION REPORT (26) Squz'd Intervals f/8095' - 8097' w/4HPF Sqz'd w/148 sxs cl "G" 8088' - 8090' w/4HPF Sqz'd w/148 sxs cl "G" 8002' - 8004' w/4HPF 7948' - 7950' w/4HPF 7652' - 7654' w/20 HPF 7520' - 7502' w/gHPF Sc 7518' - 7520' w/4HPF Sc 7335' - 7337' w/4HPF Sc 6515' - 6517' w/4HPF Sc 6500' - 6515' w/8HPF sc 6426' - 6436' w/8HPF sc 6370' - 6376' w/8HPF sc 6324' - 6330' w/4HPF sc 6116' - 6118' w/4HPF Sc 5994' - 6003' w/4HPF sc 5914' - 5924' w/4HPF sc 5141' - 5161' w/4HPF sc 5110' - 5135' w/4HPF sc 5073' - 5081' w/4HPF sc 5059' - 5066' w/4HPF sc 5054' - 5056' w/4HPF Sc 5008' - 5010' w/4HPF Sc 4998' - 5000' w/4HPF Sc 4975' - 4977' w/4HPF Sc 4895' - 4897' w/4HPF sc 4698' - 4700' w/4HPF sc z'd w/197 SXS cl "G" z'd w/160 sxs cl "G" z'd w/145 sxs cl "G" z'd w/143 sxs cl "G' z'd w/431 sxs cl "G" z'd w/134 sxs cl "G" z'd w/165 SXS cl "G" z'd w/170 sxs cl "G" z'd w/190 sxs cl "G" z'd w/165 sxs cl 'G" z'd w/163 sxs cl "G" z'd w/161 sxs cl "G" z'd w/161 sxs cl "G" z'd w/140 sxs cl % z'd w/140 sxs cl "G" z'd w/431 sxs cl "G" z'd w/771 sxs cl "G" z'd w/485 sxs cl "G" z'd w/488 sxs cl "G" z'd w/476 sxs cl "G" z'd w/486 sxs cl "G" Ali Perf Intervals not sqz'd have been properly abandoned with retainer and cement plug. RECEIVED JAN 2 1 1985 Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM TO COMPLETION REPORT (30) TeSted Intervals Tyonek f/8002' - 8004' w/4HPF 8088' - 8090' w/8HPF 7948' - 7950' w/4HPF 7652' - 7654' w/8HPF 7989' - 8004' W/12HPF 7989' - 8004' w/4HPF 7936' - 7950' w/8HPF 7916' - 7932' w/4HPF 7668' - 7642' w/4HPF Beluga f/7320' - 7330' w/4HPF 6956' - 6962' w/8HPF 6580' - 6602' w/4HPF 6500' - 6515' w/8HPF 6426' - 6436' w/4HPF 5401' - 5416' w/4HPF 5343' - 5366' w/4HPF 5141' - 5161' w/4HPF 5110' - 5135' w/4HPF 5073' - 5082' w/4HPF 5059' - 5066' w/4HPF 4987' - 4996' w/4HPF 4987' - 4966' w/8HPF HR. MCFD 1.2M 106 766 97.7 499 388 0.730M 1.03M 1.14M O.111M 1.80M O.112M O.112M 1.43M 1.43M 1.43M 1.43M 1.43M 1.43M 1.43M 0.476M PSI 730 735 748 710 710 725 770 740 706 655 68O 6OO 60O 672 .REC£1VED Alaska Oil &.Cas Cons. Commission ~nchorage I OTI lo'tis ENGINEEnl;':G CORPORA'rIO: ~iS'"CDr3,r'LET[gL~. GUIDE , L,01~s_ ' A HALLIBURTON Company (IEC-31 IqlEpAIILU I-tlR COMPANY l' [ il. P I-IOt'l F.,. OA i' ~. SIZE r . "~ I ,*-- ;~ ~ , .~:s~ ~3"~ ~,3 ~o Pup T+. .... -" -~j' ': :~'; ~ o~,~ ~' ~o~ ~b~~ ~ ~ ~ ~,~t~ ---- ..... I I ....... ~, [~T[a$1o,~ 3~" .... '?~" ~. ~s~ ~o,~s I t I I · _ . . ' ' ' .... ,-~ ~:'~', TOTAL ESTIMATE ~FC-2I 7.E A HALLIBURTON ....... ' "'-~ ~'"~ I ~%" I ....... ~,~.: ...... ~. ; . . ~ LINER .... -' -~L .... ~ . . ~ .... ,..~ , ...... ~ f ~,~ P"~ ' ~ ~[' ~ .... . -- . . . 'L ' : :' ~o~ ~.~_ ~~LV I ........ ~. ~ ~,+,, _~ ~%'%v ,~,~ ~ i . . -- :: ...... .~..' -- '" ~ -"' '~::': ~ ~v · zozo' J .... .~ .... :"" I ' i --.. I :: I ' ''~ .... ~ .. · -- -~ I ~' :J.::':-: t~ · · · ~,~, I '-~ ]3 -- ~" 1~ TOTAL r , SEPTEMBER 14, 1984 Mr. Paul Spiro Union Oil Company P. O. Box 6247 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. AK-BO-40076 Well: ~13-5 Kenai Gas Field Cook Znlet, Alaska Survey Date: September 6, 1984 Operator: Neal Mr. Spiro: Please find enclosed the "Original" and eight(8) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District. Manager kb/AK Enclosures ; EC'b iVED ..i i:i ~,.~ 0 ? .1~85 Oil & G~s Cons. Anchorage A N C H 0 R A (:i E' A L. A *.ii]; K A LiNII.-jN OIL C:L-IMI"ANV I<ENA I G~::'!; F= ill EL~'I ALAok.~ V E R'T' I C: A L S.';F= (::: T I (] N C A L f_':U L. A ]" E D A L_ 0 N G C k '.] ::E: L IR E: E'.A GE .__1', .......... DA]"E (".IF :F.;LIRVEY :=;EF'"FEMBER 6., .t.?F_~4 ...... C/"!M.:EU]:.A]LZ C'tN D.~]'.'E _' .......... BO S'; S_'; .G_Y~.'.;,:E!.c;C OFL]LC_ '.'='; LIRVEY_ ',SEFZ'TIEhlBER. :,"?, :l '.:.)E:4 ...lOB NLIMBER AK-BO.-4C)C)7.L-.. 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L.Y BUSHING ELEv. =' 9~.45 FT., · .L F ERA.T Ui:v, NEAI E:JZJJFL.':;.E .......... i-'n.~C!z-_LD2~ ..._____]:OTAI D :1:. REC:T ]: i3N .::.SEVER I TY RECTANGULAR F:OORD I N~TES I." E'f'~ ? 1.00" C -,' '-' - i ..... ,-.." c- ........ Iq.IR FH/~.'~UL .tH EA.:,T/WE..,T . ,. VERTI,_-:AL- SEC:T I ON 0. :2'8 6, 7 5.2 7 I,,I 3 3 5. !54 E 7 5 3. U,l. () _1. :1. '705 38 Iq '-' = ] . . o..,t. 47.i [.'-' 7:-':7.4:2: ("~ :3!:) .... --'_,'];_-:_.~':_,,AE~__N .......... '.F4.(:.~'-..,_~;~5_E .......... 820, 82 (), 22 764, 77' lq 380.06 E 85'.--~. 78 O. :? 7 79:3. 'P:2 N :39 4.59 E 8 8 6.34 4':::2(.")(:) 4. O0:h. 2'7 :_::916. ::::2 1 '7 :12 t'q 25. F:O E O. 2.';;' ,.1. 3 Cl 0 410 :'::, 7'P 40 ]. 2.9, 4 17 J. 2 Iq 26. 10 E O, O'P 440 q __41 'P'-.?.~';'_ 4107. ':Z4 1/-, .54 ' "" = ..... · __1:,1 .,.:._,, ',_:',!9 EL. 0. :31 ..4500 4'::.'95,., _'1. 1 420::~ ,, 66, 1 (:, 44 Iq 25, 89 Ii.:.' 0. :1. 7 ':":' 4299 4 P, .1. 6 41 N Y,'.:,. _1. 0 E 0 07 4600 4390 ........... 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L:..: 'F' .5 :'3 q. :'3.44 ]. 9 :36, · :,~'-'~"',:, ~ ) (') =: '= :34 ('.~ 3 .=;', 4 ,-1. '.-"._.,':'-'-',::, ] ':~ 49 . . ._1 ._1 # _ - ,,_.... .., F~?OC.~ =:'; '-'~ ':/~'~ ':-'='-" . F':(~ ~i', ."£<"~ ................ :..~.<,.,~.' / , .... .... ._m .~--',CZ, ~ ..... · ___,LN_..~..,'~'_. · . 0 N 2::::. :--:0 "- ("). 24 i',4 2:_--:. :5.:0 i:}_' O. FEi2 _ i",i 2:~',('-~ E O. 4 i lq 29. 1'.-.-; E O. 54 N '.-..'9.69 E O. :.27 1016.53 N 502.61 E 113:_::.64 1043. ].3 Iq 515· 5/_-, E 11/=,3.22 1069. !=;0 N 52:_--,'. 42 E 1192.54.__ · i?~ · · 1095 ,.4 Iq 541 06 E 1221 ) i 121.3'.9 N 553.67 E 1:25£). ~z r~ '--i .-, ;-m ........... 1171·'P4 N 57'P· i:--: E 1306.83 1 :l. 'P 6 · 6 'P N 5'? 1 · 'P 2 E 1 :_--: 34.67 1221 · ::;4 N ~04 · :_-':8 E 18_~,'-.' '9/-, 1247.A6 N 61,'3.21 E 1:3'P2.02 1274.1!5 N 6:32.05 E 1421·?0 1301.2i N . 646.29 E 1452. 1:32 ~.::. 58 N 66("~. 91 E 14:33.51 1:356.35 N 67e,.02 E 1515. 12 ].::.':84.. 71 N /_-,91. ::,1 E 1413.69 N 7£)7.67 E 1580.60 144:_--: 06 N 724· '-" ~.6 E 1614 ""~" 16,48 · lxL ~P... 6£L_E ....... ~2.52 ....... L4_72~Z.-7'.O._.N ...... .__7_4 !. 2 4 E A. I',,IC:HF.)F? A C';E ALASI<A LINIf]N' OIL COMF'ANY DATE OF SURVEY SEPTEMBER 6., 1'784 :1. 3-5 __ CCd"II'":'LIT. E'CI_[.jj. EIN..[jATE . ~ GYRC'I:~:;f':OPI C SURVEY " ....... ' .... '" .",~"" '.';'"" ,JFIB .NLIMBER AK-BO'4~}076 KENAI GAS F'IELD .::,IFF 1 El lEER , 1: ,::,4 ALASKA . I<ELLY BUSHING ELEV. = 91,45 FT, ' ' ;' -I' "..,, ._-t ' ' . VER]"IC:AI_ SECT.1;ON CAL. C:LILATED ALC. fl',IG C:LCd...~;L.IRF' I IEA.::,L RED DEF'TH ~"Y'II It~:::;E' ['":FI1117:~E' .[~ 'l'[q'l'~[ ..,~,._..~., ,,,,. ,,... ......... ..I_.m.._,.-_ _ ~ ............ , , -- ::.".';EVER]: 'TY REF:TA NL',L L Al:.,; COORD I NA'FES. i VERT I C:AL ., DEG/1 O0 NORTH/SOLrTH EAoT/WE.. T .. .. EC.T I ~.'.',NI ,,, .. 758.40 E 1683.19 775.67 E 1717.66 793.01E 1751.99 810.20' E 1785.71 827.26,E 1819.71 O, 2':'.....,1 ..~'='.. 1,74 N O, 09 i/:,20, 94 ht .6~5C)0 .... 6.i..'?j..._..8'? ......... ' 6 .1.. .!:.! 0 ,_.4 4: ............ ' .... ;~ '?, ...... ;::;'!0 ........ 1'4 :'::C), 1 ".? [':: () 3O ¢ ~-,5(), 01 _N :::44,. ! '_¢7~. . . .L' '--._,.-,,_._.,.,._ = .... 'c ........................................ · ....................... ... -.. ,-: ,.: -, ) 66 (30 ' '- '- _ , 2':.-". '? Zl-, ::: 4 ':;' _ ..... ....c.., ..: ,:: /., 61 :1... I I',1 :'30. ::'? E O, .=?2 :1.67R 42 N R/-,C) '-= . ......, ~R 7 ('1("1 ~ '-"-'" . '" .............,::, .z, ,:, U . '72 628':';' zl. 7 J. 8 41 N :30, 0 E 0 44 1706 '.':",? N ,::,/7, ..:,'-"-',:, E1918,55 A:::O0 64'75,/'_' ':.) 6:.384.24 ]. 8 ..... :ELi ................ b.l.:3(..]L, .... ().-..E. .............. O. 17 17:_-'::.-".:. 94 _N :3'~,L, '-.:':'.>_E 1_ '_.'-?_- :~ (-D_.._ _4_ -_-5_~_ ..... 6';? 0 ('1 "='- "' "' ~':,' o.:,/~.~ 64-7'F' 14. 18 1 '-' lq ::ii:c*0 Er 0:2',~".~ J. '7/-, :L 2'1. Iq ,.~'c~':.~. 0/_-, E J. '-.?F 1 ':~.~ 7 (") 0 ('1 F · ' '- '7 '""-' ':¢ ":' ::,c,c-,._, /', :I. .6574. 16 I ~z: .':, h.I 29, :Z¢,:.'.] I:< O. 1 ,Z, ........... ,:, 1.,:,,:,,24' N ...' '.--,: E '2(-)1 ,07 _7-t.g&~ ..... _/_,",__/. c.,_(.-L,__/__o ..... '___/?,., ¢! .(.: ,. . ;' _....~-_-.: ...... 1 :Z: 0 ' t',1 ..._:.T..'_.'_'.:.-_~__,__"~Zi¢;:L_J!ii ............ _(;L.._..J:f".J. ............ ;t. :__F.L;L5_.,.. 1F.,.. J.%l ..... Z~.;]-_,'.:.-TC,_.~LO_E 72 ~"~ 0 /-, "" .=, =' . . 4:3 · 954, :q".'? E 2074 6'? _ ,: ..... , 87 676,:.1-. 4.::.': :/'7 I",1. 2':?, 0 E A. 32 .1. 841 9:2 N _. . 7:2: (]. O. 69 ?..'] :[ ,2:3 6. 8 ._, ~'' .-:,. 79 ! 7 i '? N 2'::';', J. (:) Iii'" (). 41 :1. 86 ::".: · 24 1'4 96 '.-.?. ,.~'"';.,_'.-" E 21 (:) 4 . :::_ C) 74- c)C) 7046 '7/-. /. 9 ?, ~ :_:.: :L 17 · 4 N '.-"':~,/-, 0 E..". 0 '-' '~'' ..- ....................... , ~:,:, ;I, ::-: '7 4 . 0 :2 N ';-'?:~4, O1 E '.-'1:34.3=;',__ -750C~ 71'42.40 7C~!""~('; '-?F, :1. 6 '='"' .......... .~ Iq 29 '-":, 9 ... '-' · , ,:, .-. I:.E C) '-"-' , .,:. ~. i 19, :'::7 N 99:::, 50 E · 21 .. 7/-, c)(-} -"-"-"-' 1/-, 4:3 N 29 :::'::) E 0 1 = / ...' .:,,:,. 1:37146 /-':' · _, 1 '.-.? 44 44 N 1012, 91 E '.-"I ~ ? 43 7700 '~R'-"-' ............. 1 0:::: N __ / ._ ._-,.:,. 9';--: 7242 F-; 4. 1/-, 2:3 N :'::: C). 99' E (3. :37 96'? ....... '-' ..... '- .__ '7 :--: 00 7 42'i:?. :38 7:3:38.4:3 16 3 :'-': N :3 C,, 8'? E (], 2 :[ 1 '?'? 3.47 N 1041,68 E 2249.2'2 7 '? 00 '7, .~_ ,..'--.'._.-5 · 7 L:: 74:34-. :::: :':: :1./:,_ '-'...- .:,'-' Iq :31,30 E O, 19 20 :L 7.76 N 1 A. 5/-,_, :'~ 3 E 2277 · ,.,.:,:' '-' ;.--: 000 7 e, :21 . 67 7 ~_ :::_ (').. 22 1 A_ :':'._ :::_ N :2. 2'. (] .... E c). 25 2 (') 41 . '-?.. 1 N 1071 . 21 E 2 ::: 05, ,_,._,':":' 81 C) O 7717 2C) '-' '-' -=' 75 ]. 7 4-::: 1'4 :':: 1 19 E i '-'-' 1 /E,,.'z, 2067 07 N 10:::/-, /:,'.-7~ E ~'-"-":'~.:, 3 . . m - ,, ,, -" / · 8120 77:36,22 7644,77 1 ::-:10 N :.30, 60 E 2.02..' 2072, 37 N 1089, 86 E 2:341,48 THE F:ALCULATIr-IN F'RF~CEDI_IRE$ ARE BAF;ED ON Tide USE OF THREE DIMENSIONAL RADIUS OF CLIRVATLIRE METHOD. :,h:LEF~F_W_=oLI,.I t,I'-'1 I,.-L ..... i~F.t.V.E.Y.TN£~ F':r'zNP~d~Y t:~ I',.I '2 H C.i IR (:.~ G E.: f:~ L F.1 '..'.'-'~ I-::: (:.1 U N ]: 0 N Iq ]: L C 0 h'IF:'F:~N Y _ 1 ;q-. !--i I..'::IEN~ ]: GI~L'-.; F']:L-':I-F~ · I3 A'T' E 0 F:' '.::; U I:;~ V I-Z Y '.:-; E F' T E M B E R 6, _1. 9 :.'.'!~ 4 C f'~ Iz! F' I 17LFZCEZJ3N__DA_T E · : SEPTEHBEI:~ 9, 1':':' ,.lOB IqUI"IBFR: ~.h.K'-Bo'q. O076. ..: ' : I':::E L L Y ~:':' ' ' ' "' BLI,=,HIIqG:".:ELE:V.,.='':. 91.45 FT. · . : '] I I',lghi ' .. ,. . :: .... IN]"ERF'L-ILATEi::~ VALLIES FOR EVEN 1C~O0 F:EE"F OF MEA"".:,I_II"_LWEq [EFIH~ -'" HE(qSURED ....... DE.E'_T.H V E R T I F': ,q L., V E R T :1: C (..] I... R E C T ~.~ hi G i_1L (-/IR C:. .... "~ i"~ R B :[ i h'.t lx .... E..:,"' H D- T VD . · VER'" '"'[' I F'..(~L I] E E'_TL-t ._, ........ DEF-ZH ...... .__ N]z! [.'(T H./'~ L-! U 2]-i ..... ~LT_Z 1..1,~_..:, T Et I. F F E R E N _. E ' C FI R R E L-: TI 0 N O. O0 O, 0,3 C). 0 U 2~. :'3 ::_': Iq :q 4... 2 2 E .r'5.7 5 .'=;. 7 5 ":' ' q':" :h.I '~ '"C:,. ,/:,6., 7'":1- ~ ' ' ,'_',0 ':."':') ,.,61 · ,...., .,. ,:,. 7'7 E . . ' '. · · "" ('>75. 527 N 335. ~;..'-'1. IE .129"07 6:3.1:3 ..: ,:~,¢..":, ~.':, N ........... .47/.:,, :=i-,":,...._ ..................... E _~.c,.."' '-"-' ,_..':i':'.,_, ......... . ...... ....... 5 .z~.7:L'-' ' ........... , ................................................ · k-~ "' ~.-L.".,) ............. · .............. 12:21. :i~4. Iq 6 C) 4. L:i:L'-.': FZ 2 2'~. :z:4. 4:2 · 76 `1. 5C)2.95.2 N '75S. 4C) F 27S. 2'.2 ..52, '-.-~2_z.l..,, ?i;~_f:: '--.~:_::4_,_F_,'5/__ ...... .L=i&. :L7_ 1 C) 7" l. 21 E 5:7t-3, :':::3' 4:i: · 9 5 THE CALCLILATION F'ROC:EDLIF~ES ARE BASED FU',I THE USE '.'iF "I"I--IF:<EE DIHENSIONAL RADILIL:; OF L.I_IRVATLRE METHFiD Lb[El ............. N CH 0 R A G F " " ...... [:..~1_ A.:,I...p~ UNICIN CIIL CEddF'AI',IY DAT'E FIF :3LIRVEY SEF'TEMBER 6., 1':784 q '-' . " ....... ' KENAZ eA.:. FIELD .::.El:-] El IBER ,. ' ALASKA KELLY BUSHING. ELEV. = '.'.71.45 FT, JZ~:zEE~ Z.O EL-.lxJ E A L ..... . ............ . ............ I I',ITERF'OLATED VALI_IES F'OI:-~ EVEN 100 FIF'ET OF SUB-SEA DEPTH ';>1 'F'i. 4.5 '" , () . OC.~ () .,.~:-l/-.. S () . OC~ W, 0.00 (i .00 · ': m.m4_.L:_,.: -q,_(u ("). 0 5 0.01 0. 1:3 0 . ,.o'3"" O. 44. 0. ,:.1'-' 7'.-72 7':? 1.45 8?4 891.45 9'~7 991.4.5 .1. 09' 1.4 5 1 1 '? 1.4.5 1 ""'-' ,~ ;' 1.4.5 700. O0 800. O0 '~,o O_..p.o ............ 1 GO0. O0 1 100.00 1200. {"~ 0 o..'-. ~6 N 52.74, hi 1:3.24 E 21. ?'r? E ':":' ~ 8'7 E 7:=:. 44. N 107.72 N ..~] 1;36 ._4 Iq 9.80 14.97 .1. '.-?. 96 r,.). 0.,::.. 1,64 ,, . 2.76 4.14 5.17 4 ,.?,z/ i 416 1:3 ? 1.4..5 :I. 52:3 14-'.~ 1.45 16:30 1591.4..5 1300. O0 J. 400. O0 1500.00 1600. O0 1700.00 J. 738 1:347 J. 671.4.5 1791.4..5 1 d o. '76 N 1 '.-.?'F'. 12 N '--":'.=, :1.2 N 272.34 N :--:10.01 N "1" 05. J. 0 E 121.6,9 E 5. 6.51 7.57 1:39. ('-~ 1 E 156.4:3 E 47. :34 55.61 8. ICJ 8.27 UN I ON F'~ I L COMF'AN Y ~l, 2,- 5 I<ENAI GAS ' I:: ;I] ELD. · ..... ' : '", ALA~--;I<A ...... ;-,E:EF~E'..Y_.-_._.;,LIN__WEL:= ::~URV :.E~Z.NG CI'IMFL~NY ANIZ:HIZIRAI3E A L r-'~ SI< F4 [;ATE iZ~F._,,='l ..... IR'VFY_ SEPTEMBER .6, 1'.~84 [":r[Mr--'-'UT'(~"F 'r ON "' ' '- "'-' "":','~'* · JOB' NUIdBER':AI<-BO-40C)7/-', · , ._',EF 'i EMBER ~'/, ~..'.. ,=,'-,. . .. · · KELLYBU.=,H'"-' INF'.~ ELEV" .:i.:-'..: ')! ,45 Fl', ' , ' Di~.-~:EEo-~.ZDF-c_-] .MI. E ¢J l . INTERF'C~LATED VALLIES FOR EVEN .1.00 FEET OF' SI_lB-SEA DEF'TH MEASLIRED ......... [..EJ.=_]_H. 1 R .11: SUB-SEA TOTAL VERTZ C:AL VER"F I C:AL REL. 1 AN .:,I_II.F~F~ CO01"-(I:~ I NA1 E.:, I"I£1-TVD VERT I C:AL I ~ i ' ' ' , i "' i ' ' ~"'. i~ "' i'"- "i~*. ·" ' ' I · ~. ~ . . , ._:.[[EF_'I_IJ_- . _IZE.F_LI:.B ........ I~:!BJ:_tJ~.4L!]lbl_,__..E,~-:LT_/_~,,I .:__[~_EE~E . C ~E CTI 1':.'~55 1891.4.5 18(.")(:). 00 ' :346. :.-::7 N 173.64 E 63.57 7.96 2062 __:1. 991. 4.5 '"'1_'~C)_(_)..,_(:_).~ ....... :E,'_,'.:-~L, 56 Iq ~,'F'OLL6,:.-/ :E · 7:[, 1_1 7, 54 21/::,'..~ 2091,45 . 20(:)0.00 4"17:, 47:N 207, 65 E 78, 38 · 7.27 2276 2191.45 2100.00 451~'97 :N 224.52 E 85.50 7.12 ~.83_ .... !.: ~:~.1...~_4.-~5_, ___:_'=220-0.. 00_ ...... . ............... _4_8 S ~_Z.~:N.-- ........ Z,._2~4..:L.,:I_ '~.._F ..'.~2.._:2,:~...,_~ ............... 6_~.86_. 243mF~ 2:3'.-? 1.45 ':.2300.00 ' 518. ~'4:', N 25'7.7:3 F '.:.>'?/. 02 6./_-,6 25'.~¢7 24'?¢1.4!5 2400.00 551.7'.-.-¢ N 274.. 2:3 E 105.55 6.53 ..... ;T'~7_.Q.~ 2~51.~..5 _~.:'~0. "~_ ' _ ..... _~;E,'4,. 62 N .... 2'.:.~0.71 E 112.07/ . 6.54 2810 2671.45 2600.00 , ,'.617,38 N 307.04 E 1 ':?¢~ 16 27'..;' 1,45 2700.00 64'?, ~m5 N 323.10 E 124. 'F'7 6.3'.~ · ' '='- . . '""r-~' 7",.--.~ . · :3128 2'.-.-~'..:,' .1. 4..:, 2'.;.' 00.00 714. 06 N .:,._ 4. F: 1:37:2:6 6 18 '-"-' '-' . / 4._. 61 hi :370.51 E 14- :3.4 C) 6.0:3 · :, ..- o 4 ::: O'F~ 1 · 4..5 ::: 0 (') 0.0 C) -' ~ :~:3_.4-C) :.-_-: q~i_~zb. SZ_ :B100. (:)0 . 776.72 N :'4:s:/_-,. 02 E 14'P.27 5.:--:7 -3446 32'::~ 1. · 4.53200.00 8C)7. :34 N .4. C) 1. . ..'"":' E,_, . 154, ':/6. ~-,., · :::_,.5.~_ 1 ._"~ :::. '~. 1 · 4.5 :::_ :2, 0 (')., 00 :B 37 · 63 N 41 E, ,1 ~¢. E 160 · 51 5 · ._..,.~ =' · '-'-,~,,..,7 ~' '-'"' -':'*; '~ =':34o0,00 :_=:67 ¢:_.5__~ _a.:,;~(). 72 E 16.=, R/-, 5 '-~/- :.-:: 762. ._,-:, ._F, ':/.. 1 , 45 :'::.~i (')(') .0 ('). :B 'P 7 .23 N 4. 4- ?';_, (")_ 4 E 17 :L . 1 :--: . ._.=,.._,..':' '-" · .~1 '""1 /'1 / :.~: 6'? 1. 45 :3600. 00 'F'2 ~.~1.4.:, N 4. -=' - . _ .:, .=~. F) O E 176 · :30 5. 1 i UNIOIq OIL "]'" L.L 19F Ably 1 ':,- F-] KENAI GAS FIELD ' 'ALASKA :::;E'-'ERR~Z_~_SLII;I NELL =,LIIRV. E ¥ I I,JF-i F::Ffl,'IF, F.~NY:' ]"!"::~..::::::: :': ::::; ":':.:.' :' A N C H 0 R A G E '- "' AL.A.=,~...A DATE.CtF E;LIRVEY SEPTEMBER 6, 17:-34 C~ 1213~ T I ON [;.AZE ::. N -IMBER Ak:~BO~40076 :~:::'.'SEPTEMBER 19:B4 ~ '-lOB: I ' '" KEELY BU.~HI. NE4.'ELEV. = 91,45 FT. .. . ~~Z.I~E. AL::: ;:::::' '. . .. I lq T E R F' L] L A T E D V A L LIE S F.- 0 R E V E N 100 F'E E:' T ElF.:,L'-' I B-oEA'-' ' K~EF' ]'H . , ..: i RUE · . ,..-.,IJB-,:. -' I '' '" -" 'i-" MEA~LRED · VER rI_.AL VERTI_.AL DEF'TH ' - -' ' ~'"' '- ' . . DEF ] H · . 'DEF TH' N~R-'.TH?'";Ou '.TH'." T/WF£.C';T~"::"!.D:i:FF:ERENcE '-'"-" :3972 ._',7:, 1 4.5 '-'-~' ' , .::, / (.)U ....... 00 .'. ,.,.:, 3/", N 472 E :1. 81.....- :,. 02 4-0 77 :::::: 9.1. . 4..5 .... ~ :3991.45 :3'.90(') ..... 00 1011 8.4- Iq 500 .... =,.j'~ E IeO. 94 , 4.. 771:, 4287 4091.45 4000~ O0 J.'0:3'.:.~, 70 N 51:'3.88 E 1'.-75, 6:3 4, E,~ · ...................... ~..:?..:< 1. .4_...!..?_ ;[.. ,. 4 ~ ........... _4._!.0!_}......(;!!:!. ....................... _.l_<;L6...7..._.. :_:::_.':_":L..N .......... 527. ::':7 F '?(lC, 2.~] '4._"-A~.-C:: : zt. 4.'.-76 42'.-? 1,45 4200.00 10'74.55 Iq 540.5::: E 204, 73: 4.48 4/.,00 4.:::91.45 4:300.00 1. 12:1_ · 54 N 55:3.7]5 E 209, l 4 4.41 4704 44'.:.;':1_. 45 44.00, O0 114L=:. ~ :.--.'~ Iq 5/--,7, 07 E 213, 4.8 4.. 34 4.56 4. o6 5.09 5100. O0 1338. E: 1 N 66/.,. 4:2' E 245.81 5200.00 1368.:36 N 682.62 E 251.33 . 5300, 00 1:398.66 ,N E, 99.29 E 257, 1'4 5400.00 1429,74 N 716,,,6,7 E 2/.,3.29 5500.00 1461. 14 hi 7:::4.56. E 2/.,'.-?, 62 6.15 6.3::: ) ) .......................................................................................................... SF.::EI:;:IF(Y._-:'~UN. WELL.._o. LIFLt2E..YZNL, r_':OMPAN_Y A N C I...I 0 I::;: A E.i E A L. A'.::; K A U N ]: ~-~lq F'~ I L F: 0 M F'A N Y ] :_:~- Fi I<ENAI GAS F'IELD ALASKA D A T E: 01:: SI_II::~ V E Y S E F' T E M B E R 6: 1. 984 I-:1-11 II- I I I ¢..-, I T A i',l Ti ~.':.i'T' F: .::,EF" .... ' .... I Et%F~E.R"" 9~ .1.'P84 ,JOB NUMBER AK-BO-4C~076 KEL_.LY' BI_~,HINFi ELEV~ = ..... OPgRATOR-NFAI · IN]"ERF'nI_A]"I.::i:D VALLIES FOR EVEN ioo FEli.:"r OF SLIB-SEA DIEF'TH 'PI. 45 FT. .= LIB - .=, I:. A '1" 0 T A L TRUE '-; ' ' ...... .. MI=A.:,L REB VERT' I C:AL VERT I F:AL REC-I"ANGLII, AR ' COORD I NATI:7. S MD-TVD VERT I C:AL ........ DE.F_']._bl .......................... LE_Fi] J.-I ........................... D.L.E. T F.~ ............... N O[~ZHZ_'.::~ttZT}:L_. ....... :~-~L]7__t~.~;T__D I FEERENCE L':OF~REF:T I ON ,'2,4.99 61. 91.45 /_-,/-,05 6291.45' /: .... , .?. ~- __ .............. ~,.7__1_:L ..... &.:_-, z1_..__4 ._ 6816 6491.4.5 6921 /_-,591.45 ................ ZO2Z ........... 71 '-"-'.:, ... 6791 .4..5 .r.- .-, ~ .'-, ,-, .":, 0_(!Z_4 ........=.';7.,:,, ~ 4..5 ""5'";.j~"2L, J'i~L. . ,1, .-,,: .:. ("~ 7 N . 7 7 .1., .'1~ z.,:,~. 77 6 _1. 80 · ''~ "' '-?" _ ..... · ._,,=, .-..,. 45 !~:-%)(]. 00 1 E;?~A, 7'7 N. /-, ,' ,=, 7 .¢,,:,, o 1 '. 4. 5 ~:';'-}' 0 o. ('1 o 1 = "" '- '-"-' ' ....... . .... ..:,,:,/. ::' o .N '-"--,'-' ~'- ' :1./- 1_ o ,.~,::¢ .6,--, .-: .a60 '~_/... _4,:, 600 0.00 ........... ' ................................ :.,.~..~. ~".. ~....~o _ ,¢ .................... 6.1. 00.0 (] 1649.87: N 620 (] (")0 1 A 7':> '- ~':'~ ...... .".z ....~ N /-', ::-,'0 (). ("~__(-)___ ..... _'__i7_0'?__._::_:.8_~.4 .......... . 6400 00 . 17:2::3.51. N ,..:;.500.00 1767, 2 (} N .. ./-,/-, t')C_~ 0 (")__i 795,, ~ =' '" ':;'-'"'" ' ''? ..... '"' = .... ~_._bL ....... ;L'.,:L,'2.,,. 7.../ ............................... __,.:,. c:,:-, - 7.'_:~ 670 (). ~")0 .1.'",:, ='-' .-','-' · ':' .... .=; N 'P/44 . ,::,'"" ..'"-' E :340 . ~::~.. 'V. . '='- - - . '-' %' · 8'7 . ':~4.=' · 9 C) 7237 6::.'.:':.? 1 4-o 6:::00 OC) 1,: .... 1 N 'P60 41 E ._ - ....... / .-',~ .......... 6 .~0~_,__.4_~ ..... 6.~%u_ U.U ................ 1 :B Z2.., 20_J',l '.:.;_' 7_5.,. 61 _E ........ ~ 7446 '7091 45 7C~00 oo 1'::/0'= '~' .... '-'=.=; 30 ...... Yc, N o90.79' E .:,,.,.~ ~ ._,._, 1 71 ~. 1 . 4=..., / I AO. 00 1 '-'~:::"..~ ...... '.':..'A N 1 o" u' ._, = ..... 5;' i E ':~F.,'-?.. ::a'~~. ';'~ ='=' -"-'":~ ~ = 7 ~ ~ ~ ~')("1 ' ':/~':' ':'"'-" (1~2Cb_:3'~_ E ,-, , , · - , .~ ...... · ........... __1: ,_~,_.~., . N _L ...~: ......... ./..~ .... _.L L-t [ -' ....... / 7._, .-., 75: 'p 1.4''~c, 7 :Dr 00. 0 .... 0 .1. 9 :: ::: · 67 lq :[ (-) .... .::,' .-' = · ::31 E 7864 74'? 1 .... 45 74. 0 (') 00 2 C~ 09 1 .:'-' N i (] 51.0:3 E _5~ 21 5.16 5.01 A. Z7 4.6,2 4.50 ...4~_41 4.31 364'._._21_ ..... '.368.4.6 :372.77 UN I ON FlIl_ L.L. NF ANY 1 ":'-.=, A N C I..,I O R A F:i F' A L A E; K A " .... ' '~ ' , 9E~4 DA]"I:" FiF '.::;LIRVEY .=,EF TEM/ER 6 1 SEF'I"EMBER 9, 1984 ::' '.."OE, NUMBER AK'BC,-40076. .. ~ I~i'EL~Y. BUSHING ELEV'..:= 91.4.!5 FT. · '" I '"" .... ' \ I<ENAI GAS FIELD AI_AoI',..A I I',IT'EF:;:F'L-q_ATED VALUE.'."..'i; F'OR E-.VE-.N iF)C) F'.EE:T OF E;UB-SEA DEF'TH , ·.: . TRUE '.E;UB-.:BEA: :': :. ::i:::]'OTAL, ·. ' '. ME'ASLIRED'':: VERTIC:AL ' VERTICAL RECT~i"iE'iLILii:~F~' c:OC, RDII,,!ATES'' VERTI,::AL'.:..::'::~':::i::. 7 '.7/ ....../-, R 7 ~ 91 .45 -7 .:,' ..... (.) u . () o_ ~:'-"u .:.'-' 4 . .,:'-' .::,"-' N 1 o ...... r-, 6,. 4 ]:~ E :377 ,02 ::::o7'2 '~/: '-'" 45 -%A(')o. ().o 206() 0() N ' "'"'-' ~ ...... "-' * P]" .... / :' ~' ~ ....... . .... ~J4.'='.~~[= '",=, 1~(.)'-' ' 7'7:36,~'°2= ' / o44,77' · .... ~.'0"=''''/,:..::,'-'/ N 1U' '"",=, :~. ,.,':'/-., .E..: . .:,'"~ ~'"~'~..,./~"",=, · , . : , ' THE F:~LCl ILATI'F'~N PRF,":EDi IRF]=; ~h=;F A I ZNEAR ";[.blTEB'.F3;d..~:E.I.OI.q...BE]]NEE!~_ ........................... THE NEAREST 20 FOOl' MD (F'ROH RADILIS OF' CLIRVATURE) F'OZNTS Union Oil Company Boss Gyroscopic Survey Job No. AK-BO-40076 Well: ~13-5 Kenai Gas Field Cook Inlet,' Alaska Survey Date: September Operator: Neal Scale: 1"=500' 6, 1984 TRUE NORTH O0 8i20 500. O0 000~ O0 -50~. O0 l_500. soo'. oo ] 00~0. O0 O0 HOR[ZONTFIL PROJECT ON Union Oil Company Boss Gyroscopic Survey ,/ob No. AK-BO-40076 Well: ~13-5 Kenai Gas Field Cook Inlet, Alaska Survey Date.: Sept ember Operator: Neal Scale: 1"=2000' 6, lg84 0.00 2000. O0 4000. O0 6000. O0 8000. O0 : ~ 8'12o 2o~o. oo ~o~o. oo VER T I CFtL PROJE C T I ON for timely ccmpliance with our regulations. to d:eck Operator, Well Nam~ and Number . Reports and Materials to be received by: Required Date Received Remarks " · Cc~::~let~.on Re~:ort Yes · .. ,/-~,,'/~c-- o ~ :. Well History Yes / _~. ~F~~ " ~ y ' ' · ;-~a~ ~' , .... ~ ~/~ _p i _.~_ ~ !~ . ~ i, . , · , Core ~scr~p~on -~..~ .... ~,/ , ~* .,, Drill St~ Test Re~s ~d~On.'T~t Re~rts 7~ /__,~f r~~ ..... ~/~ , , ~ - · , . ,, ,, Digit.iz~ ~ta y~ .... /~_/~_ g~. ~)< . ,. Union Oil and Gas ["--"ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union January 15, 1985 Hr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KTU 13-5, GPS 32-13, and G-29 for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/ti Attachments (5) Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED JAN 1 ? 1985 Alaska Oil & Gas Cons. Commission Anchorage ,~-~ STATE OF ALASKA "-" · ALASKA .._ ,L AND GAS CONSERVATION CO,,~MISSION M NTHL¥ R P RT OF RILILIING AND WORI OVER OPIERAT ONS 1. Drilling well [] Workover operation [] 2. Name of,operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99'502 4. Location of Well at surface 2383' S & 1380' E o¢ NW CDr, Sec 13, T10N, R12W~ SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 99' MSLI A-028142 7. Permit No. 84-108 8. APl Number s0- 133-20370 9. Unit or Lease Name Kenai T¥onek Unit 10. Well No. KTU 13-5 1 1. Field and Pool Kenai Gas Field For the Month of December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Rigged to standby, Well on extended test ~ 2100 hrs. 12-22-84 Released Rig 01-04-85 EOM=8020' RET/8232' TD 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE RECEIVED 15. Logs run and depth where run Denslty Log F/BTM - 7882' .JAN i 7 1985 Alask8 0~1 & L~as Cons. Commission Anchorage 6. DST data, perforating data, shows of H2S, miscellaneous data Reperf'd F/4987' - 4966' 4/HPF 5343' - 5366' 4/HPF 5401' - 5416'~4/HPF 6580' - 6602' 4/HPF 6956' - 6962' 4/HPF 7320' - 7330' 4/HPF Sqz'd f/7989' - 8004' w/98 sd of 40-60 sd 7936' - 7950' w/98 sd of 40-60 sd 7616' - 7932' w/98 sd of 40-60 sd 17. I hereby certify tha [he for ing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting T~TLEENVIRONMENTAL SPECIALIST DATE 01-15-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duphcate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Union Oil and~:Gas D ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union December 13, 1984 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001Porcupint Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KTU 13~5, GPS 32-13 GPS MUCI-1, KU 43-12, and TBU D-43 for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/ti Attachments (5) Very truly yours, Lawr o~~0-.~utting ENVIRONMENTAL TECHNICIAN STATE OF ALASKA ' f .ALASKA ~,iL AND GAS CONSERVATION COMMISSION MCNTHLY REPORT OF I RILILING AND WORIROVER OPERAT iCNS . Drilling well [] Workover operation [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address P0 BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface 2383'S & 1380'E of NW Cot, Sec 13, TiON, R12W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 99' MSL I A-028142 7. Permit No. 84-108 8. APl Number 50- 133-20370 9. Unit or Lease Name KEN~ TYflNFK IINTT 10. Well No. KTU 13-5 1 1. Field and Pool KENAI GAS FIELD For the Month of November , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM = 8063' Ret / 8232' TD 13. Casing or liner run and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE RECEiVeD,. D "' ~ska 0il 6. DST data, perforating data, shows of H2S, miscellaneous data Perf'd ¢/6324'-6330' w/4 HPF: Sqz'd w/170 sxs CL "G" 6370'-6376' w/8 HPF; Sqz'd w/]65 sxs CL "6" 59].4'-5924' w/4 HPF; Sqz'd w/].63 sxs C[ "G" 59Y4'-6003' w/4 HPF: Sqz'd ~/].65 sxs CL "G" 5401'-5416' w/4 HPF: 5343'-5366' W/4 HPF: 514].'-516].' W/4 HPF: Sqz'd w/80 sxs C1 "G" i 5].10'-5135' w/4 HRF: Sqz'd w/80 sxs CL "G" 5073'-5081' w/4 HPF: Sqz'd w/70 sxs CL "G" Sqz'd f/647~'-6563' w/~40 s×$ C]. "G" 5059'-5066' W/4 HPF: Sqz'd w/70 SXS CL "G" 6476'-6563' w/161 SXS CL "G" 4987'-4996' W/8 HPF: 6500'-4996' W/~80 SXS gL "g" 17. I hereby certify that the foregoing is true and correct to the best ,,S,CNED ~:~'~,'~-~,.,.-~'",/~'~,~*~f]/c~ ~"-~',~/~"ENVIRONMENTAL TECHNIC~/~E z2/z0/84 NOTE--Report on this fo~m ~ required for~/~.a~h calendar month, regardless of the status of operations, and must be filed in duphcate wit~ lhe AlasKa Oil and Gas Conservation Cmmission by the 15th of the succeeding month, Unless otherwise directed. . . Form 10~04 ~ubmit in "'. '~" STATE OF ALASKA - ALAS¢-'],',. OIL AND GAS CONSERVATION '3MMISSION MONTHLY REPOR = DRILLING AND WORKOVER OPERATIONS 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-108 3. Address ! 8. APl Number PO BOX 6247 ANCHORAGE AK 99'502 50- 13;3-20370 ~ 9. Unit or Lease Name KENAI TYONEK UNIT 4. Location of Well at surface 2383'S & 1380'E of NW Cor, Sec 13, TiON, R12W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 99' MSL I A-028142 10. Well No. KTU 13-5 11. Field and Pool KENAI GAS FIELD For the Month of. OCTOBER ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM = 6406' Cmt Ret / 82;32' TD _ 13. Casing or liner run and quantities of cement, results of pressure tests NONE 4. Coring resume and brief description NONE 15. Logs run and depth where run CBL f/8045' - 4000' Alaska 0il & Gas Cons b ' ', 'l r--, Al,(,,...,, 6. DST data, perforating data, shows of H2S, miscellaneous data Per¢ ¢/8045' - 4000' w/12HPF 7989' - 8004' w/ 4HPF 7936' - 7950' w/ 4HPF 7916' - 79;32' w/ 4HPF 7668' - 7642' w/ 4HPF Perf/7520' - 7502' w/4HPF & SQZ w/197 sxs CL "G" 6956' - 5962' w/8HPF 7320' - 7330' w/4HPF 6580' - 6602' w/4HPF 6500' - 6515' w/8HPF & SQZ w/90 sxs CL "G" 6426' - 6436' w/4HPF & SQZ W/134 sxs CL "G" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~ ~ TITLE ENVIRONMENTAL TECHNICIAN DATE 11/14/84 NOTE-Report 'on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Union Oil and Gas~:~.',vision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL October 18, 1984 HAND DELIVERED TO: William Van Alen FROM: LOCATION: Anchorage LOCATION: ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen N. L. Gilmont Alaska District Transmitting: One (1) magnetic tape and verification listing - Union - KTU 13-5 ASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: ,~-~, STATE OF ALASKA f', l/~ ALAS. J, OIL AND GAS CONSERVATIOh. COMMISSION MONTHLY R PORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well IiX Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-108 3. Address 8. APl Number P.O. BOX 6247 ANCHORAGE, ALASKA 99502 5o-133-20370 4. Location of Well at surface 144'S & 4169'E of NW Corner, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pad 99' MSL I A-028142 9. Unit or Lease Name KENAI TYONEK UNIT 10. Well No. KTU 13-5 11. Field and Pool KENA! GAS FIELD For the Month of. SEPTEMBER ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks EOM=6066' Ret' 8232 TD 13. Casing or liner run and quantities of cement, results of pressure tests Ran 9 5/8", #47, N-80, butt csg to 8232' w/ 1600 sxs C1 psi - OK. "G" cmt - tested to 5000 14. Coring resume and brief description Shot 45 swc & recovered 41 15. Logs run and depth where run Ran DISF/GR/SP/BHC Logs f/8204' - Surface Ran VDL Log f/8204' - Surface Ran LDT/CNL/GR/CAL Logs f/8204' - Surface Ran EPT Log f/8204' - Surface Ran CBL f/8113' to Surface 6. DST data, perforating data, show6 of H?$, miscellaneous data Perf'd & tested: f/8095' - 8091 w/HPF & Sqz'd w/148 sxs c! "G" 8002' - 8004 w/HPF & Sqz'd w/148 sxs cl "G" 8088' - 8090 w/HPF 7948' - 7950 w/HPF 7652' - 7654 w/HPF 6515' - 6517 w/HPF & Sqz'd w/143 sxs cl "G" Perf'd & Sqz'd -1/. I hereby certify that the foregoing is true and correct to the best of my knowledge. f/7518' - 7520' w/41tPl- & JOO sxs cl "G" 7335' - 7337' w/4HPF & I45 sxs cl "G" 6116' - 6118' w/4HPF & 190 sxs c] "G" 5054' - 5056' w/4HPF & 431 sxs c] "G" 5008' - 50~0' w/4HPF & 771 sxs c] "G" 4975' - 4977' w/4HPF & 488 sxs cl "G" 4895' - 4897' w/4HPF & 476 sxs cl "G" 4698' - 4700' w/4HPF & 486 sxs c] "G" 4998' - 5000' w/4HPF & 485 sxs cl "G" TITLE Environmental T~r_hninian DATE 10/07/84 NOTE--Report on ~his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 , Submit in duplicate ~. STATE OF ALASKA -.--., ALAS' ] OIL AND GAS CONSERVATION ')MMISSION M?NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~D ilingwelll-~ Workover operation E] 12. Name of operato~ ~ -- 7. Permit No. [ UNION OIL COMPANY OF CALIFORNIA 84-108 '3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20370 4. aLtOsCua;¢:cneOf Well 9' Unit °rKL~aNs~a~;0NEK UNIT 144'S & 4169'E of NW Corner, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pad 55' MSL A-028142 For the Month of .~.IJGUST 10. Well No. KTU 1>-5 11. Field and Pool KENAI GAS FIELD ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ® 8/14/84. EOM 8108 TMD 13. Casing or liner run and quantities of cement, results of pressure tests Drove 20" csg to 136' PT, 111' GL Ran 13 3/8", 61fl, K-55 butt csg to 2500' w/1300 sxs cl "G" cmt - tested to 3000 psi OK. 14. Coring resume and brief description NONE RECEIVED 15. Logs run and depth where run NONE SEP ! 4 1984 Alaska Oil & Gas Cons, Commission Anchorage I 6. DST data, perforating data, shows of H2S, miscellaneous data Sqz'd 13 3/8" shoe w/450 sxs cl "G" cmt - tested to 2500 psi - OK, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED /~4,'"-~ C'~~'~ T,TLE Environmental Technicia0ATe 9,7,84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA .... ' ALASK~,'OIL AND GAS CONSERVATION L, JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-108 3. Address 8. APl Number P 0 BOX 6247 ANCHORAGE ALASKA 99502 5o133-20370 4. Location of Well 144'S & 4169' E of NW Corner, T4N, R11W, SM. 5. Elevation in feet (indicate KB, DF, etc.) PAD 66' MSL 12. I 6 . Lease Designation and Serial No. A-028142 9. Unit or Lease Name KENA! TYONEK UNIT 10. Well Number KTU #13-5 11. Field and Pool KENAI GAS FIELD Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing r-I Stimulate [] Abandon [] Stimulation [] Abandonment L-~ Repair Well [] Change Plans [~ Repairs Made [] Other ~ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following procedure is being substituted for steps 6, 7, 8, and 9 of the Permit to Drill as approved on August 2, 1984. i. Drill 12 1/4" directional hole to + 8350' MD, +. 2. Run logs. .- 3. Run and cement 9 5/8" casing @ + 8350' MD.~ Verbal approval received 8/30/84 from Jim Tremble to Gregory Terzian, Union Oil _Co. The surface coordinates should be corrected as shown on attached survey plat.. ,'~P[~ I14.1 Lerel:~ certify th~at t~l~is J,l~d correct J~llthe best .of my knowledge. si~~'~'J~_~ _~R. CAL'[E~E~-~'~" Tit,~-- e DIST. DRILLING SUPT. ~liP~space below for Commission use AlasKa Oil & Gas Cons. Commission Anchorage Date Sept 3, 1984.. Conditions of Approval, if any: ttRIGINAL ~ltlilliO I! LIIltltI[ 1, SIIITA Approved by COMMISSIONER Approved By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W.C.~o '~1 ..~ EAST ~ NW. Corner, KTU 13-5 (Center of Cellar) Sec. 7-- ~ Drill Block Let. 60°27' $4.070" N Long.151° i 6'08.952"W X = 27'0,908. ;50 Y = 2,$62,070.01 o z 4169'(N.T.S.) Lat. 60°27'$2. 640"N Long. 151°14'45.814"W X = ;~75,073,86 Y: 2,361,845.20 LEGEND AND NOTES I~Found G.L.O. brass cap monument All bearings refer to the w6st line of Section 7 as being North. Top of gravel pad elevation is 77.2 feet above M LLW of Cook Inlet or 66.1 feet above Mean Sea Level. Scale I": :500 ft. B~sisof coordinates is USC&GS Tri Station AUDRY in ASP Zone 4. /eX AUDRY Lat. 60° :50' 50.599" N Long. 151° 16':57.445"N X = 269 ,~ 866. 75 , Y = 2, :582 , 045, 4?_ Reference Bearing = Power pole with loth bears S74°:50'?0"W at 680.44 feet. -K.T.U. 13-5 UNION PREPARED FOR OIL COMPANY OF CALIFORNIA OPERATOR SURFACE LOCATION: 144 feet south and 4169 feet east from the NW Corner Sec. 7, T4N, RllW, ~.M.~ Alaska. ' Surveyed by: McLANE and ASSOCIATES, INC. Dote of Survey: August 2, 1984 Bk. No. 8:5-32 ~...¢, ..... ...% .... , ........ .:,...~ °. S r: p 0 5 1984 ;.~a~a Oil & Gas Cons. Cemmission Anchorage Union Oil and Gas DivJ.c..Zon: Western Region Union Oil Company of ~,alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen J. R. Callender District Drilling Superintendent Alaska District August l, 1984 Mr. Mike Minder AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Minder: Per your telephone conversation with Paul Spiro on Ouly 31, 1984, please note the following ammendments to our Permit to Drill for KTU 4.) Surface Location: 154'S & 794'W of NE Corner, Section 7 19.) Kick off point: 450' At the surface, this well will be 70'N of ¢43-6X, 90' N45°W of ¢43-6, llO' N20°W of KDU ¢4 and 170' N45°W of ¢43-6A. Following kick-off, at 1350' VD this proposed well will pass 350' below #43-6 and at 2700' VD this well will pass 800' below ¢43-6A. No wells will be crossed closer than 200' away. Please also make the following ammendments to our Permit to Drill for KBU #23X-6: 4.) Surface Location: 362'N & l124'E of SW Corner Sec 6 18.) Approximate spud date: October 20, 1984 19.) Kick off point: 500' At the surface, KBU ¢23X-6 will be 72' from #14X-6, 100' from #21-7, 187' from KU #13-6, 195' from KDU ¢1, and 200' from KU ¢31-7. Following kick-off, this well will be temporarily turned off course to the north to avoid intersecting KU ¢14x-6 which will be passed approximately 35' away at 1050' VD. At 1575' VD the well will also cross 400' below KU Should you have further questions concerning the drilling of these wells, please feel free to contact Mr. Paul Spiro or myself at the letterhead address. PMS/jeg cc: L. Cutting B. Anderson /~S~ncerely, .~ Jim R. Callender AUG 0 Alaska 0il & Gas Cons. Commission Anchorage August 2, 1984 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P.-0. Box 6247 Anchorage, Alaska 99502-0247 Re: Kenai Tyonek Unit KTU 13-5 Union Oil Company of California Permit No. 84-108 Sur. Loc. 154'S, 794'W of NE cr Sec. 7, T4N, RllW, SM. Btm~ole Loc. '1980'N, 590'E of SW cr Sec. 5, T4N, RllW, SM. Dear Mr. Anderson: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch ch~p from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tap~ containing the digitized log infor~p~ation shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AZ 16.05.870 and the regulations promulgated thereunder (T~tle 5, Alaska Administrative Code), Prior to commencing operations you may be contacted by the Habitat Coordinator's Officm, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be. contacted by a representative of the D~partment of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Kenai Tyonek- Unit KTu ! 3- 5 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. in the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterto~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION be Enclosure cc: Department of Fish & Game_, Habitat Section w/o encl. Department of Environmental Conse~zation w/o encl. Union Oil and Gas D' ';on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager July 9, 1984 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI SOLDOTNA AREA State of Alaska Kenai Gas Field Kenai Unit, KBU #23X-6 and KTU #13-5 A-028142 (8-86-71-5390-600972) Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies each of the above captioned Permits to Drill KBU #23X-6 and KBU #13-5. Also enclosed is our Check No. 19302 in the amount of $200.00 to cover the required filing fees for both permits. Upon approval of same, we would appreciate copies so that we may complete our files. Very truly yours, sk Enclosures cc: $. R. Callender H. Lowman-Marathon A. Lannin-O & G, Pasadena RECEIVED J U L 1 0 1984 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION CO.,,MISSION I ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL '~ REDRILL [-] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL F-I DEVELOPMENT GAS ~ SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator UNION OIL C'OMPANY OF CALIFORNIA 3. Address J~o O, BOX 6247, ANCHORAGE, AK 99502 4'L°cati°n°~r~ret~ac~~'-S~&-I-7~"'W of NE Cor, Sec 7, *~f'¢~uk At top of proposed producinCmte~v~l +1050'N & +75'E of SW Cor, Sec 5, * _ Attotalde~ ~1980'N & i~90'E of SW ~.~* ~ 6. ~ serial no. 5. Elevation i~ ~n~~'~et¢ I Pad 66' HS% i A~028~2 79. Unit or lease name KENAI TYONEK UNIT 10. Well number KTU 13-5 t 1. Field and pool KENAI GAS FIELD 12. Bond information (see 20 AAC 25.025) Type Statewide Suretyand/or number 85534278 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line South +6 miles I -+3300 feet 16. Proposed depth (MD ;~'-TVD) .- . ~ ~.. 17. Number of acres in lease +9300 MD & +8800 TVD feet 2560 19. If deviated {see 20 AAC 25.050).~ ~ltU~ 5~;RtP 7/~/~'¢ 120. Anticipated pressures KICK OFF POINT ~lfeet.~'F.~lA~7~lU~ HOLE ANGLE 20 oI (see 20 AAC 25.035 (c) (2) Proposed Casin~, Liner and Cementing Program ~at~i.g,,n~]~ ¥~qs.9 Insurance Co. of Hartford Amount $200,000 15. Distance to nearest drilling or completed we~ +600 feet -- 18. Approximate spud date August 10, 1984 ;9~ / U psig@~ Surface 3433 psig@ 7860 ft. TD (TVD) SIZE Hole I Casing Weight DrivenI 20" 94# 17½" 1133/8" 68# 12¼" 9 5/8" 47# 8½" 7" 29# 2.,~)escribe.propose~ program: · move in an~ 2 CASING AND LINER Grade Coupling I Le. ngth H-40 P 1 a i n I+1U0 K-55 Butt. 1+2500 N,80 I Butt. 1+7650 N-80' I Butt. 1~1300 SETTING DEPTH r~g up on locatiOn. MD TOP TVD 0 i 0 0 ~ 0 I 0 , 0 +7550 ~ +7015 I MD BOTTOM TVD +100 +100 ¥2500 +2400 +76501 +7250 .Drive 20" to refusal @ +100' & install diverter. +8850~ +7860 -- i I well as a dual QUANTITY OF CEMENT (include stage data) Driven 2266 sxs 3198 sxs 416 sxs 12.Remove bridge plug and complete Beluga/Tyonek 3.Drill 17½" directional Nole to +2500'. 4 Run and cement 13 3/8" casing @-+2500'. 5.Install and test BOPE to 3,000 psi. 6.Drill 12¼" directional hole to +7650'. 7.Run logs, run and cement 9 5/8" casing @ +7650'. 8 producer. 13.Rig down and move rig~out. ,ECE!v .Drill 8½" directional hole to_+8850' TD.- JUL Z 01984 9.Run logs, run and cement 7I' liner f/+7550 to 8850'. -'~,lau~,.a 0~] m Uas CCC•. Con 110 Perforate Tyonek zone and perform inside casing gravel pack. ~11.Isolate the Tyonek zone with a bridge plug; test the Beluga zone as required. Anchorage 23.1 her~ry~~t.~ ~'?~°rgg°i~~" true/~'ra~d correct to '~t ~mv k~,wledge~ '~--~ SIGNED ' ~BERT T. ANDERSON ~ ITEL DIST. LAND MANAGER DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required ! Mud Iogrequired •YES ~NO •YES ~NO Permit number . Approval date APPROVED BY I /Y /YJ~ ~~ Rev. 7-1-80 Dir/~L.¢ctional Survey required I APl number _ES •NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 2: 198/4 by order of the Commission Submit in triplicate ~ission RIIW TO ;4-6 O, H. E. lect, ' ne, , Wolfe _ 43 -6 x (_ A]I -values in feet. Depths sho'~n ~re TV~. Closure: 2587 Ft. at N 32 d~g ~ ~n E 8otto~ hoi~: TVD 7880 TMD 82gg Maqnetic declination: 24 [lag E HORIZONTAL VIEW UNIOH OIL COHPANY OF CALIFORNIA KTU 13-5 RADIUS OF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch = SOD DRAWN: 2-16-84 ; I ~' I i' ' ". 7 8 ~ ~ I Alaska Oil & ~as Cons. Commissio~ Anchorage j o ......=- ................... ~ ...... ~ ........ ? ........... VERTICAL ' UNION OIL COMPANY OF CALIFORNIA K.o.p. 300i' ,i " KTU 13-5 ~ RADIUS OF CURVATURE ,.~ ...... =--=-=--~.-=--=~-~---~---=?~-F-~~ ~ _ ~ ~ ........ ~ SINGLE SHOT SURVEY ~ :, erage! nn-~ e~ , ~ ~- ..... ~ ~ , ~ ~ ..... ~ ..................................... ~ ................... ~ ......... ~-~ ~ T ~ ' .............. ~ ............... , , ~ ~.~ ..................... ~.~ ......... ~ .......... + ........ ~ ~ .................... ~ , ~Target A T~.V.D. ~670' i ~ D ~ ~ $. i TLM.D ~909' ~: . ' I ~ ~m ~--~ -~ ........ ~ .......... ~ep~ .....~l-4e2-~-. ................... ~ .... J, ...... ~ ~ --I .......... ~ -~-'? ....................... ~ .............................. ~ .......... ~ .... ' 1 ,B.H.L. ,,~ 8298 ~ ,, , ................... ~ ' ~ T ....................... ~ .............................. ~ .......... ~ ........ ~ i · , , ~ Al ska Oil Gas : ~ ' J L ~ .......... : ...... ~ ~ ...... [ .................... l ........................ J .............................................................................. WELL' K'I U 1:5- 5 (Proposed Completion) 133/8" SURFACE CASING AT -+ 2500' DUAL PACKER TUBING STRINGS TOP BELUGA FM. +_ 4670' K. D. or +_ 5~.~ 'M. D. SINGLE PACKER TOP 7" LINER AT -+-7550' M.D. 9 5/e" CASING AT +-7650' M.D. PRODUCTION PACKER TOP TYONEt¢ FM. GRAVEL' PACK BRIDGE PLUG + 7£E0 14D. or - ~160' M. D. RECEIVED JUL .[ 0.1~ Alaska Oil & 'Gas Cons. Commission Anchorage 7" LINER AT-+ 8850'M.D. + i or - 7860 V.D. union WELL CASING STRING CASING AND IUDING DESIGN BOROUGH STATE DATE DESIGN BY 1. MUD WT. I 2. · 3. #/q. HYD GR. I psi/ft. MUD WT. II #/q. HYD. GR. II psi/ft. M.S.P. psi. INTERVAL DESCRIPTION CASING SIZE Bottom Top LENGTH Wt. Grade Thread WEIGHT TENSION MINIMUM COLLAPSE COLLAPSE INTERNAL W/ BF -top of STRENGTH PRESS. ~ RESIST. BURST MINIMUM W/O BF~><[ section TENSION bottom tension PRESSURE YIELD lbs lbs lO00 lbs TDF ,,.psi psi CDF psi psi t,,~----- HYDRIL ANGLED FILL UP LINE 13 5/8" 5000psi BLIND RAMS 13 5/8" 5000psi Double PIPE RAMS (5") HYDRAULIC OPERA TED VALVE ,,,-CHECK VALVE { '%. FROM KILL PUMP · GATE OR LO-TORQUE GATE VALVE GA TE OR LO-TORQUE TO CHOKE MANIFOLD GATE VALVE REQUIRED PIPE RAMS 13 5/8" 5000psi Single CONTRA C'TOR PROVIDED UNION OIL PROVIDED RECEIVED JUL 1 o 1384 Alaska Oil & Gas Cons. Commission Anchorage KENA I GA S FIELD B.O.P.E. STACK FOR DRILLING 121/4" UNION OIL COMPANY OF CALIFORNIA HOLE · .... ,, BAW .'. -. ' NONE -..'- JUNE 1984 AutoHydraulic Valve Opens automatically when diverter closes 6" 6" 11 TWO 6" BUTTERFLY VALVES TIED TOGETHER SO AS ONE IS AL WAYS OPEN AND ONE ICLOSED. NOTE: TWO DIFFERENT DIRECTIONS OF DIVERSION RECEIVED JUL ] 019~4 Alaska Oil & Gas Cons. Commission Anchorage 20"~ KENA I GA S FIELD 2,000psi DIVERTER ASSEMBLY UNION OIL COMPS, NY OF CALIFORNIA .L' .'. -_'. - '7. ~? .... '.'. BAW · · -~ NONE '..'; JUNE. 1984 VENT (to crown of Derrick or to Flare Pit) BUBBLE TANK OR HOME MADE DEGASSER Targeted Turn 11 LP VALVE AUXILIARY CHOKE CAMERON TYPE "F", VALVES (or equivalent) 4" LP VALVES 51"% I I~ /~,,CAMERON TYPE ..L__L % /...... I ~ "F", 2" VALVES ~ 4" CAMERON TYPE "F" ~" Targeted Tu~rn 4." VALVES (or equivalent) 11 rj h Targeted Tur,~ RECEIVED Alaska Oil & Gas Co~s. Commission Anchorage NOTE: ENTIRE ASSEMBLY IS 5,000psi W.P. MINIMUM UPSTREAM OF CHOKES KENA I GA S FIELD MINIMUM STANDARD CHOKE MANIFOLD ASSEMBLY UNION O;L COk~PAN'f' OF CALIFCPNIA · ...-. BAW -' _ , . NONE ' '--- JUNE, 1984 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /< .7'. ~{ ITEM APPROVE DATE (1) Fee (2) Loc (~th~ru8) (8), (3) Admin (9/tkru 11) (I0 and 11) (4) (i2 th~6 20) (21 thru 24) 1. Is the permit fee attached ......................................... 2. Is well to be.located in a defined pool ............................ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... ' -~' Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is Old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to 5000 psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~ Additional requirements ............................................. ~ , ,, Geology :' Engin.~.ering: JAL~ .... ~ ~ / rev: 12/08/83 6.CKLT ' INITIAL' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. · . . [,VP olO.H02 VERIFICATI{'){'.} LIS't'I~G PAGE 1 SERVICE NA,~.~E :EDIT DATE :84,/!0/!2 REEl, COM~EN TG : ** TAPE HFfiADCR SERVICE NAME :EDIT DATE :84/1o/12 DRIGI~,J :0000 rAPE ;~/% ~ E : 95'15 COt~TINI.)AT[[.)N ~ :01 PREVI[DIJS TAPE COMMENTS : ** FILF~ HEAL)F,R ** FILE NAME :EDIT SRRV ICt~; N A ~,~, E : VERSION # D A T E : MAXIMUM [,k'NGTH FI L[': TYPE : PREVIOUS Fi[,E : .001 1024 1N~'ORMATION RECORDS ~N,i : UNION OIL FN. : KEb!AI GAG RAN(i: 1.!w TOWt~: SECT: 7 COUN: KENAI STAT: AI,~SKA CTRY: USA H P A N Y ELi} SCH L U H [~ g R (;g R U hi I T 0 0 0 0~0 000 <)00 000 000 000 000 000 CAT~] 0 O0 000 000 00 ¢) 000 ;) 0 0 OOu 00 () 000 5 I. Z ~{ t) () 4 O04 () ()2 00~ 0 o 6 003 065 065 O65 065 065 06.5 065 [~VP Olno}~.~j2 VERIFICATION [,JS'I;It~G PAGE 2 A!,ASKA DIV,fSI[]N COt~PiITiNG CENTER ......... "' IT 800 BPI =================================== ...... ______ . dOB # 69575 BASE LOG: DIL ,~,RUN, l~' ~1 DATE LC.GGED 1 ~EP 84 BOTTOM LOG INTERVAb : 8200 T(]P I,OG INTERVAb = 2494 CA~ING-LCGGER = 13_...~.375 HI. SIZE = 1Z'zbO ,..TYPE HOLE FI,UID = FGM DENSITY = 10 03 24 "~ 94 [.,VP 01o,Ho2 VER.[F[CATI(]r~ L.,ISTING PAGE 3 PH FLU l' I', R~ l~ hEAS. TE!~P. R~iC (.~ HEAS. TEF, P. ,,:'.LDP: T HALSTEAD 10.50 7,20 3. 650 fa 60 F 3. 250 (a 60 F 3.030 ~,t ~0 F ],ql() ,a 121 i*i~.)DATA FORHAT RECORD iNTRY [~.LOCKS TYPE SIZF, R t;.: P r~ CODE ENTRY 9 4 6b ,lin 16 1 66 1 0 1 66 u )ATUH SPECIFICATION ~NEt4 S}-:RV]C[,7., SERVICE IJI,!T.T AP1 APl' APl API !D ORDER ; LOG TYPE CLASS NOD NO. ) E P T I~' '[' 00 0 ¢ (t 00 0 g 4 ;FLU DIL () H t'4 ~l 00 22t~ 01 O 0 4 IbM DIL fJH~h O0 120 44 0 O ~ P I) I b ~l v 00 01 f) 01 f/ 0 4 ;R DIL GAPI 00 310 01. O O iR Bi. CC GA,PI O0 310 Oi 0 0 4 ;P ;~iC i,~V 00 010 01 0 0 4 ;R LDT GAPI 00 310 0l 0 0 4 ] A L I I., D '.r I i,~ o 0 280 0 l 0 0 4 tHOB i.,DT 6/63 O0 350 02 0 0 4 ) R H 0 I, r)T (':; / C ] 00 356 01 o 0 4 ] R A T l., D T 00 420 01 0 0 4 {NRA I, DT 0() 000 0 IPHI I.,DT pti 00 890 00 O 0 4 ~EF I,OT 0o 358 01 0 0 4 ~CNL [,DT CPS 00 330 31 0 0 4 ~ C N L i, D 'l.' (' P 5 0 0 330 30 0 0 4 fPh EFT I',~ S / ~v.00 112 0{ 0 0 4 tD EPT IN 0(~ 2~t0 O1 0 0 4 ~ A E F T l ~,~ 0 {:) 280 01 0 0 4 ~R EFT GAPI 00 3J. 0 01. 0 0 4 ~VP O:lO.Ho2 vKRIFIC;,TI[~r,i I.,J,STING PaGE .4. 821 9.5000 -2 ]. H750 -23,8750 GR 2999,25(.)1.} NR A'.i 999.2500 NCNL -999. 2500 7. 6250 iL, D 4q3.2500 -999. 2500 CALl 999 500 R N R A ~999, . -999. 2500 fi200,0000 ,SFb~ ..1 ~, 3359 GR 49 -1 4.3359 GR -3268 -0.0181 NRAT 3. al 05 ~CN l, -3276 -999,250{) HI) -99 8100.0000 SFLU -30.64o0 (;R -30.64O6 GR 3.b098 NCNL 200. 2083 a~) 8000 , 0000 SF l,,tl -20.1,250 GR -20. 1,250 GR 0.03 b6 NM ~,T q· 1541 NCI',;L 243.9167 HO 7800,0000 SFi..U 8. 3594 GR El. 3594 (; R -0.01,46 NRAT 2,929'1 NCkL 221,3750 aD 7700.0000 5F'b!~ I 1.. 1 bb2 11.1562 GR 0. 0322 NRAT 3,1.582 NCNL 259,1656 Hi') 7000.0000 SFI,U 9'75'78 ILD 60,9 .~ '! 5 t;, T 64.6250. cALl 2262. O0 FCNL I 4.5703 1 3 4 1 6 .l 1 4 5 239 1 4 3 204 1 6 228 1 0 1'197 I!~D 5:9687 I 5000 C A 1, I 3:9199 R~'4RA 2,000 () F C N {.., 9.8125 SA 9.7969 Iht') 9.6553 D'.I' 1 . 9062 CALI 3.7324, 2,0000 B,V168 SA 9.55a7 IbP 4.1875 DT 9.3/138 (7 Al..,! 5. 0000 RNRA 8,0 (') 00 FCi~ i., 7.29~,9 SA 7. 5563 l hl) H, 875 (., D T 9.8125 CA[.,I 3.2402 RI'~RA 2,0000 FCNI, 8. 0000 16,9531 II, D 10.6328 99. 5625 -999. 2500 RHUB - 999,250 o ~,l P H .I -999,2500 TPh -999,2500 (;R 7 . 476 f.', I 1.., 99. 5625 (;R 17.6719 t.{HO 1, ,0000 NPIiI - ~276}], 0000 7 PI, -999. 2500 GR 1 1 . 2187 II.,M [t8.3750 GR 1,3.7422 RHOiJ 3.7383 hPHI 605,0000 '[' P b 1. b 12 ~ (:; R .1.2,1875 127.87b0 22,7qb0 Rt. itJB 4.0195 NPHI 4¢)8.500¢) TPL 2.7969 GR 26,70-~t I:iSN 99.6875 GR 19.0156 5.8203 351. ,750C) TPI., 2.2 539 (; 7.5313 99.5000 GR 18,078.1 3. 4297 ),iPH 1 665,0000 '/'FL 1.7813 GR 12.1502 iIJM '1,097'1 493,25 (..I 0 -999. 2500 -999.25o() -999. 250O -999,2500 7 4:93. 2500 0, 9 0 -999,250U -999,2500 10.523~ 60,9375 2,3906 37.9883 12,6693 04.8125 10.u437 35.9687 .1,805 'i '~ I. 74 80 ,~8.7b13 B.4141 2,259.5 39.5020 5b. -1500 20. 7969 4'i. 1875 1. 7910 63.3789 ] '.~,481 [~ 7.0469 L,a.8750 2,3495 31.~84~ 14.1562 54,9375 1.6719 - iii ]/ LVP o10~!Io2 VERIF'~CATJO~.~ blST1NG ~'AG[:: b 2.5781 GR 2..5781 (; R 0 0308 N R A T 210,7o8~J HD 7500.0000 SFLU - 4 . 5859 G R '4.5B59 GR 0.0112 WRA'r 2.7383 N C N L 218,2083 7400, c} t) ~) 0 10.8203 GR I 0, {~ 203 G R 0.0317 3.n410 NCh[, 178.7500 4,5547 GR 4. 5547 n. 04.'~ 0 NRAT 3,3~72 NCNB 237.7 () 8 ~ H -4.4492 GR -4.4~92 0.0'1~6 NRAT 2.582o 152.3750 7100, nuO~,) SF 4,3477 G 2.9961 215,6667 7000 000() 0:5391 GK 0.036t NRAT 2,b223 1'10.625() o900. OU(.)O SFbU -22 7031 -22~7031 GR 0 . 0015 NRAT 2 , 9297 NCNL 5 4.0 0 0 0 b T 3,3 3 0 1 23 '~ 4.00 (10 F C ~,, l, ~ 3. 5938 SA 20,89(;6 52.6250 5.], 9375 CALl 55,468~ 65 9 ]75 CALl 3; 4102 R ~'~ R A 2412,0000 FCNI.., 13,8125 7,4570 I.LD 57,4 ~ 63 70,6250 C~hI 3,6387 RNRA 2242,000 o FC N i.,, 13.5'1~'~1 SA 19,593 ~ , 64.8125 DT 77. 7500 CAt,] 3.~461 RNR~' 1957.0000 14.1172 8.0 'l () 3 5g. 1875 CALl 3.3 3~[~ 14,3 '150 9.~172 55. 0000 aT 62.71~8 C~LI 3.2227 14.3~° .,6 SA 15. u 3 l 3 59.25t)O [.,T ~0.3438 2,77q3 2864.0000 FCNb 15.2344 5A 95.500 12.2,422 3.51 '17 664 . 1.4766 13.6 u 9 1, (., 3.5 u 00 15.51bb ,t 29,000 (,) 1 .7119 I ] ,9141, 99~625~} 12.453 3.4102 'i 07,0{)00 I .6455 8.7 96 . 1 R 7 ~2.46d9 1.4(~'12 15.0391. 96.8750 1~.7~91 3,9668 493. 1.6123 9.9922 90,9375 14.0625 3.632~{ 654. 5000 1.64 b 5 94.4375 13.4766 3.4 O 0 772. 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O 000 2.4121 33. 4961 11,5469 n I, 5000 b 9,2 b 00 2,41b0 2fi.~113 11,1172 O-t, 1250 SP S P D R H O' PEI;' EATT DEPT SP DRHO PIEF EATT , DEPT ~P DRNO PEK gA~T ~gPT SP E ATT D~PT DRHO EATT DEPT SP PEF DEPT SP DRHO PEF EATT DEPT SP SP DRH(J 6700 , 0000 $ F l., ;j - 8 9531 ('; R -819531 GR 0 0215 [",~RAI' 311.230 NCNb 1 69.2 b (~ () ~.t D 6500. 0000 - 34.2 b 0 -34,2500 GR 3.2441 NCNL 1. 74. 0250 640 o ,, 00 (') 0 -8.7 1 O9 Ga 010506 NRAT 3.2,~05 203. t~'lSO HD 6~0. 0000 SFLU -0. ~68 -0. ~66B GR. 0. o o 54 i'~ 3.2959 160,q167 HD 6200, ~000 5FI,ti -5. 972'I GR -5. 9727 O. 126(2 .]. 1. 77 'l 210.'/083 6~00.00o0 SFLO -34.5~.)~o G -34. 500O GR -0 , 0034 12.9062 I L D 6 !.. 2813 i31' 65.0625 CALl .s. 039 J !~ i'.~ R A 2366.00(]0 ["C ['~ [~ 14.t~79'1 SA 44.7188 DT 52.0563 CAI.,I 3.5 ~ 01 R ~'~ R 4 4 0 ~) 0 t, F' C ~'i I', 1514219 18.3125 49,9062 D 53.7500 C~LI 2.9902 R,':RA 2686,0000 .16,0313 18,7 l 8H I i,L) 4~. 4(}63 DT S3.4~75 (/ALI 2. 6426 t;4I~A 66.00 b 0 F C 15.5859 13.7422 ILO 54 . 2187 L, T 53.6.563 ], 3105 I 2, O'lt., 3 97.3125 GR 14.2344 4.0 ~t 59 t,] P ii 1'. 622..5000 'l'P 1., 1.3408 GR 16.7500 Ii, Fi 98.75O0 GR 14.90~2 .1. 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A I-, ~.] :Fit)IT ~:DA3'E :84/10/1~ OR I(; 1 ~.~ : ,,.TAPE NAy, E :9575 ~iNEXT TAPE N,~i~:. : ~** REkL 'r2AI[,ER ~,$ ~.,: DATE :8,4/10/~ J~: REEL ~A,".~] : 'NEXT REEL i~Ai~,iE : 12 /'
