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Home My WebLink About193-0221. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO, N2 Development Exploratory 3. Address: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 8,308 feet See Schematic feet true vertical 6,432 feet 6,741 (fish) feet Effective Depth measured 6,319 feet 6,667 feet true vertical 4,922 feet 5,168 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-81 6,601' MD 5,127' TVD Packers and SSSV (type, measured and true vertical depth)See Schematic; N/A See Schematic See Schematic N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Chad Helgeson, Operations Engineer 324-604 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 10 Size 94' 0 101089 0 4670 1052 Production Liner 3,449' 8,308' measured TVD 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-022 50-283-20089-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL032930 Ivan River / Undefined Gas Ivan River Unit (IRU) 44-36 Plugs Junk measured LengthCasing Structural 2,940' 6,432' 3,449' 8,308' 94'Conductor Surface Intermediate 20" 13-3/8" 94' 908' 4,760psi 7,020psi 3,450psi 6,870psi 8,160psi 908'904' Burst Collapse 1,950psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Gavin Gluyas at 9:37 am, Feb 25, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.02.25 08:59:54 - 09'00' Noel Nocas (4361) RBDMS JSB 030325 DSR-2/28/25BJM 4/28/25 Page 1/4 Well Name: IRU 044-36 Report Printed: 2/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:10/20/2024 End Date: Report Number 6 Report Start Date 10/20/2024 Report End Date 10/21/2024 Last 24hr Summary Crews arrived in Beluga, Mobilzed Fox CTU 8 1.75" CT to location and partial rigged up. Report Number 7 Report Start Date 10/21/2024 Report End Date 10/22/2024 Last 24hr Summary PJSM and PTW, Crew travelled to location, finish rigging up CT Unit, batch mix 6% KCL, fill N2 unit, BOPE test 250/2500 psi Report Number 8 Report Start Date 10/22/2024 Report End Date 10/22/2024 Last 24hr Summary PJSM and PTW. Crew arrived on location spotted in N2 unit and rigged it up. Made up 2-1/8 tools with DJN. PT lubricator 250/2500. RIH started stacking weight at 5,150' cont. down to 5,200' P/U to 5,100' 4k overpull. Start FCO pumping 6%KCL @ 1.5BPM cleaned out to 6581' CTMD sent a 10 bbl gel sweep. Swapped over to N2 pumped 117k scf and recoverd 72 bbls of water. Wellhead increase from 650 to 850. LEL reading of 55%. POOH. Stack back IH. Secure Well. Turnover to Production. Report Number 9 Report Start Date 10/23/2024 Report End Date 10/24/2024 Last 24hr Summary CTCO complete, RDMO coil equipment. Staged equipment at Barge landing. Report Number 10 Report Start Date 10/25/2024 Report End Date 10/25/2024 Last 24hr Summary SL MIRU, PT Lub 250/2000 psi, pass, RU & Tag bottom @ 6420. POOH and RD SL. Report Number 11 Report Start Date 11/7/2024 Report End Date 11/7/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up equipment, Make up tool string (CCL/GR/PLUG 2.75"), Pressure test 250/2000-good, Run in hole, Tag @ 6159', Make multiple attempts to pass-no good, Pull out of the hole, Secure well & rig down. Report Number 12 Report Start Date 11/8/2024 Report End Date 11/8/2024 Last 24hr Summary SL MIRU, PT Lub 250/2500 psi, good test. Bail from 6189' to 6220'kb Report Number 13 Report Start Date 11/9/2024 Report End Date 11/9/2024 Last 24hr Summary Bail fill from 6220' to 6234'kb Report Number 14 Report Start Date 11/10/2024 Report End Date 11/10/2024 Last 24hr Summary Bail from 6214' to 6231'kb Report Number 15 Report Start Date 12/1/2024 Report End Date 12/2/2024 Last 24hr Summary Bail fill from 6157' to 6204'kb Report Number 16 Report Start Date 12/2/2024 Report End Date 12/3/2024 Last 24hr Summary Bail fill from 6205' to 6215'kb Report Number 17 Report Start Date 12/3/2024 Report End Date 12/4/2024 Last 24hr Summary Bail fill from 6218' to 6262'kb Report Number 18 Report Start Date 12/4/2024 Report End Date 12/5/2024 Last 24hr Summary Bail fill from 6262' to 6286'kb Report Number 19 Report Start Date 12/5/2024 Report End Date 12/6/2024 Last 24hr Summary Bail from 6286' to 6302'kb Report Number 20 Report Start Date 12/6/2024 Report End Date 12/7/2024 Last 24hr Summary PJSM. Permit. Ran 2", 2.25" and 2.50" drive down bailers. Recovered sand & slurry mostly full bailers. Bail from 6298' to 6315'. Tag fill w/ 2.80" gauge ring at 6317'. All measurements KB corrected. SDFN. Plan forward: Continue bailing to target 6350'+ Field: Ivan River Sundry #: 324-604 State: ALASKA Rig/Service:Permit to Drill (PTD) #:193-022Permit to Drill (PTD) #:193-022 Wellbore API/UWI:50-283-20089-00-00 Page 2/4 Well Name: IRU 044-36 Report Printed: 2/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 21 Report Start Date 12/7/2024 Report End Date 12/8/2024 Last 24hr Summary PJSM. Permit. Ran 2", 2.25" and 2.50" drive down bailers. Recovered sand & slurry mostly full bailers. Bail from 6306' to 6319'. Tag fill w/ 2.80" gauge ring at 6322'. All measurements KB corrected. SDFN. Plan forward: Continue bailing to target 6350'+ Report Number 22 Report Start Date 12/8/2024 Report End Date 12/9/2024 Last 24hr Summary PJSM. Permit. Ran 2"and 2.50" drive down bailers as well as 2.25" pump bailer. Recovered sand & slurry mostly full bailers. Bail from 6297' to 6315' MD. Tag fill w/ 2.80" gauge ring at 6320' MD. All measurements KB corrected. SDFN. NOTE: All runs lubricator was pressured up to 1100 PSI before opening swab. Morning PSI 1100. End PSI 1150. Morning FL 4300'. End FL 4115'. Plan forward: Continue bailing to target 6350'+ Report Number 23 Report Start Date 12/9/2024 Report End Date 12/10/2024 Last 24hr Summary PJSM. Permit. Ran 2"and 2.50" drive down bailers as well as 2.25" pump bailer. Recovered sand & slurry mostly full bailers. Bail from 6301' to 6325' MD. Tag fill w/ 2.80" gauge ring at 6325' MD. All measurements KB corrected. SDFN. NOTE: All runs lubricator was pressured up to 1300 PSI before opening swab. Morning PSI 1150. End PSI 1180. Morning Plan forward: Continue bailing to target 6350'+ Report Number 24 Report Start Date 12/10/2024 Report End Date 12/11/2024 Last 24hr Summary PJSM. Permit. Ran 2", 2.25" and 2.50" drive down bailers as well as 2.25" pump bailer. Recovered sand & slurry mostly full bailers. Bail from 6309' to 6325' MD. Tag fill w/ 2.80" gauge ring at 6327' MD. All measurements KB corrected. SDFN. NOTE: All runs lubricator was pressured up to 1300 PSI before opening swab. Morning PSI 1180. End PSI 1200. Plan forward: Continue bailing to target 6350'+ Report Number 25 Report Start Date 12/11/2024 Report End Date 12/12/2024 Last 24hr Summary SL Bailed fill from 6313' to 6342'kb Report Number 26 Report Start Date 12/12/2024 Report End Date 12/13/2024 Last 24hr Summary SL Bail from 6340' to 6345'kb Report Number 27 Report Start Date 12/15/2024 Report End Date 12/16/2024 Last 24hr Summary SL returned to work, reheaded, pressure tested 250/2000. continued bailing fill from 6,284' KB to 6,339'. Pressuring up lubricator with methanol before opening. 24hr SL ops ongoing. Report Number 28 Report Start Date 12/16/2024 Report End Date 12/17/2024 Last 24hr Summary Bail from 6,343' to 6,346' KB. Pressuring up lubricator before opening. Fluid level started at 2,900' and ended at 2,300'. working 24hr operations Report Number 29 Report Start Date 12/17/2024 Report End Date 12/17/2024 Last 24hr Summary SL continued to bail fill from 6349' to 6364'. Pause SL work. MIRU AK Eline. P-test 3000 PSI. Good. RIH w/ 2.79" gauge ring-spangs-CCL-Gamma. Tagged fill high at 6330' MD. POOH. RDMO. EL crew returned to Bruce platform. Report Number 30 Report Start Date 12/18/2024 Report End Date 12/19/2024 Last 24hr Summary E-Line tagged at 6,330' KB, slickline tagged at 6,366' afterwards. Bail 6,371' KB to 6,408'. Set Weatherford packoff plug assembly at 6,352', correlated from E-line tag Report Number 31 Report Start Date 12/19/2024 Report End Date 12/20/2024 Last 24hr Summary Ice Plug in SL lubricator. Rig down after setting Weatherford packoff at 6,352'. Report Number 32 Report Start Date 12/26/2024 Report End Date 12/26/2024 Last 24hr Summary AK-Eline traveled to Beluga, fired equipment, checked in with ops, completed PTW and conducted PJSM. Travel to Ivan River. MIRU equipment. Completed PT 250/3000 psi (pass). PU RG/CCL weight bars and 2.80" GR. RIH and tag 6300'. Talked to Engineer, POOH and rerun slick (max OD= 1-11/16"). RIH and tag again at 6300'. Discussed with engineer and decision made to RDMO, wait for SL to continue bailing on well. Travel back to Beluga camp. Report Number 33 Report Start Date 12/27/2024 Report End Date 12/28/2024 Last 24hr Summary SL Tag fill at 6,300' KB, bail to 6,311'. All depths are correlated off of E-Line tag. Field: Ivan River Sundry #: 324-604 State: ALASKA Rig/Service: Page 3/4 Well Name: IRU 044-36 Report Printed: 2/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 34 Report Start Date 12/28/2024 Report End Date 12/29/2024 Last 24hr Summary SL Bail fill/mud from 6,306' to 6,348'. All depths are correlated from E-Line tag. Report Number 35 Report Start Date 12/29/2024 Report End Date 12/30/2024 Last 24hr Summary SL Drift to A stop with pump bailer. Eline RU & RIH with CIBP. Unable to get deep enough. RIH with logging tool and LIB to identify set down. Good impression on LIB of SL plug. Pumped 6 bbls of MeOH in well and pressured up to 1036 psi. Prep for pulling packoff plug in AM. Report Number 36 Report Start Date 12/30/2024 Report End Date 12/31/2024 Last 24hr Summary SimOps with Slickline & Eline. SL RU and made 4 runs pulling all components of packoff plug. Eline Rigged up to drift for CIBP. while trying to fill well with water, PCE lines froze, thawed and replaced lines PT to 250/3000 psi. RIH with 2.80" GR and tagged at 6350. POOH and run CIBP and set @ 6,350'. POOH and RDMO. Report Number 37 Report Start Date 12/31/2024 Report End Date 1/1/2025 Last 24hr Summary SL bailed thick fluid off top of CIBP at 6361 SLM. Tried to blow down well tos tart swabbing and well flowed 9bbls of fluid at 200 psi. Shut well in, RIH with bailer and tagged same spot (no fill and plug did not move. Report Number 38 Report Start Date 1/1/2025 Report End Date 1/2/2025 Last 24hr Summary SL used 2.5" pump bailer to remove thick mud from above plug prior to perforating. Same depth each run to 6371'. Report Number 39 Report Start Date 1/4/2025 Report End Date 1/5/2025 Last 24hr Summary PJSM, Crew travel to location, Start & warm equipment, Pick up & make up tool string (2.80" OD GR), Pressure test 250/3000-good, Run in hole to tag @ 6349, Pull out of hole, Pick up run #2 (2.75" plug_, Run in hole, Tag @ 6335' (to shallow), Pull out of hole with plug, Pick up run #3 (2.8" Gauge ring), Run in hole, Tag @ 6349', Pull out of hole, Pick up run #4 (20 ft 2" bailer), Mix up 1.8 gal surry, Run in hole to tag @ 6306' (unable to dump cmt), Pull out of hole, empty bailer, Pressure up Wellhead to 750 psi, Rig down for the night & winterize equipment. Report Number 40 Report Start Date 1/5/2025 Report End Date 1/6/2025 Last 24hr Summary PJSM, Crew travel to location, Start & warm equipment, Pick up lube & dummy run 2" bailer, Run in hole to tag @ 6318', Pull out of hole, Pick up run #2, (2.80 GR), Run in hole to tag @ 6345', work down to 6349', Pull out of hole, Pick up Run #3 2" bailer, Run in hole to tag @ 6345', Work down to 6349' make several passes, Pull out of hole empty bailer (1 gal thick mud), Make up run #4, 4' x 2" slick line bailer, Run in hole tag @ 6349', Work several times, Pull out of hole (recovered 1/4 gal mud), Make run #5, 4' x 2" bailer, Tag @ 6349', Work several times, Pull out of hole (recovered 1/2 gal), Rig down for the night, Pressure up to 500 psi. Report Number 41 Report Start Date 1/6/2025 Report End Date 1/7/2025 Last 24hr Summary PJSM, Crew travel to location, Start & warm equipment, Pick up lube & tool string (2" x 4' drive down bailer), Run in hole & tag @ 6349', Work multiple times, Pull out of hole, Make up run #2 (2" x 7' drive down bailer), Run in hole tag @ 6349', Pull out of hole (recovered 3/4 gal thick mud), Continue making bailer runs (6 total) tagging same depth 6349', Pick up & make up run #7 (2.75" CIBP), Run in hole & correlate, Set plug @ 6346.6', Tag & log off good, Pull out of hole, Pressure test casing to 821 psi-dropped 17 psi in 30 min, Rig down & prep to move. Report Number 42 Report Start Date 1/17/2025 Report End Date 1/18/2025 Last 24hr Summary Determined well clear of obstruction to a depth of 6338'- Swabbed fluid from surface to below 2010' PJSM, Crew travel to B-pad, Mob to Ivan river, Spot in & rig up, Pick up lube & tool string, Run in hole with 2.8" GR, Tag @ 6338', Pull out of hole, Pick up 3.5" swab assembly, Make 11 runs recovering 20.67 bbls, Secure well & rig down for the night. Report Number 43 Report Start Date 1/18/2025 Report End Date 1/19/2025 Last 24hr Summary Swabbed fluid column from 2170'KB to +4430'KB PJSM, Crew travel to location, Pick up lube & tool string, run in hole with 3.5" swab assembly (Fluid top 2170), Make 16 runs recovering 30.67 bbls, Secure well & rig down for the night. Report Number 44 Report Start Date 1/19/2025 Report End Date 1/20/2025 Last 24hr Summary Swabbed fluid column from 4510'KB to 6020'KB PJSM, Crew travel to location, Pick up lube & tool string, run in hole with 3.5" swab assembly (Fluid top 4510), Make 19 runs recovering 13.5 bbls, Secure well & rig down for the night. Field: Ivan River Sundry #: 324-604 State: ALASKA Rig/Service: Page 4/4 Well Name: IRU 044-36 Report Printed: 2/25/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 45 Report Start Date 1/20/2025 Report End Date 1/21/2025 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up, Pick up lube & tool string GR/CCL/GUN, Pressure test 250/2000-good, Pressure up well to 750 psi with pad gas, Run in the hole, Correlate, Continue building pressure on well, Perf ST X3M (6336-6340), Pull out of hole, Pick up Run #2, Run in hole, Tag @ 6346, Fluid @ 5890', Continue to draw down & monitor fluid (no change), Pull out of hole, Lay down for the night. Report Number 46 Report Start Date 1/21/2025 Report End Date 1/22/2025 Last 24hr Summary PJSM, Crew travel to location, Pick up lube & tool string, Pressure test 250/2000-good, Run in hole (2-3/8"gun), Tag @ 6325', Pull out of the hole, Pick up & make up run #2 (2" bailer & spangs), Run in the hole, Tag @ 6325', Pick up & make up run #3 (2.80" GR), Run in hole, Tag @ 6325', Pull out of hole, Pick up & make run #4 (2.75" plug), Run in hole, Tag @ 6325, Set plug @ 6319', Tag & log off-good, Pull out of hole, Pick up & make up run #5, (CCL/GR/GUNS 2"), Run in the hole, Correlate, Perf 2' ST X3U (6304’-6306’), Pull up hole & monitor PSI 10 psi drop, Run in hole, Perf ST X3U (6302-6308), Monitor Pressure (2 psi drop), Pull out of hole, Pick up run #6 (GPT), Run in hole, Tag @ 6319’, Fluid @ 5875’, Monitor while drawing down from 770 to 300 psi, Fluid rose to 5845 Pull out of the hole. Report Number 47 Report Start Date 1/22/2025 Report End Date 1/23/2025 Last 24hr Summary PJSM, Crew travel to location, Pick up lube & tool string (GPT), Pressure test 250/2000-good, Run in hole to tag @ 6318', Fluid @ 5870', Pull up hole, Draw down well from 1017 psi to 300 psi, Tag @ 6315', Fluid @ 5820', Pull out of hole, Pick up & make up run #2, (2-3/8" gun), Run in hole, Correlate, Perf ST X2 Stray 6255'- 6267', Pull out of hole, Pick up & make up run #3, Run in the hole, Correlate, Perf ST X3U 6302-6307, Pull out of hole, Secure well & rig down for the night. Report Number 48 Report Start Date 1/23/2025 Report End Date 1/24/2025 Last 24hr Summary PJSM, Crew travel to location, Pick up lube & tool string (2.8" GR/GPT), Pressure test 250/2000-good, Run in hole, to 1500'-no issue, Pull out of hole, Drop 2.8" GR, Run #2 (GPT), Run in hole, Tag @ 6316', Fluid @ 6280', Flow well and perform GPT pass to confirm, Tag @ 6316, Fluid @ 6280 , Pull out of hole, Rig down & release AK eline. Field: Ivan River Sundry #: 324-604 State: ALASKA Rig/Service: ____________________________________________________________________________________ Updated by CAH 02-25-25 SCHEMATIC Ivan River Unit IRU 44-36 PTD: 193-022 API: 50-283-20089-00-00 CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Cond 94#, -Surface 94’-Driven 13-3/8”Surface 68#, K-55 Surface 908’BTC / 12.415”115 bbl / Cmt to Surface 9-5/8”Int 47#, N-80 Surface 3,449’BTC / 8.681”270 bbl / Cmt to Surface 7”Prod 29#, N-80 Surface 7,789’BTC / 6.184”115 bbl / Cmt to 4,420’29#, P-110 7,789’8,308’BTC / 6.184” TUBING DETAIL 3-1/2”Prod 9.2# / L-80 Surface 6,601’EUE 8rd Cmt @ 5088’ 4-1/2”Prod 12.6# / L-80 6,648’6,814’TC-II / 3.958”Cplg OD = 4.932” JEWELRY DETAIL No.Depth Length ID OD Item 1 6,319’2.75” CIBP 1/21/25 2 6,346.6’2.75” CIBP 1/6/25 3 6,594’7in CIBP 7/31/24 4 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 5 6,666’0.65’4.020 5.500 1.65’ K-Anchor 6 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 7 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 8 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 9 6,768’3.1’3.958 4.500 Ported Sub 10 6,814’1.08’3.670 4.950 Wireline Entry Guide 11 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 12 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 13 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. 14 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 15 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 16 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 17 7,735’0.75’2.441 3.250 Wireline Entry Guide 18 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments S X2 6,255’6,267’4,876’4,885’12’5 1/22/25 Open S X3U 6,302’6,307’4,910’4,913’5’5 1/22/25 Open S X3U 6,302’6,308’4,910’4,914’6’5 1/21/25 Open S X3M 6,336’6,340’4,934’4,937’4’5 1/20/22 Isolated S X3L 6,355’6,364’4,947’4,954’9’5 8/11/24 Isolated S A-1 6,405’6,420’4,983’4,994’15’5 8/10/24 Isolated 58-4 6,431’6,440’5,001’5,008’9’12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’6,568’5,093’5,101’11’12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Isolated 7/31/24 71-3 6,836’6,852’5,298’5,310’16’6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 16 20” @ 94’ 14 17 15 RKB: 51’ KB / GL: 26.5’AMSL 6 12 13 18 7 4 5 8 11 10 9 3 1 2 Tagged fill/guns @ 7,815’(9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 Tagged fill @ 6,850’ 6/27/20 S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 TOC @ 5088’ CBL 8-3-24 CBL TOC 4,400’ S X3L-S A-1 S X2-X3U S X3M Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 – CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250216 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # BRU 232-04 50283100230000 132037 1/18/2025 AK E-LINE Perf CLU 08 50133205340000 204005 2/13/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 1/2/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 12/13/2024 YELLOWJACKET SCBL CLU 7 50133205310000 203191 1/25/2025 YELLOWJACKET SCBL IRU 44-36 50283200890000 193022 1/21/2025 AK E-LINE Plug/Perf KALOTSA 10 50133207320000 224147 2/11/2025 YELLOWJACKET SCBL KALOTSA 9 50133207310000 224145 1/26/2025 YELLOWJACKET SCBL KBU 22-06Y 50133206500000 215044 1/11/2025 YELLOWJACKET SCBL KU 13-06A 50133207160000 223112 1/12/2025 YELLOWJACKET SCBL MRU M-25 50733203910000 187086 1/15/2024 AK E-LINE PPROF NCIU A-21 50883201990000 224086 1/6/2024 AK E-LINE Plug/Perf PBU 06-05A 50029202980100 224115 1/14/2025 HALLIBURTON RBT PBU 09-35B 50029213140200 224122 2/3/2025 HALLIBURTON RBT PBU B-12B 50029203320200 224133 1/20/2025 HALLIBURTON RBT PBU D-12 50029204430000 180015 12/19/2024 BAKER SPN PBU F-08B 50029201350200 212040 1/27/2025 HALLIBURTON RBT PBU NK-41A 50029227780100 197158 12/18/2024 YELLOWJACKET CBL PBU S-100A 50029229620100 224083 1/5/2025 HALLIBURTON RBT Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. 162-037 T40080 T40081 T40082 T40082 T40083 T40084 T40085 T40086 T40087 T40088 T40089 T40090 T40091 T40092 T40093 T40094 T40095 T40096 T40097 IRU 44-36 50283200890000 193022 1/21/2025 AK E-LINE Plug/Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.18 13:06:47 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' 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: CTCO, N2 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,308'6,741' (fish) Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Cement packer; N/A TOC @ 5088'; N/.A 6,432'6,594'5,100' Ivan River Undefined Gas 20" 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ivan River Unit (IRU) 44-36Undefined Gas Pool Same 6,432'7" ~1678psi 8,308' See Schematic Length October 21, 2024 3-1/2" 8,308' Perforation Depth MD (ft): 3,449' See Attached Schematic 6,870psi 3,450psi 94' 2,940' 94' 908'904' Size 94' 9-5/8"3,449' 908' MD 50-283-20089-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.2# / L-80 TVD Burst 6,601' 8,160psi Tubing MD (ft): Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0032930 193-022 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY 20 AAC 25.055 chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:26 am, Oct 21, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.10.17 16:19:34 - 08'00' Noel Nocas (4361) 324-604 Perforate SFD 10/23/2024 DSR-10/23/24 Yes for CT work only 10/18/24 Bryan McLellan October 21, 2024 CT BOP test to 2500 psi. Oct 21, 2024 10-404 X BJM 10/24/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.25 11:00:44 -08'00'10/25/24 RBDMS JSB 102924 Well Prognosis Well: IRU 44-36 Well Name: IRU 44-36 API Number: 50-283-20089-00 Current Status: Gas Producer Permit to Drill Number: 193-022 First Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 830-8863 (C) Maximum Expected BHP: ~ 2,172 psi @ 4,937 TVD (Using 0.44 PSI/ft Gradient) Max. Potential Surface Pressure: 1,678 psi (Max BHP minus .1 psi/ft. gas gradient). Applicable Frac Gradient: Unknown FIT, drilling reports say FIT OK on 2/21/93 Shallowest Potential Perf TVD: NA / Proposed perfs are all less than 100ft TVD separating them Top of Applicable Gas Pool: Sterling Pool is Undefined at Ivan River Sanded up gas producer Brief Well Summary IRU 44-36 was Drilled & Completed in March 1993 in the Sterling A1, A4, & C1 sands with TCP guns. The well flowed at a peak rate of ~11MMCFD. In 2001 a RWO was performed where by the well was cleaned out to 7,815’. The Beluga E,D, and F sands were added and the Sterling A1, A4, and C1 sands were re-perfed – all with TCP guns. Straddle packers were ran isolating each Sterling sand with sliding sleeves to be able to selectively flow. The Beluga Sands were isolated below a plug. In August of 2011 consideration was given to converting this well to a storage well in the Sterling C1 sand. The completion was pulled and the Sterling A1 and A4 were squeezed. A new straddle packer completion was ran and the Sterling C1 re-perfed. In June 2020, the well was cleaned out with coil tubing followed by a cement squeeze of the Beluga sands, and perforating of the Sterling B2 sand flowing over 4MM. In July of 2024 the well was worked over, pulling the 4-1/2” completion and cementing in a 3-1/2” monobore completion. The Sterling sands were perfed and flowing at 3+ mmscfd into pipeline pressure. Rate was dropping so attempts were made to unload the fluid, and the well sanded up. The purpose of this work/ sundry is to clean out the well with coil tubing, and return the well to production. If production from existing zones cannot be reestablished, additional zones will be perforated in the well. Notes Regarding Wellbore Condition - Slickline tagged fill and started bailing at 3527’ (10/17/24) - Max Inclination holds ~46 degrees from 3250’ – 6000’ MD - Current Open Perfs: Sterling X3L & Sterling A1 6355-6420’ MD Procedure 1. MIRU Fox #8 Coil Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high a. Provide AOGCC 48hr notice for BOP test 3. RIH & clean out wellbore to ~6,400’ with 6% KCl & N2 a. If necessary, add foam and nitrogen for the cleanout 4. Attempt to get well back to sales pressure and rate 5. RDMO well once production is online Contingency: (If production does not come back or continues to make sand/fill) 1. MIRU E-line, PT lubricator to 2000 psi 2. Set plug above Sterling X3L sand @ ~6350’ 3. Pressure up well to ~1000-1200 psi with N2 or sales gas Well Prognosis Well: IRU 44-36 4. Perforate Sterling sands within the below gross interval: *Sterling Pool is Undefined at Ivan River Top: Sterling X2 ±6255’ MD ±4876’ TVD Btm: Sterling X3M ±6340’ MD ±4937’ TVD a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If fill is encountered during testing, coil tubing will be placed on the well as per above approved BOP test pressures to perform a fill cleanout. 5. Return well to production Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP Diagram 4. Standard Nitrogen Operations ____________________________________________________________________________________ Updated by DMA 08-22-24 SCHEMATIC Ivan River Unit IRU 44-36 PTD: 193-022 API: 50-283-20089-00-00 CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Cond 94#, -Surface 94’-Driven 13-3/8”Surface 68#, K-55 Surface 908’BTC / 12.415”115 bbl / Cmt to Surface 9-5/8”Int 47#, N-80 Surface 3,449’BTC / 8.681”270 bbl / Cmt to Surface 7”Prod 29#, N-80 Surface 7,789’BTC / 6.184”115 bbl / Cmt to 4,420’29#, P-110 7,789’8,308’BTC / 6.184” TUBING DETAIL 3-1/2”Prod 9.2# / L-80 Surface 6,601’EUE 8rd Cmt @ 5088’ 4-1/2”Prod 12.6# / L-80 6,337’6,814’TC-II / 3.958”Cplg OD = 4.932” JEWELRY DETAIL No.Depth Length ID OD Item 1 6,594’7in CIBP 7/31/24 2 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 3 6,666’0.65’4.020 5.500 1.65’ K-Anchor 4 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 5 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 6 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 7 6,768’3.1’3.958 4.500 Ported Sub 8 6,814’1.08’3.670 4.950 Wireline Entry Guide 9 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 10 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 11 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. 12 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 13 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 14 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 15 7,735’0.75’2.441 3.250 Wireline Entry Guide 16 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments S X3L 6,355’6,364’4,947’4,954’9’8/11/24 Open S A-1 6,405’6,420’4,983’4,994’15’8/10/24 Open 58-4 6,431’6,440’5,001’5,008’9’12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’6,568’5,093’5,101’11’12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Isolated 7/31/24 71-3 6,836’6,852’5,298’5,310’16’6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 14 20” @ 94’ 12 15 13 RKB: 51’ KB / GL: 26.5’AMSL 4 10 11 16 5 2 3 6 9 8 7 1 Tagged fill/guns @ 7,815’(9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 Tagged fill @ 6,850’ 6/27/20 S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 TOC @ 5088’ CBL 8-3-24 CBL TOC 4,400’ S X3L-S A-1 Tagged fill @ 3649’ 10/17/24 Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 – CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' ____________________________________________________________________________________ Updated by CAH 10-17-24 PROPOSED Ivan River Unit IRU 44-36 PTD: 193-022 API: 50-283-20089-00-00 CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Cond 94#, -Surface 94’-Driven 13-3/8”Surface 68#, K-55 Surface 908’BTC / 12.415”115 bbl / Cmt to Surface 9-5/8”Int 47#, N-80 Surface 3,449’BTC / 8.681”270 bbl / Cmt to Surface 7”Prod 29#, N-80 Surface 7,789’BTC / 6.184”115 bbl / Cmt to 4,420’29#, P-110 7,789’8,308’BTC / 6.184” TUBING DETAIL 3-1/2”Prod 9.2# / L-80 Surface 6,601’EUE 8rd Cmt @ 5088’ 4-1/2”Prod 12.6# / L-80 6,337’6,814’TC-II / 3.958”Cplg OD = 4.932” JEWELRY DETAIL No.Depth Length ID OD Item 1 6,594’7in CIBP 7/31/24 2 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 3 6,666’0.65’4.020 5.500 1.65’ K-Anchor 4 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 5 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 6 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 7 6,768’3.1’3.958 4.500 Ported Sub 8 6,814’1.08’3.670 4.950 Wireline Entry Guide 9 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 10 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 11 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. 12 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 13 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 14 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 15 7,735’0.75’2.441 3.250 Wireline Entry Guide 16 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments S X2 –X3 ~6,255’~6,355’~4,868’~4,947’Proposed TBD S X3L 6,355’6,364’4,947’4,954’9’8/11/24 Open S A-1 6,405’6,420’4,983’4,994’15’8/10/24 Open 58-4 6,431’6,440’5,001’5,008’9’12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’6,568’5,093’5,101’11’12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Isolated 7/31/24 71-3 6,836’6,852’5,298’5,310’16’6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 14 20” @ 94’ 12 15 13 RKB: 51’ KB / GL: 26.5’AMSL 4 10 11 16 5 2 3 6 9 8 7 1 Tagged fill/guns @ 7,815’(9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 Tagged fill @ 6,850’ 6/27/20 S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 TOC @ 5088’ CBL 8-3-24 CBL TOC 4,400’ S X3L-S A-1 Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 – CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Subject:RE: IRU 44-36 (PTD# 193-022) new Sundry Request - quick turnaround Date:Friday, October 18, 2024 2:28:00 PM Attachments:IRU 44-36 AOGCC 10-403 PTD 193-022 Submitted 10-17-24.pdf image003.png Chad, Hilcorp has approval to complete the CT work only, as described in the sundry application attached. The E-line work is not approved at this time and should wait for formal sundry review and approval. Condition of approval: BOP test to 2500 psi. Provide 48 hrs notice for opportunity to witness. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, October 18, 2024 1:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: IRU 44-36 (PTD# 193-022) new Sundry Request - quick turnaround Bryan, We submitted a sundry request for IRU 44-36 (PTD# 193-022) for a coil cleanout. We brought this well online in August after a workover and was flowing really good (3+ mmscfd on Oct 1st) and this week, rate went to zero after coughing up some water. We have been SL bailing for 4 days so far and making slow progress (~100-150ft/day) and we need to get about 2500ft. We still have coil tubing on the west side of the inlet, scheduled to be shipped back to the east side next week before winter and barging gets very challenging. Any chance we can get approval or a verbal approval for a coil cleanout with N2? I’ll give you a call to discuss and answer any questions you might have. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO, N2 Development Exploratory 3. Address: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: 6,594; Total Depth measured 8,308 feet 6,732; 6,999 feet true vertical 6,432 feet 6,741 (fish) feet Effective Depth measured 6,594 feet 6,667 feet true vertical 5,120 feet 5,168 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.2# / L-80 6,601' MD 5,127' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 6,814' MD 5,277' TVD Baker Premier; 6,332' MD 5,142' TVD Packers and SSSV (type, measured and true vertical depth)Baker FAB-1; N/A 6,667' MD 5,168' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Chad Helgeson, Operations Engineer 324-296 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 10 Size 94' 5 104600 0 4670 1210 Production Liner 3,449' 8,308' measured TVD 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-022 50-283-20089-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL032930 Ivan River / 71-3 Beluga Storage Gas-Undefined Gas Ivan River Unit (IRU) 44-36 Plugs Junk measured LengthCasing Structural 2,940' 6,432' 3,449' 8,308' 94'Conductor Surface Intermediate 20" 13-3/8" 94' 908' 4,760psi 7,020psi 3,450psi 6,870psi 8,160psi 908'904' Burst Collapse 1,950psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:35 pm, Sep 18, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.09.18 12:04:34 - 08'00' Noel Nocas (4361) DSR-9/27/24 RBDMS JSB 091924 Page 1/2 Well Name: IRU 044-36 Report Printed: 8/21/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:5/17/2024 End Date: Report Number 1 Report Start Date 6/27/2024 Report End Date 6/28/2024 Last 24hr Summary MIRU Fox Energy with 1.75" Coil. BOPE test witness wiaved by Jim Regg. Test BOPE 250/3000 psi. Work on source water well with production. Makeu up roll on connector. Report Number 2 Report Start Date 6/28/2024 Report End Date 6/29/2024 Last 24hr Summary RIH with 1.75" coil for FCO. Dry tag Fill at 6181' CTMD. Online down pump @ 1.75 bbls/min. Start FCO. Washed down to 6700' and lost all returns. Tagged PBTD at 6742'. Took 70 bbls to fill wellbore. Once returns lost swap and pump remaining 150 bbls/ down back side to fluff N stuff any remaning solids back into formation. Total bbls pumped 350. Report Number 3 Report Start Date 6/29/2024 Report End Date 6/30/2024 Last 24hr Summary AK Eline PT 250/3500 RIH with 3.88 GR to 6466'. RIH with Cutter Make cut at packer 6339'. RDMO Move equipmet to H pad. Report Number 4 Report Start Date 7/27/2024 Report End Date 7/28/2024 Last 24hr Summary Conduct crew orientation of location and safety related activities. Install bunding area for workover rig and equipment. Spot support equipment and workover rig. Stand workover rig mast and secure. Bullhead tubing with 102 bbls of FW, well on vac. Install BPV and N/D tree, remove from wellhead. Inspect all threads, cut and cap 1/4'' CI line. N/U 13-5/8'' 5K BOP stack. Torque connections to API specs. Install choke and kill line co-flexip hoses and connect to manifolds. Report Number 5 Report Start Date 7/28/2024 Report End Date 7/29/2024 Last 24hr Summary Continue with preparations for BOPE testing. Connect BOP control lines. Complete torquing BOP flange connections to spec. Install rig floor and prepare test joints. Install 2-7/8'' Test joint, and shell test to 250/3000 psi- found leak at blind ram bonnet seal. Changed out bonnet seal. Bullhead 102 bbl of FW, monitor well. Reapply shell test 250/3000 psi- found leak at pipe ram bonnet seal. Retorqued pipe ram bonnet seals to spec. Reapply shell test, passing test at 250/3000 psi for 5/5min. Tested BOPE as per Sundry- Valves 250/3000 psi for 5/5 min, Ram BOP's 250/3000 psi for 5/5 min, Annular BOP 250/3000 psi for 5/5 min. Perform Accumulator drawdown test, test gas alarms. 1 fail/pass on lower kelly valve. All tests witnessed by AOGCC Inspector Josh Hunt. Disengage tbg hanger tie down bolts, 11 out of 12 are out, 1 tie down bolt remaining and appears to be cold welded. Report Number 6 Report Start Date 7/29/2024 Report End Date 7/30/2024 Last 24hr Summary Complete backing off tbg hanger tie down bolts. Unseat tbg hanger and pick up to 120k lbs. Work pipe to 155k lbs. Packer not free. Pump while working the pipe up to 155k lbs- no success. Land hanger and pull BPV. E-line arrived on location, R/U E-line unit and make up CCL/RCT tool string. RIH 6450' and log up past packer. Corrolate and log up to cut position at 6337.2'. Set anchor, anchor not holding, troubleshoot issue. POOH and investigate, found anchor arms bent. Replaced 3 anchor arms and function tested. RIH with CCL/RCT tool string to 6450'. Logged up and corrolate. Set RCT at cutting depth of 6337.2'. RCT fired, POOH to surface and L/D tools. Latched onto the 4.5'' tbg string, P/U at 83k lbs., continue to PU string, weight up to 96k lbs and stabilized at 89k lbs. Cut and capped CI line, B/O and L/D tbg hanger. Attempt circulation/bullhead, could not circulate or bullhead. Prepare to POOH. Report Number 7 Report Start Date 7/30/2024 Report End Date 7/31/2024 Last 24hr Summary Complete spotting and R/U of pipe skate and racks on trailers. R/U hole fill pump and pump 22 bbls down IA. POOH and L/D 4.5'' 12.6ppf R3 TC II completion string. Spool 1/4'' CI line onto spooler. Recover premier packer assy, 2 jts, X-Nipple, 5 jts and seal assembly from PBR. Continous hole fill at 6 bbl/hr while pulling. Wait on E-Line unit to arrive from another location. Spot and R/U E-line unit. RIH with CCL/5.80'' GR/JB. Tag HUD at 6605' WLD. POOH to surface. Report Number 8 Report Start Date 7/31/2024 Report End Date 8/1/2024 Last 24hr Summary M/U and RIH w/ 7'' CIBP, tag HUD at 6600'. Set BP at 6594'. Fill hole and attempt to pressure test BP to 1000 psi- not successful. Discuss with town while monitoring 9 bph loss rate. RIH w/ 2nd 7'' CIBP. Tag BP at 6594', log up, noticed noise on CCL at 6521'- 6530'. Discuss w/town, decision made to POH and RD Eline. P/U and M/U 3-1/2'' float shoe, 1 jt of 3-1/2'' 9.2ppf EUE 8rd L80, float collar. Continue to RIH w/3-1/2'' 9.2ppf EUE 8rd L80 tubing to 5225'- presently RIH w/ completion string. Report Number 9 Report Start Date 8/1/2024 Report End Date 8/2/2024 Last 24hr Summary Fill tbg and circulate hole volume. Continue to RIH, tag CIBP at 6608' ORKB. Circulate hole clean with FW. Circulate 170bbl of IFW. Space out and land tubing hanger w/tbg bottom at 6601' ORKB. N/D BOPE and N/U tree. Test tree to 250/4500 psi for 5/5 min. R/U Cmt Unit. Pumped 41bbl cmt job and displaced w/58 bbl of FW, bumped plug to 1100 psi. Confirmed float holding, flushed tree valves. Pressured up tbg to 200 psi above final pump pressure. Secure well. R/D cement unit. Prepare to R/D W/O rig. Report Number 10 Report Start Date 8/2/2024 Report End Date 8/2/2024 Last 24hr Summary Rig down HEC 401. Prepare to move to PCU-02. Field: Ivan River Sundry #: 324-296 State: ALASKA Rig/Service: 401Permit to Drill (PTD) #:193-022Permit to Drill (PTD) #:193-022 Wellbore API/UWI:50-283-20089-00-00 Page 2/2 Well Name: IRU 044-36 Report Printed: 8/21/2024www.peloton.com Alaska Weekly Report - Operations Report Number 11 Report Start Date 8/3/2024 Report End Date 8/4/2024 Last 24hr Summary PJSM, Crew mob to location, Spot in & rig up, Pick up lube & tool string, Pressure test 250/3000-good, Run in hole with run #1 CCL/GR/CBL, Perform CBL run, Rig down & release AK eline Report Number 12 Report Start Date 8/5/2024 Report End Date 8/6/2024 Last 24hr Summary PJSM, Crew mob equipment from G pad to IRU, Spot in & rig up equipment, Nipple up BOPE, Perform 30 min MIT on tubing & IA to 2800 psi-good, Pressure test BOPE as per sundry 250-low, 3000-high, No retests, Run in hole to tag @ 6541', Reverse out 114 bbls till N2 at surface, Shut in well & pull out of hole, Trap 2000 psi on wellhead, Secure well & rig down coil for the night. Report Number 13 Report Start Date 8/10/2024 Report End Date 8/11/2024 Last 24hr Summary PJSM, Crew mob equipment to location, Spot in & rig up equipment, Pick up lube & run #1, Pressure test lube 250/3000 psi-good, Run in hole, Correlate, Perf the ST A1 (6405-6420), Rig down for the night. Report Number 14 Report Start Date 8/11/2024 Report End Date 8/12/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up lube & GPT, Pressure test 250/3000-good, Run in hole with run #1 GPT, Fluid @ 6376', Draw down pressure & monitor fluid, Pull out of hole, Pick up run #2, Run in hole, Correlate, Perf ST X3L (6355-6364), Pull out of hole, Rig down & release AK Eline. Report Number 15 Report Start Date 8/14/2024 Report End Date 8/14/2024 Last 24hr Summary Estimated Fuel Costs Report Number 16 Report Start Date 8/19/2024 Report End Date 8/20/2024 Last 24hr Summary Morning meeting jsa permit, Drive to location, Rig up slickline p/u lub. stab on tree, Need 4 1/2'' otis connection call Josh-drive to H-pad p/u, Stab on tree p/t lub. To 2500# good test, RIH w/ 2.25'' g-ring to 884'slm w/ tool to 915'slm sit w/ tool fell to 945'w/ tool to fell to 993' w/ tool would not fall pooh shut in well, RIH w/ 2.2'' star drill while pumping methanol to 873' w/ tool to 879' fell thru to 974'slm w/ tool to 977', pooh w/ hydrates in spangs, RIH w/ 3' stem w/ 1.84'' star drill to 976'slm w/ tool start pumping methanol w/ tool to 978' pooh, have prod. Flow well-can hear ice & fluid going thru choke flow for 20 min. shut in, RIH w/ 2.25'' g-ring to 952'slm w/ tool fell to 963'slm w/ tool to 965' pooh, RIH w/ 1.84'' star drill while pumping methanol to 962'slm w/ tool 967' pooh, RIH w/ 2.25'' star drill to 998'slm w/ tool fell to 1038' w/ tool to 1048' pooh, RIH w/ 2.53'' g-ring while pumping methanol to 1048'slm w/ tool to 170'slm pooh, Lay down lub. Secure well for night drive to camp, Arrive @ camp Report Number 17 Report Start Date 8/20/2024 Report End Date 8/21/2024 Last 24hr Summary Morning meeting jsa permit, Fuel truck drive to location, P/U lub. Stab on riser, RIH w/ 2.53'' g-ring to 6349'slm 6373'kb tag pooh no obstruction, RIH w/ 2.75'' g-ring to 6373'kb tag pooh no obstruction, RIH w/ 2.5''x6' dd bailer to 6373'kb w/ tool to 6376' pooh full thick fluid w/ some solids, Rig down slickline secure well for prod., Drive to G pad- 241-26 Field: Ivan River Sundry #: 324-296 State: ALASKA Rig/Service: 401 ____________________________________________________________________________________ Updated by DMA 08-22-24 SCHEMATIC Ivan River Unit IRU 44-36 PTD: 193-022 API: 50-283-20089-00-00 CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Cond 94#, -Surface 94’-Driven 13-3/8”Surface 68#, K-55 Surface 908’BTC / 12.415”115 bbl / Cmt to Surface 9-5/8”Int 47#, N-80 Surface 3,449’BTC / 8.681”270 bbl / Cmt to Surface 7”Prod 29#, N-80 Surface 7,789’BTC / 6.184”115 bbl / Cmt to 4,420’29#, P-110 7,789’8,308’BTC / 6.184” TUBING DETAIL 3-1/2”Prod 9.2# / L-80 Surface 6,601’EUE 8rd Cmt @ 5088’ 4-1/2”Prod 12.6# / L-80 6,337’6,814’TC-II / 3.958”Cplg OD = 4.932” JEWELRY DETAIL No.Depth Length ID OD Item 1 6,594’7in CIBP 7/31/24 2 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 3 6,666’0.65’4.020 5.500 1.65’ K-Anchor 4 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 5 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 6 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 7 6,768’3.1’3.958 4.500 Ported Sub 8 6,814’1.08’3.670 4.950 Wireline Entry Guide 9 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 10 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 11 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. 12 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 13 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 14 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 15 7,735’0.75’2.441 3.250 Wireline Entry Guide 16 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments S X3L 6,355’6,364’4,947’4,954’9’8/11/24 Open S A-1 6,405’6,420’4,983’4,994’15’8/10/24 Open 58-4 6,431’6,440’5,001’5,008’9’12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’6,568’5,093’5,101’11’12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Isolated 7/31/24 71-3 6,836’6,852’5,298’5,310’16’6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 14 20” @ 94’ 12 15 13 RKB: 51’ KB / GL: 26.5’AMSL 4 10 11 16 5 2 3 6 9 8 7 1 Tagged fill/guns @ 7,815’(9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 Tagged fill @ 6,850’ 6/27/20 S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 TOC @ 5088’ CBL 8-3-24 CBL TOC 4,400’ S X3L-S A-1 Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 – CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240827 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF BRU 222-24 50283201800000 220043 8/8/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 8/6/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 8/12/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/2/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 7/28/2024 HALLIBURTON CAST-CBL IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf PBU 18-13D 50029217560400 224039 8/2/2024 HALLIBURTON RBT PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT PBU Z-228 50029237180000 222055 7/28/2024 HALLIBURTON PPROF PBU Z-234 50029237620000 223065 7/29/2024 HALLIBURTON IPROF PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Please include current contact information if different from above. T39491 T39492 T39493 T39493 T39494 T39495 T39495 T39496 T39497 T39498 T39499 T39500 T39501 T39502 T39502 IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.27 11:27:22 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240813 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-24 50283201800000 22Ϭ043 8/1/2024 AK E-LINE CIBP BRU 222-26 50283201950000 224035 7/21/2024 AK E-LINE Plug BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 7/24/2024 AK E-LINE CBL BRU 241-26 50283201970000 224068 7/31/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/10/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/18/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/23/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/28/2024 AK E-LINE Hoist IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug PBU PTM P1-08A 50029223840100 202199 7/23/2024 AK E-LINE CBL PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis PTU DW-01 50089200320000 214206 7/16/2024 READ CaliperSurvey PTU DW-0ϭ 50089200320000 214206 7/17/2024 READ TemperatureSurvey Please include current contact information if different from above. T39418 T39419 T39420 T39421 T39421 T39422 T39422 T39422 T39422 T39423 T39423 T39423 T39424 T39425 T39426 T39427 T39428 T39428 IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 13:58:22 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Joshua Stephenson - (C) Subject:RE: IRU 44-36 (PTD# 193-022) Sundry # 324-296 CBL Date:Monday, August 5, 2024 10:33:00 AM Chad, Hilcorp has approval to proceed with perforating per sundry 324-296. Note that the PTD number in the subject line was incorrect. I’ve corrected it in this reply. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, August 5, 2024 7:10 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Joshua Stephenson - (C) <Joshua.Stephenson@hilcorp.com> Subject: IRU 44-36 (PTD# 192-022) Sundry # 324-296 CBL Bryan, Attached is the uncorrelated Cement bond log for IRU 44-36. The log looks good. We proposed a TOC of ~5000’ and looks like our TOC is 5018’. This is over 1200 ft above our proposed top perf. The correlated CBL will be sent to the state once received from our vendor. Let me know if you need anything else. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________IVAN RIVER UNIT 44-36 JBR 09/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 F/P on Blinds, Cycled and passed, F/P on Lower Kelly valve (power swivel) Cycled a few times and passed. Tested with 2-7/8", 3-1/2", & 4-1/2" Test joints.Nitrogen precharge bottles 24 @ 1077 PSI. Test Results TEST DATA Rig Rep:Dusty Schulze/ Ryan COperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens/Darcy Dunb Rig Owner/Rig No.:Hilcorp 401 PTD#:1930220 DATE:7/28/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopJDH240730085845 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2287 Sundry No: 324-296 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 1 FP Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" 5M P #1 Rams 1 2-7/8X5-1/2" P #2 Rams 1 Blinds FP #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4-1/16"P HCR Valves 1 4-1/16"P Kill Line Valves 3 4-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2050 200 PSI Attained P19 Full Pressure Attained P85 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1900 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P23 #1 Rams P8 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 9 9 9 7HVW&KDUWDWWDFKHG FP FP F/P on Blinds F/P on Lower Kelly %23(7HVW+LOFRUS ,YDQ5LYHU8QLW37' $2*&&,QVSERS-'+ Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/11/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 6/28/2024 AK E-LINE Perf BRU 214-13 50283201870000 222117 7/2/2024 AK E-LINE Perf IRU 44-36 50283200890000 193022 6/28/2024 AK E-LINE TubingCut Pearl 11 50133207120000 223032 6/25/2024 AK E-LINE GPT/Plug Pearl 11 50133207120000 223032 7/8/2024 AK E-LINE Perf SRU 13-09 50133203430000 181098 6/9/2024 AK E-LINE CBL/CIBP/PUNCH Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39171 T39172 T39173 T39174 T39174 T39175 IRU 44-36 50283200890000 193022 6/28/2024 AK E-LINE TubingCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.11 13:30:29 -08'00' 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: CTCO, N2 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,308'6,184' (Fill) Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 20 AAC 25.055 jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0032930 193-022 50-283-20089-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 6,814' 8,160psi 904' Size 94' 9-5/8"3,449' 908' MD See Attached Schematic 6,870psi 3,450psi 94' 2,940' 94' 908' May 30, 2024 4-1/2" 8,308' Perforation Depth MD (ft): 3,449' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ivan River Unit (IRU) 44-36Undefined Gas Pool Same 6,432'7" ~2,287psi 8,308' 6,732' Length Baker Premier & Baker FAB-1 Pkrs; N/A 6,332'(MD / 5,142'(TVD) & 6,667'(MD) / 5,168'(TVD); N/.A 6,432'6,732'5,221' Ivan River 71-3 Beluga Storage, Undefined Gas 20" 13-3/8" See Attached Schematic m n P s t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:45 am, May 17, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.05.16 17:12:24 -08'00' 324-296 10-404 DSR-5/20/24 Perforate CT BOP test to 3000 psi Rig 401, Initial BOP test of 2024 season to full RWP 5000 psi. Subsequent tests to 3000 psi SFD 5/17/2024BJM 6/5/24 X *&:JLC 6/5/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.05 13:24:13 -07'00'06/05/24 RBDMS JSB 060624 Well Prognosis Well: IRU 44-36 Well Name: IRU 44-36 API Number: 50-283-20089-00 Current Status: SI Gas Producer Permit to Drill Number: 193-022 First Call Engineer: Jake Flora (907) 777-8442 (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Maximum Expected BHP: ~ 2,959 psi @ 6,727’ TVD (Using 0.44 PSI/ft Gradient) Max. Potential Surface Pressure: 2,287 psi (Max BHP minus .1 psi/ft. gas gradient). SI Gas Producer: Last production 500 mcfd @ 122 psi on 2/21/2024, well died 2/22/2024 Brief Well Summary IRU 44-36 was Drilled & Completed in March 1993 in the Sterling A1, A4, & C1 sands with TCP guns. The well flowed at a peak rate of ~11MMCFD. In 2001 a RWO was performed where by the well was cleaned out to 7,815’. The Beluga E,D, and F sands were added and the Sterling A1, A4, and C1 sands were re-perfed – all with TCP guns. Straddle packers were ran isolating each Sterling sand with sliding sleeves to be able to selectively flow. The Beluga Sands were isolated below a plug. The well IP’d 1.8 mmscfd and 72 bwpd in this configuration but made sand. In August of 2011 consideration was given to converting this well to a storage well in the Sterling C1 sand. The completion was pulled and the Sterling A1 and A4 were squeezed. A new straddle packer completion was ran and the Sterling C1 re-perfed. In June 2020, the well was cleaned out with coil tubing followed by a cement squeeze of the Beluga sands, and perforating of the Sterling B2 sand flowing over 4MM. The well has steadily declined and is currently SI with 600’ of fill over the open perfs. The purpose of this work/ sundry is to clean out the well with coil tubing, pull the straddle completion and recomplete with cemented tubing to isolate and test multiple uphole Sterling sands. Notes Regarding Wellbore Condition 2/25/24 - 3/04/24 Multiple days bailing w 3.5” DDB from 6114-6184’ Workover Procedure 1. Provide AOGCC 48hrs notice of BOP test 2. MIRU CTU Unit, pressure test BOPs to 3000 psi 3. Load well with water, perform fill cleanout to PBTD at 6732’ 4. MI RU E-line, PT lubricator to 3,000 psi 5. Cut inner mandrel from upper packer at ~6332’ 6. RDMO E-Line & CTU 7. MIRU 401 Workover Rig 8. Provide AOGCC 48hrs notice of BOP test 9. Bullhead tubing with water (tubing volume to perfs is 102 bbls) 10. Set BPV/TWC, ND tree, NU BOPs 11. Pressure test BOPs to 3000 psi 12. Pull BPV/TWC 13. MU landing joint, pull tubing/upper packer from seals at 6640’ 14. Close BOP rams, circulate wellbore volume a) BOPs will be used as needed for wellbore circulation b) tubing + annulus WBV = 218 bbls 15. Pull & LD 4.5” tubing & upper packer/tailpipe/seal assembly Well Prognosis Well: IRU 44-36 16. RU E-line, set 7in CIBP on top of sealbore at ~ 6640’, MIT 17. Run 3.5” completion to ~6635’ a) 10’ shoe track with landing collar @ ~6625’ b) Chemical injection sub to 1500’ 18. Tag CIBP, space out to land 4’ off bottom, land hanger 19. MU cement head to landing joint 20. Mix & pump 41 bbls Class G cement (planned TOC @ 5000’) 21. Displace with 58 bbls water to bump plug 22. WOC overnight, MIT tubing & annulus to 2500 psi 23. ND BOP, NU tree & test 24. RDMO 401 Workover Rig Post Rig Procedure 1. Provide AOGCC 48hrs notice of BOP test 2. MIRU CTU Unit, pressure test BOPs to 3000 psi 3. Clean out to landing collar 4. Log CBL from PBTD to TOC, submit to AOGCC 5. Blow well dry with nitrogen trapping 2000 psi. 6. MIRU E-line, PT lubricator to 3000 psi 7. Perforate Sterling sands within the below gross interval: *Sterling Pool is Undefined at Ivan River Top: Sterling X2 6255’ MD 4868’ TVD Btm: Sterling A5 6625’ MD 5143’ TVD a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If fill is encountered during testing, coil tubing will be placed on the well as per above approved BOP test pressures to perform a fill cleanout. 8. Return well to production Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOP Diagram 4. 401 Workover Rig BOP Diagram 5. Wellhead Diagram 6. Standard Nitrogen procedure Updated by DMA 05-16-24 IRU 44-36 Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Conductor 94#, -Surface 94’-Driven 13-3/8”Surface 68#, K-55 Surface 908’BTC /12.415”115 bbl / Cmt to Surface 9-5/8”Intermediate 47#, N-80 Surface 3,449’BTC /8.681”270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’BTC /6.184”115 bbl / Cmt to 4,420’ 29#, P-110 7,789’8,308’BTC /6.184” Tubing 4-1/2”Production 12.6#, L-80 Surface 6,814’TC-II / 3.958”Cplg OD = 4.932” Production String Jewelry Detail #Depth (RKB)Length ID OD Item 1 24’1.0’3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’3.36’3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’8.08’3.958 5.875 Packer, Baker Premier 4 6,427’1.15’3.813 5.000 X Profile, 3.813” ID 5 6,640’7.82’4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 7 6,666’0.65’4.020 5.500 1.65’ K-Anchor 8 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 9A 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 10 6,768’3.1’3.958 4.500 Ported Sub 11 6,814’1.08’3.670 4.950 Wireline Entry Guide 12 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 14 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 17 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’0.75’2.441 3.250 Wireline Entry Guide 19 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments 58-4 6,431’ 6,440’ 5,001’ 5,008’ 9’ 12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’ 6,568’ 5,093’ 5,101’ 11’ 12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Open 71-3 6,836’ 6,852’ 5,298’ 5,310’ 16’ 6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 9A 4 12 2 11 10 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL TOC 4,400’ Tagged fill @ 6,850’ 6/27/20 Tagged fill @ 6184’ (3/4/24) S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 –CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' ____________________________________________________________________________________ Updated by DMA 05-16-24 PROPOSED Ivan River Unit IRU 44-36 PTD: 193-022 API: 50-283-20089-00-00 CASING DETAIL Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20”Cond 94#, -Surface 94’-Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415”115 bbl / Cmt to Surface 9-5/8”Int 47#, N-80 Surface 3,449’BTC /8.681”270 bbl / Cmt to Surface 7” Prod 29#, N-80 Surface 7,789’BTC /6.184”115 bbl / Cmt to 4,420’ 29#, P-110 7,789’8,308’BTC /6.184” TUBING DETAIL 3-1/2”Prod Surface ~6,635 Planned TOC ~ 5,000’ 4-1/2”Prod 12.6#, L-80 6,648’6,814’TC-II / 3.958”Cplg OD = 4.932” JEWELRY DETAIL No.Depth Length ID OD Item 1 ~1,500’Chemical injection sub 2 ~6,640’7in CIBP 6 6,648’18.4’4.750 5.520 18.4’ PBR 82-47 7 6,666’0.65’4.020 5.500 1.65’ K-Anchor 8 6,667’2.52’4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’1.21’3.813 5.000 X Profile, 3.813” ID 9A 6,732’---Tripoint 4-1/2” Cement Retainer 9/29/20 10 6,768’3.1’3.958 4.500 Ported Sub 11 6,814’1.08’3.670 4.950 Wireline Entry Guide 12 6,880’38.8’-4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’2.0’--Bridge Plug, capped w/ 75’ cement 14 7,107’4.7’2.347 5.810 Packer, Baker SC-1 Ret. 15 7,122’76.0’4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’3.91’2.347 5.673 Packer, Baker Model D Perm. 17 7,701’1.06’2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’0.75’2.441 3.250 Wireline Entry Guide 19 7,815’438’-4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Ft SPF Date Comments S X2 –A5 ~6,255’~6,625’~4,868’~5,143’Proposed TBD 58-4 6,431’ 6,440’ 5,001’ 5,008’ 9’ 12 12 9/4/01 3/7/93 Squeezed 2020 59-6 6,557’ 6,568’ 5,093’ 5,101’ 11’ 12 12 9/4/01 3/7/93 Squeezed, 2020 S B2 F 6,693’6,727’5,193’5,218’34’6 9/30/20 Isolate w CIBP 71-3 6,836’ 6,852’ 5,298’ 5,310’ 16’ 6 12 12 12 8/31/11 8/15/11 9/4/01 3/7/93 Squeezed 2020 74-8 7,117’7,150’5,506’5,530’33’12 3/7/93 Isolated 2011 75-3 7,163’7,184’5,540’5,556’21’12 3/7/93 Isolated 2011 82-7 7,760’7,772’5,998’6,007’12’12 3/7/93 Isolated 2011 TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 1 18 16 RKB: 51’ KB / GL: 26.5’ AMSL 8 13 14 19 9 6 7 9A 12 11 10 2 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 Tagged fill @ 6,850’ 6/27/20 S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 Planned TOC @ ~5000’ CBL TOC 4,400’ Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 –CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' Ivan River Unit IR 44-36 06-08-2020 Ivan River 44-36 20 X 13 3/8 X 9 5/8 X 7 X 4 ½ Ground Level Casing head, Vetco Gray-W, 13 5/8 3M FE X 13 3/8 SOW, w/ 2- 2 1/16 5M SSO Casing spool, Vetco Gray-W, 13 5/8 3M FE X 11 5M FE, w/ 2- 2 1/16 5M EFO Tubing head, Vetco Gray, CWCT, 11 5M FE X 11 5M FE, w/ 2- 2 1/16 5M SSO, 6 3/8 min bore, dual alignment pins on head Tubing hanger, Vetco CWC/ T/F6, 11 x 4.909 MCA lift x 4 ½ TC-2 susp, w/ 4'’ Type H BPV, 2- 3/8 control line ports Tree assy, Vetco Gray VG-M, 4 1/16 5M x 4 1/16 5M BHTA, Bowen, 4 1/16 5M FE x 7'’ SA bowen union top The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"Spherical Annular Height: 46" Weight: 12,806 13-5/8"LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2-1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves 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. No wells on this pad meet the criteria listed in 20 AAC 25.265(d). The 660- foot offset line is drawn from the pad boundary to indicate future wells drilled from this pad will not fall under 20 AAC 25.265(d). 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: CTCO, N2 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 8,308 feet 6,732; 6,999 feet true vertical 6,432 feet 6741 fish; 6867 fill feet Effective Depth measured 6,732 feet 6,332 & 6,667 feet true vertical 5,221 feet 5,142 & 5,168 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 6,814' MD 5,277' TVD Baker Premier; 6,332' MD 5,142' TVD Packers and SSSV (type, measured and true vertical depth)Baker FAB-1; N/A 6,667' MD 5,168' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 odd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 8,160psi 94' 904' 6,870psi 3,450psi Collapse 1,950psi 4,760psi 7,020psi Casing Structural 20" 13-3/8" 9-5/8" Length 94' 908' 3,449' 8,308' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 80 Casing Pressure Liner 3,369 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-344 1,680 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-022 50-283-20089-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 1,6800 Ivan River Unit (IRU) 44-36 N/A ADL032930 3,449' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ivan River / 71-3 Beluga Storage Gas-Undefined GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"8,308' 2,940' 6,432' WINJ WAG 10 Water-Bbl MD 94' 908' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:28 am, Oct 21, 2020 ManagManagDigitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.20 08:43:18 -08'00' Taylor Wellman Gas DSR-10/22/2020 RBDMS HEW 11/10/2020 gls 10/26/20 CTCO, N2 SFD 10/21/2020 Plug Perforations Perforate Rig Start Date End Date 9/1/20 9/30/20 09/02/2020 - Wednesday Conduct JSA and approve PTW. Coil crew travel to location and prepare unit for memory logging tools. Read Memory logging tools & personnel arrive in Beluga. Yellow Jacket personnel arrived with coil connectors and MHA. Travel to location and prep tools for memory logging on coil. MU external coil connector and pull test to 25k lbs. Hook up battery on Read memory logging tools. Battery duration good for ~ 36 hrs. Finish BOPE test of Stripper, Full Body, & Checks one stabbed onto the well to 250/4,000 psi. Open well and RIH with coil. Initial pressure = 2,100 psi. The drive sprocket on coil reel motor is moving toward the reel spool. Stop coil at 95 ft and evaluate options to repair. POOH with coil and close upper & lower swab. Laydown memory logging tools and injector. Use crane to pick spool and remove drive sprocket. The set screw had become loose and allowed the sprocket to slide along the shaft. Get mechanic from Ops to assist in removing set screw and replace. Install coil reel back onto unit. Install night cap on well. Laydown for the evening. 09/03/2020 - Thursday 09/01/2020 - Tuesday Petrospec coil crew arrives in Beluga. Conduct JSA and approve PTW. MIRU Coil Equipment. Test coil BOPE to 250/4000 psi. State witness waived by Jim Regg. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 Conduct JSA and approve PTW. MU Read Memory logging tools and Yellow Jacket MHA. Load coil with freshwater using Halliburton cement pump and PT lubricator 250/4,000 psi. Open well with ~ 2,000 psi WHP. Attempt to pump downhole with freshwater, WHP increased to 2,225 psi and did not decline. RIH with coil and tag at 6,820' ctmd. PUH to 6,698' and paint Orange Flag. Continue to log up to 6,200'. PUH to 5,670' and stop. Attempt to bullhead freshwater down coil and into formation and determine if only a solids bridge. Starting WHP = 1,820 psi, pump at 0.5 bpm and WHP increased to 2,450 psi. Shut down after pumping 18 bbls . Bleed down WHP to 2,000 psi. Circulate out wellbore gas while POOH with coil. Pump down coil with freshwater and take returns to surface tanks. Pump 0.5 bpm while POOH at ~ 30 ft/min. Continue POOH taking returns until 100' then come offline with pump. Pump total of 90 bbls of freshwater. At surface with coil. Attempt Injectivity test from surface with full column of water to surface. Increase WHP to 2,000 psi at 1 bpm. No injectivity. Bleed WHP down to 500 psi and shut in well. Laydown memory logging tools. Laydown lubricator and stand back injector. Install night cap for the evening. **Download memory logging data and tied into AK e-line jewelry log dated 7-11-20 . Corrected tag depth = 6,792'. ** Test coil BOPE to 250/4000 CTU Travel to location and prep tools for memory logging on coil. Laydown memory logging tools and injector. Rig Start Date End Date 9/1/20 9/30/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 09/04/2020 - Friday Conduct JSA and approve PTW. MU Cleanout BHA with up/down jet cleanout nozzle. PT lubricator to 250/4,000 psi. Open Well. Initial wellhead pressure = 540 psi. RIH with coil. While RIH, WHP dropped from 950 psi to 500 psi and ~ 5,000'. Wellhead pressure continued to drop. Stop at flag to get corrected depth. Continue to RIH and tag at 6,847'. Top perf is at 6,832'. This depth is 55' deeper than the previous day. Appears that bridge in tubing has been pushed away. Perform injectivity test. 1 bpm @ 920 psi (ctp), 1.5 bpm @ 1,6750 psi (ctp), 2.0 bpm @ 2,230 psi (ctp). Good injectivity. Do not proceed with cleanout. Rig down N2 pumpers. POOH with cleanout BHA. MU 4-1/2 cement retainer (Yellow Jacket) and PT. RIH and stop at Flag to correct depth. RIH and place retainer at corrected depth of 6,760'. Drop 5/8" ball and circulate around to set retainer. Ball on seat and pressure sheared out seat at 3,300 psi, setting slips. Attempt to pull retainer uphole to expand sealiing element. Slips are holding on retainer, but unable to pull and release from retainer to set sealing element. Increase CTP to 4,000 psi. Pins should shear at 10k over string weight. Pulling 25k over string weight, pins not shearing. Trying different pressures and max pull on truck. Unable to release from retainer. Launch 1" disconnect ball. Ball lands on seat and disconnects at ~ 4,800 psi. Disconnect from retainer. *** Fish left in hole. 3.13" x 1.06' Diconnect, 3.05" x 0.65' XO, 2.88" x 1.20' circ sub, 2.91" x 1.05' XO, 3.57" x 5.02' setting tool, 3.57" x 2.38' composite cement retainer. OAL = 9.31' ***. POOH with coil. Laydown equipment. 09/18/2020 - Friday Conduct JSA and approve PTW. Move coil equipment (Schlumberger) out to location and RU. Pressure test BOPE to 250/4,000 psi. Install night cap and travel back to camp. 09/19/2020 - Saturday Conduct JSA and approve PTW for coiled tubing (Schlumberger). Pick up injector and lubricators. MU CTC and pull test to 25K. MU MHA with dual checks. Fluid pack coil and PT to 4,000 psi. MU bi-directional jars, disconnect, fishing motor and 3.80" overshot with grapple. Crane outrigger foot is lifting off the ground opposite of the suspended load. Discuss with Peak foreman and re-level. Outrigger will not maintain level. Laydown coil BHA and troubleshoot Crane. 09/20/2020 - Sunday Conduct JSA and approve PTW. Have 80 Ton Airport Rental crane pick coil injector and monitor if outrigger cylinder is moving. The outrigger cylinder is moving down ~ 1/4" per hour. Discuss with Peak and decide to release crane. Mobilize 50 Ton Peak crane from H pad to Ivan River. MU 3.80" overshot w/ 3.13" Spriral grapple and 2.875" fishing motor (no jars). Open well and RIH. WHP = 0 psi and is fluid packed to surface. Crack choke while RIH to reduce WHP. RIH through chemical injection profile of 3.813" with no trouble. Wt check at 6,400' of 19.5K up. Tag up at X nipple (3.813") at 6,427'. Bring pump on-line and engage fishing motor. Attempt to work through X nipple. Try different rates, speeds, etc. Unable to get through X nipple. POOH. Coil at surface. Shut in swab. Laydown BHA. 3.80" overshot has some wear on the outside for a couple inches above bottom. Appeared to have barely made it into the X nipple. Good injectivity. Do not proceed with cleanout. Rig down N2 pumpers. CTU * Fish left in hole. 3.13" x 1.06' Diconnect, 3.05" x 0.65' XO, 2.88" x 1.20' circ sub, 2.91" x 1.05' XO, 3.57" x 5.02' setting tool, 3.57" x 2.38' composite cement retainer. place retainer at corrected depth of 6,760' CIBP at 6760 ft with setting tool left 02' MU 3.80" overshot w/ 3.13" Spriral grapple and 2.875" fishing motor (no jars). Open well and RIH. WHP = 0 psi and is fluid packed to surface. C Top perf is at 6,832'. Th Rig Start Date End Date 9/1/20 9/30/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 09/21/2020 - Monday Conduct JSA and approve PTW. MU and RIH w/ 1.75" CTC, 2.875" DFCV, 2.875" BiDi jars, 2.875" Disco, 2.875" fishing motor with ITCO spear. Wt check at 6,400'. Up = 18.5K lbs, down = 8.5K lbs. Tag at 6,672'. Bring pump on-line and work thru. Tag top of cement retainer (fish) at 6,760'. Pick up to 53K lbs and wait on jars to fire. Set down and fire jars down. Come back to neutral weight. Pick up to max pull of 53K and wait on jars to fire. Continue to jar upward for 30 hits. Good jar licks, but no movement of fish. Attempt to release from fish by pumping and rotating fishing motor and release spear. Slack off weight to ~ 6K lbs. Pump 1.3 bpm at 4,200 psi taking returns to surface. Motor appears to be in a stall and isn't turning. Attempt to vary pump speeds and picking up slowing. Try slacking off different weights and working pipe up down slowly. Bypass Micromotion and get increased pump rate and pressure. Pump rate of 1.7 bpm at 5,580 psi. Continue to try and slack off weight and pick up slowly. No success in releasing from fish. Drop 3/4" Disconnect ball. Ball landed on seat and disconnected. Top of fish ~ 6,745'. *** Fish left in hole. Total length = 15.54' from GS fishing neck to bottom of spear. Have 3" GS fishing neck looking up. *** *** Total length of fish in hole now: Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52'. ***POOH with coil and laydown BHA. 09/22/2020 - Tuesday AK E-line arrived in Beluga. Conduct JSA and approve PTW. Travel to Ivan River. MIRU. MU 3' x 2" tubing punch gun with 10 punches and 3/8" wall charges. RIH and Tag top of fish. Correlate depth and determine top of fish is at 6,741'. Get weight back and Punch Tubing from 6,736' - 6,739'. MU Tripoint 4-1/2" cement retainer. RIH, correlate depth and set top of retainer at 6,734'. POOH. Laydown wireline lubricator and install night cap on coil BOPE. Open well and PT cement retainer to 500 psi. Good test. Bleed down WHP and shut in upper and lower swab valves. RDMO AK-Eline equipment. 09/27/2020 - Sunday Arrive in Beluga. Conduct JSA and approve PTW for Schlumberger Coiled Tubing. Travel to location and prep for weekly BOP Test. Test coil BOPE to 250 / 4,000 psi. AOGCC witness is waived by Jim Regg. retainer set on top of fish at 6734 ft Top of fish ~ 6,745'. (total fish 25 ft long) U Tripoint 4-1/2" cement retainer. RIH, correlate depth and set top of retainer at 6,734'. Correlate depth and determine top of fish is at 6,741'. G No success in releasing from fish. Open well and PT cement retainer to 500 psi. Good test. B Tag at 6,672'. Total length of fish in hole now: Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52'. ***POOH with coil and laydown BHA. Tag top of cement retainer (fish) at 6,760' Rig Start Date End Date 9/1/20 9/30/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 AK E-line arrive in Beluga. Conduct JSA and approve PTW. Travel to location, spot equipment and RU. PT lubricator 250 / 3,000 psi. Open well. Initial WHP = 1,150 psi. RIH with 20' x 2-7/8" perf gun w/ razor charges, 6 spf, 60 deg phasing. Tag cement retainer at corrected depth of 6,732'. Send correlation data to town and confirm on depth. Perforate 6,707' - 6,727' MD. Initial press = 1,150 psi. 5 min = 1,550 psi. 10 min = 1,640 psi. 15 min = 1,680 psi. POOH. Shots fired, gun had small amount of water in bull plug. MU and RIH with 14' x 2-7/8" perf gun w/ razaor charges, 6 spf, 60 deg phasing. Tag cement retainer again, corrected depth of 6,732'. Send correlation data to town and confirm on depth. Perforate 6,693' - 6,707' MD. Initial press = 1,700 psi. 5, 10, 15 min = 1,700 psi. POOH. Shots fired, gun had small amount of water in bull plug. RDMO. Hand well over to operations. 09/28/2020 - Monday Conduct JSA and approve PTW for SLB coiled tubing. Travel to location, finish RU for cement squeeze. MU cement stinger BHA. 2.86" x 0.75' CTC, 2.87" x 0.43' XO, 3.75" x 1.38' centralizer, 2.76" x 0.71' XO, 2.88" x 2.13' disco, 2.88" x 8.0' pup joint, 2.90" x 0.43' XO, 2.63" x 0.66' XO, 3.67" x 2.0' Tripoint Stinger. PT BHA to 3,500 psi minus the stinger. go to the well and PT lubricator low/high. RIH with stinger BHA. Open well while RIH, well is fluid packed. Sting into retainer at 6,737' ctmd. Set down 6K lbs and perform injectivity test down coil. 0.5 bpm @ 950 psi. 1.0 bpm @ 2,750 psi. Confirm no flow to tank and that coil is stung into retainer. PT Halliburton cement lines low/high to 4500 psi. Batch up cement and get to weight of 15.8 ppg. Halliburton pump 5 bbls of freshwater ahead, followed by 18.4 bbls of 15.8# cement, followed by 5 bbl spacer of freshwater. Pump rate 0.6 bpm @ ~ 3,300 psi. SLB pump truck take over pumping after 5 bbl freshwater spacer. Displace cement down coil with freshwater. Pump rate = 0.5 bpm @ 3,600 psi with cement at retainer. Pressure continues to climb, reduce rate. 0.4 bpm @ 4,040 psi, 0.3 bpm @ 4,060 psi. Continue to pump at 0.2 bpm and then started to see pressure breakovers at ~ 4,100 psi. Pressure would drop ~ 300 psi, then build back up to 4,100 psi. Shut down pump and hesitate squeeze. Come back on-line at 0.2 bpm and pressure increased to 4,300 psi. Unsting from cement retainer with 14 bbls of cement below retainer. Pick up 2' above retainer and circulate remaining cement out of coil, chase returns to surface. Coil at surface. Shut in swab. Laydown BHA. Install night cap on BOP's. 09/29/2020 - Tuesday Conduct JSA and approve PTW for Schlumberger Coiled Tubing. MU 3.75" mill, motor and jars. Go to the well and PT to 250 / 4,000 psi. RIH and tag cement retainer at 6,737' without encountering any cement stringers. Pick up off retainer and circulate a ball around and shift circ sub open. Halliburton N2 pump down coil taking fluid returns to tank. Blow down well from retainer to surface. Leave ~ 1,100 psi on wellhead. RDMO. 09/30/2020 - Wednesday Halliburton pump 5 bbls of freshwater ahead, followed by 18.4 bbls of 15.8# cement, followed by 5 bbl spacer of freshwater. P Travel to location, finish RU for cement squeeze. Perforate 6,707' - 6,727' MD. Unsting from cement retainer with 14 bbls of cement below retai CTU Halliburton N2 pump down coil taking fluid returns to tank. Blow down well from retainer to surface. Leave ~ 1,100 psi on wellhead. RDMO. cement sqz Sting into retainer at 6,737' ctmd. Set down 6K lbs and perform injectivity test down coil. Perforate 6,693' - 6,707' MD. Updated by DMA 10-12-20 IRU 44-36 Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184” 115 bbl / Cmt to 4,420’ 29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 9A 6,732’ - - - Tripoint 4-1/2” Cement Retainer 9/29/20 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments S B2 F 6,693’ 6,727’ 34’ 6 Open, 9/30/20 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 6,693’ 6,707’ 71-3 6,836’ 6,852’ 16’ 6,12,12,12 Squeezed, (8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 6,732’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 9A 4 12 2 11 10 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Tagged fill @ 6,850’ 6/27/20 Tagged fill @ 5,910’ (1/27/14) S B2 F Tubing Punches 6,736’-6,739’ 9/22/20 Directional Data: max hole angle = 48.8° at 4,225’ MD FISH @ 6,741’ 9/22/20 – CEMENTED IN PLACE Cement retainer fish (8.98') + fishing BHA w/ spear (15.54') = 24.52' retainer S B2 F 6,693’6,727’34’6 cmt sqz Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 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: 10/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL IRU 44-36 (PTD 193-022) Depth Correlation 09/03/2020 Please include current contact information if different from above. PTD: 1930220 E-Set:34107 Received by the AOGCC 10/16/2020 Abby Bell 10/20/2020 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: CTCO/N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7.If perforating:20 AAC 25.055 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): 8,308'6,867 (Fill) Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 5, 2020 4-1/2" 8,308' Perforation Depth MD (ft): 3,449' See Attached Schematic 8,308' 6,432'7" 20" 13-3/8" 94' 9-5/8"3,449' 908'3,450psi 94' 904' 2,940' 94' 908' 12.6# / L-80 TVD Burst 6,814' 8,160psi MD 6,870psi Length Size Undefined Gas Pool 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 ADL032930 193-022 50-283-20089-00-00 Ivan River Unit (IRU) 44-36 Ivan River / 71-3 Beluga Storage Gas-Undefined Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 6,432'6,999'5,419'2304 psi 6,999' Baker Premier & Baker FAB-1 Pkrs; N/A 6,332'(MD / 5,142'(TVD) & 6,667'(MD) / 5,168'(TVD); N/.A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:41 am, Aug 20, 2020 320-344 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.19 18:22:15 -08'00' Taylor Wellman SFD 8/20/2020 Plug Perforations Perforate CTCO/N2 10-404 (close out 320-067 also) X CTU * 4000 psi BOPE test (CTU) gls 8/20/20 DSR-8/20/2020dts 8/20/2020 8/21/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.21 08:36:32 -08'00' RBDMS HEW 8/24/2020 Well Prognosis Well: IRU 44-36 Date: 8/18/2020 Well Name: IRU 44-36 API Number: 50-283-20089-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: August 10, 2020 Rig: CT / EL Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 193-022 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) AFE Number: Maximum Expected BHP: ~ 2,963 psi @ 6,594’ TVD (Using 0.45 PSI/ft Gradient) Max. Potential Surface Pressure: 2,304 psi Using Max BHP minus .1 psi/ft. gas gradient to 6,594’ TVD). Brief Well Summary IRU 44-36 was Drilled & Completed in March 1993 in the Sterling A1, A4, & C1 sands with TCP guns. The well flowed at a peak rate of ~11MMCFD. In February of 1996 a coil clean out was performed down to 6,848’ md. In August of 2001 a rig W/O was performed where by the well was cleaned out to 7,815’. The Beluga E, D, and F sands were added and the Sterling A1, A4, and C1 sands were re-perfed – all with TCP guns. In Sept of 2001 a workover was performed where straddle packers were ran isolating each Sterling sand with sliding sleeves to be able to selectively flow. The Beluga Sands were isolated below a plug. The well IP’d 1.8 mmscfd and 72 bwpd in this configuration but made sand. In August of 2011 consideration was given to converting this well to a storage well in the Sterling C1 sand. The completion was pulled and the Sterling A1 and A4 were squeezed. A new straddle packer completion was ran and the Sterling C1 was to be re-perfed with TCP guns. The TCP guns did not fire and they were dropped. The well was then re-perfed with E-line guns. On June 18, 2020, AOGCC approved Sundry 320-267 to clean out the well with coil and then isolate the 71-3 sand with a through Tubing Plug and cement. The well was cleaned out with coil tubing, ending on June 28, 2020. Attempts to get wireline down the well to set the through tubing plug were not successful. The purpose of this work/ sundry is to Clean out the well with coil, isolate the 71-3 sand with a cement squeeze through a cement retainer set in the tubing tail. The well will then be perforated in the Sterling B2 sand, as was approved in sundry 320-067. Notes Regarding Wellbore Condition x Coil tubing cleaned out to 6850’ on 6/27/2020 x Eline could not pass 6788’ on 6/28/2020 x Eline worked tools to 6790’ on 7/14/2020, bottom was sticky Coiled Tubing 1. MIRU CTU Unit. Pressure test BOPs to 250 psi low / 4,000 psi high. 2. RIH with BHA including GR/CCL (memory or e-coil) and JSN. Clean out fill down to 6,850’ with foam. Paint flag on coil. POOH. Correlate flag depth to jewelry log ran dated 7-11-2020. e perforated in the Sterling B2 sand, as was approved in sundry 320-067. On June 18, 2020, AOGCC approved Sundry 320-267 to clean out the well with coil and then isolate the 71-3 sand with a through Tubing Plug and cement. The well was cleaned out with coil tubing, ending on June 28, 2020. Attempts to get wireline down the well to set the through tubing plug were not successful. Notify inspector to witness. FCO retainer sqz Well Prognosis Well: IRU 44-36 Date: 8/18/2020 3. RIH with BHA including one-trip 4-1/2” cement retainer. Set retainer at ~6,760’. The objective is to set the retainer above the ported sub @ 6,770’ while leaving us some rathole for perforating. 4. Fill up CT backside and test retainer to 500 psi. 5. Pump the following down CT: a) 5 bbl freshwater spacer b) 20 bbls 15.8 ppg class G cement c) 5 bbl freshwater spacer d) Displacement fluid to get cement to the perforations 6. Establish baseline injectivity pressure while displacing cement to the perforations. 7. Aim for a squeeze pressure of 2000 psi for 30 minutes. 8. If unable to achieve a squeeze batch mix another 20 bbls of cement and attempt re-squeeze. We will remain stung into the retainer. Contact operations engineer to discuss hesitation parameters. 9. Once squeeze is achieved, un-sting from retainer and lay in remaining volume of cement in tubing. 10. Open backside and circulate gel for contamination to the stinger. Contaminate cement to top of retainer and POOH. 11. WOC until next morning. 12. RIH with BHA including motor and junk mill. Clean out to the top of the cement retainer. 13. Blow down tubing with N2. 14. POOH W/ coil. Leave 1,000 psi trapped on tubing. RDMO CT. E-line 1. RU E-line. Pressure test lubricator to 3,000 psi. 2. PU perf gun and RIH to 6,693’. Log perf gun on depth. Send correlation log to Reservoir Engineer – Anthony McConkey and Geologist – Matt Petrowsky to confirm depth. 3. Perforate the Sterling B2 sand through tubing from 6,693’ MD (6,578’ TVD) – 6,727’ (6,594 TVD) With 2-7/8” perf guns 6 SPF, 60 degree phasing. a) Record pressures at 5 min, 10 min, and 15 min intervals. 4. POOH W/ Perf guns. RDMO E-line. 5. Turn well over to production to test. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOP Schematic 4. Wellhead Diagram 5. Standard Nitrogen procedure Perforate the Sterling B2 sand through tubing from 6,693’ MD (6,578’ TVD) – 6,727’ (6,594 TVD) Set retainer on CT sqz cement Updated by DMA 07-21-20 IRU 44-36 Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184” 115 bbl / Cmt to 4,420’ 29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 71-3 6,836’ 6,852’ 16’ 6,12,12,12 (8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 6,999’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 10 4 12 2 11 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Tagged fill @ 6,850’ 6/27/20 Tagged fill @ 5,910’ (1/27/14) Directional Data: max hole angle = 48.8° at 4,225’ MD Updated by TCS 08-18-20 IRU 44-36 Proposed Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184”115 bbl / Cmt to 4,420’29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 9A ~6,760’ - - - 4-1/2” Cement Retainer 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments S B2 F ±6,693’±6,727’ 34’ 6 Proposed (TBD) 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 71-3 6,836’ 6,852’ 16’ 6,12,12, 12 Squeezed,(8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 6,999’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 9A 4 12 2 11 10 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Tagged fill @ 6,850’ 6/27/20 Tagged fill @ 5,910’ (1/27/14) S B2 F Directional Data: max hole angle = 48.8° at 4,225’ MD S B2 F ±6,693’±6,727’34’6cement sqz retainer Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 241-33 6/10/2020 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: CTCO, N2 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 8,308 feet 6,999 feet true vertical 6,432 feet 6,867(fill) feet Effective Depth measured 6,999' feet 6,332 & 6,667 feet true vertical 5,419 feet 5,142 & 5,168 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 6,814' MD 5,277' TVD Baker Premier; 6,332' MD 5,142' TVD Packers and SSSV (type, measured and true vertical depth)Baker FAB-1; N/A 6,667' MD 5,168' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 8,160psi 94' 904' 6,870psi 3,450psi Collapse 1,950psi 4,760psi 7,020psi Casing Structural 20" 13-3/8" 9-5/8" Length 94' 908' 3,449' 8,308' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 10 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-267 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 193-022 50-283-20089-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Ivan River Unit (IRU) 44-36 N/A ADL032930 3,449' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ivan River / 71-3 Beluga Storage Gas-Undefined GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"8,308' 2,940' 6,432' WINJ WAG 11 Water-Bbl MD 94' 908' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 9:05 am, Aug 07, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.07 08:31:27 -08'00' Taylor Wellman RBDMS HEW 8/7/2020 DSR-8/7/2020 SFD 8/10/2020gls 9/18/20 Rig Start Date End Date 6/22/20 7/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 E-line Prep Tools, rebuild setting tool for plug, mobe eq. to Pad. Coil R/D un-essential eq., e-line spot eq. & partial rig up, move supplies to work site. Wait on tools & e-line supplies flown in. E-line cont. rig up & surface test tools RIH w/GPT t/ 6,478' tagged, unable to wk dn, sticky Log OOH fluid level 4,414', send information to town. R/D e-line, stage eq. @ IRU 11- 06. 06/23/2020 - Tuesday MU slim BHA with CTC, dual checks, 2 x stingers, 1.75" downjet nozzle. PT lubricator on backside. RIH and soft tag 6,046'. Pull up hole and re-tag to confirm. slight overpull. Pick up above fill and start cooling down N2 unit. Clean out fill with N2/foam. Fluid pump rate = 0.7 bpm, N2 rate = 700 scfm, whp ~ 280 psi. Take bites and hard tag at 6,853'. Set down and try to jet, but unable to get past. PUH into tubing tail and go back for final sweep and tag again at 6,853'. Pump until out of foam. RIH to tag depth and jet N2 to displace fluid from wellbore while POOH. Coil at surface. Rig down. Leave equipment for e-line perforate support. 06/22/2020 - Monday JSA and PTW MIRU. Bring a swab valve and flange above existing swab in order to reach above wellhouse to flange up BOPE. Test coil BOPE to 250 psi low / 4,000 psi high. Jim Regg with AOGCC waived witness. NU BOPE on tree and finish RU. 06/24/2020 - Wednesday 06/30/2020 - Tuesday R/U slick line, had to mobe out companion flange to accommodate lubricator. Cont.R/u lubriaator, & P/T 250/3,000 psi good. RIH w/ 3" bailer dressed with mule shoe t/ 6,846' WLM, wk bailer as needed, POOH. Repair flange leak, m/u 3.76" gr no go. RIH wk through upsets as needed, no go @ WLEG 6,820 wlm', verifying depth good, POOH. RDMO w/l. 06/27/2020 - Saturday R/U , mobe in crane & n2 trailer, p/u injector, m/u coil connector, pull test t/35k good, m/u BHA- 3.5" mill, 2 7/8" mud mtr, circ. sub, Hyd disconnect, dual check valve sub, Ext. coil connector =19.1', m/u lubricator, p/t 250/4k good RIH t/5k' Wait on n2 pump R/U n2 pump, pt lines good, circ @ .7bpm, 800 SCF, 2,500-2,800 coil pressure, 1,500 annulus pressure, cleanout down t/6850', attempt make more hole, no joy, CBU clean, @7bpm, 800 SCF, 2,500-2,800 coil pressure, increase annular pressure t/2,150-2,300 Pump OOH t/surface, getting clean foam/n2 returns, t/650', clean n2 returns, cont. pump out into lubricator, s/d n2 pump, shut in wellhead pressure 2,340psi. R/D lubricator/BHA & injector, secure well. 06/28/2020 - Sunday Mobe e-line unit to IRU 44-36, re-head & p/u GPT tool GPT tool P/T lubricator, 250/3,000 good, open well, 2,335 psi, rih find fluid level @ 6,152', tagged up at 6,778', attempt to work through, no joy, POOH P/U 2.25" bailer w/spang jars, CCL, RIH t/6,644' wlm, unable to wk through, POOH R/D secure well, tool options to arrive tomorrow. CTU Rig Start Date End Date 6/22/20 7/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name IRU 44-36 50-283-20089-00-00 193-022 07/11/2020 - Saturday Mobe to location, move eq. from 11-06 to 44-36, M/U lubricator & tool string (gr, ccl, 2-wt bars.) P/T 250/3,000 RIH tag @ 6,783', wk several times to 6,785', no making progress, POOH C/O tool string 3- wt bars ,ccl, jars, starbit, P/T lubricator, repair o ring re-test 250 3,000 good, tubing pressure 2220psi. RIH tag & wk tools down t/ 6,790' started getting sticky, and stopped making progress, POOH. Consult with Engineering, decision made to pull off & look at different options. R/D & secure well. Updated by DMA 07-21-20 IRU 44-36 Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184” 115 bbl / Cmt to 4,420’ 29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 71-3 6,836’ 6,852’ 16’ 6,12,12,12 (8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 6,999’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 10 4 12 2 11 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Tagged fill @ 6,850’ 6/27/20 Tagged fill @ 5,910’ (1/27/14) Directional Data: max hole angle = 48.8° at 4,225’ MD 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: CTCO, N2 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): 8,306'6,867 (Fill) Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 tkramer@hilcorp.com 6,432'6,867'5,316'2,304 7,074' Baker Premier & Baker FAB-1 Pkrs; N/A 6,332'(MD / 5,142'(TVD) & 6,667'(MD) / 5,168'(TVD); N/.A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL032930 193-022 50-283-20089-00-00 Ivan River Unit (IRU) 44-36 Ivan River / 71-3 Beluga Storage Gas-Undefined Gas Length Size Undefined Gas Pool Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L-80 TVD Burst 6,814' 8,160psi MD 6,870psi 3,450psi 94' 904' 2,940' 94' 908' 6,432'7" 20" 13-3/8" 94' 9-5/8"3,449' 908' 8,308' Perforation Depth MD (ft): 3,449' See Attached Schematic 8,308' 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: June 23, 2020 4-1/2" m n P 66 t 2 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:26 am, Jun 17, 2020 320-267 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.17 07:50:20 -08'00' Taylor Wellman Plug Perforations SFD 6/17/2020 DSR-6/17/2020 10-404 SFD 6/17/2020 Perforate SFD 6/17/2020 20 AAC 25.055 8308' CTCO, N22 GAS gls 6/18/20Comm 6/18/2020 dts 6/18/2020 JLC 6/18/2020 RBDMS HEW 6/19/2020 Well Prognosis Well: IRU 44-36 Date: 6/8/2020 Well Name: IRU 44-36 API Number: 50-283-20089-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: June 23, 2020 Rig: CTU / E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 193-022 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Second Call Engineer: Christina Twogood (907) 777-8443 (O) (907) 378-7323 (C) AFE Number: Maximum Expected BHP: ~ 2,963 psi @ 6,594’ TVD (Using 0.45 PSI/ft Gradient) Max. Potential Surface Pressure: 2,304 psi Using Max BHP minus .1 psi/ft. gas gradient to 6,594’ TVD). Brief Well Summary IRU 44-36 was Drilled & Completed in March 1993 in the Sterling A1, A4, & C1 sands with TCP guns. The well flowed at a peak rate of ~11MMCFD. In February of 1996 a coil clean out was performed down to 6,848’ md. In August of 2001 a rig W/O was performed where by the well was cleaned out to 7,815’. The Beluga E,D, and F sands were added and the Sterling A1, A4, and C1 sands were re-perfed – all with TCP guns. In Sept of 2001 a workover was performed where straddle packers were ran isolating each Sterling sand with sliding sleeves to be able to selectively flow. The Beluga Sands were isolated below a plug. The well IP’d 1.8 mmscfd and 72 bwpd in this configuration but made sand. In August of 2011 consideration was given to converting this well to a storage well in the Sterling C1 sand. The completion was pulled and the Sterling A1 and A4 were squeezed. A new straddle packer completion was ran and the Sterling C1 was to be re-perfed with TCP guns. The TCP guns did not fire and they were dropped. The well was then re-perfed with E-line guns. The purpose of this work/ sundry is to Clean out the well with coil and then isolate the 71-3 sand with a through Tubing Plug and cement. The well will then be perfed in the Sterling B2 sand. Notes Regarding Wellbore Condition x A PT survey found fluid in the well from Sterling C1 at 3910’ MD. Coil Work 1. MIRU CTU Unit. Pressure test BOPs to 250 psi low / 4,000 psi high. 2. PU, RIH W/jet nozzle. Clean out fill down to 6,880’. POOH With coil Stand back unit. 3. MI RU E-line. Pressure test lubricator to 3,000 psi. 4. PU, RIH With TTP and set same @ 6,830’ (+/-). POOH. 5. PU Dump Bailer. Fill W/ Cement and RIH to TTP and dump 15’ of Cement on top of plug (Est. TOC = 6,815’ (+/-). POOH W/ E-line, Stand back E-line unit. 6. RU Coil Unit. RIH W/ Jet nozzle. RU Nitrogen Unit. -00 The purpose of this work/ sundry is to Clean out the well with coil and then isolate the 71-3 sand with a isolate the 71-3 sand w through Tubing Plug and cement. The well will then be perfed in the Sterling B2 sand. perfed in the Sterling B2 sand. CT (expandable Isolation plug) CT FCO displace with N2 NOTE: review Nitrogen SOP guidelines with crew before starting wellwork)( set TTP / cmt & Eline Well Prognosis Well: IRU 44-36 Date: 6/8/2020 7. Drop ball and Come on line with Nitrogen blowing out fluid to tank down to 6,750’ (+/-). POOH W/ coil. Leave 1,900 psi on tubing. RDMO Coil. 8. RU E-line. Pressure test lubricator to 3,000 psi. 9. PU perf gun and RIH to 6,693’. Log perf gun on depth. Send correlation log to Reservoir Engineer – Anthony McConkey and Geologist – Matt Petrowsky to confirm depth. 10. Perforate the Sterling B2 sand through tubing from 6,693’ MD (6,578’ TVD) – 6,727’ (6,594 TVD) With 3-1/8” perf guns 6 JSPF, 60 degree phasing. a) Record pressures at 5 min, 10 min, and 15 min intervals. 11. POOH W/ Perf guns. RDMO E-line. 12. Turn well over to production to test. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOP Schematic 4. Wellhead Diagram 5. Standard Nitrogen procedure .Perforate the Sterling B2 sand through tubing from 6,693’ MD (6,578’ TVD) – 6,727’ (6,594 TVD) Perf Sterling B2 IRU 44-36 Actual Well Schematic 1-31-14.docx Updated by STP 1-31-14 IRU 44-36 Actual Well Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184” 115 bbl / Cmt to 4,420’ 29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.750 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 71-3 6,836’ 6,852’ 16’ 6,12,12,12 (8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 8,272’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 10 4 12 2 11 Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Tagged fill @ 6,867’ (8/30/11) Tagged fill @ 5,910’ (1/27/14) Directional Data: max hole angle = 48.8° at 4,225’ MD Tagged fill @gg 910’ (1/27/1 71-3 5,9 CT FCO 71-3 Updated by DMA 06-05-20 IRU 44-36 Proposed Schematic Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Updated on 1/27/14 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 94#, - Surface 94’ - Driven 13-3/8” Surface 68#, K-55 Surface 908’ BTC / 12.415” 115 bbl / Cmt to Surface 9-5/8” Intermediate 47#, N-80 Surface 3,449’ BTC / 8.681” 270 bbl / Cmt to Surface 7” Production 29#, N-80 Surface 7,789’ BTC / 6.184” 115 bbl / Cmt to 4,420’ 29#, P-110 7,789’ 8,308’ BTC / 6.184” Tubing 4-1/2” Production 12.6#, L-80 Surface 6,814’ TC-II / 3.958” Cplg OD = 4.932” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 24’ 1.0’ 3.900 10.75 0 Tubing Hanger, 4-1/2” Vetco Gray 10” 5M 2 1,943’ 3.36’ 3.999 5.750 Chemical Inj Sub 3.813” ID, 4-1/2” TC-II 3 6,332’ 8.08’ 3.958 5.875 Packer, Baker Premier 4 6,427’ 1.15’ 3.813 5.000 X Profile, 3.813” ID 5 6,640’ 7.82’ 4.000 4.750 15.82’ Seal Assembly (Bury 8.0’ of seals) 6 6,648’ 18.4’ 4.750 5.520 18.4’ PBR 82-47 7 6,666’ 0.65’ 4.020 5.500 1.65’ K-Anchor 8 6,667’ 2.52’ 4.000 5.870 Packer, Baker Model FAB-1 (6.41’ MOE) 9 6,725’ 1.21’ 3.813 5.000 X Profile, 3.813” ID 10 6,768’ 3.1’ 3.958 4.500 Ported Sub 11 6,814’ 1.08’ 3.670 4.950 Wireline Entry Guide 11A ±6,830’ Through Tubing Plug w 15' of cement TOC ~6,815' 12 6,880’ 38.8’ - 4.950 4-5/8” TCP Gun, 12 spf (Released) 13 7,074’ 2.0’ - - Bridge Plug, capped w/ 75’ cement 14 7,107’ 4.7’ 2.347 5.810 Packer, Baker SC-1 Ret. (Min ID thru S-22 latch) 15 7,122’ 76.0’ 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242’ 3.91’ 2.347 5.673 Packer, Baker Model D Perm. 17 7,701’ 1.06’ 2.313 3.500 X Nipple, 2.313” ID, (PX Plug set 10/23/01) 18 7,735’ 0.75’ 2.441 3.250 Wireline Entry Guide 19 7,815’ 438’ - 4.500 4-1/2” TCP Gun, 12 spf (Left in hole 3/7/93) Perforation Data Zone Top Btm Amt spf Comments S B2 F ±6,693’ ±6,727’ 349’ 6 Proposed (TBD) 58-4 6,431’ 6,440’ 9’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59-6 6,557’ 6,568’ 11’ 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 71-3 6,836’ 6,852’ 16’ 6,12,12,12 (8/31/11), (8/15/11), (9/4/01), (3/7/93) 74-8 7,117’ 7,150’ 33’ 12 Isolated, TCP Perf (3/7/93) 75-3 7,163’ 7,184’ 21’ 12 Isolated, TCP Perf (3/7/93) 82-7 7,760’ 7,772’ 12’ 12 Isolated below tubing plug, TCP Perf (3/7/93) TD =8,308’ PBTD = 8,272’ 13-3/8” @ 908’ KB-THF: 24’ KB 7” @ 8,308’ 9-5/8” @ 3,449’ 17 20” @ 94’ 15 3 18 16 1 RKB: 51’ KB / GL: 26.5’ AMSL 5 8 13 14 19 9 6 7 10 4 12 2 11 11A Tagged fill/guns @ 7,815’ (9/7/01) 58-4 X 59-6 71-3 74-8 75-3 82-7 CBL Top: 4,400’ Cement PBTD: 6,999’ Top of Fill @ ~6,880’ Tagged fill @ 5,910’ (1/27/14) S B2 F Directional Data: max hole angle = 48.8° at 4,225’ MD S B2 F ±6,693’±6,727’349’6 Proposed (TBD) 6693 ' to 6727' SFD 6/17/2020 new 34 1-3 6,836’6,852’16’6,12,12,12 q ()() (8/31/11), (8/15/11), (9/4/01), (3/7/93) TTP w/cmt ----.> isolate w/plug stripper blind/shear Pipe/slip Ivan River Unit IR 44-36 06-08-2020 Ivan River 44-36 20 X 13 3/8 X 9 5/8 X 7 X 4 ½ Ground Level Casing head, Vetco Gray-W, 13 5/8 3M FE X 13 3/8 SOW, w/ 2- 2 1/16 5M SSO Casing spool, Vetco Gray-W, 13 5/8 3M FE X 11 5M FE, w/ 2- 2 1/16 5M EFO Tubing head, Vetco Gray, CWCT, 11 5M FE X 11 5M FE, w/ 2- 2 1/16 5M SSO, 6 3/8 min bore, dual alignment pins on head Tubing hanger, Vetco CWC/ T/F6, 11 x 4.909 MCA lift x 4 ½ TC-2 susp, w/ 4'’ Type H BPV, 2- 3/8 control line ports Tree assy, Vetco Gray VG-M, 4 1/16 5M x 4 1/16 5M BHTA, Bowen, 4 1/16 5M FE x 7'’ SA bowen union top 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS ON MAR 1 2 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U U Pull Tubing U Plug Perforations U Fracture Stimulate AOGCC Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other: Well Status Change ❑l 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 193-022 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic0 Service 0 6.API Number: AK 99503 50-283-20089-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL032930 Ivan River Unit(IRU)44-36 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ivan River/71-3 Beluga Storage Gas-Undefined Gas 11.Present Well Condition Summary: Total Depth measured 8,308 feet Plugs measured 7,074 feet true vertical 6,432 feet Junk measured 6,867(fill) feet Effective Depth measured 6,867 feet Packer measured 6,332&6,667 feet true vertical 5,316 feet true vertical 5,142&5,168 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 94' 94' Surface 908' 13-3/8" 908' 904' 3,450psi 1,950psi Intermediate 3,449' 9-5/8" 3,449' 2,940' 6,870psi 4,760psi Production 8,308' 7" 8,308' 6,432' 8,160psi 7,020psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCAN , Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 6,814'MD 5,277'TVD Baker Premier; 6,332'MD 5,142'TVD Packers and SSSV(type,measured and true vertical depth) Baker FAB-1;N/A 6,667'MD 5,168'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development❑., Servicephic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q ' WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ p WAG ❑ GINJ ❑ SUSF'� SPLUG❑ 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: 318-077 Authorized Name: Chad Helgeson 777-8405 Contact Name: Larry Greenstein Authorized Title: Operations Manager Contact Email: Igreenstein4hilcorp.com Authorized Signature: . /././,(7//‘ Date: 3/i/IT Contact Phone: 777-8322 ;2 /g Form 10-404 Revised 4/2017 ED!'!S ti , ,7 1 ,1 738 Submit Original Only • • . • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date IRU 44-33 50-283-20089-00 193-022 3/8/18 3/8/18 Daily Operations: 03/07/2018 -Wednesday No activity to report. 03/08/2018-Thursday Change in well status from "gas storage" to "gas producer". 03/09/2018 - Friday No activity to report. 03/10/2018-Saturday No activity to report. 03/11/2018 -Sunday No activity to report. 03/12/2018- Monday No activity to report. 03/13/2018 -Tuesday No activity to report. II , . IRU 44-36 Ivan River Unit Well IRU 44-36 Completed on 7/31/11 Actual Well Schematic Updated on 1/27/14 Hilcorp Alaska,LLL RKB:51'KB I GL:26.5'AMSL KB-THF:24'KB Casing and Tubing Detail 1` 1 , Size Type Wt/Grade Top Btm CONN/ID Cement/Other 20" t . 20" Conductor 94#,- Surface 94' Driven 13-3/8" Surface 68#, K-55 Surface 908' BTC/1/1682...415" 115 bbl/Cmt to Surface ?, 9-5/8" Intermediate 47#, N-80 Surface 3,449' BTC 681" 270 bbl/Cmt to Surface 13-318" " 7" Production 29#, N-80 Surface 7,789' BTC/6.184" 115 bbl/Cmt to 4,420' @ 908' 2 �` 29#, P-110 7,789' 8,308' BTC/6.184" ,1Tubing I' *'i 4-1/2" I Production 12.6#, L-80 Surface 6,814' TC-II/3.958" Cplg OD=4.932" I _ Production String Jewelry Detail 9-518" # Depth(RKB) Length ID OD Item @ 3,449' 1 24' 1.0' 3.900 10.750 Tubing Hanger,4-1/2"Vetco Gray 10"5M 2 1,943' 3.36' 3.999 5.750 Chemical Inj Sub 3.813"ID,4-1/2"TC-II CBL Top:4,400' 3 6,332' 8.08' 3.958 5.875 Packer,Baker Premier 4 6,427' 1.15' 3.813 5.000 X Profile,3.813"ID Tagged fill @ . : F 5 6,640' 7.82' 4.000 4.750 15.82'Seal Assembly(Bury 8.0'of seals) 5,910'(1127114) •1;tir, r.1 6 6,648' 18.4' 4.750 5.520 18.4'PBR 82-47 3 , .1.6".1 y of 7 6,666' 0.65' 4.020 5.500 1.65' K-Anchor y 8 6,667' 2.52' 4.000 5.870 Packer,Baker Model FAB-1 (6.41'MOE) Al 9 6,725' 1.21' 3.813 5.000 X Profile,3.813"ID 4 '.tirtir u 58-4 10 6,768' 3.1' 3.958 4.500 Ported Sub 1I .0.41; 11 6,814' 1.08' 3.670 4.950 Wireline Entry Guide el ;Yyr 59-6 12 6,880' 38.8' - 4.950 4-5/8"TCP Gun,12 spf(Released) et :i 13 7,074' 2.0' - - Bridge Plug, 5 ,:,,, capped w/75'cement 6 l % 14 7,107' 4.7' 2.347 5.810 Packer, Baker SC-1 Ret.(Min ID thru S-22 latch) •4r{r'I 15 7,122' 76.0' 4.480 5.500 Meshrite sand screen,2 jts(Possible holes) 7 tl 1;1r1f_ 16 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. j':f:rt , 17 7,701' 1.06' 2.313 3.500 X Nipple,2.313"ID, (PX Plug set 10/23/01) 8 'Z .tifti%•w. 18 7,735' 0.75' 2.441 3.250 Wireline Entry Guide it '3.1f1f 19 7,815' 438' - 4.500 4-1/2"TCP Gun, 12 spf(Left in hole 3/7/93) 9 ti_:} Perforation Data lit10 ••:r;f Zone Top Btm Amt spf Comments 11 Aft.: 58-4 6,431' 6,440' 9' 12,12 Squeezed,TCP Perf(9/4/01), (3/7/93) :.7-114�{�'�� 59-6 6,557' 6,568' 11' 12,12 Squeezed,TCP Perf(9/4/01), (3/7/93) t 1:Lrti}}f}ftirti '"tiftify?yr1f.. 71-3 71-3 6,836' 6,852' 16' 6,12,12,12 (8/31/11),(8/15/11),(9/4/01), (3/7/93) Tagged fill @ r r r•r r r•r, 1111111.1 rrZ.r r• 6,86T(8130111) 1r1r1r:r1 � 74-8 7,117' 7,150' 33' 12 Isolated,TCP Perf(3/7/93) 11111 75-3 7,163' 7,184' 21' 12 Isolated,TCP Pert(3/7/93) r r r•r 1 1 1.1 Cement PBTD: ` ;ryr;r;f; ..•. 12 82-7 7,760' 7,772' 12' 12 Isolated below tubinplug,TCP Perf 3/7/93 6,999' 1',.g•1.11. t ( ) x �a4* ', 13 � ••1rr• 14 r. rtir•r It, r1r •i ..1r:!r�r 1.:• 7a-8 15 f4r:'1'r1r:• •r:} 75-3 °4• 1.1• gat- . rtirtir r•r•r 16 '`' 1.1• a �:.r,ryr'`: K PSC 704 1:1. 17 `M • 18 Tagged filllguns'- 82-7 @7,815'(917101)"r� f 19 • 7"@ 8,308' %4 Directional Data: 1 TD=8,308' PBTD=8,272' max hole angle=48.8°at 4,225'MD IRU 44-36 Actual Well Schematic 1-31-14 Updated by STP 1-31-14 r • • OF T� 4+1. 1//7:.6, THE STATE Alaska Oil and Gas ofLASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ivan River Field, Beluga Undefined Gas Pool, IRU 44-36 Permit to Drill Number: 193-022 Sundry Number: 318-077 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of March, 2018. R.F." ' L K! ‘ a 2018 • i I STATE OF ALASKA RI _g/�0/ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well p 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other:Well Status Change❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development 0 193-022 3.Address: 3800 Centerpoint Dr,Suite 1400 Strati ra hic 0 Service Q6.API Number: Anchorage Alaska 99503 50-283-20089-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Ivan River Unit(IRU)44-36 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL032930 Ivan River/71-3 Beluga Storage Gas-Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,308' 6,432' 6,867' 5,316' 1 7,074' 6,867(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 94' 94' Surface 908' 13-3/8" 908' 904' 3,450psi 1,950psi Intermediate 3,449' 9-5/8" 3,449' 2,940' 6,870psi 4,760psi Production 8,308' 7" 8,308' 6,432' 8,160psi 7,020psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 6,814' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Premier&Baker FAB-1 Pkrs;N/A 6,332'(MD/5,142'(1VD)&6,667'(MD)/5,168'(TVD);N/.A 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Strat' ra is � ph 0 Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: February 28,2018 Commencing Operations: OILWINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: AS Ell ' WAG 0 GSTORresentative: ` ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Larry Greenstein Authorized Title: Operations Manager Contact Email: Igreenstein(G�hiIcorp.com Contact Phone: 777-8322 Authorized Signature: eil/#74.-- Date: 'Zit(r/ 0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: g 12 04. Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Re 'd? Er .,3 N: r q Yes 0 No 0 Ram -� (il..i�� -,<� %E1 Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: /©"ii Oy ��•'�/'`�J APPROVED BY I '' Approved by: C , COMMISSIONER THE COMMISSION Date: fGrI44 �'r�IsinForm 10-40Revised412017 Approved appiicatio i he date of approJaf. Attachments in Duplicate • • Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 February 26, 2018 Commissioners Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Ivan River Unit 44-36 Dear Commissioners: Hilcorp Alaska is requesting to change the well status of Ivan River 44-36 well from "gas 44' storage"to "gas producer". The well was permitted and converted to a gas storage well in 2011. No gas has been stored in the reservoir as the formation would not take the gas. Hilcorp has canceled the gas storage lease with ADNR,the storage injection order(SIO-11)has expired, and Hilcorp has no future plans of using this well as a gas storage well. Hilcorp is available at the commission's convenience to discuss the Sundry Application. Should you have any additional questions, please contact Larry Greenstein at 907-777-8322. Sincerely, had Helgeson Operations Manager Hilcorp Alaska, LLC iro IRU 44-36 Ivan River Unit Well IRU 44-36 Actual Well Schematic Completed on 7/31/11 Illikorp Alaska,LLc Updated on 1/27/14 RKB:51'KB 1 GL:26.5'AMSL KB-THF:24'KB Casing and Tubing Detail �F 1 .41, Size Type Wt/Grade Top Btm CONN/ID Cement/Other 20"@ 6`" 20" Conductor 94#,- Surface 94' Driven 94' ` 13 3/8" Surface 68#, K-55 Surface 908' BTC/1621.48145: 115 bbl/Cmt to Surface ,: r 1 9-5/8" Intermediate 47#, N-80 Surface 3,449' BTC 8.681 270 bbl/Cmt to Surface ' 29#, N-80Surface7,789' BTC 13-3/8" 7" Production 115 bbl/Cmt to 4,420' @ 908' t`; 29#, P-110 7,789' 8,308' BTC/6.184" •4 2 Tubing 4-1/2" Production 12.6#,L-80 Surface 6,814' TC-II/3.958" I Cplg OD=4.932" 06 tog i4iti Production String Jewelry Detail 9-518" # Depth(RKB) Length ID OD Item @ 3,449' 1 24' 1.0' 3.900 10.750 Tubing Hanger,4-1/2"Vetco Gray 10"5M 2 1,943' 3.36' 3.999 5.750 Chemical Inj Sub 3.813"ID,4-1/2"TC-II CBL Top:4,400' 4' 3 6,332' 8.08' 3.958 5.875 Packer, Baker Premier 4 6,427' 1.15' 3.813 5.000 X Profile,3.813"ID Tagged fill @rti}2. 5 6,640' 7.82' 4.000 4.750 15.82'Seal Assembly(Bury 8.0'of seals) 5,910'(1127114) , 6 6,648' 18.4' 4.750 5.520 18.4'PBR 82-47 ‘N._A--- '8 ., r AT. 7 6,666' 0.65' 4.020 5.500 1.65'K-Anchor ' ' 1:41 ` 8 6,667' 2.52' 4.000 5.870 Packer,Baker Model FAB-1 (6.41'MOE) 1,04 �;;t 9 6,725' 1.21' 3.813 5.000 X Profile,3.813"ID ti 4 :J 58-4 10 6,768' 3.1' 3.958 4.500 Ported Sub IZ ,rr•,}f 11 6,814' 1.08' 3.670 4.950 Wireline Entry Guide 1..4 tif 59-6 12 6,880' 38.8' - 4.950 4-5/8"TCP Gun,12 spf(Released) 5 4 ):::::...VS 13 7,074' 2.0' - - Bridge Plug,capped w/75'cement 'ZS14 7,107' 4.7' 2.347 5.810 Packer, Baker SC-1 Ret.(Min ID thru S-22 latch) 6 ;j •tiftir 15 7,122' 76.0' 4.480 5.500 Meshrite sand screen,2 jts(Possible holes) 7 i I :ftii( 16 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. L j•:F�Ff f 17 7,701' 1.06' 2.313 3.500 X Nipple,2.313"ID,(PX Plug set 10/23/01) 8 ;: tirtir• 18 7,735' 0.75' 2.441 3.250 Wireline Entry Guide ei�� •.stir 0 j giS 1 19 7,815' 438' - 4.500 4-1/2"TCP Gun, 12 spf(Left in hole 3/7/93) 9 -11 ::�f It' 'op Perforation Data 10 •;F`r. Zone Top Btm Amt spf Comments 11 :tiftiI 58-4 6,431' 6,440' 9' 12,12 Squeezed,TCP Perf(9/4/01), 3/7/93 513:-1.01145::: r. r.r q ( ) 13:-1.;r r`r rti 59 6 6,557' 6,568' 11' 12,12 Squeezed,TCP Perf(9/4/01), 3/7/93 ,.ti.ti.ti.ti.,.,. q ( ) y {{{ti•{ iti:i' 71.3 Tagged rill @ r•r•r•r•r.r.r..- 71-3 6,836' 6,852' 16' 6,12,12,12 (8/31/11),(8/15/11),(9/4/01), (3/7/93) jik-ti•ti•ti•..•ti 6,867'(8/30/11) 52.2.4f{:' 74-8 7,117' 7,150' 33' 12 Isolated,TCP Pert(3/7/93) r r r•r , itrf: 12 75-3 7,163' 7,184' 21' 12 Isolated,TCP Pert(3/7/93) rrr•r + Cement PBTD: tirtir'•}}r• , 82-7 7,760' 7,772' 12' 12 Isolated below tubingplug,TCP Perf 3/7/93 6,999' kr;:P..1•.• { P 9. ( ) il,!314 rti.Lr VZI i i~} -__ 74-8 15 a:51,:: - ribs 75 -3 kJ ti:}t 16 4 1.11:5S ti• +,t. `.4 f ri 'YY 17 +' t 18 Tagged fill/guns - 82-7 @7,815'1917/01) -.:4::x 7"@ 8,308' t �r Directional Data: TD=8,308' PBTD=8,272' max hole angle=48.8°at 4,225'MD IRU 44-36 Actual Well Schematic 1-31-14 Updated by STP 1-31-14 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l ?3 '~ ~' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [3 Logs 'of various kinds . [] Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • evro Ivan River Unit IRU 44 -36 Well IRU 44 -36 ft.-.........--- Actual Well Schematic Completed on 7/31/11 Updated on 8/31/11 RKB: 51' KB / GL: 26.5' AMSL Az KB - THF:24' KB Casing and Tubing Detail 1 \ ( Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20" @ 20" Conductor 94 #, - Surface 94' - Driven 94 13 -3/8" Surface 68 #, K -55 Surface 908' BTC / 12.415" 115 bbl / Cmt to Surface 9 -5/8" Intermediate 47 #, N -80 Surface 3,449' BTC / 8.681" 270 bbl / Cmt to Surface 13-3/8" 7" Production 29 #, N -80 Surface 7,789' BTC / 6.184" 115 bbl / Cmt to 4,420' @ 908' 29 #, P -110 7,789' 8,308' BTC / 6.184" 2 i Tubing 4 -1/2" 1 Production 1 12.6 #, L -80 1 Surface [ 6,814' 1 TC -II / 3.958" 1 Cplg OD = 4.932" Production String Jewelry Detail 9 - 518" # Depth (RKB) Length ID OD Item @ 3,449' 1 24' 1.0' 3.900 10.750 Tubing Hanger, 4 -1/2" Vetco Gray 10" 5M 2 1,943' 3.36' 3.999 5.750 Chemical Inj Sub 3.813" ID, 4 -1/2" TC -II CBL Top: 4,400' 3 6,332' 8.08' 3.958 5.875 Packer, Baker Premier 4 6,427' 1.15' 3.813 5.000 X Profile, 3.813" ID 5 6,640' 7.82' 4.000 4.750 15.82' Seal Assembly (Bury 8.0' of seals) IT , ' 6 6,648' 18.4' 4.750 5.520 18.4' PBR 82 -47 3 7 6,666' 0.65' 4.020 5.500 1.65' K- Anchor 8 6,667' 2.52' 4.000 5.870 Packer, Baker Model FAB -1 (6.41' MOE) _ 9 6,725' 1.21' 3.813 5.000 X Profile, 3.813" ID 4 = 584 10 6,768' 3.1' 3.958 4.500 Ported Sub 11 6,814' 1.08' 3.670 4.950 Wireline Entry Guide 596 12 6,880' 38.8' 4.950 4 -5/8" TCP Gun, 12 spf (Released) 5 _ 13 7,074' 2.0' - - Bridge Plug, capped w/ 75' cement 14 7,107' 4.7' 2.347 5.810 Packer, Baker SC -1 Ret. (Min ID thru S -22 latch) 6 I 15 7,122' 76.0' 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 16 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. 7 ref 17 7,701' 1.06' 2.313 3.500 X Nipple, 2.313" ID, (PX Plug set 10/23/01) 8 18 7,735' 0.75' 2.441 3.250 Wireline Entry Guide w. J 19 7,815' 438' - 4.500 4 -1/2" TCP Gun, 12 spf (Left in hole 3/7/93) 9 3 Perforation Data 10 Zone Top Btm Amt spf Comments 11 58 -4 6,431' 6,440' 9' 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) 59 -6 6,557' 6,568' 11' 12,12 Squeezed, TCP Perf (9/4/01), (3/7/93) Tagged fill @ 71.3 71 -3 6,836' 6,852' 16' 6,12,12,12 (8/31/11), (8/15/11), (9/4/01), (3/7/93) : • r•r•r•r• 6,867'(8130111), ti 74 - 8 7,117' 7,150' 33' 12 Isolated, e 1tititi r r• 75 -3 7,163' 7,184' 21' 12 Isolated, TCP Perf (3/7/93) •%•%•%-.. r • i • %• •r 12 Cement PBTD: •1.1.1.1• 82 - 7 7,760' 7,772 12' 12 Isolated below tubing plug, TCP Perf (3/7/93) 6,999' • r•r• : }: } : } r•r-. : }: }: 13 -;•:::•::-. r•r•r 14 rif~r •1.1. r -r•r r tirr a c-11 . 4 1.1•, - 74.8 15 l•r•r r :43%: = 75 -3 1 . 1 • • r•r•r 1 •r•r•r• 1f ti 1 1 f..... 16 1r1r1r: � 4 rg'g 17 18 Tagged fill /guns = 82.7 @ 7,815' (917101) 0 19 O // O 7" @ 8,308' / \ Directional Data: TD = 8,308' PBTD = 8,272' max hole angle = 48.8° at 4,225' MD IRU 44 -36 Acutal Well Schematic 8- 31- 11.docx Updated by STP 8 -31 -11 Chevron • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) IRU 44 -36 IVAN RIVER UNIT 44 -36 ADL0032930 5028320089 QU1638 51.00 Jobs .. • Primary Job Type Job Category Objective Actuai Start Date Actual End Date Completion - Reconfigure Major Rig 6/30/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number IRU 44 -36 502832008900 1930220 Daily_ Operations 7/1/2011 00:00 - 7/2/2011 00:00 Operations Summary Continue Barging equipment to Westside. Rig up equipment on Ivan pad. 7/2/2011 00:00 - 7/3/2011 00:00 Operations Summary Continue Barging equipment to Westside. Rig up equipment on Ivan pad. 71312011 00:00 - 7/4/2011 00:00 Operations Summary Continue Barging equipment to Westside. Rig up equipment on Ivan pad. 7/4/2011 00:00 - 7/5/2011 00:00 Operations Summary Continue Barging equipment to Westside. Rig up equipment on Ivan pad. 7/5/2011 00:00.7/6/201100:00 Operations Summary Rig up slickline and test lubricator to 250 psi low /1,500 psi high. RIH w/ shifting tool and attempt to shift sliding sleeve at 3,071' - no joy. Rig down slickline. Rig up to heater string and displace glycol w/ 90 bbl lease water. Pressure test 7" casing to FH packer at 3,117' to 1,500 psi for 30 min - test OK. Rig up wireline and test lubricator to 2501ow /1,500high. 7/6/2011 00:00 - 7/7/2011 00:00 Operations Summary RIH w/ 1- 9/16" tubing punch and tag fill at 6,112' WLM. PU and punch tubing from 6.103' - 6,109' WLM. POOH. RIH w/ 2nd 1- 9/16" tubing punch and punch tubing from 3,132' - 3,138' WLM, POOH. RD wireline. RU to pump down 2 -7/8" long string. Bullhead lease water down 2 -7/8" long string. Set BPV in 2 -7/8" long string and 2 -3/8" heater string. ND Tree. Notify John Crisp w/ AOGCC of upcoming BOPE Test at 14:05 on 7/05/11. 7/7/2011 00:00 - 7/8/2011 00:00 Operations Summary NU BOPE. RU Koomey Unit. 7/8/2011 00:00 - 7/9/2011 00:00 Operations Summary Continue to NU BOPE. Test annular to 250 psi low/ 2.500 psi high. Test remaining BOPE to 250 psi low/ 3.000 Dsi hi• h. Defer testing 3 -1/2" test joint until running 3 -1/2" workstring. AOGCC Ins•ector John Cris. •n I. -'• I • 1- • • - Pull BPV on 2 -3/8" heater string and MU landing joint. POOH and lay down 2 -3/8" heater string. 7/9/2011 00:00 - 7110/2011 00:00 Operations Summary Continue to POOH and lay down 2 -3/8" heater string. Pull BPV on 2 -7/8" long string and MU landing joint. Unseat tubing hanger and release FH packer. Circ btms up. POOH and lay down 2 -7/8" long string. 7/10/2011 00:00 - 7/11/2011 00:00 Operations Summary Continue to POOH and lay down 2 -7/8" long string. RU and test BOPE using 3 -1/2" test joint to test VBRs to 250 psi low / 3,000 psi high that was deferred on 7/08/11 until running 3 -1/2" workstring. MU 1.660" cleanout BHA. RIH on 3 -1/2" workstring to 6,210'. 7/11/2011 00:00 - 7/12/2011 00:00 Operations Summary RIH on 3 -1/2" workstring to 6,365'. MU tubing swivel and reverse circulate down to Upper SC -2 packer at 6.513' DPM (6,525' Orig RV). Wash down below packer into 2 -7/8" tubing down to 6,585' DPM (6,597' Orig RKB). Circ btms up x 2. POOH 40 stands. RIH to bottom. Spot 25 bbl Calcium Carbonate Pill. Rack back workstring. LD 1.660" cleanout BHA. 7/12/2011 00:00.7/13/2011 00:00 Operations Summary PU SC1 -L packer retrieval tool. RIH on 3 -1/2" workstring. Latch into Upper SC -2 packer at 6,525' Orig RKB. Pull and release Upper SC -2 packer and lower snap latch. Spot 25 bbl Calcium Carbonate pill. POOH 10 stands. Circ btms up x 2. POOH. UD Upper SC -2 packer and retrieval tool. 7/13/2011 00:00 - 7/14/2011 00:00 Operations Summary UD 2 -7/8" tubing and snap latch. MU 1.660" cleanout BHA. RIH on 3 -1/2" workstring to 6,585' DPM. Wash down to 6,792' DPM (6,805' Orig RKB). Circulate btms up. POOH. UD 1.660" BHA. MU seal assembly BHA. RIH on 3 -1/2" workstring to 6,214' DPM Chevron • Chevron - Alaska 1 %. Daily Operations Summary Well Name Legal Well Name Lease Surface LAM ChevNo Original RKB (ft) Water Depth (ft) IRU 44 -36 IVAN RIVER UNIT 44 -36 ADL0032930 5028320089 QU1638 51.00 Daily Operations , 7/14/2011 00:00 - 7/16/2011 00:00 Operations Summary Continue to RIH on 3 -1/2" workstring to 6,772' DPM (6,783' Orig RKB). Land snap latch in Lower SC -2 packer. Un -sting and space out above packer. Displace 8.4 ppg lease water w/ 8.8 ppg 9% KCI. Pump Calcium Carbonate pill and displace down to above packer. Land snap latch. Rig up wireline and test lubricator to 2501ow /3,000high - test OK. RIH w/ 1- 9/16" tubing punch and tag fill at 6,729' WLM. Unable to work deeper, stuck in bottom of BHA. POOH. Rig down wireline. Un -sting and circ out pill into the annulus. Reverse circ pill to surface. Sting into packer w/ snap latch. Rig up wireline and test lubricator to 2501ow /3,000high - test OK. RIH w/ 1- 9/16" tubing punch and punch tubing from 6,783' - 6,789' WLM. _POOH. Rig down wireline. Monitor well. Un -sting out of packer and PU 10' above. Monitor well. Spot Calcium Carbonate pill. Nofitied Jim Regg w/ AOGCC of upcoming weekly BOPE test. Jim Regg waived witness on 7/14/11. 7/15/2011 00:00 - 7/16/2011 00:00 Operations Summary POOH. UD seal assembly BHA. Perform weekly BOPE test._ Test annular to 250 psi low/ 2,500 psi high. Test remaining BOPE to 250 psi low/ 3,000 psi high. AOGCC witness waived by Jim Regg. PU SC1 -L packer retrieval tool. RIH on 3 -1/2" workstring to 6,730' DPM. 7/16/2011 00:00 - 7117/2011 00:00 Operations Summary Latch into Upper SC -2 packer at 6,783' Orig RKB. Pull and release Lower SC -2 packer and lower snap latch. Reverse circulate well. POOH. Fill hole on trip out and gas coming up workstring. Stabbed safety valve and shut -in annular. Monitor well and rig up to circulate down workstring. Pump 8.9 ppg 9% KCI down workstring. Monitor well, no pressure on workstring or annulus. Continue POOH. Notified AOGCC of well control evegt. UD Lower SC -2 ✓ packer, retrieval tool, tubing and snap latch. Rig up to test annulajpreventer. Test annular to 250 psi low/ 2,500 psi high. 7/17/2011 00:00 - 7M8/2011 00:00 Operations Summary MU 6" bit and 7" casing scraper assembly. RIH on 3 -1/2" workstring and set down at 6,836' DPM. Pulled free with overpull. Attempt to rotate and wash through but unable to work deeper. POOH. 7/18/2011 00:00 - 7/19/2011 00:00 Operations Summary Continue POOH. UD casing scraper BHA. MU tapered mill and 6 "string mill BHA. RIH on 3 -1/2" workstring. Tag up at 6,835' DPM w/ 10K down. Work down from 6,835' to 6,847' DPM. 7/19/2011 00:00 - 7/20/2011 00:00 Operations Summary Continue to work down from 6,847' to 6,855' DPM. Work pipe from 6,835' to 6,855' multiple times. RIH and tag fill at 7,002' DPM. Wash down mostly sand and some calcium carbonate pill from 7,002' to 7,091' DPM and tai SC -1 packer, circulate, POOH. UD tapered mill and string mill BHA. MU 7" bridge plug and setting tool. RIH on 3 -1/2" workstring. Set bridge plug at 7,074' DPM (7,086' Orig RKB). Tag bridge plug w/ 15K down to confirm set. PU to 7,064' DPM and circulate and condition hole. 7/20/2011 00:00 - 7/21/2011 00:00 Operations Summary RU to cement. Mix and pump 8 bbl (33 sx) of 15.3 ppg Class G Easy Block cement. Displace w/ 9% KCI. PU to 6,643' DPM. Reverse circ above cement plug. POOH. UU setting tool. MU 6" drilling BHA. RIH on 3 -1/2" workstring to 6,729' DPM. RU to circulate and wash down and tag hard cement at 6,866' DPM. Drill hard cement to 6,921' DPM. 7/21/2011 00:00 - 7/22/2011 00:00 Operations Summary Continue to drill hard cement from 6,921' DPM to 6,999' DPM (7,011' Orig RKB), leaving 75' cement on brid a plu at 7,074' DPM (7,086' Orig RKB). Circ 2 Hi -Vis sweeeps. Reverse circ 2 btms up. POOH. UD 6" drilling BHA. RU to pe orm weekly B PE test. oti le CG of upcoming BOP test. 7/22/2011 00:00 - 7/23/2011 00:00 Operations Summary Perform weekly BOPE test. Test annular to 250 psi low/ 2,500 psi high. Test remaining BOPE to 250 psi low/ 3,000 psi high. AOGCC witness waived by Jim Regg. RU E -line unit. RIH w/ FAST -CAST casinq /cement evaluation tool. Unable to work tool below 2,305' WLM. POOH. RIH w/ 6.0" gauge ring and junk basket. Tag up at 6,832' WLM (top of Beluga 71 -3 perfs). POOH. Re- configure FAST -CAST and remove CBL tool and 3 centralizers. RIH and log from 6,985' WLM to 4,000' WLM. POOH. 7/23/2011 00:00 - 7/24/2011 00:00 Operations Summary R/D E -line Unit. MU 7" FasDril composite bridge plug. RIH on 3 -1/2" workstring. Set bridge plug at 6,563' DPM (6,575' Orig RKB). Perform injectivity test into 58 -4 and 59 -6 perfs at 1 bpm at 240 psi. RU to cement. Mix and pump 20 bbl (83 sx) of 15.3 ppg Class G Easy Block cement. Displace w/ 9% KCI. PU to 6,020' DPM. Reverse circ above cement plug. Squeeze 2 bbl cement into perfs at 700 psi squeeze pressure. Bled to 250 psi in 40 mins. Held 250 psi for 60 mins. Circ 1 tubing volume. Monitor well. POOH. UD setting tool. 7/24/2011 00:00.7/25/2011 00:00 Operations Summary MU 6" drilling BHA. RIH on 3 -1/2" workstring to 6,181' DPM. RU to circulate and wash down and tag hard cement at 6,250' DPM. Drill hard cement to 6,560' DPM. Drill bridge plug to 6,564' DPM. C hase plug to 6,573' DPM. Monitor well. RIH to 6,930' DPM. Tag fish w/ 5K down. 7/25/2011 00:00 - 7/26/2011 00:00 Operations Summary PU power swivel and work fish down to new PBTD of 6,999' DPM (7,011' Orig RKB). Circ and cond. POOH. UD 6" drilling BHA. RU E -line unit. RIH w/ FAST -CAST casing /cement evauiation tool. RIH and log from 4,000' WLM to surface. POOH. RD E -line unit. MU lower completion assembly w/ TCP guns, tubing tail and lower packer. • Chevron 1100 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) IRU 44 -36 IVAN RIVER UNIT 44 -36 ADL0032930 5028320089 QU1638 51.00 Dolly Qperatlons 7/26/2011 00 :00 - 7/2712011 00:00 Operations Summary RIH w/ lower completion assembly w/ TCP guns, tubing tail and lower packer. RIH on 3 -1/2" workstring to 6,882' DPM. Space out to place TCP guns on depth. RU E -line unit. RIH w/ GR/CCL to correlate TCP gun depth w/ Cement Bond Log from 3/05/1993. POOH. RD E -line unit. Review logs and find guns on depth at 6,836' to 6,85'Orig RKB. Drop setting ball and pressure up to 1,500 psi to set FAB -1 packer at 6.667' Orig RKB. Pull 30K over to release setting tool. POOH. UD setting tool. MU packer plug and RTTS packer. RIH on 3 -1/2" workstring to 1,960' DPM. 7/27/2011 00:00 - 7/28/2011 00:00 Operations Summary Continue RIH on 3 -1/2" workstring to 6,663' DPM. Set packer plug in FAB -1 packer at 6,667' Orig RKB. POOH to 6,632' DPM and set RTTS. Test FAB -) packer to 1,500 psi for 10 min. POOH to 6,380' DPM and set RTTS. Test 7" casing above 6,380' to 3,100 psi for 30 min. POOH. UD RTTS. RIH w/ packer plug re tool to 6,667' Orig RKB. Circ and cond. Latch onto packer plug and rotate to release. POOH. UD 3 -1/2" workstring. 7/28/2011 00:00 - 7/29/2011 00:00 Operations Summary Continue POOH. UD 3 -1/2" workstring. UD packer plug. RU and test VBR a rams on 4 -1/2" test joint to 250 psi low/ 3,000 s0i high. PU seal assembly and Upper Packer assembly. RIH on 4 -1/2" completion tubing. 7/29/2011 00:00 - 7/30/2011 00:00 Operations Summary Continue RIH on 4 -1/2" completion tubing. Land K- Anchor and PBR in FAB -1 packer. Shear out of PBR and space out seal assembly above. Displace well with packer fluid (9% KCI and corrosion inhibitor). Spot diesel in annulus for freeze protection. Land tubing hanger. RU slickline and RIH w/ PX plug. Unable to latch plug in lower X- profile. POOH. Inspect tools and re -pin to re -run. 7/30/2011 00:00 - 7/31/2011 00:00 Operations Summary Re -run PX plug and set in lower X- profile at 6,768' WLM. POOH. RIH w/ Prong and set in PX plug body. POOH. Pressure up tubing to 4,000 psi to set Upper Packer at 6,332' Orig RKB (Premier Packer). Hold 4,000 psi for 30 min to test tubing. Test packer to 1,500 psi for 30 min. RD slickline. ND BOPE. NU Tree. Test tree to 5,000 psi high/ 250 psi low. R/D Key Pulling Unit. 8/11/2011 00:00 - 8/12/2011 00:00 Operations Summary RU slickline. RU and test lubricator to 250psi low /2,500psi high. RIH w/ 4 -1/2" swab cups. Swab fluid down to 2,200' SLM._ 8/12/2011 00:00 - 8/13/2011 00:00 Operations Summary Continue swabbing 4 -1/2" tubing down to 4,200' SLM. Shutdown for slickline unit repairs. RD lubricator. RU and test lubricator to 250psi low /2,500psi high. RIH and pull PX plug - full recovery. RD slickline and secure well. 8/14/2011 00:00 - 8/15/2011 00:00 Operations Summary RU slickline. RU and test lubricator to 250psi low /3,000 psi high. RIH w/ 2.80" GR to find fluid level. Could not determine fluid level. POOH. RIH and set PX plug in X- Profile at 6,725' RKB. Fluid level at 4,030' SLM. RD slickline unit. RU braided line unit. Test lubricator to 250 psi low /3,000 psi high. RIH w/ 4 -1/2" swab cups and swab fluid from 4,030' to 5,000' SLM. Unable to remove additional fluid below 5,000' SLM. RD braided line unit. 8/15/2011 00:00 - 8/16/2011 00:00 Operations Summary RU slickline. RU and test lubricator to 250 psi low /3,000 psi high. RIH and pull PX plug t 6,725' RKB. Load TCP firing bar and pressure up tubing to 300 psi. Drop bar - did not get acoustic confirmation of guns firing. RIH w/ 3.50" GR and find fluid level at 5,010' SLM. Tag TCP assembly at 6,803' SLM. Tap down and TCP guns fell to 6,815' SLM. Work guns down to 6,880' SLM. POOH. RD slickline. Turn well over to production. 8/16/2011 00:00 - 8/17/2011 00:00 Operations Summary Monitoring well. 8/28/2011 00:00 - 8/29/2011 00 :00 Operations Summary Test lubricator to 250psi low /2,500psi high. RIH w/ 16' 3 -1/8" perf gun. Set down at 6,828' Orig RKB. POOH. UD tools. N/D lubricator. Secure well. 8/29/2011 00:00 - 8/30/2011 00:00 Operations Summary RU slickline. Test lubricator to 250psi low /2,500psi high. RIH w/ 3.50" OD gauge ring. Tag up at 6,688' SLM, work thru and tag up at 6,838' SLM (6,862' Orig RKB). POOH. RIH w/ 3.50" 11' drive down bailer to 6,833' SLM and tag fill. Work bailer to 6,836' SLM. POOH. RIH w/ 3.50" x 11' drive down bailer to 6,838' SLM and tag fill. Work bailer to 6,841' SLM (6,865' Orig RKB). POOH. N/D lubricator. Secure well. 8/301201100:00.8131 /2011 00:00 Operations Summary RU E -line. Test lubricator to 250psi low /2,500psi high. RIH w/ 10' 3 -1/8" perf gun. Set down at 6,867' Orig RKB and tag fill. Correlate depths and place perfs from 6,842' - 6,852' Orig RKB. Fire guns. POOH. UD tools. RD Eline. Secure well. 8/31/2011 00:00 - 9/1/2011 00:00 Operations Summary RU E -line. Test lubricator to 250psi low /2,500psi high. RIH w/ 6' 3 -1/8" perf gun to 6,867' Orig RKB and tag fill. Correlate depths and place perfs from 6,836' - 6,842' Orig RKB. Fire guns, POOH. UD tools. RD Eline. Secure well. STATE OF ALASKA ALASKA NPAND GAS CONSERVATION COMMISSIO10 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate ❑ Other Ei Convert to Gas Performed: Storage Injector El Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 193 -022 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 283 - 20089 -00 •• 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL032930 [Ivan River Unit] Ivan River Unit 44 -36 " 9. Field /Pool(s): ,V11 Ivan River Field/ U n d B fi n e c - G Pool `7 1 e ,Lu p 3 $ k G - A St z ( 1 �1 J/ 10. Present Well Condition Summary: Total Depth measured 8,308 feet Plugs measured 7,074 feet true vertical 6,432 feet Junk measured 6,867 (Fill) feet Effective Depth measured 6,867 feet Packer measured 6,332; 6,667 feet true vertical 5,316 feet true vertical 5,142; 5,168 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 94' 94' • Surface 908' 13 -3/8" 908' 904' 3,450psi 1,950psi Intermediate 3,449' 9 -5/8" 3,449' 2,940' 6,870psi 4,760psi Production 8,308' 7" 8,308' ECE1}3Z 1�Y! Et OCT 160psi 7,020psi Liner 0 Perforation depth Measured depth 6,836 -6,852 feet t A 0 4 2 °11 True Vertical depth 5,293 -5,305 feet Mesita Oil &e Gas Cons. COtilim$sfon �R �" r'� �r 5aty Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6#/ L -80 6,814' 5,277' Baker Premier Packer 6,332'(MD); 6,667'(MD) Packers and SSSV (type, measured and true vertical depth) Baker FAB -1 Packer 5,142'(TVD); 5,168'(TVD) N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): 6,431' - 6,440'; 6,557' - 6,568' d] � :g `, (' Treatment descriptions including volumes used and final pressure: 20 BBL 15.3ppg Class G Easy Block cement at 700psi final squeeze pressure. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A 10 200 Subsequent to operation: N/A N/A N/A 0 1,240 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR o - WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 311 -208 Contact Chris Kanyer Phone: 263 -7831 Printed Name Timothy C. Branden.urg Title Drilling Manager ■ Signature 'r' _ Phone 276 -7600 Date 10/4/2011 I AB AS OCT 04 101 P(;; c Form 10 -404 Revised 10/2010 Submit Original Only ID Page 1 of 1 • Maunder, Thomas E (DOA) From: PORHOLA, STAN T [stan.porhola @chevron.com] Sent: Thursday, August 04, 2011 3:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Cc: Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)]; Eastham, Kevin (KEastham); Greenstein, Larry P; Ross, Gary D; Castillo, Flaco; Powell, Dennis A Subject: Notice to Commence Initial Gas Storage Injection - IRU 44 -36 (PTD 193 -022), SIO 11 Jim, Tom, and Winton, This is a notification that Union Oil Company of California plans to start Gas Storage Injection in well IRU 44 -36 (PTD 193 -022) under Storage Injection Order No. 11 around August 15tH We will be in contact to coordinate the witnessed MIT after stabilized conditions have been established. Stan Porhola•• Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 d �f^ D AUG 1 5 201 Cell 907 229 1769 stan.porhola@chevron.com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy thi s message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. 8/4/2011 • • Page 1 of 1 Regg, James B (DOA) From: Nienhaus, Doug R [nienhausd @chevron.com] (r7 1(741 Sent: Thursday, July 28, 2011 1:39 PM l 1 To: Regg, James B (DOA) Subject: IRU 44 -36 P'.6 lR 3 -0L2- Mr. Regg As per our conversation today, Chevron IRU 44 -36 is due for a BOP Test on 7/29/11. We have just completed laying down our work string and are prepared to run our 4'/2" completion. Chevron would like to test only the VBR'S on 4 %2" pipe to 250/3000 PSI & move right in to running completion today. We should have the well completed by end of day tomorrow. If we encounter problems and the completion v has to be pulled, chevron will perform a complete BOP test when we get out of the hole. Regards Doug R Nienhaus Drilling Superintendent Chevron North America Exploration & Production Company (a Chevron U.S.A Inc. division) 3800 Centerpoint Drive. , Anchorage,Alaska 99503 z "; i+ A' 0 -' L01 Office 907 - 263 -7840 CeII 907 - 223 -6947 nienhausd@chevron.com 7/28/2011 • • Page 1 of 1 Regg, James B (DOA) From: Menapace, Michael Sam [MQIK @chevron.com] qt.. I I CI Sent: Sunday, July 17, 2011 5:34 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Nienhaus, Doug R; PORHOLA, STAN T; Brandenburg, Tim C Subject: BOP test due to closure zpa. 44 Attachments: Key 003 7- 16- 11.xls 1'"t t(73 — Michael "Sam" Menapace Drill Site Manager MQIK @chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501 -3322 Mobile 907 230 8031 Home 907 283 2812 Fax 1 866 401 9376 eD JUL 1 8 2011 7/18/2011 • • STATE OF ALASKA 01/25/10 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq @alaska.gov doa.aogcc.prudhoe.bav @alaska.qov phoebe. brooksaalaska. qov Contractor: Key Energy Rig No.: 3 DATE: 7/16/11 Rig Rep.: John Nodolf Rig Phone: Rig Fax: Operator: Chevron Op. Phone: 776 -6606 Op. Fax: Rep.: Sunderland /Menapace E -Mail MQIK @chevron.com Well Name: IRU 44 -36 - PTD # 1930220 Operation: Drlg: Workover: x Explor.: Test: Initial: Weekly: x Bi- Weekly Test Pressure: Rams: 200/3000 - Annular: 200/2500 - Valves: 200/3000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 NT Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 0 NA Standing Order Posted P Misc NA Inside BOP 1 NT FSV Misc 1 P 1 BOP STACK: Quantity Size /Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 NA Trip Tank NA NA Annular Preventer 1 13 5/8" P .' Pit Level Indicators NA NA #1 Rams 1 Blinds NT Flow Indicator NA NA #2 Rams 1 2 7/8x5" var NT Meth Gas Detector NT NT #3 Rams 0 NA H2S Gas Detector NT NT #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 2 1/16" P Inside Reel valves 0 NA HCR Valves 1 2 1/16" NT Kill Line Valves 3 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure NT CHOKE MANIFOLD: Pressure After Closure NT Quantity Test Result 200 psi Attained NT No. Valves 11 NT Full Pressure Attained NT Manual Chokes 1 NT Blind Switch Covers: All stations YES Hydraulic Chokes 1 NT Nitgn. Bottles (avg): CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 1.0 Hours Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: jim.regg @alaska.gov Remarks: Test Annular preventer, inside kill line valve, manual choke, and FSV to 250/2500 psi due to closure of ✓ annular preventer for a well control event. Tested annular as soon as we were out of the hole 24 HOUR NOTICE GIVEN YES NO Waived By Date 7/16/11 Time 14:00 Witness Test start 22:00 Finish 23:00 PLB 01/25/10 Key 003 7- 16- 11.xIs Page 1of1 I/ 4k 44 -34, Regg, James B (DOA) p, p, jq 3 zZ From: Menapace, Michael Sam [MQIK @chevron.com] Sent: Saturday, July 16, 2011 2:12 PM (Vi ` I8I I( To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Nienhaus, Doug R; PORHOLA, STAN T; Brandenburg, Tim C; Sunderland, Sloan [Swift Technical Services] Subject: BOP closure notification Mr. Regg We closed the annular preventer to circulate out a small 20 psi gas kick @ 09:15 on July 16 Our last BOP test was on July 15th. We will test the annular as soon as we get out of the hole and follow up with a test form. Please let me know if you need any other information Thanks Michael "Sam" Menapace Drill Site Manager MQIK @chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501 -3322 Mobile 907 230 8031 Home 907 283 2812 Fax 1 866 401 9376 7/18/2011 • • SIKH o ARASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg ° Drilling Manager t f Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: Ivan River Field, Undefined Gas Pool, Ivan River Unit 44 -36 Sundry Number: 311 -208 Dear Mr. Brandenburg: 4 4f JU 2.01i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. I S? Chair DATED this / day of July, 2011. Encl. • • 0. Chevron Timothy C Brandenburg Union Oil Company of California 4101 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com June 27, 2011 EN, 1 _ 11N 2 8 7..0t Commissioner Alaska Oil & Gas Conservation Commission Alb :8 Gil & Gat Coos. Commission 333 W. 7 Avenue, Suite 100 Anrherago Anchorage, Alaska 99501 -3572 Re: Ivan River Unit 44 -36 PTD: 193 -022 Conversion to Gas Storage, Application for Sundry Approval Dear Commissioner Enclosed is an Application for Sundry Approval (Form 10 -403) for the above referenced well. The outlined workover is for conversion from a shut -in gas well to gas storage, scheduled to start July 2 " We would like to request a variance from requirements of 20 AAC 25.035(e)(1)(A), requiring BOPS for each size of tubing to be run in t e ell. We are planning t• . 3 preventer stackup. From top to bottom, we will run an annular preventer, blind rams, and 7/8 "x5" ariable pipe rams. The long string will be 2 -7/8" and the heater string will be 2 -3/8 ". Lease - - will be pumped down the heater string annulus to displace the glycol currently above the FH packer at 3,117' and the annulus tested to 750 psi prior to mobilizing the pulling unit. The 2 -3/8" heater string will be pulled before removing the FH packer at 3,117'. In the event of a need to shut -in during removal of the heater string, the rig crew will have a joint of 2 -7/8" tubing with a 2 -3/8" crossover ready to place across the 2- 7/8 "x5" variable rams or the annular preventer to be able to close in on the well if necessary. Therefore, pulling of the heater string separately without a 2 -3/8" pipe ram should not present a risk to well control. Due to the proximity of the Key Energy pulling unit to the well IRU 14 -31 (PTD 175 -008), we will keep this well in a shut -in status for the duration of our workover program at Ivan River which is expected to last into mid - August. This well is historically used for produced water disposal. During the workover program, we will be utilizing IRU 13 -31 (PTD 192 -088) for disposal injection purposes. This well is currently being used in the place of IRU 14 -31 for produced water disposal in anticipation of the start of the workover program in late June. If you have any questions pertaining to this variance, please contact Stan Porhola 907 - 263 -7640. Timothy C. Brandenburg Drilling Manager Enclosure Cc: Well File Union Oil Company of California / A Chevron Company vt4 << w- • ∎.I 6•$11110 REC `1 \7 " °r► STATE OF ALASKA i IN , "i; ) 0I1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSIUa: .1 a & Ci Crf�5. C r 20 AAC 25.280 1 / . +ra o ff,,MM 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change app�bv€t Program ❑ Suspend ❑ Plug Perforations 0 / Perforate 0 ° Pull Tubing 0 • do w.VGYt fo ' T J iime E`tgnson ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: pet t e ai +.-c-o r . 2. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ► Union Oil Company of California Development El • Exploratory ❑ 193 -022 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 283 - 20089 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Ivan River Unit 44 -36 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL032930 [Ivan River Unit] IVAN RIVER FIELD / UNDEFINED GAS POOL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): _ Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8,308' 6,438' / 8,272' 6,408' 6,806' 6,217' (Fill) Casing Length Size MD / TVD Burst Collapse Structural Conductor 94' 20" 94' 94' Surface 908' 13 -3/8" 908' 904' 3,450 psi 1,950 psi Intermediate 3,449' 9 -5/8" 3,449' 2,940' 6,870 psi 4,750 psi Production 8,308' 7" 8,308' 6,432' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing M 6,431' - 7,772' 4,996' - 6,002' 2 -7/8" & 2 -3/8" (heater) / 6.4# L -80 & 4.6# L -80 7,735' 2, 990' (heater) Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): f FH /SC- 2 /SC- 2 /SC -1 /Model D packers & N/A 3, 117 '/6,525'/6,753' /7,107'/7,242' MD (2, 710/5,067'/5,235' /5,49615,597' ND) & N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Development ❑ Service El • 14. Estimated Date for 2 -J -11 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR El . SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263 -7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature / 1 LAt-- Phone 276 -7600 Date 6/27/2011 COMMISSION USE ONLY t Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t k.' a 04 % Plug Integrity Lid BOP Test Mechanical Integrity Test 2 Location Clearance ❑ Other: ? fo 20 Aitc. Ls. Zgs a.) , aifE✓K et!. 3o ;S stilprlvvtd• 1,J a11 op : 0 1..., r&u.if eo K.40r.•1 to OP ✓a1 ZK e,,. orJer !lc °L1. 49" tl • Test BoPE to T000 ft z, Subsequent Form Required: 1 0 _ n q . 0 i APPROVED BY Approved by: O 7 it i J MMISSIONER THE COMMISSION Date: RB S JUL tS 2Qf ; „P 6' Zif <r Form 10 -403 Revised 1/2010 1 G I N AL Submit in Duplicate VV Y • • Chevron Ivan River Unit IWO IRU 44 -36 6 -22 -2011 Objective: • Pull current completion; Convert to gas storage completion with 4 -1/2" tubing. Current BHP: 665 psi @ 5,302' TVD 2.4ppg EMW (Based on depleted Beluga 71 -3 sand) Maximum BHP 2,468 psi @ 5,546' ND 8.6ppg EMW (Based on non - depleted Beluga 75 -3 sand) MASP: 2,191 psi (Based on actual reservoir conditions of the Beluga 75 -3 sand and dry gas (0.56 sp gr) gradient (0.05psi /ft) to surface) Procedure Summary: 1. MIRU Key Energy Rig #3. 2. Kill well with 8.4 ppg lease water. Install BPV, ND tree. 3. NU BOPE & test same 250psi low/ 3,000psi high, Test annular to 2500pss ow/ 2,500psi high. Contingency: If unable to thread test joint into hanger, anchor tsePs tg bottom rams to test. t 4. Pull BPV. Pull 2 -3/8" heater string. (Displace glycol above FH packer with water prior to rig). 5. Pull on 2 -7/8" production string to unset FH packer at 3,117'. 6. Pump 8.4 ppg lease water down tubing and annulus. 7. RU E -line. RIH and cut tubing at 6,200' ( + / -). 8. Pull 2 -7/8" production tubing from cut depth of 6,200' ( +1 -). 9. Wash down and retrieve tubing down to upper SC -2 packer at 6,525'. 10. Retrieve upper SC -2 packer at 6,525'. 11. Wash down and retrieve tubing down to lower SC -2 packer at 6,753'. 12. Displace 8.4 ppg lease water tor$.8 ,ISpg 9% KCI. 13. RU E -line. RIH and punch tubing above G -stop at 6,805'. 14. Spot 20 to 40 bbl Calcium Carbonate pill to isolate the 71 -3 interval. 15. RIH and cut tubing above G -stop at 6,805'. RD E -line. 16. Retrieve lower SC -2 packer at 6,753'. 17. Wash down and retrieve tubing down to SC -1 packer at 7,107' ( + / -). 18. PU 7" casing scraper and tag cut tubing above SC -1 packer at 7,107' ( + / -). 19. RU E -line. RIH w/ casing and cement evaluation log above and below Beluga 71 -3 zone at 6,836'- 6,852'. Iti s oft 20. PU Cast -Iron Bridge Plug. Set Bridge Plug above tubing cut above SC -1 packer at 7,107'. IA ' ` � 21. Tag Bridge Plug w/ 10k to confirm set. 2 • /( 06/22/2011 SP • • Chevron Ivan River Unit M11110 IRU 44 -36 MOO 6 -22 -2011 22. Mix and pump 5 to 8 bbl cement and spot on top of Bridge Plug. Wait on cement. 23. PU 7" casing scraper and 6" bit. RIH to top of cement at 6,875' ( + / -). 7 S t. 1/416/4" .. 24. Drill out cement, leaving a minimum & cement on top of ba. a✓ l 25. PU Drillable Bridge Plug and set below base of 59 -6 zone at 6,568'. 26. Perform injectivity test of Beluga 58 -4 and 59 -6 zones. 27. Mix and pump 10 to 20 bbl cement and spot on top of Bridge Plug. Squeeze into zones. Wait on cement. 28. PU 6" bit. RIH to top of cement at 6,425' ( + / -). Drill out cement to drillable Bridge Plug. Contingency: If no cement is found above bridge plug, plan to pump a 2 cement job. 29. Drill out drillable Bridge Plug. Cleanout to plugback depth of 7,055' ( + / -). 30. PU 16' of 4 -5/8" TCP guns and 7" FAB -1 packer. Correlate on depth and set packer at 6,725' ( + / -). Note: TCP guns will be correlated to perforate the following intervals: Beluga 71 -3 from 6,836'( + / -) to 6,852'( + / -) ®� � �, 29 1/ 31. PU 7" Premier Packer, anchor assembly and 4 -1/2" completion tubing. 32. RIH and land anchor in FAB -1 packer. Space out completion. 33. RU slickline. RIH and set N -test tool in profile below Premier Packer at 6,400' ( + / -). 34. Pressure up tubing and set packer. Test tubing to 3,400 psi for 30 min. Pull N -test tool. 35. Test annulus to Premier Packer at 6,400' ( + / -) to 2,500 psi for 30 min. 36. Set BPV. ND BOPE. Pull BPV. Set TWC. NU and test tree. 250psi Low/ 5,000psi High. Pull TWC. 37. Release Key Energy Rig #3. 38. RU slickline. RIH and pull PX plug from below FAB -1 packer at 6,725' ( + / -). 39. Turn well over production for gas storage operations. 06/22/2011 SP • wro Ivan River Unit IRU 44 -36 Well IRU 44 -36 %"*"......./". Actual Wellbore Schematic Completed 4/11 1 Updated 4/14/11 RKB: 51' KB 1 GL: 26.5' AMSL KB-THF: 24' KB Casing and Tubing Detail 1 L Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20" @ i 20" Conductor 94 #, - Surface 94' - Driven 94' 13 -3/8" Surface 68 #, K -55 Surface 908' BTC / 12.415" 115 bbl / Cmt to Surface 9 -5/8" Intermediate 47 #, N -80 Surface 3,449' BTC / 8.681" 270 bbl / Cmt to Surface 7" Production 29 #, N -80 Surface 7,789' BTC / 6.184" 115 bbl / Cmt to 4,400' 13.318" 29 #, P -110 7,789' 8,308' BTC / 6.184" @908' 2 L.. Tubing 2 -7/8" Production 6.4 #, L -80 Surface 7,735' IBT SCC / 2.441" Cplg OD = 3.220" as 3 2 -3/8" Heater 4.6 #, L -80 Surface 2,990' IBT SCC / 1.995" Fluid: Propylene Glycol t 9-5/8" @3'449' Production String Jewelry Detail # Depth (RKB) Length ID OD Item CBL TOC: 4,400' Dual Tubing Hanger, 2 -7/8" x 2 -3/8" 10" 5M Vetco 1 22' 0.30' 2.441 - Gray (2 -7/8" & 2 -3/8" IBT lift threads) Fill at6,217' 2 3,071' 3.86' 2.313 3.750 Sliding Sleeve, Baker, CMD, 2 -7/8" [CLOSED] 4 ■ Tag 4114/11 3 3,117' 6.40' 2.441 5.980 Packer, FH Retrievable (30K Shear) 1•S• :ftif 4 6,384' 3.85' 2.313 3.750 Sliding Sleeve, Baker, CMD, 2 -7/8" [CLOSED] E I 4 5 6,525' 4.71' 2.347 5.970 Packer, Baker SC -2 Ret. (Min ID thru S -22 latch) ' r•r• At r•r 6 6,548' 3.87' 2.313 3.750 Sliding Sleeve, Baker, CMD, 2 -7/8" [LEAKING] 1.ti.ti ti ..ti.. ti+ 1ftifti :PS ryf;1 58.4 Fish, 1/3 of Pinning Protection Sleeve from 2.5" GR r•r• r •r•r'. g f ; r ti � ti. ;r . ,. 7 6,660' 0.18' 2.200 adapter (2.2" OD, ' /z' thick), (lost 2/14/06) - 7e. _ 8 6,753' 4.69' 2.347 5.970 Packer, Baker SC -2 Ret. (Min ID thru S -22 latch) 5 9 6,805' - - - G -Stop (set 9/5/04) tif; . wm i •L•,•. 4 tifti, 1 0 6,806' - - - Packoff (set 9/5/04) ' r• •r•r � }•r• �f ?f' ti . ▪ f�fti 11 6,807' - - - Separation Tool w/ Side Door Choke (set 11/14/01) , ti }.F }' 3r,: } }. 6 r ti , ;rtif, ' • L , . 12 6,807' 3.87' 2.313 3.750 Sliding Sleeve, Baker, CMD, 2 -7/8" IBT [OPEN] :. '" 7 . {ftif'' f4f + ". 5 13 7,068' 1.14' 2.313 3.500 X Nipple, 2.313" ID, ...r... [_� •r•. 1 14 7,107' 4.7' 2.347 5.810 Packer, Baker SC -1 Ret. (Min ID thru S -22 latch) 8 = '. , 15 7,122' 76.0' 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) j�'1 16 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. ti ~ 17 7,701' 1.06' 2.313 3.500 X Nipple, 2.313" ID, (PX Plug set 10/24/01) 9 18 7,735' 0.75' 2.441 3.250 Wireline Entry Guide 10 19 _ 7,815' 438' - 4.500 4 -1/2" TCP Gun, 12 spf (Left in hole 3/7/93) • ' 1 11 Fill at 6,914' ■ ■ _126, .g7 6, Perforation Data Tag 11/14101 _ r:r - 714 Zone Top Btm Amt spf Comments ~ ftif 58 -4 6,431' 6,440' 9' 12,12 4 -1/2" TCP (9/4/01), (3/7/93) E 13 59 -6 6,557' 6,568' 11' 12,12 4 -1/2" TCP (9/4/01), (3/7/93) :PS 71 -3 6,836' 6,852' 16' 12.12 4 -1/2" TCP (9/4/01), (3/7/93) f1f ~:Y4' ftif 74 -8 7,117' 7,150' 33' 12 Meshrite Screen, TCP Perf (9 /4/01) I 14 - r 1( 1 75 -3 7,163' 7,184' 21' 12 Meshrite Screen, TCP Perf (9/4/01) I { ' I •:::::::. ff+ 82 -7 7,760' 7,772' 12' 12 Isolated below tubing plug, TCP Perf (9/4/01) ftif ▪ {r ' f.. ..:: r }.,: - 8 ti •1.1:, � 74•s 15 I'::::::. - ; ftif {r4> = 75-3 f {f {f. r•ftif• :f 16 = ••••s• i { f.r• ▪ 17 18 Tagged fill/guns 82-7 @ 7,815' (917101) 19 O 0 7" @ 8,308' / Directional Data: TD = 8,308' PBTD = 8,272' max hole angle = 48.8° at 4,225' MD IRU 44 -36 Actual Well Schematic 4- 14- 11.docx Updated by STP 5 -25 -11 hevro 1 Ivan River Unit IRU 44-36 Well IRU 44 -36 �- PROPOSED SCHEMATIC Proposed 5131111 RKB: 51' KB I GL: 26.5' AMSL KB 24' KB Casing and Tubing Detail 1' Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 20„ @ 20" Conductor 94 #, - Surface 94' Driven 94' 13 -3/8" Surface 68 #, K -55 rfae Surface 9 518" Intermediate 47 #, N -80 SS urface c 3908,449' BTC / 12.415" 115 bbl / Cmt to Su BTC / 8.681" 270 bbl / Cmt to Surface 13 -3/8" 7" Production 29 #, N -80 Surface 7,789' BTC / 6.184" 115 bbl / Cmt to 4,420' @ 908' 29 #, P -110 7,789' 8,308' BTC / 6.184" 2 i, c Tubing 4 -1/2" I Production 1 12.6 #, L -80 I Surface 1 ( + / -) 6,800' 1 TC -II / 3.958" I Cplg OD = 4.932" ..G yi. Production String Jewelry Detail 9 -518" # Depth (RKB) Length ID OD Item @ 3,449' 1 24' 1.0' 3.958 4.500 Tubing Hanger, 4 -1/2" Vetco Gray 10" 5M 2 ( + / -) 2,000' 3.0' 3.813 5.000 Chemical Inj Sub 3.813" ID, 4 -1/2" TC -II CBL Top: 4.400 3 ( + / -) 6,400' 5.0' 4.525 5.910 Packer, Baker Premier 4 ( + / -) 6,430' 1.0' 3.813 4.932 X Profile, 3.813" ID 5 ( +/ -) 6,694' 15.0' 3.875 4.750 15' Seal Assembly (Bury 8' of seals) ' a : . 6 ( + / -) 6,709' 15.0' 4.750 6.000 15' PBR 3 fir r 7 ( + / -) 6,724' 2.0' 3.875 4.750 K- Anchor 8 ( + / -) 6,725' 5.0' 4.750 5.9xx Packer, Baker Model FAB -1 _ 9 ( + / -) 6,770' 1.0' 3.813 4.932 X Profile, 3.813" ID 4 ` = 584 10 ( + / -) 6,800' 1.0' 3.950 4.932 Wireline Entry Guide 11 ( + / -) 6,965' 50.0' - 4.625 4 -5/8" TCP Gun, 12 spf (Leave in hole) 59 12 ( +/ -) 7,090' 2.0' - - Bridge Plug, capped w/ 75' cement 13 7,107' 4.7' 2.347 5.810 Packer, Baker SC -1 Ret. (Min ID thru S -22 latch) 5 14 7,122' 76.0' 4.480 5.500 Meshrite sand screen, 2 jts (Possible holes) 6 ` 15 7,242' 3.91' 2.347 5.673 Packer, Baker Model D Perm. • 1 16 7,701' 1.06' 2.313 3.500 X Nipple, 2.313" ID, (PX Plug set 10/23/01) 7 17 7,735' 0.75' 2.441 3.250 Wireline Entry Guide ij�1 18 7,815' 438' - 4.500 4 -1/2" TCP Gun, 12 spf (Left in hole 3/7/93) 8 . Perforation Data 9 Zone Top Btm Amt spf Comments 58 -4 6,431' 6,440' 9' 12,12 To be squeezed, TCP Perf (9/4/01), (3/7/93) 10 59 -6 6,557' 6,568' 1 1' 12,12 To be squeezed, TCP Perf (9/4/01), (3/7/93) 71 -3 6,836' 6,852' 16' 12,12 Re- perf TCP Perf (9 /4/01), (3/7/93) V 71-3 74 -8 7,117' 7,150' 33' 12 To be isolated, TCP Perf (3/7/93) p 75 -3 7,163' 7,184' 21' 12 To be isolated, TCP Perf (3/7/93) h 11 82 -7 7,760' 7,772' 12' 12 Isolated below tubing plug, TCP Perf (3/7/93) � 12 13 J%11J •rr lf:l f 1f1f �_ ti•ti•, 74-8 14 yfyf _ 75 .}: }1}: 1 ti 15 1 ::r: L " r:r f In 16 17 Tagged fill /guns - 82-7 @ 7,815' (9/7/01) 18 O O 7" @ 8,308' L - \ Directional Data: TD = 8,308' PBTD = 8,272' max hole angle = 48.8° at 4,225' MD IRU 44 -36 Proposed Well Schematic 5- 31- 1 1.docx Updated by STP 5 -31 -11 Chevron • 1 %0 Summary of Key Energy Riq #3 Specifics IRU 44 -36 Convert to Gas Storage The IRU 44 -36 workover will involve pulling the existing completion, abandoning the lower and upper zones and running a completion to the 71 -3 zone to be used for Gas Storage. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration Rig Model The rig model is a Hopper Hydra- hoist, Back -model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft — 9/16" sand line. Derrick The derrick is a 102' tall telescoping double, with 260,000 lb capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a Pipe Wrangler, 45' long, 8.5' wide, 9' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2 -7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 13 -5/8" Hydril GK Single gate, 5M, 13 -5/8" Shaffer SL w/ blind ram Mud Cross, 5M, 13 -5/8" w/ 2 each 3 -1/8" 5M x 2- 1/16" 5M Double Studded Adapters Single gate, 5M, 13 -5/8" Shaffer SL w/ pipe ram (2 -7/8 ", 3 -1/2 ", 4 -1/2" or 2- 7/8 "x5" VBR rams) BOP Diagram See attached. Accumulator 240 gallon KOOMEY Accumulator System on an enclosed skid unit. Includes 7 functions with manual bypass and remote panel. Sixteen 15 gallon accumulator bottles. 462 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard - hydraulic driven. Pumps The primary pump is a National JWS -400 7 "x4.5" Triplex rated to 5,000 psi on an independent skid. A secondary pump is a Gardner Denver PAH 8 "x4.5" Triplex rated to 4,000 psi on an independent skid. The primary pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. The secondary pump will be used in conjunction with the primary pump as needed for increased flow rates and used for fluid disposal in well IRU 13 -31 (PTD 192 -088). Key Energy Rig #3 Specs (IRU 44-36) rev0.doc 6/16/11 Chevron • • %. , IWO Kill Line The Kill Line /Circulating Line consists of 2 ", 5,000 psi hose with Unibolt/Hub- flanged connectors. Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2- 1/16 ", 5M valves attached to the mud cross with co -flex hose with a Unibolt/Hub- flanged connectors. Choke Line The choke line consists of 2 ", 5,000 psi hose with Unibolt /Hub - flanged connectors. r — .. Choke Line Valves The choke ij valves consist of 1 ea. manually operated, 2- 1/16" 5M valve and 1 ea. automatically operated CI »calve that is attached to the mud cross with co -flex hose with a Unibolt/Hub- flanged connecto ,v - Choke Manifold See attached. Choke Return Line /Diffuser Line The diffuser line will consist of 2 ", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Trip Tank A trip tank will be placed adjacent to the rig with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. + wt1-0 Ic e 4.-e,- (Lc- .4 i's- WG 1 PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. ` Key Energy Rig #3 Specs (IRU 44-36) rev0.doc 6/16/11 • • Chin West Side �� Ivan River 44 -36 06/16/2011 Key Stripper head assy 1.17' Iil lit Ill lillii .38' 4.54' • Hydril • GK 13 5/8 -5000 lil 111 1111 111111 Shaffer SL 13 5/8 5M 14.00' o0 1.44' ca _ I!1 1!I 111 : ' 74 • l! Iii - - Eh - - -' 2 1/16 5M choke and kill lines unibolt ends V • • Shaffer SL 13 5 . 7 ® 1.44' 0 1 111 1!1 1 1 1! I Spool, 13,5/8 5M FE X 11 " M studded 1.00' CN •= Tubing head, Vetco Gray, CWCT, 11 5M FE X 115M , n 2.29' ° ° !I�i °.1° tt + i, FE, w/ 2- 2 1/16 5M SSO, 1 114 1 . 1 - 1I . I 6 3/8 min bore, dual - L alignment pins on head iii L Ground Level ' £ha11=Ofl • Ivan River 2011 ' 41100 Choke Manifold MONO 06/07/2011 Blooey Line To Gas Buster arms / am t.l A, - I., is ® I.I e a;' 00F % 0 i ; ; , 0 4'4 0 ., Cl 0 d 0 laNue sr / it ; .: ;1 N / ; 1. ; / _ i _ _ m_ _ ; Allt 0 ` 0 ` . , — , _ - 00 - ® p 4' 0 'irr ?l 0 04,.® d, 0 I 0 0 !!:115 V � ; 000 , L p • L 9,0 , ii IIIII 111 womill n) Super Choke "' All valves 2 1/16 5M on ,•, r ,•, manifold © �� Unibolt Connection pp , I • • pet FUl1 A FREE SUBStR 17 t2 S orne ,!.- f,crtithn subscriptions FFubticatfons Vol. 16, No. 24 Week of June 12, 2011 Providing coverage of Alaska and northern Canada's oil and gas industry Ivan River plan out for public comment Union Oil applies for new gas storage lease; would store gas in Beluga gas sand; storage would be for company use, not third party tgx)L\Ll JuN 4. 'La Kristen Nelson Petroleum News Up to 3 billion cubic feet of natural gas storage would be added to the 32.8 bcf of storage already in place in Alaska's Cook Inlet under a proposal by Union Oil Company of California, a Chevron subsidiary, for storage at the company's Ivan River unit northeast of Beluga on the west side of Cook Inlet. Union Oil told the state in March that it intends to use the lease storage space "exclusively for storage of Union Oil's gas" and said the company does not intend to apply to the Regulatory Commission of Alaska to become a utility, which would allow it to offer commercial storage to third parties. Union Oil already has Cook Inlet storage at Swanson River on the west side and Pretty Creek on the east side. Cook Inlet's largest gas storage facility, at the Kenai field on the east side, is owned by Marathon. All of these facilities are used for storage of company -owned gas. Cook Inlet Natural Gas Storage Alaska has a proposal under way for a storage facility in the Kenai area which would offer third -party storage. CINGSA is a joint venture of Semco Energy, the parent company of Southcentral Alaska gas distribution utility Enstar Natural Gas, and MidAmerican Energy Holdings Co. Initial customers for the • • CINGSA facility include Enstar, Chugach Electric Association, Municipal Light & Power and Alaska Electric and Energy Cooperative, the wholesale power supplier to Homer Electric Association. Comments due July 5 The Alaska Department of Natural Resources' Division of Oil and Gas said comments on Ivan River gas storage proposal are due July 5. Union Oil originally filed for gas storage at Ivan River in early 2010, but withdrew its application in March 2010. The company reinstated the application in March 2011. Union Oil told the state that it proposes to begin installation of a gas storage facility at the Ivan River pad this summer. Ivan River is some nine miles northeast of Beluga on the west side of Cook Inlet. "The purpose of this project is to facilitate delivery of sufficient quantities of gas at peak demand times (during winter months) to accommodate consumer needs," the company said. Union Oil said existing west side nonproducing gas wells were evaluated for gas storage potential and the Ivan River unit 44 -36 well was found to be the only available well with required reservoir properties — high permeability and porosity and manageable size. Up to 3 billion cubic feet of natural gas would be injected into storage in the well over a three -year period, 2011 through 2013, during summer months, filling the storage reservoir to capacity to aid in meeting peak demand during the winters of 2012 -14. Gas injection will continue in following summers to replace gas delivered the previous winter, the company said. Compression equipment The Ivan River unit 44 -36 well would be converted to gas storage, compression equipment would be installed and production facilities at the Ivan River pad would be upgraded to support gas storage. Compressor installation and facility upgrades involve installation of compression modules and associated piping; communication upgrades; reactivation of the A -train glycol dehydration system and upgrades to existing facilities at the pad to facilitate gas injection into and delivery from the IRU 44 -36 well. Compression equipment will consist of one large compressor or two smaller • • compressors. Union Oil said that because of the aggressive schedule for the project and the long lead time for permanent compression equipment, a smaller temporary compressor will be installed to support gas storage "until permanent compression equipment can be designed, procured, mobilized, installed, inspected and tested." Permanent compression equipment is expected to be delivered in late fall of 2012 or spring 2013 and would be operational by summer or fall 2013. Gas well conversion and well workover activities at a nonproducing gas well on the pad, IRU 41 -01, are planned for mid -June through mid - August 2011, according to Union Oil's plan, submitted in May. The company said some pad preparation and equipment mobilization may take place in early to mid -June. Equipment and supplies will be barged from Nikiski to Beluga. • Page 1 of 3 • • Maunder, Thomas E (DOA) From: PORHOLA, STAN T [stan.porhola @chevron.com] Sent: Tuesday, November 11, 2008 11:18 AM cC), To: Maunder, Thomas E (DOA) Cc: Sullivan, Sharon T Subject: RE: Ivan RU 13 -31 (192 -088) Attachments: Ivan River Well Depths Summary.xls Tom, See the attached spreadsheet for the depth and distance information for IRU 13 -31 and IRU 44 -36. Stan PorholaiUiU Drilling Engineer MidContinentlAlaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 5'P , 2.01'l sta n. porhola @chevron. com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: 11/11/2008 . • • Wellpath Data - Ivan River IRU 13 -31 and IRU 44 -36 Rectangular Coord Well Depths IRU 13 -31 FSL FEL TVDSS TVD MD Surface 682 699 -51 0 0 Top Injection 3572 1018 4221 4272 5544 Btm Injection 4060 1081 4630 4681 6183 Rectangular Coord Well Depths IRU 44-36 FSL FEL TVDSS TVD MD Surface 742 777 -51 0 0 Top Injection 3667 827 4243 4294 5427 Btm Injection 4070 823 4635 4686 5989 Distance Between 13 -31 and 44 -36 at depth Surface 98' to the Northwest Top Injection 213' to the Northeast Btm Injection 258' to the Northeast • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 11, 2008 10:04 AM To: 'PORHOLA, STAN T' Cc: Sullivan, Sharon T' Subject: RE: Ivan RU 13 -31 (192 -088) Stan, I am continuing to review the sundry application to convert IRU 13 -31 to disposal service. I have a couple of additional questions /requests ... 1. Do you have the "numbers" as to what the horizontal distance is from IRU 13 -31 to IRU 44 -36 at the top and bottom of the zones? 2. If! read the plot correctly, I get the following ... 1RU 13 -31 IRU 44-36 1RU 13 -31 IRU 44 -36 Top of zone (tvd) 4221 4243 Top of zone (md) 5'1)' -t IA Bottom of zone (tvd) 4630 4635 Bottom of zone (md) , Would you provide the measured depths? Thanks in advance. Torn Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, November 07, 2008 3:26 PM To: 'PORHOLA, STAN T' Cc: Sullivan, Sharon T Subject: RE: Ivan RU 13 -31 (192 -088) Thanks Stan. 1 thought of that later. Tom From: PORHOLA, STAN T [ mailto :stan.porhola ©chevron.com] Sent: Friday, November 07, 2008 11:16 AM To: Maunder, Thomas E (DOA) Cc: Sullivan, Sharon T Subject: RE: Ivan RU 13 -31 (192 -088) Tom, Per your review of the IRU 13 -31 workover sundry application: 1.) The area of review was discussed in the Disposal Injection Order application for IRU 13 -31. I am attaching a summary of the area of review that was discussed in the DIO application. 2.) We anticipate ConocoPhillips releasing the rig from Beluga River BRU 232 -26 to Ivan River about November 11, 2008. It will take 5 - 7 days to fully move and rig up for the workover. Stan Porholae Drilling Engineer 11/11/2008 - • rage a m • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 04, 2008 2:09 PM To: 'PORHOLA, STAN T' Subject: Ivan RU 13 -31 (192 -088) Stan, I am reviewing the sundry application to workover and convert this well to Class II disposal service. 1. I do not find any discussion regarding the "Area of Review" (AOR). The AOR is a 1 /4 mile radius of the well starting at the top of the injection zone and continuing to the bottom. The existence of any welibores or wellbore sections in that radius needs to be determined and then the integrity of any wellbore or wellbore section needs to be assessed. 2. What does it look like the spud date might be? Call or message with any questions. Tom Maunder, PE AOGCC 11/4/2008 • Page 2 of 2 • be assessed. 2. What does it look like the spud date might be? Call or message with any questions. Tom Maunder, PE AOGCC c — C_CD 456-SC\ L( \ t'kS j (.( 11/7/2008 0 • 1 _ — LI T! T13N R9W T14N R9i/V r" I I F Section 36a sroxt 31 I I 'T ' "hh UMi S "s -:'f I 1/4 mile radius around top of proposed injection zone in IRU 13 -31 *rte R11 .R UN IT 14 -51 e fbiil R3s1tR UNIT 48- T - ' mow i IL', tr cR UNIT 4 , t t I i i . 1 1 .4 ,24 I ) .8$ y. Sedittr. t ip SUCtart i? I 1112WICSIdel t -4,.337 I Wells within the 1/4 mile radius of the injection r` zone in IRU 13-31 1y' I NA.14 itF1'E UYT' Ut 1 - i T14N -R . T 13 N R9W I I ' Chevron I Ivan River Unit Unit Area I Se,r 12 Section 7 and Well Paths I Revised July 2, 2008 N RIVER or 23-12 e� " p ii 1 873 / �Ufllt tfOUlldfj/ FEET Exhibit 2 - Unit Boundaries and Well Locations and Paths 3 • • Wells Within the Area of Review 20 AAC 25.252 (c) 12 The 1 /4 mile area of review around the top of the proposed injection zone in IRU 13 -31 is shown on Exhibit 2. This perimeter encompasses two wells: IRU 14 -31 and IRU 44 -36. Both wells are cased and cemented so as to not provide a conduit for injected wastes to escape the injection Zone. No correction action plans are required. Detailed information on these wells has been provided to the State. Additional copies can be provided if requested. Well IRU 14 -31: Exhibit 18 includes the well schematic. The 10 % inch surface casing is set at 2,037 feet MD (1,960 feet TVD). Cement was recorded to the surface and bond logging shows good bonding. The 7 -inch casing was set at 7,018 feet MD (5,829 feet TVD) and cemented to 4,197 feet TVD, which is above the top of the proposed injection zone. Second stage cement was placed from 3,646 feet TVD to 625 feet TVD, thus cement is across the injection zone and both ends of the upper confining zone. This well is an active Class II disposal well that has injected 46,500 barrels to date. Well IRU 44 -36: Exhibit 19 includes the well schematic. The 9 % inch surface casing is set at 3,449 feet MD (2,941 feet TVD). Cement was recorded at the surface; logging shows good bonding from 3,449 to 2,400 feet, with fair bond up to 1,600 feet. The 7 -inch casing logging shows good bond up to 4,400 feet with some cement to 4,250 feet MD, the top of the logged interval. Calculations place the top of cement at 3,591 feet TVD, which is across the injection zone and very near the top of the upper confining zone. c�O� \Jo�c. �0 ■c) (0 0 0 I � This well is an active gas producer. 38 ■ 1 0 0 , '1 ............m.eare.........7 Ivan 1 Field i Well 1441 i 1 .w.............., ... . _____________ SPtia56517St , .1USP4/1017$'. 20'; 0 , 1 ; I . , 7 :I . I 2v. • 94# @ 421' 1 ■ :4 / 17 C V 1230 For 7" ,CSG. ; . is N o, 2;7/8" S.4# 11480 Butt Tubing i ) 10414" 43.5# Pc ; PO - J., ,13 Padker3t2903' A 2asr 0 q '' P P real] a of2948' 23t2 - ID) 'ITC A $T ''iensed on Baker ;WL - Reentry G bide-at 2982' FicikeSizo -.. ISIS' ris Based on :Equalization - CernertV Retainerat S225' Thou fkeettSboe , Cernerit:P1.41380'-;05a8' ' A - Stage it 4234' • . '-6119SXS Annotus ITC aetween , 4845'ond4056 aft „(CK Not,ConOtuaive) ; &:1 : -, fiaea - 5812 Sot !d 200 .SX ' ) 1 ' r 2Z,26-& 29# I440 : 'Fish Si BHA Total 'Length:228 ' Probably on ; Bettom i at 110,064 tir7018'10SSXS - A fish -422206 :tif27/8” . 7.0P. Top A 7495' A -9701' 1 ;Fish4.31W.D..;AssylA'aC."1 Length=380' 1 ilk ' • 7.9p V 734.5' 'Bottom 407725' . 1 ; : - ; Fish #4 . 2876'24 TG . & ; 3 112' D. ,1 - 'I • - "Top A 2510 Warm ; @ 0588' -I 1 Cement . Plug WOO-- -9927 S lir - Liner* 11:4000 ' 0 1 pt. :Cement Plug 10,i4,00' - 10;350' ':/,:i.0; Cermet Plug 10850' - 10,900. TD — 10 S58' — ;,05;61401 Exhibit 18: IRU 14 Well Schematic 38 . • 44,00 Ivan River Chevron Well 44 -36 Actual Completion 9/12/01 CASING A.•D TUBING DETAIL SIZE 11T GRADE CORN ID TOP BTU. 1 20" - 94' 1 .3 :8 518 11 -55 Buttress Surface 968' -, , J 9 -.5'8" 47 8 -80 Buttress Surface 3,449' ' h�� \ v C6 7 ` 29 N-80 Bu rresz 6 184 Surface 7,789' (� � , 'T" 29 P4 10 Enures, 6. 164 7,769" 8,30H' Les L' l _ 5 A v ( 3 { Tubing 2 -7,1" 6:4 L -81) Btm SC 2:441 23.05' 1724' 2-3 /8' 1 6 L -Sr' Batt SC 1.995 23.0 2,980' .-] A JEUI DETAIL NO. Death ID OD 1rem Dual Tubing Banger. 2 -7 8" x 2-18 Vetco Gray 10" 5M 2 tl•'1' _ Jsia�' 2.313 3.500 Sliding Sleeve, Baker, MID. ' -7.8 Buh . 3 3,108' 2.441 5.980 Packer. Baker FH Retrievable 3 a 1�� i 4 6. 374' 3.313 3.500 Sliding Sleeve Baker, CMD, 2-7.4' Bart L 5 6,.514 2.347 5.970 Parker. Baker SC-2 Rel. Chin ID through 5 -22 Snap Latch Seal Assy. 6 6,591 2.313 3.750 Sliding Sleeve, Baker, CMD. 2 -71V Butt "7 6,,77'3 2.147 5 470 Parker, Baker SC -2 Bet. (Min ID through S -22 Snap Latch) S 5 2.313 3.750 Sliding Sleeve, Bak CMD, 2 -78 Butt a 7057' 2.313 3 500 Nipple, X, 2.313 "ID. 2 -7'8" Butt 10 7.094' 2.347 5 810 Packer. Baker SC-1 Bet. (Min ID through 5-22 Snop Latch) it '7,111' 4 -480 5 .504) Meshrite sand Screen asst 2 i8' at 38` each 12 7,222' 2.347 5 67'3 Packet, Baker Mod. D. (Min ID through S - Snap Latch) I3 7,690' 2.313 3.500 Nipple, X, 2313 W. 2 -78" Butt 14 7;724 2.441 3.250 Wirelitte Ezm;' Guide 4 I 1 Heater String A 898')' 2-3."8" =. N_80 Butt Tubing With Mule Slur 5 0:411 6 n.t ..i PERFORATION HISTORY 7 ►1 (iMli interval - .+,Cann. 8 ■ Date Zone 'Top Bun Aunt spt Comments �' 1 ,.63 50-4 6,431' 6,440' 9' 13 Reperted9'4.0! 9 11 1;7 53 -6 6,557' 6,563' 11' 1S Repezf8d940i © 3 = 7,93 71 -3 6,836' 6,852' 16' 16 Repetfed9:4.'Oi 10 'ogrem. 9 4.91 74-8 7,.117' 7,153' 33' 12 Mesht'it• Screen 11 == 9401 75 -3 7.163' 7. 21' 12 blechrite5cn,en :+.:4.01 _ 82 -7 '7 -760' 7.77< 12' 6 12 ►�1 �� 13 El 1.4 F; i r.ICtimS vat to wpm' Gar %,,2l ?,113 0915 ETD = 8,272'. ID = 8,308' Max Hole angle = 48 deg @ 4,225' IRU 44 -3 WB:D 9-t2-fit cvx.doe, DRAWN BY tcb REVISED: 9/25/03 Exhibit 19: IRU 44 - 36 Well Schematic 38 f~, STATE OF ALASKA -' · ALASKA OiL AND GAS CONSERVATION C~J~vlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: Sand Control 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: × 24.5' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Ivan River 4. Location of well at surface 8. Well number 742' FSL, 777' FEL, Sec. 1, T13N, R9W, SM 44-36 At top of productive interval 9. Permit number/approval number 4,382' FSL, 817' FEL, Sec. 1, T13N, R9W, SM 93-22 At effective depth 10. APl number 50-283-20089 At total depth 11. Field/Pool 298' FSL, 932' FEL, Sec. 36, T14N, R9W, SM Ivan River/Unnamed 12. Present well condition summary Total depth: measured 8,308' feet Plugs (measured) true vertical 6,438' feet Effective depth: measured 8,272' feet Junk (measured) true vertical 6,408' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 88' 20" Driven 88' 88' Surface 908' 13-3/8" 115 bbls 908' 905' Intermediate 3,449' 9-5/8" 270 bbls 3,449' 2,941' Production 8,308' 7" 129 bbls 8,308' 6,438' Liner ~EcEivED Perforation depth: measured ' See Attached true vertical 'J~ ~'~' ~:! ~'? L IJ 0;? See Attached - Tubing (size, grade, and measured depth) Alaska 0il & Gas Cons. Commission Long String: 2-7/8", 6.4#, L-80 Imp Butt @ 7,724'; Heater String: 2-3/8", 4.6#, L-80, Imp Butt @ 0'-2,980' Anchorage Packers and SSSV (type and measured depth) ~ Baker Mod. "D" @ 7,232'; Baker Mod. SC-1 @ 7,096'; Baker Mod SC-2 @ 6,773'; Baker SC-2 @ 6,514'; Baker Mod. FH @ 3,106' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8/23/01 0 0 0 0 0 psi Subsequent to operation 1/8/02 0 5,060 1 0 1,225 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signe an Williamson Title: Drilling Manager Date: ~ Form 10-404 Rev 06/15~88 N'P I IXI"'A 1' SUBMIT IN DUPLICATE Ivan River 44-36 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt SPF Date Comments 58-4 6,431' 6,440' 4,997' 5,004' 9' 18 3/7/93 Re-perforated 59-6 6,557' 6,568' 5,536' 5,552' 11' 18 3/7/93 Re-perforated 71-3 6,836' 6,852' 5,294' 5,305' 16' 18 3/7/93 Re-perforated 74-8 7,117' 7,150' 5,502' 5,526' 33' 12 9/4/01 Added 75-3 7,163' 7,184' 5,536' 5,552' 21' 12 9/4/01 Added 82-7 7,760' 7,772' 5,994' 6,003' 12' 6 9/4/01 Added 102' UNOCAL Ivan River 44-36 Workover Summary 8/23/01- 11/15/01 Day 1 8/23/01 ACCEPT RIG FROM TURNKEY MOVE AT MIDNIGHT. CONT RIG MODIFICATIONS FOR IVAN RIVER PAD RU. DAY 2 8/24101 CONT RU OPEP, ATIONS. DAY 3 8/25/01 CONT. RU OPERATIONS. PLUMB IN NEW SUCTION LINES AND EQUALIZING LINES TO PITS. INSTALL CUTTINGS TANK DAY 4 8126/01 MIX 9%KCI FLUID. BULLHEAD 55 BBL DOWN TUBING. WELL DEAD. INSTALL BPVS. NIPPLE DOWN TREE. NU BOPE. DAY 5 8/27/01 CONT NU BOPE. TEST BOPE 250LOW/3000PSI HIGH. INSTALL TWC AND TEST BLINDS TO 250 PSI LOW/3000PSI HIGH. PULL TWC. INSTALL BPV IN LS. ENGAGE 2-3/8" SHORT STRING WITH LANDING JOINT. PULL MANDREL HANGER TO FLOOR. POOH LD SS = 2959'. ENGAGE LS HANGER WIH LANDING JT. PULL NO. 1 PACKER FREE AT 115K. PULL NO 2 PACKER FREE W/ 112K. SHUT IN AND CIRCULATE OUT GAS. OPEN WELL UP STATIC LOSSES AT 10 BPH. SPOT 23 BBBLLCM PILL. POOH LD 2-7/8' LONG STRING. DAY 6 5128/01 CONT LD TUBING (6399') AND JEWELRY. 100% RECOVERY. STATIC LOSSES 4BPH. INSTALL 3- 1/2" PIPE RAMS AND TEST 250/300PS1. PU 6" CLEANOUT MILL NAD BHA. RIH PU 3-1/2" DP. DAY 7 8129/01 CON RIH PU DP. TAG FILL AT 6820'.CLEAN OUT FROM 6820'TO 6920'. CIRC. OUT SOME GAS. CONT. CO TO 7046'.SUCTION LINE TO MUD PUMP LEAKING. CBU. CONT. CLEAN OT TO TOP OF TCP FISH AT 7815'. CBU. STATIC LOSSES AT % BPH. PUMP HIGH VIS SWEEP. DAY 8 8/30/01 POOH WORKING THROUGH CLEANOUT INTERVAL. RIH AND DRY TAG AT 7815'. CLEAN 20 BBLS OF FIN SILT/SAND OUT OF PITS. STATIC LOSSES AT .8 BPH. MIX AND FILTER 9%KCL TO 20 NTU'S. DISPLACE WELL WITH FILTERED FLUID. PUMP DRY JOB. POOH. DAY 9 8/31101 CONT. POOH. LAY DOWN BHA. MU HALLIBURTON TCP ASSEMBLY. RIH AND SECURE WELL. IR 44-36 WO Summary. DOC Page 1 Of 5 1/15/02/6:29 AM UNOCAL Ivan River 44-36 Workover Summary 8/23/01- 11/15/01 DAY 10 911101 SUSPENED RIG OPERATIONS FOR LABOR DAY WEEKEND AS REQUIRED BY FISH AND GAME FOR DUCK HUNTING OPENER. DAY 11 9/2/01 OPERATIONS SUSPENDED. DAY 12 9/3/01 OPERATIONS SUSPENDED. DAY 13 9/4/01 COMMENCE RIG WORK AT MID-NIGHT. RU E-LINE. RIH AND TIE IN TCP GUNS. POOH WITH E- LINE. PLACE GUNS ON DEPTH. RU HOWCO SURFACE EQUIPMENT. DROP BAR AND PERFORATE 7760-7772' 6SPF; 7163'-7184' 12 SPF; 7117'-7150' 12 SPF; 6836'-6852' 6SPF; 6557'- 6568' 6SPF; 6431'-6440' 6SPF. RU SLICKLINE AND RIH TO RECOVER BAR. UNABLE TO RECOVER. OPEN BY PASS ON PACKER AND REVERSE OUT GAS. PU AND UNSEAT THE PACKER AN ATTEMPT TO CIRC. THE LONG WAY. NO-GO. RESET PACKER AND OPEN OMNI- VALVE. CBU. LOSSES AT 6 BPH DIMINISHING TO 4 BPH. DAY 13 9/5/01 POOH TO 3204'. HOLE NOT TAKING PROPER FILL. PRESSURE ON CASING TO 775 PSI. CIRCULATE OUT GAS. WELL DEAD. RIH TO BOTTOM. TAG AT 7706'. CIRCULATE WELL. SLIGHT AMOUNT OF GAS ON BU. WELL TAKING 6 BPH. CIRC ADDITIONAL BU. DAY 14 9/610'1 CONT. CBU. NO GAS AT BU. MONITOR WELL, LOSSES AT 6BPH. PUMP 30 BBL SIEZED SALT PILL. POOH. SLIGHT AMOUNT OF GAS BREAKING OUT OF GUNS AT SURFACE. LD TCP BHA. MU 6" BLADED JUNK MILL AND RIH TO 6800'. DAY 15 9/7/01 CONT. RIH. ATG AT 7675'. CLEAN OUT TO 7815'. CBU. ClRC AND FILTER KCl. POOH. LD BHA. NOTED SLIGHT FLOW. SHUT WELL IN ON ONE STAND OF DRILL PIPE NAD BHA. NO PRESSURE. RIH RO 7815' AND CBU. SOME GAS IN RETURNS. WEIGHT UP FROM 8.8 PPG TO 9.PPG. WITH KCI. LOSSES AT 9.5 BPH. CBU. NO GAS. SPOT 25 BBL CALCIUM CARBONATE PILL FROM 7008'- 6100'. STATIC LOSSES TO % BPH. POOH. DAY 16 9/8/01 CONT. POOH. LD BHA. TEST BOPE 25/300 PSI. MU SUMP PACKER ASSY. RIH ON DRILL PIPE. RU E-LINE. RIH AND CORRELATE PACKER ON DEPTH. POOH AND RD E-LINE. SET BAKER MOD. D PACKER WITH TAIL PIPE AT 7,232'. RELEASE FROM PACKER. CBU. NO GAS. DAY 17 919/01 CONT. CBU. NO GAS. POOH. IR 44-36 WO Summary. DOC Page 2 of 5 1/15/02/6:29 AM UNOCAL Ivan River 44-36 Workover Summary 8/23/01 - 11/15/01 MU MESHRITE SAND CONTROL SCREEN AND RUN ON BAKER SC-1 PACKER. RIH. SNAP INTO MOD. D PACKER AT 7232' SET SC-1 PACKER AT 7096'. RELEASE FROM PACKER. CBU. POOH. MAKE UP ISOLATION PACKER NO. 1 - BAKER SC-1 PACKER WITH 2-7/8" ISOLATION TAIL PIPE, SLIDING SLEEVE AND SEALS. RIH. DAY 18 9/10/01 CONT. RIH. SNAP INTO PACKER AT 7096'. SET NO. 1 ISOLATION PACKER AT 6773'. RELEASE FROM PACKER. WELL STATIC. POOH. MU ISOLATION PACKER NO. 2 - BAKER SC-1 WITH 2-7/8" ISOLATION TAIL PIPE, SLIDING SLEEVE AND SEALS. RIH AND LATCH INTO PACKER AT 6773'. SET PACKER AT 6514'. RELEASE FROM PACKER AND CBU. NO GAS. POOH LAYING DOWN 3-1/2" DP. DAY 19 9/11/01 CONT. LD DRILL PIPE. INSTALL 2-7/8" X 2-3/8" DUAL RAMS AND TEST 250/3000 PSI. PREP TO RUN TUBING. RIH WITH 2-7/8' TUBING AND BAKER FH PACKER SPACED OUT AT 3106'. SNAP INTO PACKER AT 6514'. SNAP OUT AND SPACE OUT TUBING. DAY 20 9/12/01 LAND 2-7/8" LONG STRING. PU 2-3/8" HEATER STRING. RIH WITH SAME TO 2980'. LAND SAME. RU SLICKLINE. RIH AND SET PRONG AT 6374'. PRESSURE UP AND SET FH PACKER AT 3106'. RETRIEVE PRONG. RD SLICKLINE. INSTALL BPV IN LONG STRING. (SHORT STRING LANDED WITH TWC). ND BOPE. NU TREE AND TEST 250/5000 PSI. GOOD TEST. DAY 21 9/13/01 RELEASE RIG. DAY 22 9/14/01 PULL TWC'S. DISPLACE HEATER STRING AND ANNULUS TO 84.5 BBLS OF GLYCOL. ATTEMPT TO KICK OFF WELL. SWAB 24 BBLS OF WATER. UNLOAD 120 BBLS OF WATER. WELL MAKING SAND. SI WELL. DAY 23-32 9/15/01-9124101 ATTEMPT TO UNLOAD WELL. MAKING SAND AND WATER TO SURFACE TANK. DAY 33 9/25/01 RU SLICKLINE. MU 1.85' GR. UNABLE TO GET BELOW 320'. MU 1.75" DD BAILER. GET BELOW 344'. RECOVERING FINE SAND. UNABLE TO DAY 34 9/26/01 CONT BAILING DOWN TO 1020'. RECOVERING FINE SAND. SHUTD DOWN. WAIT FOR COILED TUBING. IR 44-36 WO Summary. DOC Page 3 of 5 1/15/02/6:29 AM UNOCAL Ivan River 44-36 Workover Summary 8/23/01- 11/15/01 DAY 35 10/22/01 MIRU CT. DAY 36 10/23/01 RIH AND CLEAN OUT 2-7/8" TUBING FROM SURFACE TO 7354'. ClRCULTE OUT FINE SAND. CIRCULATION LOST TEMPORARILY WHILE CLEANING OUT MESHRITE SAND CONTROL SCREENS. RETURNS CLEAN. PUMP HIGH VIS SWEEP WITH NO ADDITIONAL RECOVERY POOH. SET BACK INJECTOR HEAD. RU POLLARD SLICKLINE. ATTEMPT TO RUN PX PLUG. DAY 37 10/24/01 SET PX PLUX IN X NIPPLE AT 7691'. POOH. RUN AND SET PRONG. POOH. RE STAB INJECTOR HEAD AND ATTEMPT TO JET WELL ON. JET AT 2,00' AND RECOVER 96 BBLS OF WATER. POOH. SET BACK INJECTOR HEAD. CONT. TO LET WELL UNLOAD. DAY 38 10/25/01 RIG DOWN COILED TUBING. DAY 39 10/26/01 CONTINUE TO ATTEMPT TO UNLOAD WELL. MAKING WATER SAND AND SOME COAL. DAY 40 1 O~3O~O 1 RU SLICKLINE. RUN BAILER TO 3'. SECURE WELL FOR NIGHT. DAY 41 10131/01 RUN 1.75 DD BAILER. BAIL FROM 6902'-6915'. RECOVER FINE SAND. DAY 42 11/01/01 CONTINUE BAILING TO 6917'. RIG DOWN. Day 43 1113101 RU SLICKLINE. BAIL FROM 6907'-6912'. DAY 44 1115101 BAIL AT 6914'. RD SLICKLINE. DAY 45 11/14/01 RU SLICKLINE. BRUSH FROM 6776'-6830'. RIH W/BO SHIFTING TOOL AND VERIFY ALL SLEEVES CLOSED. RIH AND SHIFT SLEEVE AT 6786' SLM. RIH AND SET PLUG IN PROFILE AT 6786' SLM. DAY 46 11/15/01 IR 44-36 WO Summary. DOC Page 4 of 5 1/15/02/6:29 AM UNOCAL BRING WELL ON. Ivan River 44-36 Workover Summary 8/23/01 - 11/15/01 DAY 46 BAIL SAND FROM 6914'-6914'. Rig down. IR 44-36 WO Summary. DOC Page 5 Of 5 1/15/02/6:29 AM UNOCAL Fill cleaned out to top of Guns ~ 7,815 DPM 4 5 6 7 8 9 10 11 12 13 14 SIZE WT ~-'~,van River Nell 44-36 Actual Completion 9/12/01 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 68 K-55 Buttress 9-5/8" 47 N-80 Buttress 7" 29 N-80 Buttress 7" 29 P-110 Buttress Tubing 2-7/8" 6.4 L-80 Butt SC 2-3/8" 4.6 L-80 Butt SC Surface Surface 6.184 Surface 6.184 7,789' 2.441 1.995 23.05' 23.05' 94' 908' 3,449' 7,789' 8,308' 7,724' 2,980' JEWELRY DETAIL NO. Depth ID OD Item 1 2 3,060' 3 3,106' 4 6,374' 5 6,514' 2.313 3.500 2.441 5.980 2.313 3.500 2.347 5.970 6 6,537' 2.313 3.750 7 6,773' 2.347 5.970 8 6,796' 2.313 3.750 9 7,057' 2.313 3.500 10 7,096' 2.347 5.810 11 7,111' 4.480 5.500 12 7,232' 2.347 5.673 13 7,690' 2.313 3.500 14 7,724' 2.441 3.250 2,980' Dual Tubing Hanger, 2-7/8" x 2-3/8" Vetco Gray 10" 5M Sliding Sleeve, Baker, CMD, 2-7/8" Butt Packer, Baker FH Retrievable Sliding Sleeve, Baker, CMD, 2-7/8" Butt Packer, Baker SC-2 Ret. (Min ID through S-22 Snap Latch Seal Assy. Sliding Sleeve, Baker, CMD, 2-7/8" Butt Packer, Baker SC-2 Ret. (Min ID through S-22 Snap Latch) Sliding Sleeve, Baker, CMD, 2-7/8" Butt Nipple, X, 2.313" ID, 2-7/8" Butt Packer, Baker SC-1 Ret. (Min ID through S-22 Snap Latch) Meshrite sand screen assy. 2 jts at 38' each Packer, Baker Mod. D. (Min ID through S-22 Snap Latch) Nipple, X, 2.313" ID, 2-7/8" Butt Wireline Entry Guide Heater String 2-3/8", 4.6#, N-80 Butt Tubing with Mule Shoe PERFORATION HISTORY Imerval Accum. Date Zone Top Btm Ami spf Comments 3///'93 ~ 8-4 o,43 l' o,qou' ~' t 8 vteper~ea ~/'4/'u t 3/7/93 59-6 6,557' 6,568' 11' 18 ' Reperfed 9/4/01 3/7/93 71-3 6,836' 6,852' 16' 18 Reperfed 9/4/01 9/4/01 74-8 7,117' 7,150' 33' 12 Meshrite Screen 9/4/01 75-3 7,163' 7,184' 21' 12 Meshrite Screen 9/4/01 82-7 7,760' 7,772' 12' 6 ETD = 8,272', TD = 8,308' Max Hole Angle = 48 deg ~ 4,225' IR 44-36 9-12-01.doc DRAWN BY: tcb REVISED: 9/25/01 ,"-"" STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION CUMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 24.5' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 Anchorage, Alaska .99519 Service: Ivan River 4. Location of well at surface .v/' ~/' '-.-/ 8. Well number 742' FSL, 777' FEL, Sec. 1, T13N, R9W, SM 44-36 At top of productive interval 9. Permit num/ber 4,382' FSL, 817' FEL, Sec. 1, T13N, R9W, SM 93-22 At effective depth 10. APl number ./,~ 50-283-20089 V At total depth 11. Field/Pool 298' FSL, 932' FEL, Sec. 36, T14N, R9W, SM Ivan River/Unnamed 12. Present well condition summary Total depth: measured 8 308' / true vertical 6'438' ~-~ feet Plugs (measured) , feet Effective depth: measured 8,272' feet Junk (measured) true vertical 6,408' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 88' 20" Driven 88' 88' Surface 908' 13-3/8" 115 bbls 908' 905' Intermediate 3,449' 9-5/8" 270 bbls 3,449' 2,941' Production 8,308' 7" 129 bbls 8,308' 6,438' Liner Perforation depth: measuredRECEIVED 6,431 '-6,440'; 6,557'-6,568'; 6,836'-6,852' true vertical 4,997'-5,004'; 5,089'-5,097'; 5,294'-5,305'J U L 0 6 ;~0 0 ] Tubing (size, grade, and measured depth) Long String: 2-7/8", 6.4#, N-80 Butt @ 6,425'; Heater String:2-3/8", 4.6#, N-80, Buttl @ 0'-2,987' Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. Commission Baker Mod. "FH" Retrievable @ 3,058' and 6,339' Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 7/22/2001 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I herebv,,c'~rv:~j~that the fore~al, ~~ ~is true .~nd correct to the best of my knowledge. ~ ""~,~--'"~"'~/ Signed Williamson Title: Drilling Manager Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness '~1;~(~(~ ~ ~,~x ~'~(~t~::~ ~%'~ IApproval No. Plug integrity BOP Test '~ Location clearance I ~'"~-.~ ["-I ~ Mechanical Integrity Test Subsequent form required 10- I~.~L~I~ ORIGINAL SIGNED BY /,~j/~j~~/ Approved by order of the Commissioner D Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN 'P/RIPLICATE Ivan River 44-36 Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments 58-4 6,431' 6,440' 4,997' 5,004' 9' Existing 59-6 6,557' 6,568' 5,536' 5,552' 11' Existing 71-3 6,836' 6,852' 5,294' 5,305' 16' Existing 74-8 7,117' 7,150' 5,502' 5,526' 33' Proposed 75-3 7,163' 7,184' 5,536' 5,552' 21' Proposed 82-7 7,760' 7,772' 5,994' 6,003' 12' Proposed 102' Unocal Alaska Business Unit Ivan River Well No. IR 44-36 UNO CAL No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Prep Well Remove well house. Punch Tubing below packer at 3,066'. Run GR. Circulate out/recover glycol. Pump out cellar. Remove production lines. Mix 9% KC1 Fluid and kill well. Pull Completion 1 Install BPV 1.0 1 0.0 2 ND Tree. (Corroded) 4.0 5 0.2 3 NU 11" Mud Cross, DBL Gate, Annular and valves. 15.0 20 0.8 4 Install Two Way Checks, Test Joint 1.0 21 0.9 5 Test BOPE to 3,000 psi 10.0 31 1.3 6 Pull Test Joint, Two Way Checks 1.0 32 1.3 7 RU to Pull Completion. 1.0 33 1.4 8 MU LD Joint., Back Out Lock Down Screws. 1.0 34 1.4 9 Work Short string free 2.0 36 1.5 10 POOH LD Short String 4.0 40 1.7 11 Attempt to unseat packers 2.0 42 1.8 12 Circulate well 4.0 46 1.9 13 POOH Laying down 2-7/8" Tubing. 10.0 56 2.3 14 Lay down completion. 2.0 58 2.4 15 PU Drill Pipe. 15.0 73 3.0 16 MU BHA RIH and Clean Out. 6.0 79 3.3 17 Cleanout fill to aproximately 7,823' 12.0 91 3.8 18 POOH. 3.0 94 3.9 19 MU Scraper Assy RIH. 6.0 100 4.2 20 Filter Brine. 15.0 115 4.8 21 POOH. 3.0 118 4.9 22 RU E-line. 2.0 120 5.0 23 RIH and set F-1 Packer at 7,194'. 4.0 124 5.2 24 POOH. 2.0 126 5.3 25 RIH perforate 7,117'-7,150' (74-8 Sand) and 7,163'-7,184' (75-3 Sand). 18.0 144 6.0 26 MU Meshrite Sand Control Screen Assembly and SC-1 Packer. 2.0 146 6.1 IRU 44-36 State Attach.xls Page 1 of 2 7/2/01 Unocal Alaska Business Unit Ivan River Well No. IR 44-36 UNOCAL No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 27 RIH. 6.0 152 6.3 28 Stab in to F-1 Packer, Set SC-1 Packer at approx 7,094'. 2.0 154 6.4 29 POOH LD Drill Pipe. 12.0 166 6.9 30 RU to run completion. 1.0 167 7.0 31 RIH with 2-7/8" Tubing with packers at 6,791', 6,515', 3,000'. 15.0 182 7.6 32 Prep to run heater string. 2.0 184 7.7 33 Run Heater string to 2,900'. 5.0 189 7.9 34 Land hanger, set long string packers. 2.0 191 8.0 35 ND BOPE. 12.0 203 8.5 36 Install Tree. 4.0 195 8.1 37 Perforate 7,760'-7,772' (12') after rig is moved off. 4.0 207 8.6 ISubtotal (Days) 8.631 IRU 44-36 State Attach.xls Page 2 of 2 7/2/01 T1 ,~N I I i I I I I I I I I ! I I I I I I I I I I I I I I I T14N ' R1 OW T14N TI,~N I B~,'tS''I I 'tt- I I I I t I I I I , I I I I I I I I I I I I I · I, L I I I I T13N 'R10W I I I I I I I I I 5~.'_ .... r I I I I I I 1 T14N ROW I I I I T I I I I I RNER UNIT I I PRET[Y CREEK UNIT ~ ! ! ! ! ! + 1 ! ! -I I ! I I I I I I NAN RIV[E UNIT i I I I I I I I I STUMP LAKE I NIT Ivan River Pad i i ! J I I I I I I* I I I I I I I I I I I I I I I I i I I ! I I I I ~,( I I T12N RIOW 'UNIT i ! , I ..... I ..I ENSTAR MI'TI:RING &: OEHYDI~ATIONI PHASE II EXPANSION I - - - J - °, ..... + ................. ~' - r - - + BRU211-3 )-' 224-341 r-'-'-i T12N Rgw ..... I I I Figure 1 I ~,L~ 1'..400~' ~IAWN ~ r TANN~'R E~TEI 11--dl--SB P. ~ Foot Print 670' Figure 2 VICINITY MAP 1" - 1 LEGEND I h~m~nid A.S.L.S. 75-70 Pi Monument · roe F'lpdlne p£ Q 0o.' Pipeline D#~lptot NOTES 1) 1ho azimuth was obtained fram ALA.qCA STATE 1.4NO SURV[~' N~ 75-70 by direct tiao to recovered 2) 11re 80~ Ih# 8hmm heruefl ture genoroted from dlmct to the recovered cadaMrd 8urvoy camera es deplGtad end from 3) 1he bomlng and dbtmeeo thomt hemofl em true meofl geodetJ~ ufll#8 noted othefldM. 4) Tho rdatlve positions shown hreo, are bated on dk'e=t tree to'Pt monumoflto recowrod from A.S.L.S. No. 75-70 as deplctod. 5) Bev~t~le: eho~m hereon ~ mpplJed by the olmer and are m M~a~ ~ea L~ d~ 6) Th~ ~ll~d I~tlm ~f 23-12 ~m~ ~upHled by mmv- md 1/17/00 IAddd ud~. rotabd & trmakflmf dug to A.q' D~to I ~ !By / UNOI::ALO IVAN PJ-v'~R UNIT AS-BUILT SURVEY 280--A P..c~kr Stroet ! Kraal. AK 99611 Dote Pre. Ired Aug 20,1000 Drown by d~ecked by mare Md. ANE CONSULTING GRCY, JP P.O. Box 468 So~dotna. AK No. 89-10 ProJ~t No. 003006 Sheet I of 1 Dwg. File 003006 W-C-0021 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL JUL 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Dan Williamson Drilling Manager Friday June 29, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval Ivan River Unit 44-36 Workover West Side, Cook Inlet Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to re-complete Well IRU 44-36 in the Ivan River Field on the West Side of Cook Inlet. IR 44-36 (a gas well) is currently shut in due to excessive water production. The propOsed workover will consist of pulling the old completion, cleaning out fill, adding additional Beluga perforations and installing a completion with sand control equipment across the newly opened interval. Isolation packers will be run to separate the existing perforations so that the wet interval can be determined and isolated via a sliding sleeve. Because the reservoir pressure in this well is 2,590 psi (5,994' TVD), Unocal requests approval to test BOPE to a maximum of 3,000 psi. The anticipated start date on this work is August 15, 2001. Please find enclosed an application for Sundry Approval (Form 403), a summary workover procedure and wellbore schematic. If you have any question please do not hesitate to call Tim Brandenburg at 263-7657. Drilling Manager ORIGINAl_ JUN-24-96 lION 04:03 Pli UNOO~NOHORflGF 7' CASING AT TD ^T 8,.'.'.'.'.'.'.'.'.~e' ., ' I.VAN'RIVIER FIELD ~ :.WELL 44-36 PRESENT _ .. .... jiLLI ........ · . . .. .. · · , · .i : : '. · · .. , .. · .. : · · ., : . · .. . · .. .. ,. . . · . · : . , .. · · . · .. ~. · . BAKER.Fi.t, PACKE,~'RA,T.3058. " ,' , ,. ., . .. , . ,. ,. 2-7/* ~4~, N-~ B~ CO~~N " ,, ... '. '. . ,,' . . ., ,' ~ , '. ,, ' . ,,. . .,, , ,. ., '.. . . .. ' , ,,, .. , .. ., . , , ,. ,. , ,. ,. .. .. .'. ,' ... ., , %' . . .', ,~ .." .; . , . '~'... ,. .. . ~R ~ PR~,,'(~ ~1.~!' " , , ,. 'i PERFO~NO 12~PF ' . .. '. , .. . : F,qX NO. 907 26~_.788.4 ., , ..' .. .. , ... . . . . : 2-3~,'. 4.~..'N-8o,,' 8~ to 2987" "' "" P, 05;/16 .'" "'JUN .2;5 1996' ' ; , . lla.ka 0tl 'l Oa~ Cons.'C(~mmiss~°~ ' " ' ~nehei'aoe oN OR BEFORE DECEMBER 01 2000 W C:LOP. lkl~ILMDOC JUN-24-g6 UON 04:01 PU UNOOflL flNOHORflGE l--fiX NO, SU! ~'U;~ {~4 · ' : ' ,".": STATE'. OF': :.' , , :~' 4~ ' I A'LAS~ OIL AND GAS CONSERVATION. COMMISSION ' i:' ... .':.APPL'ICATION FOR, SUNDRYAPPROVALS 1", UR/10 .. .; ,. 1. Type of Request:.'. :Abandon!'. ' ". Suspend: .. ; Alter caS!ng-~ ~' Chan~e.;'appr0v~d~r,,,rogram; Pull tub'----in.g; 2. Name of Operator .. " .... UNION OIL coMPANY: oF' CAUF. 0RNIA (UNOCAL) 3, Address .. .:. '. :'......... 742' FSL,.777' FE~ of Sec: 1~ T13N, '~W, SM At top of p~u~Ne inte~al . : .:... (~.431) 4~38~' FSL, 817' FEL.of S~; 1;. T13N, RgW, SM At t~l dept~ ':, : ' · . ' (.,;o.~ ags' FS~,93Z'.FE~' 0f SeC ~;,' T~4N, ~sw, SM ', . , , ,, t 2, Present ~1~ cond~ion'summa~" ',:. , Total dep!h: '. Effective ,depth: ; Casing Structural . Conductor ' Surface Intermediat~ i :· Productio~ ' measu~! true '.re'tic. al. : ., , , ,. true ~ical:'. ', 'Length ""' 25"-~8'" '. .:, 25'.: 908' : ,' 25' - 3499' '. '2r. 8i30s' 8,308' feet 6,438' feet $,272' feet $,408' Size 20% 13-3/8% 68ff K-SS 9-~Ir, 47F N-SO 7", ~9# N-~0 Operation shutdowh: Re-enter suspended well: ,, Plugging! ....... .' '-i--Time extension: ..... stimulate~.' _.... Variance: ' ..Perforate: Other;. NRWO 5. Type of.well;. . .... 6. Datum elevation (DF or KB) .'. Develqpment:. X'"' ' $1' ' .. Expt0ra~o. ry: ~' . 7, Unit or Property name 'Stratlgraphic: Set, ice; Ivan River .- "':.':"" .', : ~. Well44;36number . Permit number ". 93-22 : ' ' ~ .~. APl number ' {;0-283-20089 ,, .:1.1. Field/Pool Ivan River .. , Cement plug back 8,272' Plugsi(measured) Junk .(measured). Cemented Driven , t:16 BBL - sUR 270 BBL - SUR ' 3499' ' =,'..L. · . , Measuf.ecl depth .. Perforation'depth.: measul~d ..: , ,. ... .... true vertical., ,' , ., '. 6,431' - 6,440', 6,667' - 6,5~' & 6,836' - 6,862' ' I ' , 5,000' - 6,006' , 6,090' - $,09~.' & 5,295' -'$,306' ' '. . .' . . 4.6# N,ao to2,987' (Heater St~ng).. ' i. 6.6# N-aQ to.$,425"- Prc~luction'..String ': '. Packem.a~.d $S$V (.type and.measured depth) , .. '. T': Baker· FH p_.._a...(~_ .~ Set ~ 3,0GB' & 6,339' :, 13. A~taohem'~nts Description summary of proposal: X · .. ' i-, ,~ .......... 14. Estimated'date for =om'menDing ope~ti0n'. June 28th, 18e6. '" ~' " , 16. If propose! .well Verbally appJ:ovedi ',.... . . Name of a'pprQ~,r ' ' '. Date approved ' Service: 17. I hereby ~rtify that the.. foregoi .rig is ~'ue and correct to the best of my knowt, edge; ORIGINAL' · ,, True vertical depth ,. ;!.66' .. .: 2938' ': 7348' : 8,161' ' · RECEIVED . JUN 2 5 1996' ,', Alaska 011 & ~a~ons. ........ Commission.. , ' Detailed operations p.rogram:! X Susper~ded: 15, Status of well classification as: ,. , ':.Oil: ' .:, C_~S: X' .. · ..," ,. ... ., Date: 6/24/1~9e "j . Title; Regional Drilling Manager. ,. ' FOR COMMISSION USE ONLY,· Conditions of approval: N0fi~y COmmis~iori.'so representative may witness Plug integrity:::. :. Mecha .nical Inteo.r.;~ 'f'eSt BOP Test , Location c~earan~=e Subsequent form required 10-:.. A~.p._r.0ved by:order 0~ the, CommisSiOner ,, ' ' Form 10-403' Rev'06/15/88 ' ' ,, , : . Original Signed BY David W.'.' John® ':. Commissioner Approved Copy Returned . SUBMIT IN ~RIPLtC~TE'.' ': JUN-24-96 MON 04:02 PM UNOOIhL flNOHORRGE 1% Ud/lO ".' : . ,.' Ivan River Well # 44-36.. " Shut off existing Beluga sand with MaraSEAL Gel & complete Beluga .82-7.'. Sand :. :' !~Yi S.S. Lam~ ,, '" . 'Date: June 19, 1996 '. " '. , ". R~i~ion #: Draft · : , 1) call out :'Three Mile creek 'services with pole track. Detach and remove well. house.' ,, .' . , 2) Carl out/and.rig up/slickline, umt, lubricator and BOPs. Pressur,'.:test:to 25.00 psi against swab vabre, Bleed.prossure,:to Shut in tubing pressure, MU 2.25".gauge ring. RIH an,d tag fill, RD ancmmc. , .... : . ,.... ,. .. ',., 3) RU 1-1/2, coil tubing' unit..RU supply line to both the water track and 400 BBL .tank. RU return line from pump in:~b.i°DSR's 100 bbl shaket tank, with option ~ using PIo~I..'. uCtion facility bl~din§ .gas pressure.. RUinj~or, BOPs, and lubricator. Pressure test all surface lines to 4500 pt& Pressure test. coil and lubricator to 4500 psi. FunctiOn and p/~$ure te'~t. ,, .. .". .'. 4) EnSure batch .mixers are.clean. Fill up cleaned batch mixers with g0 bbls ~d 47'bb15 respectively for tl~ i00 bbl', and 75 bbl batch mixers with cold'freshiwatcr for.polymer. Load 50 bbls of2% KCL in' water'tmck. . ,- ;. . , , . . . , 5) Measure:up 2.0" cementing nozzle and coil connector. 'RIH.circulating Water from Vac truck at minimum rat~ tald'.ngremms'.to 400 bbl tank.' .. ,. ,." :. ',, ;. . :. NOTE: Bleed g~ presmr~.t0'pro~cfion md take liquid retnrm to: tank. via:cl~okemenifol& ... . . .. . . ' . 6) Shut down pureI~'a~d ;lightly: tag fill recorded with slicldine.. Correct COil m,'.bing depth r~ordcr. PU' COil fiozzl~ to.6,840' md. : · .. 7) Close in tubing by ..?coil.,' armUlus: Establish inj~t~ion, rates down c0il tubing, and into open perforations at 1/2:', 3/4; and 1" bpm~, l~__~x-~_rd pressure from rail"by 2.-7/8" robing annulus. : ..', . ., .. , .,. .' . ,. . . .. · , .. ,. .. i . formation is below I bpm.. 100 bbl batclt'mixer':: yield: · . , 75'bbl batch mixer:.' .',, · . ., , Yield: ., ,. ,. '. 80 'bbls fresh water IR~,en..lO~F' 60*F 1275 lbs J491, MaraSEAL gel (15 Ibs/bbl) · 16;.$ gallons J492 activator ~lutlon (4.6 gal!on~/: 1,000 .gallon~) 85. bbls I50/bbl Mara~EAL.Gd" .. : .47 bbl~ fresh water between.40*F". 60~F .750 Ib~ J49~, Mar~;EAL gel (lSIb~JbbO :' '. .10' gMIons J4~2 activator relation'(4..6 gMlonS/1,000 .gallom) :'.$0 I~bl~ l~Fnbl Mar~_~EAL C~''· .. . .. .. = :.. R'E,CEIVED JUN-24-g6 MON 04:02 ?M UNOCAL ANCHOEAOE ~A~ NV, ~Uf ZVd IVVq · . · '·i} ', , .. .It), / III) · . 'TemD 1:3'' 7 2 !14" 8 2 28 ' ·1.4 3 1", uq/ 10 , . . . ,, · , , . . . , '. . . . ,. .. , . ., . ., . . . . ':. , ., . . , . , , ., ,,, .... · . . ·, '. . . . . , ,,: · . ,, '... ',, '. .i' i. 'i: ~ " R:EC. EIVED: ' · . JUN .' ... . , . 9) .!, ;Position' the coil nozzle at 6,55Y. Circulate polYmer do.~ coil taking raurns from coil by. :. .!.tub!rig annulus. SI amaulus and start inj .ex:ting into fonnati0n:at maximum coil pros~u'o. Slowly . ( . r~i.'.p~o~,at, the coil across the Beluga interval fwm 6:$36~ tO 6,852'. .. 1'.0) 'SD' .P%~p$ with 100 % of g~l displa~,~l in~o formation. '.Pull coil out of hole pumping at a~ 1: I fill up r~tio,: .. ... H) Measu~ up 2" jetting nozzle. AllOw MaraSEAL gel':..to'set UP ( 3 hours at temperatu~), Monitor " '... ~ff, ace ,sample for gelling, Place filter ~ betwee~ pump suction and I00 bbl shaker tank. RIH. ',.' : "with jefliug uoz~l¢ r~ir~Jating fluids from 100 I~Is. sliakCr ~ through filter pod at miaimum ., ' ",late~ ' . . ~. ' .' ,..:. . . 1'~ .. ' SD'p .ump~ at 6,400'. RIH slowly and .Watch for.. weight change~ acw~ the l~fforat~ intcrva!., · f-mm .6,a~o' to 6,~oo'. let through p01ym~r a~ reqtfi/~ed taking retur~ a~ros~ shak~'.tank.' ,f ,, . , . .. .... ' .En~a~ iholo i~ cleaned of any obmstctio~_ '. .. . , . ·.,, · ,. 1'3) ' With'Coil po,ition~ at tab~g tail ¢irmlat, 13 bottom up. v01ame. Block in mil tnbing .at · " ~.' di~. H anowin~ w~n to ~b i~ r~ from Up~x~/ ., .' : /. .' : 14) <lliJ.coiland cie, an ap lomtion~ Filt~ all !lui~ l~ffore di~osing in inj~'tion w~ll, Plato ~olid~ in :' ~ 'lin~tmnd box~ for ~rt bar& ~o Kenai. :.Worn ¢a~ ~olid~ volnm¢ i~ 4 . : ,. : ,~·.. .., ,~.~ , . NOTE;'"" . Prior to arming'cxpl0sivcs and until e~plosives are $oo' h ' .. ' ' hole, eatablbh all ~tfe~ar.d~ for handling explogv~ Re- : '. ' ' e~tabllsh safeguards When'POOR feom ~00'. ., , , ,, . , ,. · .,( . ,. ,, , 1:'5) .' .'RuiE;Lin¢ unit, lubricator, and.BOPs:' Pr'~ test:to 250~ i~i. MU 1-11/16" eCL and' j. .... peffomt, ing ~ noted below. Shoot the following int~. · . .~ ' . . ' ., B~luga:'82,.7 7,760' - 7,770'. 10' 2.;1/8, .:NREI III, 6 ~pf, (+t*) 45° -pha~ .".. : J~ ,. , Cai1 :mit TI~ Mile Cr~ ~rvic~ with. poie track. Re'attach wdl hou,~. ,. " , .: ,16) ,, .':~,).."... 'P,e,;l.' ~.~ '~'~ll 1~ production §roup,. , 1, ., , ,, ., .. 4" 117 ~9 41 2'i 4~3 119 65 44 23 $'i 202 115 ~2 ' 44 Verify volumes on fresh water in batch mixei-s.' Start batch mixers at highest sPeed.'.. Add gel from sack at '50 #'s' per minute.' ML~ gel' additional I0 minutes after all gel:. has been added, . Take and record rheologies with..Fann 35 and Compare to thc table below: " . Add the crosslinker throughout .the gel', Circulate and paddle for 10-minutes, and' pump immediately. Repeat mixing for 50 bbl batch mixer. ' Farm 35 dial reading*w/R1BI bob, spring'factor I at rotor speed: ' ~_.~ ~ 2oo ' 'l.oo aox' ' JUN-24-96 NON 04:03 PM UNOCRL RNCHORRGE .. 7" CA$1N~ AT 8308' TD AT 830~' 'IVAN'RIVER FIELD ' :.WELL 44-36 , pRESENT ll~.l .l I1.1 I. IIL . ., .'~ · · · ., . ,1 ' Ill , · ,, . '.. ., , ., ,, · · · · : · · .. · · . ,, ., · . . '. . , ' Ill · ,. . . .. .. · , . ,,,'1 ~,'/~///?~.;.'/. .., :.' ',' ' ,:' "' JUN ,2:5.1996' . , . ., Y, Ub/! U , Al.~k,'Otl & G"~ Cons.'Cdu'miss'°p ,~n~hci'a,qe Completed:-3/8/9,5--_; .... "(-._' .. '..i i :'-'.: .ii; .;'('-.iv(in.-R,veill Fi'e"td'i.i'_...i .ii;.: .-.'s-'. i:...) Angle; @ PeriS: '-..-'Degs. :. :i' ';;i..i .i.-...i. i LoSt 'Work' O'V~r: 3/8/93: -'--- ....... '-'- "' ' APl-No::'50=283~:20089LO0'-- '.'----'-':' --'..=' .' '-':- .... iHong~;: - "- -- -'.-.-.'- .'. -:-'-- · 6:S56.0' ;:_ 63.63.10" P[RFS..57:6, ..Poi'entiol Stu!!n9 7' · . · 2-4.,t, - 6425:0' 2.875" 01) 6,40///[! N-80.TBC LONG STRING.· .... ~ 635J.1 -;6.~52.4' 2:257'" ID N_'.O':GO'.NIPPI~ Boi~e~;' R" 650.0 - 6§64.0' PERFS 60-6, PoLentiol Siedin9 698.0 - 6720.0' PERFS 60-8, PoLentiol S[erli~9 22' 6923.0 - 6929.0' PERFS 72-5, Potentiol ~lua, o 6' 71'~8.0- 7150.0' PERFS 74-§, Potentioi Beiu(ja ~2' 7~63.0 - 7184.0' PERFS 75-3, Po[enEol Belug~ 21' --'.'-7257.0 ~' 724ZO"PERFS'76:.], Potential Bdugo 5'- 7375.0 - 7396.0' PERFS 77-9, Potential Belu9o 21' 6425,1 - 6425:8~..CROSSO.VER 2 7/81'.:8utt'l:lox x. 2.7/.6" §r(t Pin 6353.0 - 6358.2' B~er [lostomer Shock Absorber " ~ . -.. 6339.4-~ 6346.7' R[TRV, PACKER Baker-FH.PIm-.- - 643lj0 - 6.440.0.'. pERFS'Ster]ini], 12HPF, '9S 3/1/93 ...... 6557.0 ~ 6568.0'-PERFS Sterling, !2H~F, 11S 5/t/95 - 6358.2 - 6~,59.2' B~ke~ RA Sub 6392.0 - 6392.9' PORTED NIPPL[ Baker Ported SW) W/Glass Disc 6836.0 - 6852.0' PERFS Beluga, 12HPF, 16', 3/t/93 ... .25.2 =.7789.4' 7" OD-29.0OJ/ft iN-80 PROD ""' "'"- . ._... CSt ?-760,0 - 777~,0'. PERFS-82-- 7, P0[enJi~! 8dUgoJ~_ '.o ,-i'826~'.O'iC~i.nSU ~,~'0'[ .¢.3/8'.'--TCP Peri Guns _...... .... .... 826l.¢.'. i_. 6262,5, FLCOLLARHgwCO. -. 89.4 - 8~8,0' 7" OD 29.00J~/lt P-110 PROD CS(; 8261.0 - 8,~08.0' CEMENT PLUG 8~§6.7 - 830&,0' FLOATSHOE H0wco 0 cD Z <:2> lhu Jun 1~ i4:22:50 1996 JUN-24-96 I"ION 04:03 PI"I · . UNOCRL RNCHORRGE / Rev. A March ~ 902" , FRX NO, 907 263 7884 · COILED TUBING OPERATORS MANUAL . , ,1i* 80.P commonly found on Dowell SchlUmbe' rge~ (DS.) coiled tubing units (CTUs) is manufactured by .'rexas:Qil ; '. ToOls (TOT). This is available in a range Of sizes (bom), .' pressure tatim:js and services (e,g,, H,S, Arctic 0rStandard ' ,.: ., . The,model most commonly used is the 3-'in,, lO,O00-Psi '" :,.. Working Pressure, ~S service Quad BOP..it is thi~ model : On'which the ~iagrams and mxl in this:$~ton are; based, . , . , ,. ' i S!de Port (Kill Port) , , , , . , . ,, . '.. . .. .. . , :~ · . .' . '.. ,. ,. '. . . .. ... ., Stud-Up Flange . . T.0p Connection%. Pipe,Ram.Equalizing, ,', Pin and Collar con.'nection · BOP Body · Blind Rams * Shear Rams o Slip Rams , Pipe Rams F, Uf/1U Figure,'1.. Tytgleal festtl~.'s of a quad BOP-.fror~t' vletV. ,. ',, . ,, .., The following components are identified' in·Figure 1 and 2. ,. ., .' R:ECE..I,VED · , . , , ,. . ,.' ,. Manual L°dk Handle Pressure Port" Blind-Ram ,,. Equalizing Vaive .... ' '. · . , . ,' --~ .... :'Blind'Rams ' .'(Ram No, 1) ,, ,.~.' sheai'. Rams ' '(Ram.'No, 2) .. .' '..,,~,..;~ SliP.Rams .' .(Ram.No, 3) . , , , "i '.Pipe Rams "(Ram No,4) . , . ,. ; ,.' ' HydraOlicActuator .· with' Ram Position'lndjoator ,. . Bottom Flange Conne 'cli0n. ,'," ,. , ,, . , , , , .,. . ,, ... , ·., · . : . ;.. , , · JUN-24-96 HON 04:03 PH UNOORL hNOHORRGE FhX NO, 907 263 7884 Y, UU/[U . ': ' cOILED TUBING ~ SectiOn 3!.0.:1;' Rev A . . '"'~. ';,. OPERATORS. MANUAL ' 1~ March 1992 '~ Page 3 of 38 .......................................... ~ ! m~m _..' '-'-' ........... · Ram Bonnet and Actuator '~ The hydraulic s~Jppl~f and contro~', systems for these . component~ will Vary:withthe.'manufacturer and model of · Equalizing Valve ,~ the CTU power packand controlcab. For the purpo$o of this manual section,' the,. hydraulic supply and control · Si~e Port . , systems described a~ply to the current generation Hydra- Rig CTU, While ·minor var. i~ati0ns, ma, y exist on units of a · Pressure Port different model'"or manufacturer., the facilities identified " below will apply.to most .CTU. S in use by DS, · · Top an~ 8ottom Connections - Dedicated BOP Hydraulic SupPly Pump · Hydraulic ConnectiOns · Hand- o~'iAir-oper~ted Emer§ency supply Pump " · Hydrauii 'Acc mu oi .' .'. , · BOP System Isota[ion ValVe. · POSitive Action Control' vatves. · .. · . : · Pressure1 ' port . . Blind-Ram'' ' Ii,,- ".. .* EqUalizing Valve .. '....'. .. . , ',. Hydraulic 'connectors Side 'Port " (Kill Port) "'- Bonnet Bolts.." . .. . . . ,. ., . , ,. , Pipe-Ram Equalizing Valve .. .; . .,.. ';' ..' . . RE.CHI. VIeD ,. J'UN,."~"'.5 199G . .. . : Anchmage :' .. ' .Figure · :. · :I)OWEI,L SCHLUMBERGERCONFIDENTIAL. ',. ' JUN-24-96 MON 04:04 PM UNOCAL aNCHORaGE . . ,.. ,. . FaX NO, 907 263 7884 U~ocal corP°ration P, O. Box 196247 Anchorage, Alaska 907.263-7676 . UNOCALe Dale Haines, Drilling lV~nag~r ,' ' Bear'.Mr', Wondzell: Eriday, J U'ne" 2,1,: 1996 Mr. Blair Won.dz~ll .. AOGCC: . . 3001.. Porcupine Drive Anchorage; AK 99501 .. ., Ivan River..Well:' 1'3-31 CTNRWO U'NOCAL'r:iS"preposing to abandon the watered out Tyonei<,gas sands in Ivan RiVer: Unit Well'13-31 with cement and complete 3 BelUga 'gas sands behind tuu~nu, , .,! , , .. Cement'.Wili'.bi~:..placed in the annulus'betWeen, the 7'". casing and the 2-7/8' tubing tO: pm¥ide'zone isolation in the' ovent remedial wor~' is roquired. The production Packer set at 3,082' will provide isolation 'from the heater string. The'.. maximum .ant!c[peted gas pressure of 2600 psi (2450.' psi surfac~) is well within ,, the operating .constraints of the existing co:mpletion~ .....' .: : ,, . T:hank YOU in ;advance for immediate review of the attaChe~ program, If you ... h'.ave::any questions, please contact the undersigned:at 26'3-7660 or Dan WilliamSon at 26'3-7677, " Sincerely,..'.. Dale 'Haines Drillihg :Manager :" RECEIVED..' .. , ,. '; .. JUN 2~ 5 1996" Alaska 011 & Gas Cons, C0mmis~ion Anchorage UNOOhL hNOHOR~GE NO, ', Dear Mr. WondZell: ' Unocal Corporation P, O. Box 196247 Anchorage, Alaska 99519 907.263-7676 · 'UNOiCAL Friday, June 21~ 1996 Mr. Blair Wondzell ,.. AOGCC " .. 3001 Porcupine Drive Anchorage, AK '99501 Ivan River Wei1'44-36 CTNRWO ' UNOCAL is pmposin.'g tO isolate the ;.watered out Beluga 71-3:.gaS sand i:n ilvan River Unit well 4'4-36. with MaraSEAL GEL and complete the Beluga 82-7 'gas sand, " " ' :' '"" '"' " ' ' 'i i ;' The mechanical:]ntegritY:.'of.the.well Will be unaffected, Other :take points are' available in the event the. treatment effects the open sterling::intervals",' ' .:.. Thank you in advance for. immediate review of the attached program., if you.. have any questions, please.contact the undersigned at 2.'63-7660' or'Dan ' .. Williamson at 263-7677L .'... .. GRS/leg . ~lncerew,_ .. ,, ,. .. .. . Dale Haines ...' . ; Drilling Manager. 'i ,, ., . . . . .L · , . ,, . .. · . : ... .i'....RECEIV:.ED :... ,,' 0u, ':.2 s V, UI/I~ ",, i" Alaska Oil & Gas C°n~. commission .' ..' .: ..: ...' Ancho~ag..e' . ' PERMIT 93-022 93-022 93-022 93-022 93-022 93-022 93-022 93-022 93-022 93-022 93-022 93-022 DATA 5608 DRY DITCH SURVEY CURVE Y DWOP ~' 407 ~- SBT/GR t AOGCC Individual Well GeOlogical Materials Inventory T DATA_PLUS T 3360-8132 DIFL/AC/CDL S 3450-8308 SS#877 R 0.00-8308 E TELECO R 0.00-8308 E TELECO R 02/10-03/08/93 R COMP DATE:03/07/93 L 3500-8246 MUD(FORMATION L~.~L 3453-8308 L 3400-8111 L 5920-8111 L 3420-8114 DIL/FL/GR z CDL/CNL/GRf~ CAL/GR / BHC/AC/GR/CALL ..... L 3400-8111 Page: Date: 01/09/95 RUN DATE_RECVD 1 04/20/93 04/28/93 04/20/93 04/20/93 04/20/93 04/20/93 1 04/20/93 1 04/20/93 1 04/20/93 1 04/20/93 1 04/20/93 1 04/20/93 Are dry ditch samples required? yes 'n~) And received? yes no · Was the well cored? yes /~o ~, Analysis & description received? Are well tests required? yes --~-~:--(n°'/)~ Received? y~'~'~ Well is in compliance Initial COMMENTS Unor.~l North Americaf Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL April 19, 1993 RECEIVED APR 2 0 1993 Alaska 011 & Gas Cons. C0mm~Jor. Anchorage TO' Larry Grant LOCATION: 3001 PORCUPINE DroVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Eric Graven LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS 2 survey listings PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING ONE COPY OF THIS ooct~:~r ~~s~:~:ay ~.A~.~Ot~ /~ DATED: Unocal North Amerir~ Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL April 19, 1993 TO' Larry Grant LOCATION: 3001 PORCUPINE DroVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Eric Graven LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS 1 blueline and 1 sepia ~/BHC Acoustilog\Gamma Ray\Caliper Segmented Bond Log\Gamma Ray Log\7" casing 4-Arm Caliper Log Gamma Ray Compensated Densilog\Compensated Neutron\Gamma Ray Dual Induction Focused Log\Gamma Ray Mudlog - Formation Log ,/Gpen Hole Tape and listing DATED: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF UNOCAL ) CORPORATION for an order ) granting an exception to spacing ) requirements of Title ) 20 AAC 25.055 to provide for ) the drilling of the Ivan River ) Unit 44-36 Gas Development Well. ) Conservation Order No. 308A UNOCAL Corporation Ivan River Unit 44-36 Gas Development Well February 5, 1993 IT APPEARING THAT: UNOCAL Corporation submitted an application dated December 22, 1992 requesting an exception to 20 AAC 25.055 (a)(4) to allow drilling the Ivan River Unit 14-31 RD No. 1 gas development well closer than 1500 feet from the boundary of a drilling unit and to within 3,000 feet of another well capable of producing from the same pool. 2. Notice of hearing was published in the Anchorage Daily News on December 29, 1992 pursuant to 20 AAC 25.540. 3. No protests to the application were received. 4~ UNOCAL Corporation through correspondence dated February 3, 1993 has canceled its plans to drill Ivan River Unit 14-31RD No. 1 well to the approved spacing exception location and instead requests that the provisions of Conservation Order No. 308 be applied to Ivan River Unit 44-36. Conservation Or~ February 5, 1993 Page 2 No. 308A FINDINGS: I , e 3, e Conservation Order No. 308 issued January 19, 1993, granted a spacing exception for the Ivan River Unit 14-31 RD No. 1 gas development well to allow drilling to a proposed bottomhole location in Section 36, T14N, R9W, SM. The Ivan River Unit 44-36 well as proposed will be directionally drilled from a proposed surface location 742 feet from the south line (FSL) and 777 feet from the east line (FEL) of Section 1, T13N, Rgw Seward Meridian (SM). The proposed bottomhole location is 209 feet FSL and 791 feet FEL of Section 36, T14N, R9W SM. An exception to 20 AAC 25.055 (a)(4) is necessary to allow drilling of the Ivan River Unit 44-36 well. The proposed bottomhole location of the Ivan River Unit 44-36 is within the same quarter, quarter section as previously approved for spacing exception under Conservation Order No. 308 for the Ivan River Unit 14-31 RD No. 1 well. CONCLUSION: I · The proximity of the proposed bottomhole location of Ivan River Unit 44-36 and the previously proposed and approved bottomhole location of Ivan River Unit 14-31 RD No. 1 is such that the intent and provisions of Conservation Order No. 308 may be applied to the Ivan River Unit 44-36 spacing exception. Granting a spacing exception to allow drilling of the Ivan River Unit 44-36 well as proposed will not result in waste nor jeopardize correlative rights. Conservation Orde~ ~. 308A February 5, 1993 Page 3 NOW, THEREFORE, IT IS ORDERED: UNOCAL Corporation's application for an exception to 20 AAC 25.055 for the purpose of drilling the Ivan River Unit 44-36 well is approved as proposed. Conservation Order No. 308 is hereby revoked and Conservation Order 308A is issued in its place. DONE at Anchorage, Alaska and dated February 5, 1993. Commission · Russell A. Douglass,/Xgommissioner Alaska Oil and Gas Conservation Commission ,~-'-~, STATE OF ALASKA ~ ' ' ALASF iL AND GAS CONSERVATION COMME N WELL COMPLETI( N OR RECOMPLETION RE,-, ORT AND LOG 1. Status of Well ' ClassificatiOn of Service Well' OIL U GAS [~ SUSPENDED [--] ABANDONED[-~ SERVICE ~ ' 2. Name of Operator [~..,AT~i 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) ~J~ 93-22 / ... 3. Address'~/]' - ~, ] 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 ~~ 283-20089 4. Location of well at surface 742' FSL, 777' FEL OF SEC. 1, T13N, R9W, SM ~ 9. Unit or Lease Name i ~OMPLETiOtq IVAN RIVER -" ~)./" At Top Producing Interval (6431') 4382'FSL 817' FEL OF SEC. 1, T13N, R9W, SM ~ _ i-~ATF~ ~ 1'0. Well Number At Total Depth (8308') 298' FSL, 932' FEL OF SEC. 36, T14N, R9W, SM--~ V~':hIF,.E~:~' ~ 11. Field and Pool i~ _~¢'._//~._..~..~ ~ IVAN RIVER/UNNAMED 5. Elevation51,KB in feet (indicate KB, DF, etc.) 6. Lease DesignatiOnlvAN RIVERand Serial No. 12. Date Spudded 02/10/93 13' Date T'D' Reached 03/0.1/93 114' Date C°mp" Susp' °r Aband' I15' Water Depth' if °fish°re 16' N°' °f C°mploti°ns 03/07/93 N/A FoetMSL 1 17. Total Depth (MD+TVD)8308,/6438, 18' plUg Back Depth (MD+TVD)8272'/6408' YEsl 9' Directi°nal Surve~ 120' Depth where SSSV set~ NO ~_J N/A feet MD 121 ' Thickness of PermafrostN/A 22. Type Electric or Other Logs Run CNL/C- DENSITY/DIL/BHC-ACOUSTIC/GR/SP SBT/GR/CCL 23. CASING, LINER AND CEMENTING RECORD ' CASING SIZE WT. PER GRADE TOP I BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# 26' 88' DRIVEN 13- 3/8" 68# K- 55 26' 908' 17.5" 115 BBLS (to surface) 9-5/8" 47# N-80 25' 3499' 12.25" 270 BBLS (to surface) 7" 29# N-80 25' 8308' 8.5" 129 BBLS 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 2-7/8" 6425' 3058' & 6339' Measured TVD 2-3/8" 2987' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6431'-6440' 5000'-5005' DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 6557' - 6568' 5090' - 5097' N/A 6836' - 6852' 5295' - 5306' 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/22/93 FLOWING Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAs-OIL RATIO 2/22/93 TEST PERIOD FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL oILGRAvITY-API (corr) Press. 2300 0 24-HOUR RATE 6580 --- 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED A~aska Oil & G~s Co~s. rJor~tmtss~°~' Anchorage Form 10-407 Submit in duplicate 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 Beluga 6748 5128 NONE 31. LIST OF A~ACHMEN~ 32. I hereb~ify~t t~ ~oi~to the best of my knowledge ~, Signed G. RUSSELLSCHMIDT Title DRILLING MANAGER Date 04/13/93 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: Indicatewhich 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 recordsfor thiswell 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". IVAN RIVER FIELD WELL 44-36 PRESENT 13-3/8' at 908' 9-5/8' at 3449' 7' CASING AT 8308' TD AT 8308' 2-3/8", 4.6#, N-80, Butt to 2987' BAKER CMU SLIDING SLEEVE 3104' BAKER "FH' PACKER AT 3058 2-7/8" 6.4#, N-80 BUI-I' COMPLETION BAKER 'FH" PACKER AT 6339' BAKER 'R' PROFILE (2.257' ID) 6351' TAIL AT 6425' PERFORATIONS 12 SPF 6431' - 6440' 655T - 6568' 6836' - 6852' 438' 4-3/8" TCP PERF GUNS GRB 3-18-92 NOTE: TUBING MEASUREMENTS ARE 13' DEEPER THAN DIL IVAN RIVER #44-36 IRU 44-36 DAY I (2/10/93) 20" ~ 94' CONT'D TO MOVE RIG. ACCEPTED GRACE RIG Cf154 AT 0600 HRS. MIXED MUD. DRILLED 17-1/2" HOLE TO 136'. STABALIZER HUNG UP ON THE 20" DRIVE SHOE. POOH. IRU 44-36 916'/619' DAY 2 (2/11/93) 20" ~ 94' CONT'D POOH. DRESSED 20" DRIVE SHOE AT 94'. RIH WITH BHA, 17.5" STAB WOULD NOT PASS SHOE. POOH. DRESSED 20" DRIVE SHOE. RIH AND DRILLED 17-1/2" HOLE FROM 136'-755'. IRU 44-36 2234'/1318' DAY 3-5 (2/12-14/93) 20" @ 94' DRILLED 17-1/2" HOLE TO 916'. SHORT TRIP. POOH. RAN AND CEMENTED 13-3/8" CASING AT 908'. REMOVED DIVERTER. INSTALLED AND TESTED BOPE TO 2000 PSI, OK. RIH AND TAGGED CMT AT 854'. TESTED CASING TO 1500 PSI, OK. DRILLED 12-1/4" HOLE TO 916'. PERFORMED LEAK OFF TEST, GOOD. DRILLED 12-1/4" HOLE TO 1654'. TRIPPED FOR BHA. DRILLED 12-1/4 HOLE TO 2234'. IRU 44-36 2234'/1318' DAY 6 (2/16/93) 20" ~ 94' DRILLED 12-1/4" HOLE FROM 2234'-2634'. TRIP FOR BIT. DRILLED TO 2834'. IVAN RIVER #44-36 IRU 44-36 2234'/1318' DAY 7 (2/17/93) 20" @ 94' DRILLED 12-1/4" HOLE FROM 2834'-3400'. SHORT TRIP. IRU 44-36 2234'/1318' DAY 8 (2/18/93) 20" @ 94' DRILLED 12-1/4" HOLE FROM 3400'-3453'. WIPER TRIP. CHANGED TO 9-5/8" RAMS. R/U AND RAN 9-5/8" CASING. IRU 44-36 4290'/887' DAY 9-11 (2/19-21 20" @ 94' 0.484 PSI /93) RAN 9~5/8" CASING TO 3453'. CEMENTED 9-5/8" CASING WITH 270 BBLS CEMENT. WOC. REMOVED BOPE. SET SLIPS. CUT CASING. INSTALLED AND TESTED PACKOFF, OK. INSTALLED BOPE, AND TESTED TO 5000 PSI, OK. RIH AND DRILLED CEMENT F/3342'-3365'. TESTED 9-5/8" CASING TO 1500 PSI, OK. DRILLED 8-1/2" HOLE TO 3465'. PERFORMED L.O.T., OK. DRILLED TO 4290'. IRU 44-36 5025'/735' DAY 12 (2/22/93) 20" @ 94' 0.484 PSI DRILLED 8-1/2" HOLE TO 4290'-4452'. TRIPPED FOR BIT. DRILLED FROM 4452'-5025'. IVAN RIVER #44-36 IRU 44-36 6235'/1210' DAY 13 (2/23/93) 20" @ 94' 494 PSI DRILLED 8-1/2" HOLE FROM 5025'-5564. SHORT TRIP. DRILLED FROM 5564'- 6235'. IRU 44-36 6866'/631' DAY 14 (2/24/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 499 PSI DRILLED 8-1/2" HOLE FROM 6235'-6306'. SHORT TRIP. DRILLED FROM 6306'- 6866'. IRU 44-36 7100'/234' DAY 15 (2/25/93) 20" @ 94' 13-3/8" @ 908' 9-5/8"@ 3449' 499 PSI DRILLED 8-1/2" HOLE FROM 6866'-7050'. SHORT TRIP. DRILLED FROM 7050'- 7082'. TRIP FOR WASHOUT. DRILLED FROM 7082'-7100'. IRU 44-36 8120'/1020' DAY 16-18 (2/26-28/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 520 PSI DRILLED 8-1/2" HOLE FROM 7100'-8120', CIRC & COND FOR LOGS, RAN ATLAS GRAND SLAM (DIL-GR-SP-CNL-DENSITY-CALIPER). RUN #2 4 ARM CALIPER. RUN #3 SBT 3450' - SURFACE RUN #4 DIA-LOG 64 ARM CSG CALIPER. RIGGED DN LOGGERS. TEST BOPE. TRIP IN W/RTTS. IVAN RIVER #44-36 IRU 44-36 8308'/188' DAY 19 (3/01/93) 20" @ 94' 13-3/8" @ 908' 9-5/8"@ 3449' 522 PSI RIH TO 3425' W/R~-FS. SET TOOL. PRESS 9-5/8" CSG TO 4100 PSI. 30 MINS. GOOD TEST. POOH DN RTFS. RIH W/BHA. DRILLED 8-1/2" HOLE F/8120'8308'. CIRC & COND HOLE FROM CSG. POOH BREAKING 5" D.P. IRU 44-36 8308' DAY 20 (3/02/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 7"@ 8308' 522 PSI BREAK KELLY 4D 5" HWDP & BHA. R/U & RUN 7" CSG TO 8308' CMT CSG @ 2400 HRS. 550 SXS TRINITY LIGHT W/ADDITIVES. IRU 44-36 8308' DAY 21 (3/03/93) 20" @ 94' 13-3/8" @ 908' 9-5/8" @ 3449' 7" @ 8308' 522 PSI CMPTD CMT 7" CSG WITH 550 SXS TRINITY LIGHT CEMENT PLUS ADDITIVES AT 13.2 PPG. CIP @ 0100. WOC 1HR INJECTED DOWN BACKSIDE (7"X 9-5/8" ANNULUS) 100 BBLS 2100 PSI @ 2 BPM. LIFTED STACK. SET CSG ON VETCO "W" SLIPS CUT OFF CSG. N/U TBG SPOOL TEST SAME. INSTALL 2-7/8" RAMS IN BOPE. RAN STACK TEST. L/D 5" D.P. FROM DERRICK. IVAN RIVER #44-36 IRU 44-36 8308' DAY 22 (3/04/93) 20" @ 94' 13-3/8" @ 908' 9-5/8"@ 3449' 7" @ 8308' 463 PSI CMPTD L/D 5" D.P. M/U 7" SCRAPER. RIH PICKING UP 2-7/8" TBG. CLEAN PITS. IRU 44-36 8308' DAY 23-25 (3/05-07/93) 20" @ 94' f 13-3/8" @ 908' 9-5/8" @ 3449' 7" @ 83O8' 463 PSI CMPTD P/U & RIH W/2-7/8" TBG & SCRAPER. CHG'D OVER TO 8.9 PPG KCL BRINE. POOH. RU ATLAS W/L RAN SBT W/GR. R/D ATLAS. MADE UP BAKER 4.5" TCP GUNS. RAN 2-7/8" COMPLETION W/2-3/8" SIDE STRING. POSITIONED GUNS ACROSS INTERVALS (6440'-6431 '; 6568'-6557'; 6852'-6836'). INSTALL BPV'S IN TBG HANGER. N/D BOPE. N/U & TEST TREE. PULLED BPV'S. SET PACKERS @ 6339' & 3058'. USING FIELD GAS DISPLACED BRINE TO ACHIEVE A 500 PSI UNDERBALANCE. DROPPED BAR & FIRED GUNS @ 1948 HRS 3/7/93 FLUID TO SURFACE @ 1957 HRS. RECOVERED 51 BBLS BRINE. R/U TO FLOW WELL TO PRODUCTION LINES. PREP WELLS #44-1, #41-1 & #13-31 FOR RIG MOVE @ 2400 HRS 3/7/93. IVAN RIVER #44-36 IRU 44-36 8308' DAY 26 (3/08/93) 20" @ 94' 13-3/8" @ 908' 9-5/8"@ 3449' 7" @ 8308' 463 PSI CHANGED HEATER STRING AND ANNULUS TO FREEZE PROTECTED BRINE. CLEANED PITS. RELEASED GRACE RIG #154 @ 1800 HRS FOR A TURNKEY RIG MOVE. UNOCAL Ivan River 44-36 slot #44-36 Ivan River Field Cook Inlet, Alaska SURVEY LISTING by Eastman Te[eco Your ref : PMSS <0-8308'> Our ref : svy3?09 License : Date printed : 5-Mar-93 Date created : 12-Feb-93 Last revised : 2-Mar-93 Field is centred on 360387.836,2645652.913,999.00000,N Structure is centred on 360387.836,2645652.913,999.00000,N Slot location is n61 14 27.606,w150 47 48.844 Slot Grid coordinates are N 2646404.221, E 359619.950 Slot local coordinates are 742.00 N 7T7.00 W Reference North is True North UNOCAL SURVEY LISTING Page 1 Ivan River ,44-36 Your ref : PMSS <0-8308'> Ivan River Field,Cook Inlet, Alaska Last revised : 2-Mar-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 97.00 0.50 222.10 97.00 0.31S 0.28 W 0.52 -0.31 191.00 1.00 222.10 190.99 1.23 S 1.11W 0.53 -1.23 284.00 0.40 153.60 283.98 2.12 S 1.51W 1.00 -2.12 376.00 1.60 356.10 375.97 1.13 S 1.45 ~ 2.15 -1.13 465.00 3.30 356.10 464.89 2.67 N 1.71W 1.91 2.66 555.00 4.70 359.90 554.67 8.94 N 1.89 ~ 1.58 8.94 645.00 6.20 350.50 644.26 17.42 N 2.70 W 1.93 17.41 733.00 7.80 354.70 731.60 28.06 N 4.04 W 1.91 28.04 825.00 8.30 358.20 822.70 40.91N 4.82 W 0.76 40.89 859.00 9.10 355.40 856.30 46.04 N 5.12 ~ 2.66 46.03 952.00 10.80 356.10 947.90 62.07 N 6.30 W 1.8~ 62.05 1044.00 13.00 356.40 1037.92 81.00 N 7.54 W 2.39 80.97 1135.00 15.10 354.70 1126.19 103.02 N 9.27 ~ 2.35 102.99 1227.00 17.50 354.00 1214.49 128.71N 11.83 ~ 2.62 128.67 1319.00 19.70 354.30 1301.68 157.90 N 14.81 ~ 2.39 157.85 1411.00 22.00 352.20 1387.65 190.41N 18.69 ~ 2.63 190.35 1502.00 24.10 353.60 1471.38 225.76 N 23.08 W 2.38 225.69 1594.00 25.80 354.30 1554.79 264.35 N 27.16 ~ 1.88 264.27 1686.00 28.30 355.70 1636.72 306.03 N 30.78 ~ 2.80 305.93 1778.00 31.30 357.10 1716.55 351.65 N 33.63 ~ 3.35 351.55 1867.00 33.30 358.90 1791.77 399.17 N 35.27 ~ 2.49 399.06 1960.00 35.80 359.90 1868.37 451.91N 35.80 W 2.76 451.80 2052.00 39.30 0.60 1941.30 507.97 N 35.55 ~ 3.83 507.86 2144.00 42.90 1.00 2010.61 568.43 N 34.69 W 3.92 568.32 2236.00 43.30 1.00 20T7.79 631.28 N 33.60 W 0.43 631.18 2329.00 42.30 2.40 2146.02 694.44 N 31.73 ~ 1.48 694.34 2420.00 43.40 2.40 2212.74 756.27 N 29.14 W 1.21 756.18 2513.00 43.10 2.10 2280.48 819.94 N 26.64 ~ 0.39 819.86 2605.00 43.60 2.10 2347.38 883.05 N 24.32 W 0.54 882.98 2696.00 44.60 1.70 2412.72 946.34 N 22.22 W 1.14 946.27 2791.00 45.60 1.00 2479.78 1013.62 N 20.64 W 1.17 1013.55 2883.00 46.20 0.30 2543.81 1079.68 N 19.90 W 0.85 1079.61 2973.00 44.60 0.60 2607.00 1143.76 N 19.39 ~ 1.79 1143.69 3065.00 44.30 0.60 2672.67 1208.18 N 18.72 W 0.33 1208.12 3158.00 44.90 0.60 2738.89 1273.48 N 18.04 ~ 0.64 1273.42 3250.00 45.90 359.20 2803.49 1338.98 N 18.16 ~ 1.53 1338.92 3340.00 47.10 359.90 2865.44 1404.26 N 18.67 W 1.45 1404.20 3400.00 46.10 359.60 2906.67 1447.85 N 18.86 W 1.70 1447.79 3490.00 46.40 1.00 2968.90 1512.86 N 18.51 W 1.17 1512.80 3581.00 47.10 359.60 3031.26 1579.14 N 18.17 W 1.36 1579.08 3672.00 47.60 359.90 3092.91 1646.07 N 18.46 W 0.60 1646.00 3764.00 46.90 358.90 3155.36 1713.62 N 19.17 ~ 1.10 1713.55 3857.00 46.30 359.60 3219.26 1781.18 N 20.05 ~ 0.84 1781.12 3949.00 46.30 359.60 3282.82 1847.70 N 20.52 ~ 0.00 1847.62 4134.00 46.50 358.20 3410.40 1981.64, 23.09, 0.56 1981.56 4225.00 46.80 358.20 3472.87 2047.78 N 25.17 g 0.33 2047.69 4316.00 46.90 357.80 3535.10 2114.13 N 27.49 ~ 0.34 2114.04 4407.00 46.90 357.10 3597.28 2180.51 N 30.45 ~ 0.56 2180.40 All data is in feet unless otherwise state~ Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea [eve[ Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.48 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature methedd. Presented by Eastman Te[eco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <0-8308'> Last revised : 2-Mar-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 4498.00 47.50 357.50 3659.11 2247.20 N 33.59 W 0.73 2247.09 4591.00 48.60 357.10 3721.28 2316.29 N 36.85 W 1.22 2316.17 4684.00 48.00 357.80 3783.15 2385.66 N 39.94 W 0.86 2385.53 4776.00 47.60 357.80 3844.94 2453.76 N 42.56 W 0.43 2453.62 48~.00 48.40 358.20 3906.50 2522.09 N 44.94 ~ 0.93 2521.94 4959.00 47.60 357.80 3967.40 2589.67 N 47.30 W 0.94 2589.52 5052.00 46.10 358.50 4031.00 2657.48 N 49.50 W 1.70 2657.32 5144.00 45.40 359.60 4095.20 2723.37 N 50.59 ~ 1.14 2723.21 5235.00 45.10 359.90 4159.26 2788.00 N 50.88 W 0.40 2787.83 5324.00 45.40 0.30 4221.92 2851.20 N 50.76 W 0.46 2851.04 5417.00 46.10 0.30 4286.81 2917.82 N 50.42 ~ 0.75 2917.65 5509.00 45.90 359.90 4350.72 2984.00 N 50.30 W 0.38 2983.83 5603.00 45.70 0.60 4416.25 3051.39 N 50.01 ~ 0.57 3051.22 5696.00 45.60 0.60 4481.26 3117.88 N 49.31 ~ 0.11 3117.72 5785.00 46.10 0.30 4543.26 3181.74 N 48.81 ~ 0.61 3181.58 5878.00 45.80 1.00 4607.92 3248.58 N 48.05 ~ 0.63 3248.42 5971.00 45.20 1.00 4673.10 3314.90 N 46.89 W 0.64 3314.74 6064.00 45.20 1.40 4738.63 3380.88 N 45.51 ~ 0.30 3380.72 6158.00 45.00 1.00 4804.90 3447.44 N 44.12 ~ 0.37 3447.30 6251.00 44.50 359.20 4871.04 3512.91 N 44.00 W 1.46 3512.76 6345.00 44.60 358.90 4938.02 3578.85 N 45.09 ~ 0.25 3578.70 6/,39.00 44.70 358.20 5004.90 3644.89 N 46.76 W 0.53 3644.73 6532.00 43.00 356.40 5071.96 3709.24 N 49.78 ~ 2.27 3709.07 6626.00 42.40 355.70 5141.05 3772.83 N 54.17 W 0.81 3;r72.65 6719.00 42.70 355.70 5209.56 3835.54 N 58.89 ~ 0.32 3835.35 6811.00 42.10 355.40 5277.50 3897.39 N 63.70 ~ 0.69 3897.18 6903.00 42.50 355.40 5345.54 3959.11 N 68.67 W 0.43 3958.88 6995.00 42.50 355.00 5413.37 4021.04 N 73.87 ~ 0.29 4020.80 7089.00 42.30 355.00 5482.79 4084.19 N 79.39 ~ 0.21 4083.93 7182.00 41.70 354.30 5551.90 4146.14 N 85.19 ~ 0.82 4145.87 7275.00 41.10 354.30 5621.66 4207.34 N 91.30 W 0.64 4207.05 7369.00 40.60 354.30 5692.76 4268.52 N 97.41 W 0.53 4268.21 7460.00 40.00 354.30 5762.16 4327.09 N 103.25 ~ 0.66 4326.76 7553.00 39.30 354.00 5833.77 43~.12 N 109.30 ~ 0.78 4385.77 7647°00 38.80 354.70 5906.77 4445.05 N 115.13 ~ 0.71 4444.68 7738.00 38.30 354.00 5977.94 4501.49 N 120.71 W 0.73 4501.10 7830.00 37.50 354.30 6050.53 4557.71 N 126.47 ~ 0.89 4557.30 7926.00 37.10 354.00 6126.90 4615.58 N 132.40 W 0.46 4615.16 8020.00 36.50 354.00 6202.17 4671.58 N 138.29 W 0.64 4671.14 8085.00 35.60 354.00 6254.72 4709.62 N 142.29 ~ 1.38 4709.17 8114.00 35.30 354.00 6278.34 4726.35 N 144.04 ~ 1.03 4725.89 8206.00 34.80 354.00 6353.66 4778.89 N 149.57 ~ 0.54 4778.42 8273.00 34.30 354.00 6408.84 4816.68 N 153.54 W 0.75 4816.20 8308.00 34.30 354.00 6437.76 4836.30 N 155.60 W 0.00 4835.80 Projected Data - NO SURVEY AIl data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean Vertical section is fr~ wellhead on azi~th 0.17 degrees. Declination is 23.48 degrees, Convergence is -0.69 degrees. Calculation uses the mini~ curvature ~th~. Present~ by East~n Te[eco UNOCAL SURVEY LISTING Page 3 Ivan River ,44-36 Your ref : PMSS <0-8308'> Ivan River Field,Cook Inlet, Alaska Last revised : 2-Mar-93 Co,~aents in wellpath MD TVD Rectangular Coords. Comment 8308.00 6437.76 4836.30 N 155.60 W Projected Data - NO SURVEY Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 44-36 #2 Revised not specified 5571.00 4201.00N 12.69E 24-Jan-93 44-36 Revised not specified 4990.00 3640.00N 11.00E 24-Jan-93 All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Bottom hole distance is 4838.80 on azimuth 358.16 degrees from wellhead. Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.48 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco Alaska Region UNOCAL~ Unocal North Americ; Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 DOCUMENT TRANSMITTAL March 25, 1993 TO' Larry Grant LOCATION' 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Eric Graven LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL IVAN RIVER UNIT 44-36 TRANSMITTING AS FOLLOWS 3 boxes dry cut samples ~ /5'-0 .-- 5/30 75-0 -' g3o ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK~Y~OU RECEIVED BY' MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to. avid John~3n Commissioner date: file: thru: Blair E Wondzell ~/(.d?.y subject: Sr Petr Engineer from: L~ou Grimaldi Petr Inspector February 18, 1993 LOU02091.DOC Diverter Inspection Grace Rig 154 UNOCAL Ivan River 44 Ivan River Unit P.T.D. 93-22 Tuesday, February 9, 1993: I traveled to the west side of Cook Inlet to witness the function test of Grace rig 154 diverter system When I arrived the rig crew was still erecting the vent lines and tightening up the stack. I made a tour of the rig and stood by till the following morning. Wednesday, February 10, 1993: The rig crew summoned me at 0600 hrs this morning and we function tested the diverter system. I found the closure test time of 52 seconds to be normal for this rig and acceptable for a 20 inch annular preventer. All valves operated properly and the accumulator recovered quickly. The layout of the vent lines was quite good with all flanges made up properly. The vent line was 10 inch which ran to the edge of the pad with a tee that was valved and went to the reserve pit. Terry Coleman (Grace toolpusher) conducted the function test and I found him to be friendly, cordial and helpful in answering my questions. Summary; The diveder inspection and function test I observed on Grace rig 154 revealed all to be in compliance. February 9, 1993 G. Russell Schmidt Regional Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Ivan River 44-36 UNOCAL .Permit No: 93-22 Sur. Loc. 742'FSL, 777'FEL of Sec. 1, T13N, R9W, SM Btmhole Loc. 209'FSL, 791'FEL, of Sec. 36, T14N, R9W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. David W~ Johnsto~ - Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ printed on recycled paper STATE OF ALASKA .--* ALASKA'¢-''', AND GAS CONSERVATION COl~ SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~ 1 lb. Type of well. Exploratory ~ Stratigraphic Test [~ Development Oil Re-Entry ~ Deepen ~I Service ~ Development Gas [~ Single Zone[] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 51.5 feet IVAN RIVER/UNNAMED 3. Address 6. Property Designation P.O. Box 196247, Anchorage, AK 99519 ADL ~ $.2,, 4. Location of well at surface 742' FSL, 777' FEL of 7. Unit or property name 11. Type Bond (SEE 20 ACC 25.025) Sec. 1, T13N, R9W, SM Ivan River United Pacific Ins. Co. At top of productive interval (7207') 4202' FSL, 788' FEL 8. Well number Number of Sec. 1, T13N, R9W, SM 44-36 U62-9269 At total depth (8007') 209' FSL, 791' FEL, 9. Approximate spud date Amount Sec. 36, T14N, R9W, SM ~..~. o~mue~ 9, 1993 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and 3'VD) property line Greater than 1500 feet 25' @ surface feet 2295.34 8007'MD/6156' TVD feet 16. To be completed for deviated wells 17. Anticipated Pressure(see 20 AAC 25.~35 (e)(2)) Kickoff depth 400 feet Maximum hole angle 45 deg Maximum surface 1145 psig At total depth (WD) 6156' pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 94# WELDEE 64' 0 0 88' 88' DRIVEN 17-1/2" 13-3/8" 61# K55 BU-I-I' 871' 0 0 895' 891' 1000 SXS (To surface) 12-1/4" 9-5/8" 47# N80 BUTT 2976' 0 0 3000' 2586' 1800 SXS (to surface) 8-1/2" 7" 29# NS0 BUTT 7983' 0 0 8007' 6156' 500 SXS (to 4000') 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface ;i'~:~ '".'-~' ii~ Intermediate Production i:' :'. i;'? -" ,'? ¢.;., Liner Perforation depth: measured ,,":~i;:?(:! i..ii! ,'?: i;.;.:': :: ,;;:. i~3. ,.;,;.?? true vertical 20. Attachments Filing fee [~; Property plat ~: BOP SketchE~ Diverter Sketch [~: Drilling program E~ Drilling fluid program E~; T~e vs depth plot E~ Refraction analysis ~ Seabed report [] 20 AAC 25.050 requirements 21.1 hereby cer~t~~nd correct to the best of my knowledge Signed G. RUSSELLSCHMIDT Title REGIONAL DRILLING MANAGER Date Commission Use Only Permit Number APl numberI ~]~Y~ees I Appr~,~,a, ..da~ ..._ See cover letter ~._,~ -,,.~ ,2. 50- .7_ ~ ~ --.2.. co :~ c~ for other requirements Conditions of approval Samples required ~ Yes ~ No Mud log required ~ No Hydrogen sulfide measures [~ Yes ~' No Directional survey required ~ Yes ~ No Required working pressure forBOPE ~ 2M; r-1 3M; [~ 5M; ~ 10M; [~ 15M Other: Approved by F~vid W. o,~nr~ston Commissioner the commission Date Form 10-401 Rev. 12-1-85 ,~;~'~r~it in triplicate IVAN RIVER 44-36 PROCEDURE: 1. DRIVE 20" CASING TO 88' KB. 2. INSTALL DIVERTER. . . DRILL 17-1/2" HOLE TO 895'. RUN AND CEMENT 13-3/8" CASING. 5. INSTALL 13-5/8" 5000 PSI BOPE AND TEST TO 2000 PSI. , . . DRILL 12-1/4" HOLE TO 3000'. RUN AND CEMENT 9-5/8" CASING. TEST BOPE TO 5000 PSI. 9. DRILL 8-1/2" HOLE TO 8007' MD. 10. RUN AND CEMENT 7" CASING. 11. CHANGE THE WELL OVER TO BRINE. 12. RUN A 2-7/8" COMPLETION TO 6350' WITH TCP DROP OFF GUNS AND PACKERS AT 3050' AND 6300'. 13. 14. RUN A 2-3/8" N-80 BUTT HEATER STRING TO 3000'. CHANGE THE TOP 3000' OVER TO GLYCOL/WATER HEATER STRING FLUID. 15. REMOVE BOPE, INSTALL TREE. 16. PERFORATE THE STERLING-BELUGA SANDS AND DROP OFF THE GUNS. TIME: 35 DAYS + 4- 35 +4- ! r.mmmm 13-31 AN R 14-31 to ..I- i 44-1 4- R 4- 13 UNOr..ALO Unocal North American Oil & Gas Division ALASKA REGION IVAN RIVER UNIT STRUCTURE CONTOURS TOP UPPER TYONEK TESTED GAS SAND IVAN RIVER FIELD WELL 44-36 PROPOSED 13-3/8" at 895' 9-5/8" at 3000' 7" CASING AT 8007' TCP /'////////////~ 2-3/8", 4.6#, N-80, Butt to 3000' SLIDING SLEEVE AT 3000' PACKER AT 3050' 2-7/8" COMPLETION PACKER AT 6300' DROP OFF GUNS ACROSS THE STERLING BELUGA GRB 2-3-92 CASING AND TUBING DESIGN ELL Ivan River 44-36 ~SING STRING 13-3/8"-9-5/8"-7" FIELD Ivan River BOROUGH Mat-Susitna. STATE AK DATE 2/3/93 DESIGN BY George Buck · t,IUD WT. I 9.6 #/q. HYD GR. I ,0,5 pst/ft. MUD WT. II 9.9 0.514 10.1 0.525 #/q. HYD. GR. II psi/ft. M.S.P. psi. INTERVAL ASING SIZE Bottom Top · 13-3/8" 895' 24' DESCRIPTION LENGTH Wt. Grade Thread 871 61# K-55 Butt WEIGHT IENSION MINIMUM COLLAPSE COLLAPSE W/ BF -top of STRENGTH .PRESS. ~ RESIST. W/O BF sectton TENSION bottom tension lbs lbs 1000 lbs TDF , psi psi 53,131 Same 962 18 447 1540 INTERNAL BURST MINIMUM PRESSURE YIELD CDF psi psi BDF 3.4 447 3090 6.9 ' 9-5/8" 3b00' 2~' 2977 47# N-80 Butt 29# N-80 Butt 139,919. Same 893 6.4 1329 4750 3.6 1329 1870 ..... '~'5.2 '. 7" 8007' 23' 7984 231,536 Same.. 676 2.9 3231 , 7020 2.2 323~ q______~ 2.5 EXHIBIT F ANGLED FILL UP LINE-~ t0 "VENT LINE WEI'I' NAME:_ lva__n River I · :. · RIG CONTRACTOR: F[JG: ~3 J V ER TER SIZE: DJVERTER LINE SIZE: DEPT. APPROVAL 20" lO" lO - ~-IYDRAUUC: NOTES: VENT LINES ARE 180° APART· FLEX HOSE (~.~ IS TO BE USED' I NECESSARY WITH DDt, APPROVA 3. BALL VALVES TIED TOGE'f SO THAT ONE IS OPEN AND ONE CLOSED. 4. DIVERTER LINE MIN. 10" O.D. NOTE: ALL CHANGES Must HAVE WRITTEN APPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT. M.E.G.i 1 1/26185 20" OR 30" DiVERTER C O NTRACTOR Ri G UNION OIL COMPANY OF CALIFORNIA · ',NCHORAGE , /tLASKA on,~w# 43 A W APP'O. DAT~: F-ILL-UP KILL LINE ANNULAR BOP 13%"3000 ps~ PIPE RAMS 13%"5000' ps~ BLIND RAMS 135/8"5000 pst FLOW ~3s/a'soo9 p~~ CHOKE 5000 ~i I ~l~ ] iI[t 4" 5000 psi I PIPE RAMS I ~a%"sooo ps~ LINE~ RISER 135/8" 5000 psi, IVAN RIVER BOPE STACK 13 %" 5000 psi IVAN RIVER UNIT WELL NO. 44-36 MUD TYPE: DEPTH: SPUD MUD PROGRAM Low Solids/Non Dispersed/Fresh Water Gel 24' - 895' MUD PROPERTIES: Weight (Lbs/Cu ft) = 68-72 PCF Funnel Viscosity (Sec/Qt) = 60 - 150 API Fluid Loss < 20 cc MUD PROGRAM MUD TYPE: Low Solids/Non Dispersed/Fresh Water Gel DEPTH'. 895'- 3000' MUD PROPERTIES: Weight (Lbs/Cu ft) = 70-74 PCF Funnel Viscosity (Sec/Qt) = 38 - 50 Plastic Viscosity (cps) = 12 - 25 Yield Point (#/100 Cu ft) = 12 - 25 API Fluid Loss (cc) = 5 - 8 pH = 9.0 - 10.0 MBT (Lbs/bbl) < 25 Drilled Solids (Lbs/bbl) < 50 MUD TYPE: Fresh Water Gel / Polymer Mud DEPTH: 3000'- 8,007' MUD PROPERTIES: Weight (Lbs/Cu ft) = 72-76 PCF Funnel Viscosity (Sec/Qt) = 38 - 50 Plastic Viscosity (cps) = 12 - 25 Yield Point (#/100 Cu ft) = 12 - 25 API Fluid Loss (cc) = 5 - 8 HPHT Fluid Loss (cc) = 12 - 15 (500 psi @ 200 Degrees F) pH = 9.0 - 10.0 MBT (Lbs/bbl) < 25 Drill Solids (Lbs/bbl) < 50 IVAN RIVER UNIT WELL NO. 44-36 Anticipated Pressures for the 17-1/2" hole: Mud Weight = 70 PCF = 0.486 psi/ft Total Depth of 17-1/2" hole is 895' MD , 895' TVD Pore Pressure Gradient = 0.450 psi/ft Maximum Surface Pressure cannot exceed maximum bottom hole pressure; 895' * 0.450 psi/ft = 403 psi Anticipated Pressures for the 12-1/4" hole: Mud Weight = 74 PCF = 0.514 psi/ft 13-3/8" shoe is proposed to be at 895' MD, 895' TVD Total Depth of 12-1/4" hole is 3000' MD , 2586' TVD Estimated fracture gradient (13-3/8" shoe) = 0.90 psi/ft Pore Pressure Gradient = 0.450 psi/ft Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure = (2586 ft * 0.450 psi/ft) -0.5 (2586 ft * 0.514 psi/ft) - 0.5 (2586 ft * 0 psi/ft) = 499 psi Anticipated Pressures for the 8-1/2" hole: Mud Weight = 76 PCF = 0.528 psi/ft 9-5/8" shoe is proposed to be at 3000' MD, 2586' TVD Total Depth of 8-1/2" hole is 8007' MD , 6156' TVD Estimated fracture gradient (9-5/8" shoe) = 0.90 psi/ft Pore Pressure Gradient = 0.450 psi/ft Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure = (6156 ft * 0.450 psi/ft) - 0.5 (6156 ft * 0.528 psi/ft) - 0.5 (6156 ft * 0 psi/ft) = 1145 psi GRACE ~154 ~ ~o~.- ~ Active Mud System ~ PILL PIT ~ SUCTION PIT ~ 72 BBL i 200 BBL i ~BBL/INCIt ¢ 2.3BBL/INCIt '/////? -"- 442' i VOLUME PIT ~ 4-37 BBL ~ 5.0B / / ? / t"' 145' / ///////////////////////////////////////~-,~// "///////////////////////////////////////////////// I#~l DESILTER PIT Iff°l DEGASSER PIT 140 BBL s4 152 BBL 11////i/.//////.////////~ //_/ I~' ........... 81'- ..... ~' 55: ._ . ,: ///////////////////////////,," ,'-/i / //////I//I//I//'/I///////////////////// ////////////////.//////////////////' TOTAL USABLE VOLUME - 1001 BBL - 11.7 BBL/INCH UNOCAL Ivan River 44-36 slot #44-36 Ivan River Field Cook Inlet, Alaska PROPOSAL L I ST I NG by Eastman Teleco Your ref : 44-36 Version #3 Our ref : prop672 License : Date printed : 2-Feb-93 Date created : 22-Jan-93 Last revised : 2-Feb-93 Field is centred on 360387.836,2645652.913,999.00000,N Structure is centred on 360387.836,2645652.913,999.00000,N Slot location is n61 14 27.606,w150 47 48.844 Slot Grid coordinates are N 2646404.221, E 359619.950 Slot local coordinates are 742.00 N 777.00 W Reference North is True North UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Measured [nclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 0.00 0.00 0.17 0.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 0.17 400.00 0.00 N 0.00 E 0.00 0.00 500.00 2.50 0.17 499.97 2.18 N 0.01 E 2.50 2.18 600.00 5.00 0.17 599.75 8.72 N 0.03 E 2.50 8.72 700.00 7.50 0.17 699.14 19.61 N 0.06 £ 2.50 19.61 800.00 10.00 0.17 797.97 34.82 N 0.10 E 2.50 34.82 895.00 12.38 0.17 891.16 53.25 N 0.16 E 2.50 53.25 900.00 12.50 0.17 896.04 54.32 N 0.16 E 2.50 54.32 1000.00 15.00 0.17 993.17 78.09 N 0.24 E 2.50 78.09 1100.00 17.50 0.17 1089.17 106.07 N 0.32 E 2.50 106.07 1200.00 20.00 0.17 1183.85 138.21 N 0.42 E 2.50 138.21 1300.00 22.50 0.17 1277.04 174.45 N 0.53 E 2.50 174.46 1400.00 25.00 0.17 1368.57 214.72 N 0.65 E 2.50 214.73 1500.00 27.50 0.17 1458.25 258.95 N 0.78 E 2.50 258.95 1600.00 30.00 0.17 1545.92 307.04 N 0.93 E 2.50 307.05 1700.00 32.50 0.17 1631.40 358.92 N 1.08 E 2.50 358.92 1800.00 35.00 0.17 1714.54 414.47 N 1.25 E 2.50 414.47 1900.00 37.50 0.17 1795.18 473.60 N 1.43 E 2.50 473.60 2000.00 40.00 0.17 1873.16 536.18 N 1.62 E 2.50 536.19 2100.00 42.50 0.17 1948.34 602.11 N 1.82 E 2.50 602.12 2199.74 44.99 0.17 2020.38 671.07 N 2.03 E 2.50 671.08 2500.00 44.99 0.17 2232.72 883.36 N 2.67 E 0.00 883.37 3000.00 44.99 0.17 2586.32 1236.88 N 3.74 E 0.00 1236.88 3500.00 44.99 0.17 2939.91 1590.39 N 4.81 E 0.00 1590.40 4000°00 44.99 0.17 3293.51 1943.90 N 5.87 E 0.00 1943.91 4500.00 44.99 0.17 3647.10 2297.41 N 6.94 E 0.00 2297.42 5000.00 44.99 0.17 4000.69 2650.92 N 8.01 E 0.00 2650.94 5500.00 44.99 0.17 4354.29 3004.43 N 9.08 E 0.00 3004.45 6000.00 44.99 0.17 4707.88 3357.95 N 10.15 E 0.00 3357.96 6398.93 44.99 0.17 4990.00 3640.00 N 11.00 E 0.00 3640.02 6428.56 44.92 0.17 5010.97 3660.94 N 11.06 E 0.25 3660.95 6528.56 44.67 0.17 5081.93 3731.40 N 11.28 E 0.25 3731.41 6628.56 44.43 0.17 5153.19 3801.55 N 11.49 E 0.25 3801.57 6728.56 44.18 0.17 5224.76 3871.39 N 11.70 E 0.25 3871.41 6828.56 43.93 0.17 5296.62 3940.93 N 11.91 E 0.25 3940.95 6928.56 43.69 0.17 5368.79 4010.16 N 12.12 E 0.25 4010.18 7028.56 43.44 0.17 5441.25 4079.07 N 12.33 E 0.25 4079.09 7128.56 43.19 0.17 5514.01 4147.67 N 12.53 E 0.25 4147.69 7206.61 43.00 0.17 5571.00 4201.00 N 12.69 E 0.25 4201.02 7500.00 43.00 0.17 5785.57 4401.09 N 13.30 E 0.00 4401.11 8000.00 43.00 0.17 6151.25 4742.08 N 14.33 E 0.00 4742.11 8006.61 43.00 0.17 6156.08 4746.59 N 14.34 E 0.00 4746.61 KOP 13 3/8" Csg Pt EOC 9 5/8" Csg Pt Target A - Top Sterling Target B - Base Beluga TD - 7" Csg Pt All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 44-36 Version Last revised : 2-Feb-93 Comments in weLLpath MD TVD Rectangular Coords. Cocment 400.00 400.00 0.00 N 0.00 E 895.00 891.16 53.25 N 0.16 E 2199.74 2020.38 671.07 N 2.03 E 3000.00 2586,32 1236.88 N 3.74 E 6398.93 4990.00 3640.00 N 11.00 E 7206.61 5571.00 4201.00 N 12.69 E 8006.61 6156.08 4746.59 N 14.34 E KOP 13 3/8" Csg Pt EOC 9 5/8" Csg Pt Target A - Top Sterling Target B - Base Beluga TD - 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 100.00 100.00 O.OON O.OOE 20" Conductor 0.00 0.00 O.OON O.OOE 895,00 891.16 53.25N 0.16E 13 3/8" Csg Pt 0.00 0.00 O.OON O.OOE 3000.00 2586.32 1236.88N 3.74E 9 5/8" Csg Pt 0.00 0.00 O,OON O.OOE 8006.61 6156.08 4746.59N 14.34E 7" Csg Pt Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised 44-36 #2 Revised not specified 5571.00 4201.00N 12.69E 24-Jan-93 44-36 Revised not specified 4990.00 3640.00N 11.00E 24-Jan-93 ALL data is in feet unless otherwise stated Coordinates from slot ~44-36 and TVD from wellhead (51.00 Ft above mean sea level Bottom hole distance is 4746.61 on azimuth 0.17 degrees from wellhead. Total Dogleg for wellpath is 46.99 degrees. Vertical section is from wellhead on azimuth 0.17 degrees. ........ Declination is 23.68 degrees Convergence is -0.69 degrees. Calculation uses the minin~Jm curvature method. Presented by Eastman Teleco UNOCAL Ivan River 44-36 slot #44-36 Ivan River Field Cook Inlet, Alaska CLEARANCE REPORT by Eastman Teleco Your ref : 44-36 Version #3 Our ref : prop672 License : Date printed : 2-Feb-93 Date created : 22-Jan-93 Last revised : 2-Feb-93 Field is centred on 360387.836,2645652.913,999.00000,N Structure is centred on 360387.836,2645652.913,999.00000,N Slot location is n61 14 27.606,w150 47 48.844 Slot Grid coordinates are N 2646404.221, E 359619.950 Slot local coordinates are ?42.00 N 777.00 W Reference North is True North Main calculation performed with 3-D minimum distance method Object wetlpath PGMS <O-5000'>,,44-1,Ivan River MSS <O-11288'>,,23-12,Ivan River PMSS <O-9170'>,,41-1,Ivan River PGMS <O-11400'>,,13-31,Ivan River MSS <O-10958'>,,14-31,Ivan River Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 10-Sep-92 139.0 400.0 400.0 lO-Nov-92 118.2 220.0 220.0 16-Jan-93 46.9 433.3 433.3 21-Jan-93 104.0 0.0 8006.6 1-Feb-93 21.2 533.3 533.3 UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 1 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object wellpath : PGMS <0-5000'>~44-11Ivan River Horiz Min'm TCy[ M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 0.0N O.OE 0.0 0.0 81.0S 113.0E 125.6 139.0 139.0 100.0 100.0 O.ON O.OE 99.8 99.8 81.1S 113.0E 125.7 139.1 139.1 200.0 200.0 O.ON O.OE 199.9 199.9 81.4S 112.9E 125.8 139.2 139.2 300.0 300.0 O.ON O.OE 300.1 300.1 81.6S 112.7E 125.9 139.1 139.1 400.0 400.0 O.ON O.OE 400.2 400.2 81.7S 112.4E 126.0 139.0 139.0 500.0 500.0 2.2N O.OE 500.2 500.2 81.8S 112.2E 126.8 140.1 140.2 500.0 500.0 2.2N O.OE 500.2 500.2 81.8S 112.2E 126.8 140.1 140.2 600.0 599.7 8.7N O.OE 600.2 600.2 81.7S 111.9E 128.9 143.9 144.1 600.2 600.0 8.7N O.OE 600.4 600.4 81.7S 111.9E 128.9 143.9 144.1 700.0 699.1 19.6N 0.1E 699.6 699.6 81.6S 111.7E 132.2 150.7 151.2 700.9 700.0 19.7N 0.1E 700.4 700.4 81.6S 111.7E 132.2 150.7 151.3 800.0 798.0 34.8N 0.1E 798.3 798.3 81.6S 111.4E 136.3 161.0 162.3 802.0 800.0 35.2N 0.1E 800.3 800.3 81.6S 111.4E 136.4 161.3 162.6 900.0 896.0 54.3N 0.2E 896.5 896.5 81.6S 111.0E 140.8 175.4 177.9 904.0 900.0 55.2N 0.2E 900.5 900.5 81.6S 111.0E 141.0 176.1 178.6 1000.0 993.2 78.1N 0.2E 993.9 993.9 81.5S 110.6E 145.3 194.0 198.5 1007.1 1000.0 79.9N 0.2E 1000.8 1000.8 81.5S 110.6E 145.6 195.5 200.2 1100.0 1089.2 106.1N 0.3E 1089.7 1089.7 81.2S 110.5E 149.5 217.3 225.0 1111.4 1100.0 109.5N 0.3E 1100.6 1100.6 81.2S 110.5E 150.0 220.2 228.4 1200.0 1183.8 138.2N 0.4E 1184.5 1184.5 80.9S 110.6E 153.3 245.2 257.6 1217.2 1200.0 144.2N 0.4E 1200.6 1200.6 80.8S 110.6E 153.9 250.5 263.8 1300.0 1277.0 174.4N 0.SE 1278.1 1278.1 80.4S 110.7E 156.6 277.7 296.7 1324.9 1300.0 184.1N 0.6E 1301.1 1301.1 80.3S 110.7E 157.4 286.5 307.6 1400.0 1368.6 214.7N 0.6E 1369.1 1369.1 80.1S 110.7E 159.5 314.7 343.4 1434.8 1400.0 229.7N 0.TE 1400.6 1400.6 80.1S 110.7E 160.4 328.7 361.4 1500.0 1458.2 259.0N 0.SE 1458.0 1458.0 80.OS 110.8E 162.0 356.4 397.7 1547.3 1500.0 281.2N 0.8E 1499.7 1499.7 80.1S 110.8E 163.1 377.7 426.2 1600.0 1545.9 307.0N 0.9E 1545.8 1545.8 80.1S 110.9E 164.1 402.4 460.2 1663.0 1600.0 339.3N 1.0E 1599.9 1599.8 80.1S 110.9E 165.3 433.5 504.2 1700.0 1631.4 358.9N 1.1E 1631.6 1631.6 80.OS 111.0E 165.9 452.5 531.8 1782.3 1700.0 404.4N 1.2E 1700.3 1700.3 80.0S 111.0E 167.2 496.6 598.0 1800.0 1714.5 414.5N 1.2E 1714.5 1714.5 80.0S 111.0E 167.5 506.5 613.2 1900.0 1795.2 473.6N 1.4E 1795.1 1795.1 80.0S 111.0E 168.8 564.3 706.2 1906.1 1800.0 477.3N 1.4E 1800.0 1800.0 80.0S 111.0E 168.9 568.0 712.3 2000.0 1873.2 536.2N 1.6E 1873.2 1873.2 80.OS 111.0E 169.9 625.8 812.0 2035.3 1900.0 559.0N 1.7E 1900.0 1900.0 80.0S 111.0E 170.3 648.4 852.8 2100.0 1948.3 602.1N 1.8E 1949.0 1949.0 80.0S 111.0E 170.9 690.8 932.8 2171.1 2000.0 650.9N 2.0E 2000.7 2000.7 79.9S 111.0E 171.5 738.9 1029.2 2199.7 2020.4 671.1N 2.0E 2021.0 2021.0 79.9S 111.0E 171.7 758.8 1070.8 2312.3 2100.0 750.7N 2.3E 2099.9 2099.9 79.9S 111.0E 172.5 837.6 1185.0 2453.7 2200.0 850.6N 2.6E 2198.9 2198.9 80.0S 110.8E 173.4 936.9 1328.9 2500.0 2232.7 883.4N 2.7E 2231.1 2231.0 80.1S 110.8E 173.6 969.5 1376.1 2595.1 2300.0 950.6N 2.9E 2298.2 2298.2 80.2S 110.8E 174.0 1036.4 1473.2 2736.5 2400.0 1050.6N 3.2E 2397.6 2397.6 80.4S 110.8E 174.6 1136.1 1617.4 2877.9 2500.0 1150.6N 3.5E 2496.4 2496.4 80.7S 110.8E 175.0 1235.9 1761.0 3000.0 2586.3 1236.9N 3.7E 2578.8 2578.8 81.1S 110.6E 175.4 1322.3 1884.1 3019.3 2600.0 1250.6N 3.8E 2592.4 2592.4 81.2S 110.6E 175.4 1336.0 1903.6 3160.8 2700.0 1350.5N 4.1E 2690.5 2690.5 81.8S 110.4E 175.8 1436.3 2045.6 3302.2 2800.0 1450.5N 4.4E 2787.0 2787.0 82.6S 110.1E 176.0 1536.8 2187.2 3443.6 2900.0 1550.5N 4.7E 2883.3 2883.3 83.5S 109.6E 176.3 1637.5 2328.9 3500.0 2939.9 1590.4N 4.8E 2922.0 2922.0 83.9S 109.5E 176.4 1677.7 2385.5 All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 2 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object weLlpath : PGMS <O-5000,>,,44-1,Ivan River Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 3585.0 3000.0 1650.5N 5.0E 2981.1 2981.0 84.6S 109.2E 176.6 1738.3 3726.4 3100.0 1750.4N 5.3E 3080.5 3080.5 85.7S 108.7E 176.8 1839.1 3867.8 3200.0 1850.4N 5.6E 3177.0 3177.0 86.8S 108.2E 177.0 1940.0 4000.0 3293.5 1943.9N 5.9E 3268.9 3268.8 87.9S 107.8E 177.1 2034.5 4009.2 3300.0 1950.4N 5.9E 3275.3 3275.2 88.0S 107.8E 177.1 2041.1 4150.6 3400.0 2050.4N 6.2E 3375.5 3375.4 89.2S 107.5E 177.3 2142.1 4292.0 3500.0 2150.3N 6.5E 3475.5 3475.4 90.3S 107.2E 177.4 2243.0 4433.4 3600.0 2250.3N 6.8E 3575.3 3575.2 91.4S 107.0E 177.5 2344.0 4500.0 3647.1 2297.4N 6.9E 3624.5 3624.4 91.9S 106.9E 177.6 2391.5 4574.8 3700.0 2350.3N 7.1E 3681.0 3680.9 92.4S 106.9E 177.7 2444.8 4716.2 3800.0 2450.3N 7.4E 3785.7 3785.7 93.0S 106.8E 177.8 2545.3 4857.6 3900.0 2550.2N 7.7E 3886.9 3886.8 93.6S 106.7E 177.8 2645.7 4999.0 4000.0 2650.2N 8.0E 3990.7 3990.6 94.0S 106.7E 177.9 2746.0 5000.0 4000.7 2650.9N 8.0E 3991.4 3991.3 94.0S 106.7E 177.9 2746.7 5140.4 4100.0 2750.2N 8.3E 4091.9 4091.8 94.3S 106.7E 178.0 2846.2 5281.8 4200.0 2850.2N 8.6E 4193.3 4193.2 94.5S 106.6E 178.1 2946.3 5423.2 4300.0 2950.2N 8.9E 4296.1 4296.0 94.7S 106.6E 178.2 3046.4 5500.0 4354.3 3004.4N 9.1E 4350.2 4350.2 94.7S 106.7E 178.2 3100.7 5564.6 4400.0 3050.1N 9.2E 4395.9 4395.8 94.8S 106.8E 178.2 3146.4 5706.0 4500.0 3150.1N 9.5E 4495.2 4495.2 94.9S 106.9E 178.3 3246.5 5847.4 4600.0 3250.1N 9.8E 4593.4 4593.3 95.1S 107.0E 178.3 3346.6 5988.8 4700.0 3350.1N 10.1E 4692.9 4692.8 95.3S 107.1E 178.4 3446.8 6000.0 4707.9 3357.9N 10.1E 4700.8 4700.7 95.4S 107.1E 178.4 3454.7 6130.3 4800.0 3450.0N 10.4E 4801.6 4801.5 95.4S 107.3E 178.4 3546.7 6271.7 4900.0 3550.0N 10.7E 4908.6 4908.6 95.2S 107.6E 178.5 3646.5 6398.9 4990.0 3640.0N 11.0E 4998.8 4998.8 94.9S 108.0E 178.5 3736.2 6413.1 5000.0 3650.0N 11.0E 5000.0 4999.9 94.9S 108.0E 178.5 3746.2 6428.6 5011.0 3660.9N 11.1E 5000.0 4999.9 94.9S 108.0E 178.5 3757.1 6528.6 5081.9 3731.4N 11.3E 5000.0 4999.9 94.9S 108.0E 178.6 3828.4 6554.0 5100.0 3749.2N 11.3E 5000.0 4999.9 94.9S 108.0E 178.6 3846.7 6628.6 5153.2 3801.5N 11.5E 5000.0 4999.9 94.9S 108.0E 178.6 3900.7 6694.0 5200.0 3847.3N 11.6E 5000.0 4999.9 94.9S 108.0E 178.6 3948.5 6728.6 5224.8 3871.4N 11.7E 5000.0 4999.9 94.9S 108.0E 178.6 3973.9 6828.6 5296.6 3940.9N 11.9E 5000.0 4999.9 94.9S 108.0E 178.6 4047.9 6833.2 5300.0 3944.2N 11.9E 5000.0 4999.9 94.9S 108.0E 178.6 4051.4 6928.6 5368.8 4010.2N 12.1E 5000.0 4999.9 94.9S 108.0E 178.7 4122.8 6971.7 5400.0 4039.9N 12.2E 5000.0 4999.9 94.9S 108.0E 178.7 4155.3 7028.6 5441.2 4079.1N 12.3E 5000.0 4999.9 94.9S 108.0E 178.7 4198.4 7109.3 5500.0 4134.5N 12.5E 5000.0 4999.9 94.9S 108.0E 178.7 4260.0 7128.6 5514.0 4147.7N 12.5E 5000.0 4999.9 94.9S 108.0E 178.7 4274.7 7206.6 5571.0 4201.0N 12.7E 5000.0 4999.9 94.9S 108.0E 178.7 4334.8 7246.3 5600.0 4228.0N 12.8E 5000.0 4999.9 94.9S 108.0E 178.7 4365.5 7383.0 5700.0 4321.3N 13.0E 5000.0 4999.9 94.9S 108.0E 178.8 4472.4 7500.0 5785.6 4401.1N 13.3E 5000.0 4999.9 94.9S 108.0E 178.8 4565.1 7519.7 5800.0 4414.5N 13.3E 5000.0 4999.9 94.9S 108.0E 178.8 4580.9 7656.5 5900.0 4507.8N 13.6E 5000.0 4999.9 94.9S 108.0E 178.8 4690.9 7793.2 6000.0 4601.0N 13.9E 5000.0 4999.9 94.9S 108.0E 178.8 4802.2 7929.9 6100.0 4694.3N 14.2E 5000.0 4999.9 94.9S 108.0E 178.9 4914.8 8000.0 6151.2 4742.1N 14.3E 5000.0 4999.9 94.9S 108.0E 178.9 4973.0 8006.6 6156.1 4746.6N 14.3E 5000.0 4999.9 94.9S 108.0E 178.9 4978.5 TCy[ Dist 2470.6 2611.4 . All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean Vertica[ section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, ALaska CLEARANCE LISTING Page 3 Your ref : 44-36 Version #3 Last revised : 2-Feb-g3 Reference wellpath Object wellpath : MSS <O-11288'>,,23-12, Ivan River Horiz Min'm TCyL M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 45.0 50.0 71.0S 95.0E 126.8 128.7 - 100.0 100.0 O.ON O.OE 95.3 100.3 70.9S 94.8E 126.8 118.4 - 200.0 200.0 O.ON O.OE 195.0 200.0 70.6S 94.7E 126.7 118.2 118.2 300.0 300.0 O.ON O.OE 294.7 299.7 70.1S 95.3E 126.4 118.3 118.3 400.0 400.0 O.ON O.OE 394.3 399.3 69.4S 96.4E 125.7 118.8 118.8 500.0 500.0 2.2N O.OE 495.0 500.0 70.2S 96.0E 127.0 120.2 120.3 500.0 500.0 2.2N O.OE 495.1 500.0 70.2S 96.0E 127.0 120.2 120.3 600.0 599.7 8.7N O.OE 593.4 598.2 75.3S 92.2E 132.4 124.7 125.0 600.2 600.0 8.7N O.OE 593.7 598.4 75.4S 92.1E 132.4 124.7 125.1 700.0 699.1 19.6N 0.1E 691.9 696.0 84.6S 84.8E 140.9 134.4 135.5 700.9 700.0 19.7N 0.1E 692.8 696.8 84.7S 84.7E 141.0 134.5 135.6 800.0 798.0 34.8N 0.1E 786.1 789.0 95.9S 75.1E 150.2 150.9 154.7 802.0 800.0 35.2N 0,1E 788.1 790.9 96.1S 74.9E 150.3 151.4 155.2 900.0 896.0 54.3N 0.2E 878.8 880.0 109.05 63.7E 158.7 176.0 184.4 904.0 900.0 55.2N 0.2E 882.5 883.6 109.6S 63.2E 159.0 177.2 185.8 1000.0 993.2 78.1N 0.2E 970.7 969.9 122.8S 50.7E 165.9 208.4 224.1 1007.1 1000,0 79.9N 0.2E 977.1 976.2 123.7S 49.8E 166.3 210.9 227.3 1100.0 1089.2 106.1N 0.3E 1058.8 1056.0 136.1S 37.7E 171.2 247.3 275.7 1111.4 1100.0 109.5N 0.3E 1068.8 1065.8 137.7S 36.2E 171.8 252.1 282.5 1200.0 1183.8 138.2N 0.4E 1140.6 1135.6 149.6S 24.3E 175.2 292.8 342.8 1217.2 1200.0 144.2N 0.4E 1155.2 1149.7 152.2S 21.7E 175.9 301.3 356.1 1300.0 127-/.0 174.4N 0.SE 1218.1 1210.4 163.9S IO.OE 178.4 345.0 426.7 1324.9 1300.0 184.1N 0.6E 1234.1 1225.8 167.1S 7.0E 179.0 359.0 450.3 1400.0 1368.6 214.7N 0.6E 1288.6 1278.0 178.5S 3.7S4 180.6 403.5 529.3 1434.8 1400.0 229.7N 0.7E 1312.0 1300.3 183.6S 8.4W 181.2 425.2 570.3 1500.0 1458.2 259.0N 0.SE 1358.7 1344.8 194.2S 18.1W 182.4 467.5 654.4 1547.3 1500.0 281.2N 0.SE 1391.0 1375.4 201.6S 25.2~ 183.1 499.4 723.0 1600.0 1545.9 307.0N 0.9E 1425.1 1407.6 209.7S 33.0~ 183.8 536.0 813.5 1663.0 1600.0 339.3N 1.0E 1463.9 1444.1 219.0S 42.1~ 184.4 581.2 952.6 1700.0 1631.4 358.9N 1.1E 1483.7 1462.8 223.9S 46.9S4 184.7 608.6 1056.4 1782.3 1700.0 404.4N 1.2E 1531.0 1507.0 235.7S 58.6~ 185.3 671.2 1410.9 1800.0 1714.5 414.5N 1.2E 1541.9 1517.2 238.5S 61.4W 185.5 685.0 1503.1 1900.0 1795.2 473.6N 1.4E 1595.5 1567.2 252.7S 74.2~ 185.9 765.0 2113.1 1906.1 1800.0 477.3N 1.4E 1599.0 1570.5 253.7S 75.0~ 186.0 770.0 2153.6 2000.0 1873.2 536.2N 1.6E 1637.5 1606.4 264.4S 83.7S4 186.1 848.1 2882.4 2035.3 1900.0 559.0N 1.7E 1655.9 1623.6 269.6S 87.6~ 186.2 878.1 3170.2 2100.0 1948.3 602.1N 1.8E 1684.7 1650.6 278.0S 93.6~ 186.2 934.1 3640.8 2171.1 2000.0 650.9N 2.0E 1718.6 1682.2 288.0S 100.6W 186.2 996.6 4349.1 2199.7 2020.4 671.1N 2.0E 1731.7 1694.4 291.8S 103.3~ 186.2 1022.0 4755.1 2312.3 2100.0 750.7N 2.3E 1763.5 1724.0 301.3S 109.9S4 186.1 1122.8 5513.6 2453.7 2200.0 850.6N 2.6E 1811.0 1768.0 316.2S 120.0W 186.0 1250.2 6187.8 2500.0 2232.7 883.4N 2.7E 1827.2 1782.9 321.4S 123.6W 186.0 1292.2 6357.5 2595.1 2300.0 950.6N 2.9E 1875.7 1827.6 336.8S 134.0~ 186.1 1378.2 6755.9 2736.5 2400.0 1050.6N 3.2E 1927.0 1874.9 353.6S 144.9W 186.0 1506.5 7351.9 2877.9 2500.0 1150.6N 3.5E 1925.6 1873.6 353.1S 144.6~ 185.6 1635.6 7897.8 3000.0 2586.3 1236.9N 3.7E 1945.1 1891.2 360.1S 149.0W 185.5 1748.4 8257.1 3019.3 2600.0 1250.6N 3.8E 1952.3 1897.8 362.8S 150.714 185.5 1766.3 8310.4 3160.8 2700.0 1350.5N 4.1E 1994.8 1935.7 378.9S 161.0~ 185.4 1898.0 8628.3 3302.2 2800.0 1450.5N 4.4E 2001.4 1941.6 381.5S 162.7i4 185.2 2030.0 8881.5 3443.6 2900.0 1550.5N 4.7E 2048.6 1983.1 400.2S 174.9~ 185.2 2162.9 9116.5 3500.0 2939.9 1590.4N 4.8E 2039.6 1975.2 396.6S 172.5W 185.1 2215.9 '., All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco 9206.3 . UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 3585.0 3000.0 1650.5N 5.OR 3726.4 3100.0 1750.4N 5.3E 3867.8 3200.0 1850.4N 5.6E 4000.0 3293.5 1943.9N 5.9E 4009.2 3300.0 1950.4N 5.9E 4150.6 3400.0 2050.4N 6.2E 4292.0 3500.0 2150.3N 6.5E 4433.4 3600.0 2250.3N 6.8E 4500.0 3647.1 2297.4N 6.9E 4574.8 3700.0 2350.3N 7.1E 4716.2 3800.0 2450.3N 7.4E 4857.6 3900.0 2550.2N 7.7E 4999.0 4000.0 2650.2N 8.OR 5000.0 4000.7 2650.9N 8.0E 5140.4 4100.0 2750.2N 8.3E 5281.8 4200.0 2850.2N 8.6E 5423.2 4300.0 2950.2N 8.9E 5500.0 4354.3 3004.4N 9.1E 5564.6 4400.0 3050.1N 9.2E 5706.0 4500.0 3150.1N 9.5E 5847.4 4600.0 3250.1N 9.8E 5988.8 4700.0 3350.1N 10.1E 6000.0 4707.9 3357.9N 10.1E 6130.3 4800.0 3450.0N 10.4E 6271.7 4900.0 3550.0N 10.7E CLEARANCE LISTING Page 4 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object we[lpath : MSS <O-11288'>,,23-12,Ivan River Horiz Min'm M.D. T.V.D. Rect Coordinates Bearing Dist 2058.8 1992.1 404.4S 177.5W 185.1 2296.0 2105.7 2032.7 423.8S 190.6W 185.1 2430.0 2099.5 2027.4 421.2S 188.714 184.9 2563.8 2105.2 2032.2 423.6S 190.4~ 184.7 2689.7 2107.9 2034.6 424.8S 191.2~ 184.7 2698.4 2116.4 2041.8 428.4S 193.8W 184.6 2833.6 2166.8 2084.2 450.6S 209.4W 184.7 2969.2 2164.6 2082.4 449.7S 208.714 184.6 3104.7 2166.2 2083.8 450.4S 209.2~ 184.5 3168.8 2186.5 2100.7 459.5S 215.714 184.5 3240.7 2206.9 2117.6 468.7S 222.4W 184.5 3377.0 2225.9 2133.3 477.4S 228.6~ 184.5 3513.4 2223.2 2131.1 476.2S 227.8~ 184.3 3650.1 2264.6 2164.9 495.5S 241.8W 184.5 3651.4 2292.9 2187.6 509.0S 252.0~ 184.6 3787.8 2293.3 2187.9 509.2S 252.2W 184.4 3924.5 2327.2 2214.6 525.7S 265.0W 184.5 4062.7 2346.4 2229.4 535.2S 272.5~ 184.5 4138.0 2277.5 2175.3 501.6S 246.4~ 184.1 4198.8 2279.6 2176.9 502.6S 247.2W 184.0 4336.4 2311.1 2201.9 517.8S 258.8~ 184.1 4474.3 2310.2 2201.2 517.4S 258.5W 184.0 4612.2 2312.6 2203.1 518.5S 259.4~ 184.0 4623.1 2307.3 2199.0 516.0S 257.4W 183.9 4750.4 2336.8 2222.0 530.4S 268.714 183.9 4888.8 6398.9 4990.0 3640.0N 11.0E 2328.1 2215.3 526.1S 265.3~ 183.8 5013.2 6413.1 5000.0 3650.0N 11.0E 2330.9 2217.5 527.6S 266.4~ 183.8 5027.0 6428.6 5011.0 3660.9N 11.1E 2334.1 2219.9 529.1S 267.714 183.8 5042.2 6528.6 5081.9 3731.4N 11.3E 2384.6 2258.5 554.5S 288.1~ 184.0 5141.0 6554.0 5100.0 3749.2N 11.3E 2323.4 2211.6 523.8S 263.5~ 183.7 5165.0 6628.6 5153.2 3801.5N 11.5E 2338.5 2223.3 531.3S 269.4~ 183.7 5238.0 6694.0 5200.0 3847.3N 11.6E 2351.8 2233.6 538.0S 274.714 183.7 5302.0 6728.6 5224.8 3871.4N 11.7E 2430.3 2292.6 578.0S 307.4W 184.1 5338.2 6828.6 5296.6 3940.9N 11.9E 2341.6 2225.7 532.8S 270.6~ 183.6 5433.7 6833.2 5300.0 3944.2N 11.9E 2342.5 2226.4 533.3S 271.0W 183.6 5438.2 6928.6 5368.8 4010.2N 12.1E 2362.1 2241.5 543.1S 278.914 183.6 5531.4 6971.7 5400.0 4039.9N 12.2E 2329.7 2216.5 526.9S 266.0~ 183.5 5573.9 7028.6 5441.2 4079.1N 12.3E 2342.3 2226.3 533.2S 270.914 183.5 5629.3 7109.3 5500.0 4134.5N 12.5E 2358.9 2239.0 541.5S 277.6~ 183.5 5708.2 7128.6 5514.0 4147.7N 12.5E 2435.6 2296.5 580.7S 309.6W 183.9 5728.3 7206.6 5571.0 4201.0N 12.7E 2452.9 2309.3 589.8S 317.2~ 183.9 5805.1 7246.3 5600.0 4228.0N 12.8E 2387.6 2260.8 556.0S 289.4W 183.6 5842.0 7383.0 5700.0 4321.3N 13.0E 2381.7 2256.3 553.0S 286.914 183.5 5975.6 7500.0 5785.6 4401.1N 13.3E 2438.9 2299.0 582.5S 311.1W 183.7 6090.8 7519.7 5800.0 4414.5N 13.3E 2373.1 2249.8 548.7S 283.4~ 183.4 6109.4 7656.5 5900.0 4507.8N 13.6E 2400.3 2270.3 562.5S 294.714 183.5 6243.2 7793.2 6000.0 4601.0N 13.9E 2427.5 2290.6 576.6S 306.2~ 183.5 6377.3 7929.9 6100.0 4694.3N 14.2E 2415.6 2281.7 570.4S 301.1W 183.4 6511.2 8000.0 6151.2 4742.1N 14.3E 2389.5 2262.2 557.0S 290.1~ 183.3 6580.1 8006.6 6156.1 4746.6N 14.3E 2462.8 2316.5 595.05 321.5W 183.6 6586.9 TOy[ Dist 9337.6 9553.8 . . - . . . - . . . . - . . - . . . . Alt data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teteco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska CLEARANCE LISTING Page 5 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Reference wel[path Object wel[path : PMSS <O-9170'>,,41-1,Ivan River Horiz Min'm TCy[ M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.1 0.1 30.OS 40.OE 126.9 50.0 50.0 100.0 100.0 O.ON O.OE 100.4 100.4 30.3S 39.4E 127.6 49.7 49.7 200.0 200.0 O.ON O.OE 200.6 200.6 31.5S 36.9E 130.5 48.6 48.6 300.0 300.0 O.ON O.OE 300.4 300.3 32.9S 34.5E 133.6 47.6 47.6 400.0 400.0 O.ON O.OE 400.4 400.3 33.8S 32.5E 136.2 46.9 46.9 500.0 500.0 2.2N O.OE 500.3 500.2 34.8S 30.6E 140.5 48.0 48.0 500.0 500.0 2.2N O.OE 500.3 500.2 34.8S 30.6E 140.5 48.0 48.0 600.0 599.7 8.7N O.OE 599.8 599.6 36.0S 29.0E 147.1 53.3 53.5 600.2 600.0 8.7N O.OE 600.0 599.9 36.0S 29.0E 147.1 53.3 53.5 700.0 699.1 19.6N 0.1E 698.9 698.7 37.2S 27.6E 154.2 63.1 63.6 700.9 700.0 19.7N 0.1E 699.8 699.6 37.2S 27.6E 154.2 63.2 63.7 800.0 798.0 34.8N O.1E 797.5 797.3 38.5S 26.4E 160.2 77.9 79.1 802.0 800.0 35.2N 0.1E 799.5 799.4 38.5S 26.4E 160.3 78.2 79.4 900.0 896.0 54.3N 0.2E 895.7 895.5 39.6S 25.4E 165.0 97.3 99.6 904.0 900.0 55.2N 0.2E 899.6 899.5 39.7S 25.4E 165.1 98.2 100.6 1000.0 993.2 78.1N 0.2E 993.7 993.5 39.9S 24.7E 168.3 120.5 124.5 1007.1 1000.0 79.9N 0.2E 1000.5 1000.3 39.8S 24.6E 168.5 122.2 126.5 1100.0 1089.2 106.1N 0.3E 1088.5 1088.3 40.2S 23.9E 170.8 148.1 155.6 1111.4 1100.0 109.5N 0.3E 1099.3 1099.1 40.2S 23.8E 171.1 151.6 159.6 1200.0 1183.8 138.2N 0.4E 1181.1 1180.9 41.3S 23.3E 172.7 181.0 194.0 1217.2 1200.0 144.2N 0.4E 1197.1 1196.9 41.6S 23.2E 173.0 187.2 201.4 1300.0 1277.0 174.4N 0.SE 1272.2 1271.9 43.4S 22.7E 174.2 219.1 238.9 1324.9 1300.0 184.1N 0.6E 1295.6 1295.3 44.0S 22.5E 174.5 229.2 250.7 1400.0 1368.6 214.7N 0.6E 1364.9 1364.6 45.4S 21.5E 175.4 261.0 287.0 1434.8 1400.0 229.7N 0.TE 1398.4 1398.1 45.7S 21.1E 175.8 276.1 304.0 1500.0 1458.2 259.0N 0.SE 1461.9 1461.6 45.3S 20.8E 176.2 305.0 335.3 1547.3 1500.0 281.2N 0.SE 1511.2 1511.0 44.1S 21.1E 176.4 326.1 357.6 1600.0 1545.9 307.0N 0.9E 1568.5 1568.1 41.3S 21.8E 176.6 349.6 382.2 1663.0 1600.0 339.3N 1.0E 1636.4 1635.8 35.7S 22.9E 176.6 377.3 411.5 1700.0 1631.4 358.9N 1.1E 1675.0 1674.2 31.5S 23.6E 176.7 393.4 429.2 1782.3 1700.0 404.4N 1.2E 1765.1 1763.4 19.3S 25.3E 176.7 429.0 469.6 1800.0 1714.5 414.5N 1.2E 1786.3 1784.4 15.9S 25.8E 176.7 436.7 478.2 1900.0 1795.2 473.6N 1.4E 1884.7 1881.3 1.1N 27.2E 176.9 480.9 525.6 1906.1 1800.0 477.3N 1.4E 1890.2 1886.6 2.1N 27.2E 176.9 483.7 528.4 2000.0 1873.2 536.2N 1.6E 1998.3 1992.4 24.3N 27.8E 177.1 526.3 570.8 2035.3 1900.0 559.0N 1.7E 2038.0 2031.0 33.7N 27.8E 177.2 542.0 586.5 2100.0 1948.3 602.1N 1.8E 2121.9 2111.8 56.2N 27.0E 177.4 570.4 615.9 2171.1 2000.0 650.9N 2.0E 2212.5 2198.0 84.2N 26.0E 177.6 600.8 649.1 2199.7 2020.4 671.1N 2.0E 2247.2 2230.6 96.0N 25.9E 177.6 612.8 662.7 2312.3 2100.0 750.7N 2.3E 2372.7 2347.5 141.6N 28.0E 177.6 658.0 702.4 2453.7 2200.0 850.6N 2.6E 2532.6 2494.0 205.4N 32.6E 177.3 709.7 747.7 2500.0 2232.7 883.4N 2.7E 2588.1 2544.2 229.1N 34.7E 177.2 725.3 761.4 2595.1 2300.0 950.6N 2.9E 2698.4 2642.8 278.1N 39.0E 176.9 755.7 787.6 2736.5 2400.0 1050.6N 3.2E 2860.9 2786.3 354.4N 43.0E 176.7 797.1 824.5 2877.9 2500.0 1150.6N 3.5E 3019.7 2923.6 434.2N 45.9E 176.6 833.3 862.1 3000.0 2586.3 1236.9N 3.7E 3128.0 3017.2 488.6N 47.2E 176.7 864.6 893.0 3019.3 2600.0 1250.6N 3.8E 3146.7 3033.4 497.9N 47.7E 176.7 869.6 898.1 3160.8 2700.0 1350.5N 4.1E 3298.2 3163.8 574.9N 53.1E 176.4 905.1 933.6 3302.2 2800.0 1450.5N 4.4E 3444.8 3289.5 650.0N 57.8E 176.2 939.8 969.5 3443.6 2900.0 1550.5N 4.7E 3545.4 3376.1 701.2N 60.5E 176.2 975.2 999.8 3500.0 2939.9 1590.4N 4.8E 3655.2 3470.4 757.3N 62.7E 176.0 989.4 1011.8 All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea [eve[ Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco M.D. UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wettpath CLEARANCE LISTING Page 6 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object wettpath : PMSS <O-9170'>,,41-1,Ivan River Horiz Min'm TCy[ T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dis[ Dist 3585.0 3000.0 1650.5N 5.0E 3746.1 3546.9 806.5N 64.0E 176.0 1007.4 1029.4 3726.4 3100.0 1750.4N 5.3E 3888.5 3666.2 884.1N 66.1E 176.0 1036.7 1056.8 3867.8 3200.0 1850.4N 5.6E 4042.1 3794.1 969.1N 68.4E 175.9 1064.7 1081.9 4000.0 3293.5 1943.9N 5.9E 4189.1 3915.2 1052.6N 70.5E 175.8 1088.6 1103.9 4009.2 3300.0 1950.4N 5.9E 4203.0 3926.5 1060.6N 70.7E 175.8 1090.2 1105.4 4150.6 3400.0 2050.4N 6.2E 4351.0 4047.1 1146.4N 72.4E 175.8 1113.7 1128.2 4292.0 3500.0 2150.3N 6.5E 4494.9 4163.7 1230.6N 74.2E 175.8 1136.3 1152.5 4433.4 3600.0 2250.3N 6.8E 4621.3 4266.7 1303.9N 75.0E 175.9 1159.7 1179.6 4500.0 3647.1 2297.4N 6.9E 4680.8 4315.4 1338.1N 75.2E 175.9 1171.2 1193.5 4574.8 3700.0 2350.3N 7.1E 4745.0 4368.3 1374.4N 75.5E 176.0 1184.7 1210.2 4716.2 3800.0 2450.3N 7.4E 4857.5 4462.0 1436.9N 75.7E 176.1 1212.4 1245.0 4857.6 3900.0 2550.2N 7.7E 4970.9 4557.6 1497.9N 75.6E 176.3 1242.8 1282.6 4999.0 4000.0 2650.2N 8.0E 5077.7 4648.7 1553.5N 75.7E 176.5 1276.0 1320.1 5000.0 4000.7 2650.9N 8.0E 5091.3 4660.4 1560.4N 75.6E 176.4 1276.4 1320.4 5140.4 4100.0 2750.2N 8.3E 5200.0 4754.5 1614.8N 75.3E 176.6 1312.3 1361.7 5281.8 4200.0 2850.2N 8.6E 5342.0 4877.2 1686.4N 74.4E 176.8 1348.1 1403.2 5423.2 4300.0 2950.2N 8.9E 5448.1 4969.6 1738.5N 73.1E 177.0 1385.8 1443.9 5500.0 4354.3 3004.4N 9.1E 5506.5 5021.0 1766.2N 72.3E 177.1 1407.7 1466.3 5564.6 4400.0 3050.1N 9.2E 5572.2 5078.7 1797.4N 71.5E 177.2 1426.1 1485.9 5706.0 4500.0 3150.1N 9.5E 5716.6 5205.5 1866.6N 69.5E 177.3 1465.8 1528.3 5847.4 4600.0 3250.1N 9.8E 5856.5 5327.9 1934.2N 67.6E 177.5 1504.9 1570.0 5988.8 4700.0 3350.1N 10.1E 5970.9 5428.5 1988.7N 66.9E 177.6 1545.1 1612.0 6000.0 4707.9 3357.9N 10.1E 5981.5 5437.9 1993.7N 66.9E 177.6 1548.3 1615.3 6130.3 4800.0 3450.0N 10.4E 6111.8 5552.7 2055.4N 66.7E 177.7 1585.8 1654.0 6271.7 4900.0 3550.0N 10.7E 6253.6 5677.3 2123.0N 66.4E 177.8 1625.9 1696.7 6398.9 4990.0 3640.0N 11.0E 6372.2 5781.5 2179.6N 66.1E 177.8 1662.0 1736.0 6413.1 5000.0 3650.0N 11.0E 6385.7 5793.4 2186.0N 66.0E 177.8 1666.0 1740.1 6428.6 5011.0 3660,9N 11.1E 6400.6 5806.4 2193.1N 66.0E 177.8 1670.4 1744.6 6528.6 5081.9 3731.4N 11.3E 6494.5 5889.1 2237.8N 66.2E 177.9 1698.6 1773.2 6554.0 5100.0 3749.2N 11.3E 6520.2 5911.7 2250.0N 66.4E 177.9 1705.7 1780.4 6628.6 5153.2 3801.5N 11.5E 6594.9 5977.3 2285.7N 67.0E 177.9 1726.3 1801.4 6694.0 5200.0 3847.3N 11.6E 6643.6 6020.2 2308.9N 67.4E 177.9 1744.3 1819.8 6728.6 5224.8 3871.4N 11.7E 6676.8 6049.4 2324.5N 67.6E 177.9 1753.8 1829.4 6828.6 5296.6 3940.9N 11.9E 6767.1 6129.3 2366.8N 68.2E 178.0 1781.7 1856.9 6833.2 5300.0 3944.2N 11.9E 6771.6 6133.2 2368.9N 68.3E 178.0 1783.0 1858.2 6928.6 5368.8 4010.2N 12.1E 6858.7 6210.2 2409.5N 69.2E 178.0 1809.2 1884.3 6971.7 5400.0 4039.9N 12.2E 6897.1 6244.2 2427.4N 69.5E 178.0 1821.1 1896.1 7028.6 5441.2 4079.1N 12.3E 6948.7 6290.0 2451.3N 69.8E 178.0 1836.7 1911.6 7109.3 5500.0 4134.5N 12.5E 7027.5 6359.8 2487.7N 70.1E 178.0 1858.7 1933.4 7128.6 5514.0 4147.7N 12.5E 7046.0 6376.2 2496.2N 70.2E 178.0 1863.8 1938.6 7206.6 5571.0 4201.0N 12.7E 7114.6 6437.1 2528.0N 70.4E 178.0 1884.8 1959.5 7246.3 5600.0 4228.0N 12.8E 7152.0 6470.3 2545.1N 70.4E 178.0 1895.5 1971.1 7383.0 5700.0 4321.3N 13.0E 7286.2 6589.5 2606.9N 70.7E 178.1 1932.2 2011.7 7500.0 5785.6 4401.1N 13.3E 7386.0 6678.2 2652.5N 70.8E 178.1 1964.0 2047.2 7519.7 5800.0 4414.5N 13.3E 7405.0 6695.1 2661.2N 70.8E 178.1 1969.4 2053.2 7656.5 5900.0 4507.8N 13.6E 7529.1 6805.7 2717.4N 71.6E 178.1 2007.2 2095.1 7793.2 6000.0 4601.0N 13.9E 7657.8 6920.6 2775.5N 72.6E 178.2 2045.4 2138.1 7929.9 6100.0 4694.3N 14.2E 7772.9 7023.5 2827.0N 73.1E 178.2 2084.0 2181.0 8000.0 6151.2 4742.1N 14.3E 7834.5 7078.7 2854.2N 73.4E 178.2 2104.2 2202.8 8006.6 6156.1 4746.6N 14.3E 7840.8 7084.4 2857.0N 73.5E 178.2 2106.1 2204.9 Alt data is in feet un[ess otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea [eve[ Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. CalcuLation uses the minimum curvature method. Presented by Eastman Teteco M.D. UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference weltpath CLEARANCE LISTING Page 7 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object weltpath : PGMS <O-11400'>,,13-31,Ivan River Horiz Min'm TCyl T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.0 0.0 60.OS 85.0E 125.2 104.0 104.0 100.0 100.0 O.ON O.OE 99.4 99.4 61.2S 84.5E 125.9 104.4 104.4 200.0 200.0 O.ON O.OE 199.3 199.3 63.8S 83.4E 127.4 105.0 105.0 300.0 300.0 O.ON O.OE 299.7 299.6 65.8S 82.4E 128.6 105.5 105.5 400.0 400.0 O.ON O.OE 399.9 399.8 67.3S 81.5E 129.6 105.7 105.7 500.0 500.0 2.2N O.OE 499.9 499.8 68.5S 80.7E 131.2 107.2 107.3 500.0 500.0 2.2N O.OE 500.0 499.8 68.5S 80.7E 131.2 107.2 107.3 600.0 599.7 8.7N O.OE 599.7 599.6 69.6S 79.9E 134.4 111.8 112.0 600.2 600.0 8.7N O.OE 599.9 599.8 69.6S 79.9E 134.4 111.8 112.1 700.0 699.1 19.6N 0.1E 699.1 699.0 70.5S 79.1E 138.7 119.8 120.4 700.9 700.0 19.7N 0.1E 700.0 699.8 70.5S 79.1E 138.8 119.9 120.5 800.0 798.0 34.8N 0.1E 798.0 797.9 71.1S 78.4E 143.6 131.7 133.0 802.0 800.0 35.2N 0.1E 800.0 799.9 71.2S 78.3E 143.6 132.0 133.4 900.0 896.0 54.3N 0.2E 896.1 896.0 71.6S 77.7E 148.4 147.9 150.5 904.0 900.0 55.2N 0.2E 900.1 899.9 71.6S 77.7E 148.6 148.6 151.3 1000.0 993.2 78.1N 0.2E 996.0 995.9 71.2S 77.0E 152.8 167.9 171.7 1007.1 1000.0 79.9N 0.2E 1003.9 1003.8 71.1S 76.9E 153.1 169.4 173.3 1100.0 1089.2 106.1N 0.3E 1095.8 1095.7 68.7S 75.7E 156.6 190.5 196.2 1111.4 1100.0 109.5N 0.3E 1107.4 1107.2 68.3S 75.6E 157.1 193.2 199.2 1200.0 1183.8 138.2N 0.4E 1196.3 1196.0 64.5S 74.1E 160.0 216.0 223.3 1217.2 1200.0 144.2N 0.4E 1214.9 1214.6 63.4S 73.8E 160.5 220.6 227.9 1300.0 1277.0 174.4N 0.5E 1306.4 1305.7 55.1S 72.5E 162.6 242.2 249.1 1324.9 1300.0 184.1N 0.6E 1333.4 1332.5 51.6S 72.1E 163.1 248.5 255.1 1400.0 1368.6 214.7N 0.6E 1419.2 1417.0 37.5S 70.8E 164.5 266.3 272.1 1434.8 1400.0 229.7N 0.7E 1462.9 1459.9 28.6S 69.8E 165.0 274.0 279.1 1500.0 1458.2 259.0N 0.SE 1547.7 1541.8 7.2S 66.7E 166.1 286.6 289.2 1547.3 1500.0 281.2N 0.SE 1612.0 1602.5 13.8N 63.8E 166.8 293.2 295.2 1600.0 1545.9 307.0N 0.gE 1673.3 1659.5 36.3N 61.1E 167.5 299.7 301.9 1663.0 1600.0 339.3N 1.0E 1735.9 1717.3 60.ON 58.3E 168.4 308.2 311.7 1700.0 1631.4 358.9N 1.1E 1772.8 1751.4 74.0N 56.5E 169.0 314.1 318.1 1782.3 1700.0 404.4N 1.2E 1868.5 1839.1 111.9N 51.8E 170.2 327.8 331.0 1800.0 1714.5 414.5N 1.2E 1891.3 1859.7 121.7N 50.6E 170.4 330.5 333.4 1900.0 1795.2 473.6N 1.4E 2009.2 1963.8 176.8N 44.6E 171.7 344.0 346.8 1906.1 1800.0 477.3N 1.4E 2017.0 1970.5 180.7N 44.2E 171.8 344.8 347.6 2000.0 1873.2 536.2N 1.6E 2122.1 2061.0 234.0N 38.7E 173.0 357.8 360.0 2035.3 1900.0 559.0N 1.7E 2174.8 2105.0 262.7N 35.6E 173.5 362.0 363.0 2100.0 1948.3 602.1N 1.8E 2272.0 2182.2 321.3N 28.6E 174.6 366.4 366.6 2171.1 2000.0 650.9N 2.0E 2370.8 2255.1 387.3N 19.7E 176.1 367.3 367.3 2199.7 2020.4 671.1N 2.0E 2404.5 2279.2 410.7N 16.5E 176.8 367.4 367.4 2312.3 2100.0 750.7N 2.3E 2547.7 2376.8 514.4N 1.8E 180.1 364.0 364.8 2453.7 2200.0 850.6N 2.6E 2701.4 2472.2 634.0N 12.6W 184.0 348.2 350.5 2500.0 2232.7 883.4N 2.7E 2752.2 2503.2 674.0N 16.714 185.3 342.6 345.2 2595.1 2300.0 950.6N 2.9E 2846.5 2560.4 748.7N 23.1W 187.3 330.6 333.2 2736.5 2400.0 1050.6N 3.2E 2987.5 2645.7 860.9N 28.4W 189.5 312.0 314.8 2877.9 2500.0 1150.6N 3.5E 3126.7 2731.1 970.8N 30.2~ 190.6 294.7 297.0 3000.0 2586.3 1236.9N 3.7E 3244.2 2803.4 1063.3N 34.5W 192.4 280.6 282.3 3019.3 2600.0 1250.6N 3.8E 3263.2 2815.1 1078.2N 35.6~ 192.8 278.4 280.1 3160.8 2700.0 1350.5N 4.1E 3401.1 2900.8 1186.0N 43.6W 196.2 263.9 265.1 3302.2 2800.0 1450.5N 4.4E 3539.2 2987.8 1293.0N 52.1W 199.7 251.5 252.4 3443.6 2900.0 1550.5N 4.7E 3678.7 3075.3 1401.2N 61.2W 203.8 239.5 240.2 3500.0 2939.9 1590.4N 4.8E 3733.7 3110.1 1443.5N 64.9W 205.4 235.4 236.0 All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference weltpath CLEARANCE LISTING Page 8 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object wel[path : PGMS <O-11400'>,,13-31,Ivan River Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 3585.0 3000.0 1650.5N 5.0E 3816.5 3162.9 1507.1N 70.714 207.8 229.8 3726.4 3100.0 1750.4N 5.3E 3955.5 3252.1 1613.2N 81.1W 212.2 222.4 3867.8 3200.0 1850.4N 5.6E 4094.8 3342.1 1719.0N 91.7~/ 216.5 216.6 4000.0 3293.5 1943.9N 5.9E 4225.7 3426.9 1818.1N 102.1W 220.6 212.8 4009.2 3300.0 1950.4N 5.9E 4234.7 3432.8 1824.9N 102.8~ 220.9 212.6 4150.6 3400.0 2050.4N 6.2E 4375.3 3524.2 1931.2N 114.1W 225.3 210.0 4292.0 3500.0 2150.3N 6.5E 4516.3 3615.4 2038.1N 125.6~ 229.6 208.3 4433.4 3600.0 2250.3N 6.8E 4657.4 3706.1 2145.5N 137.0W 233.9 207.2 4500.0 3647.1 2297.4N 6.9E 4723.7 3748.7 2196.0N 142.4W 235.8 207.2 4574.8 3700.0 2350.3N 7.1E 4798.0 3796.3 2252.7N 148.5~ 237.9 207.4 4716.2 3800.0 2450.3N 7.4E 4938.3 3886.1 2360.0N 160.1~ 241.7 208.9 4857.6 3900.0 2550.2N 7.7E 5078.8 3975.8 2467.4N 171.9W 245.2 211.8 4999.0 4000.0 2650.2N 8.0E 5218.7 4064.9 2574.6N 183.8W 248.5 216.2 5000.0 4000.7 2650.9N 8.0E 5219.6 4065.5 2575.3N 183.914 248.5 216.2 5140.4 4100.0 2750.2N 8.3E 5358.5 4154.0 2681.7N 196.0~ 251.4 222.2 5281.8 4200.0 2850.2N 8.6E 5498.6 4243.5 2788.8N 208.4~ 254.2 229.6 5423.2 4300.0 2950.2N 8.9E 5638.6 4332.9 2895.8N 220.8W 256.7 238.3 5500.0 4354.3 3004.4N 9.1E 5714.7 4381.6 2953.8N 227.6~ 257.9 243.5 5564.6 4400.0 3050.1N 9.2E 5778.7 4422.6 3002.6N 233.3~ 258.9 248.2 5706.0 4500.0 3150.1N 9.5E 5918.6 4512.2 3109.4N 245.9W 260.9 258.9 5847.4 4600.0 3250.1N 9.8E 6058.5 4601.8 3216.0N 258.714 262.8 270.7 5988.8 4700.0 3350.1N 10.1E 6199.1 4691.8 3323.2N 271.6~ 264.6 283.1 6000.0 4707.9 3357.9N 10.1E 6210.0 4698.8 3331.5N 272.6~ 264.7 284.1 6130.3 4800.0 3450.0N 10.4E 6338.6 4781.4 3429.5N 284.4~ 266.0 296.2 6271.7 4900.0 3550.0N 10.7E 6477.8 4870.9 3535.3N 297.6~ 267.3 310.1 6398.9 4990.0 3640.0N 11.0E 6602.1 4950.7 3629.7N 310.1~ 268.2 323.7 6413.1 5000.0 3650.0N 11.0E 6616.1 4959.7 3640.4N 311.6W 268.3 325.2 6428.6 5011.0 3660.9N 11.1E 6631.2 4969.4 3651.9N 313.1W 268.4 327.0 6528.6 5081.9 3731.4N 11.3E 6730.0 5032.6 3727.1N 323.3W 269.3 338.3 6554.0 5100.0 3749.2N 11.3E 6755.2 5048.7 3746.2N 326.0W 269.5 341.2 6628.6 5153.2 3801.5N 11.5E 6831.1 5097.4 3803.9N 333.8~ 270.4 349.8 6694.0 5200.0 3847.3N 11.6E 6906.4 5144.8 3862.1N 340.1W 272.4 356.4 6728.6 5224.8 3871.4N 11.7E 6949.3 5171.3 3895.8N 342.2W 274.0 358.8 6828.6 5296.6 3940.9N 11.9E 7064.9 5242.3 3987.0N 343.714 277.4 362.6 6833.2 5300.0 3944.2N 11.9E 7069.5 5245.1 3990.6N 343.6~ 277.4 362.8 6928.6 5368.8 4010.2N 12.1E 7182.9 5315.0 4079.9N 339.9W 281.2 362.9 6971.7 5400.0 4039.9N 12.2E 7233.3 5346.3 4119.1N 336.2W 282.8 361.4 7028.6 5441.2 4079.1N 12.3E 7297.3 5386.5 4168.6N 330.5~ 284.6 358.5 7109.3 5500.0 4134.5N 12.5E 7397.4 5450.1 4244.8N 317.4W 288.5 351.4 7128.6 5514.0 4147.7N 12.5E 7418.4 5463.4 4260.7N 314.0W 289.1 349.2 7206.6 5571.0 4201.0N 12.7E 7507.6 5519.5 4327.9N 297.3~ 292.3 338.9 7246.3 5600.0 4228.0N 12.8E 7553.1 5548.0 4362.0N 287.6~ 294.0 333.0 7383.0 5700.0 4321.3N 13.0E 7701.0 5640.5 4471.2N 250.1~ 299.7 308.6 7500.0 5785.6 4401.1N 13.3E 7828.5 5720.4 4562.6N 211.4W 305.7 284.3 7519.7 5800.0 4414.5N 13.3E 7848.6 5733.0 4576.8N 204.714 306.6 279.9 7656.5 5900.0 4507.8N 13.6E 7989.6 5820.7 4674.9N 154.1W 314.9 249.7 7793.2 6000.0 4601.0N 13.9E 8123.0 5904.1 4764.5N 100.9~ 324.9 221.6 7929.9 6100.0 4694.3N 14.2E 8254.5 5987.3 4849.4N 44.8~ 339.2 200.6 8000.0 6151.2 4742.1N 14.3E 8320.4 6029.5 4890.6N 15.3~ 348.7 194.3 8006.6 6156.1 4746.6N 14.3E 8326.3 6033.3 4894.2N 12.714 349.6 193.9 TOy[ Dist 230.2 222.6 216.7 212.8 212.6 210.0 208.3 207.2 207.2 207.4 208.9 211.9 216.3 216.4 222.4 230.0 238.8 244.1 248.8 259.8 271.7 284.2 285.2 297.6 311.7 325.7 327.3 329.0 340.5 343.5 351.7 357.3 359.3 362.7 362.8 363.0 361.6 359.1 353.3 351.4 342.1 336.7 314.2 291.0 286.7 256.1 225.9 202.2 194.8 194.3 All data is in feet un[ess otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco M.D. UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wel[path CLEARANCE LISTING Page 9 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object wet[path : MSS <O-10958'>,,14-31,Ivan River Horiz Min'm T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 0.0 0.0 O.ON O.OE 515.5 515.4 11.8S 15.4E 127.5 515.8 100.0 100.0 O.ON O.OE 515.5 515.4 11.8S 15.4E 127.5 415.9 200.0 200.0 O.ON O.OE 515.5 515.4 11.8S 15.4E 127.5 316.0 300.0 300.0 O.ON O.OE 515.5 515.4 11.8S 15.4E 127.5 216.3 400.0 400.0 O.ON O.OE 515.5 515.4 11.8S 15.4E 127.5 117.0 500.0 500.0 2.2N O.OE 501.0 500.9 12.6S 15.6E 133.3 21.5 500.0 500.0 2.2N O.OE 501.0 501.0 12.6S 15.6E 133.3 21.5 600.0 599.7 8.7N O.OE 601.0 600.8 7.0S 14.8E 136.8 21.6 600.2 600.0 8.7N O.OE 601.3 601.1 7.05 14.8E 136.8 21.6 700.0 699.1 19.6N 0.1E 700.9 700.5 1.0S 13.6E 146.7 24.7 700.9 700.0 19.7N 0.1E 701.8 701.4 1.OS 13.6E 146.8 24.7 800.0 798.0 34.8N 0.1E 801.3 800.6 6.3N 13.6E 154.6 31.7 802.0 800.0 35.2N 0.1E 803.4 802.7 6.5N 13.6E 154.7 31.8 900.0 896.0 54.3N 0.2E 903.1 901.5 19.6N 14.4E 157.7 38.0 904.0 900.0 55.2N 0.2E 907.1 905.5 20.2N 14.4E 157.8 38.2 1000.0 993.2 78.1N 0.2E 1003.8 1000.8 36.9N 14.0E 161.4 44.1 1007.1 1000.0 79.9N 0.2E 1011.2 1008.0 38.2N 14.0E 161.7 44.6 1100.0 1089.2 106.1N 0.3E 1105.3 1100.2 57.0N 14.1E 164.3 52.2 1111.4 1100.0 109.5N 0.3E 1116.7 1111.3 59.4N 14.1E 164.6 53.1 1200.0 1183.8 138.2N 0.4E 1208.1 1199.8 82.4N 15.0E 165.3 59.8 TCyt Dist 21.5 21.5 21.6 21.6 24.7 24.8 31.8 31.9 38.0 38.3 44.2 44.7 52.4 53.3 59.9 1217.2 1200.0 144.2N 0.4E 1226.0 1217.0 87.5N 15.3E 165.3 60.9 1300.0 1277.0 174.4N 0.5E 1308.9 1296.2 111.9N 16.8E 165.4 67.4 1324.9 1300.0 184.1N 0.6E 1334.0 1320.1 119.5N 17.3E 165.4 69.7 1400.0 1368.6 214.7N 0.6E 1409.8 1392.2 143.0N 19.5E 165.3 77.9 1434.8 1400.0 229.7N 0.TE 1445.1 1425.5 154.3N 20.7E 165.1 82.0 1500.0 1458.2 259.0N 0.8E 1511.1 1487.6 176.5N 23.3E 164.7 90.3 1547.3 1500.0 281.2N 0.SE 1559.6 1533.1 193.4N 24.0E 165.2 96.7 1600.0 1545.9 307.0N 0.9E 1613.2 1583.1 212.5N 23.0E 166.8 104.0 1663.0 1600.0 339.3N 1.0E 1676.0 1641.6 235.4N 21.4E 168.9 113.7 1700.0 1631.4 358.9N 1.1E 1713.3 1676.2 249.4N 20.5E 170.0 119.9 61.1 67.7 70.1 78.4 82.7 91.1 97.6 105.1 115.2 121.7 1782.3 1700.0 404.4N 1.2E 1799.8 1755.5 283.6N 18.1E 172.0 134.0 1800.0 1714.5 414.5N 1.2E 1819.5 1773.4 291.9N 17.5E 172.4 136.9 1900.0 1795.2 473.6N 1.4E 1925.6 1868.0 339.9N 14.6E 174.4 152.8 1906.1 1800.0 477.3N 1.4E 1931.7 1873.3 342.8N 14.4E 174.5 153.7 2000.0 1873.2 536.2N 1.6E 2026.9 1956.3 389.4N 12.8E 175.7 169.1 135.8 138.7 154.5 155.4 171.8 2035.3 1900.0 559.0N 1.7E 2062.4 1987.2 407.0N 12.6E 175.9 175.6 2100.0 1948.3 602.1N 1.8E 2127.6 2043.6 439.8N 12.4E 176.3 188.5 2171.1 2000.0 650.9N 2.0E 2199.5 2105.4 476.4N 11.8E 176.8 204.2 2199.7 2020.4 671.1N 2.0E 2227.4 2129.3 490.8N 11.?E 176.9 210.8 2312.3 2100.0 750.7N 2.3E 2340.8 2225.8 550.5N 11.5E 177.4 236.6 2453.7 2200.0 850.6N 2.6E 2481.9 2344.9 626.1N 10.3E 178.0 267.4 2500.0 2232.7 883.4N 2.7E 2529.5 2384.7 652.2N 9.8E 178.2 276.8 2595.1 2300.0 950.6N 2.9E 2636.1 2472.4 712.7N 8.5E 178.6 293.9 2736.5 2400.0 1050.6N 3.2E 2787.8 2593.3 804.2N 5.4E 179.5 313.2 2877.9 2500.0 1150.6N 3.5E 2938.7 2710.3 899.5N 2.9E 180.1 327.5 178.8 192.7 209.5 216.7 242.6 273.0 281.8 297.4 315.1 328.8 3000.0 2586.3 1236.9N 3.7E 3065.1 2806.8 981.1N 0.gE 180.6 337.7 3019.3 2600.0 1250.6N 3.8E 3084.4 2821.4 993.7N 0.6E 180.7 339.1 3160.8 2700.0 1350.5N 4.1E 3225.8 2928.2 1086.2N 3.OW 181.5 349.3 3302.2 2800.0 1450.5N 4.4E 3366.0 3034.4 1177.7N 7.8W 182.6 359.9 3443.6 2900.0 1550.5N 4.7E 3503.3 3138.2 1267.3N 14.5W 183.9 370.6 338.6 340.0 350.2 360.9 372.1 3500.0 2939.9 1590.4N 4.8E 3553.9 3177.2 1299.6N 14.8~ 183.9 375.8 Att data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco 378.0 UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 10 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 M.D. T.V.D. Rect Coordinates Object wellpath : MSS <O-10958'>,,14-31,[van River Horiz Min'm M.D. T.V.D. Rect Coordinates Bearing Dist 3585.0 3000.0 1650.5N 5.0E 3631.2 3237.7 1347.6N 11.5W 183.1 385.4 3726.4 3100.0 1750.4N 5.3E 3765.4 3344.0 1428.8N 1.2W 181.2 403.7 3867.8 3200.0 1850.4N 5.6E 3900.4 3451.8 1509.4N 10.3E 179.2 423.9 4000.0 3293.5 1943.9N 5.9E 4030.0 3555.6 1586.0N 22.3E 177.4 443.9 4009.2 3300.0 1950.4N 5.9E 4039.0 3562.8 1591.3N 23.1E 177.2 445.3 4150.6 3400.0 2050.4N 6.2E 4176.3 3672.8 1672.3N 36.0E 175.5 467.2 4292.0 3500.0 2150.3N 6.5E 4313.6 3783.4 1752.8N 48.7E 173.9 490.1 4433.4 3600.0 2250.3N 6.8E 4453.1 3895.7 1834.4N 62.4E 172.4 513.4 4500.0 3647.1 2297.4N 6.9E 4518.4 3948.2 1872.6N 69.3E 171.6 524.4 4574.8 3700.0 2350.3N 7.1E 4591.1 4006.7 1915.1N 77.2E 170.8 537.0 4716.2 3800.0 2450.3N 7.4E 4731.0 4118.9 1996.9N 93.5E 169.2 560.9 4857.6 3900.0 2550.2N 7.7E 4872.3 4231.8 2080.1N 110.9E 167.6 584.6 4999.0 4000.0 2650.2N 8.0E 5010.2 4341.4 2161.9N 128.8E 166.1 608.0 5000.0 4000.7 2650.9N 8.0E 5011.1 4342.2 2162.4N 129.0E 166.1 608.1 5140.4 4100.0 2750.2N 8.3E 5130.4 4437.2 2231.8N 148.5E 164.9 634.1 5281.8 4200.0 2850.2N 8.6E 5256.9 4538.8 2302.8N 173.9E 163.2 664.6 5423.2 4300.0 2950.2N 8.9E 5385.7 4642.6 2374.3N 200.4E 161.6 696.9 5500.0 4354.3 3004.4N 9.1E 5460.5 4703.0 2415.5N 216.2E 160.6 715.0 5564.6 4400.0 3050.1N 9.2E 5533.1 4761.0 2456.2N 231.8E 159.4 729.8 5706.0 4500.0 3150.1N 9.5E 5710.0 4898.2 2560.4N 271.8E 156.0 758.3 5847.4 4600.0 3250.1N 9.8E 5859.4 5009.6 2653.3N 307.5E 153.5 782.6 5988.8 4700.0 3350.1N 10.1E 6002.4 5114.9 2743.6N 342.2E 151.3 806.3 6000.0 4707.9 3357.9N 10.1E 6015.4 5124.4 2751.9N 345.4E 151.0 808.2 6130.3 4800.0 3450.0N 10.4E 6149.7 5221.4 2838.2N 379.8E 148.9 829.6 6271.7 4900.0 3550.0N 10.7E 6291.1 5322.6 2930.2N 415.6E 146.8 852.5 6398.9 4990.0 3640.0N 11.0E 6416.0 5410.8 3012.3N 448.7E 145.1 873.3 6413.1 5000.0 3650.0N 11.0E 6428.3 5419.5 3020.4N 452.0E 145.0 875.6 6428.6 5011.0 3660.9N 11.1E 6443.3 5430.0 3030.2N 455.9E 144.8 878.2 6528.6 5081.9 3731.4N 11.3E 6537.4 5496.6 3091.8N 480.8E 143.7 895.2 6554.0 5100.0 3749.2N 11.3E 6558.4 5511.6 3105.6N 486.4E 143.6 899.7 6628.6 5153.2 3801.5N 11.5E 6627.0 5560.6 3150.0N 504.3E 142.9 912.9 6694.0 5200.0 3847,3N 11.6E 6685.8 5602.9 3188.0N 519.7E 142.4 924.7 6728.6 5224.8 3871.4N 11.7E 6719.2 5626.9 3209.4N 528.4E 142.0 931.1 6828.6 5296.6 3940.9N 11.9E 6810.3 5692.9 3267.4N 552.2E 141.3 950.0 6833.2 5300.0 3944.2N 11.9E 6809.4 5692.3 3266.9N 552.0E 141.4 950.9 6928.6 5368.8 4010.2N 12.1E 6895.8 5755.3 3321.5N 574.8E 140.8 969.7 6971.7 5400.0 4039.9N 12.2E 6937.4 5785.7 3347.5N 585.8E 140.4 978.4 7028.6 5441.2 4079.1N 12.3E 6987.2 5822.4 3378.6N 599.0E 140.0 990.0 7109.3 5500.0 4134.5N 12.5E 7060.8 5876.8 3424.2N 618.3E 139.5 1006.7 7128.6 5514.0 4147.7N 12.5E 7079.3 5890.5 3435.7N 623.2E 139.4 1010.7 7206.6 5571.0 4201.0N 12.7E 7150.3 5943.4 3479.2N 641.7E 138.9 1027.2 7246.3 5600.0 4228.0N 12.8E 7184.2 5968.8 3500.0N 650.5E 138.8 1035.8 7383.0 5700.0 4321.3N 13.0E 7313.4 6066.1 3578.1N 683.6E 137.9 1065.8 7500.0 5785.6 4401.1N 13.3E 7424.1 6149.9 3644.7N 711.9E 137.3 1092.2 7519.7 5800.0 4414.5N 13.3E 7443.1 6164.3 3656.2N 716.8E 137.2 1096.6 7656.5 5900.0 4507.8N 13.6E 7574.1 6264.4 3734.2N 749.1E 136.4 1127.9 7793.2 6000.0 4601.0N 13.9E 7657.1 6328.9 3782.4N 769.5E 137.3 1161.5 7929.9 6100.0 4694.3N 14.2E 7724.8 6383.0 3818.6N 788.1E 138.5 1202.4 8000.0 6151.2 4742.1N 14.3E 7777.5 6425.7 3845.3N 803.4E 138.6 1225.7 8006.6 6156.1 4746.6N 14.3E 7783.7 6430.7 3848.4N 805.2E 138.6 1227.9 TCy[ Dist 388.3 407.7 428.8 449.2 450.6 473.3 496.9 520.6 532.0 544.9 569.0 592.6 618.3 618.5 649.4 682.8 716.3 732.6 745.0 769.8 793.9 817.5 819.4 840.7 864.2 886.7 889.2 892.0 910.4 915.1 929.5 942.5 949.5 970.3 971.3 991.6 1001.0 1013.4 1031.4 1035.7 1053.1 1062.3 1094.4 1124.4 1130.6 1178.7 1227.5 1276.8 1302.2 1304.6 All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea level Vertical section is from wellhead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL Ivan River ,44-36 Ivan River Field,Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 1 Your ref : 44-36 Version #3 Last revised : 2-Feb-93 Object wettpath : GMS <O-500'>,,14-31,Ivan River Horiz M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing 0.0 0.0 O.ON O.OE 0.0 0.0 15.0S 20.OE 126.9 100.0 100.0 O.ON O.OE 100.1 100.1 15.0S 19.6E 127.4 200.0 200.0 O.ON O.OE 200.1 200.1 15.0S 18.7E 128.8 300.0 300.0 O.ON O.OE 300.1 300.1 15.2S 17.8E 130.4 400.0 400.0 O.ON O.OE 400.2 400.2 15.1S 17.0E 131.7 500.0 500.0 2.2N O.OE 500.9 500.9 12.6S 15.6E 133.3 6398.9 4990.0 3640.0N 11.0E 500.0 499.9 12.6S 15.7E 179.9 7206.6 5571.0 4201.0N 12.7E 500.0 499.9 12.6S 15.7E 180.0 Min'm TCy[ Dist Dist 25.0 25.0 24.6 24.6 24.0 24.0 23.4 23.4 22.8 22.8 21.5 21.5 5788.1 - 6593.2 - All data is in feet unless otherwise stated Coordinates from slot #44-36 and TVD from wellhead (51.00 Ft above mean sea [eve[ Vertical section is from we[thead on azimuth 0.17 degrees. Declination is 23.68 degrees, Convergence is -0.69 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco Unocal Energy Resources ~dsion Unocal Corporation 909 West 9th Avenue, RO. Bo,, , 96247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7602/276-7600 Facsimile 263-7698 UNOEAL( Kevin A. Tabler Land Manager Alaska February 4, 1993 Mr. Russell Douglas Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Ivan River Unit State of Alaska Permit to Drill Ivan River #44-36 Dear Mr. Douglas: Pursuant to the provisions of 20 ACC 25.005, I have enclosed check number 11220 dated February 4, 1993 in the amount of $100.00 to cover the application fee for Permit to Drill Ivan River #44-36. On February 3, 1993, Unocal hand delivered our proposed application but neglected to enclose the permit application fee. Please place this check with same. KAT:nk V~ry truly yours, Land Manager Enclosure cc: George Buck Unocal North American ~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region February 3, 1993 Mr. Russell A. Douglas Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 IVAN RIVER WELL ~ 44-36 Dear Mr. Douglas: In an application dated December 22, 1992 Unocal requested an exception to 20 AAC 25.055 (a) (4) for a proposed bottom hole location to permit drilling of the Ivan River Unit 14-31 RD gas development well closer than 1500' to a section line and within 3000' of another well capable of producing from the same pool. The notice of hearing was published, no protests to the application were received, and the exception was granted on January 19, 1993 in conservation order No. 308. In a letter with an attached 10-403 form dated January 29, 1993, Unocal requested a change of approved procedure to reflect a new bottom hole location. Please disregard this letter and application. The new bottom hole location was selected in order to maximize recoverable reserves based on information gathered from the recently completed Ivan River Unit 44-1 well. However, as we have discussed, mechanical problems in the Ivan River Unit Well 14-31 have eliminated it as a redrill candidate. Unocal is therefore requesting approval to drill a new well, Ivan River 44-36, to a bottom hole location within the same quarter, quarter section. Unocal is also asking that the notice of public hearing be waived for economic reasons. We have an active drilling rig on location and placing this rig on standby would be costly to Unocal. The new bottom hole location will increase the recoverable reserves and there are no property owners adjacent to the Ivan River Unit that will be affected. The two proposed bottom hole locations are as follows: IRU 14-31RD 689' FSL, 576' FEL, Sec 1, T14N, R9W, SM IRU 44-36 209' FSL, 791' FEL, Sec 1, T14N, R9W, SM Attached is the permit to drill for the Ivan River Unit 44-36 development gas well. If you have any questions please call George Buck at 263-7685. Sincerely, G. Russell Schmidt Drilling Manager IRF44CMT.XLS State: Well: Field: State Permit 44-38 ivan River 93-22 E iqgineei': Work Sheet: Date: £emen! t/o&~me L?a/c~/lalbn,~ Casing Type Casing Size Casing Length Hole Diamete~ Cement-Sack., Cement- Yield Cement- Cubic ft Cement- Cubic R Cement- Sacks Cement- Yield Cement- Cubic ft Cement- Cubic ft Cemeni - Sacks -Inches - Feet -Inches ~I1 ~2 ~2 Il2 ~2 Cement- Yield :!:I3 Cement- Cubic ft Cer~ent- Cubic ft ~I3 Cement- Cubic ft /Vol Cement- Fill Factor Conductor 13.375 871.000 17.500 1,000,000 1.150 1,150.000 1,150.000 0.000 0.000 O. O00 0.000 1.t~.OO8 1.901 Surface 9.625 2,976.800 12.250 1,800.000 1.150 2,070.000 2,070.000 0.000 0.000 O. OOO 0.000 0.000 0.000 0.000 0.000 2..070.000 2.221 Liner 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 O. 008 :I:I:DIV/O! Casing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks Cement-Yield Cement- Cubic ftIll Cement- Cubic irt :1:I1 Cement- Sacks Il2 Cement- Yield ~2 Cement. - Cubic tt :1:12 Cement-Cubic ft:1:I2 Cement-Sacks 1:13 Cement- Yield Cement- Cubic t't ~3 Cement- Cubic tt Cement- Cubic It / Vol Cement-Interval It Top of Cement- Feet Intermediate 0.000 O. O00 O. OOO 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 0.00 0.00 O. O0 0.00 0.00 ~DIV/O! I~DIV/O! Intermediate tl2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. OO 0.00 0.00 IIDIV/O! I~DIV/O! Production 7.000 8,007.000 8.500 500.00 1.15 575.00 575.00 0.00 0.00 0.00 0.00 0.00 O. OO 0.00 0.00 575.00 4,534.46 3,472.5 Measured Deplh fRF44-~.XLS State: Alaska 19orough: Well: 44-36 Field: Ivan River SI. Perm ;93-22' Date 24'9]93 Engr: M. Minder Casir~g tr~terva! Inter-al Size Bottom Top Length la 13.375 891 0 871 2A 9,625 2586 0 2976 3A 7 6156 0 7983 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A' 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Descriptior~escriptionescription Tensior: Lbs Grade Thread Lbs 61 K-55 BTC 0 47 N-80 BTC 0 29 N-80 BTC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/~ psi/It 1B 9.6 0.499 0,399 2B 9,9 0,515 0.415 3B 10,1 0,525 0,425 4B 0.0 0.000 -0.100 5B 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0,0 0.000 -0.100 8B 0,0 0.000 -0,100 9B 0,0 0,000 -,0.100 10B 0.0 0,000 -0.100 Maximum Minimum Pressure Yield psi psi 8DF 4-4.7 3090 6.9 1829 6870 5.2 3231 8160 2L5 0 0 #DIV/O! 0 0 0 0 ~D~IO~ 0 0 ~D~ 0 0 ~DiV/0~ o o ~D~ 0 0 ~D~/O~ Tension Strength K,/. Lbs KJLbs 1C 53.13 ! 962 2C 139.872 1086 3C 231.507 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 TDF 18.11 7.76 676 2.92: 0 #DIV/0.~ 0 0 #D[V/0! 0 #DIVI0! 0 #DR//(}! 0 #DlV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 356 1540 4.330 1073 4750 4.4;2"8 2618 7020 2.682 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIVI0! 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIV/O! CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee (2) Loc ~/~_ ... _ ~_~./_-/.//~ ['2 thru [8] (3) Admi n ~,£< .~/~/z~-5 '[9 thru 13]' [10 & 13] (4) Casg ,~.~. ~"/~: ~- ~; - ~ $ [14 thru 22] [23 thru 28] (6) Other [29 thrum31] (7) Contact/;~ [32] (8) Addl ~.~.~'. . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13 14. 15. Company ~'~,/E.7C>C~--(/ Lease & We]] 9/~ 3~_ ~.~" _3~"z.~,.. ~,t~ ~j,~ ~-3~z~ Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is ~ll located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES 7 Does operator have a bond in force ................................... Is a conservation order needed ....................................... 29. 30. 31. 32. Is administrative approval needed ..................... , .............. DoesIS l eaSewell ntmberhave aappr°Prunique i atename ......................................... ~ nunber . Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor $ surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate-safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of eq~pment a.d_,equate ..... Are necessary diagrams & descriptions of divert~r & BOPE-attached Does BOPE have sufficient pressure rating -- test to Oo2y_~~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY $ STRAT IGRAPH IC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nunber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. NO REMARKS .... // o -t geology' DWJ__,~_____ RPC~Q · rev 12/92 jo/6.011 MTM/~engineering:RAD~J~" P ' ~-J~) ~"I~ BEW JP~~/ LG ' INITIAL GEOL IJ'Nt'T ON/OF'F POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM MERIDIA~I' SM TYPE' Exp/Dev Redrill Inj Rev 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. Tape Subfil~ 1 is type: LIS **** REEL HEADER **** 93/ 3/22 01 **** TAPE HEADER **** 01 Tape Subfile: 1 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 2 is type: LIS CN : UNOCAL WN : IRU 44-36 FN : IVAN RIVER UNIT COUN : KENAI STAT : ALASKA LIS COMMENT RECORD(s): REPEAT SECTION * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC AC 68 1 US/F 2 ACQ AC 68 1 3 CHT AC 68 1 LB 4 GR AC 68 1 GAPI 5 RB AC 68 1 DEG 6 SPD AC 68 1 F/MN 7 TTEN AC 68 1 LB 8 CAL CDL 68 1 IN 9 CORR CDL 68 1 G/C3 10 DEN CDL 68 1 G/C3 11 CN 2435 68 1 PU-L 12 CNC 2435 68 1 PU-S 13 CNCF 2435 68 1 PU-S 14 LSN 2435 68 1 CPS 15 SSN 2435 68 1 CPS 16 RFOC DIFL 68 1 OHMM 17 RILD DIFL 68 1 OHMM 18 RILM DIFL 68 1 OHMM 19 SP DIFL 68 1 MV 20 VILD DIFL 68 1 MV 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 06 969 49 6 4 4 69 189 02 1 4 4 61 094 30 1 4 4 95 558 30 1 4 4 87 374 67 0 4 4 34 168 75 6 4 4 59 047 24 5 4 4 52 326 75 5 4 4 98 211 23 1 4 4 98 211 23 1 4 4 84 023 70 1 4 4 83 368 34 1 4 4 27 515 24 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 04 522 10 6 80 DSB indicates: Data Record Length indicates: 1 FRAMES 12 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 126 Tape File Start Depth = 8132.000000 Tape File End Depth = 7756.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31606 datums Tape Subfile: 2 132 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS CN : UNOCAL WN : IRU 44-36 FN : IVAN RIVER UNIT COUN : KENAI STAT : ALASKA LIS COMMENT RECORD (s): MAIN PASS * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC AC 68 1 US/F 2 ACQ AC 68 1 3 CHT AC 68 1 LB 4 GR AC 68 1 GAPI 5 RB AC 68 1 DEG 6 SPD AC 68 1 F/MN 7 TTEN AC 68 1 LB 8 CAL CDL 68 1 IN 9 CORR CDL 68 1 G/C3 10 DEN CDL 68 1 G/C3 11 CN 2435 68 1 PU-L 12 CNC 2435 68 1 PU-S 13 CNCF 2435 68 1 PU-S 14 LSN 2435 68 1 CPS 15 SSN 2435 68 1 CPS 16 RFOC DIFL 68 1 OHM~ 17 RILD DIFL 68 1 OHMM 18 RILM DIFL 68 1 OHMM 19 SP DIFL 68 1 MV 20 VILD DIFL 68 1 MV 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 06 969 49 6 4 69 189 02 1 4 61 094 30 1 4 95 558 30 1 4 87 374 67 0 4 34 168 75 6 4 59 047 24 5 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 04 522 10 6 80 DSB indicates: Data Record Length indicates: 1 FRAMES 12 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1590 Tape File Start Depth = 8128.000000 Tape File End Depth = 3360.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 400534 datums Tape Subfile: 3 1596 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** 01 **** REEL TRAILER **** 93/ 3/22 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 22 MAR 93 10:20a Elapsed execution time = 41.30 seconds. SYSTEM RETURN CODE = 0